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200-056
MEMORANDUI State of Aleka Alaska Oil and Gas Conservation Commission TO: Jim Regg ..- 4(4I �3 DATE: March 17, 2013 P.I. Supervisor ! \ J SUBJECT: Plug & Abandonment FROM: Jeff Jones Spark 1A Petroleum Inspector CPAI Plug & Abandonment 2000560 - Section: 8 Township: 10N Range: 2E Meridian: UM Drilling Rig: Nabors 19E Rig Elevation: 115' Total Depth: 8522' MD - Lease No.: FEDA081802 Operator Rep.: Perry Klein Casing /Tubing Data: Casing Removal: Conductor: 16" " O.D. Shoe@ 115' MD - Casing Cut@ Feet Surface: 7.625" O.D. Shoe@ 2610' MD " Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: 5.5" O.D. Shoe@ 8512' MD - Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: 3.5 O.D. Tail@ 8082' MD Casing Cut@ Feet Plugging Data: Type Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement T.O.C. Depth Verified? above plug Test Casing stub XXN TTP 7145' MD - wire line tag - 10 PPG 2260 psi Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag 1 0 Annulus Balanced C.T. Tag SCANNED JUL L. 1 0 2013 Casing Stub Retainer No Surface March 17, 2013: I traveled to CPAI's (ConocoPhillips Alaska Inc.) Spark #1 exploratory well location (NPRA) to witness the wireline tag and pressure test of an abandonment plug. On my arrival Halliburton wire line ran in the hole with a 2.65" OD tool of approx. 500 Ib. assembly of weight bars, jars and sample catcher to tag a 15.8 PPG class G cement plug set in the tubing. Cement stringers were encoutered well above the expected TOC (top of cement) at 7245' MD. After several attempts to reach the expected plug depth, this tool was removed from the well and a smaller 2.25" OD assembly was run in the well and reached 7260' MD. Both tools returned samples of soft uncured cement contaminated with diesel. The plug was then successfully pressure tested to 2100 PSI. Summary: I witnessed the wireline tag high above expected TOC, soft unset diesel contaminated cement samples returned and a successful pressure test of an abandonment plug in the Spark #1A exploratory well. cc' Attachments: Distribution: -Well File (original) -Read File - DNR/DOG Rev.:01/26/09 by L.R.G. 2013 - 0317_ Plug _Verification_Spark- 1A jj.xlsx 4/4/2013 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 26, 2013 TO Jim p � 4 ' �I 3 SUBJECT: Mechanical Integrity Tests P.I. Supervisor ( CONOCOPHILLIPS ALASKA INC lA FROM: Jeff Jones SPARK IA Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J� NON - CONFIDENTIAL Comm Well Name SPARK 1A API Well Number 50 103 - 20313 - 01 - 00 Inspector Name: Jeff Jones Permit Number: 200 - 056 - Inspection Date: 3/17/2013 Insp Num: mitJJ130318172029 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA Type Inj N TVD 11f A IA 70 160 160 160 PTD 2000560 Type Test SPT Test psi 2000 • OA 230 , 240 240 240 Interval OTHER P/F P Tubing 600 , 2260 2140 2100 Notes: MIT - performed per Sundry 312 -468 to demonstrate P -A plug integrity. II Tuesday, March 26, 2013 Page 1 of 1 • • ARCO Spark #1A - Q ( D Zoo S P&A Schematic ev by TJB 05/01/2013 16" Conductor 3-W FMC Tubing Hanger wuth BPV installed (a115' RKBtoGL Base Permafrost — 600' MD 7 -5/8" x 5-W OA cemented to surface ind top job III 7 -5/8" casing cemented to surface 9-7/8" Hole with good returns Opened CMU @ 2725' SLM. Cement in tbg & IA to surface with SCANNED MAY 7 -5/8 ".29.7 #. L -80, top job. 01 2 013 BTC Mod. R3 Surface Casing I • 1' j8)p 2610' MD -RKB f6S @ 2734' MD Shoot perfs 7205' to 7210'- circulate 22 bbls cement down tbg into IA- est TOC @ 6140 +/- Bullhead 15 bbls to perfs- tagged TOC @ 7261' SLM. Set CIBP @ 7230' SLM f GLM with dummy @ 7852' MD f "X" nipple w/ 2.813" ID @ 7904' MD = 3 412" 9.3 ppf L -80 tbg to 7944' MD • • •• Baker FB -1 Packer @ 7944' MD 2 -7/8" 6.4 ppf L -80 tbg below packer 6-3/4" Hole — GLMs @ 8009'& 7980' MD f XN with XXN plug @ 8031' MD Tubing tail @ 8082' MD 5 -1/2 ", 15.5 #, L -80 BTC Mod, R3 Perforations from 8135' to 8150' MD @ 6spf Production Casing @ 8512' M 4 DD - a 77' of TCP Guns from PBTD of 8335' MD TD .1 8522' MD/ 8445' ND RECEIVED • STATE OF ALASKA • APR 19 2013 7 i ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND166CC la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned isi b Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory • El GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test Ell 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Abend.: April 1, 2013 • 200 - 056 /312 - 468 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 13, 2000• 50 103 - 20313 - 014 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1608' FNL, 2497' FWL, Sec. 8, T1ON, RO2E, UM • April 22, 2000 • Spark 1A • Top of Productive Horizon: 8. KB (ft above MSL): 88' RKB • 15. Field /Pool(s): 2306' FNL, 2502' FWL, Sec. 8, T1ON, R2E, UM GL (ft above MSL): 56' AMSL • NPRA' Total Depth: 9. Plug Back Depth (MD + TVD): 2306' FNL, 2502' FWL, Sec. 8, T1ON, R2E, UM 8335' MD / 8259' TVD • Exploration • 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 291158 y 5939589 Zone 4 • 8522' MD / 8445' TVD • ADL AKAA81802 - TPI: x - 291144 y - 5938892 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 291144 y - 5938892 Zone 4 none AK 5147 18. Directional Survey: Yes ❑ No Q- 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 600' MD / 600' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# B 33' 115' 33' 115' 20" 135 sx AS I 7.625" 29.7# L -80 2610' 2610' 9.875" 305 sx Class G, 240 sx Class G 5.5" 15.5# L -80 33' 5046' 33' 4978' 6.75" 110 sx LiteCRETE, 115 sx Class G 5.5" 15.5# L -80 5046' 8512' 8435' 6.75" included in above 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" x 2.875" 8082' 7944' MD / 7868' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ Noll DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED SCANNED APR 2 9 2013 e 0 L 22 bbls 15.8# Class G cement Scar - _. j°4--- ' 63 bbls of ASI cement 3 // P et ( e✓ -s 1510- '� • Ci..t Oft 33 8846 ` .2..CA 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 12 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RSDMS APR 2 2 � l Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE t Submit original only , A 1� /� te,77 x\* V 29. GEOLOGIC MARKERS (List all formations and It encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 600' 600' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / Contact: Tom Brassfield © 265 -6377 Email: Tom. J.Brassfield @conocophillios.com , } P Name G. L. Alvord Title: Alaska Drilling Manager � Signature Phone 265 - 6120 Date 't(!6 1 1 0 c 3 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 10/2012 • • Spark #1A ConocoPhillips Alaska Inc. Permanent plug and abandonment of Spark #1A report Sundry 312 -468 Well Status: Permit to Drill 200 -056 Spark #1A was drilled/completed on 4/29/2000. The well was tested and suspended in Property Designation 2001. The well was reentered in March of 2002 to puN the Panex gauges hung -off ki the p y g XN nipple at 8031' MD and resecured. The 3-1tr tubing is loaded with 10.2 ppg kill AKAA81802 weight brine with a 2000' diesel cap for freeze protection. A `XXN" tubing plug Is set in the NPRA Exploration `XN" nipple at 8031' MD. The 3-1/2" by 5 -1/2" annulus Is loaded with kill weight fkild from 7852' MD to 1400' MD with a diesel cap on top. The 7-5/8" x 5-1/2• annulus Is freeze protected to 2000' +/- MD. Bottom hole pressure in the Jurassic is estimated to be a 9.4# Equivalent Mud Weight. A 10.0 ppg kill weight brim should give us 200 psi+ overbalance. The Jurassic interval has been flow tested. The well wili be plugged and abandoned as • outlined below. Location Spark #1A (Exploratory Test) 1608' FNL, 2497' FWL, Sec 8, T10N, R2E, UM X=291,158 & Y=5,939,589 ASP4 NAD27 2306' FNL, 2502' F'WL, Sec 8, T10N UM ▪ 2306' FNL, 2502' FWL, Sec 8, T10N R2E, UM Current Status: • At time of report Spark #1A has been plugged and abandoned according to procedures with labeled seal welded cap on casing with 1/8" ported hole installed. Lou Grimaldi (AOGCC), and or Tom Zelenka (BLM) were intricate throughout this process if not witnessing most of procedures. Over burden will be laid in place within 24hrs of 1900 hrs 4 -1 -2013. • December 7 2012 • Sundry application drafted and sent to AOGCC for approval. Sundry received at AOGCC Dec 10, 2012. Sundry approved Dec 13 2012 by AOGCC and signed by Daniel T. Searmout, Jr. • March 22 2013 Wells Group performed TBG / IA plug system. 22 BBLS 15.8 PPG cement down tubing taking returns through tubing punches at 7,205' ELMD. Cement chased with 5 BBLS water, 25 BBLS of 10.5 brine / 25 BBLS diesel. • OA cement plug consisted of 33 BBLS AS1 cement for OA surface plug. • Note (surface plug pump program on OA was waived by Chuck Scheve) • March 23 2013 Wells Group Brush / flush post cement with CMU opened up for final TBG / IA cement plug. • March 24 2013 Pumped 63 BBLS of AS1 down tubing through sliding Sleeve up IA to open top tank. Good cement samples at surface. • March 26 2013 48 hour notice was sent by this office (Field Drilling Supervisor) to agencies as to abandonment initiation to commence on March 28 2013. • • • March 27 2013 Production tree removed in preparation for Well casing cut / dig operations. It illill"‘ ' in I I �. ..; a ; in .,,y,yyvk5 • • i Y ., "a x.. * ' 'I .:;'''' - '''' ''* 44 . — 4''' f ' .. i■ , , r ar i \ \ ., 'P` \\ w k • * ? ;; T r -„ r Y K," .' • * • March 28' 2013 Production tree / casing cut fo well cap procedures. Noted no visual cement in 5 X 7 5/8" Annulus. , \ t #� y A 144 z C . Y. A .45 ,i � � e• � ♦ � she °' ',t°�- • • • u j ,, wk o 0 ` ?0'1' 15 2$1U' • • March 30 2013 plan forward for Schlumberger to arrive in AM post Moose's Tooth abandonment cement program for Spark #1A 7 5/8" X 5'/2" annulus cement fill. • Perform "sounding" of 7 5/8" X 5'/2" Annulus for proper cement placement depths. w. l l f F z . a , r �°"� 0112612013 13 -07 .. ,;/,'`. i - VII • Second opinion performed... 1 I ' '41c,,41 ;.,'''E ": . 1 / ',. l j''.;:* � .. , . + ,, ,, i. , : :..,,, ,.... y i 1 L.,,, -' 1/4 -.- ' 7 44 . 01726/2013 13 ' • • Based on "sounding" placement of 120' .84" pipe was installed via welding of threadless joints so as to minimize collar upsets while driving .84" OD /'/" ID pipe into 7 5/8" X 5'/2" Annuli. Note: tagged hard at 120' several times. That's where it stayed! • • • March 31 2013 Schlumberger arrive for proper placement of TOC. ,A....N*Irlr ::,. ‘4. ;., .,,i: 1010,. qtr, ' '' rt � wv, ,..4-, 1 . ./rte �, ,1 h f k g # 9 �, . :, .41.1' *Nlet4;;:te.3 1,. .., ‘ ,t. :444:s 'dr' :*'., _ ° : '. 7 " littl `tea "'R A , evr- .., _ _ . „ , , . , , , , _. — . I I I if 0 0 - 7" : L -1 J J ) „......0 �Jl 2S120ta tE 27 v u *f " ■ ump ° ■ Begin ping AS1 cement po st confirmation of air movement through system to confirm circulation a bility. • • x -ilf uppor""" s..44b.r.10:41,Asit ,,. -:, ,,,',.."-i''' T -....'''.'.. ..;;:„..414., A y " x . � � � 'fie ti i , ,...: ,' ,„ . „„ .. .... ,, ... ‘,.... ..., , „ .. ,, ,...., . , :,.. „ .,••,..0.,„ ,,,, „., :.,,i, ..,,,, . ,....., l ,,. .,..... ,. .. „. , .„si ., „„.„. ,,,„. , ,...:. .„,.,,. , . 1,1,,nikela lle:ffl ,.,,,,,, . • At 8.5 BBLS away cement co at surface. t. " « sue ,., �: .fir 7 ,. . N ■ • • n x l J ■ ■ At 9 -9.5 BBLS of cement away pumps shut down monitor well for liquid level. �'t . -',;,• n' tF 3 i ‘,,,, c+ t x y 3 `<,` • Post Schlumberger pumping an additional 28 gal of cement was added to casing for of refill dropped level within two hours. ja I111 �� € yt : -1 , i ' I ., F 'R!ti F , Y • • • April 1, 2013 At 0230 hrs cement was confirmed hard with wells end cap seal welded in place by contract welder. ad^ , , '3 r k..61 2'3 • it C Y f',7"1 r ' v • • • r, 1 m W, •,c ; J : � k 01130!2013 02 2 • • 4f7;`4"7" . , • • April 1, 2013 At 1800 hrs confirmed green light for overburden to begin. t. o µR: • • . a ♦ 4r'' R i t • Lacking 15 yds of over to complete a 3' rise above tundra level for completion. Overburden to arrive 4-2-2013 and will complete project. We expect to have final environmental sign off on or about 4_5-2 013. T y ou for y our time, Field drilling Supervisor WSR - Well Service Report° • Page 1 of 1 Well Service Report Well IIJob Scope II CPAI Rep SPARK 1 lIDismantlement II Pittman, Russell Date Daily Work II Unit Number 3/24/2013 FRAC EQUIP Network If II Company II Unit Supervisor 10346729 SLB -DS GRANT, Rich -SLB - DS Initial & Final Field: ATIONAL PETROLEUM RESERVE Pressures: TBG & IA surface plug. Pumped 63 bbls AS1 cement down tubing through sliding 24 hr. sleeve up the IA to open top tank. Good cement smaples at surface. Wellhead Summary ready for removal. TBG & IA surface plug pumping waived by Chuck Sheve STARTTIME OPERATION 06:00 AM Travel to location. 08:30 AM PJSM. 09:00 AM Little Red and SLB Pumpers rig up. 10:45 AM Fluid pack and pressure test surface lines (3000 / 300). 11:15 AM Open swab and pump S/D down tbg and take returns up the IA to ensure good communication through sliding sleeve. Pump rate @a, 2 bpm @ 500 psi. 11:45 AM Pump 3 bbl F/W spacer and then 63 bbls of AS 1 cement down TBG taking returns up the IA. 12:10 PM Cement @ surface at 57 bbls. Continue pumping until good cment samples in chokehouse. 12:22 PM Switch to F/W and pump 1.5 bbls . 12:31 PM Pump offline. Shut in swab valve. 12:37 PM Evacuate surface lines of cement by flushing to open top tank. 02:07 PM Secure location and RDMO. Fluid Type To From Non- Note Well Well recoverable DIESEL, SLICK 18 Open Top FRESH WATER 200 TBG & IA (cement & wash up fluid) http: / /akapps.conocophillips. net /alaskawelleventquery/ worklog .aspx?ID= 7AD5E663409640... 4/3/2013 WSR - Well Service Report. • Page 1 of 1 Well Service Report Well IIJob Scope II CPAI Rep SPARK 1 IlDismantlement II Condio, John Date Pally Work I) Unit Number 3/23/2013 II II 768 Network # 11 Company II unit Supervisor 10346729 II HES 11 Galle, Brandon Initial & INITAL PRESSURES Final T/I /O= 0/0/0 FINAL Field: 'NATIONAL PETROLEUM RESERVE Pressures: PRESSURES= 0/0/0 24 hr. BRUSHED & OPENED CMU @ 2725' RKB, WELL READY FOR FINAL TBG Summary & IA CEMENT PLUG. STARTTIME OPERATION 11:00 AM TRAVEL FROM CD4 PAD TO SPARK 1A, 03:00 PM JSSM, INSPECT AREA, SPOT UNIT, R/U .125" & 1.50" STEM TS= RS,QC,5',QC,KJ,5',QC,KJ,5',QC,LSS,QC. 05:15 PM RIH w/ 2.89" BLB & 2.77" GUAGE RING, WENT TO 3000' SLM, P/U, MADE 30 PASSES THRU CMU @ 2717' SLM( 2734' RKB), CLEAR, POOH, COT. 06:15 PM RIH w/ 2.81" 42 BO & 2.77" GUAGE RING, OPENED CMU, POOH, TTL GOOD, CONFER w/ CWG REP, 07:15 PM PJSM, BEGIN R/D, SECURE WELL, INSPECT AREA, 09:00 PM TRAVEL TO ALPINE CAMP, DOWNLOAD CPU, TURN IN FILE, END TICKET. Fluid Type To From Non- Note Well Well recoverable http: / /akapps.conocophillips. net / alaskawelleventquery /worklog .aspx ?ID= 0502A352188A47... 4/3/2013 • WSR - Well Service Report Page 1 of 2 • Well Service Report Well °Job Scope II CPAI Rep II SPARK 1 IlDismantlement I Ferguson, Sid Date °Daily Work II Unit Number 3/22/2013 II II OTHER t N rk # Company Unit Supervisor Network ° p y II p 10346729 SLB -DS GRANT, Rich -SLB - DS Initial & . Final Field: NATIONAL PETROLEUM RESERVE Pressures: TGB & IA PLUG: PUMPED 22 BBLS OF CEMENT(15.8 CLASS G) DOWN TBG TAKING RETURNS THROUGH TBG PUNCHES @ 7205' ELM UP IA TO OPEN TOP TANK. CHASED CEMENT WITH 5 BBLS OF WATER, 25 24 hr. BBLS OF 10.5 BRINE AND 25 BBLS OF DIESEL. OA CEMENT PLUG: Summary PUMPED 50 BBLS OF FRESH WATER DOWN OA. PUMPED 33 BBLS OF AS1 CEMENT FOR OA SURFACE PLUG. WELL READY FOR SLICKLINE TO SHIFT OPEN CMU, IN PROGRESS. * *SURFACE PLUG PUMPING ON OA WAS WAIVED BY CHUCK SCHEVE** STARTTIME OPERATION 06:00 AM CEMENT CREW ROLLING OUT OF DEAD HORSE, LRS TRAVELING FROM ALPINE. WELL SUPPORT & TRUCKS ROLLING FROM KRU. 09:00 AM ARIVE ON LOCATION. INSPECTECT LOCATION. CONDUCT TGSM. SPOT UP EQUIP ON THE SMALL ICE PAD. RU SLB & LRS PUMPING UNITS. 11:30 AM CONDUCT PRE -JOB WITH ALL ON LOCATION. DISCUSS HAZZARDS AND JOB PROCEDURE. PT LINES & EQUIP TO 2500 PSI. SLB PUMPER, PUMP 5 BBLS OF WATER AHEAD, PUMP 20 BBLS OF 15.8 11:45 AM CLASS G CEMENT, CHASE WITH 5 BBLS OF WATER, TAKING RETURNS FROM IA TO OPEN TOP TANK. NOTE: RATE @ 2.75 BPM @ 1000 PSI. PUMP RESSURE WAS AT 200 PSI NEAR THE END OF THE WATER FLUSH. SWAP TO LRS, PUMP @ 2.5 BPM(PUMP PRESSURE AT 0.) CHOKE BACK IA 12:30 PM TO 600 PSI, 25 BBLS OF 10.5 BRINE, CHASED WITH 30 BBLS OF DIESEL, SHUT DOWN. WHP & FINALLY CATCH SOME PUMP PRESSURE NEAR END OF FLUSH. SHUT IN BOTH TBG & IA. SWAP REVERSE SKID TO PUMP DOWN OA. LRS PUMP 5 BBLS OF DIESEL TO ENSURE FLUID MOVEMENT. SWAP TO SLB, PUMP 50 BBLS OF WATER 0110 PM DOWN OA TO FLUSH. SWAP TO AS1 CEMENT, PUMP 33 BBLS. HAVE LRS PUSH A LITTLE DIESEL BACK TO THE WELL THE FLUSH THE OA VALVE. 02:30 PM WASH UP SLB TUBS.CONDUCT PJSM: RD SLB & LRS PUMPING UNITS. SUCK FLUID OUT OF THE RETURN TANK. RDMO. 03:30 PM TRAVEL BACK TO KRU. Fluid Type To From Non- Note Well Well recoverable WATER 60 50 DOWN OA. 10 DOWN TBG , CIRCULATED TO IA. http: / /akapps.conocophillips. net /alaskawelleventquery /worklog .aspx ?ID= CD665F8AF95C 4/3/2013 WSR - Well Service Report. • Page 1 of 1 Well Service Report Well IIJob Scope II CPAI Rep SPARK 1 °Dismantlement II Fama, Jake Date IlDaily Work II Unit Number 3/20/2013 II II 4863 Network # II Company II Unit Supervisor 10346729 0 HES -Eline II Galligan, Bill Initial & INITIAL T/I /O - 800/45/250 Final FINAL T/I /O - 400/45/250 Field: ATIONAL PETROLEUM RESERVE Pressures: TAG TOP OF CEMENT AT 7261', SET BAKER CIBP AT 7230', PERFORATE INTERVAL 7205 -7210' USING 2" HSC LOADED 4 SPF PHASED 0 DEG 24 br' ORIENTED TO LOW SIDE OF TUBING, CORRELATED TO TUBING Summary DETAIL RECORD DATED 28 APRIL 2000. CIRCULATED DIESEL AT 2 BPM A 1500 PSI, WELL READY FOR CEMENT PLUG # 2, IN PROGRESS. STARTTIME OPERATION 05:00 AM PREP FOR JOB, SYNC LAPTOP, CONVOY TO LOCATION 08:30 AM SPOT EQUIPMENT, INSPECT WELLHEAD, LAYOUT LINES, UNLOAD PCE BASKET, CHECK STRAY VOLTAGE 10:30 AM PJSM W/ BAKER HAND, PU LUBE, MU PCE/TOOLSTRING, CHECK FIRE, STAB ONTO WELLHEAD 11:30 AM PRESSURE TEST TO 3000 PSI 12:00 PM RIH W/ CH, SWIV, WB7, ROLL, WB5, CCL, 1 -11/16 SETTING TOOL, BAKER 2.77 CIBP, OAL: 31'x2.77', TO 7261' 01:30 PM CORRELATE TO TUBING DETAIL RECORD DATED 28 APRIL 2000 , SET CIBP AT 7230', CCL TO MID- ELEMENT: 9.5', STOP DEPTH: 7220.5', POOH BUMP UP, BLEED PRESSURE, BREAK PCE AT QUICK TEST SUB, SWAP 03:00 PM TOOLS, CHECK FIRE, ARM GUN, STAB ONTO WELL, PT QUICK TEST SUB TO 3000 PSI 03:45 PM RIH W/ CH, SWIV, WB7, ROLL, WB5, CCL, 2" HSC 4 SPF 0 DEG PHASING ORIENTED TO LOW SIDE OF TUBING, TO 7212' CORRELATE TO TUBING DETAIL RECORD DATED 28 APRIL 2000, 04:15 PM PRESSURE UP TUBING TO 1500 PSI, PERFORATE INTERVAL 7205'- 7210', CCL TO TOP SHOT: 3.8', STOP DEPTH: 7201.2', TUBING PRESSURE IMMEDIATELY FELL TO 1150 PSI/IA TO 450 PSI, POOH 05:00 PM BUMP UP, BLEED PRESSURE, BREAK DOWN TOOLSTRING, BREAK DOWN PCE STACK, LAY DOWN LUBE, LOAD PCE BASKET, INSPECT LOCATION 06:15 PM CONVOY BACK TO SHOP, BLOW DOWN LINES, SYNC LAPTOP Fluid Type To From Non- Note Well Well recoverable DIESEL 15 Pumped diesel thru tbg punches http: / /akapps.conocophillips. net / alaskawelleventquery /worklog .aspx ?ID= 31E2CBFBFF0D4... 4/3/2013 WSR - Well Service Report • Page 1 of 1 Well Service Report Well IIJob Scope 11 CPA" Rep SPARK 1 IlDismantlement II Klein, Perry Date (IDaily Work II Unit Number 3/17/2013 it II 764 Network # II Company II Unit Supervisor 10346729 II HES II POTTER Initial & 1NITIAL T/UO= 700/100/240 Final FINAL T/I /0= 700/100/240 Field: ATIONAL PETROLEUM RESERVE Pressures: RAN 2.5" BAILER TAG @ 7256' SLM RECOVER CEMENT & CHUNK OF 24 hr. FOAM BALL , RAN 2.25" BAILER SIT DOWN 7260' SLM WORK DOWN TO Summary 7262' RECOVER CEMENT. PERFORMED STATE WITNESSED MITT TO 2260 PSI - PASSED (AOGCC WITNESS JEFF JONES) STARTTIME OPERATION 01:00 PM TRAVEL FROM ALPINE 03:00 PM CONTACT DSO, ARRIVE & INSPECT LOCATION, TGSM, RU HES, (.125 WIRE) 2.125" STEM, TS = RS, QC, 6',QC,KJ,5',QC,OJ,QC,KJ,LSS,QC. (OAL 331") PT RIH W/ 2.65" CENT & 2.5" X 5' BAILER, TOOLS FALL FREELY TO 6570' 05:00 PM SLM WORK PAST TIGHT SPOT SIT DOWN @ 7245' SLM WORK DOWN TO 7256' SLM UNABLE TO WORK PAST TIGHT SPOT JAR DOWN FOR 15 MIN POOH OOH RECOVER BAILER FULL OF CEMENT & FOAM BALL 06:30 PM PT RIH W/ 2.25" x 5' BAILER, TOOLS FALL FREELY TO 7260' SLM JAR DOWN WORK TOOLS DOWN TO 7262' SLM POOH OOH RECOVER CEMENT RIG DOWN SECURE WELL, PJSM, TRAVEL TO MIDWAY ICE PAD STAGE 08:00 PM EQUIPMENT. LRS PERFORM STATE WITNESSED (JEFF JONES) MITT. PRE T/I /O/ = 60/70/230, PUMPED 0.5 BBLS DIESEL, INITIAL T/I /O = 2260/160/240, 15 MIN T/I /O= 2140/160/240, 30 MIN T/I /0= 2100/160/240 - PASSED. 09:00 PM TRAVEL TO CAMP, TURN IN PAPERWORK, CPU & FILES. END TICKET Fluid Type To From Non- Note Well Well recoverable http: / /akapps.conocophillips. net/ alaskawelleventquery /worklog.aspx ?ID= 10755047B3F 142... 4/3/2013 WSR - Well Service Report • • Page 1 of 1 Well Service Report Well (!Job Scope II CPAI Rep SPARK 1 !!Dismantlement II Klein, Perry Date liDaily Work II Unit Number • 3/16/2013 II II OTHER Network # II Company II Unit Supervisor ( 10346729 1 SLB -DS 11 ANDERSON Initial & Initial T/I /O = 2100 /SI/SI Final Final T/I /O = 600 /SI /SI Field: NATIONAL PETROLEUM RESERVE Pressures: 24 hr. Bullhead 15 bbls of 15.8 class G cement down the tubing with 5 bbls of water and Summary 49 bbls diesel for a total displacement of 69 bbls. Theoretical TOC at 7930' MD. STARTTI ME OPERATION 07:00 AM Pick up well file and drive to location Pre job with SLB cementers, LRS Hot oilers, and ASRC support truck operators. 09:00 AM Location very small for the amount of equipment needed, safety concerns discussed. Spot equipment and rig up. 12:00 PM Pre job safety / Ops meeting before going down hole. Prime up SLB 361 cementer with water. LRS flood treating iron with diesel and PT to 2600 psi W/ LRS pump. 12:30 PM Open up to tubing, pressure 2100 psi. Pump 25 bbls diesel to the tubing slowly increasing rate from 1 to 1.7 BPM at 2000 psi. S/D and block in LRS. Open up SLB, mix and pump 10 bbls 11.2 ppg Mudpush spacer to the tubing at 2 01:00 PM BPM and 1650 psi. Mix and pump 15.2 bbls 15.8 G unisluryto the tubing at 2 BPM and 500 psi. S/D pressure 150 psi. Pump 4.9 BBLs water to the tubing to clear surface lines S/D and block in cement pump. LRS pump 5 bbls diesel to the tubing to sweep H2O from surface lines. S/D to realign R 59.1 bbls diesel for a total cement displacement to launch foam pig. LRS pump p pg p p lacement 01:30 PM of 69 bbls. Treated at 2 bpm and 150 psi for the first 40 bbls. Reduced rate to 1 BPM and pressure climbed to 1000 through final displacement. S/D and monitored pressure. S/I well trapping 600 psi on the tubing. 02:00 PM Wash up Cementer. Rig down and move off location. 03:30 PM Drive back to office. Fluid Type To From Non- Note Well Well recoverable DIESEL 89 25 http: / /akapps.conocophillips. net / alaskawelleventquery/ worklog .aspx7ID= 659B396D4E3F4... 3/18/2013 WSR - Well Service Report • Page 1 of 1 Well Service Report Well IIJob Scope II CPAI Rep SPARK 1 IITemporary NETWORK Only 0 Rick Overstreet Date IlDaily Work II Unit Number 3/12/2013 II 214 I Network # 11 Company II Unit Supervisor 00000000 I HES II WALSH Initial & INITIAL T/I/0= 0/ 0/ 0 Final FINAL T/I /0= 0/ 0/ 0 Field: NATIONAL PETROLEUM RESERVE Pressures: DRIFT DN TO XXN PLUG @ 8030' RKB WITH 2.28" CENT, MEASURE 24 hr. Summary SBHP @ 8020' RKB, MIT TBG & IA TO 2000 PSI, BOTH PASSED, PULLED XXN PLUG. READY FOR CEMENT STARTTIME OPERATION PU WELL FILE & CPU, TRAVEL TO J1, CONVOY TO SPARK 1, ARRIVE & 06:00 AM INSPECT, ** FUSEABLE CAP ON SSSV UPON ARRIVAL, NSKWS ( JOHN HANSEN) ON LOC. WITH SUNDRY, SPOT UP EQUIPMENT 08:30 AM TGSM WITH LRS,FMC, RU HES CRAIN TO ASSIST FMC WITH BPV PULL BACK PRESSURE VALVE, SCAFFOLDING CREW ON LOC TO 09:30 AM ROTATE PLATFORM TO ASSESS IA VLVS TO REMOVE VR PLUGS, FMC HAVING ASSURE GRABBING A HOLD OF VR PLUG ON IA. 12:00 PM TGSM, RU HES, .125 WIRE, 1.875" TS= 5',KJ,5',OJ,LLS (OAL =24.5' RIG UP LRS, PT TO 2500 PSI, RIH W/ 2.82" CENT, 2', KEYLESS GS TO XXN 01:00 PM NIPPLE @ 8031' RKB, SD @ 8010' SLM, POOH, OOH W/ TOOLS GS IS SHEARD (CLEAN FISHING NECK) MAKE UP HALLIBURTON MEMORY GAUGES, PT W/ LRS, HAVE LRS PUT 500 PSI ON WELL HEAD TO ENERGIZE 0 -RING RIH W/ 1.91" 03:00 PM CENT,KJ,GAUGES @ 100' FPM TO 8000' SLM, BROKE 3 RIGHT ANGLE DRIVE PINS AND DRIVE ON WAY DOWN HOLE, START 15 MIN STOP @ 1650, POOH 100 FPM, 00H, GOOD DATA. 06:30 PM STAND BY FOR FMC TO PULL VR PLUGS IN IA & OA RIH W/ 2.5" GR & EQ PRONG STOP @ 7900' SLM, HAVE LRS MIT TBG TO 2000 PSI ** PASS ** RIG LRS ONTO IA AND MIT IA TO 2000 PSI * *PASS ** 08:30 PM JAR DN ON XXN PLUG @ 8031' RKB / 8010' SLM, NO PRESSURE CHANGE BLEED TBG DN TO ZERO AND START WORKING JAR LICKS UP FROM 600 # TO 1400# GET PLUG MOVING NORTH, WELL GOES ON VAC, POOH, OOH W/ PLUG 11:30 PM SECURE WELL, PJSM, NOTIFY DSO OF WELL STATUS 01:30 AM TRAVEL TO CAMP, TURN IN PAPERWORK, CPU & FILES. END TICKET Fluid Type To From Non- Note Well Well recoverable DIESEL 2 IA =1 TBG =1 http: / /akapps.conocophillips. net / alaskawelleventquery /worklog.aspx ?ID =51 EB393B5CB 8... 3/13/2013 • • Schwartz, Guy L (DOA) From: Regg, James B (DOA) ( ) Sent: Tuesday, April 02, 2013 9:47 AM To: Schwartz, Guy L (DOA) Subject: FW: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG 0092JPG, IMG_0103JPG, IMG_ 0106.JPG, IMG_0110JPG Spark 1A (PTD 2000560) P &A I guess pictures will be sent with 10 -407 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 Original Message From: NSK Fld Drlg Supv [n aii o:n1335 ?conocophil! ps.com] Sent: Monday, April 01, 2013 4:03 PM To: Grimaldi, Louis R (DOA); Herbert, Frederick 0; Brassfield, Tom J Cc: Regg, James B (DOA) Subject: RE: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG_0092.JPG, IMG_0103.1PG, IMG_0106.JPG, IMG_0110.1PG Good afternoon gentlemen, Just a quick correction on pipe size. This pipe was .84" OD with 1/2" ID and yes, 120' we tagged up hard on what appeared to be a collar. After several attempts it was apparent further penetration was unachievable. After cement was circulated to surface at 8.5 BBLS we shut cement transfer pump down at 9 BBLS away. Within one hour (after rigging SWS down) we begin adding up to 28 gal of cement to hole via 5 gal buckets to top off. This process was completed ^' 2100hrs. At 0245 hrs we were satisfied with hardened top of cement with no visual signs of sinking or sloughing. Pictures were taken for visual log accountability. Please let me know if further information is needed. Rock Bobby Morrison / Rock Rauchenstein NSK Field Drilling Supervisors 907 - 659 -7726 Pager 907 - 659 -7000, 243 n1:3_, &Jo n gn, =.iiiips._c°T Original Message From: Grimaldi, Louis R (DOA) [+mnailto:louEr maldi •alaska. ov] Sent: Monday, April 01, 2013 6:00 AM To: NSK Fld Drlg Supv; Herbert, Frederick 0 1 • • Cc: Regg, James B (DOA) Subject: [EXTERNAL]RE: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG_0092.JPG, IMG_0103.JPG, IMG_0106.JPG, IMG 0110.JPG Rock, Thank you for the report and pictures. The 1/2" pipe you ran to approx 120 could not be inserted any deeper, correct? How long did you observe cement to surface without any fall back? You stated cement did harden before welding cap, correct? Thank you, Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907 -776 -5402 (Home) 907 - 252 -3409 (Cell) Original Message From: NSK FId Drlg Supv [mailto :n1335 conocophilljps _cam] Sent: Monday, April 01, 2013 5:30 AM To: Herbert, Frederick 0 Cc: Grimaldi, Louis R (DOA) Subject: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG_0092.JPG, IMG_0103.JPG, IMG_0106.JPG, IMG_0110.1PG Importance: High Good morning gentlemen, Please note that Spark 1A has been successfully cemented to surface via 5 1/2" X 7 5/8" annuli. 9 BBLS of AS1 cement was injected through our .848" OD pipe set at ^' 120' TVD inside of 7 5/8" X 5 1/2" Annuli to perform this top job. 3 1/2" tubing void of ^ 12' was accomplished by allowing overflow from annuli into tubing. Cement hardened at surface ' 245 AM this morning. Cap has been welded with backfill to commence on approval of AOGCC satisfactory reply. Best regards, Rock Bobby Morrison / Rock Rauchenstein NSK Field Drilling Supervisors 907 - 659 -7726 Pager 907 - 659 -7000, 243 f 133 :coaccop ili ps.corn The message is ready to be sent with the following file or link attachments: IMG_0131.JPG IMG_0134.JPG 2 • • IMG_0092.JPG IMG_0103.JPG IMG_0106.JPG IMG — 0110.JPG Note: To rotect against computer viruses, e-mail programs may prevent sending or receiving certain types of file P g p P g YP g g attachments. Check your e-mail security settings to determine how attachments are handled. 3 :27 zwo90 o Regg, James B (DOA) From: NSK Fld DrIg Supv [n1335 @conocophillips.com] Sent: Monday, April 01, 2013 4:03 PM 4 tz k To: Grimaldi, Louis R (DOA); Herbert, Frederick O; Brassfield, Tom J Cc: Regg, James B(DOA) Subject: RE: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG_0092.JPG, IMG_0103.JPG, IMG_ 0106.JPG, IMG_0110.JPG Good afternoon gentlemen, Just a quick correction on pipe size. This pipe was .84" OD with 1/2" ID and yes, 120' we tagged up hard on what appeared to be a collar. After several attempts it was apparent further penetration was unachievable. After cement was circulated to surface at 8.5 BBLS we shut cement transfer pump down at 9 BBLS away. Within one hour (after rigging SWS down) we begin adding up to 28 gal of cement to hole via 5 gal buckets to top off. This process was completed — 2100hrs. At 0245 hrs we were satisfied with hardened top of cement with no visual signs of sinking or sloughing. Pictures were taken for visual log accountability. Please let me know if further information is needed. Rock Bobby Morrison / Rock Rauchenstein NSK Field Drilling Supervisors 907 - 659 -7726 SCANNED JUL ZD�3 Pager 907 - 659 -7000, 243 n1335(aconocophillips.com Original Message From: Grimaldi, Louis R (DOA) [ mailto:lou.grimaldi @alaska.gov] Sent: Monday, April 01, 2013 6:00 AM To: NSK Fld Drlg Supv; Herbert, Frederick 0 Cc: Regg, James B (DOA) Subject: [EXTERNAL]RE: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG_0092.JPG, IMG_0103.JPG, IMG_0106.JPG, IMG_0110.JPG Rock, Thank you for the report and pictures. The 1/2" pipe you ran to approx 120 could not be inserted any deeper, correct? How long did you observe cement to surface without any fall back? You stated cement did harden before welding cap, correct? Thank you, Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907 - 776 -5402 (Home) 907 - 252 -3409 (Cell) Lou. Grimaldi@Alaska.gov Original Message From: NSK Fld Drlg Supv [ mailto :n13350conocophillips.com] Sent: Monday, April 01, 2013 5:30 AM 1 • • To: Herbert, Frederick 0 Cc: Grimaldi, Louis R (DOA) Subject: Emailing: IMG_0131.JPG, IMG_0134.JPG, IMG_0092.JPG, IMG_0103.JPG, IMG_0106.JPG, IMG_0110.JPG Importance: High Good morning gentlemen, Please note that Spark 1A has been successfully cemented to surface via 5 1/2" X 7 5/8" annuli. 9 BBLS of AS1 cement was injected through our .848" OD pipe set at — 120' TVD inside of 7 5/8" X 5 1/2" Annuli to perform this top job. 3 1/2" tubing void of — 12' was accomplished by allowing overflow from annuli into tubing. Cement hardened at surface — 245 AM this morning. Cap has been welded with backfill to commence on approval of AOGCC satisfactory reply. Best regards, Rock Bobby Morrison / Rock Rauchenstein NSK Field Drilling Supervisors 907 - 659 -7726 Pager 907 - 659 -7000, 243 n1335@conocophillips.com The message is ready to be sent with the following file or link attachments: IMG_0131.JPG IMG_0134.JPG IMG_0092.JPG IMG_0103.JPG IMG_0106.JPG IMG_0110.JPG Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 2 Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, January 10, 2013 4:33 PM To: 'Brassfield, Tom J' Cc: Alvord, Chip Subject: RE: Carbon #1 & Spark #1A P&A Procedures (PTD 203 -218 and 'TD 200 -056 Tom, Your changes to the two P & A procedures for Carbon #1 (PTD 203 -218) and Spark 1A (PTD 200 -056) are approved as written below. Pressure tests for the bottom plug should be 30 min and charted. They should pass the same criteria that is used for injection well MIT -IA's. I will file this email in the well folder to document the changes and forward to the inspectors so they have a record of the changes. Regards, Guy Schwartz Senior Petroleum Engineer SCANNED APR 1 1 2013 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Brassfield, Tom 3 [mailto:TOM.J .Brassfield @conocophillips.com] Sent: Thursday, January 10, 2013 4:10 PM To: Schwartz, Guy L (DOA) Cc: Alvord, Chip Subject: Carbon #1 & Spark #1A P&A Procedures Guy, as discussed this date will make the following modifications to the approved P&A procedures: • Carbon #1 • Add PT to IA & tbg to 2000 psi in step #2 • In step #6 lower PT from 2500 to 2000 psi and chart for 30 minutes • Delete step #11 because we will tag TOC in step #6 • Spark #1A • Delete step #11 because we will tag TOC in step #6 Thanks, Tom Tom Brassfield Staff Drilling Engineer 907/265 -6377 (w) 907/244 -5684 (c) 1/10/2013 6,0" \\ O THE STATE Alaska Oil and Gas 'ALASKA Conservation Commission GOVERNOR SEAN PARNELL �. 333 West Seventh Avenue * '�`` Anchora Alaska 99501-3572 0� Anchorage, ALAS* 9 Main: 907.279.1433 Fax: 907.276.7542 Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 a, Anchorage, AK 99510 Re: Exploration Field, Exploration Pool, Spark # 1A Sundry Number: 312 -468 JAN 2 31 ��� 'VNEU Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 13 y da of December, 2012. Encl. il • • i. 9544, IV E D 1 • STATE OF ALASKA v'`� DEC 10 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon 0 • Plug for Redrill ❑ Pe fora 11] New Pool ❑ Repair Well ❑ Change Approved Program Suspend ill 1 Plug Perforations , Perforate ❑ Pull Tubing 111 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well [V( ( Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 . Development ❑ 200 -056 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 100360, Anchorage, AK 99510 50- 103 - 20313 -01 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 Spark #1A • 9. Property Designation (Lease Number): 10. Field /Pool(s): AKAA81802 • NPR Exploration . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8522' • 8445' • 8335' • 8259' Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 16" 115' 115' Surface 2522' 7.625" 2610' 2610' Production 5013' 5.5" 5046' 4978' Production 3466' 5.5" 8512' 8435' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8135' -8150' • 8058' -8074' 3.512.875" L -80 8082' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): FB -1 packer FB -1 © 7944'. 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 « Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for • 2/1/2013 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned B - Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Engel @ 263 -4063 Email iosepheaconocophillips.com Printed Name Chip Alvord Title Drilling Manager 2..6 5 (10 k - 7 i (2 Signature Phone Date A-L,k_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 z--(4(i y Plug Integrity V BOP Test ❑ Mechanical Integrity Test El r Location Clearance Yr 'Sc + •-- Z,r> /3 Other: 1 pit oh) 4 J - a CS i n ( c f4 g Wes(.de.c s ,/a A- No "« c 1 k, 5D � aar 4. s 1 et-41 c.- 1 . !! RE3E-MS DEC 14 201i Spacing Exception Required? Yes ❑ No IA Subsequent Form Required: / 0 L •-� t 0 T APPROVED BY I � l / � I , /Z . Approved by: ,I / COMMISSIONER THE COMMISSION Date: l c R1c03 Submit Form and N d 2 i 2) Approved application is valid for 12 months from the date oft pproval. Attachments in Duplicate \ � �\ A /Z. /2../ D • • Conoco Phillips Alaska, I . RECEIVIE DEC 10 2012 Nov AOGGC ConocoPhillips Box 100360 Alaska 99510 -0360 December 7, 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry approval to P &A: Spark #1A (Exploratory Test) Surface Location: 1608' FNL, 2497' FWL, Sec 8, T1ON, R2E, UM X= 291,158 & Y= 5,939,589 ASP4 NAD27 Target Location: 2306' FNL, 2502' FWL, Sec 8, T1ON -R2E, UM Bottom Hole Location: 2306' FNL, 2502' FWL, Sec 8, T1ON -R2E, UM Dear Commissioners: ConocoPhillips Alaska, Inc. would like to permanently plug and abandon the Spark #1A wellbore, located in the National Petroleum Reserve- Alaska. Nabors 19E spud this well on 3/24/00 and completed the well on 4/29/00. The attached Sundry form 10 -430 and back -up information describes the P &A procedure for the existing wellbore and has been forwarded to BLM personnel for review. If you have any questions or require any further information, please contact me at 263 -4063 or Tom Brassfield at 265 -6377 or Chip Alvord at 265 -6120. Sincerely, SI Drilling Engineer cc: CONFIDENTIAL — Spark #1A Well File Chip Alvord ATO -1570 • • Spark #1A P &A Procedures CONFIDENTIAL TJB 10/31/2012 Well Status: Spark #1A was drilled /completed on 4/29/2000. The well was tested and suspended in 2001. The well was reentered in March of 2002 to pull the Panex gauges hung -off in the XN nipple at 8031' MD and resecured. The 3 -1/2" tubing is loaded with 10.2 ppg kill weight brine with a 2000' diesel cap for freeze protection. A "XXN" tubing plug is set in the "XN" nipple at 8031' MD. The 3 -1/2" by 5 -1/2" annulus is loaded with kill weight fluid from 7852' MD to 1400' MD with a diesel cap on top. The 7 -5/8" x 5 -1/2" annulus is freeze protected to 2000' +/- MD. Bottom hole pressure in the Jurassic is estimated to be a 9.4# Equivalent Mud Weight. A 10.0 ppg kill weight brine should give us 200 psi+ overbalance. The Jurassic interval has been flow tested. The well will be plugged and abandoned as outlined below. Outline: 1. Pull the XXN plug at 8031' MD and fluid pack well with 10.0 ppg KWF. 2. Pump cement from the surface to the pert zone @ 8135'- 8150' MD. Circulate approx 700' of cement above the GLM (tbg & annulus) at 7852' MD. 3. Tag TOC & PT cement plug. 4. Bullhead 2000' of AS1 cement into the 7 -5/8" x 5 -1/2" annulus 4. Set tubing plug at 500' +/- in tubing. Punch holes and cement tubing and IA to surface. 5. Excavate wellhead. Cut off 4' below GL and weld on cover plate. Backfill. Procedure: 1. Notify BLM /AOGCC 48 hours in advance of all pressure testing and well suspension operations. Hold pre job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Wrap the wellhead and set -up heater. Pull the VR plugs from the IA & OA casing heads. Check pressures on the wellhead /valves and advise Anchorage staff of any anomalies. P T IA 'F. T P""l X g P - C 6E- 3. RU slickline and pull "XXN" plug from the "XN" nipple at 8031' MD. 4. Have Hot Oil truck RU and ready to load the wellbore with 10.0 ppg NaCI /NaBr kill weight fluid. 5. Load tubing by Bullheading 10.0 ppg NaCI /NaBr kill weight Brine down the 3 %2" tubing with a minimum of 10 bbls- note injection rate and start/end pressures, confirm that the well is static. 6. RU cementing crew. Mix approx. 15 bbls (1724' of 3 -1/2" tubing volume) usable cement (Class G with additives as per below specs. Pump down tubing to perfs. Hesitate squeeze additional cement (approx 11.5 bbls planned) into Jurassic perfs as required. Leave TOC at approx. 7900' MD or 69 bbls of displacement. 1r�� al N o k v C' ® r 7. SI tubing. RU slicklinepnd pull dummy from GLV © 7852' MD. RD slickline. Line up -roc. pumps to tubing. -roc. P 2.600 psi 8. Open the 3 -1/2" x 5 -1/2" annulus and circulate 17 + bbls of 10.0 ppg NaCI /NaBr kill weight brine down the tubing taking returns thru the IA to tanks displacing the freeze protect diesel and confirming circulation. Close the 3- 1/2 "x5 -1/2" annulus valve. TJB 10/31/2012 • • Place the tubing and annulus into communication to allow equalization. Check surface pressures. Maintain a pressure log i.e. every 5 or 10 bbls while pumping. Confirm that the well is static. 9. RU cement crew. Mix approx. 15 bbLs (1724' of tubing volume) usable cement (Class G with additives as per below specs. Open 3- 1/2 "x5 -1/2" annulus valve and displace TOC to approx. 7152' MD with approx. 62 bbls of KWF through open GLM at 7852' 8$ . MD. This will place approx. 700_ ±.of cement in the IA and tubing above the GLM @ 7852' MD. , ' 008 7 + • 10. SI IA valve. - 7C6 0 c - mk - 1,4 0 t S3 2 -7/8" tbg volume= 0.00579 bpf • °2 ° be/ , 3 -1/2" tbg volume = 0.0087 bpf 3 -1/2" x 5 -1/2" annulus volume = 0.0119 bpf 3' /Z "Tbg plus tbg X 5 -1/2 "annulus volume = 0.0206 bpf 7 -5/8" 29.7 ppf x 5-1/2" annulus volume = 0.0165 bpf 5 -1/2" 15.5 ppf csg = 0.0238 bpf Class G + 0.2% BWOC D046 + 1.0 % BWOC D202 + 0.8% BWOC D400 + 8.0% BWOC D154 + 1.5 % BWOC D174 + 0.4% BWOC D198 Wt: 15.8 ppg Yield: 1.16 cuft/sk Working Time: Estimated @ 5 hrs +/- (inclusive of 1 hour surface time) 11. Rig up slickline unit and RIH to tag top of cement plug inside tubing @ 7152' MD ik 7 approx. to verify placement. Record and report results. Pressure test tubing and IA to - - -ft,6 . 1500 psi. AOGCC /BLM may want to witness tag of cement and pressure to t. i L--7 30 J....:... 12. RU cementing crew to pump down the 7 -5/8" x 5 -1/2" annulus. Pump 50 bbls of water to flush annulus and verify injectivity- note rate and pressures. (Annulus freeze ° ,cs 8�� 0, protected to approx. 2000' MD with 40 bbls diesel © 1.5 bpm with 750 to 1100 psi surface pressures.) Downsqueeze 33 bbls of AS1 cement into the annulus. Annular volume @ 2000' x 0.0165 bpf = 33 bbls ✓ °•• 13. RIH with slickline and open the CMU. SS at 2725' +/- MD. POOH. Open 3- 1/2 "x5 -1/2" annulus to establish circulation down the tubing up the annulus. SI. RD slickline. 14. RU cementing crew. Open 3- 1/2 "x5 -1/2" annulus. Circulate AS1 cement (approx. 56 bbls) down the tubing up the casing /tubing annulus to surface. SI and wait 30 • minutes. Confirm the 3- 1/2 "x5 -1/2" annulus stays full- SI. S` • , o2 ° 2 g° /` NOTE: Notify AOGCC /BLM Inspectors before setting surface plug(s). 15. Clear lines and shut down pumps. Rig down cementing unit and clean up. 16. Cut off wellhead and all casing strings at 4 feet below original ground level. Verify that cement is back to surface in all strings. Add cement as required. Send casing head with stub to Materials for repair / re- dressing. TJB 10/31/2012 • • 17. Weld Y4 thick cover plate (16" in diameter) over all casing strings with the following information bead welded into the top (Drill 1/8" weep hole in cover plate). Conoco Phillips P kz' Spark #1A PTD # 200 -056 API # 50- 103 - 20313 -01 18. Remove cellar. Back fill cellar with gravel /fill as needed. Back fill remaining hole to ground level with gravel /fill. Clear and scrape the ice pad location as needed and demob all materials and equipment. Close out with the appropriate agencies. TJB 10/31/2012 • • • • Spark #1A FINAL Schematic - P By TJB 10/24/2012 16" Conductor 3 -' /z" FMC Tubing Hanger wuth BPV installed (a115'RKBtoGL4 Base Permafrost - 600' MD 7 -5/8" x 5.5" annulus freeze protected to 2000' with Diesel ti 5 7 - 5/8" casing cemented to surface 9 - 7/8" Hole with good returns - a Zap ht p 7 -5/8 ",29.7 #, L -80, • BTC Mod, R3 A SS @ 2725' MD Surface Casing & al& -� @2610' MD -RKB 10.2 ppg kill weight brine inside tbg from perfs to 2000' MD with diesel cap to surface /10 9.9 ppg KW brine in the IA from 7852' MD to 1400' MD with diesel cap to surface TOC 12 ppg - 6050' MD 3 - /12" 9.3 ppf L - 80 tbg to 7944' MD TOC 15.8 ppg - :� - f GLM with dummy @ 7852' MD 7200' MD "X" nipple w/ 2.813" ID @ 7904' MD Baker FB -1 Packer © 7944' MD 2 -7/8" 6.4 ppf L -80 tbg below packer 6 -3/4" Hole .14-GLMs @ 8009'& 7980' MD - XN with XXN plug @ 8031' MD Tubing tail @ 8082' MD 57 / 5 -1 /2 ", 15.5 #, L -80, BTC Mod, R3 Perforations from 8135' to 8150' MD @ 6spf Production Casing ' _ 8512' MD -RKB A 77' of TCP Guns from PBTD of 8335' MD TD @ 8522' MD/ 8445' TVD • • Spark #1A FINAL Schematic w By TJB 10/24/2012 16" Conductor • 3 - %" FMC Tubing Hanger wuth BPV installed ©115' RKB to GL, Base Permafrost – 600' MD 7 -5/8" x 5.5" annulus freeze protected to 2000' with Diesel 7 -5/8" casing cemented to surface 9 - 7/8" Hole with good returns — 7 -5/8 ",29.7 #, L -80, BTC Mod, R3 a SS @ 2725' MD Surface Casing 1 • (c�2610' MD -RKB 10.2 ppg kill weight brine inside tbg from perfs to 2000' MD with diesel cap to surface 9.9 ppg KW brine in the IA from 7852' MD to 1400' MD with diesel cap to surface TOC 12 ppg --.- 6050' MD 3 - /12" 9.3 ppf L - 80 tbg to 7944' MD TOC 15.8 ppg �-► � - - GLM with dummy @ 7852' MD 7200' MD ke - "X" nipple w/ 2.813" ID @ 7904' MD Baker FB -1 Packer @ 7944' MD . ` 2 -7/8" 6.4 ppf L -80 tbg below packer 6 -3/4" Hole j -.4–GLMs @ 8009'& 7980' MD 1 i -4 – XN with XXN plug @ 8031' MD 3 � PIP Tubing tail @ 8082' MD 5 15.5 #, L - 80, BTC Mod, R3 Perforations from 8135' to 8150' MD @ 6spf Production Casing @ 8512' MD-RKB i ] 77' of TCP Guns from PBTD of 8335' MD TD @ 8522' MD/ 8445' TVD ~ u ~4 '~~ ~~~ t F~ ~ ;. .> ' " ~p~F, ; ~ a~~ ~~4~~ ~~f~ ~~p~, ~ 4 ~ ~' , ~ K ~ ~ ~ ~ ~, ~ ~ ~ ~ ~ ~ ~' ~ ~ ~ ~ ~ ~~ ~, ~' ~ ~ ~ -~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~ ~ ~ ~ _~ . ~. ~ °x ~~ ~ ~~ ~~~ ~~~ ~ ~ ~~~ ~. ~~, ~~e ~ ~~ ~ ~ ~_ ~ ~ .~s.A-.5~~ ~IL ~~ ~S ~~ 333 W. 7th AVENUE, SUITE 100 COI~TSERVATIOl~ CO1~II~IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ,~ FAX (907) 276-7542 Mr. Chip Alvord - Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 , , ti. , . .;.: . _ ~ ~i"w. ~ ~~ Re: Exploration, SparklA ~~~ '~ Sundry Number: 309-329 - Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this lEtter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair sfi DATED this 2- ~day of September, 2009 Encl. • ~ • s ~onocoP'h~llips Box100360 Alaska 99510-0360 September 15, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 -~ J ~ ~ ao ~ o ~ Re: Renewal of suspension status 10-403 Sundry Spark #1A (Exploratory Test) Surface Location: 1608' FNL, 2497' FWL, Sec 8, T10N-R2E, UM X=291,158 & Y=5,939,589 ASP4 NAD27 Target Location: 2306' FNL, 2502' FVVL, Sec 8, T10N-R2E, UM Bottom Hole Location: 2306' FNL, 2502' FWL, Sec 8, T10N-R2E, UM Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a request for renewal of suspension status • for the Spark #1A wellbore per 20 AAC 25.110. The well was visually inspected on 8/19/09 and the results submitted with a 10-404 sundry. Attached is a wellbore schematic noting the condition of the wellbore. Please note the following: • The wellbore has been perforated • A tubing plug is set in the "XN" nipple at 8031' MD • Kill weight fluid in the tubing to 2000' with a diesel cap and kill weight fluid in the IA from 7852' MD to 1400' MD with a diesel cap. Tubing & IA pressure tested. • VR plugs installed in the annulus valves • Freeze protect diesel in the 7-5/8" x 5-1/2" annulus to 2000' +/- MD • Cement to surface on the 7-5/8" casing • BPV installed in the tubing hanger CPAI requests renewal of the suspension because the well is awaiting the expansion . of key infrastructure west of Alpine into the National Petroleum Wildlife Refuge (NPRA). Spark #1A has future utility as a service well within the GMTU for gas . resource exploitation. Si cer ~ r~ Tom Brassfield Senior Drilling ngineer • cc: CONFIDENTIAL - Spark #1A Well File Chip Alvord ATO-1570 Leslie Senden ATO-1390 • , , > • • `: , i: ; ~.'> _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ~ Perforate ^ Waiver ~ Other ~ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ~ Time Extension ~ e~Rension of Change approved program ~ Pull Tubing ~ Perforate New Pool ^ suspension Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, If1C. Development ~ Exploratory ^~ • 200-056 - 3. Address: Stratigraphic ~ Service ~ 6. API Numbef: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20313-01 • 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Spacing Exception Requires? YeS NO ^d Spark 1A ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL AA081802 . RKg gg~ Exploration . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8522' . 8445' • 8335' 8259' Casing Length Size MD ND Burst Collapse CONDUCTOR 82~ 16" 115' 115' SURFACE 2522' 7.625" 2610' 2610' PRODUCTION 5013' 5.5" 5046' 4978~ PRODUCTION 3466' 5.5" 8512' 8435' Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing 5ize: Tubing Grade: Tubing MD (ft): 8135'-8150' 8058'-8074' 3.5"/2.$75" L-80 8082' Packers and SSSV Type: Packers and SSSV MD (ft) Baker FB-1 packer ~ 7g44' no SSSV 13. Attachments: Description Summary of Proposal Q 14. Weil Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory Q. Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operati~ Sepkember 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ~ GINJ ~ WINJ ^ WDSPL ~ Commission Representative: suspended ^~ ' 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield ~ 265-6377 Printed Nam Chl Alvord Title: Driliing Manager ~ Signatu ~ ~ y ~ Phone 265-6120 Date C` ~~~' Commission Use Only Sundry Number: Conditions of approval: Noti Commission so that a representative may witness - ~ Plug Integrity ~ BOP Test ~ Mechanicai Integrity Test ~ Location Clearance ^ other. ~nf.avc~..\ Cf~ SvS Q l\Sr ~'~, G C'p ~S ~,~~\` S G Q~`1CJ~.\ lS Q`Z~ ~~ ~~3 ~-`~ ~ ee ee Subsequent Form Required: h,p~~, G.~ ~~~5 ~~ ~~- ,r~ ~ Ps~ ~ ~ j ~ `~~~ (~~j ~ ~ ~ ~ ? .- ° ~ ~ E:f° ~Ull~ APPROVED BY ~/~/~ Approved by: OMMISSIONE THE COMMISSION Date: ~ . .,.... ... T..~.......,.... ...,.~.,..., - - - - _ . . _ . . _ ~~ •~t~, ~ 1,~G • 09 ,~~1"~.~"~~~ ~ ~ r ~ z~~'j • • ARCO Spark #1A FINAL Schematic By TJB 9/14/09 1~a.115' RKB to GL ~ -~ 9-7/8" Hole 6-3/4" Hole 3-'/z° FMC Tubing Hanger wuth BPV installed Base Permafrost ~ 600' MD 7-5/8" x 5.5" annulus freeze protected to 2000' with Diesel 7-5/8" casing cemented to surface with good returns ~SS @ 2725' MD 10.2 ppg kill weight brine inside tbg from perfs to 2000' MD with diesel cap to surface 9.9 ppg KW brine in the IA from 7852' MD to 1400' MD with diesel cap to surface 3-/12" 9.3 ppf L-80 tbg to 7944' MD f GLM with dummy @ 7852' MD Baker FB-1 Packer @ 7944' MD 2-7/8" 6.4 ppf L-80 tbg below packer f GLMs @ 8009'& 7980' MD ~- XN with XXN plug @ 8031' MD Tubing tail @ 8082' MD Perforations from 8135' to 8150' MD @ 6spf • 77' of TCP Guns from PBTD of 8335' MD 16" Conductor ~ 7-5/8".29.7#. L-80. BTC Mod. R3 Surface Casina c~i2610' MD-RKB TOC 12 ~pp ~ ~ 6050' MD TOC 15.8 ppg ~ 7200' MD 5-1 /2". 15.5#. L-80. BTC Mod. R3 Production Casina , ~ 8512' MD-RKB TD @ 8522' MD/ 8445' TVD • PHILLIPS Alaska, Inc. • KUPARUK RIVER UNIT WELL SERVICE REPORT K1(SPARK-1 A W4-6)) WELL JOB SCOPE JOB NUMBER SPARK-1A DRILLING SUPPORT-CAPITAL 0314021710.13 DATE DAILY WORK UNIT NUMBER 03/20/02 DISPLACE TBG W/ KILL WEIGHT FLUID & SET PLUG 3904 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 NO YES HES-WILBURN CHANEY FIE~D AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE AX2163 FDUNDV4RA $17,019.80 $42,735.80 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 1700 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY DISPLACED TBG W/ KILL WEIGHT FLUID ( 55 BBLS OF 10.2# BRINE & 17.5 BBLS OF DIESEL FOR A CAP DOWN TO 2000'). SET 2.313" XXN PLUG (38-1/2") IN XN NIPPLE @ 8031' RKB. PRESSURE TESTED PLUG TO 3000 PSI AND HELD FOR 30 MINUTES. DE-PRESSURED TBG TO 0 PSI. INSURED IA WAS DE-PRESSURED TO 0 PSI. READY FOR BPV & VR PLUGS.[PT Tbg-Csg] TIME LOG ENTRY 07:00 ROAD S/LINE UNT FROM ALPINE TO SPARK-1A 08:30 ROAD LRS HOT OILTRUCK FROM KUPARUK TO SPARK -1A 09:00 S/LINE ARRIVED ON LOCATION AND BEGIN RU 09:30 APC BRINE TRUCK ON LOCATION. 11:30 LRS HOT OIL UNIT ON LOCATION AND BEGIN RU. 12:20 PUMP 20 BBLS OF DIESEL 2 BPM. FOR A SWEEP. 12:30 PUMP 55 BBLS OF 10.2# BRINE 2 BPM. 12:50 PUMP 17.5 BBLS OF DIESEL (FREEZE PROTEC~ @ 2 BPM. SHUT DOWN PUMP AND WELL IS DEAD 0 PSI ON TBG. 13:00 RIH W/ 2.313" XXN PLUG W/ 18" DEBRIS & STANDARD EQUALIZING HOLES (TOTAL LENGTH 38-1/2") TO 8014' WLM 8031' RKB & SET PLUG IN XN NIPPLE. POOH 13:45 ON SURFACE RUNNING TOOL INDICATES GOOD SET. 13:50 PRESSURE TEST TBG TO 3000 PSI AND HELD . IA REMAINED AT 0 PSI DURING TBG 14:30 DE-PRESSURED TBG TO 0 PSI. NOTE THAT THERE IS FLUID TO SURFACE ON BOTH THE TBG & IA. NOTE THAT IA WAS PRESSURE TESTED ON WSR DATED 03/15l02 15:00 RDMO LRS HOT OIL TRUCK. 15:30 RDMO S/LINE UNIT 16:30 WELL SECURED AND ALL PERSONNEL LEAVE LOCATION. FLUID SUMMARY 37.5 BBLS DIESEL (TBG) 55 BBLS DIESEL BG SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,440.00 $4,440.00 FMC $0.00 $1,200.00 HALLIBURTON $3,720.00 $12,240.00 LITTLE RED $2,450.00 $8,820.00 MI FLUIDS $2,960.00 $2,960.00 PHILLIPS $5,450.00 $13,076.00 TOTAL FIELD ESTIMATE $17,020.00 $42,736.00 ~ ~~ ~ PHILLIPS Alaska, Inc. • KUPARUK RIVER UNIT WELL SERVICE REPORT K1(SPARK-1 A(W4-6)) WELL JOB SCOPE JOB NUMBER SPARK-1A DRILLING SUPPORT-CAPITAL 0314021710.13 DATE DAILY WORK UNIT NUMBER 03/21/02 INSTALL BPV & VR PLUGS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 YES YES CHANEY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE AX2163 FDUNDV4RA $5,940.00 $48,675.80 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY INSTALLED FMC BPV & VR PLUGS IN WELLHEAD. ALL VALVES CLOSED AND HANDLES REMOVED. RE-HUNG WELL ID SIGN ON THE WELLHEAD. TIME LOG ENTRY 12:00 MIRU APC BOOM TRUCK. 13:00 FMC ARRIVED ON LOCATION. 14:00 INSTALL FMC BPV IN HANGER 14:30 INSTALLED VR PLUGS IN ANNULI 15:00 CLOSED ALL VALVES AND REMOVED VALVE HANDLES. NOTE: THAT THE VALVE HANDLES WILL BE STORED AT THE KUPARUK DRILLING TOOL HOUSE. 15:30 WELL SECURED LEAVE LOCATION. 15:30 RE-HUNG WELL ID SIGN 16:00 CALL FOR SCAFFOLD REMOVAL AND MOBILE EQUIPMENT TO BE HAULED OFF. NOTIFIED RICK OVERSTREET OF WELL & LOCATION STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,550.00 $6,990.00 FMC $1,400.00 $2,600.00 HALLIBURTON $0.00 $12,240.00 LITTLE RED $0.00 $8,820.00 MI FLUIDS $0.00 $2,960.00 PHILLIPS $1,990.00 $15,066.00 TOTAL FIELD ESTIMATE $5,940.00 $48,676.00 ~ ~ Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Sunday, September 20, 2009 1:47 PM To: Ramirez, Darlene V (DOA) Subject: Re: 309-329 Approve Sent from my iPhone On Sep 18, 2009, at 10:29 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirez~a alaska.gov > wrote: > «S45C-209091808590.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091808590.pdf > > > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain rypes of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091808590.pdf> t~v~.; tsoctyrage • , - 1.:~J . - ~~~_~C ~~.~~€i._S~~~e;~~~c~ ~~e~~~ • ~~GC~ `~ s~spF~~~~ ra~c i ul ~ ~ c7~~ "'~~ b `` I y- a0o ~ (a) If allowed under 20 AAC 25, I_0_5, an operator may apply to the commission under this section to approve the suspension of a well or to renew the approval of the suspension of a well. The operator must state the reasons the well should be suspended, and not completed or ~bandoned, and must demonstrate to the commission's satisfaction that ~" ~ V~ ~1`~ (1) the well ~ (A) is mechanically sound; ~:~ ~ - _. ,. °~~;~~ ,~. ~.., ~ a _ /~ (B) will not allow the migration of fluids; „/' (C) will not damage freshwater or producing or potentially producing formations; /(D) will not impair the recovery of oil or gas; ~(E) is secure, safe, and not a threat to public health; and (F) is in compliance with all provisions of AS_31,05, this chapter, and any order, stipulation, or permit issued by the commission; (2) the well /~ (A) has future utility as an exploratory, development, or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. S~1A~:.4~ ~ ~ I~5 -o S (b) An Application for Sundry Approvals (Form 10-403) must be approved by the commission before operations to suspend a well commence, except that oral approval may be requested under 20 AAC 2_5.5_07~b~ . In addition to meeting the requirements of (a) of this section, the application must include the following: (1) wellbore diagrams illustrating the current and proposed mechanical configurations of the well; (2) information on abnormally geo-pressured or depleted strata; (3) a description of the proposed work plan, including how the integrity of existing and proposed plugs will be demonstrated. (c) Unless the commission otherwise requires or approves a variance under 20 AAC 25_,_l 12(i) , any well suspended under this section must be plugged in accordance with 20 AAC 25.112, except that the requirements of 20 AAC 25,1__12~d~ do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and La+.... //"..'.." 1..,`:,. ..4..~.. .,1. ,,../1+...,;~./~ 1;...~..~r~v.. ..n.+7,•«~-~44r~•~~~aninv ~onin ntn4v o~r »o/rrri_hin/f uni i~nn4 DOC BodyPage ~ • rage ~ ot ~~ (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface. (d) The operator of a suspended well shall maintain the integrity and safety of the well and surrounding location and clear the location in accordance with 20 AAC 25.170~a} (2) or (b) or with 20 AAC 25_.172 ~c) (2) or (d), as applicable. ~' I~S -O~ (e) For a well suspended before January 1, 2009, the o erator shall ins ect the well site before Septem er , 2010. For a well initially suspended on or after January 1, 2009, the operator shall inspect the well site within 12 months after the date of suspension. For a well suspended under this section, subsequent inspections shall be conducted within 24 months before September 30 of every calendar year ending in 0 or 5, except that a suspended well is not required to undergo a subsequent inspection under this subsection if the initial inspection under this subsection occurred within the prior 24-month period. For all inspections under this section, the operator shall provide the commission notice at least 10 days before the inspection and the opportunity for commission inspectors to accompany the operator on the inspection tour. If convenient for the commission, shorter notice periods may be accepted. ( fl Within 30 days after any well-site inspection required under this section, including (e), (h), and (i) of this section, the operator shall file a Report of Sundry Well Operations (Form 10-404). The report must include `~ ( ~S -O ~ ~/ (1) a description of the condition of the wellhead and surface location, including any discoloration, fluid or sheen visible on the ground or in any nearby water; f(2) a plat showing the location of the suspended well and any wells within a one-quarter-mile radius of the wellbore; (3) well pressure readings, if practicable; ~oQcresSv~ ~~<`~S ~v-`~-~'`~ f(4) photographs clearly showing the condition of the wellhead and surrounding location; and (5) an update of all information and documentation required in (b) of this section. (g) A suspension or renewal of a suspension approved on or after January 1, 2009 is valid for 10 years from the date of approval. (h) Renewal of an existing suspension may be requested by the submission of an Application for Sundry Approvals (Form 10-403) meeting all requirements of (b) of this section. A renewal is not effective until approved by the commission. If a complete renewal application is submitted at least 60 days before the expiration of an existing suspension, the existing suspension will continue until the commission acts on the application. Within 24 months before the submission of a request for suspension renewal, a well-site inspection must be completed. (i) For wells suspended before January 1, 2009, an A~~ation for Sundry Approvals (Form 10-403) section must ~(1) no later than December 31, 2010 for all wells suspended before January 1, 2006; and ~---- (2) no later than December 31, 2015 for all wells sus~ended on or after January 1, 2006. ,,. ,. ,. , , .. „ , ~ ._._ -~---~__: L._ir oi~i i~nnn DOC BodyPage rage ~ oi ~~ • • (j} The operator shall immediately notify the commission and propose appropriate action if the operator learns that there is a reasonable risk that a suspended well is (1) mechanically unsound; (2) allowing the migration of fluids; (3) causing damage to freshwater or producing or potentially producing formations; (4) impairing the recovery of oil or gas; (5) a threat to public health or not secure or safe; or (6) not in compliance with all provisions of AS_ 31,05, this chapter, and any order, stipulation, or permit issued by the commission. (k) within five working days after notifying the commission under (j) of this section, the operator shall file a report and all relevant information and documentation regarding the well, including all information and documentation that may be required by the commission. (~ If the operator learns that any information required under this section is no longer complete or accurate, the operator shall, within 30 days, notify the commission in writing, provide updated information, and propose appropriate action. (m) At any time, the commission may request that an operator provide, within 10 days after the date of request, any information concerning whether suspension remains appropriate for a well. If the operator does not comply with the information request or if the commission determines that information is insufficient to support allowing the well to remain suspended, the commission may take action u.nder 20 AAC 25.540, including (1) revoking the well's suspended status, effective as of the date determined by the commission, and (2) prescribing actions the operator must take, which may include plugging and abandonment of the well; if action is ordered, including plugging and abandonment under this chapter, a separate notice and hearing is not required notwithstanding any other provision of this chapter, including 20 AAC 25.1 Q5. (n) Upon written request of the operator, the commission may modify a deadline in this section upon a showing of good cause. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am 11/19/2008, Register 188 Authority: AS 31.05.030 A~ 31.05.040 AS 31.05.095 ~;fl ~,~ ~5.~~~. ~~e~~~_ic~~i~ ~ec~~~re~se_n~s „ , • , . , ,, - ~r-~'-------- ----^---,_,_~._.~~._...__, ~,.~... ,.~,..,. ,.~...,.i,.,.; ~,;,,i~ oi~i i~nno ra~e 1 Ul G ~ ~ Maunder, Thomas E (DOA} From: Brassfieid, Tom J [TOM.J.Brassfieid@conocophillips.com] Sent: Wednesday, September 16, 2009 7:21 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip Subject: RE: Suspended Well Extensions for CPAI Attachments: 4Spark 1A.jpg 7~~m, v~re've att~mpted to ~ddress tfiese issu~s in the ~'~03140~a's su~mit#ed on tfi~e six P~P€~A ~~lis inspected tt~+is year i,e.: ~~'V's instailed VR piugs instalied on the annulus vafves Tubing t~ii plugs isoi~ting th~ intervals of interest F~ressure ~'e5ts ~~+9i ~~;~ic~ht ~iuids in the tubing ~ iA's Freeze proYection aY s~arfi~ce ~stirna4Ed cement t~ps Good cemen~ retums on the surface casing jobs ~~€~i has been very pra a,ctive far fhe lasf three ~;~~~rs in p~rforming visu~l insp~cti~ns on o~ar remate 1oc~tions. !Ne hav~ seen no indicatior~ of any "safety" issues associ~ted witt~ the six ~,~ells submit#ed. It is not very pract+cal to pull the VR plugs to check ~nnulus pressures- see attached Spark 1A phato as an example. Re~ards, l~om From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, September 15, 2009 2:56 PM To: Alvord, Chip; Brassfield, Tom J; Kanady, Randall B Cc: Aubert, Winton G(DOA); Regg, James B(DOA); Colombie, Jody J(DOA); Schwartz, Guy L(DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE; Suspended Well Extensions for CPAI Ghip, Tam and Randy Sorry you all got missed on the original send. Please share with others in the CPAI organization as needed. Tom P~aunder, P~ AOGCC From: Schwar~, Guy L (DOA) Sen#: Tuesday, September 15, 2009 2:33 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Aubert, Winton G(DOA); Maunder, Thomas E(DOA); Regg, James B(DOA); Colombie, Jody J(DOA) Subject: Suspended Well Extensions for CPAI 9/16/2009 r~t.~'GGUlG i • MJ/Perry, in regards to "remote pad" suspended weU extensions; two issues came up ira ~ur engineering -evi~wr of tfie recent weBls submitted (Scout 1and Puviaq 1) and would like addressed in future 403 Sundry applications and the 404 report documentation. 1) At least one annulus pressure shouid be taken to verify that the w+efl st+ii has integrity. This may mean bringing a calibrated gauge to the remote site and installing it 4emporariiy to get pressures. Commonly, a9! gauges are taken off and flanges buli-piugged for safety arad environmentai reasons. The reguiations currently say to "get pressures if prar,tical " and that is rather open ended. 2) Remote vdell-sites need to have a written plan for future utility to quatify for an extension of the suspended status. 20 AAC 25.9 9 D(a) (2) s#ates three possibilities for qualifying for the extension. V1/ritten detail for one of #hese qualifications should be included in the anafication far sundrv. (Scout 1 clearly has a future utilify as it witl be flow tesfed For the suspended w+eJls vn "Active pads" the report should b~ very similar. As above, getting annulus pressures if at all prac#ical is a necessity. A formal written plan for future utility is no# as critical as it meets one of the listed criteria by default. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 9/16/2009 Remote Explaration Site Inspec~s-CPAI • Maunder, Thomas E (DOA) From: Brassfield, Tom J [TOM.J.Brassfield@conocophillips.com] Sent: Wednesday, August 26, 2009 12:20 PM To: Regg, James B (DOA) Cc: Kanady, Randall B; Alvord, Chip; Maunder, Thomas E(DOA) Subject: RE: Remote Exploration Site Inspections-CPAI Page 1 of 3 Jim, typically we do not leave pressure gauges on the wells (see statement below usually included in our well plans) as a mitigation measure. NO, we did not install gauges and check pressures during these visits. 1. Set BPV in tree. Close all valves and remove handles. Install flanges with ~/z" plugs screwed into the flanges on all outer valves and a bull plug with ~/2" plug in the valve on the wellhead (annulus valve). Thanks, Tom From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 26, 2009 11:13 AM To: Brassfield, Tom J Cc: Kanady, Randall B; Alvord, Chip; Maunder, Thomas E(DOA) Subject: RE: Remote Exploration Site Inspections-CPAI Do you maintain pressure gauges on the wells, or were gauges installed during visits to check for pressures? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brassfield, Tom ) [mailto:TOM.J.Brassfield@conocophillips.com] Sent: Tuesday, August 25, 2009 2:41 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B(DOA); Kanady, Randall B; Alvord, Chip Subject: RE: Remote Exploration Site Inspections-CPAI Tom, will fill-out the10-403 or 10-404 (?) forms and forward as required; in the meantime: Rick Overstreet fi-oni the Drilling aud Wells group and Leslie Senden w/ Envii-onmental inspected the following wells by helicopter on 8/19 & 8/20, landinb at each site: Well Name Comments from Inspection/Pictures Wellhead tarp in good shape, some free water around in cellar and Puviaq around wellhead, no sheen. Some distressed vegetation around the cellar. 9/ 16/2009 Remote Exploration Site Inspec~s-CPAI ~ Scout 1 Wellhead tarp in good shape Carbon 1 Wellhead tarp in good shape Mooses Tooth C Wellhead tarp needs repair Spark lA Wellhead tarp needs repair Lookout 1 Tree mostly covered, should be re-wrapped next season. Distressed vegetation around the cellar. Page 2 of 3 From a well inte~,n~ity stand point nothing of note was seen. Generally, all wells were in good condition with t~he bird covers. Puviaq had some standing surface water in or arou~ld fl1e cellar, but this water appeared to be froiil rece~lt rainstornis and no sheen was noted in any of tlie areas. Based on field observations, Mooses "Tooth C, Spark 1 A, and Lookout 1 should llave the bird covers replaced. Thanks, Tom From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 24, 2009 2:41 PM To: Brassfield, Tom J; Kanady, Randall B Cc: Regg, James B (DOA) Subject: RE: Remote Exploration Site Inspections-CPAI Tom and Randy, Were you able to accomplish the inspections as planned? Can you provide a summary? Thanks in advance, Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Monday, August 10, 2009 3:38 PM To: Brassfieid, Tom J; DOA AOGCC Prudhoe Bay Cc: Alvord, Chip; Kanady, Randall B; NS Env Studies Coord; Senden, Leslie; Maunder, Thomas E(DOA) Subject: RE: Remote Exploration Site Inspections-CPAI Checking schedules to see if we can accomodate your planned inspections. Will get back to you in day or so. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brassfield, Tom J [mailto:TOM.J.Brassfield@conocophillips.com] 9/16/2009 Remote Exploration Site Inspec~s-CPAI ~ Page 3 of 3 Sent: Monday, August 10, 2009 2:40 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B(DOA); Alvord, Chip; Kanady, Randall B; NS Env Studies Coord; Senden, Leslie Subject: Remote Exploration Site Inspections-CPAI Tom, as we discussed; CPAI is planning to perform remote exploration site inspections on 8/19 & 8/20. Leslie and I are planning to meet the chopper at the KIC heli pad at 1000 hrs on Wednesday 8/19/09. The plan is as follows: Wednesday 8/19/09 Meet at the KIC heli pad @ 1000 hrs Visit Lookout #1, Spark 1 A, Mooses Tooth C, Carbon #1, and Scout #1 Return to A~pine for the night Thursday 8/20/09 Lv Alpine for Puviaq- early as possible Return to Alpine for 1530 hrs flight to Deadhorse Chopper could fly back to Kuparuk with AOGCC inspector or? Thanks, Tom Tom Brassfield Staff Drilling Engineer 907/265-6377 (w) 907/244-5684 (c) 907/275-7352 (pgr) 9/16/2009 ~ ~ • ~ f:onoc.c~P"h~ll'ps Box 100360 Alaska 99510-0360 September 15, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~ ~ W ~~~ ' Re: Well Inspection 10-404 Sundry Spark #lA (Exploratory Test) Surface Location: 1608' FNL, 2497' FWL, Sec 8, T10N-R2E, UM X=291,158 & Y=5,939,589 ASP4 NAD27 Target Location: 2306' FNL, 2502' FWL, Sec 8, T10N-R2E, UM Bottom Hole Location: 2306' FNL, 2502' FWL, Sec 8, T10N-R2E, UM Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a status update for the field inspection of the Spark #1A location performed on 8/19/09 as required by 20 AAC 25.110. Please find attached the following documents: • Remote Well inspection Checklist - this inspection was a visual inspection and no pressure readings were taken. • The "as-built" plat • Photographs • A wellbore diagram • The 10-404 Sundry The request for renewal of suspension status will be filed with a 10-403 Sundry. Si~cerel ~ z``~,~'s!~-~'/; ~ Tom Brassfield ,~ Senior Drilling ~figineer cc: CONFIDENTIAL - Spark #1A Well File Chip Alvord ATO-1570 Leslie Senden ATO-1390 • • , STATE OF ALASKA ' " ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repalf Well ^ Plug Perforations ~ Stimulate ~ Othef ~ remote site insoection Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time E~ension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillipsAlaska, Inc. ~~=~c.~3~~„~3,; ^ Exploraiory ^~ 200-056/ / 3. Add~ess: Stratigraphic ^ Service ^ 6. API Numbel': P. O. Box 100360, Anchorage, Alaska 99510 50-103-20313-01 /" 7. KB Elevation (ft): 9. V~leli Name and Number: RKB 88' Spark 1A ,/`~ 8. Property Designation: 10. FieldlPool(s}: AA081802 ~ ../fJf~ _ ~f~ Exploration 11. Present Well Condition Summary: Total Depth measured 8522' ~ feet ' ~ true vertical 8445 feet PEugs (measured; Effective Depth measured 8335' feet Junk (measured) true vertical 8259' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 82' 16'" 115' 115' SURFACE 2522` 7.625" 2610' 2610' PRODUCTION ~~13' 5.5" 5046' 4978' PRODUCTION '4~~' S.5" 8512' 8435' Pertoration depth: Measured depth: 8135'-8150' true vertical depth: 8058'-8d74' Tubing (size, grade, and measured depth) 3.5"l2.875" , L-84 , 8082' Packers & SSSV (type & measured depth) Bakcr FB-1 packer a~ 7844' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) naR~ 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 -- Subsequent to operation -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^~ Development ^ Service ^ Daily Report of Well Operations _ 16. Well Status after work: s~~~~~r~es~ Q CQ Ga~ WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tom Brassfield @ 265-6377 Print d Name Chip Alvord '~ Title Drilling Manager ~. Si ture ,,. °" ~~: ~ Pho~e: 265-6120 ~ ~ Date ~~ j~~i / C. Y Pre ared b Sharon Allsu -Drake 263-0612 - - er • 7 Form 10-404 Revi~d 04/2006 ~ '~ ~' 1~ ~ ~ ~ ~ 'x .. ~ ~~ . :~ ~. `_ 2a0~ ~ ~~~~0 ~ ~~ .~~ it Original nly °1 ~ • Remote Well Inspection Checklist Well Name ~~„"~,~~_ Suspended ~ Abandoned ~ Coordinates: 7~ ~ ,~~~`~ - ~~~, f~~~ Date: G G Yes No N/A 1. Area surrounding Wellhead • Impounded Water ~ ^ ^ • Sheen present on ground water p ~ ~ 2. Cellar Area rrn.~_ ~~l y~~ ~1 ~ • Fluid in cellar ~ ~ ~ ~ Sheen present ^ ~~ ^ • Fluid level in cellar is..higher ~ lower ~ the same as ~ the level of the ground water outside the cellar. I~,~ /~ 3. Wellhead and tree • Presently leaking ^ [~ ^ • Evidence of prior leaks ~ ~' ~ 4. Bird Cover i~~ • Complete and secure S~ t~~ ~~t~.~ ~ ~ ~ • Evidence of fluids on inside of cover ^ ~ ^ Description of Tree and Wellhead: ( i.e. valve handles. Gages, `n_eedle valves, number of valves,etc.) ~IR°~ Vtv~., viSc~o~~r.~.P - C.'ir~ CL'V7°_~' , - i.v ~ Gi,L1>i/"l Printed Name: ~ Original to : Sharon ~~? Ct('/1 Signature Drake ATO 1533 • • ARCO Spark #1A FINAL Schematic By TJB 9/14/09 ~a115'RKBtoGL ~ 9-7/8" Hole 6-3/4" Hole 3-'/" FMC Tubing Hanger wuth BPV installed Base Permafrost ~ 600' MD 7-5/8" x 5.5" annulus freeze protected to 2000' with Diesel 7-5/8" casing cemented to surface with good returns ~SS @ 2725' MD 10.2 ppg kill weight brine inside tbg from perfs to 2000' MD with diesei cap to surface 9.9 ppg KW brine in the IA from 7852' MD to 1400' MD with diesel cap to surface 3-/12" 9.3 ppf L-80 tbg to 7944' MD ~- GLM with dummy @ 7852' MD Baker FB-1 Packer @ 7944' MD 2-7/8" 6.4 ppf L-80 tbg below packer ~-GLMs @ 8009'& 7980' MD f XN with XXN plug @ 8031' MD Tubing tail @ 8082' MD PerForations from 8135' to 8150' MD @ 6spf 77' of TCP Guns from PBTD of 8335' MD 16" Conductor ~ 7-5/8".29.7#. L-80. BTC Mod. R3 Surface Casina c~i~2610' MD-RKB TOC 12 ppa ~ ~ 6050' MD TOC 15.8 ~pa ~- 7200' MD 5-1 /2". 15.5#. L-80. BTC Mod. R3 Production Casinp ~a. 8512' MD-RKB TD @ 8522' MD/ 8445' TVD 1 _l _!~ • • 1 2 MRT A,~ PER K00~17ACS NOTES: ~ $B « ~ u sa as . . ~ ~ 1. CO~RDINATES SHOWN ARE ASP Z(N~IE 4, ~ NAD 27. • tj" ~~ 2. GEOGRAPHIC ~OORDINATES ARE NAD 27. v •e 1 -+ i 3 ~ ` • 4~ ~ 3. ELEVATIONS SHOWN ARE B.P.M.S.L 4. ALL D[STANCES ARE TRUE. ~ ~ y ~# ,~~ t 5. DATE OF SURVEY: 3/10/~H, ~B. L 00-fb7, ° ~~ Pg. 41, 42. & 53. ~ ~ .. •, u ~s ~ ~ ~ .~ ~ ` ~ . L \ 24 , ~l tp ~ 2e R ~ Y3p 14 ~ . ~~ ,A ~~ Cuttinq ~ ~ ~ s~0 ~ ~ toroy . ~ ~ ~ ~ ~ ~ 6~ . ~ ~~ ~ T~ICINI.TY ~l~lP NOT TO SCALE ~ p°a ~ zasr ~= R~q , ~ ~~ ~ ~ ARCO SPARK ~1 , c > ~ \ .~ ~ ~ ~ J LOCATED WITHIN PROTRACTEO ~ , Z~~ SEC. 8 TWP. 10 N., RGE. 2 E. Road UMIAT MERI~IAN ARCO SPARK #1 ~, s ~` LAT. = 70' 14' 17.793" ~ ~ ~~~ °~~. LQNG. ~ 151' 41' 11.395" !ce Pad Y = 5.939,589.0~# ~ X = 291,158.37 ~ 1608' F.N.L., 2497' F.W.L. ~ GROUND ELEVATION = ~5.7' ~0 ' N TOP Of [CE PAD ELEV. S 58.4 SURVEYOR'S CERTIFI~ATE .~~,~~~~~~~~~i~, ++ ~, -~~ ~. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ANp L[CEWSE~ TO PRACTICE ~ ~ ... ....... ~~P,.• LAND SURVEYING IN THE S7ATE OF ' r Gj ,~ ~` ~ ~~ 49th ~ '~~ ALASKA AND THAT THIS P~AT REPRESENTS A~URVEY DONE BY ME OR UNDER MY j ~ ~ DIRECT SUPERVISfON ~N~ TFiAT ALl %.....u ...... ..... ... . .... ~ DIMENSIONS AN0 OTHEF2 ~ETAf RE ~ LS A ., .. ~~~ "' """'• "•~ ~ J. ROOKUS~ I •~ ~ CORRECT AS OF MARCN 12, 2000 ~~~ ,,'~~~~ -~~ ~•~ ,,= ~~ rF~~~ ~ ~ LOUNSBURY ~ +~~~'~~~wa-~~~ <t ' ~-~ dc AS~tATES~ INC. ~~ ~ . ~it~ PtAN1V8R~ ~ IkF~A: Ml MODIlI.E: li~fX INItT: Yl ARCO Alesk~ Inc ~S ~Y ~ , . 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'~, A • ~ * '. ~~ N;~ . ~' , ~ ~ n~ .~ ~~~ ^ . ~ ^ * ~ ~ _ V ~, ~, ~ - ~ V ~ O r -a ~ w : ~ . ~' ~ ~ ~ ~ ' o ~ ~ ~ p Y V1 ~ ~ ~ ~ Y ^ O N C.~ ' , , R Q ..~ ~ ~ . ~ - O ~ ~ ~ :~ tA _ ~ - a O ~y N ^ .~ ~' ~ ~y O N - , ;..~ ~ a Qo ._ .~ o;^ oa , .... .. ~° v," eC N ~ ~~. = ~ ~ - ~ ~ O s= ~ c~,~ `o ~ ~ a~~' a~_ ~ ~~ - ~ ~ ~ x ~~ ~ Q .^r~ ~A ~ '~ ~'~ ~' ~ ~ N X ~ tA ~ . ~ ~ ~ . - . 4~! !~•' 1- U ..^. d> 'd ~,xr =' ' ~ :~: ~'~ ~ fl~= 1 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc FW: Disclosure of6 CPAI wells approved Subject:.. FW:piscH,)sureqf.(>ÇPAI weUsapprQv~d From:"Jim Cowan"<jc@dnr.state.ak.i1s> Date: TIm, 26 lun 2003 10: 16:06 ~0800 To: <sarah_palin@admin.state.ak.us>"., .; :"..'.' . "'.," . CC: <Steve_Davies@adinin.s1ate.ak.us>~ <HqwE,U'd_OkIand@ad!ßin;state.ak.us>,."Markp.Myers" " :<mdm@dnr.state.ak.ù~,~:~BonnieRoþ~öl1'!5i)r@çI.or;~tàte.*.uS>:;"~;::~:':;:.;: "!~~:::~::::;:'::.h!::/;;th,:~',:': ~:",~".,.,): . '.. Sarah, Steve and Howard, As follow-up to the message below, CPAI's land manager confirmed today that the only wells subject to appeal are the two Trailblazer wells. The Nigliq 1 & lA, Spark lA, Moose's Tooth C, Rendezvous A & 2 may be disclosed immediately. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 -----Original Message----- From: Jim Cowan [mailto:jc@dnr.state.ak.us] Sent: Wednesday, June 25, 2003 4:05 PM To: sarah palin@admin.state.ak.us Cc: Steve Davies@admin.state.ak.us; Howard Okland@admin.state.ak.us Subject: Disclosure of CPAI Trailblazer A-I & H-l wells appealed Sarah, Steve and Howard, The DNR received the anticipated appeal from ConocoPhillips regarding the Division of Oil & Gas' denial of extended confidentiality for data from the Trailblazer Al & Hl wells (NPR-A). That denial was issued on June 5, but release was delayed until tomorrow, June 26, so CPAI could utilize the 20-day notice-of-appeal period to formulate its position. The AOGCC is copied on the appeal letter and may have already have reached you. Consequently, we ask that you do not disclose confidential information and data from these two wells until we notify you that the appeal process is complete. Appeals of the similar denials for the other six wells are also due today, but have not yet been received. If we hear nothing more from CPAI I'll notify you in the morning that you may proceed with their release effective tomorrow, June 26. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 lofl c~(¡ VV' :.' ~ ,i; 8/11/2004 4'Só PM Re: [Fwd: Request to inspect NPR-A well data] Subject: Re: [F'Y<l: RequesttÖ inspect NPR..A Fróm:"R.ób ,Mintz" <Rob~rL Mintz@law.state.akus> Date: Thu, 15 May20031():54:~QrQ8QO. To: <steve - davies@admin.s~at~~ak~u!ì> " " ., ,'" "" ; ". .. Steve, is this the same thing you e-mailed about yesterday? Subject:Re: [Fwd: RequesttoinspectNPR-A well data] From: "Dan T.Semnonnt" <Dan_Semnount@admin.state.akÜs> Hate: Tim, 15 May 2003 15:09:54 -0800 To: Sarah Palin <sarah""p~..d¡n@adrnin.~tllte.ak.us>,.Ro):) Mintz<RQbert_Mint:('@law.stat~.ak.us> . ~~C: Randolph A Ruedrich~~l1dy_nle9ri,ch@ad.min;state.ak~lÙ!>':¡i,'. " "" .."':¡!¡fi'\',(:':;:,,',{:i¡::V,.,.; '" ok by me. Sarah Palin wrote: ------------------------------------------------------------------------ Subject: Request to inspect NPR-A well data Date: Wed, 14 May 2003 15:56:52 -0800 From: "Jim Cowan "::J.~_~nr . ~_!=..9:~.t?_:~!<_:..1,1,..~",- Reply-To: ~,gil!U~.~~~J!~9-EE' stat~.~!<_~_.'::1:~.~ To: .~~~_ë!:~-P~_!_~.!:!~~Q!!l-~~:..~~~!:.5'_~ë!:_)(._:..!:!.~"'- CC: "Mark D. Myers" ~!!.~.l!l...@!g.!.l-I::..:.stë!:!=~_,~k-'..~_f?"'::: Good afternoon Sarah. ConocoPhillips Alaska has applied to the Division of Oil and Gas for extensions of the normal 24-month confidentiality period for eight wells, six of which are within the NPR-A. At Mark's request (and as is the Division's normal procedure), ConocoPhillips will be presenting their case to the Division next wednesday. Inasmuch as the well data are archived only at the AOGCC and in order to prepare for CPAI's showing we would like to review the well data on your premises on the afternoon of Monday, May 19. This is to avoid having only the applicant's "spin" on the significance of the well data and information when arriving at our determination. This represents a rather recent and advantageous change in protocol between our two agencies and is the result of consultations between our respective attorneys, Mintz and Landry. I believe it's the first opportunity we've had to take advantage of it. With your approval I'll work out the details with Steve Davies. The wells of interest, but for which we have no information, are: Trailblazers A-I & H-l Spark lA Moose's Tooth C Rendezvous A Rendezvous 2 Nigliq 1 & lA are also on CPAI's list, but we have all appropriate data for those and need not review AOGCC files. Thanks for your help. Jim Cowan Manager, Resource Evaluation State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 10£2 ,"" :"';" /~ O"J "I lOll . ."' "" ". . . , ...' 8/1l/2004 4:59 PM Re: [Fwd: NPRA wells in question are. . .j AI\ vJ~ t: 1-0<1 To: <stevc_davics@admin.state.aJ<:.us> '," ., ':'!:' '.. ," ..;' ,::" . .: , .' "., ,;.,", .. ,..: ; What's the deal with CPAI "showing" to Mark? I am guessing that means CPAI has requested that DNR grant extended confidentiality for these wells and that they are approaching the end of their two-year confidentiality period. If that is the case, and the purpose of the review requested by Jim Cowan is to assist Mark in making the determination whether to grant CPAI's request, then I don't see a problem. Otherwise we should talk about it. Steve Davies <steve davies@admin.state.ak.us> 05/14/03 -"'-.-..---.-----.----- 03:15PM »> Rob: Jim Cowan wells as described their staff to requests to view all files related to conhfidential below. Do we have an agreement with DNR that allows view confiedntial data? Thanks, Steve Davies 793-1224 1 of 1 8/11/20044:58 PM Re: NPRA wells in question are. . . SllbJeçt:R~:NPRA wells in questìòriareO.; From: . Steve Davies <steve - davies@admin.state.ak.us> Date: Wed, 14 May 2003 '" ,', ' :fO;;'Jþl1- ç~)v~@dnf.~tat~;,tik.:~~,~: :;;: :~:¡~Î~:;.~~9¡~tÆ¡~~t ;:)ii!i~.~<,'::', ;"¡"';r:: ' ¿¡J. ø'l.P.J.¿;> 7""Ø , :.~~~" .::" ;:'~~~,,::,;.l!:);;:;:ir::~~7~~:;::":\::: >.:h~A./:...r~~';~;;,i:;:',;::,;":::"?f};~:!~:;: :,;'::,:,j Jim: A formal request though Sarah Palin is the proper procedure. I have a call in to Rob Mintz about this. I have booked the small conference room for next Monday afternoon for your use if the request is approved. I'll let you know what Rob says. Steve D. Jim Cowan wrote: Trailblazers A-1 Spark 1A Mooses's Tooth C Rendezvous A Rendezvous 2 & H-1 I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 1 of 1 8/11/20044:58 PM [Fwd: NPRA wells in question are. . .J Subject: [Fwd: NPRA wells in question are. . .] From: Steve Davies <steve_davics@admin.state.ak.us> Dl1tc: Wed, 14 May 2003 15:15: 18 -0800 .;Jt.,'c' - e: 5"'" To: '~QÞ: Miri~ ,~9b.~Í1~~i~t~J~w ~s~t~;~JÇ;~i~~~i~~~~~;~¡h;~¡~iP1i;j~:~;¡i~\' ;:i ~¡::\'~~;i;~~¡:;~~;~~~ifN~~¡¡~:~'\:~.~\~¡~~',::;:ii,:~:¡t~~; ,:,~ .~~~::~~F:,:,:!;:>b~,(:j Rob: Jim Cowan requests to view all files related to conhfidential wells as described below. Do we have an agreement with DNR that allows their staff to view confiedntial data? Thanks, Steve Davies 793-1224 Subject:NPRA wells Ì1lqUt~sti9nare,.. . }c'rom: "Jim Cclwan" <je@dnr.state.ak.us> Hate: Wed, 14 May 2003 13:56:30 -0800 To: <steve...:. davies@a(Jiri.nj~a~è'i~K.US>C '" ,.:., ""',.., ". ' " ,'" , " .,' ...: ,'..",'.'.', , . :, .::,. "',.", Trailblazers A-I Spark lA Mooses's Tooth C Rendezvous A Rendezvous 2 & H-l I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 Content-Type: message/rfc822 ,NPRA wells in question are. . ..em) Content-Encoding: 7bit lofl 8/11/20044:57 PM NPRA wells in question are. . . Stìbject: NPRA wells in question are. . . From: "Jim Cowan" <jc@dnr.state.ak.us> Date: Wed, 14.May 2003 13:56:30.,0800 To:. ~sieye - daVies@a~iq;~tatQ,a1f;~1J~~. :,:; ¡(. " Trailblazers A-1 Spark 1A Mooses's Tooth C Rendezvous A Rendezvous 2 & H-1 I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 1 of 1 R/1 1/2004 4:';7 PM f ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 20l.:J ,-ðS-? TRANSMITT AL CONFIDENTIALDATA* FROM: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: Spark lA DATE: 11/07/2002 Transmitted herewith is the following: Spark 1A 501032031301 permit 200-056 CDROM Production Test Data, Fluid PVf Data _Schlumberger Oilphase report- Fluid Analysis on Separator Samples, Oct 2001(NAM675)(PDF) _Halliburton final report 2000 Spark 1 _Halliburton Flow tests 1, 2, 3, 4, 5, 6 Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska desiqnated (AOGCC) release date *IIOn behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Spark 1A Well, Drilling Permit No. 200-056 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31. 05.035(c) and 20 AAC 25.537(d). While we are submitting this d~ta for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue.1I cc:~reg ~iISO/)I Geoløg~~ndY Bond, Engineering Evaluatiøn RtiCcipt: ~. {A.YJ~/ Date: RECEIVED Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 NOV 0 72002 AlaSka Oil & Gas Gons. Commission Prepared by:MråtdI'ltll. Lemke Phillips Alaska IT Technical Databases [Fwd: Spark lA (200-0056) Data CD] Subjétt: '[Fwd: Sparkî~;(200-005Q) Ðata CD]' From: John Hartz <jack _hartz@åän1in.state.ak'.us> Date: Tue, 27 Apr 200409:16:28 -0800 This should go to well file on Spark 1A -- 200-056 ** API WELL # PTD # Conf 50-103-20313-01-00 2000560 CONOCOPHILLIPS ALASKA INC UICPermit# No SPARK 1A Oper Name Well Name Thanks, Jack -------- Original Message -------- Subject: Spark 1A (200-0056) Data CD Date: Tue, 06 Apr 2004 11:00:16 -0800 From: John Hartz <jack hartz@admin.state.ak.us> Organization: State of Alaska To: Howard Okland <howard okland@admin.state.ak.us> CC: Robert Crandall <bob crandall@admin.state.ak.us>, <steve davies@admin.state.ak.us> Stephen F Davies The subject Production Test Data and Fluid PVT Data are releasable according Sandra Lemke at CPA (265-6947) and Von Cawvey. Sandra and Von conferred this morning and Sandra confirmed to me that the data on the CD is releasable. Jack 1 of! 4/27/2004 10:57 AM ~ r'\ The subject Production Test Data and Fluid PVT Data are releasable according Sandra Lemke at CPA (265-6947) and Von Cawvey. Sandra and Von conferred this morning and Sandra confirmed to me that the data on the CD is releasable. Jack Þ (tv1 0-- ~ \.I~ # 11:2-,;),88 FW: Disclosure of 6 CPAI wells approved Subject: FW: Disclosure of 6 CPAI wells approved Date: Thu, 26 Jun 2003 10:16:06 -0800 From: "Jim Cowan" <jc@dnr.state.ak.us> Reply-To: <Jim_Cowan@dm'.state.ak.us> To: <sarah_palin@admin.state.ak.us> CC: <Steve_Davies@admin.state.ak.us>, <Howard_Okland@admin.state.ak.us>, "Mark D. Myers" <mdm@dnr. state.ak.us>, "Bonnie Robson" <br~dnr.state.ak.us> Sarah, Steve and Howard, As follow-up to the message below, CPAI's land manager confirmed today that the only wells subject to appeal are the two Trailblazer wells. The Nigliq 1 & lA, Spark IA, Moose's Tooth C, Rendezvous A & 2 may be disclosed immediately. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 ..... Original Message ..... From: Jim Cowan [~.~.~.~.!.~.~.~..~.~.~_9.~.~..~..~.~..:..~.~] Sent: Wednesday, June 25, 2003 4:05 PM To: sarah_palin®admin.state.ak.us Cc: Steve Davies@admin.state.ak.us; Howard Okland@admin.state.ak.us Subject: Disclosure of CPAI Trailblazer A-1 & H-1 wells appealed Sarah, Steve and Howard, The DNR received the anticipated appeal from ConocoPhillips regarding the Division of Oil & Gas' denial of extended confidentiality for data from the Trailblazer A1 & HI wells (NPR-A). That denial was issued on June 5, but release was delayed until tomorrow, June 26, so CPAI could utilize the 20-day notice-of-appeal period to formulate its position. The AOGCC is copied on the appeal letter and may have already have reached you. Consequently, we ask that you do not disclose confidential information and data from these two wells until we notify you that the appeal process is complete. Appeals of the similar denials for the other six wells are also due today, but have not yet been received. If we hear nothing more from CPAI I'll notify you in the morning that you may proceed with their release effective tomorrow, June 26. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 FRANK H. MURKOWSKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF Oil. AND GAS 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL #7002 0860 0003 3538 7846 RETURN RECEIPT REQUESTED June 5,2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR Re: Request for extended confidentiality Spark lA, Rendezvous A & 2, Moose's Tooth C Dear Mr. Mott: JUN 0 9 2003 Alaska Oil & Gas Cons. Commission Anchorage I am responding to your April 10, 2003, letter to Commissioner Irwin in which you requested, on behalf of ConocoPhillips Alaska, Inc. (CPAI) and the working interest owners, extended confidentiality under 11 AAC 83.153 for the Spark IA, Rendezvous A, Rendezvous 2 and Moose's Tooth C well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission (AOGCC). Originally scheduled for release during May 2003, the Division of Oil and Gas (Division) temporarily extended the confidentiality of this well information until June 6, 2003, to allow CPAI to make a showing that the information is significant for the valuation of unleased land more than three miles from the wells. CPAI presented the information to the Division on May 29, ~ 2003. CPAI requested that the Division authorize extended confidentiality for information derived from these wells until 90 days after the next federal NPR-A oil and gas lease sale (tentatively scheduled for mid-2004) or until the Bureau of Land Management rules that disclosure is appropriate (upon lease expiration or with earlier consent of the lessee), whichever first occurs. As you know, 11 AAC 83.153(a) provides that the commissioner may extend confidentiality for well information if the well is located more that three miles from unleased lands. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05.035from a well located more than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or information contain significan, t information relating to the valuation ofunleased land beyond the three-mile radius." All wells subject to this request are more than three miles from unleased lands. "Develop, Conserve, attd Enhance Natural Resources for Present attd Future Alaskans." Having considered the information provided by CPAI, the request for extended confidentiality of reports and information derived from the referenced wells is denied. The reasons for this denial include, but are not limited to: While information from the wells is significant for evaluation of surrounding leased lands it is not significant for evaluation of unleased lands eight and more miles away and for which the applicant failed to submit bids in the June 2003 NPR-A lease sale. · Information from the Spark 1 well, the "mother" borehole for the Spark lA sidetrack, has been released to the public. · CPAI disclosed in a press release dated May 21, 2001, that the Spark 1 and lA, Moose's Tooth C and Rendezvous A and 2 wells all targeted the Alpine producing interval and that all encountered oil or gas or condensate in what was believed to be three separate accumulations. · The same press release disclosed test information germane to the Spark lA and Rendezvous A wells. · Long available to the public are the data and information from exploration wells drilled by the federal government during the U.S. Navy and U.S. Geological Survey NPR-A exploration programs. A number of these wells are located in the unleased areas used by the applicant to justify the requested extension of well confidentiality. Hence substantial information regarding the petroleum potential of these unleased areas already exists in the public record. By copy of this letter I am advising the AOGCC to release reports and information from the Spark lA, Rendezvous A & 2, and Moose's Tooth C wells on Friday, June 6, 2003, upon expiration of the previously granted temporary 45,day extension. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals~dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Sincerely, Mark D. Myers Director Cc~ Sarah Palin, Commission Chair, AOGCC Jeff Landry, Department of Law Mike Kotowski Jim Cowan ~~Sl~k OIl~ ~ GAS CO~SI~RYA~I~IO~ CO~SSIO~T FRANK H. MURKOWSKI, GOVEFtlVOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 16, 2003 Mr. Richard P. Mott Vice President, Exploration and Land ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Requested notice before disclosure to DNR Dear Mr. Mott: When ConocoPhillips Alaska, Inc. ("ConocoPhillips") submitted to the Commission the data required under 20 AAC 25.071 for wells Spark lA, Moose's Tooth C, Rendezvous A, and Rendezvous 2, you asked the Commission to notify you before the'data are disclosed to the Department of Natural Resources ("DNR") or the public. We understand that ConocoPhillips has applied to DNR for extended confidentiality for these wells under AS 31.05.035(c) and 20 AAC 25.537(d). DNR has informed us that it would like to review these well data at the Commission's offices on the afternoon of May 19, 2003, for the purpose of determining whether to grant the application for extended confidentiality. It is our understanding that DNR has the authority to review such confidential well data for that purpose. See 1984 Inf. Op. Att'y Gen. (661-84-0523; July 3); State, Dep't of Natural Resources v. Arctic Slope Regional Corp., 834 P.2d 134 (Alaska 1991). In light of your request that the Commission provide you advance notice in these circumstances, we are providing you this notice as a courtesy. ~,cerely, ~ Randy~~R edrich, Commissioner Alaska Oil and Gas Conservation Commission CC: Jim Rudd, ConocoPhillips (mailed and faxed) Barbara Fullmer, ConocoPhillips (mailed and faxed) Paul Mazzolini, ConocoPhillips {mailed and faxed) Richard P. Moth ConocoPhfllips {marled and faxed) John Bridges, Anadarko {mailed and faxed) SD\RR/jjc FRANK H. MURKO IFSKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS CERTIFIED MAIL #7002 0860 0003 3538 7778 RETURN RECEIPT REQUESTED 550 WEST 7TM A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 April 21, 2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR Re: Requests for Extension of Confidentiality under 11 AAC 83.153 Nigliq 1 Nigliq lA Trailblazer A-1 Trailblazer H-1 Spark lA Moose's Tooth C Rendezvous A Rendezvous 2 50103203700000 50103203700100 501032036400 501032036900 501032031301 501032031500 501032031600 501032036300 I am responding to your letters of April 9 and 10, 2003, requesting extended confidentiality under 11 AAC 83.153 for well data, reports and information generated from the eight referenced wells and filed with the Alaska Oil and Gas Conservation Division (AOGCC) under AS 31.05.035. For wells more than three miles from unleased land, as is the case here, 11 AAC 83.153(a) grants the commissioner discretionary authority. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05.035 from a well located more than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three-mile radius." Inasmuch as all wells are more than three miles from unleased lands, confidentiality for the eight referenced wells is extended for only 45 days from this date (through June 5, 2003) during which time the Division of Oil and Gas will require a showing to establish the significance of well data from the referenced wells to unleased OCS and NPR-A lands and to state lease ADL 390348 which is due to "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." expire September 30, 2003. The showing should be scheduled prior to May 30, 2003, to allow the Division to make a decision by June 5, 2003, regarding further extension of the confidentiality period. Extended confidentiality for the remaining four wells for which you requested extended confidentiality (Hunter A, 501032040500; Lookout 1, 501032035900; Lookout 2, 501032041000; and Mitre 1, 501032040900) will be reviewed prior to their 2004 disclosure dates. Please submit that request on or about March 26, 2004, so that the significance of the well information can be evaluated in the context of activities up to that time. By copy of this letter I am notifying the AOGCC of the 30-day extension of confidentiality for the eight referenced wells. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals@dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31 st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Mark D. Myers Director Cci Sarah H Palin, Commission Chair, AOGCC JeffLandry, Department of Law J. R. Cowan, Division of Oil and Gas Permit to Drill 2000560 MD 8522 TVD DATA SUBMITTAL COMPLIANCE REPORT 4115~2003 Well Name/No. SPARK lA Operator CONOCOPHILLIPS ALASKA INC 8445 Completion Dat 4/4/2001 Completion Statu SUSP Current Status SUSP A~I I~o. 50-103-20313-01-00 UIC N REQUIRED INFORMATION Mud Log ~ ~.~ ~, Sample Directional Survey ~y-~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Run No (data taken from Logs Podion of Master Well Data Maint) Interval OH / Dataset Start Stop CH Received Number Comments 25 8320 Open 6/22/2000 09662 25-8320 Well Cores/Samples Information: Name '--G~CL-TEM/PRES 5 cP~KER SE'IT 5 u~1~l - CASED2~0 0(~ ~BE'~ST DT DIP SL ~2 S~RPT ~)/]; J~ ~' OGPJCTN/SLD-TVD 2/5 ~GPJEWR4-TVD 2/5 DGPJCTN/SLD-MD 2/5 ~-'~R/EWR4-MD 2/5 /..,,,Production Log2~Cu~ 1/2 Interval Start Stop FINAL FINAL FINAL FINAL FINAL 1 1 FINAL FINAL FINAL FINAL FINAL FINAL 2646 8468 Open 6/29/2000 09632 0 8360 Open 6/22/2000 09659 OH 6/29/2000 9632 8110 8145 OH 6/22/2000 7800 8200 CH 6/22/2000 7800 8020 CH 6/22/2000 25 8320 CH 6~22~2000 600 8350 OH 6/22/2000 OH 6/22/2000 OH 6~22~2000 2716 8522 OH 5/10/2000 2610 8445 OH 6/29/2000 2610 8445 OH 6~29~2000 2730 8522 OH 6~29~2000 2730 8522 OH 6~29~2000 5500 8287 CH 6/6~2000 0 7894 OH 6/11/2001 9659 9662 2646-8468 0-8360 SPERRY DGPJCTN/SLD/EWR4 8110-8145 7800-8200 7800-8020 25-8320 BL(C) 600-8350 SCHLUM DS-DT SCHLUM DSI/FMI SPERRY 2716.89-8522. 2610-8445 2610-8445 2730-8522 2730-8522 BL(C) 5500-8287 0-7894 BL, Sepia Sent Dataset Received Number Comments Permit to Drill 2000560 MD 8522 TVD DATA SUBMITTAL COMPLIANCE REPORT 411512003 Well Name/No. SPARK lA Operator CONOCOPHILLIPS ALASKA INC 8445 Completion Dat 4/4/2001 Completion Statu SUSP APl No. 50-103-20313-01-00 Current Status SUSP UIC N ADDITIONAL INFORMATION Well Cored? Y/~) A ~'1'~'~ Y iN R~.r~v~.d. Daily History Received? Formation Tops Comments: Compliance Reviewed By: ALASKA OIL GAS CONSERVATION FAX 907-276-7542 PHONE 907-279-1433 COMMISSION FACSIMILE TRANSMITTAL SHEET TO: J , ~ I Y~ co~-P~! FAX NUMBER: DATE: / TOTAL NO. OF PAGES INCLUDING COYER: PHONE NUMBER: SENDER'S REFERENCE NUMBER: [] URGENT [] FOR REVIEW [] PLEASE COMMENT [] PLEASE REPLY [] PLEASE RECYCLE NOTES/COMMENTS: AOGCC 333 WEST 7TM AVENUE, SUITE 100 ANCHORAGE, AK 99501-3935 ALASKA OIL AND GAS CONSERYA~ION C0~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 20, 2002 James R. Winegamer, CPL ConocoPhillips Alaska, Inc. Exploration and Land P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Public Data Release Date for the ARCO Spark lA Well (Permit 200-056) Dear Mr. Winegarner: ConocoPhillips Alaska, Inc. ("CPA") has requested the Alaska Oil and Gas Conservation Commission ("Commission") reconsider its earlier determination and recognize April 4, 2001 as the completion date of the ARCO Spark lA well. On September 17, 2002 the Commission had advised CPA that in the course of an audit of the NPRA wells drilled by Phillips to verify well status and projected release dates, it had concluded the correct completion date for the Spark lA well to be April 29, 2000. A review of this well file highlights the confusion surrounding selection of an appropriate "completion" date.. Adding to the confusion was a request by CPA to the Department of Natural Resources ("DNR") to extend confidentiality to this data that would otherwise be subject to release on July 1, 2002. DNR granted extended confidentiality for the well' through September 3, 2002. However, based on a review of' the well records and in particular,' because of an Application for Sundry Approval for an operatiOnal shut down that was approved by the Commission on May 9, 2000 (approval number 300-115), the Commission has reconsidered its earlier determination and accordingly finds that April 4, 2001 is the appropriate well completion date for the Spark lA well. The projected release date should be May 4, .2003. If you have any questions, please contact Steve Davies at 793-1224. S~cerely, Camm~Oechsli TaylOr Chair ConocoPhillips Alaska, Inc. Exploration B. Land P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Phone: (907) 265-9614 Fax: (907) 263-4966 James R. Winegarner, CPL Staff Landman October 28, 2002 Cammy Taylor, Chairman/Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501-3539 Re: Public data Release date for the ARCO Spark lA well (permit 200-056) ConocoPhillips Alaska, Inc. ("CPA") appreciates the opportunity to meet with Alaska Oil and Gas Conservation Commission representatives on October 16, 2002, to discuss CPA's position regarding the disputed completion date and anticipated release date of the ARCO Spark lA well. CPA respectfully requests the Commission to recognize April 4, 2001 as the completion date on this well, based on the fact that well test operations during the winter drilling season in 2000 were not completed due to termination of the winter exploration season (20 AAC 25.072). CPA erroneously submitted a 10-407 dated June 1, 2000, which showed no completion date and the well status as suspended; date of first production was also reported in error as May 1, 2000. Our intent was to report a suspended status for the well at that time and show the production tests shutdown on May 1, 2000, as noted in the well summary report submitted with the 10-407. Attached is a corrected Form 10-407 accurately categorizing ARCO Spark IA as a completed oil well with the completion date tied to the actual conclusion of well testing operations on April 4, 2001. Other documents submitted in support of the ARCO Spark lA well operations by CPA are as follows: · Form 10-403 approved by the Commission May 7, 2000 (approval 300-115) recognizing the well as being in a status of 'Operational shut-down'. · Application for Sundry Approvals (Form 10-403) received and approved by the Commission (approval 300-296) on November 29, 2000. This sundry outlined CPA's intent to return to complete testing operations on the ARCO Spark lA well during the 2001 winter drilling season. · Forml0-403 approved by AOGCC on April 27, 2001 (approval 301-097) which granted Administrative Shut-In (20AAC.25.990(62)). This sundry included an overview of well test procedures and referenced completion of test operations on April 4, 2001. · Sundry 302-11 reclassifies the well as shut-in effective July 23, 2002, as we intend to return to the well for future operations. If you have any questions or need additional information, please call me. RECEIVED 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 r'~ Gas r~ Suspended ~] Abandoned [--} Service E~ 2. Name of Operator 7. Permit Number ConocoPhillips Alaska, Inc. 200-056 / 302-115 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20313-01 4. Location of well at surface 9. Unit or Lease Name 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM (ASP: 291158, 5939589) Exploration NPRA At Top Producing Interval 10. Well Number 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65) Spark #lA At Total Depth 11. Field and Pool 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65) Exploration 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. RKB 88 feetI ADL AA-081802 ALK AK5147 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 13, 2000 April 22, 2000 April 4, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8522' MD / 8445' TVD 8335' MD / 8259' TVD YES [~ No C~I N/A feet MD 605' MD 22. Type Electric or Other Logs Run LWD, Neutron/Density/4_phase/GR, DSI, VSP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# [] Surface 115' 20" 135 sx AS I 7.625" 29.7# L-80 Surface 2610' 9.875" 305 sx Class G, 240 sx Class G 5.5" 15.5# L-80 Surface 5046' 6.75" 110 sx LiteCrete, 115 sx Class G 5.5" 15.5# L-80 5046' 8512' 6.75" included in above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 8050' 7848' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8135' - 8150' MD 8059'- 8074' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Temporarily Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/19/2001 115 hours Test Period · 8180 83480 495 24/64 to 64/64"'1 10200 scf/stb Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 2500 psi 1900 psi 24-Hour Rate > 1707 bopd 17420 mcfd 103 bwpd 55 deg. APl 28. CORE DATA water, core Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or Submit chips. OCT 2¢ 2002 ~,laska 0il & Anchora,,.,, Form 10-407 Rev. 7-1-60 CONTINUED ON REVERSE SIDE Submit in duplicate ~9. '. ~, 30. ~, GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Base Permafrost 605' 605' Top Nanushuk 3005' 3004' LCU 7540' 7466' Upper Jurassic 8105' 8029' TD 8522' 8445' Wellbore P&A'd 31. LIST OF ATTACHMENTS 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 S ig n ~,L,..~J,-,-/~/'~., -,.~/~'~ ' .~ Title Exploration Drilling Team Leader Date //////~ ~' ./~ ~,, Prepared by Sharon Al/sup-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 "none". RE EI'VED Form 10-407 OCT 2 9.2002 Oil& Gas ~ns. Comml~lon Anchorage Re: Release of Spark IA Well Data Subject: Re: Release of Spark lA Well Data Date: Fri, 20 Sep 2002 16:26:06 -0800 From: Cammy Oechsli Taylor (Cammy_Taylor~admin. state.ak.us~ Organization: DOA-AOGCC To: James R Winegarner (jwinega@ppco.com> CC: Richard A Garrard (rgarrard~ppco.com~, James M Ruud (jruud~ppco.com>, Gregory C Wilson (gcwilso~ppco.con~, David B Bannan (dbannan~ppco.corn~, Tom J Brassfield (tbrass~ppco.com>, Barbara F Fullmer <bffullm~ppco.com>, john_bridges~nadarko.com, craig_lewis@anadarko.com, Dan Seamount <dan_seamount~admin. state.ak, us>, Mark Myers <mark_myers~dnr. state.ak, us> Thank you for your e-mail. As a result of the issues ConocoPhillips raised, the Commission will stay the effect of its September 17, 2002 decision to release the Spark lA until October 30, 2002 for the purpose of reconsidering the Commission's original decision. Cammy Taylor James R Winegarner wrote: > Commissioner, > Pursuant to your letter dated September 17, 2002, ConocoPhillips Alaska, > Inc. (formerly known as Phillips Alaska, Inc.), respectfully requests an > additional thirty (30) days before the Spark iA well data is released to > the public. This will give representatives from ConocoPhillips and the > Alaska Oil and Gas Conservation Commission ("AOGCC") time to meet and > discuss/clarify all of the Spark IA well data issues. Once ConocoPhillips > and AOGCC have met, ConocoPhillips will then need time to discuss with > senior management, legal department, and partners before any decision can > be made regarding an extended confidentiality request. Some of the issues > that need clarification are described below. Please let know if the AOGCC > will grant an additional 30 days to work through these issues. > Thanks, JRW The status of the Spark iA well, and whether or not the Spark iA well is a "completed" well, needs to be discussed/clarified. (as well as all other ConocoPhillips NPRA wells). Review the procedures and requirements for temporary shut down of drilling or completion operations pursuant to 20 AAC 25.072. In the spring of 2000, completion operations at Spark iA were shut down due to weather conditions, therefore, was a correct Application for Sundry Approvals (Form 10-403) submitted to AOGCC requesting approval of such operation shut down? If the correct Application for Sundry Approvals (Form 10-403) was not submitted to AOGCC, can it be submitted to AOGCC or corrected at this point in time? If Spark iA well data is released, Spark iA well data collected in the spring of 2001 should not be released to the public. Cammy Oechsli Taylor <cammy_taylor~admin. state.ak.us> Commissioner Alaska Oil and Gas Conservation Commisison Department of Administration 1 of 2 9/20/2002 4:26 PM Release of Spark lA Well Data ~ Subject: Release of Spark lA Well Data Date: Thu, 19 Sep 2002 17:12:38-0800 From: "James R Winegarner" <jwinega~ppco.com> To: cammy_taylor~admin~ state.ak.us CC: "Richard A Garrard" <rgarrard~ppco.com>, "James M Ruud" <jruud~pco.com>, "Gregory C Wilson" <gcwilso~ppco.com>, "David B Bannan" <dbannan~ppco.com>, "Tom J Brassfield" <tbrass~ppco.com>, "Barbara F Fullmer" <bffullm~pco.com>, john_bridges~anadarko.com, craig_lewis~anadarko.com Commissioner, Pursuant to your letter dated September 17, 2002, ConocoPhillips Alaska, Inc. (formerly known as Phillips Alaska, Inc.), respectfully requests an additional thirty (30) days before the Spark IA well data is released to the public. This will give representatives from ConocoPhillips and the Alaska Oil and Gas Conservation Commission ("AOGCC") time to meet and discuss/clarify all of the Spark IA well data issues. Once ConocoPhillips and AOGCC have met, ConocoPhillips will then need time to discuss with senior management, legal department, and partners before any decision can be made regarding an extended confidentiality request. Some of the issues that need clarification are described below. Please let know if the AOGCC will grant an additional 30 days to work through these issues. Thanks, JRW The status of the Spark iA well, and whether or not the Spark IA well is a "completed" well, needs to be discussed/clarified. (as well as all other ConocoPhillips NPRA wells). Review the procedures and requirements for temporary shut down of drilling or completion operations pursuant to 20 AAC 25.072. In the spring of 2000, completion operations at Spark lA were shut down due to weather conditions, therefore, was a correct Application for Sundry Approvals (Form 10-403) submitted to AOGCC requesting approval of such operation shut down? If the correct Application for Sundry Approvals (Form 10-403) was not submitted to AOGCC, can it be submitted to AOGCC or corrected at this point in time? If Spark IA well data is released, Spark IA well data collected in the spring of 2001 should not be released to the public. I of 1 10/20/2002 3:36 PM ALASKA OIL AN~ GAS CONSERVATION COPl~I~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James R. Winegamer District Landman Exploration and Land ConocoPhillips PO Box 100360 Anchorage AK 99510 September 17, 2002 Dear Mr. Winegamer: The Alaska Oil and Gas Conservation Commission ("Commission") has completed an audit of the NPRA wells drilled by Phillips Alaska, Inc. ("Phillips") to v. erify the well status and projected release dates. In letters accompanying data submittals for these NPRA wells, Phillips requested that the Commission provide notice prior to any public disclosure of confidential information so that Phillips might be heard on the issue. Pursuant to AS 31.05.035(c), the data Phillips provided as required by AS 31.05.035(a) will be kept confidential for 24 months following the 30-day filing period unless the owner of the well gives written permission to release the reports and information at an earlier date. The Commissioner of Natural Resources may extend the 24-month period of data confidentiality under certain circumstances. In the case of the Spark lA, Permit to Drill # 200-056, the Department of Natural Resources ("DNR") granted extended confidentiality for the well through September 3, 2002 although the Commission's records indicated that the status of this well is "Operation Shutdown". An audit of the Commission's records indicates that this status is in error. The Commission has determined that the Spark lA well was in fact completed (equipped and conditioned so that it was capable of producing or injecting fluids) on April 29, 2000 and is therefore subject to release after September 3, 2002. Unless the Commission hears from Phillips before September 20, 2002, the Spark lA file will be released to the public on September 23, 2002. Post-it® Fax Note 7671 James R. Winegamer September 17, 2002 Page 2 of 2 The following is a list of Phillips' NPRA wells that have projected release dates. Rendezvous A PTD # 200-054 5/27/03 Lookout 1 PTD # 201-003 5/4/04 Rendezvous 2 PTD # 201-007 5/28/03 Hunter A PTD # 202-013 4/26/04 Mitre 1 PTD # 202-026 5/21/04 Lookout 2 PTD # 202-027 6/5/04 Mooses Tooth C PTD # 201-049 5/6/03 If you have any questions about these release dates, please contact Steve Davies at 793- 1224. Although it has been the practice of the Commission to publish well data release dates in advance on its website, it is the operator's or owner's responsibility to make a timely application to the Department of Natural Resources in the event that extended confidentiality is desired. You should not rely on receiving any reminders from the Commission regarding the release dates for these wells. Sincerely, Chair COT:\jjc cc: Mark Meyers, DOG James R. Winegamer District Landman Exploration and Land Phillips Alaska, Inc. The Alaska Oil and Gas Conservation Commission (Commission) has completed an audit of the NPRA wells drilled by Phillips Alaska, Inc. (PAI) to verify the well status and projected release dates. There are a number of wells drilled by Phillips in NPRA for which the Commission received a request from Phillips to provide notice prior to any public disclosure of confidential information so that Phillips might be heard on the issue. Pursuant to AS 31.05.035(c), the data you provided as required by AS 31.05.035(a) will be kept confidential for 24 months following the 30-day filing period unless the owner of the well gives written permission to release the reports and information at an earlier date. The Commissioner of Natural Resources may extend the 24-month period of data confidentiality under certain circumstances. In the case of the Spark lA, Permit to Drill # 200-056, the Department of Natural Resources (DNR) granted extended confidentiality for the well through September 3, 2002 although the Commissioffs records indicated that the status of this well was 'Operation Shutdowrl'. An audit of the Commissioffs records indicates that status was in error. The Commission has determined that the Spark lA well was in fact completed on April 29, 2000 and is therefore subject to release after September 3, 2002. Unless the Commission hears from Phillips before September 20, 2002, the Spark lA file will be released to the public on September 23, 2002. The following is a list of Phillips' NPRA wells that have projected release dates. Rendezvous A PTD # 200-054 Lookout 1 Rendezvous 2 Hunter A PTD # 201-003 w'~/sI PTD # 201-007 PTD # 202-013 Mitre 1 PTD # 202-026 Lookout 2 PTD # 202-027 Mooses Tooth C PTD # 201-049 5/27/03 /28/0 03 / 4W /o 4 5/21/04 6/5/04 If you have any questions about these release dates, please contact Steve Davies at 793- 1224. Although it has been the practice of the Commission to publish well data release dates in advance on its website, it is the operatol~s or ownel's responsibility to make a timely application to the Department of Natural Resources in the event that extended confidentiality is desired. You should not rely on receiving any reminders from the Commission regarding the release dates for these wells. Permit to Drill No. 2000560 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2002 Well Name/No. SPARK iA Operator PHILLIPS ALASKA INC. API No. 50-103-20313-01-00 MD 8522 TVD 8445 Completion Date Completion Status Current Status OPSHD UIC N REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name T T Mud Log ~ 7,]./%.. Log Log Run Interval OH / Scale Media No Start Stop CH Received L DGR/CTN/SLD-MD ~25 L DGR/CTN/SLD-'I'VD ~ 25 L DSI- CASED ~ 5 L GRJCCL-TEM/PRE8a''~''~ 5 L Production Log c,,''''~'~ 12 L PACKER SETT~ 5 L RFT ~ O 6/22/2000 FINAL 2730 8522 OH 6/29/2000 FINAL 2610 8445 OH 6/29/2000 FINAL 25 8320 CH 6/22/2000 FINAL 7800 8200 CH 6/22/2000 FINAL 0 7894 OH 6/11/2001 FINAL 7800 8020 CH 6/22/2000 FINAL 8110 8145 OH 6/22/2000 O 6/29/2000 FINAL 600 8350 OH 6/22/2000 FINAL 5500 8287 CH 6/6/2000 FINAL 2730 8522 OH 6/29/2000 FINAL 2610 8445 OH 6/29/2000 O 6/22/2000 89 8522 OH 5/10/2000 L BEST DT DIP SL L USIT ~ 5 L DGR/EWR4-MD ~ 25 L DGR/EWR4-'I'VD ~ 25 ~ SRVY RP.T Directional Survey No -- (data taken from Logs Portion of Master Well Data Maint) Dataset Number Comments 09662 ~'""25-8320 BL, Sepia 09632 ~ 2646-8468 BL(C) BL(C) 09659 ~-~0-8360 SPERRY 2716.. Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Permit to Drill No. 2000560 MD 8522 TVD Well Cored? Y ~ _Chips Re~ed? . ¥/_hl.-- _ A n a lysi~Re~c~ e~?---~N DATA SUBMITTAL COMPLIANCE REPORT 5/20/2002 Well Name/No. SPARK lA Operator PHILLIPS ALASKA INC. 8445 Completion Date Completion Status Daily History Received? Formation Tops Receuived? Current Status 6N AP1 No. OPSHD 50-103-20313-01-00 UIC N Comments: Compliance Reviewed By: Date: MRY 13 '02 89:32RM ST-RI~ BMR WRTER State of Alaska Department of Natural Resource Division of Oil & Gas $50 West 7!h Avenue, Suite 800 Anchorage, AK 99501-3560 90? 269 8947 P.1 Number of p.ge. ln=luding =over .heel: ~' _ For Review r-I Plwa!e comment [~ aks You Itequwatmd [~ FYll C:'~Users~Kld~n~ Form,do; 09ti 7/01 , REOEIYED AJasJ(a Oil& Gas Cons. Cofllmiss~n MAY lB '02 09:3BAM ST-AY DMR WATER 907 269 8947 DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS TONY KNO 'WLE,$, GO VF, RNOI~ &gO WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALA~q KA el:)5 01~3S l O PHONE: (907) 269-8800 CERTIF~D MAlL ff7099 3220 0004 9021 6659 RETI. rRN RECEIPT REQUESTED May 10, 2002 Richard P, Mort Vice President Exploration and Land Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 DECISION OF THE DIRECTOR ~Request for Extension of Confidentiality under 11 AAC 83,153 Spark I APl #501032031300 Rendezvous 2 API #501032036300 Spark IA APl #501032031301 Lookout ! APl #501032035900" Rendezvous A API #$01032031600 Moose's Tooth C API #501032031500 k Clover A API #501032031000 ., I am responding to your March 22, 2002, letter requesting extended confidentiality under 11 A.AC 83.153 for well data, reports, and information generated from seven NPR-A wells, and. filed with the Alaska Oil and Gas Conservation Commission under AS 31.05.035, Based on your presentation to the Division on May 8, 2002, I extend the confidentiality tkne period for the data, reports, and information generated from four of the seven wells listed in Attachment A to your !otter. This extension is granted based on the significance of the well information to evaluation of unleased acreage which will be offered for sale by the Bureau of Land Management's NPR-A sub now scheduled for ~Iune 3, 2002. No future extensions will be granted for these wells, The information generated from the other three wells--Rendezvous 2, Lookout 1, and Moose's Tooth C--does not become public under AS 31.05,035 until the middle of next year, so I am not extending the confidentiality time period for that information at this time, This confidentiality extension for tl~e information from these four wells is through September 3, 2002, 90 days after the Bureau of Land Management's NPR-A lease sale scheduled for lune 3, 2002. "D,velop~ Conserve, and Enhance Natural Resources for Present and Future 0~: 34AM ST-.F)K DHR ~IATt~R ~07 ~6~ B~47 F', 3 By copy of this letter, I am notifying AOGCC of the extended confidentiality granted these wells. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040(c) and (d) and may be mailed or delivered to Pat Pourchot, Commissioner, Department of Natural Resources, 550 W. 7~ Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dm-. ap. pe~s @.dnr.state.ak.9s, This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 3 l~t day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before app.,almg this decision to Superior Court, A copy of 11 SC 02 may be obtained from any regional, in.formation office of the Department of Natural Resources. Mark D. Myers Director Daniel Seamount, Commissioner, A00CC Cammy Taylor, Commissioner, AOGCC Jeff Landry, Dept, of Law Don Bfizzolara, DO&G PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 TO: AOGCC 333 WEST7TH ANCHORAGE, AK. ATTN:BOBCRANDALL DATE: APRIL 12, 2002 AIRBILL: 5131166 AFT#: PBV02-04-11-01 CHARGE CODE:42374 OPERATOR: Phillips Alaska, Inc. SAMPLE TYPE: DRY NUMBER OF BOXES: 9 BUNDLES NAME: SAMPLES SENT: r;;L6O.. O.I,i'SPARK 1 2. t3~- O~"i~SPARK lA ),,.~ -~"'~ RENDEZVOUS A )...~31 - b(3'7 RENDEZVOUS 2 ONE COMPLETE SET OF DRY CUTTING AS RECEIVED FROM THE RIG '------[0'"!(o100'-8850' ~O~- 007 LOOKOUT 1 o,,..t~lt....-O~ff MOOSES TOOTH C ,2¢~-O~) HUNTER A 16"/, ? 3350'-8522' to,ct ~ 250'-8333' [. (:::,'.,t") ~ 200'-8651' 20'-8350' 16~ 170'-8738' .) 0 (~ i~ 100'-9600' ;),.~2- b~.~MITRE 1 ITRE PB1 ~ 80'-8090' 5870'-8240' ~,.~6 . b~,'7 CLOVER A [ b'? I 100'-8570' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: RECEIVED BY: D. GARRARD G. WILSON R. CRANDALL / ~" PAl # PAl AOGCC Phillips Alaska Inc. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: PHILLIPS Alaska, Inc. A Subsicliary of PHILLIPS PETROLEUM COMPANY EXPLORATION & LAND P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 PHONE (907) 2L~3-4556 FACSIMILE (907) 265-6339 Richard P. Mott Vice President March 22, 2002 Pat Pourchot, Commissioner State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 1400 Anchorage, AK 99501-3510 RECEIVED APR .5 2002 Re: Request for Extension of Confidentiality Alaska Statute 31.05.035 & Regulation 11 AAC 83.153 Phillips Alaska, Inc. ("PAI"), as operator for and on behalf of the working interest owners ("Lessees") of the wells listed in Attachment A hereto ("NPRA Wells"), hereby respectfully requests extended confidentiality for the reports and information generated from the NPR-A Wells and filed with the Alaska Oil and Gas Conservation Commission as required by state law ("Data"). All of the NPR-A Wells are located on federal lands located within the NPR-A. The Lessees make this request for the following reasons: (1) this Data is important to the Lessees in evaluating acreage in future federal oil and gas lease sales in the NPR-A; and (2) the Data for the NPR-A Wells is protected fi.om public disclosure under federal law and state law. First, the Data fi.om the NPR-A Wells contain significant proprietary and sensitive information relating to the valuation of unleased land within the NPR-A. Disclosing the Data to the public would cause financial harm to the Lessees because additional leasing of lands in the NPR-A will probably take place in the future. An EIS is currently underway for the planning of a federal oil and gas lease sale in the western NPR-A. Due to the remoteness of the lands that could be leased in the NPR-A and the restrictiveness of protections already in place for exploration and development of the leased lands within the NPR-A, disclosure of Data to the public about what the future potential for development for the currently leased lands, which Data was obtained at the sole risk and expense of the Lessees, would be detrimental to the Lessees' competitive position in NPR-A. Second, the Data is protected fi.om disclosure under federal law. Federal statute 5 USC 552(b)(9) exempts "geological or geophysical information and data, including maps, concerning wells" from the right of public inspection and disclosure provided in the Freedom of Information Act at 5 USC 552(a). The NPR-A lease terms under which Lessees leased the lands on which the Wells were drilled states as follows: During existence of this lease, information obtained under this section [section 5] shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 u.s.c. 552). Pat Pourchot, Commissioner State of Alaska, DNR March 22, 2002, Page 2 Paragraph 2, Section 5, NPR-A Lease Form, a copy of which is attached hereto as Attachment B. When a record is protected under federal law, it is also protected under Alaska law. Pursuant to AS 40.25.120(a)(4), a record required to be kept confidential by federal law or regulation is not available for public inspection. The focus of the provision for release of well data after two years under AS 31.05.035 appears to be data taken on state lands, not federal lands over which the Department of Natural Resources does not have jurisdiction. Because the Data is protected from disclosure by federal and state law, the commissioner should extend the confidential status of the Data. If you have any questions or require any additional information, please call me or Mr. Jim Winegamer at 265-6914 and we will arrange a meeting to review this request in more detail. Sincerely, Richard P. Mott Vice President Exploration and Land RPM:JPW Cc: U.S. Department of Interior Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 9950%2591 Attn: Peter Ditton, Field Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 tthorage, Alaska 99501 : Cammy Taylor, Chairman Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, AK 99503 Attn: John A. Bridges, Land Supervisor, Alaska State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 Attn: Mark Myers, Director Pat Pourchot, Commissioner State of Alaska. DNR March 22, 2002, Page 3 Attachment A Extended Confidentiality Requested for the following NPRA Wells Spark 1 Spark lA Rendezvous A API# 501032031300 API# 501032031301 API# 501032031600 05.13.02 Data Release Date 07.01.02 Data Release Date 06.03.02 Data Release Date Clover A APl # 501032031000 05.22.02 Data Release Date Rendezvous 2 API# 501032036300 05.30.03 Data Release Date Lookout 1 API# 501032035900 06.01.03 Data Release Date Moose's Tooth C API# 501032031500 07.01.03 Data Release Date PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 2, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval (APD 200-056) CONFIDENTIAL Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to temporary suspend the exploration well Spark lA. If you have any questions regarding this matter, please contact me or Tom Brassfield at 265-6377. Sincerely, P. Mazzol~l Drilling Team Leader PAI Drilling PM/skad RECEIVED 1. Type of request: Abandon _ Alter casing _ Repair well _ Change approved program _ STATE OF ALASKA i" ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend. Operational shutdowr Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM At top of productive interval 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM At effective depth At total depth 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM 5. Type of Well: Development _ Exploratory _X Stratigraphic __ Service __ (asp: 291158, 5939589) (asp: 291144, 5938892) (asp: 291144, 5938892) 6. Datum elevation (DF or KB feet) RKB 88 feet 7. Unit or Property name Exploration NPRA 8. Well number Spark #lA 9. Permit number / approval number 200-056 10. APl number 50-103-20313-01 11. Field / Pool Exploration 12. Present well condition summary Total depth: measured 8522 true vertical 8445 Effective depth: measured 8335 true vertical 8259 Casing Length Size Conductor 82' 16" Surface 2522' 7.625" Production 5013' 5.5" 3466' 5.5" Perforation depth: measured 8135' - 8150' true vertical 8059' - 8074' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) feet Plugs (measured) feet feet feet Cemented 135 sx AS I 305 sx Class G & 240 sx Class G 110 sx LiteCrete & 115 sx Class G 3.5", 9.3#/ft, L-80 @ 8050' MD Baker FB-1 packer @ 7848', No SSSV Measured Depth 115' 2610' 5046' 8512' True vertical Depth 115' 2610' 4978' 8435' RECEIVED APR 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _ 15. Status of well classification as: 14. Estimated date for commencing operation April 1,2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Suspended Service _ 17. I hereby certifv that the foregoing is true and correct to the best of my k. nowledge. Sig '' ' ~'¥"~'""' "¢/'- Title: Exploration Drilling Team Leader Paul Mazzolini FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance _ Mechanical Integrity Test_ ~1Slgrt~sequent___, form required 10.__ Approved by order of the Commission Commissioner Questions? Call Tom Brassfield 265-6377 pjeparedDb;t~haro'?~su~?r~ke~ I Approval Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 2, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for Spark #lA - Confidential Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the exploration well Spark #lA, Drilling Permit No. 200-56 as specified in 20 AAC 25.071. This report covers the recent operations to pull the gauges and suspend the well. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Exploration Drilling Team Leader PAI Drilling PM/skad RECEIVED STATE OF ALASKA l'"' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing __ 2. Name of Operator: Phillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: Stimulate__ Alter casing __ 5. Type of Well: Development _. Exploratory X. Stratagrapic ~ Service __= 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM (ASP: 291158, 5939589) At top of productive interval: 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65) At effective depth: At total depth: 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65) 12. Present well condition summary Plugging __ Perforate Repair well __ Other __X -~:-~1.~ --u,J 16. Datum of elavation (DF or Ku zeeL); 88' RKB 7. Unit or Property: Exploration NPRA 8. Well number: Spark #lA 9. Permit number/approval number: 200-056 10. APl number: 50-103-20313-01 11. Field/Pool: Exploration Total Depth: measured 8522' true vertical 8445' Plugs (measured) 2.313" XXN plug in XN nipple @ 8031' Effective Depth: measured 8335' true vertical 8259' Junk (measured) Casing Length Size Conductor 82' 16" Surface 2522' 7.625" Production 5013' 5.5" 3466' 5.5" Liner Cemented Measured depth 135 sx AS I 115' 305 sx Class G 2610' 240 sx Class G 110 sx LiteCrete & 5046' 115 sx Class G 8512' True vertical depth 115' 2610' 4978' 8435' Perforation Depth measured 8135'-8150' true vertical 8059'-8074' Tubing (size, grade, and measured depth) 3.5"@ 8050' Packers and SSSV (type and measured depth) Baker FB-1 Production packer @ 7848', No SSSV RECEIVED APR 4 2002 3. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A N/A Tubing Pressure 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations _~X Oil_ Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedd/~,,-~--'~~''~'')~J~'~'~'~'~'~''~' Title Ex Iorat,on Drllhn T ' '.~/_ ,~/ ' :p ' ' ' g eam Leader Form 1~a~;~a~e°/vin;6/15/~88 Suspended __X Service Questions? Call Tom Brassfield 265-6377 Date Prepared by Sharon A//sup-Drake SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (SPARK- lA (W4- 6 ) ) WELL JOB SCOPE JOB NUMBER SPARK-lA DRILLING SUPPORT-CAPITAL 0314021710.13 DATE DALLY WORK 03/15/02 PULL PLUG & EMR,S & SET PLUG DAY OPERATION COMPLETE I SUCCESSFUL I NO I NO Initial Tbg Press Final Tbg Press I Initial Inner Ann 0 PSI 1500 PSII 0 PSI DALLY SUMMARY KEY PERSON HES-WILBURN Final Inner Ann I 0 PSI I UNIT NUMBER 39O4 SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI REMOVED FMC BPV & VR PLUG. PULLED 2.313" XXN PLUG W/PANEX GAUGES FROM XN NIPPLE @ 8031' RKB. SET 2.313" XXN PLUG W/DEBRIS CATCHER (38-1/2") IN XN NIPPLE @ 8031' RKB. PRESSURE TESTED TBG TO 3000 PSI BLED BACK SLOWLY TO 2700 PSI. UNABLE TO BLEED DOWN COMPLETELY, APPEARS TO HAVE A GAS BUBBLE IN TBG. PT'D THE IA (3- 12/" X 5-1/2" ANNULUS) TO 2000 PSI HELD ROCK SOLID. WILL ATTEMPT TO BLEED GAS FROM TBG TOMMORROW & TROUBLESHOOT PLUG IF NECESSARY. JOB IN PROGRESS[Pressure Data, PT Tbg-Cs~l] TIME LOG ENTRY 00:00 *** NOTE HAD FMC OUT YESTERDAY AND PULLED BPV & VR PLUG FOR THE FOLLOWING S/LINE WORK TODAY. * .... 05:00 STAND-BY FOR FUEL TRUCK 06:30 08:30 DEPART ALPINE FOR REMOTE ICE PAD IN NPRA (SPARK-IA LOCATION) M/I R/U WlRELINE EQUIPMENT ADD 2 EXTRA SECTIONS OF LUBRICATOR TO COVER LENGTH OF GAUGE ASSEMBLY 10:30 RIH W/EQUALIZING PRONG TO 2.313" XXN PLUG @ 8014' WLM (8031' RKB). SAW NO PRESSURE CHANGE AT THE SURFACE. POOH ** NOTE THAT FLUID LEVEL APPEARED TO BE @ 120 .... 12:00 RIH W/2-1/2" GR PULLING TOOL. LATCHED 2.313" XXN PLUG @ 8014' WLM (8031' RKB)AND UNABLE TO PULL. POOH. 13:00 RIH W/MARK CHANEY SPECIAL EQUALIZING PRONG TO 8014' WLM (8031' RKB). KNOCKED EQUALIZING WATERMELON OFF SEAT, PER DESIGN. STILL NO APPARENT PRESSURE CHANGE AT THE SURFACE. POOH 14:00 14:30 RIH W/2-1/2" GR TO 8014' WLM (8031' RKB) AND LATCHED 2.313" XXN PLUG W/GAUGES AND PULLED. POOH. 2.313" XXN PLUG W/GAUGES AT SURFACE. EVERYTHING LOOKS GOOD BREAKDOWN GAUGES FOR TRANSPORT. 15:15 RIH W/2.313" XXN PLUG WITH 18" DEBRIS CATCHER (TOTAL LENGTH 38.5" ) TO 8014' WLM (8031' RKB). PERFECT SET. POOH. 15:50 ON SURFACE STAND-BY S/LINE WHILE PRESSURE TESTING. 16:00 PRESSURE TEST TO 3000 PSI, LOST 500 PSI IN 30 MINUTES. IA (3-12" X 5-1/2" ANNULUS) STAYED AT 0 PSI THROUGH OUT TEST. PUMPED 10 BBLS OF DIESEL. LOOKS LIKE WE HAVE A GAS BUBBLE IN THE Ti3G. BLED TBG BACK TO 1000 PSI. FLUID SUMMARY 6 BBLS DIESEL (TBG) 1/2 BBL DIESEL (IA) TIME 16:45 17:20 LOG ENTRY HOOKED PUMP UP TO IA (3-1/2" X 5-1/2" ANNULUS) AND PRESSURE TEST TO 2000 PSI. MONITORED FOR 30 MINUTES LOST ONLY 50 PSI. TBG PRESSURE REMAINED CONSTANT @ 1000 PSI. USED 1 BBLS OF DIESEL. BLED BACK TO 0 PSI (BLED BACK 1/2 BBLS OF DIESEL) BLED TBG BACK TO 500 PSI (BLED BACK FLUID ABOUT 1/2 THE AMOUNT WE PUMPED WITH SOME GAS). SHUT IN FOR 30 MINS AND ALLOW GAS TO COME TO SURFACE. 17:50 RESUMED BLEEDING TBG BLED BACK ALL DIESEL THAT WE PUMPED IN THE WELL AND THEN STARTED TO GET SOME GAS W/FLUID. 18:30 PUMPED 6 BBLS OF DIESEL BACK DOWN TBG WHTP 1500 PSI. STILL ACTS LIKE A GAS BUBBLE. DECIDED TO WAIT UNTIL MORNING TO BLEED TBG AGAIN, TO ALLOW GAS TO GET TO SURFACE. 19:30 RDFN S/LINE & LRS. WELL SECURED. 21:00 ROAD BACK TO ALPINE FOR THE EVENING. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 ( SPARK- lA (W4 - 6 ) ) WELL JOB SCOPE JOB NUMBER SPARK-lA DRILLING SUPPORT-CAPITAL 0314021710.13 DATE DAILY WORK UNIT NUMBER 03/16/02 PULL PLUG DAY OPERATION COMPLETE I SUCCESSFUL I NO I NO InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 1000 PSI 800 PSI 0 PSI DALLY SUMMARY KEY PERSON HES-WILBURN SUPERVISOR CHANEY Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSi UN-SUCCESSFUL IN BLEEDING DOWN TBG. FOUND PLUG TO BE LEAKING. PULLED 2.313" XXN PLUG FROM XN NIPPLE @ 8031'. FREEZE PROTECTED TBG DOWN TO 2100' W/DIESEL. WILL COME BACK TO RE-SET PLUG AND PUMP KILL WEIGHT FLUID AT A LATER DATE. JOB IN PROGRESS.[PT Tbg-Csg] TIME LOG ENTRY 06:00 TRAVEL TO SPARK-lA FROM ALPINE 07:30 ARRIVE LOCATION CK LOC. R/U BLEED TANK TO WELL 08:30 BLED GAS UNTIL FLUID HIT SURFACE. APPEARS PLUG IS LEAKING. CAN NOT BLEED THE WELL DOWN. 09:30 NO SUCCESS W/BLEEDING OFF THE TBG. 10:45 PRESSURED WHTP BACK UP WITH PUMP AND STILL HAS A SLOW LEAK. PRESSURED UP TO 3000 PSI AND IN 30 MINUTES IT DROPPED BACK TO 2000 PSI. IN ONE HOUR IT DROPPED BACK TO 1750 PSI. DECIDED TO PULL PLUG. TALKED WITH TOWN AND WILL COME BACK WITH KILL WEIGHT FLUID BEFORE ATTEMPING RE- SET OF THE PLUG. 11:00 S/LINE POWER PACK BROKE DOWN. STAND-BY FOR REPAIRS. 13:00 S/LINE UNIT REPAIRED, RU TO PULL PLUG. 13:30 RIH W/2-1/2" GR & EQUALIZING PRONG TO XN NIPPLE @ 8014' WLM (8031' RKB) RAISED THE WHTP TO 2500 PSI LATCHED 2.313" XXN PLUG AND SHEARED OFF. THE WHTP DROPPING SLOWLY. POOH. 14:15 WHTP HAD DROPPED DOWN TO 1750 PSI. RIH W/2-1/2" GR & EQUALIZING PRONG TO XN NIPPLE @ 8014' WLM (8031' RKB). LATCHED 2.313" XXN PLUG AND SHEARED OFF. THE WHTP STILL DROPPING SLOWLY. POOH. 14:55 RIH W/EQUALIZING PRONG ONLY. NO BIG CHANGE IN WHTP. POOH 15:45 RIH W/2-1/2" GS PULLING TOOL TO XN NIPPLE @ 8014' WLM (8031' RKB). LATCHED 2.313" XXN PLUG AND PULLED SAME. POOH 16:15 ON SURFACE WITH PLUG. APPEARS EQUALIZING DEVICE O-RINGS WERE DAMAGED. 16:15 FREEZE PROTECTED TBG DOWN TO 2100' WITH 18 BBLS OF DIESEL. 17:30 RDMO S/LINE & LRS PUMP TRUCK. 18:00 WELL SECURED AND LEAVING LOCATION. 20:00 ROAD EQUIPMENT BACK TO ALPINE. FLUID SUMMARY 12o BBLS DIESEL (TBG) I PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (SPARK-IA (W4- 6) ) WELL JOB SCOPE JOB NUMBER SPARK-lA DRILLING SUPPORT-CAPITAL 0314021710.13 DATE DALLY WORK UNIT NUMBER 03/20/02 DISPLACE TBG W/KILL WEIGHT FLUID & SET PLUG 3904 DAY 2 OPERATION COMPLETE I SUCCESSFUL NOI YES Initial Tbg Press 1700 PSI DALLY SUMMARY KEY PERSON HES-WILBURN Final Tbg Press I Initial Inner Ann 0 PSII 0 PSI SUPERVISOR CHANEY Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSII 0 PSI 0 PSi DISPLACED TBG W/KILL WEIGHT FLUID ( 55 BBLS OF 10.2# BRINE & 17.5 BBLS OF DIESEL FOR A CAP DOWN TO 2000'). SET 2.313" XXN PLUG (38-1/2") IN XN NIPPLE @ 8031' RKB. PRESSURE TESTED PLUG TO 3000 PSI AND HELD FOR 30 MINUTES. DE-PRESSURED TBG TO 0 PSI. INSURED IA WAS DE-PRESSURED TO 0 PSI. READY FOR BPV & VR PLUGS.[PT Tbg-Cs~l] TIME LOG ENTRY 07:00 ROAD S/LINE UNT FROM ALPINE TO SPARK-lA 08:30 ROAD LRS HOT OILTRUCK FROM KUPARUK TO SPARK -lA 09:00 S/LINE ARRIVED ON LOCATION AND BEGIN RU 09:30 APC BRINE TRUCK ON LOCATION. 11:30 LRS HOT OIL UNIT ON LOCATION AND BEGIN RU. 12:20 PUMP 20 BBLS OF DIESEL @ 2 BPM. FOR A SWEEP. 12:30 PUMP 55 BBLS OF 10.2# BRINE @ 2 BPM. 12:50 PUMP 17.5 BBLS OF DIESEL (FREEZE PROTECT) @ 2 BPM. SHUT DOWN PUMP AND WELL IS DEAD 0 PSI ON TBG. 13:00 RIH W/2.313" XXN PLUG W/18" DEBRIS & STANDARD EQUALIZING HOLES (TOTAL LENGTH 38-1/2")TO 8014' WLM (8031' RKB) & SET PLUG IN XN NIPPLE. POOH 13:45 ON SURFACE RUNNING TOOL INDICATES GOOD SET. 13:50 PRESSURE TEST TBG TO 3000 PSI AND HELD. IA REMAINED AT 0 PSI DURING TBG 14:30 DE-PRESSURED TBG TO 0 PSI, NOTE THAT THERE IS FLUID TO SURFACE ON BOTH THE TBG & IA. NOTE THAT IA WAS PRESSURE TESTED ON WSR DATED 03/15/02 15:00 RDMO LRS HOT OIL TRUCK. 15:30 RDMO S/LINE UNIT 16:30 WELL SECURED AND ALL PERSONNEL LEAVE LOCATION. FLUID SUMMARY 37.5 BBLS DIESEL (TBG) 55 BBLS DIESEL (TBG) PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (SPARK-IA (W~-6) ) WELL JOB SCOPE JOB NUMBER SPARK-lA DRILLING SUPPORT-CAPITAL 0314021710.13 UNIT NUMBER DATE DALLY WORK 03/21/02 INSTALL BPV & VR PLUGS DAY OPERATION COMPLETE I SUCCESSFUL 3 YES I YES InitialTbgPress IFinalTbgPress [InitiallnnerAnn 0 PSI 0 PSI 0 PSI DAILY SUMMARY KEY PERSON Final Inner Ann I I 0 PSI SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI I INSTALLED FMC BPV & VR PLUGS IN WELLHEAD. ALL VALVES CLOSED AND HANDLES REMOVED. RE-HUNG WELL ID SIGN ON THE WELLHEAD. TIME LOG ENTRY 12:00 MIRU APC BOOM TRUCK. 13:00 FMC ARRIVED ON LOCATION. 14:00 INSTALL FMC BPV IN HANGER 14:30 INSTALLED VR PLUGS IN ANNULI 15:00 CLOSED ALL VALVES AND REMOVED VALVE HANDLES. NOTE: THAT THE VALVE HANDLES WILL BE STORED AT THE KUPARUK DRILLING TOOL HOUSE. 15:30 WELL SECURED LEAVE LOCATION. 15:30 RE-HUNG WELL ID SIGN 16:00 CALL FOR SCAFFOLD REMOVAL AND MOBILE EQUIPMENT TO BE HAULED OFF. NOTIFIED RICK OVERSTREET OF WELL & LOCATION STATUS. ALASKA OIL AND GAS CONSERYA~I~ION COHHISSION Greg Wilson NPR-A Contact for Geologic Data Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 April 4, 2002 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Wilson: As operator of the following wells, Phillips Alaska, Inc. ("Phillips") is required to provide the Alaska Oil and Gas Conservation Commission ("AOGCC") with certain data within 30 days after completion, suspension, or abandonment of a well.. A review of AOGCC records indicates that Phillips has failed to provide the AOGCC with samples of drill cuttings as required by 20 AAC 25.071(b)(2) for the following wells: Spark 1 Spark 1-A Rendezvous A Lookout 1 Rendezvous 2 PTD# 200-034 PTD# 201-003 PTD# 201-007. Please' " ensure that Phillips brings itself immediately into compliance with .20 AAC 25.071(b)(2). Please contact me at 793-1230 if you have any questions. Sr. Petroleum Geologist RC:jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O.Taylor,~ ~~' DATE: Chair Tom Maunder, P.I. Supervisor THRU: August 12, 2001 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector Location Inspection Arco Spark #lA Phillips Alaska Inc. ~p.[operty) Sunday, Auqust 12,.2001; i made a Location Inspection on Phillip's Suspended well "Arco Spark #lA". This exploratory location was clean with no evidence of drilling activity other than the suspended tree. The well sign had the proper information bead-welded to it but was attached loosely to the wellhead with mechanic's wire. I recommended to Rick Overstreet (P.P.Co. rep.) that this sign should be bolted to the wellhead. SUMMARY: ! made a Location Inspection on Phillip's Suspended Exploratory well "Arco Spark #lA'. Attach,m. ents:, Arco Spark #lA Tree 8-12-01 LG.jpg Arco Spark #lA Airshot 8-12-01 LG.jpg cc: Overstreet/Morrison (Phillip's Alaska Inc.) NON-CONFIDENTIAL Location Inspection Arco Spark tA 8-t2-01 LG.doc PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 5, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 RECEIVED JUL 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for Spark #lA - Confidential Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the exploration well Spark #1 A, Drilling Permit No. 200-56 / 300-097 as specified in 20 AAC 25.071. This report covers the recent coiled tubing operations to frac the well and temporarily abandon the well. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. If you have any questions regarding this matter, please contact me at 263-4603 or William Lloyd at 265-6531. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PAI Drilling PAM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator: Phillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: Operation Shutdown _)~ Stimulate____ Pull tubing _ Alter casing _ 5. Type of Well: Development ~ Exploratory X, Stratagrapic ~ Service __~ Plugging _ Perforate _ Repair well _ Other _ 6. Datum of elavation (DF or KB feet): 88' RKE ... 7. Unit or Property: Exploration NPRA 8. Well number: 1608' FNL 2497' FWL Sec. 8, T10N, R2E, UM (ASP: 291158, 5939589 At top of productive interval: 2306' FNL, 2502' FWL Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65 At effective depth: At total depth: 2306' FNL 2502' FWL Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65 12. Present well condition summary Spark #lA 9. Permit number/approval number: 200-056 / 301-097 10. APl number: 50-103-20313-01 11. Field/Pool: Exploration / Total Depth: measured 8522' Plugs (measured) true vertical 8445' Effective Deptl measured 8335' Junk(measured) true vertical 8259' Casing Length Size Cemented Conductor 82' 16" 135 sx AS I Surface 2522' 7.625" 305 sx Class G 240 sx Class G Production 5013' 5.5" 110 sx LiteCrete & 3466' 5.5" 115 sx Class G Liner Measured depth 115' 2610' 5046' 8512' True vertical depth 115' 2610' 4978' 8435' Perforation Depth measured 8135'-8150 true vertical 8059'-8074 Tubing (size, grade, and measured depth) 3.5"@ 8050' Packers and SSSV (type and measured depth) Baker FB-1 Production packer @ 7848', No SSS¥ JUL 0 6 001 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured; 8135'-8150' ME Treatment description including volumes used and final pressure 122,000#, 16/20 Carbo-Lite 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surve~zs run _ Daily Report of .Well O. p, et/?F~ns _~ 17. I hereb, Y cerJ~ Signe?.: ,."';:~' Form 10-404 Re~/O6/l'~g~Sx.x~ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure No production - 1707 BOPD 17420 MCFD 103 BWPD 1900 Tubing Pressure 2500-1500 psi 16. Status of well classification as: Oil _ Gas _ Suspended Service is true and correct to the best of my knowledge. Title: ~/L Date SUBMIT IN DUPLICA~ PHILLIPS Alaska, Inc. A SubsidlaW of PHIl. UPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA * FROM: Sandra D. Lemke, AT01486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Spark lA DATE: 06/08/2001 Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following; _Sj~ark IA 501032031301 permit 200-056 Log data fi/~)g and i bluel/ne print each ~' .Schlumberger - Production Log with Oilphase sampler 3-29-2001 Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Spark lA Well, Drilling Permit No. 200-056 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue." CC: Greg Wilson, PA:]: Geologist Return receipt to: Phillips Alaska, Inc. AI'rN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska 1T Technical Databases RECEIVED JUN 1 1 2001 Ala~a Oil & Gas Cons. Commmen SENT BY:ARCO ALASKA INC · 4-12- 1 ' 4: 56PM ;PRB RESOURCE DEVELOP~ ~07 276 7542'# 2/ 5 PHILLIPS Alaska, Inc. A ~ub$l,"Jiory of PHIl IIPS PETROLEUM COMPANY P, O, BOX 100360 ANCHOF'IAG.F.. ALASKA 99510-0300 April 12, 2001 Daniel .3. Seamount, Jr,, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite _100 Anchorage, AK 99501 Application for Sundry Approval; Spark #lA Surface Location: 1608' FNL, 2497' FWL, Sec. 8, T10N-R2E Target Location; 2180' FNL, 2432' FWL, Sec. 8, T10N-R2E Bottom Hole Location; 2180' FNL, 2432' FWL, Sec, 8, T9N-R2E Dear Commissioner Seamount, PHILLIPS Alaska, Inc. hereby submits an Application for Sundry Approval to tempor_.arlly sus_.p_end the referenced well, located in the National Petroleum Reserve - Alaska. The welt was. originally drilled. cased, and suspended on May 5, 2000 as part of the 1999/2000 Exploration program, and subsequently production tested in March and April of 2001. Included with the Application for Sundry Approval Is a program outline and wellbore schematic indicating the proposed well work and the current completion string. The well will be suspended with bottom hole pressure bombs located in the tailpipe below the packer in order to monitor possible reservoir connectivity between this well and Rendezvous A. It is currently planned to retrieve the pressure bombs during the 2001/2002 winter exploration operations. The following are PHILLIP's designated contacts for reporting responsibilities to the Commission: Completion Report (20 AAC 25,070) Sharon AIIsup-Drake, Drilling Technologist , 263-46_12 ~[f you have any questions or require further information, please contact Bill Lloyd at (907) 265-65;31 or Paul Mazzolini at (907) 263-4603 William B...LloyU'~. [ L'~ Senior Drilling engir~r CC: CONFIDENTIAL - SPARK lA Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECEIVED APR 1 3 2001 Annhnr,,C, SENT BY:ARCO ALASKA INC ; 4-12- 1 ' 4:56PM ;PRB RESOURCE DEVELOP~. 907 276 7842'# 8/ 5 . · ~, .-~ ,. , ~ -- . ,-~ , .. ALASK~ OIL AND ~AS ~NSE~VATION GOM~ISSlON APPLICATION FOR SUNDRY APPROVALS ..... ~1. Type of request:· ^band;~ _ " ~uspen.~'~:-~.,i. ~ Operational sh~icJow~/~: ,., i i..;. R~-enter ~'~)ended well_ Othe~' Al~r c~tng _ R~al~wdl _ ~'-~'~l Plu~ _ ~' ~me exiensbn _ ~lmu~te_ C~an~ Hole/ Chan~ approved pm~ _ Pull tubing Variance Pe~omte _ _~.~ng Si~(s) 2. Name of O~ra~r ' ~. T~e of Well: 6, Da~m elewtlon (DF or KB test) Phillip,[ Alaska Inc ~l~t_ RK,[ ~8 feet 3. Address E~lemto~ _x 7, Unit or Proper~ name P. O. Box 100360 ~ A~homge,~K 99510-0360 sew~_ . ...... ~xploration N PRA 4. Location of Well at e~rf~e ........ 8, Well number 1608' FNL, 2497' ~L, Sec. 8, T10N, R2E, UM Spark ~IA At ~p of productive interval 9. Permit n~'~b~r / approval numbe~ ........ ' .... 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM 200-056 At eff~ve depth ~ ~API number 50-103-20313-01 At to~l depth 11. Field/-~1 ...... 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM ........... ......... Exploration 12. Present well '~-ndi~on summa~ To~l depth: measured f~t Plugs (measUre) ~ue ver~cN feet Effe~t~e depth; measU[~ ~ t~t. Junk (m~aured) true ver~l C~ing Length Size Cement~ Measured D~th True v~loal Depth Condu~or Pt~uollon . , See A~ached Program and Wellborn Schematic RECEIVED Perfora~on ~epth; measured 8135' - Bt~ APR 1 3 2001 ~u. ver~a~ AI~ 0il & Gas ~s. Anchorage Tubing (size, grade, and measured ~pth 3.S' ~.3~ L-80 ~ 8031' MD ~Pae~rs & SSSV (~pe & measured dep~) FB-1 ~ l~'~chments bes~ri~on summa~ of propo~ ...... D~{~'~;d operations pr~ram __ ' ...... BOP Ref? lo a~h,e_~ ~.~?ng drilling raped for LOT test, surface cement de,ils and ~slng d~?~s~eet~r s,chemetl¢ ~7~'Sti~t~d date tot Commencing operation 1'~.' Status oi well April 14, 2001 ,, ' *' ' ,i ~ ~ ~ ~ ~"6,-i~"propo~~~ ~pprgved --~ ~ 011~ Gas__ Suspen~ N~O 17, I ~et~ ce~lfy that the/o~lng Is I~e a~d corr~ to the best ~ ~ ~owledge, OUeSflOtlS7 Call WllSa~ $lgned~ ~~ Title: Drllll,g Team ~ade, D~, Paul M~zot~I WBL .................... FqR,,~g, MB~Ssld~' USE ONE'? Conditions of approval; No~ Co~mission so rep~'senb~ve may wl~ess ......... [ ApproV~!~. D Taylor Se~~, SENT BY'ARCO ALASKA INC ' 4-12- 1 ; 4' 57PM ;PRB RESOURCE DEVELOP* 807 '276 755542;# 4/ .5 WELL INFORMATION: SPARK $$1A Well Suspension Plan SPARK #lA 1608' FNL, 2497' FWL, Sec 8, T10N-R2E (Surface) 2180' FNL, 2432' FEL, Sec 8, T10N-R2E (TD) APl No. 50-103-20313-01 . On March 13, 2001, testing and stimulation operations commenced on the referenced well and were completed on April 4, 2001. Following cor~Pietib.~!iblSeatibns oii thist well, ~qi~.;ment was moved to Rendezvous A for production testing at that location, As a function of th'~""{i6Wtest on Rendezvous A and in order to determine reservoir connectivity between wells, Phillips. Alaska Inc, hereby requests to temporarily suspend Spark #lA with bottomhole pressure gauges in place, and return next winter to retrieve the gauges. The following outlines the proposed procedure for this program: 1. MIRU slickline unit, NU slick line lubricator on tree and RIH with 2 Panex Bottom hole Pressure gauges on a 2.31 XXN plug w/full extension and bomb hanger. Hang off bombs in XN nipple @ 8031' MD '"~ T~', ~, \ ~ c,, c.-~,~',Xe,', ~,,¢.),~\ ~, ~x,,c.~ ~- l ~,\,o ~..° 2. Pull GLM from nipple @ 7850' MD (above packer). Circulate 9.9 ppg brine (kill weight) down tubing casing annulus and up tubing until tubing string is loaded with brine (tubing capacity above GLM is 68.3 bbls). Once brine returns are achieved, freeze protect well to 1500' by pumping 36 bbls 0t diesel down tubing/c~tsing unnulus then equalize with tubing, 4. ,Set BPV in tree. Close all valves and remove handles. [3_~..~.,.~.~ ~.,~, ~ V~<~ '~\~ ~-~-- , 5. Clean-up cellar and loCation to prepare for inspections, and Summer Operations ~c3 "~,.~..~.-~e.." -~-¥' [: Shutdown. 6~ Hang sign on tree with the following information: . Spark #lA PTD # 20o-056 APl # 50-103-20313-01 SHL: 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM SENT BY:ARCO ALASKA INC ' 4-12- 1 ' 4' 57PM ;PRB RESOURCE DEVELOP+ 907 276 7542;# 5/ 5 laNiLLIla$ Alaska, Inc. Planned Suspension 16" Conductor i" 9-718" Hole . 7-5/8",29.7#, L-80, DTC Mod, R3 Surface Casing @2610' MD-RKB TO_C.,12 ppg ~ ~ 6_050' MD Base Permafrost - 600' MD ~ Diesel from 1500' to surface ~ SS @ 2725' Kill weight brin__e ~ from 7850' to dies~! RECEIVED APR 1 3 2001 Nasl(a 011 & Gatt ~Ol~. ~ntt~ Anchorage TOG 15;8 ppg ~ 7200' MD II ~ GLM @ 7850' 6-3/4" Hole GLMs @ 8008'& ~ 7980', ~ XN @ 8031' 5-1/2", 15.5#, L-80, ,BTC..,Mod, R3 Production Casin¢l @ 8512' MD-RKB Perforations: 8135' - 8150' MD 3/18/01: DAILY SUM~R~ OPERATIONS SUMMARY (' SPARK #lA FRAC TREATMENT / TEMPORARY ABANDONMENT PUMP BREAKDOWN STAGE AT 25 BPM - PERFS BROKE DOWN AT 7300 PSI - PRESSURE DOWN TO 3450 PSi WITH WATER ON PERFS -ISlP=1185 PSI - FG=0.59- ATTEMPT SCOUR STAGE - GEL TOO HEAVY- PUMP 2ND SCOUR STAGE WITH 2125 LBS 16/20 CARBOLITE AT 1 PPA- ISlP=1600 PSI - FG=0.62 - PUMP DATA FRAC - HAD TROUBLE WITH STIMPLAN DURING ANALYSIS - CLOSURE TIME IS LONGER THAN DESIGN - DECIDE TO PUMP DESIGNED PAD OF 275 BBLS DUE TO ODD PRESSURE RESPONSE DURING SCOUR STAGES- PUMP FRAC- ADDED 12 PPA STAGE- DID NOT SCREENOUT- PLACED A TOTAL OF 121408 LBS 16/20 CARBOUTE BEHIND PiPE (INCLUDING SCOUR STAGE VOLUME)- LEFT 2736 LBS PROPPANT IN TUBING - RECOVERED ALL TREESAVER RUBBERS[Frac-Refrac] 4/]5/901 Set duel panex EMR's w/shock absorber & bow spring cent. on 2.313 XXN plug w/debris catcher at 8027' WLM. Pull 1' DGLV at 7847' WLM. Circ brine & diesel. Set 1' DGLV & PT - all tests good. Phillips Alaska, Inc. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 29, 2000 Daniel ]. Seamount, Ir., Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Sundry Approval: Spark #:LA Surface Location: 1608' FNL, 2497' FWL, Sec. 8, T10N-R2E Target Location: 2180' FNL, 2432' FWL, Sec. 8, T10N-R2E Bottom Hole Location: 2180' FNL, 2432' FWL, Sec. 8, T9N-R2E Dear Commissioner Seamount, PHILLIPS Alaska, Inc. hereby submits an Application for Sundry Approval to complete and test the referenced well, located in the National Petroleum Reserve - Alaska. The well was originally drilled. Cased, and suspended on May 5, 2000 as part of the 1999/2000 Exploration program. Included with the Application for Sundry Approval is a program outline and wellbore schematic indicating the proposed well work and the current and completion string. The well will be perforated, frac stimulated and tested with the existing completion string in place. Anticipated start date of operations is dependent upon approval of tundra opening and construction of the required ice road and ice pad and at this point, is approximated at December 20, 2000. The duration of the work is estmimated at 14 days. The following are PHILLIP's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 If you have any questions or require further information, please contact Bill Lloyd at (907) 265-6531 or Paul Mazzolini at (907) 263-4603 Sincerely, William B.._Lloyd Senior Drilling Engin~r CC: CONF]:DENT[AL - SPARK lA Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECEIVED Nov ooo Alaska Oil & Gas Cons. Co~missio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _X TEST 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM At top of productive interval 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM At effective depth At total depth 2180' FNL, 2432' FEL, Sec. 8, T1 ON, R2E, UM 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 33 feet 7. unit or Property name Exploration 8. Well number ARCO Spark #lA 9. Permit number / approval number 200-056 / 300-115 10. APl number 50-103-20313-01 11. Field / Pool Exploration 12. Present well condition summary Total depth: measured 8522 true vertical 8445 Effective depth: measured 8522 true vertical 8445 Casing Length Size Conductor 80' 16" Surface 2577' 7.625" Production 8479' 5.5" feet Plugs (measured) feet feet feet Cemented 135 sx AS I 305 sx Class G & 240 sx Class G 109.8 sx LiteCrete & 115 sx Class cement plug #1' 7640'-6940' cement plug #2: 4500'-4000' cement plug #3: 2900'-2500' Measured Depth True vertical Depth 80' 80' 2610' 2521' 8512' 8440' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth 3.5" x 2-7/8", 9.3# & 6.4#, 7956' / 8045' Packers & SSSV (type & measured depth) Baker FB-1 packer @ 7944', No SSSV RECEIVED I 0V 29 000 Alaska 0il & (;as Cons. Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program N BOP sketch __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 15. Status of well classification as: 14. Estimated date for commencing operation December 12, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Service __ Gas__ Suspended_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~-'~Z.~ ~/~~~-~--' Title: Exploration Drilling Team Leader Paul Mazzo/ini FOR COMMISSION USE ONLY Questions? Call William Lloyd265-6531 Date I~I~//Z°C:)O Prepared by Sharon Al/sup-Drake Conditions of approval: Notify Commission so representatjve may witness I ~no. Plug integrity __ BOP Test ~, Location clearance _ -- Mechanical Integrity Test_ Subsequent form required 10- [-~i~,.~ ~. ~t~..~.,,.~' C..~'¥,,3~-~ ORIGINAL SIGNED BY _ Approved by order of the Commission ~1 M, Heusser Commissioner Date Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLI CATE WELL INFORMATION: SPARK #lA 1608' FNL, 2497' FWL, Sec 8, T10N-R2E (Surface) 2180' FNL, 2432' FEL, Sec 8, T10N-R2E (TD) APl No. 50-103-20313-01 OVERVIEW On May 5, 2000, operations on the referenced well were temporarily suspended as a result of the terminus of the winter exploration season. This suspension was in accordance with the Application for Sundry Approval, Form 10-403, as approved on April 28, 2000. The well was suspended with a plug in the XN nipple at 8031' MD, 9.8 ppg brine from the packer at 7944' MD to 2000' MD, and a diesel cap from 2000' MD to surface. All fluids were left both inside the 3.5" tubing and in the 3.5" x 5.5" annulus. A dummy valve was set in the GLM at 7852' MD, and a BPV was set in the 3.5" tree. All flanges were blinded, the master and wing valves secured and handles removed and stored in KRU. The purpose of this Application for Sundry Approval, is to commence testing of the referenced well during the upcoming winter exploration season. The following outlines the proposed procedure for this program: 1) RU and secure hardline and surface testing equipment to well to PAl and regulatory requirements. 2) Install handles, open master valve. Pull BPV and dummy valve. Circulate out remaining brine above packer with diesel. 3) Pull plug from XN nipple. LD plug and RIH with sinker bars to tag bottom. 4) RU and frac stimulate existing perforations. 5) RU CTU and perform clean out below perfs. 6) Run gas lift valves as needed. 7) Open well to surface testing equipment; use nitrogen for additional kick-off support, if needed. 8) Flow well to clean up. Upon reaching stabilized conditions, flow test well for additional 2-4 days as necessary. 9) Perform pressure build-up test(s) as necessary. 10) Rig down test equipment and secure well. A separate sundry as well as a completion report will be submitted at the conclusion of the test for appropriate follow-up well work. RECEIVED NOV 29 2000 Alaska Oil & Gas Cons. Commission Anchorage ARCO Spark #lA Current Conditions PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 7-5/8'~0, ~ BTC Mod, R3 Surface Casin,q @2610' MD-RKB Base Permafrost ~ 600' MD Diesel from 2000' to surface ~ SS @ 2725' TOC 12 pp.q -,-~,.. 6O50' MD Kill weiqht brine (>9.6) from 7850' to diesel cap TOC 15.8 pp.q -~- 7200' MD -~- GLM @ 785O' 6-3/4" Hole GLMs @ 8008'& 7980' 5-1/2", 15.5#, L-80, BTC Mod, R3 Production Casing @ 8512' MD-RKB -~- XN @ 8031' RECEIVED NOV 29 2000 Alaska 0ii & Gas Cons. Commission Anchorage Notes to File 200-056 Correction to Weekly Report of June 9, 2000 On June 2, 2000, AOGCC received a 10-407 form with attachments for the ARCO Spark # lA well. On this form, the status of the well was marked as "Suspended." While reading through to assign a completion date, I noted that the well has a tree, casing, tubing and perforations, but no plugs. The well had not been properly plugged to be considered suspended, rather it seemed to have been completed. I noted this and spoke with Blair about status of the well and the apparent completion date of 4/29. My work log notes are below: June 6, 2000 09:35 "Review for completion dates: Spark #1 and #lA. Spark #1 lost deep section of hole. Cement plugs across uphole sections on 4-12-00 with intent to sidetrack. Speak with BW about downhole equiopment and completion date for Spark # lA. Completed on 4/29 with perfs, tubing, and tree, so capable of production/injection. Left junk in hole, which was fished out on 5/08. Junk is minor aside, well was capable of production / injection on 4/29.." On June 23, 2000, AOGCC received a letter from Phillips Alaska Inc. (formerly ARCO) which contained a letter and a 10-404 form for the Spark # lA. well. The letter requested that the commission disregard the completion report (form 10-407) sent earlier in June, and to utilize the attachments from the 10-407 and append them to the 10-404 form. A search of the well file for Spark #lA (200-056) turned up an email from Tom Brassfield to Blair Wondzell dated 21 April 2000 notifying the commission of the likelihood of an operational shutdown, and a 10- 403 form requesting an operational shutdown that was received on May 3, 2000, approved on May 9, 2000, and returned on May 10, 2000. Because the 10-407 was in error, and because an operational shutdown was requested in advance, the completion date of 4/29/2000 that I assigned is invalid. A correction stating the well is in operational shutdown will be placed in the weekly report dated June 30, 2000. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, ~ q~L) DATE: August 3, 2000 Chairman Z~ THRU: Blair Wondzell, ~ P. I. Supervisor ~(~ FROM: Lou Grimad~, I~c, F~- SUBJECT: Petroleum Inspector Location Inspection Suspended Well Spark 1/Spark lA PTD #200-034 (1) PTD #200-056 (lA) Wednesday, August 2,. 2000; I made a Location Inspection on the suspended · exploratory well Spark 1 / lA. I was accompanied today by Lee Gooding (Phillips environmental tech) and Rick Overstreet (Phillips KRU drilling superintendent). We flew to the location by helicopter and verified proper location by G.P.S. coordinates. Spark 1 was drilled and suspended this last winter exploratory season. It is planned to production test this well next winter. Other than the test tree and guardrail around it, there were no indications of any drilling activity on this location. We flew the ice road path this was clean and seemed well vegetated. The following is bead-welded on a marker plate bolted to the test tree; PHILLIPS ALASKA INC, ARCO SPARK #lA PTD #200-056 APl 350-103-20313-01 SHL: 1608' FNL, 2497 FWL SEC 8, T10N, R2E UM SUMMARY: I made a Location inspection on Suspended well Spark lA. No problems were observed. Attachments: Loc Insp Spark lA 8-2-00 LG.xIs Digital Photographs (2); Spark tree.jpg Spark airshot.jpg "As Built" for location cc: Phillip's Petroleum Co: Loc Insp Spark 1 8-2-00 LG.doc Subject: Weekly Report Correction Text for Spark lA Well Date: Mon, 10 Jul 2000 12:32:13 -0800 From: Steve Davies <steve_davies~admin.state.ak.us> To: Steve McMains <steve_mcmains~admin.state.ak.us> CC: Camille Oechsli <cammy_oechsli@admin.state.ak.us>, Daniel Seamount <dan_seamount~admin.state.ak.us>, Robert P Crandall <bob_crandall~admin.state.ak.us> Steve: Please print the following correction for the Spark #lA well in this week's edition of the Alaska Drilling Statistics report. ~Correction to the Alaska Drilling Statistics for Week Ending 06/09/2000: the completion date of 04/29/2000 reported for the Spark #lA well, Permit Number 200-056, was in error. This well is not completed." Thanks, Steve Davies TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lernke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 AOGCC ATTN: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 DATE: 06/27/2000 Transmitted here3~th is the following: ,, , , ,, Spark 1A(501032031301) &t. qte'~ Sperry Sun CD ROM: MWD; log date 4/22/2000; 2646-8468'md + Sperry LIS Verification list 1 reproducible and 1 blueline print each: Sperry Sun EWR/DGR/ROP (MD) 4/23/2000; 2730-8522'md 2&5" Sperry Sun EWR/DGR/(TVD) 4/23/2000; 2730-8522'md 2&5" Sperry Sun DGR/CTN/SLD (MD) 4/23/2000; 2730-8522'md 2&5" Sperry Sun DGR/CTN/SLD (TVD) 4/23/2000; 2730-8522'md 2&5" All NPRA data is to be held strictly confidential CC: Mark McDermott Approved for transmittal by: Greg Wilson Receipt: Return receipt to: Phillips Alaska, Inc. ATTN: $. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 Date: Alaska 0ii & Gas Cons. Commission Prepared by: S~l~i~ri~.eLemke Phillips Alaska IT Geoscience Group STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator: Phillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: Operation Shutdown ? Stimulate__ Pull tubing _ Alter casing _ 5. Type of Well: Development ~ Exploratory X. Stratagrapic __, Service ~ 1608' FNL, 2497' FWL, Sec. 8, T10N, R2F, UM (ASP: 291158, 5939589 At top of productive interval: 2306' FNL 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65 At effective depth: At total depth: 2306' FNL 2502' FWL, Sec. 8, T10N, R2E, UM ('ASP: 291144, 5938891.65 12. Present well condition summary Plugging _ Perforate _ Repair well_ Other_ 6. Datum of elavation (DF or KB feet): 33' RKI: 7. Unit or Property: Exploration 8. Well number: ARCO Spark #lA 9. Permit number/approval number: 200-056 / 300-115 10. APl number: 50-103-20313-01 11. Field/Pool: Exploration / Total Depth: measured 8522' Plugs (measured) true vertical 8445' Effective Deptt measured 8335' Junk (measured) true vertical 8259' Casing Length Size Cemented Conductor 82' 16" 135 sx AS I Surface 2577' 7.625" 305 sx AS III 240 sx Class G Production 5013' 5.5" 110 sx LiteCrete & 3466' 5,5" 115 sx Class G Liner Measured depth 115' 2610' 5046' 8512' True vertical depth 115' 2610' 4978' 8435' Perforation Depth measured 8135'-8150 true vertical 8059'-8074 ORIGINAL Tubing (size, grade, and measured depth) 3.5" / 2.875, 9,3# / 6.4#, L-80 @ 7944' / 8082 Packers and SSSV (type and measured depth) Baker FB-1 Production packer @ 7944', No SSSb ,JUN 2,.:) 2000 I' ~'~. ,, , ,~ 13. Stimulation or cement squeeze summary Intervals treated (measured: N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 15. Attachments ] 16. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _Z Oil _ Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~,~ ~'/'~~~.~_~ Title', '"~11~/.,~, Suspended _X Service Date SUBMIT IN DUPLICAT~ Form 10-404 Rev 06/15/88 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 June 22, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for Spark #lA - Confidential Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Report of Sundry Well Operations for the exploration well Spark #lA, Drilling Permit No. 200-56 / 300-115 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. Please disregard the Completion Report (AOGCC form 10-407) sent earlier in June. The attachments to the Completion Report can be attached to this Sundry. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PA1 Drilling JUN 25 2000 O,i~ ~, Gas C. ons. PHILLIPS Alaska, Inc. A Subsidiary ~ PHILLII~ PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 Ak. Oil &Gas Conservation Comm. ATTN: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99507 DATE: 06/20/2000 Transmitted herewith is the following: Spark 1 (501032031300) ,,~.OO · O~ 14 Sperry Sun CD ROM: MWD WELL data 44-8795Ynd; log date 4/4/2000; + 1 LIS verification tape listing .1 r. eprodueible and 1 blueline print each: Sperry Sun MWD DGR/EWR - TVD; end logging 4/4/2000 Sperry SUn MWD DGR/EWR/ROP - MD; end logging 4/4/2000 Sperry Sun MWD DGR/CTN/SLD - TVD; end logging 4/4/2000 Sperry Sun MWD DGR/CTN/SLD - MD; end logging 4/4/2000 ' Spark IA (501032031301) ' Q, O0 · D ~' CD ROM Schlumberger Dipole Sonic DT's 0-8360tnd; logged 4/27/2000 ~ qEv ~ ~'~ CD ROM Schlumberger Open Hole edits; DSI; FMI LDWG; 25:8320'; log date 4/27/2000~:g- q (O(.P ~- Schlumberger Best DT Dipole Sonic (color log) DSI/USIT; date processed 6/1/2000 .1. reproducible and 1 blueline print each Schlumberger Repeat Formation Tester; 4/23/2000; 8110-8145ind Schlumberger GR/CCL W/Pressure/Temp; 5/3/2000; 7800-8200ind Schlumberger Packer Setting record 4/28/2000; 7850-8020ind Schlumberger Dipole Sonic Imager; cased hole 4/27/2000 Rendezvous A (501032031600) ~ OO. C) ~ c~ Sperry Sun CD ROM: MWD WELL data; 122-8344tnd; log date 4/28/2000 + 1 LIS verification tape listing 1 blueline print each: Sperry Sun MWI) DGR/EWR/ROP; MD/TVD; end logging 4/12/2000 Sperry Sun MW]) DGR/CTN/SLD; MD/TVD; end logging 4/12/2000 Core Lab Core Analysis Results - Rendezvous A - ~copies . ~,.[ ~'//(eachce.,.,tg, with 3.5" floppy digital report copy) CC: Mark McDermott Approved f°r trans"mittal bY: Greg Wilson-'"'",,-..2....( ~ ~ t-'x ~,,-"~"'~ - '~~~ _ ' C'~'~ ~~ Receipt: % ~_~~ ~x'x) ~.~. ~_aA~ Date: ,I,,I ~o Ottttfl [ [ n~/ ~hillips Alask/'~lnc. u~,~ ~.~ '-,,,,,, Return receipt to: · .TTN: S. Lemke, ATO-1354 Alaska 0il & Gas Cons. Com;llission 700 G. Street Prepared by: ~a~. Lemke Anchorage. AK 99501 Phillips Alaska IT Geoscience Group FROM: PHILLIPS Alaska, Inc. A Sut:~idiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA Sandra D. Lemke, ATO1354 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Ak. Oil & Gas Conservation Comm. AT'I2q: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 DATE: 6/05/2000 Transmitted herewith is the following: . ~Rendezvous A 501032031600 ~OC), C) ~'t4 . Epoch Formation log (~s.e_p~~ ~ ~x~ ~3.x~o.~ CDROM data Schlumberger DSI · reprocessed merged Main Pass w/raw Customer Waveform DLIS format 4/26/200~1 of 2)~ Raw customer waveform DLIS file 4/26/20~- Schlumberger Reproducible log films + 1 Bluelines each: (Schlumberger Dipole Sonic Imager 70-8090~nd 4/26/2000 ~Schlumberger Repeat Formation Tester 8085-8164' md 4/27/2000 Color Log Print Schlumberger Best DT Dipole Sonic Q.C. Plot - GEOFRAME processed interpretation (2 copies) Spark 1 (501032031300) .).~ ,o~ Epoch Formation Log (sepia film) Spark lA (501032031300) ~.OD- C)%'-~ Epoch Formation Log (sepia film) ,/Schlumberger Ultrasonic Imager/CCL/GR 4/27/2000 5500-8287~nd ~ Sperry Sun Directional Survey data; 1- 3.5" disk, Clover A, .RendezvousA, Spark 1, lA (Sperry logging runs forthcomin ~ ~ ~ CC: Mark McDermott t ' Appr°ved f°r(~~7;--'--" (D ~. ~.. ~4-~~ Receipt: .~/~ ~'~ Date: -,]UN 0~ ~000 Return receipt to: /P~illips Alaska, Inc. ';. -- "., - ,-,,,. t',,ns C0mmissior= · ~-FN: S. Lemke, ATO-1354 AlaSKa Ua a ~ ,,,, · ,., AnChor_age 700 G. Street Prepared by: ~anora D. Lemke Anchorage, AK 99501 Phillips Alaska IT Geoscience Group Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 1, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for Spark #lA - Confidential Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached data for the exploration well Spark #lA, Drilling Permit No. 200-56 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. Attachments to the Completion report include a summary of daily operations, a directional survey, as-built and geologic tops. We will send under separate cover the log and mud logs. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PM/skad ~..I" STATE OF ALASKA.~.;" AL/~,... A OIL AND GAS CONSERVATION COfv~ ..,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas BI Suspended [~ AbandonedD Service E] I~~.,, :~ 7. Permit Number 2. Name of Operator ' Phillips Alaska, Inc. - ~.' 200-056 / 300-115 3. Address~~"~r -' - t 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 t~, 50-103-20313-01 . 4. Location of well at sudace ~~&,._ ~. Unit or Lease Name 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM (ASP: 291158,5939589) ,~~ ~~ Exploratio~ NPRA At Top Producing tnte~al~ ~, 10. Well Number 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65)~,..,~;,"~..' ~~~. ~- 11. Field and PoolARCO Spark ~IA At Total Depth ~ . 2306' FNL, 2502' FWL, Sec. 8, T10N, R2E, UM (ASP: 291144, 5938891.65) Exploration 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. RKB 33 feet~ ADL AA-081802 ALK AK5147 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~15. Water Depth, if offshore 16. No. of Completions ~{ ~~ N/A feet MSL 1 April 13, 2000 April 22, 2000 .~,~/ ~/ ~ ~ 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey 120. Depth where SSSV set 21. Thickness of Permafrost 8522' MD / 8445' TVD 8335' MD / 8259' TVD YES ~ No ~~ N/A feet MO 760' SS 22. Type Ele~ric or Other Logs Run LWD, Neutron/Density/4_phase/GR, DSl, VSP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5¢ B Surface 115' 20" 135 sx AS I 7.625" 29.7¢ L-80 Surface 2610' 9.875" 305 sx Class G, 240 sx Class G 5.5" 15.5¢ L-80 Surface 5046' 6.75" 110 sx LiteCrete, 115 sx Class G 5.5" 15.5¢ L-80 5046' 8512' 6.75" included in above 24. Pedorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) 'PACKER SET (MD) 3.5" / 2.875" 7944' / 8082' 7944' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8135' - 8150' MD 8059'- 8074' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A ORIGINAL 27, PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 1,2000 Temporarily Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 5/1/2000 25.5 Test Period > 220 2.4 mmscfd 0 48/64~ 10000 scf/stb Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 230 psi 700 psi 24-Hour Rate > 48.5 deg. APl 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A 0 2 2000 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~," 30.,."¢ GEOLOGIC MARKER~. ~, FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. see attachment Wellbore P&A'd 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-built, Geologic Tops 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call James Trantham 265-6434 Signed Title Exploration Drillinq Team Leader Date Pau/ Mazzolini INSTRUCTIONS Prepared by Sharon AIIsup-Dral~e 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 "none". Form 10-407 Tops Base Permafrost Top Nanushuk HRZ LCU Upper Jurassic Nechelik TD ARCO Spark 1 (Measured Depth) 605 3005 absent 7460 8010 8565 8850 ARCO Spark lA (Measured Depth) 6O5 3005 absent 7540 8105 np 8522 Date: 05/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:SPARK#iA STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD:04/13/00 START COMP: RIG:NABORS 19E WI: 0% SECURITY:0 API NUMBER: 50-103-20313-01 BLOCK: FINAL: 04/13/00 (D1) MW: 11.4 VISC: 53 PV/YP: 16/24 APIWL: 9.4 TD/TVD: 2518/2518 (2518) RIH W/ DRILLING ASSEMBLY " SUPV:S. GOLDBERG/R.W. SPRINGER R/U & reverse circulate. PJSM. POH. Shut down operations, falling ice, clear ice in derrick. Test BOPE. 04/14/00 (D2) MW: 9.5 VISC: 52 PV/YP: 12/24 APIWL: 4.4 TD/TVD: 3270/3265 ( 752) CIRCULATING AND CONDITIONING HOLE FOR SHORT TRIP SUPV:S. GOLDBERG/R.W. SPRINGER PJSM. RIH. Tag TOC at 2518'. Clean out cement from 2518' to 2730' Kickoff cement plug. Slide from 2730' to 2796' Circulate in new Kcl based LSND mud. Drill 6.75" hole from 2796' to 3270'. Hold Kick while drilling drill. 04/15/00 (D3) MW: 9.6 VISC: 61 PV/YP: 17/35 APIWL: 5.6 TD/TVD: 4485/4428 (1215) DRILLING 6 3/4" HOLE AT 4753' SUPV:S. GOLDBERG/R.W. SPRINGER Continue drilling 6.75" hole from 3270' to 3585'. Pump high viscosity sweep around. Short trip from 3585' to 2610' Continue drilling 6.75" hole from 3585' to 4485' 04/16/00 (D4) MW: 9.5 VISC: 44 PV/YP: 11/23 APIWL: 5.8 TD/TVD: 5039/4971 (554) DRILLING 6 3/4" HOLE AT APPROX. 5210' SUPV:S. GOLDBERG/R.W. SPRINGER Continue drilling 6.75" hole from 4485' to 4849'. Pump low/high viscosity sweeps around. Continue to C&C mud until shakers clean. POOH slowly. Monitor well, static. Run back in hole to bottom. Flow check well. Static. Circulate. Small amount of gas at bottoms up. POOH to 7-5/8" casing shoe. Kelly up and circulate with bit below 7-5/8" shoe. Lots of clay unloading at shakers. Circulate until clean. Run in hole slowly. Smooth except for probable key seat from 3293' to 3387'. work through twice to clean up. Continue to bottom. Circulate bottoms up. Continue drilling 6.75" hole from 4849' to 5039' 04/17/00 (D5) MW: 9.7 VISC: 50 PV/YP: 12/25 APIWL: 6.4 TD/TVD: 5835/5711 (796) DRILLING AHEAD TO APPROX.6300' SUPV:M.CUNNINGHAM/R.W. SPRINGER Drill from 5039' to 5607'. Circulate combo hi-lo vis sweeps around. Drill from 5607' to 5639'. Circulate bottoms up. Short trip from 5639' to 4796'. Drill from 5639' to 5835' Date: 05/25/00 ARCO ALASKA INC. WELL S~RY REPORT Page: 2 04/18/00 (D6) MW: 9.8 VISC: 46 PV/YP: 14/28 APIWL: 7.2 TD/TVD: 6934/6755 (1099) TRIP OUT HOLE-DOWNLOAD LWD-CHECK BIT-SWAP MUD OVER KCL SUPV:M.CUNNINGHAM/R.W. SPRINGER Drill from 5828' to 6934' Safety assessment conducted. 04/19/00 (D7) MW: 11.0 VISC: 50 PV/YP: 14/24 APIWL: 2.8 TD/TVD: 6935/6755 ( 1) DRILL AHEAD F/6935' SUPV:M.CUNNINGHAM/R.W. SPRINGER Swap mud over to KC1/GEM. POOH to shoe. Monitor well 8 shoe, OK. PJSM. Test BOPE 250/5000 psi. RIH & break circulation @ 4619', no tight spots. MAD pass log from 6155' to 6484' 04/20/00 (D8) MW: 11.0 VISC: 39 PV/YP: 12/19 APIWL: 2.9 TD/TVD: 7699/7624 ( 764) DRILL TO TOP OF ZONE OF INTEREST & SHORT TRIP SUPV:D.J. CUNNINGHAM/R.W. SPRINGER PJSM. MAD pass log from 6484' to 6935'. Circulate bottoms up, no excess cuttings, hole good, gas @ 20 units. Line up and slide from 6935' to 6966' Drill from 6966' to 7029' Slide from 7029' to 7036'. PJSM. Drill from 7036' to 7699' Drill and ream after each kelly down. Gas @ 60 units. 04/21/00 (D9) MW: 11.0 VISC: 40 PV/YP: 12/16 APIWL: 3.0 TD/TVD: 8419/7624 (720) TRIP TO SURFACE& RIG UP E-LINE UNIT SUPV:D.J. CUNNINGHAM/R.W. SPRINGER Drill from 7692' to 7945'. Held for kick while drilling drill. Drill from 7945' to 8008'. PJSM. Circulate hole clean. Short trip from 8008' to 6900'. RIH. Drill from 8008' to 8419' 04/22/00 (D10) MW: 11.0 VISC: 42 PV/YP: 12/16 APIWL: 3.0 TD/TVD: 8522/8445 (103) RIH W/DRILLPIPE CONVEYED LOGS - NOTE TD OF WELL @ 852 SUPV:D.J. CUNNINGHAM/R.W. SPRINGER Drill from 8419' to 8522'. Circ hi-vis sweep and circ hole clean. Wiper trip to 7965' PJSM. Run RFT. Tagged bridge ~ 3490'. RIH to 3488' tagged fill, work tight spot. RIH to 5551' circulate hole clean, some small clay balls across shakers but were minimal clay. 04/23/00 (Dll) MW: 11.0 VISC: 43 PV/YP: 12/16 APIWL: 3.0 TD/TVD: 8522/8445 ( 0) CIRCULATE & CONDITION HOLE FOR 5.50" CASING SUPV:D.J. CUNNINGHAM/R.W. SPRINGER Circulate hole clean. RIH to 5647', no tight spots. POOH to 5557' Pump dry job. POOH. Hold safety meeting. RIH with logging tools, stop at 7575'. Problems obtaining signal from tool. POOH with e-line and repair. Hold safety meeting. Run e-line. RIH to 8140' to log. POOH to 7575' Date: 05/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/24/00 (D12) MW: 11.0 VISC: 40 PV/YP: 13/14 APIWL: 3.0 TD/TVD: 8522/8445 ( 0) CIRCULATE & CONDITION HOLE FOR CEMENT SUPV:D.J. CUNNINGHAM/R.W. SPRINGER POOH w/logging assembly. RIH to 2610' and circ RIH to 5652' and circ. RIH to 8522' hole good. Pump hi-vis sweep. Circ and condition mud. Check well for flow, hole good. POOH slow. PJSM. Rig up to run 5.5" casing. 04/25/00 (D13) MW: 11.0 VISC: 42 PV/YP: 12/14 APIWL: 3.0 TD/TVD: 8522/8445 ( 0) SET PACK-OFF ON 5.5" CASING SUPV:R.L. MORRISON/MOOSE CUNNINGHAM PJSM. Run 5.5" casing. Circulate bottoms up ~ 2610' and 5440', no mud losses while circulating. PJSM. Continue to run 5.5" casing to 8513'. Casing was differentially sticking while running through production zone. Made up circulating swedge. Circulate and condition mud prior to cement job. Made several attempts to pull casing free while circulating, no success. PJSM. Pump litecrete and cement. 04/26/00 (D14) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) RUNNING DIPOLE SONIC SUPV:R.L. MORRISON/MOOSE CUNNINGHAM Pump cement. Bleed off pressure and monitor pressure, good. Set pack-off and test to 5000 psi, good. E-line VSP run ~1 in hole. E-line lost signal downhole, electrical problems. POOH. Run #2 for VSP log. 04/27/00 (D15) MW: 0.0 VISC: 42 PV/YP: 0/ 0 TD/TVD: 8522/8445 ( 0) LAY-DOWN DRILLPIPE SUPV:R.L. MORRISON/MOOSE CUNNINGHAM APIWL: 0.0 PJSM, out of hole with run #2 VSP, clean out logging tools. Run #2 D-S & USIT. Run #4 GR & CCL. PJSM. Rig up to run completion string - perf guns, G/L mandrels, SBE, packer. 04/28/00 (D16) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) INSTALL BPV, NIPPLE DOWN STACK, NIPPLE UP TREE SUPV:MOOSE CUNNINGHAM/R.L. MORRISON Hold PJSM. Fill BOPE w/water. M/U test plug. Rig up to run 3.5".tu___bing. Hold PJSM. RIH with 3.5" tubing. 04/29/00 (D17) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) RELEASE RIG ~ 23:59 HRS. 29 APRIL RDMO SUPV:MOOSE CUNNINGHAM/R.L. MORRISON Test 5.5" casing x 3.5" tubing to 3500 psi, good. Install BPV. PJSM. ND BOPE. N/U BOPE/tree. Install test plug, test -- to 250/5000 psi. PJSM. Test tree to 250/5000 psi. Good. Pull test plug. RIH. Set catcher basket in XN nipple at 8031' POOH. RIH to pull DV at 7852'. POOH recovered DV. the DV latch mechanism fell off the valve while POOH. RIH to pull catcher basket. POOH. Change well over to diesel. Set BPV. Release rig at midnight on 4/29/00~%~;~ ......... ~'~.~ ........... ~'~'~.~':?~'~% Date: 05/25/00 ARCO ALASKA INC. WELL SLTNIMARY REPORT Page: 4 04/30/00 (D18) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) MOVING RIG TO KUPARUK, WELL STATUS - GLM LATCH RECOVER SUPV:MOOSE CUNNINGHAM/R.L. MORRISON Rig down. Rig off well at 1730 hrs. 4/30/00. Make final preparations to leave location. Moving rig from Arco Spark #1 to Kuparuk. 05/01/00 (D19) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) MOVING RIG TO 2L PAD ~ 3H PAD AT 6 AM. WELL TEST STATU SUPV:MOOSE CUNNINGHAM/R.L. MORRISON Moving rig to 2L pad. 05/02/00 (D20) TD/TVD: 8522/8445 ( SUPV:R.L. MORRISON MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 0) 60 MAN CAMP READY FOR MOVE - EXPECT TRUCKS AM 5/3. WEL Finish moving rig to 2L pad. Start breaking down 60 man camp. Crews cleaning up ARCO Spark and Clover pads. 05/03/00 (D21) TD/TVD: 8522/8445 ( SUPV:R.L. MORRISON MW: 0.0 VISC: 42 PV/YP: 0/ 0 0) SETTING DV IN GLM AT 7852' APIWL: 0.0 Prepare 60 man camp for move to 2L pad. Ran GR/CCL to check location of perfs. Continue to rig down, move off location. Date: 05/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:SPARK#iA TEST STATE:ALASKA COUNTY: NORTH SLOPE EXPL FIELD: WILDCAT SPUD: START COMP: RIG:NO RIGNAME BLOCK: FINAL: -- --. WI: 0% SECURITY:0 API NUMBER: 50-287- - 04/24/00 (D1) MW: 11.0 VISC: 40 PV/YP: 13/14 APIWL: 3.0 TD/TVD: 8522/8445 (8522) CIRCULATE & CONDITION HOLE FOR CEMENT SUPV:D.J. CUNNINGHAM/R.W. SPRINGER POOH w/logging assembly. RIH to 2610' and circ RIH to 5652' and circ. RIH to 8522' hole good. Pump hi-vis sweep. Circ and condition mud. Check well for flow, hole good. POOH slow. PJSM. Rig up to run 5.5" casing. 04/25/00 (D2) MW: 11.0 VISC: 42 PV/YP: 12/14 APIWL: 3.0 TD/TVD: 8522/8445 ( 0) SET PACK-OFF ON 5.5" CASING SUPV:R.L. MORRISON/MOOSE CUNNINGHAM PJSM. Run 5.5" casing. Circulate bottoms up ~ 2610' and 5440', no mud losses while circulating. PJSM. Continue to run 5.5" casing to 8513'. Casing was differentially sticking while running through production zone. Made up circulating swedge. Circulate and condition mud prior to cement job. Made several attempts to pull casing free while circulating, no success. PJSM. Pump litecrete and cement. 04/26/00 (D3) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) RUNNING DIPOLE SONIC SUPV:R.L. MORRISON/MOOSE CUNNINGHAM Pump cement. Bleed off pressure and monitor pressure, good. Set pack-off and test to 5000 psi, good. E-line VSP run #1 in hole. E-line lost signal downhole, electrical problems. POOH. Run #2 for VSP log. 04/27/00 (D4) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) LAY-DOWN DRILLPIPE SUPV:R.L. MORRISON/MOOSE CUNNINGHAM PJSM, out of hole with run #2 VSP, clean out logging tools. Run #2 D-S & USIT. Run ~4 GR & CCL. PJSM. Rig up to run completion string - perf guns, G/L mandrels, SBE, packer. 04/28/00 (D5) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) INSTALL BPV, NIPPLE DOWN STACK, NIPPLE UP TREE SUPV:MOOSE CU~NINGHAM/R.L. MORRISON Hold PJSM. Fill BOPE w/water. M/U test plug. Rig up to run 3.5" tubing. Hold PJSM. RIH with 3.5" tubing. Date: 05/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/29/00 (D6) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) RELEASE RIG ~ 23:59 HRS. 29 APRIL RDMO SUPV:MOOSE CUNNINGHAM/R.L. MORRISON Test 5.5" casing x 3.5" tubing to 3500 psi, good. Install BPV. PJSM. ND BOPE. N/U BOPE/tree. Install test plug, test to 250/5000 psi. PJSM. Test tree to 250/5000 psi. Good. Pull test plug. RIH. Set catcher basket in XN nipple at 8031'. POOH. RIH to pull DV at 7852' POOH recovered DV. the DV latch mechanism fell off the valve while POOH. RIH to pull catcher basket. POOH. Change well over to diesel. Set BPV. Release rig at midnight on 4/29/00. 04/30/00 (D7) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) MOVING RIG TO KUPARUK, WELL STATUS - GLM LATCH RECOVER SUPV:MOOSE CUNNINGHAM/R.L. MORRISON Rig down. Rig off well at 1730 hrs. 4/30/00. Make final preparations to leave location. Moving rig from Arco Spark #1 to Kuparuk. 05/01/00 (D8) TD/TVD: 8522/8445 ( SUPV:R.L. MORRISON MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 0) MOVING RIG TO 2L PAD @ 3H PAD AT 6 AM. WELL TEST STATU Moving rig to 2L pad. 05/02/00 (D9) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8522/8445 ( 0) 60 MAN CAMP READY FOR MOVE - EXPECT TRUCKS AM 5/3. WEL SUPV:R.L. MORRISON Finish moving rig to 2L pad. Start breaking down 60 man camp. Crews cleaning up ARCO Spark and Clover pads. 05/03/00 (D10) TD/TVD: 8522/8445 ( SUPV:R.L. MORRISON MW: 0.0 VISC: 42 PV/YP: 0/ 0 0) SETTING DV IN GLM AT 7852' APIWL: 0.0 Prepare 60 man camp for move to 2L pad. Ran GR/CCL to check location of perfs. Continue to rig down, move off location. 05/04/00 (Dll) TD/TVD: 8522/8445 ( SUPV:R.L. MORRISON MW: 0.0 VISC: 42 PV/YP: 0/ 0 0) LOADING HOWCO EQUIPMENT APIWL: 0.0 Pull catcher basket from XN nipple at 8031' Pull DV from GLM at 7852'. Run XXN plug to 7930'. Bullhead 5 bbls diesel down tubing followed by brine. Land XXN plug in XN nipple at 8031' and pressure to 500 psi, shear off plug. Open 3.5 x 5.5 annulus and continue brine displacement. Run and set DV in GLM at 7852' POOH. Pressure test tubing. Set BPV. Have been rigging down and moving test equipment off pad. 05/05/00 (D12) TD/TVD: 8522/8445 ( SUPV:R.L. MORRISON MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 0) CLEANING UP CUTTINGS PIT, MOVING EQUIPMENT OFF PAD. Continue to move equipment off pad. Date: 05/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 05/06/00 (D13) MW: 0.0 VISC: 42 PV/YP: 0/ 0 TD/TVD: 8522/8445 ( 0) MOVE CAMP TO KUPARUK SUPV:R.L. MORRISON Continue move rig equipment off location. APIWL: 0.0 04-05-2000 04:48am From-O WING +gO?-B5g-7401 T-gT8 P. 001/002 F-868 ., 3 ELEVATIONS SHOWN ARE BPMSL uOcA~ED w~THIN PRotRAcTED ~ ~ ~ ~C~ SPARK ~1 ~,~ UM[AT MERIDIAN ¢~k k .......... " ,c'~ LAT. = 7"' 14' 17.793" ~ ~ GROUND ELEVATION = 55,7' n~-~ TOP OF iCE PAD ELEV 58 4' SUR~YOR'S CERTIFICATE _~*~l~i- I HEREBY CERTIFY THAT I AM PROPERLY ~~ ~_..~~. REGISTERED AND LICENSED TO PRACTICE ~ .- ~-..¢ .~ ALASKA AND THAT THIS PLAT REPRESENTS ~ ~ 49th .~~-~ A SURVEY DONE BY ME OR UNDER MY ~ ..... ~. ..... ~ ...... ~..¢~..a ..... ~ DIRECT SUPERVISION AND THAT ALL ~-- ~~t~JJi'i ,z~ ~ DIMENSIONS AND OTHER DETAILS ARE ARCO Alaska, Inc a. co SPARK1 ' ~F EXPLORATORY ~ CONDUCTOR SUbsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON. m LK6e!D332 3/12/ee CEA-M1XX,-6~I D33~, ...... North Slope Alaska Alaska State Plane 4 EXPL ORA TION_NON-PAD Spark #lA Surveyed: 21 April, 2000 SURVEY REPORT 28 April, 2000 Your Ref: API.50103203101 Surface Coordinates: 5939589.04 N, 291158.37 E (70° 14' 17.7933" N, Kelly Bushing: 90.32ft above Mean Sea Level 151° 41' 11.3948" W) DRILLING SERVI r' E-~ A H.4,I.UBU~'I'O~ CONI~At'~ Survey Ref: svy9189 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for Spark #lA Your Ref: AP1-$0103203101 Surveyed: 21 April, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2716.89 0.790 249.210 2626,54 2716.86 2730.00 0.740 247.790 2639.65 2729.97 2845.17 5.150 185.050 2754.65 2844.97 2940.08 6.710 188.510 2849.05 2939.37 3036.00 7.980 189.250 2944.18 3034.50 3130.19 10.340 185.220 3037.16 31'27.48 3225.56 11.920 189.670 3130,74 3221.06 3319.07 14.390 189.530 3221.79 3312.11 3414.35 16.060 187.190 3313.72 3404.04 3515.07 17.090 185.430 3410.26 3500.58 3603.05 16.510 185.940 3494.48 3584.80 3696.43 16.340 186.520 3584.05 3674.37 3792.48 15.920 185.250 3676.32 3766.64 3886.55 16.390 188.250 3766.68 3857.00 3982.65 17.700 182.230 3858.56 3948.88 4076.55 17.740 187.810 3948.01 4038.33 4171.86 17.310 187.630 4038.90 4129.22 4267.07 16.860 186.870 4129.91 4220.23 4360.90 16.180 187.400 4219.86 4310.18 4455.00 15.510 189.640 4310.39 4400.71 4549.28 14.270 185.390 4401.50 4491.82 4645.19 13.050 188.010 4494.70 4585.02 4738.76 12.660 189.860 4585.92 4676.24 4834.27 11.430 187.630 4679.33 4769.65 4928.70 10.110 189.900 4772.09 4862.41 1.15 S 8.78 W 1.21 S 8.94 W 6.64 S 10.09 W 16.37 S 11.28W 28.49 S 13.18W 43.36 S 15.00W 61.59 S 17.43W 82.58 S 20.98w 107.33 $ 24.59W 135.89 S 27.74w 161.19 S 30.25W 187.44S 33.12W 213.98 S 35.86W 239.96 S 38.94W 267.98 S 41.46W 296.42 S 43.96W 324.86 S 47.81W 352.61S 51.34W 379.08 S 54.66W 404.49 S 58.45W 428.48 S 61.65W 450.98 S 64.27W 471.54S 67.50w 491.23 S 70,55W 508.67 S 73.22W 5939588.14 N 291149.56 E 5939588.08 N 291149.40 E 5939582.68 N 291148.10 E 5939572.99 N 291146.64 E 5939560.93 N 291144.40 E 5939546.11N 291142.17 E 5939527.95 N 291139.24 E 5939507.08 N 291135.11 E 5939482.43 N 291130.82 E 5939453.97 N 291126.88 E 5939428.75 N 291123.66 E 5939402.59 N 291120.07 E 5939376.14 N 291116.60 E 5939350.25 N 291112.80 E 5939322.31 N 291109.51 E 5939293.95 N 291106.22 E 5939265.63 N 291101.58 E 5939237.99 N 291097.28 E 5939211.62 N 291093.24 E 5939186.33 N 291088.74 E 5939162.43 N 291084.87 E 5939140.02 N 291081.63 E . 5939119.55 N 291077.83 E 5939099,95 N 291074.24 E 5939082.59 N 291071.09 E Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Rate (°/100ft) 0.408 4.216 1.686 1.328 2.595 1.885 2.642 1.867 1.138 0.680 0.253 0.571 1.018 2.285 1.809 0.455 0.528 0.742 0.964 1.752 1.426 0.606 1.377 1,468 Vertical Section (ft) Comment 1.92 2.00 7.51 17.31 29.54 44.52 62.89 84.11 109.08 137.81 163.23 189.63 216.31 242.47 270.60 299.15 327.81 355,77 382.43 408.07 432.26 454.89 475.66 495.54 513.15 Tie-on Survey Window Point Continued... DrillQuest 1,05.05 28 April, 2000 - 11:52 - 2 - North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for Spark #lA Your Ref: API-50103203101 Surveyed: 21 April, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5023~2 8.840 185.780 4865.42 4955.74 5117.75 7.500 187.420 4958.89 5049.21 5212.96 6.100 186.910 5053.43 5143.75 5307.99 4.660 172.850 5148.04 5238.36 5401.88 3.050 177.750 5241.72 5332.04 5497.19 2.020 181.160 5336.93 5427.25 5594.19 1.620 200.880 5433.88 5524.20 5686.35 1.460 207.680 5526.01 5616.33 5781.14 1.300 214.730 5620.77 5711.09 5876.00 1.150 204.200 5715.61 5805.93 5971.82 1.340 226.490 5811.41 5901.73 6066.52 1.680 227.350 5906.08 5996.40 6157.19 1.360 225.000 5996.72 6087.04 6252.99 1.250 222.590 6092.49 6182.81 6350.80 1.280 216.410 6190.28 6280.60 6445.78 1.150 219.510 6285.24 6375.56 6539.77 1.300 188.550 6379.20 6469.52 6635.60 1.800 164.730 6475.00 6565.32 6730.48 2.370 158.540 6569.82 6660.14 6825.22 3.670 142.630 6664.43 6754.75 6919.42 3.520 153.130 6758.44 6848.76 7013.80 3.730 151.600 6852.63 6942.95 7108.96 4.500 144.980 6947.55 7037.87 7203.50 5.510 150.200 7041.73 7132.05 7298.21 7.170 131.720 7135.86 7226.18 524.09 S 75.38W 537.42 S 76.90W 548.60 S 78.31W 557.45 S 78.44W 563.73 S 77.87W 567.94 S 77.80W 570.93 S 78.33W 573.19 S 79.34W 575.14 S 80.51W 576.89 S 81.51W 578.54 S 82.72W 580.24 S 84.54W 581.90 S 86.28W 583.48 S 87.79W 585.14 S 89.16W 586.73 S 90.40W 588.51S 91.16W 591.04 S 90.92W 594.30 S 89.81W 598.54 S 87.26W 603.51S 84.12W 608.80 S 81.35W 614.58 S 77.74W 621.55 S 73.35W 629.43S 66.68W 5939067.24 N 291068.51E 5939053.96 N 291066.61 E 5939042.82 N 291064.89 E 5939033.98 N 291064.52 E 5939027.69 N 291064.92 E 5939023.47 N 291064.87 E 5939020.50 N 291064.26 E 5939018.27 N 291063.19 E 5939016.35 N 291061.96 E 5939014.63 N 291060.91 E 5939013.01N 291059.66 E 5939011.36 N 291057.79 E 5939009.75 N 291056.00 E 5939008.22 N 291054.45 E 5939006.59 N 291053.03 E 5939005.04 N 291051.75 E 5939003.28 N 291050.95 E 5939000.74 N 291051.11 E 5938997.45 N 291052.13 E 5938993.15 N 291054.57 E 5938988.09 N 291057.57 E 5938982.73 N 291060.19 E 5938976.85 N 291063.64 E 5938969.76 N 291067.83 E 5938961.69 N 291074.28 E Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Rate (°/100ft) 1.521 1.440 1.472 2.044 1.749 1.092 0.760 0.263 0.246 0.285 0.539 0.360 0.359 0.128 0.143 o.153 0.712 0.840 0.645 1.620 0.716 0.245 0.949 1.171 2.756 Vertical Section (ft) Comment 528.70 542.11 553.38 562.20 568.40 572.59 575.62 577.95 580.00 581.84 583.59 585.44 587.25 588.95 590.73 592.42 594.27 596.76 599.92 603.91 608.59 613.60 619.04 625.60 632.86 Continued... 28 April, 2000- 11:52 -3- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for Spark #lA Your Reft AP1.50103203101 Surveyed: 21 April, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 7393.60 6.240 146.350 7230.61 7320.93 637.71 S 59.36 w 5938953.22 N 291081.37 E 7488.12 7.710 132.890 7324.43 7414.75 646.30 S 51.87 W 5938944.42 N 291088.62 E 7583.05 7.040 132.820 7418.57 7508.89 654.59 S 42.94 W 5938935.89 N 291097.32 E 7677.44 5.600 134.900 7512.39 7602.71 661.78 S 35.43 W 5938928.50 N 291104.62 E 7770.97 5.140 134.970 7605.51 7695.83 667.96 S 29.23 W 5938922.15 N 291110.64 E 7866.32 4.220 130.680 7700.54 7790.86 673.26 S 23.55 W 5938916.69 N 291116.18 E 7962.57 3,460 140.610 - 7796.57 7886.89 677.82 S 19.02 W 5938912.01 N 291120.58 E 8057.31 2.990 140.700 7891.16 7981.48 681.94 S 15.64 W 5938907.80 N 291123.84 E 8150.66 3.270 123.480 7984.38 8074.70 685.29 S 11.88 W 5938904.34 N 291127.51 E 8245.39 3.840 125.060 8078.92 8169.24 688.60 S 7.03 W 5938900.90 N 291132.27 E 8340.39 3.140 128.830 8173.75 8264.07 692.06 S 2.40 W 5938897.31 N 291136.80 E 8434.89 2.910 124.180 8268.11 8358.43 695.03 S 1.60 E 5938894.23 N 291140.72 E 8522.00 2.910 124.180 8355.11 8445.43 697.52 S 5.26 E 5938891.65 N 291144.31 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True Nodh. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.331° (22-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 185.070° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8522.00ft., The Bottom Hole Displacement is 697.54ft., in the Direction of 179.568° (True). Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Rate (°/100.) Vertical Section (ft) Comment 2.031 2.316 0.706 1.545 0.492 1.032 1.046 0.496 1.046 0.610 0.775 0.356 0.000 640.46 648.36 655.83 662.32 667.93 672.71 676.85 680.65 683.66 686.53 689.57 692.17 694.32 Projected Survey :.:i:'=!.:; ':: Continued... DrillQuest 1.05.05 28 Apr~ 2000-11:52 -4- North Slope Alaska Sperry-Sun Drilling Services Survey Report for Spark #lA Your Ref: AP1.$0103203101 Surveyed: 21 April, 2000 Alaska State Plane 4 EXPLORATION_NON-PAD Comments Measured Depth (fi) 2716.89 2730.00 8522.00 Station Coordinates TVD Northings Eastings (~) (~) (~) 2716.86 1.15 s 8.78W 2729.97 1.21 s 8.94w 8445.43 697.52 s 5.26 E Comment Tie-on Survey Window Point Projected Survey SurVey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 8522.00 8445.43 Survey Tool Description MWD Magnetic 28 April, 2000 - 11:52 -5- DrillQuest 1.05.05 ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 04/04/2002 NUMBER NUMBER 200-056-0 103-20313-01 SPARK WELL WELL LEASE NAME NUMBER ,SORT, NUMBER IA 0110 FED-NPRA CODE NAME ...... 134200 PHILLIPS ALASKA INC. FLDPOL FIELD AND POOL Ioooooo CODE I AREA SHORE LATERL ............... 890 ARCTIC SLOPE ON MULTIPLE POOLS 000000 000000 000000 000000 000000 UNIT 00000 UNIT NAME KB 33 8522 8445 I .... 1608 N 2497 W 08 i0N 002E U 2306 N 2502 W 08 i0N 002E U INITIAL FINAL CURRENT REQUIREMENTS ..... ~1ACCTING EXP 1-OIL EXP OPSHD YES YES RCV +_ + APPROVED ISSUED SPUDDED COMP. ETC CUR STATUS LAST UPDTD CODE 04/14/2000 04/14/2000 04/13/2000 06/30/2000 03/16/2001 11111 + Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 8, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Directional Surveys for ARCO Spark #1 & #lA - Confidential Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the enclosed directional surveys for Drilling Permit No. 200-034 and 200-056. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PM/skad RECEIVED ¢::AY 10 200(} Oil & Gas Cons. Corr~missio~ A~chor~je 28-Apr-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well Spark #lA Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 2,716.89' MD 2,730.00' MD 8,522.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 2, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Sundry Application for ARCO Spark #lA Operation Shutdown - Confidential Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached application for sundry, Drilling Permit No. 200-056. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PM/skad RLCE VED MAY 2000 Alaska Oil & G~s Cons~ Commission Anchorege STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _X Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. ©. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM At top of productive interval 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM At effective depth At total depth 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 33 feet 7. Unit or Property name Exploration 8. Well number ARCO Spark #lA 9. Permitnumber/approvalnumber 200-056 10. APInumber 50-103-20313-01 11. Field / Pool Exploration 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2577' Production ' 8479' 8522 8445 8522 8445 Size 16" 7.625" 5.5" feet Plugs (measured) feet feet feet Cemented 135 sx AS I 305 sx Olass G & 240 sx Class G 109.8 sx LiteOrete & 115 sx Olass G Cement Plug #1' 7640'-6940' Cement Plug #2: 4500'-4000' Cement Plug #3: 2900-2500' Measured Depth 80' 2610' 8512' True vertical Depth 80' 2521' 8440' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) ORIGINAL 3.5" x 2-7/8", 9.3# & 6.4#, 7956'/8045' Baker FB-1 packer @ 7944', No SSSV RECEIVED 0 3 2000 Alaska 0ii & Gas Co~,s. Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __X BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 15. Status of well classification as: 14. Estimated date for commencing operation May 1,2000 16. If proposal was verbally approved Blair Wondzell Name of approver Date approved Oil __ Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~~'/~ Title: Exploration Drilling Team Leader Paul Mazzolini FOR COMMISSION USE ONLY Questions? Carl James Trantham 265-6434 Date O~O Z"/O ~ Prepared b~/ Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test__ Location clearance _ Mechanical Integrity Test Subsequent form required ~O,-~!~d~ut~, DR~GINAL SIGNED. BY ~99.., ~ ~°'~e e6;. 0 /-) Approved by order of the Commission RObe~ Hr Chri~e.n_son ~' ~ ¥~e'tG~ -' ....issioner Form 10-403 Rev 06/15/88 · ~~Corffm Approval no. Date SUBMIT IN TRIPLICATE ARCO Spark #lA Sidet!'°ck Temporary Abandonment Procedure 4~28/2OOO Attachment to ARCO Spark #1, lA Well Plan Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. . Rig up slickline unit and pull the memory gages from the two lower most GLM's and replace with dummy valves. Run a plug to the packer depth above the bottom XN nipple (do not seat in the XN). RU a pump truck and bullhead kill weight fluid (>9.6 ppg Brine) in the tubing, past the plug. Set the plug prior to kill weight brine exiting the tubing, keeping brine from getting into the formation. . Pull the dummy valve from the GLM that is right above the packer. Circulate kill weight fluid (>9.6 ppg Brine) through the lower GLM and equalize at least 2000' of diesel in the annulus and the tubing. Set the dummy valve back in the lower most GLM above the packer. 3. Test the tree and tubing with diesel to 1500 psi. , Set BPV in tree. Close all valves and remove handles. Install flanges with Y2" plugs screwed into the flanges on all outer valves and a bull plug with Y2" plug in the valve on the wellhead (annulus valve). · Risks: First time we have temporarily abandoned a well in the NPRA. A spill could result if vandalism occurred. · Level: Low · Mitigation: All flanges will be blanked. In the event pressure leaks to the blind flange, 1/2" plugs will be installed to allow to bleed off pressure prior to taking off the flange. 5. RDMO the camp and all test equipment. 6. Clean-up cellar and location to prepare for inspections and Summer Operations Shutdown. 7. Hang sign on tree with the following information: Phillips Alaska, INC ARCO Spark #lA PTD # 200-056 APl # 50-103-20313-01 SHL: 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM MAY 2000 Oil & Gas Cons. Commission A~chor~e ARCO Spark #1 Temporary Abandonment _16" Conductor I J @80' RKB t__~~_~ 7-5/8 ,29 7#, L-80, BTC Mod, R3 Surface Casing @2610' MD-RKB Base Permafrost - 600' MD ~- Diesel from2000' to surface ~ SS @ 2725' TOC 12 ppg ~.-~,. 6050' MD Kill weight brine (>9.6} from 7850' to diesel cap TOC 15.8 ppg ~ 7200' MD -~- GLM @ 7850' 6-3/4" Hole GLMs @ 8008'& 7980' -~- XN @ 8031' 5-1/2"1 15.5#, L-80, BTC Mod, R3 Production Casing @ 8512' MD-RKB RECEIVED MAY O~ 2000 ,~a~ka Oi{ & Gas Co~s. Commission A~chorage , ARC~ Spark #1 A & Rendezvous "A" Scenarios- CONFIDENTIAL Subject: ARCO Spark #1 A & Rendezvous "A" Scenarios- CONFIDENTIAL Date: Fri, 21 Apr 2000 10:25:06 -0900 From: "Tom J Brassfield" <TBRASS~mail.aai.arco.com> To: Blair Wondzell <blair_wondzell@admin.state.ak.us>, pditton@ak.blm.gov CC: "Paul Mazzolini" <PMAZZOL@mail.aai.arco.com>, "James A Trantham" <JTRANTH@maihaai.arco.com> Peter/Blair, we would like to get concurrence on some options for finishing out this season's NPRA wells. As the season nears an end we see the following possibilities: ARCO Spark #1 A: If we complete this well next week, our intent is to start testing the well before break-up. There is the possibility that we will not have enough time to complete the testing phase and will need to secure the well for a Summer shutdown. The intent would be to return next Winter season, complete the test, and then P&A the wellbore. Attached is a propsed "Operations Shutdown" procedure for your review and comment. ARCO Spark #1 A: if time and mother nature would cooperate, there is the remote possibility that we could finish the test and P&A the wellbore. Attached is a proposed "P&A" procedure for your review and comment. Rendezvous "A": We should know early next week if we want to complete this well. We would not have time to test this well. The intent would be to return next Winter season, thru tubing perforate, probably stimulate, complete a well test, and then P&A the wellbore. Attached is a proposed "Operations Shutdown" procedure for your review and comment. We have some schematics we can fax which should help explain the procedures. The depths on the schematics are very rough estimates. Thanks for considering these proposals and your assistance in completing a successful Winter Drilling season. Tom (See attached file: Ren A BLM AOGCC Ops SD Proc by TJB 4 21 00.doc) (See attached file: AS 1 BLM AOGCC Ops SD Proc by TJB 4 21 00.doc) (See attached file: AS 1 BLM AOGCC P&A Proc by TJB 4 20 00.doc) Name: Ren A BLM AOGCC Ops SD Proc by TJB 4 21 00.doc ~Ren A BLM AOGCC Ops SD Proc by TJB 4 21 00.doc Type: Rich Text Format - (application/rtf) Encoding: base64 Description: Rich Text Format ~AS 1 BLM AOGCC Ops SD Proc by TJB 4 21 00.doc Name: AS 1 BLMAOGCC Ops SD ~ Proc by TJB 4 21 00.doc ' Type: Rich Text Format (application/nO Encoding: base64 ~ Description: Rich Text Format 1 of 2 4/24/00 8:55 AM ARCO Spark #1 A & Rendezvous "A" Scenarios- CONFIDENTIAL ~AS 1 BLM AOGCC P&A Proc bv TJB 4 20 00.doc Name: AS 1 BLM AOGCC P&A Proc by TJB 4 20 00.doc Type: Rich Text Format (application/nO Encoding: base64 Description: Rich Text Format 2 of 2 4/24/00 8:55 AM PROI:J~...,ED ARCO Spark #lA Operations CONFIDENTIAL Revised 4/21/00 .]tdown PURPOSE: In the event we are not able to complete the testing at the ARCO Spark #1 location, ARCO requests an Operations Shutdown to secure the well until next Winter's exploration season. The intent would be to return in the 2000/2001 Winter season, complete the well test and P&A the wellbore. This proposed procedure assumes that the well has been completed with full tree on wellhead and has live perforations. Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 1. Rig up slickline unit and set dummy valves in GLM's at XXXX', XXXX', and XXXX'. Pull the dummy from the GLM above the packer at XXXX'. RD slickline. 2. Mobilize and rig up D/S. , Bullhead kill weight fluid (Brine- weight to be determined by RFT or well test data) to the tubing tail plus 20 bbls. Circulate 3-1/2" x 5-1/2" annulus to kill weight fluid- leaving 2000' diesel cap (approx. 24 bbls.) for freeze protect. Bullhead 17 bbls of diesel down tubing for 2000' freeze protect. RU wireline and set dummy Valve in GLM above the packer at XXXX'. 4. RIH with wireline and set plug in "XN" Nipple at the tubing tail @ approx. XXXX' 5. Rig up D/S to tree and pressure test tubing with diesel to 1500 psi. RU to 7-5/8" x 5- 1/2" annulus and bullhead approx. 33 bbls diesel to 2000'. RD DIS. . Set BPV in tree. Close all valves and remove handles. Clean-up cellar and location to prepare for inspections and Summer Operations Shutdown. 8. Hang sign on tree with the following information: ARCO ALASKA, INC ARCO Spark #lA PTD # 200-056 APl # 50-103-20313-01 SHL: 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM TJB 4/21/00 FILE: ARCO Spark #1 i". _,.)POSED ARCO Spark #1 A Final'(' CONFIDENTIAL Revised 4/20/00 A PURPOSE: This proposed procedure will be used to P&A the ARCO Spark #1 A sidetrack once the well testing has been completed. This procedure could be initiated this drilling season before break-up, but probably will be used for final P&A next 2000/2001 drilling season after the well test has been finished. This procedure assumes that there are no freshwater zones within 100' on either side of the surface casing shoe. Logs to be reviewed with the agencies. Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Rig up slickline unit and set dummy valves in GLM's at XXXX', XXXX', and XXXX'. Pull the dummy from the GLM above the packer at XXXX'. RD slickline. 3. Mobilize and rig up DIS for well P&A operation. Bullhead kill weight fluid to the tubing tail. Displace 3-1/2" x 5-1/2 .... annulus to kill weight fluid. RU wireline and set dummy Valve in GLM above the packer at XXXX'. RD wireline unit. . Rig up D/S to tree and establish injection rates into perforations. Mix approx. XX bbls. cement (Class G with additives) and pump down tubing into the peforations. Pump enough slurry (XX bbl) to cover PBTD to tubing tail, leaving remaining slurry in tubing. Hesitate squeeze cement into perfs as required- do not displace top of cement past XXXX' MD. Dipslace cement with kill weight fluid. 6. Rig up SWS "eline" unit and RIH to tag top of cement plug to verify placement. ~, Record and report results. Pressure test tubing to 1500 psi. BLM/AOGCC may want ..,,: ..... to witness tag of cement and pressure test. ~?~,-~ ..... 7. RU cementing unit to 5-1/2" x 7-5/8" annulus. Establish injection rate down annulus with fresh water followed by approx. XX bbls of Arctic Set cement slurry to fill annulus ,~;~:;,~, to casing shoe at 2750' MD plus 100'. . RIH with 2.795 gauge ring to 350'. Set Baker 3-1/2" bridge plug at approx. 310'. Make up SWS tubing puncher and perforate tubing at approx. 300'. POOH and RD SWS "eline" unit. 9. RU D/S and circulate surface cement plug (approx. XX bbls. Arctic Set 1) down tubing into tubing/casing annulus to surface. NOTE: Notify Slope BLM/AOGCC Inspectors before setting surface plug, "~'I 10. Clear lines and shut down pumps. Rig down cementing unit and clean up. 11. Cut off wellhead and all casing strings at 3 feet below original ground level. Send O~.. casing head with stub to Materials for repair / re-dressing. 12. Weld cover plate over the 7-5/8" casing and 3-1/2" tubing. Weld another plate across the 7-5/8" x 16" annulus. Drill 1/8" weep holes in both cap sections. Make sure the two sections are isolated from each other. Weld the following information on the 7- 5/8" x 16" annulus plate: "il ARCO ALASKA, INC ARCO Spark #1 A TJB 4/20/00 ¢'. _..)POSED ARCO Spark #1 A Final CONFIDENTIAL Revised 4/20/00 PTD # 200-056 APl # 50-103-20313-01 SILL: 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM 13. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 4/20/00 FILE: ARCO Spark #1 A TJB 4/20/00 ALASKA OIL AND GAS CONSERVATION COPl~IISSION Paul Mazzolini Exploration Drilling Team Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: SPARK #lA ARCO Alaska, Inc. 200-056 1608' FNL, 2497' FWL, Sec. 08, T10N, R02E, UM 2180' FNL, 2432' FEL, Sec. 08, T10N, R02E, UM Dear Mr. Mazzolini' 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / ~' -/-% day of April, 2000 dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April12,2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill ARCO Spark #1 A Sidetrack Surface Location: 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM or ASP4, NAD 27 coordinates of X=291,158 & Y=5,939,589 Target & BHL: 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM CONFIDENTIAL Dear Commissioner Christenson: ARCO Alaska, Inc. hereby applies for a Permit to Drill (Sidetrack) an onshore exploratory well, the ARCO Spark #1, located approximately 25 miles south and west of the Alpine Development. This well will be accessed via ice road originating at Kuparuk's 3H Pad, drilled using Nabors 19E, completed, tested, and permanently abandoned prior to spring breakup. Attached is the information required by 20 ACC 25.005 (c) for your review. There were no shallow hazards encountered while drilling the ARCO Spark #1 wellbore. The proposed sidetrack will be deviated below the 7- 5/8" surface casing set at 2610' TVD/MD to a bottom hole location approximately 500' to the south of the original wellbore. There will be no reserve pit for this well. Waste drilling mud will be hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. If this well is tested, the produced fluids will either be hauled to Kuparuk for recycling or injected into an appropriate disposal well or the produced fluids will be reinjected into the ARCO Spark #1 A wellbore. Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating, as is the usual case while drilling wells in and near the Kuparuk River Field or the Alpine Development area. This well is located on Federal Lands and will also be under the jurisdiction of the BLM. Please hold information on this well confidential. If you have any questions or require any further information, please contact me at 263-4603 or James Trantham at 265-6434. Sincerely, Paul Mazzolini Drilling Team Leader Exploration/Tarn Team Leader Attachments cc: ARCO Spark #1 A Well File RECEIVED APR 1 2000 Oil a Gas Cons. Commission ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company STATE OF ALASKA ALA.I,'~' -~ OIL AND GAS CONSERVATION COMI~(.'" SION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill E lb Type of Well Exploratory X Stratigraphic Test E Development Oil Re-Entry E Deepen F' Service F Development Gas F single zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 33', Pad 59' feet 3. Address 6. Property Designation Exploration P. O. Box 100360, Anchorage, AK 99510-0360 AA-081802 / AK5147 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) Exploration NPR-A Statewide 1608' FNL, 2497' FWL, Sec. 8, T10N, R2E, UM At top of productive interval (@ TARGET ) 8. Well number Number 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM ARCO Spark #lA #U-630610 At total depth 9. Approximate spud date Amount 2180' FNL, 2432' FEL, Sec. 8, T10N, R2E, UM 4/13/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ARCO Spark #1 MD 8600' 2848' @ TD feet 500 feet 5672 TVD 8500' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 2730' feet Maximum hole angle 17° Maximum surface 1877 psig At total depth (TVD) 4770 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 33' 33' 113' 113' } 243 cu ft '" 9 7/8" 7 5/8" 29.7 L-80 BTC 2031' 33' 33' 2610' 2610'~ 305 sx AS3 plus 240 sx CIG PPf 6 3/4" 5.5" 15.5 L-80 BTC-M 8600' 33' 33' 8600' 8500' 200 sx CIG PPf 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth S,r ctur , RECEIVED Conductor Surface Intermediate Production LinerAPR 1 3 2000 Perforation depth: measured true vertical0il & 6as Coos. Oommi ion 20. Attachments Filing fee X Property plat r-] BOP Sketch X I:~/~lk,~tV~;~h Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis F~ Seabed report E~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~_, ~~ Title LeaderEXpl°rati°n Drilling Team Date O'~"/l~,/O Commission Use Only Permit Number.,,.~_~.~..-.~,~ APl number50./~:~ '~-~ .~..~...~ / ~ '-" (~3, I Appr°val date~l~//¢/~ Isee cover letterfor Conditions of approval - Samples required,.~ Yes ['"'. N M "~o~ //'~ --" other requirements o ua og reqt~ired j~r_ Yes r- No survey required ~ Yes r- No Hydrogen sulfide measures ~ Yes E No ~ Directional Required working pressure for BOPE F' 2M E~ 3M~ r- 1OM F, 15M Other: Robert N. Chdstenson by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE ARCO Spark #lA Sidetrack , Complete P&A of ARCO Spark #1 hole section below 7 5/8" surface casing shoe as per discussions with AGOCC and BLM. 2. Set cement kick off plug across casing shoe from about 2900' - 2500' MD/TVD. 3. Pick up directional BHA with 6 3/4" bit. . Dress cement plug and kick off and drill as per directional program. A Iow solids non dispersed mud system with 2-3% KCI to be used. A 15.9 ppg FIT was established while drilling the ARCO Spark #1 wellbore. o Directionally drill 6 3/4" hole to TD (8600' MD/8500' TVD). A conventional core may be cut in this hole section. 6. Run open hole evaluation logs as requested by G&G. 7. If the well is to be tested, run and cement 5.5", 15.5 ppf L-80, BTC-M production casing. Go to step 8. Pressure test casing to 3500 psi. If the well will not be tested, P&A it per AOGCC regulations. Go to step 12 8. Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU upper tree and test to 5,000 psi. 9. Shut in and secure well. RDMO Nabors 19E. 10. Hook up well for flow testing to surface tanks. Produced fluids to be trucked to Kuparuk production facilities. 11.Test zones as appropriate. When testing is complete, plug and abandon the well as per AOGCC/BLM regulations. 12. Thoroughly clean location and block off access ice road. PM 04/12/00 RECEIVED APR 1,3 .000 Alaska Oil & Gas Coas. Commissio~ Anchorage ARCO Alaska, Inc. Spark #1 Sidetrack Baroid Mud Program (04/11/00) RECEIVED APR 1,3 2000 General Discussion: Ala~0ii&GasCons. Commission An~oralle The well will have a cement plug laid at the 7 5/8" shoe. A 6 3,2' hole will then be drilled from the base of the 7 5/8" surface casing to the final well TD at 9,000'+/- MDFFVD. Prior to setting the cement plug, the rig will spot a thick gel pill for the cement to rest on in this vertical hole. For the 6 3A,, hole, we will displace to a new 9.5 ppg 3% KCI mud after successfully drilling out of the 7 5/8" surface casing and getting a good formation test at the casing shoe. Daily mud treatments need to focus on maintaining effective drilling support and those treatments should be made as required. The mud weight will be increased as necessary, keeping the Iow gravity solids to a minimum. The well will then be displaced again to a new 11 ppg, 6% KCI/GEM GP mud just prior to entering the HRZ. This is an inhibited system which should help stabilize the shales. Special Considerations: 1. Lime and zinc carbonate should be on location for H2S contingency (@ 1 pallet No Sulf and 2 pallets lime). 2. Maintain an adequate barite supply (and other necessary products ) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@ 1000 sxs barite on location at all times). 3. Due to the remote nature of this location, maintain an adequate supply of LCM and the other mud additives, which may be required to support this drilling program. Cement Operations Prior to spotting the cement plug, a 300-350 viscosity ( 50-70 YP) high vis pill should be spotted below the cement placement point. Mix using the base LSND mud and add Aquagel to the required viscosity. The high viscosity will help support the cement and the use of Aquagel as the viscosifier will add more thickness if any cement tries to settle through it. A 20 bbl pill will cover @ 420' of hole ( assuming a 7" hole). Use the current LSND system to drill out and establish the kick off. Treat out cement contamination with Bicarb, SAPP, and thinners as required. Do not displace to the new KCI fluid until certain that a kick off has been established. Displacement to 3% KCI Polymer Baroid Mud Program vl Reduce the yield point of the LSND mud to the 12-15 range on this final circulation and prepare the rig pit system to receive the 3% KCL polymer fluid from the Baroid mudplant and to build the Iow viscosity and high viscosity spacers. Dump and clean the rig pits and flush all pumps, solids control equipment, and lines with fresh water. Take the KCI fluid into the pits and displace according to the following procedure: Pump a 30 barrel Iow viscosity sweep consisting of mud from the previous section which has had the yield point reduced to the 6 to 9 range through additions of Therma Thin/SAPP and dilution. The pH should be lowered to 7.5-8 with PH-6. Maintain a 9.5 ppg weight. Pump a 30 barrel freshwater high viscosity spacer consisting of N-Vis mixed to a yield point of 45 to 65 ( approximately 2.5 ppb N-Vis ) and weighted to 9.5 ppg with barite. Manipulation of the pH to ensure proper polymer dispersion and hydration along with slow mixing of the polymer will prevent the formation of polymer fish eyes. Once the high viscosity spacer is away, begin displacing with the KCI fluid. Pump at rates of no less than 300 gpm, which should allow for efficient displacement. The drill string should be rotated while displacing to disturb any solids. Once displacement has started, the pumps should remain on until clean returns are seen. · Ensure the bit is on bottom as the new fluid exits the drill string. Monitor the flow line for break through of the spacers and the new KCI polymer fluid. Discard the Iow viscosity and high viscosity spacers as they will be contaminated with unwanted drilled solids and cuttings which would compromise the integrity of the KCL system. · Pull inside the casing and clean the possum bellies, under the shakers, and any pits which were taking the dirty returns then begin drilling. Intermediate Interval: , :.~,,:~ Initially, target a mud density of 9.5 ppg and a YP of the fluid in the 10 to 15 rang~:~'nd , ,~,~,~ maintain until out of the sticky clays just below the casing seat. Then, adjust..YP as~:.. ......... · required with Barazan D polymer as needed for efficient hole cleaning. If scr~e'h~ ......, .. blinding from heavy clays is a problem, use DriI-N-Slide treatments. DriI-N-Sli~ie"~",~,. worked the best on the Clover well. Once through the sticky clays, adjust the YP U.P to the 20-25 range with Barazan D to ensure good hole cleaning support. Regular .~.~1 sweeping of the hole with high viscosity sweeps is recommended every 4-6 hours w~.i;te drilling to supplement the hole cleaning ability of the fluid. Flowrates of 300 GPM will provide annular velocities of 151 '/min (4" pipe / 6.75" hole) which should suffi(:Je~.jn this vertical hole. .. '." Refer to the original wellbore for weight requirements at depth. All personal should be aware of the possibility of encountering unexpected pressure. Olose monitoring of return mud weights, pit volumes, and the flowline flow meter are of utmost importance Baroid Mud P,rogram vl at all times and will give warning of changing pressures. Maintain ample stocks of barite on location. Should any signs of settling or sag become evident, immediately elevate the LSYP. Maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the APl filtrate <6 with PAC/Dextrid. Maintain the chlorides in the 13,000-15,000 range with KCI. Daily additions of Aldacide G should be made to control bacterial action. K©H should be used for pH control. Intermediate Hole suggested mud pr()perties Density YP PV 10 S. LS CI APl PH Gel YP FL Initial 9.5 10-15 6-12 2-5 2-4 12- <6 9-9.5 15K HRZ 9.5 20-25 8-14 2-6 3-6 12- <6 9-9.5 15K HRZ to TD Just prior to entering the HRZ formation, an open hole displacement to an 11 ppg, 6% KCI, 5% GEM GP mud will be made. Follow the same displacement guidelines as above, except the high viscosity sweep should be weighted to 11 ppg and then have the viscosity adjusted to the proper range with Barazan. The mud will be delivered with a 200° F HTHP of <10 cc. Maintain this tight filtration to TD of the well with N-Dril HT and Baranex. A 2 ppb treatment with Barotrol will be made once the fluid is in the hole and drilling has commenced. Keep Iow gravity drilled solids to a minimum (<6% by volume if possible). Maintain the MBT at <11 through dilution. Maintain the pH between 9.0-9.5 with KOH. Daily additions of Aldacide G should be made to control bacterial action. The chloride level should be kept in the 28-32K range through additions of KCI. The GEM GP concentration will be maintained at 5% by volume. A 20-25 YP is recommended. Special efforts should be made to keep ECD's and surge/swab pressures to a minimum. This will reduce the chances of lost circulation and also reduce damage to the exposed shales. The 11 ppg mud weight should give @ 100 psi differential on the shales which doesn't allow for much swab. Prior to tripping, a 10-12 ppb Barotrol pill should be considered for spotting across the lower 1,200' of shales. The YP of this pill should be raised to the 35-45 range with N-Vis. Once casing is on bottom, the YP should be reduced to less than 20 to allow for a more efficient cement job and to reduce ECD's while pumping the cement. RECEIVED ~:~ 13 2000 Alaska 0il & Gas Co~s. Commission A~chorage Baroid Mud Program vl Production Hole suqgested mud p'operties ..... Density -Y-P PV ' 'i0 S. Gel 200° PH CL HTHP HRZ 11.0 20-25 12-22 5-10 <10 9-9.5 28-32K _,, TD 11.0 20-25 12-22 5-10 <10 9-9.5 28-32K Trip margin calculations will be performed and the appropriate increase in density will be made prior to tripping out of the hole. Yield Point Trip Margin = 11.7 (Dh-Dp) + Mud Weight to balance 3 % KCI formulation Aquagel- Barazan - Dextrid PAC L BARANEX - Caustic - Baroid - 3 ppb 1.0 ppb ( or as needed for 25 YP ) 2 ppb 1 ppb 3 ppb 0.15 ppb (to a 9.0-9.5 pH) to a 9.5 ppg 6 % KCI/GEM formulation N-Dril HT+ - Baranex - N-Vis - KC1 - GEM GP - Barite - KOH - Barotrol - 4 ppb 3 ppb .7 ppb to a 20-25 YP 20.5 ppb 5% v/v to an 11 ppg to a 9.0-9.5 pH 2 ppb to be added at the rig RECEIVED 13 000 Naska 0il & Gas Cons. C0mmia~ Baroid Mud Program vl ARCO Spark #lA Sidetrack PRESSURE INFORMATION AND CASING DESIGN (Per 20 AAC 25.005 (c) (4) DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of ARCO Spark #lA Sidetrack. Casing Fracture Pressure Pore ASP Drilling Size Gradient Gradient Pressure 16" i 113' TVD /113' MD ' 11.0ppg ' 8.5 ppg 52 psi ~ N/A 7 5/8" i 2610' TVD / 2610' MD i 15.9 ppg i 9.5 ppg 1500 ps ! 1870 psi 5 1/2 8500 TVD/8600 MD ~ 17.6 ppg 10.8 ppg ~ 4770psl N/A Expected Maximum Mud Weights: 6 3/4" Production Hole to 8500' TVD / 8600' MD: 11.0 ppg Procedure for calculating Anticipated Surface Pressure (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)- 0.11] D Where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft. RKB OR RECEIVED APR 2000 Ala~a Oil & ~ls ~s. ~mml~gion 2) ASP = FPP-(0.11 x D) Where: FPP = Formation Pore Pressure at the next casing point -1- ARC( .;park #lA Sidetrack PRESSURE INFORMATION AND CASING DESIGN ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)- 0.11] D = [(11 x 0.052) - 0.11] x 113 = 52 psi OR . ASP = FPP- (0.11 x D) = 1300 - (0.11 x 2610') = 1012 psi Drilling below surface casing (9-5/8") ASP = [(FG x 0.052)- 0.11]D = [(15.9 x 0.052)- 0.11] x 2610' = 1870 psi OR ASP = FPP- (0.11 x D) = 4770 - (0.11 x 8500') = 3835 psi <. ECEIVED ~.o I~' APR 15 ~000 .~aska 0~1 & Gas Co~s. 6omm~ Casing Performance Properties, ~ ~ Tens e Strength i i i i Internal i ............................................................................................. 8ze i We g. ht Grade Oonnection i Yield Oolla.p,,se i Joint i Body.. II : : ; ' : ' 7 5/8 29.7 ppf L-80 BTC 6890 ,p..,s~ 4790 .p..s~ ~ 721 M 683 M .............. ..5........!,..,/....2..:: ............... i .............. ,,1.,..5...,~..,,5.,,,.,p....p.,.¢. ............. .[ ............... ...L.:.,8....,0.. ............... i ....................... ...B...!...C.,,:..M.... ........................ i ............ Z...o....,.o.,...o....,...p..,..s,.! ............. ,[ ............ ...4.,~...9...~.....p.....s,.! ............. L_2,.?....8_..M... .................. ,,3..,..6...!_.M__J Casing Setting Depth Rationale 16"-113' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 7 5/8"-2618' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. 5 1/2"-8500' TVD RKB Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. -2- ARCO Spark #lA Sidetarck PRESSURE ANALYSIS AND PREDICTION (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the ARCO ARCO Spark #1 well as required by AOGCC regulations. This information was submitted in the original permit package. ARCO does not expect to encounter abnormal pressure from any zones while drilling the ARCO Spark #lA Sidetrack. The prediction is based on an evaluation of offset wells North Inigok Test Well #1, West Fish Creek #1 and South Harrison Bay #1. Attached are the following: Mud weight versus depth graph for these wells. Pore pressure, frac pressure and anticipated mud weight graph. Estimated Timing 1 day to set kick off plug across 7 5/8 casing shoe from 2900' - 2500' MD/TVD. 6 days to kick off and drill to TD 1 day to E-line logging 4 days to run casing and completion 4 days to test well 2 days to P&A RECEIVED ~'.PR 1,3 2000 Alaska 0il & Gas Cons. Commission Anchorage 2OOO 4000 6O00 8000 10000 12000 North Inigok Test Well #1 i'~ '~- '~- '~' '~ I,. ww w~ .~ w~ .,w .,~ .~ wi..w .w .,w .~k i I I I I I I I I I I I I I I ~ ~ [ ] ~ ~ ~ ~ ~ I I I~ I I I I I I I ---- ~ I ~ ~ ~ I I ~_~- --1--~--I--~- 4 l-- q--~q--P _1_ ~ _1_ ~-- --p 4--1-- · ---- ~ q-- ~ ~ .......... J.. ~=-.=~,/o~/o, ~/..~;~+1 ..... ~ ................... , ................... 11.8 V~ III /I /l~ff/u/ // uiiilO[ i i i i i i i I IVl0 ~ I ~ ~ [ ~ ~ , ~ ~ ~ ~ ~ ~ ', , , ' LJ_LJ__!__L---J--I .... 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I1 ~._~_,___~ _I~_i~_,_, .... ~ ~ ..... ~, .... ,~ ___%_~. .... ~ ........... ~D.qT#2~ ..... 9.2 - -~- - - ~ ............. i i I /--~Uh i~t~l~ i i I ~ I f i i i i i i i i i i i / ~ J I I i i I i ~ i _LLi_:_JJ_:_:__:_LLL I-:-:-:-[:-:-',-',--,--,-- -,-,-q---:-~::-,±+~ q:~-:-',--i-:-~-~¢~q--- '-' '"' ', q ...... ,'--,'-,'-t~-q-:-',-:--:-:-,'-~ ~ ~ I ! I I I I I I I I:J I I I I I i [ , -'~4, ~ ,,,, ,,,, ,,.~, ,~ii,,.,,,, ,, ........ ,,, , , ,,,, ~ ,l~ascu~mun ,, ,,,, I,',' '''' '''' ,,,,-- 9.0 rrT~- -l-l-i-i---i-r-r ~ ~-i-J~-I-i-i--i-rrT T-I-I~ .... I--I---FTTT --I --I --I -- -- -- I-- I-- I-- r 'TT-T~.--1--[ ....... I-i-i---i-[-r-I-I-rrT'~- -1-1-1-1--]-I-rrT~-I-I- ,,,, ~,,, ,,,, ,i~,,,j,,,, ,,,, ,,,, ''" ''" '" ..... "'"~"' :::: :::: ::: ~ ::: :::: :::: :::: 8.8 _- __ FI ~ ~ ........... 8.6 ' ! ! I I--I----I--! ! ~ I ' I--I--I--I-- -! I I I ! I I I-- --I~l--I I I I I I I I I IIIII ! III IIII II!I ~1~ ~l I I I / .L.L---L -l------I----I--bt-I.- 4..4-4.4--4--~--,--, ..................... . , , T_.~.. , , s__ 8.4 I ! I I ! I ! I I I I I ! I I I I I I I i i I I I I I I IIII/ I I ! i ! ~ ii , , , - - I I I I I I I I I I I I I I ! I I I I I I I I I I I I ! I I I I III~ IIII IIII la ~ .............. ................................................... 75' , , , ........ , ,,'¢~ , ,, , ,,,, , , .... , ....... ~- ........... I LOggeoI -- ''' 8.2 I I I I I I I I t I I I I I I I I I I I I I I I I I I ! I I I I I ! I I I I I I I I ! I I I I I I I ! I I I I I I I I I I1-i~'~'-~'~--~ 12OOO 0 5 10 15 20 25 30 35 40 45- 50 55 60 65 70 75 80 85 90 95 100 TIME TO DRILL (DAYS) ' jt 9/99 2400 ARCO Alaska, I] c. Structure: Spark #1 Field : Exploration Well: SprklA Location : North Slope, Alaska 2700 3000 3300 3600 3900 4200 4500 ~ 4800 ~-~ 5100 54-00 5700 6000 6300- 6600 6900 7200 7500 7800 8100 8400 8700 KOP - Sidetrk Pt 2.17 4,61 7.10 DLS: 2.50 dog per 100 ft 9.59 12.08 14.58 EOC 16.50 Begin Angle Drop 15.00 13.50 12.00 10.50 9.00 7,50 6.00 4.50 3.00 1.50 DLS: 1,50 dog per 100 ft <- West (feet) 160 120 80 40 0 I I I I I I I I I I EOD Tgt Spark #1^ Tgt 11-Apr-2000 9000 , , 300 0 300 600 900 Verflcol Secflon (feet) Azimuth 185,07 wlth reference 0.00 No 0.00 E from slot #1 RECEIVED ;!.?R 1:5 ?_000 NaSa Oil & Gas Cass. Comm~ 40 80 1 f i KOP - Sidetrk Pt EOC Begin Angte Drop Tgt Spark #lA Tgt 11 -Apr-200¢ 120 160 200 0 240 ,-4- 280 "~ 320 I V 360 400 440 480 520 . - 560 600 Created by jane= Date platted: 12-Apr-2000 PIct Reference Is Spark #lA Version 1~2, Coor~lnotN are in feet reference slat ~1. True Vefflcol ~ptha am~K6 (Nabore 19E), IN'r~9 RECEIVED P.p~ 13 2000, ~~----.,--~~u a~aska, Inc. '1' '- Structure: Spark ~I Well : SprklA PROFILE Point MD Inc KOP - Sidetrk Pt 2730.00 0.74 EOC 3398.46 17.04 Begin Angle Drop 4456.54 17.04 COMMENT DATA Dir TVD North East 247.79 2729.97 -1.19 -8.89 185.07 3388.41 -101.09 -21.65 185.07 4580.72 -404.02 -48.55 V. Sect Deg/lO0 1 97 0.00 102 61 2.50 406 74 0.00 EOD 5572.28 0.00 185.07 5500.00 -571.04 -65.38 574 40 1.50 Tgt 8072.28 0.00 185.07 8000.00 -571.04 -63.38 574 40 0.00 TD 8600.00 0.00 185.07 8527.72 -571.04 -63.38 574 40 0.00 ,1" 5000 psi BOP Stac Nabors Rig 19E Kill Line 4 RECEIVED 1 ;.?R 2000 Alaska Oil & Gas Cons. Commission Anchorage Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. I Choke Line BOP Stack Test ~2. Che--~ 1. F~illBcOktPhSattaa(~haor~dd_dmoawninfO~reWiwthsaWraetfeurilYretracted. Predetermine 1 depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. L 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi Iow for 5 minutes :3 and 5000 psi high for 10 minutes. DO not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 30 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. 1. 16" Starting Head 2. 11" 5000 psi Through Bore System Wellhead 3. 11" 5000 psi Hydril SGL Gate (pipe rams), 4-1/16" 5000 psi Side Outlets w/Manual Locks 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic.gate and one 3" 5000 psi Manual gate 2 Kill valves - one 2" 5000 psi Hydraulic gate and one 2" 5000 psi Manual gate 1 Check valve in Kill Line - 5000 psi 5. 11" 5000 psi Hydril Double Ram (pipe rams on top, blind on bottom), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 6. 11" 5000 psi Hydril Annular Preventer, Flange Connection jt Rev 01/20/00 ARCO Alaska, inc. AAI PAYABLES P.O. Box 102776 ~ Anchorage, AK: 995 10-2776 PAY TO THE ORDER OF: 73-426 839 ~..~. ~.". 205093840 MARCH 13, 2000 0997579 *** VOID AFTER 90 DAYS *** STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE EXACTLY *********** I00 DOLLARS AND O0 CENTS $*********** 100.00 The First National Bank of Chicago~0710 ~ Chicago. Illinois ~ / 0~ Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 205093840 Oqq? 5 SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO, AA-081819 ARCO ALASKA, INC. ~e~ee'~ Signa~r/e/ James M. R,,u'ud Attorney-imFact Lessee's Name (Print or Type) & Title January 31,2000 Date ARCO Alaska, Inc. Company Name THE UNITED STATES OF AMERICA STATE OF ALASKA This certifies that on the 31st day of January, 2000, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared James M. Ruud, to me known and known to me to be the person described in, and who executed the foregoing lease, · who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. N~ta~ublic r'~'~*-- My Commission expires: 6-8-2003 SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA-081819 ANADARKO PETROLEUM CORPORATION Lessee's S~gnature Todd L. Liebl Agent and Attorney-in-Fact Lessee's Name (Print or Type) & Title January c¢~,, 2000 Date Anadarko Petroleum Corporation Company Name THE UNITED STATES OF AMERICA ) ) SS. STATE OF TEXAS ) This certifies that on the .,~,g/~'~ day of January, 2000, before me, a notary public in and for the State of T. exas, duly commissioned and sworn, personally appeared Todd L. Liebi, to me known and known to me to be the person described in, and who executed the foregoing lease, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. NOTARY PUBLIC State of Texas Nota-~,~ublic '~/-- My Com~ mission expires: SPECIAL STIPULATION(S) FOR LEASE AA-081819 Standard Lease Stipulation Numbers 1-24, 26-28, 30, 32, 34-38, 40-44, 46-48, 51, 53, 55-79, as identified and delineated in the Final Record of Decision and Detailed Statement of Sale, pertain to all leases created from the National Petroleum Reserve-Alaska Sale 991, and are herein incorporated by reference and made a part of this lease. The following Special Stipulation(s) is/are specifically delineated in the Record of Decision and Detailed Statement of Sale as pertaining to this tract, and is/are hereby made a part of this lease. This/these is/are a direct quote(s) from the Detailed Statement of Sale document. All references to Exhibit A pertain to Exhibit A of the Detailed Statement of Sale. No part of this lease is identified as Exhibit A.: III. The "No Permanent Oil and Gas Facilities" and "No Permanent Oil and Gas Facilities within 1/4 mile of Fish-Bearing Lakes Stipulations," Number 39, are identified on each specific tract in Exhibit A hereof. They pertain to some of the tracts in both Area A and Area B. { Attatchment B ~" ' UNITED STATES ( ISerial No. DEPA R ~"i'MENT OF THE INTERIOR I BUREAU OF LAND MANAGEMENT ALASKA STATE OFFICE OFFER TO LEASE AND LEASE FOR OIL AND GAS AA-081819 The undersigned (reverse) offers to lease all or any of the lands in Item 2 that are available for lease pursuant to the Mineral Leasing Act of 1920, as amended and supplemented (30 U.S.C. 181 et seq.), the Mineral Leasing Act for Acquired Lands of 1947, as amended (30 U.S.C. 351-359), the Attorney General's Opinion of April 2, 1941 (40 Op. Atty. Gen. 41), or the Naval Petroleum Reserve Production Act of 1976 (42 U.S.C. 6501 et seq.), as amended. 1. Name Street READ INSTRUCTIONS BEFORE COMPLETING ARCO Alaska Inc. (78%) P.O. Box 100360 Anchorage, Alaska 99510 and Anadarko Petroleum Corporation (22%) P.O. Box 1330 Houston, Taxes 77251 City, State, Zip Code 2. This application/offer/lease is for Public Domain Lands in the National Petroleum Reserve - Alaska (NPR-A) Legal description of land requested: *Tract No.: 991-H-070 *SEE INSTRUCTIONS BELOW PRIOR TO COMPLETING PARCEL NUMBER AND SALE DATE T. R. Meridian State TllN, R2E Umiat SE 1/4 Amount remitted: Filing fee $ Rental fee $ 28,780.00 DO NOT WRITE BELOW THIS LINE *Sale Date (m/d/y): May / 05 / 1999 County Total acres applied for 5,756 Total $ 3. Land included in lease: T. R. TllN, R2E SE 1/4 Meridian Umiat State County Total acres in lease 5,756 Rental retained $ 28,780.00 This lease is issued granting the exclusive right to drill for, mine, extract, remove and dispose of all the oil and gas (except helium) in the lands described in Item 3 together with the right to build and maintain necessary improvements thereupon for the term indicated below, subject to renewal or extension in accordance with the appropriate leasing authority. Rights granted are subject to applicable laws, the terms, conditions, and attached stipulations of this lease, the Secretary of the Interior's regulations and formal orders in effect as of lease issuance, and to regulations and formal orders hereafter promulgated when not inconsistent with lease rights granted or specific provisions of this lease. NOTE: This lease is issued to the high bidder pursuant to his/her duly executed bid or nomination form submitted under 43 CFR Part 3130 and is subject to the provisions of that bid or nomination and those specified on this form. The parties agree ~ 1) that this lease form replaces the previous lease tbrm executed by the parties for this lease; ~2) that this lease will be deemed to have been issued pursuant to this lease form; (3) that this lease will be deemed to have been executed as of the original date each party cxecu{cd thc previous lease form: and (4) that the effective date of this lease is Sel>tember 1. 1999. THE UNITED STATES OF AMERICA Type and primary term of lease: by [ ] Noncompetitive lease (ten years) [ ] Competitive lease (ten years) [ X ] Other Competitive NPR-A Lease (ten years) (Signing Officer) Sr. Leasable Minerals Adjudicator (Title) (Date) EFFECTIVE DATE OF LEASE September 1, 1999 AK-3130-1 (April 1999) 4. (a) Utfdersigned certifies that (1) offeror is a citizen of thel, ~[States: an association of such citizens: a municipality; or a corl~~ organtzeo under the taws of the United States or of any State or TerritOry thereof; (2) all parties holding an interest in the offer a~3mpliance with 43 CFR Part 3100 and the leasing authorities: (~,,,~or is not considered a minor under the laws of the State in which the lands covered by this offer are located. · (b) Undersi~med agrees that signature to this offer constitutes acceptance of this lease, including all terms, conditions, and stipulations of which offeror has been given notice, and any amendment or separate lease that may include any land described in this offer open to leasing at thc time this offer was filed but omitted for any reason from this lease. The offeror further agrees that this offer cannot be withdrawn, either in whole or in part. This offer will be rejected and will afford offeror no priority if it is not properly completed and executed in accordance with the regulations, or if it is not accompanied by the required payments. 18 U.S.C. Sec. 1001 makes it a crime for any person 'knowingly and willfully to make to an>, Department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. NOTICE The Privacy Act of 1974 and the regulations at 43 CFR 2.48¢d) provide that you be furnished with the following information: AUTHORITY: 50 Stat. 900; 25 U.S.C. 500 PRINCIPAL PURPOSE: The primary uses of the records are (1) to determine your qualification to receive an oil and gas lease: and (2) to provide information concerning oil and gas leases for administrative and public use. ROUTINE USES: BLM and the Department of the Interior (DOB may disclose your information on this form: (1) to members of the public who have a need for the information that is maintained by BLM for public record; (2) to the U.S. Department of Justice, court, or other adjudicative body when DOI determines the information is necessary, and relevant to litigation; (3) to appropriate Federal, State, local or foreign agencies responsible for investigating, prosecuting violations, enforcing or implementing this statute, regulation, or lease: and (4) to a congressional office when you request the assistance of the Member of Congress in writing. EFFECT OF NOT PROVIDING THIS INFORMATION: If you do not furnish all the information required by this form, your application may be rejected. Duly executed this day of , 19 SEE ATTACHED SIGNATORY PAGE(S) (Signature of Lessee or Attorney-in-fact) LEASE TERMS Sec. 1. Rentals - Rentals shall be paid to the proper office of lessor in advance of each lea.ge year. Annual rental rates per acre or fraction thereof are: (a) Noncompetitive lease, $1.50 for the first 5 years; thereafter $2.00: (b) Competitive lease, $1.50; for the first 5 years; thereafter $2.00; (c) Other, see attachment; or for NPR-A: $5 for Area A; $3 for Area B: as specified in the detailed statement of sale. If this lease or a portion thereof is committed to an approved cooperative or unit plan which includes a well capable of producing leased resources, and the plan contains a provision for allocation of production, royalties shall be paid on the production allocated tO this lease. However, annual rentals shall continue to be due at the rate specified in (a), (b), or (c) for those lands not within a participating area. Failure to pay annual rental, within 30 days after receipt of a Notice of Delinquency shall cause this lease to terminate. Rentals may be waived, reduced, or suspended by the Secretary upon a sufficient showing by lessee. Sec. 2. Royalties - Royalties shall be paid to proper office of lessor. Royalties shall be conCuted in accordance with regulations on production removed or sold. Royalty rules are: (a) Noncom~titive lease, 12½%; (b) Competitive lease, 12V2%; (c) Other, ,see attachment, or for NPR-A: 16%% for Area A; 12.5% for Area B as specified in the detailed statement of sale. Lessor reserves the right to specify whether royalty is to he paid in value or in kind, and the right to establish reasonable minimum values on products after giving lessee notice and an opportunity to be beard. When paid in value, royalties shall be due and payable on the last day of the month following the month in which production occurred. When paid in kind, production shall he delivered, tmless otherwise agreed to by lessor, in n~rehantable condition on the premises where produced without cost to lessor. Lessee shall not be required to hold such production in storage beyond the last day of the month following the month in which production occurred, nor shall lessee be held liable for loss or destruction of royalty oil or other products in storage from causes beyond the reasonable control of the lessee. Minimum royalty in lieu of rental of not less than the rental which otherwise would be required for that lease year shall be payable at the end of each lease year beginning on or after a discovery in paying quantities. This minimum royalty may be waived, suspended, or reduced, and the afore royalty rates may be reduced, for all or portions of this lease ff the Secretary determines that such action is necessary to encourage the greatest ulttmate recovery, of the leased resources, or is otherwise justified. An interest charge shall be assessed on late royalty payments or underpayn~nts in accordance with the Federal Oil and Gas Royalty Management Act of 1982 (FOGRMA) (30 U.S.C. 1701). Lessee shall be liable tbr royalty payments on oil and gas lost or wasted from a lease site when such loss or waste is due to negligence on the part of the operator, or due to the failure to comply with any rules, regulations, order, or citation issued under FOGRMA or the leasing authority. Sec. 3. Bonds - A bond shall be flied and maintained for lease operations as required under regulations. Sec. 4. Diligence, rate of development, unitization, and drainage - Lessee shall exercise reasonable diligence in developing and producing, and shall prevent unnecessary damage to, loss of, or waste of leased resources. Lessor reserves the fight to specify rates of development and production in the public interest and to require lessee to subscribe to a cooperative or unit plan, within 30 days of notice, ff deemed necessary for proper development and operation of area, field, or pool embracing these leased lands. Lessee shall drill and produce wells necessary to protect leased lands from drainage or pay compensatory royalty for drainage in amount detem'fined by lessor. Sec. 5. Documents, evidence, and inspection - Lessee shall file with proper office of lessor, not later than 30 days after effective date thereof, any contract or evidence of other arrangement for sale or disposal of production. At such tin~s and in such form as lessor may prescribe, lessee shall, furnish detailed statements showing anaounts and quality of all products removed and sold, pwceeds therefrom, and amount used for production pml~oses or unavoidably lost. Lessee may be required to provide plats and schematic diagrams showing development work and improvements, and repons with respect to parties in interest, expenditures, and depreciation costs. In the form prescribed by lessor, lessee shall keep a daily drilling record, a log, information on well surveys and tests, and a record of subsurface investigations and furnish copies to lessor when required. Lessee shall keep open at all reasonable tim~s for inspection by any authorized officer of lessor, the leased premises and all wells, improvements, machinery, and fixtures thereon, and all books, accounts, maps, and records relative to operations, surveys, or investigations on or in the leased lands. Lessee shall maintain copies of all contracts, sales agreements, accounting records, and documentation such as billings, invoices, or similar documentation that support costs claimed as manufacturing, preparation, and/or transportation costs. All such records shall be maintained in lessee's accounting office for future audit by lessor. Lessee shall maintain required records for 6 years after they are generated or, ff an audit or investigation is underway, until released of the obligation to maintain such records by lessor. During existence of this lease, information obtained under this section shall he closed to inspection by the public in accordance with the Freedom of Ird'ormation Act (5 U.S.C. 552). Sec. 6. Conduct of operations - Lessee shall conduct operation in a manner that minirmz' es adverse tmPacts to the land, air, and water, to cultural, biological, visual, and other resources, and m other land uses or users. Lessee shall take reasonable measures deemed necessary by lessor to accomplish the intent of this section. To the extent consistent with lease fights granted, such measures may include, but are not limited to, modification to siting or design of facilities, timing of operations, and specification of interim and final reclamation maasures. Lessor reserves the right to continue existing uses and to authorize future uses upon or in the leased lands, including the approval of easeme.nts or rights-of-way. Such uses shall be conditioned so as to prevent unnecessary or unreasonable interference with rights of lessee. Prior to disturbing the surface of the leased lands, lessee shall contact lessor to he apprised of procedures to be followed and modifications or reclamation measures that may be necessary. Areas to b,e disturbed may require inventories or special studies to determine the extent of impacts to other resources. Lessee may be required to complete minor inventories or short term special studies under guidelines provided by lessor. If in the conduct of operations, threatened or endangered species, objects of historic or scientific interest, or substantial unanticipated environn~ntai effects are observed, lessee shall immediately contact lessor. Lessee shall cease any operations that would result in the destruction of such species or objects. Sec. 7. Mining operations - To the extent that impacts from mining operations would be substantially different or greater than those associated with normal drilling operations, lessor reserves the fight to deny approval of such operations. Sec. 8. Extraction of helium - Lessor reserves the option of extracting or having extracted helium from gas production in a manner specified and by means provided by lessor at no expense or loss to lessee or owner of the gas. Lessee shall include in any contract of sale of gas the provisions of this section. Sec. 9. Danxages to property - Lessee shall pay lessor l'br damage to lessor's improvements, and shall save and hold lessor ham,.less from all claims for damage or harm to persons or property as a result of lea.se operations. Sec. 10. Protection of diverse interests and equal opportunity - Lessee shall pay when due all taxes legally assessed and levied under laws of the State or the United States; accord all employees complete freedom of purchase; pay all wages at least twice each month in lawful money of the United States, maintain a safe working environment in accordance with standard industry practices; and take measures necessary to protect the health and safety of the public. Lessor re,ryes the right to ensure that production is sold at reamnable pti to prevent n×)nopoly. Iflcssce o,peYates a p~peline, or owns control.ling interest in a pipeline or a company operating a pipeline, which nm',' be · operated accessible to oil derived fi'om these leased lands, lessee shall comply with section 28 of thc Mineral Lea.stag Act of 1920. Les~e shaU comply wiflt Executive Order No. 11246 of September 24. 1965, as an~nded, and regulations and relevant orders of the Secretary. of Labor issued pursuarlt thereto..Neither lessee nor lessee's subcontractors shall mare!am segregated facilities. During the performance of this ~ease, the Lessee must comply rUBy ,,,.,Rh paragraph.~ I 1 ) through (7) of 41 CFR 60-1.~a) with respect to employment dimnmination on the basis of race. color, religion. ~x or national origin, and must incorporate the requirements set forth in those para~ raph$ in every, subcontract or purchase order, as provided by that regulation. Sec. 11. Transfer of lea~m interests and relinquishment of lease - As required by regulations, lessee shall file with lessor any assignment or other transfer of an interest in this lease. Les~c nmy relinquish this lease or an), legal subdivision by fding in the proper office a written rel. inquishn-~ent. ',,. rich shall be effective a.~ of the date of filing. subject to the continued obligation of the lessee and surety to pay all accrued rentals and royalties. Sec. 12. Delivery of premises - A~l~h tin'~e n~ all or pot'lions of this lease are returned to lessor, lessee shall place affected wells in condition for suspen.~on or abandonnznt, recla.u'n the land as specified by lessor and. within a reasonable period of nme. remove equipment and u'nprovements not deemed nece,~a"y by. lessor for preservation of producible wells. Sec. 13. Proceedings in case of default - If les~e fails to comply with any pmvisionx of this lease, and the noncompliance commues for $0 days ~'ter wmten notice thereoL this lease shall be subject to cancellation u.l'fless or until the leasehold con!ams a well capable et' production ofoil and ga~ in paying quantities, or the lease i~ corem.it!ed to an approved cooperative or un. it plan or commun, itization agreement which con!ams a well capable of production o! unitized substances m paying quantities. This provision shall not be construed to prevent the exerci~ by lessor of an), other legal an(" equitable remedy, including wa~,er of the default. ,As such remedy or waiver shall prevent later cancellation for the same default occurring at any other tirm. Lessee shall he subject to applicable provisions and penalties of FOGRMA (30 U.S.C. 1701). Sec. 14. Heirs and successors-in-mterest - Each obligation of this leac,;e shall extend to and be binding upon, and every, benefit hereof shall inure to. the heirs, executors, adm. irfistrators, successors, beneficiaries, or assignees of the respective parties hereto. INSTRUCTIONS A. General 1. The front of this form is to be completed only by parties filing for a noncompetitive lease. The BLM will complete front of form for all other types of leases. 2. Entries must be typed or printed plainly in ink. Offeror must sign Item 4 in ink. 3. An original and two copies of this offer must be prepared and filed in the proper BLM State Office. See regulations at 43 CFR 1821.2-1 for office locations. 4. If more space is needed, additional sheets must be attached to each copy of the form submitted. B. Special: Item 1 - Enter offeror's name and billing address. Item 2 - A single tract number and Sale Date shall be the only acceptable description. Item 3 - This space will be completed by the United States. PAPERWORK REDUCTION ACT STATEMENT The Paperwork Reduction Act of 1990 (44 U.S.C. 3501 et seq.) requires us to inform you that: 1. This information is being collected pursuant to the law. 2. This information will be used to create and maintain a record of oil and gas lease activity. 3. Response to this request is required to obtain a benefit. EFFECT OF NOT PROVIDING INFORMATION - If all the information is not provided, the offer nmy be rejected. See regulations at 43 CFR 3130. AK-3130-1 (April 1999) WELL PERMIT CHECKLIST COMPANY ,~'~_.~ WELL NAM~~/,~/PROGRAM: exp 4// dev redrll serv wellbore seg ann. disposal para req FIELD &'POOL W: ',~, INIT CLASS ~-~-x.,~,,/ ~-(.,~;/~/'c_~. i//"'~); /''') GEOL AREA /~-'~/?) UNIT# ~ ,~, ON/OFF SHORE v ,,.. x--~==.~ - - - ADMINI~'RATION 1. Permit fee attached ....................... iil~, 2. Lease number appropriate ................... ,~II~.~. 3. Unique well name and number .................. 1!~" 4. Well located in a defined pool 5. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... 71 Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... Operator only affected party ................... 101 Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ ~,P. PR DATE 12. Permit can be issued without administrative approval ...... ,.~ ..z. lL. /~. Z:D 13. Can permit be approved before 15-day wait ........... .E. NGINE,~ERING 14. Conductor string provided ...................~~¢:~'~N -v~ .'r. 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... . 19. Casing designs adequate for C, T, B & permafrost ....... .:~ 20. Adequate tankage or reserve pit ................. ':.) N _ 21. If a re-drill, has a 10-403 for abandonment been approved... ":. 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 APPR '! DATE 26. BOPE press rating appropriate; test to .¢',,0~O psig. (~ N {~~ f-rdrczlt(e~ 27. Choke manifold complies w/APl RP-53 (May 84) ........~ N ' 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLO~,.Y 30. Permit can be issued w/o hydrogen sulfide measures ..... Y~'"h-~,. . , .~ ~ . , _ _. ~.. . ,,. ,, ,.. 31. Data presented on potential overoressure zones'~. ' ..... ~~?~,,-. ~-.,':" ¢-- ~ ~.,-/'~ .~ _,5~,,~-~./,~/.,, /°c2'~_ '/'-~¢'~ ~ .Sz:~c?., ~ -/¢',¢.>/~,-,--~,~,..~ 32. oe,sm,c aHaly~ Ul 5lli;lllUW ga~5 ZUIl~5,,~ .~7~,. .......... _ '1'1,,~ I~l~lc..J~.. .,,~,~ _~,,~.. ,¢~., .. .... ,z~ _,~.../' x,.~. ,~,,~..~_,,~,- /' ~ ' ,-~ - ..~ ~wz~Z ¢ ,'. ~. , / ~__~/ 33. Seabed cond,t,on survey (,f off-shore) ............ .d,/;'~'- ~ N ~/;~-.,. ~ / ~,~,/~ ,~,~--~. ~-z~-g=3~&,, ~3d~ ..?y.~,~ ,,~ ~;,4~[,~ ,4,~ ~,~..~o"$ ,~¢.~., , -~ 34. Contact name/phone for weekly progress reports [exploratory only]~ N . L.~z-..~x.~ .~",~-, ~.~ 2-~-- ~j_~ .~ ANNU~ DISPOS. AL35. With proper cerr~el~ting records, this plan '.i!~i~; (A) will contai/n~vaste in a..~.ui~?~eceiving zone' . ...... Y N APPR ;..:='DATE (B) w,llno_tz, unta~..,~.~~waste... Y N (C) wil,I/~~~tegrity of thee/well usedf~p~'osal; Y N (D) wi im ' overyfroma Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC//~nn~ar COMMISSION: Comments/Instructions: 1:7 O Z O -I c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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, Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jun 06 10:48:47 2000 Reel Header Service name ............. LISTPE Date ..................... 00/06/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 00/06/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 0t Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER Exploration MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MM-00021 P. SMITH R. SPRINGER/ Spark iA 501032031301 Arco Alaska, Inc. Sperry Sun 05-JUN-00 MWD RUN 2 AK-MM-00021 P. SMITH R. SPRINGER/ 8 10N 02E 1608 2497 94.02 92.85 55.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.750 16.000 113.0 2ND STRING 6.750 7.625 2610.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS l&2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO- DENSITY (SLD). 3. RESISTIVITY DATA FROM 6130'MD, 6160'TVD TO 6888'MD, 6818'TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN THE HOLE FOR MWD RUN 2 OWING TO EARLY MEMORY-FILL OF THE EWR TOOL ON MWD RUN 1. THIS DATA IS PRESENTED MERGED WITH MWD RUN 1 DATA. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH W. CAMPAIGN OF PHILLIPS ALASKA, INC. ON 05/09/00. NO WIRELINE REFERENCE LOG IS AVAILABLE. MWD DATA IS PDC. THIS WELL IS TIED INTO SPARK %1 AT THE KICKOFF POINT OF 2730'MD, 2730'TVD USING THE DEEP PHASE RESISTIVITY CURVES. 5. MWD RUNS 1-2 REPRESENT WELL SPARK %lA WITH API%: 50-103-20313-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8522'MD, 8445'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSOPRPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD DENSITY: 11.0 PPG MUD SALINITY: 25000 PPM CHLORIDES FORMATION WATER SALINITY: 15000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NPHI NCNT FCNT RHOB DRHO PEF GR RPX RPS RPM RPD FET SROP $ START DEPTH 2611.0 2611 0 2611 0 2627 0 2627 0 2627 0 2646 5 2653 5 2653 5 2653 5 2653 5 2653 5 2701 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ STOP DEPTH 8431.0 8431.0 8431.0 8446.0 8446.0 8446.0 8468.0 8475.0 8475.0 8475.0 8475.0 8475.0 8522.0 EQUIVALENT UNSHIFTED DEPTH -- BIT RUN NO MERGE TOP MERGE BASE 1 2611.0 6935.0 2 6843.0 8522.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 2611 8522 ROP MWD FT/H 0 3802.79 GR MWD API 45.99 185.7 RPX MWD OHMM 1.14 31.413 R?S MWD OHMM 1.12 44.18 R?M MWD OHMM 1.02 42.09 RPD MWD OHMM 1.16 34.02 FET MWD HOUR 0.2841 40.9928 NPHI MWD PU-S 12.21 52.7 FCNT MWD CNTS 119.5 1178.4 NCNT MWD CNTS 14268.8 35427.5 RHOB MWD G/CM 2.112 3.447 DRHO MWD G/CM -0.124 1.023 PEF MWD BARN 1.02 14.25 Mean Nsam 5566.5 11823 89.7689 11642 108.072 11644 4.62464 11644 4.82309 11644 4.80987 11644 4.86448 11644 5.98613 11644 31.7991 11641 315.275 11641 21177 11641 2.50963 11639 0.111314 11639 4.79079 11639 First Reading 2611 2701.5 2646.5 2653.5 2653.5 2653.5 2653.5 2653.5 2611 2611 2611 2627 2627 2627 Last Reading 8522 8522 8468 8475 8475 8475 8475 8475 8431 8431 8431 8446 8446 8446 First Reading For Entire File .......... 2611 Last Reading For Entire File ........... 8522 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT FCNT NPHI PEF DRHO RHOB GR RPD FET RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2611.0 2611 0 2611 0 2627 0 2627 0 2627 0 2646 5 2653 5 2653 5 2653 5 2653 5 2653 5 2701 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON STOP DEPTH 6842.5 6842.5 6842.5 6857.5 6857.5 6857.5 6879.0 6888 0 6888 0 6888 0 6888 0 6888 0 6935 0 19-APR- 00 Insite 0.41 MEMORY 6935.0 1.1 17.7 TOOL NUMBER 1432grvf4 1432grvf4 1432grvf4 SLD $ STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1432grvf4 6.750 2610.0 3%KCL 9.70 44.0 9.0 14500 5.8 .420 .251 .140 .200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 NPHI MWD010 PU-S 4 1 68 32 9 FCNT MWD010 CNTS 4 1 68 36 10 NCNT MWD010 CNTS 4 1 68 40 11 RHOB MWD010 G/CM 4 1 68 44 12 DRHO MWD010 G/CM 4 1 68 48 13 PEF MWD010 BARN 4 1 68 52 14 71.0 123.5 71.0 71.0 Name Service Unit Min Max DEPT FT 2611 6935 ROP MWD010 FT/H 0 3802.79 GR MWD010 API 45.99 185.7 RPX MWD010 OHMM 1.14 26.33 RPS MWD010 OHMM 1.12 26.58 RPM MWD010 OHMM 1.02 20.21 RPD MWD010 OHMM 1.16 15.41 FET MWD010 HOUR 0.2841 40.9928 NPHI MWD010 PU-S 12.21 52.7 FCNT MWD010 CNTS 119.5 1178.4 NCNT MWD010 CNTS 14268.8 35427.5 RHOB MWD010 G/CM 2.112 3.447 DRHO MWD010 G/CM -0.124 1.023 PEF MWD010 BARN 1.02 10.87 Mean 4773 95.6906 107.363 4.89855 5.09998 5.08051 5.14311 7.38676 32.8347 292.762 20618 2.48774 0.112416 3.69098 Nsam 8649 8468 8466 8470 8470 8470 8470 8470 8464 8464 8464 8462 8462 8462 First Reading 2611 2701.5 2646.5 2653.5 2653.5 2653.5 2653.5 2653.5 2611 2611 2611 2627 2627 2627 Last Reading 6935 6935 6879 6888 6888 6888 6888 6888 6842.5 6842.5 6842.5 6857.5 6857.5 6857.5 First Reading For Entire File .......... 2611 Last Reading For Entire File ........... 6935 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/05 Maximum Physical Record..65535 File Type ................ LO 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 ....... 00/06/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 6843.0 FCNT 6843.0 NCNT 6843.0 PEF 6858.0 RHOB 6858.0 DRHO 6858.0 GR 6879.5 STOP DEPTH 8431 0 8431 0 8431 0 8446 0 8446 0 8446 0 8468 0 RPM 6888.5 RPS 6888.5 RPD 6888.5 FET 6888.5 RPX 6888.5 ROP 6935.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8475.0 8475.0 8475.0 8475.O 8475.0 8522.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 22-APR-00 Insite 0.41 MEMORY 8522.0 2.9 7.7 TOOL NUMBER 1432grvf4 1432grvf4 1432grvf4 1432grvf4 6.750 2610.0 Glycol based 11.00 39.0 9.0 27000 2.9 .140 .070 .120 .180 78.0 161.6 78.0 78.0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep Code Offse FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 1 MWD020 OHMM 4 1 68 1 MWD020 OHMM 4 1 68 2 MWD020 OHMM 4 1 68 2 MWD020 HOUR 4 1 68 2 MWD020 PU-S 4 1 68 3 MWD020 CNTS 4 1 68 3 MWD020 CNTS 4 1 68 4 MWD020 G/CM 4 1 68 4 MWD020 G/CM 4 1 68 4 MWD020 BARN 4 1 68 5 t Channel 0 1 4 2 8 3 2 4 6 5 0 6 4 7 8 8 2 9 6 10 0 11 4 12 8 13 2 14 Name Service Unit Min Max Mean DEPT FT 6843 8522 7682.5 ROP MWD020 FT/H 0 240 73.9702 GR MWD020 API 48.68 161.26 109.963 RPX MWD020 OHMM 1.54 25.33 3.85439 RPS MWD020 OHMM 1.61 44.18 4.08422 RPM MWD020 OHMM 1.6 42.09 4.08764 RPD MWD020 OHMM 1.64 34.02 4.12095 FET MWD020 HOUR 0.724 31.9106 2.24846 NPHI MWD020 PU-S 16.43 40.84 29.0401 FCNT MWD020 CNTS 209.3 782.5 375.251 NCNT MWD020 CNTS 17657.7 29950.9 22666.1 RHOB MWD020 G/CM 2.307 3.101 2.56794 DRHO MWD020 G/CM -0.027 0.401 0.108377 PEF MWD020 BARN 4.01 14.25 7.72016 Nsam 3359 3174 3178 3174 3174 3174 3174 3174 3177 3177 3177 3177 3177 3177 First Reading 6843 6935.5 6879.5 6888.5 6888.5 6888.5 6888.5 6888.5 6843 6843 6843 6858 6858 6858 Last Reading 8522 8522 8468 8475 8475 8475 8475 8475 8431 8431 8431 8446 8446 8446 First Reading For Entire File .......... 6843 Last Reading For Entire File ........... 8522 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/06/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 00/06/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File
