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Home My WebLink About182-086 Ima.d" ~roject Well History File Covert ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / Organizing RESCAN .. Er~ Color items: [] G~ayscale items: Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCEN~ARIA WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non,Scannable) n Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation .. '~ x 30 = DATE: /S/ /'~ = TOTAL PAGES /~/~/' BY: BEVERLY ROBIN (~~HERYL MARIA WINDY ,,, Production Scanning Stage 1 PAGE COUNT FROM SCANNED FLEE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ' ,/~ YES , NO ~: ~~ v,,c~,~ ~.~.~ ~^.,^ w,,~. ~^~:/-~,/-cs ,~,"~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES ,, ,.NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE I~,SIS , RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE:. /SI Quality Checked 12110/02Rev3NOTScanned.wpd ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG " SEP 2 t[i!i Z005 1a. Well Status: 0 Oil 0 Gas 0 Plugged iii Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25,110 21. Logs Run: OIL I BHC I GR I SP, CDL I CNL I GR I CAL, GR I CNL, CBL, Gyro CASING, LINER AND CEMENTING RECORD I ,.'.", .......'..,.'.,. .'.', ,. '. :. .. ..,. '.'. "...'. ,. :,. ,I .., I." ':. .'. I:·· ,.' 'SI:TiT·· ''':1(:1 Dc:: nTU I 1M'· n:' I'QC'"'I",d 'r'\C';¡'~î:.I':T\ÎÖ'·;' '!' I ,.:''."... ,'I..' I I I I I I I ,I I , ','1.' 1:111', 1;,1"1 .,11,'",1,:", III' "TI I,.., ,~~~': 1~r¡í"~I,I'~"II' ~:":' 1,1~Iöjo:JI',I'1 ~:'~1 ~~r::r"I'I'~,II"III~,,! ~:""" ~"":':"bI'Q~~":","'::'" : :WrJf' Pe~;.Fr.': 11:!,:'GRð~~,'!I,I':I::,,:mQPI,"II,'BCiT~9'~: ;:,I'IIî'J1ÞA"!III'11 ,~,Ø~,â~/,:',:"SliE;I:!""¡':': 2011 91.5# 'Surface 111' Surface 111' 3011 350 sx Permafrost II L -80 Surface 2517' Surface 2517' 17-1/211 2500 sx Arcticset III, 400 sx AS II L-80 I SOO-95 Surface 12036' Surface 8877' 12-1/411 500 sx Class 'G', 300 sx AS II L -80 11762' 13060' 8682' 9641' 8-1/211 400 sx Class 'G' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2715' FNL, 1562' FEL, SEC. 09, T10N, R14E, UM Top of Productive Horizon: 4220' FNL, 1220' FEL, SEC. 16, T10N, R14E, UM Total Depth: 4849' FNL, 1365' FEL, SEC. 16, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 674948 y- 5937618 Zone- ASP4 TPI: x- 675463 y- 5930844 Zone- ASP4 Total Depth: x- 675334 y- 5930212 Zone- ASP4 18. Directional Survey 0 Yes iii No 22. CÂSINº:', .,',' ,:$:14E',II::"1 111' 13-3/811 9-518" 72# 47# 29# 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state IInonell): None MD TVD MD - F)or\ï.: 'L p 1-'\' ('¡' L \ ;,P .'·f' i\<-i!'~'NíE~.> S L (' {:, E.: - . '{:J\L;~s \.\~\ ,'" '. '..... .",l,' .". 26. Date First Production: Not on Production Date of Test Hours Tested Zero Other 5. Date Comp., Susp., or Aband. 7/30/2005 , 6. Date Spudded 07118/1982 7. Date T.D. Reached 08/07/1982 8. KB Elevation (ft): 71' 9. Plug Back Depth (MD+ TVD) 12435 + 9174 10. Total Depth (MD+ TVD) 13060 + 9641 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: o Development 0 Exploratory o Stratigraphic iii Service 12. Permit to Drill Number 182-086 305-182 13. API Number 50- 029-20756-00-00 14. Well Name and Number: PBU 14-21 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028314 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) I: ~~,9,u~r, :.' 1,~!:Pú;.tEb: ;\ 24.. TVD I' tUB I r.k; . RE66RÐI':~: . SIZE DEPTH SET (MD) 5-1/2",17#, L-80 8700' -11725' 4-1/2",12.6#, L-8? ... .....>11725' -118?~'3 25.··. ' ·',t\CID>PRACTURE".CEME~T'8QUEeZe~ETc;.'· ',',":"';::' ',;',j, :":,"'.',":".' '. ',''",'' 'i ',',',1:,",',' ':",',,'', I:""'''';;'''' ",,', ,:,>",,, , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11428' P&A wI 59 Bbls Cement 8522' Set EZSV 8531' Set Whipstock PACKER SET (MD) 11707' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BsL PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 24-HoUR RATE 27. GAs-McF W A TER-BsL CHOKE SIZE GAS-OIL RATIO GAs-McF W A TER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "nonell. .".1~~~~!.1fflc:'!:#'.r . ,.. ..c .,J.: ¡ None Form 10-407 Revised 12/2003 RBDMS BFl SEP 2 1 2005 ~ " I'· ; 7- J:>',_D5i ¡Ø". CONTINUED ON REVERSE SIDE Lìt-,~ ! r~ ~ ~. , /\ , ) 28. GEOLOGIC MARKERS 29. ) FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed s,,",pporting data as necessary. If no tests were conducted, state "None". Sag River 12091' 8918' None Shublik 12112' 8933' Sadlerochit 12197' 8997' Original OIW Contact 12306' 9078' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. .La - . L1_ IlfU A Terne Hubble'" I{)\/lle ~~ PBU 14-21 Well Number Title Technical Assistant Date OC(, ~ .. OS 182-086 305-182 Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Jeff Cutler, 564-4134 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: 14-21A Prudhoe Bay Unit 50-029-20756-01-00 205-107 Accept: Spud: Release: Rig: 08/13/05 08/16/05 08/26/05 Nabors 2ES PRE-RIG WORK 07/14/05 RAN GYRO TOOL FROM SURFACE TO 12000' MD. JOB COMPLETED. 07/16/05 SET 4 1/2 DBP PLUG AT 11,751' (SLM) LRS CMIT TO 4000 PSI (PASS, SEE LRS WRS FOR DETAILS). PULLED 4 1/2 DBP PLUG AT 11,751' (SLM). 07/30/05 P&A PERFS. RIH WITH 2.0" BDJSN WHILE KILLING WELL DOWN BACKSIDE WITH 440 BBLS 1 % KCL. TAKE RETURNS FROM TBG AND IA TO ENSURE BOTH ARE FLUID PACKED. TAG TD AT 12,390' CTMD (MOST LIKELY FILL AND JUNK ON TOP OF PLUG). PUH AND UNDERBALLANCE WELL WITH 120 BBLS DIESEL. INJECTIVITY TEST 1.4 BPM AT 350 PSI. LAYED IN 5 BBLS NEAT 15.8 PPG CEMENT FOLLOWED, BY 17 BBLS OF 15.8 PPG CEMENT WITH AGGREGATE 1:1. PULLED COIL PAST PERFS TO 12,000' CTMD - AND SI CHOKE WHILE CONTINUING TO PUMP CEMENT INTO PERFS. WHP CAME UP TO 430 PSI AND HELD CONSTANT. PUMPED APPROXIMATELY 29 BBLS IN FORMATION OPENED CHOKE AND LAYED IN REMAINING CEMENT 1:1 UP TO 10,600 CTMD. WHILE PUH AND LAYING IN LAST 2 BBLS OF CEMENT, COIL LOST ABILITY TO MOVE. PUMPED REMAINING 2 BBLS CEMENT OUT THE NOZZLE AND IMMEDIATELY SWAPPED TO 1% KCL DOWN BACKSIDE. TOTAL OF 59 BBLS CMENT PUMPED. PUMPED TOTAL OF 5 BBLS AND COIL CAME FREE. WELL FREEZE PROTECTED WITH DIESEL. WELL LEFT SI. JOB COMPLETE. 08/01/05 RAN 4.5" CENT AND SAMPLE BAILER. TAGGED CEMENT AT 11,428' SLM. HARD TAG. BAILER EMPTY. MIT-T TO 2500#, PASSED. CUT TUBING AT 8698'. CORRELATED TO ARCO TUBING TALLY DATED 25-JAN- 88. RDMO. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) BP EXPLORATION Operations Summary Report Page 1 _ 14-21 14-21 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/12/2005 Rig Release: 8/26/2005 Rig Number: Spud Date: 8/16/2005 End: 8/26/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/12/2005 12:00 - 00:00 12.00 MOB P PRE Move rig from well # 14-30 to 14-21. Move was around the reserve pit. Bridle up, lower pipe shed chute, pull pins and UD derrick. Move to next location & spot rig. Raise derrick & pin, unbridal and hang lines. Raise pipe shed chute. Spot shop, camp and pits. R/U floor. Hook up interconnect lines. Rig accepted @ 00:01 hrs, 8/13/2005. Held pre-spud meeting with drill crew, Toolpusher & WSL. 8/13/2005 00:00 - 00:30 0.50 WHSUR P DECaMP Rig accepted @ 00:01 hrs 8/13/2005. Held pre-spud meeting with drill crew, tool pusher & WSL. 00:30 - 01 :00 0.50 WHSUR P DECaMP Install secondary annulus valve. Inner and outter annulus = 0 psi. 01 :00 - 02:00 1.00 WHSUR P DECaMP R/U DSM lubricator and pull BPV. 02:00 - 02:30 0.50 WHSUR P DECaMP R/U circ lines & test to 4000 psi. 02:30 - 05:00 2.50 WHSUR P DECaMP Reverse circ 60 bbl seawater and displace diesel from tubing. 0.00 WHSUR P DECaMP Pump soap pill and hot seawater, pump 590 bbl @ 9 bpm @ \ 970 psi to displace well to clean seawater. Verify well is dead. Tubing & annular pressure = o. 05:00 - 06:00 1.00 WHSUR P DECaMP R/U DSM lubricator & set TWC valve, test to 1000 psi. Check for flow. 06:00 - 08:30 2.50 WHSUR P DECaMP N/D tree and adaptor flange. Function LDS. Verify tubing hanger lift threads are 5 7/8" right hand Acme. Install tree test plug. 08:30 - 11 :30 3.00 WHSUR P DECaMP N/U 135/8" BOPE. 11 :30 - 17:30 6.00 WHSUR P DECaMP Test BOPE to 4000 psi high test & 250 psi low test. Test top drive, choke manifold, and all related valves & Iines.Top pipe rams (3.5" X 6") and annular preventor failed. Witness of test waived by AOGCC Rep. Chuck Scheve. Test witnessed by WSL Bill Decker & Toolpusher Cleve Coyne. 17:30 - 00:00 6.50 WHSUR N DECaMP RID test equipment, change top rams. Remove bell nipple and replace packing unit in annular preventor. 8/14/2005 00:00 - 00:30 0.50 WHSUR N DECaMP Install bell nipple & turn buckels on BOPE. 00:30 - 03:00 2.50 WHSUR P DECaMP R/U & test BOPE, top rams to 250 low pressure & 4000 high. Test annular preventor to 250 low & 3500 psi high using 5.5" landing jt. Witness of test waived by AOGCC Rep. Chuck Scheve. Test witnessed by WSL James Willingham. 03:00 - 04:00 1.00 WHSUR P DECaMP R/U DSM lubricator & pull test dart & TWC valve. R/U Camco control line spooler. 04:00 - 04:30 0.50 PULL P DECaMP M/U 57/8" RH Acme xa to Jt of 5" DP. BOLDS. Run in and screw into hanger ( 12 1/2 turns). M/U top drive. Pull 5 1/2" tubing free with 175 K. Pull hanger to floor. String wt 145K wI TD & blocks. 04:30 - 05:00 0.50 PULL P DECaMP CBU @ 12 BPM - 370 psi. Seawater clean. Shut down, monitor well - static. 05:00 - 06:00 1.00 PULL P DECaMP Break out & UD tubing hanger. POH w/5 1/2" tubing, spooling up control line. 06:00 - 08:30 2.50 PULL P DECaMP POH UD 5.5" tubing from 8700' to 6522'. 08:30 - 09:00 0.50 PULL P DECaMP RID control line spooler. UD tools. 09:00 - 15:00 6.00 PULL P DEcaMP POH UD 5.5" tubing. Retreive 49 SS bands, 4 GLM, 1 SSSV, 208 Jts tubing & 1 cut joint. RID running tools & clean rig floor. 15:00 - 17:00 2.00 WHSUR P DECaMP M/U test joint, set test plug. Test top rams 3.5" X 6" & bottom rams 27/8" x 5" to 250 psi low pressure & 4000 high. Test annular preventor to 250 low & 3500 high with 5 " test joint. Test witnessed by WSL Bill Decker. Install wear bushing. Printed: 8/29/2005 7:28:58 AM · , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) Page 2 .. BP EXPLORATION Operations Summary Report 14-21 14-21 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 8/14/2005 17:00 - 23:00 From - To Hours Task Code NPT Phase DECOMP Date 23:00 - 00:00 8/15/2005 00:00 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 22:00 22:00 - 23:00 23:00 - 23:30 8/1 6/2005 23:30 - 00:00 00:00 - 00:30 00:30 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 10:00 10:00 - 12:30 12:30 - 13:00 13:00 - 15:00 15:00 - 00:00 8/17/2005 00:00 - 13:30 13:30 - 14:30 6.00 DHB P 1.00 PULL N SFAL DECOMP Start: 8/12/2005 Rig Release: 8/26/2005 Rig Number: Spud Date: 8/16/2005 End: 8/26/2005 3.00 STWHIP P WEXIT Description of Operations R/U SWS, RIH with GR/JB to top of 5.5" tubing stump @ 8685' WLM. POH logging up. Recovered 1 SS band in JB. M/U EZSV, GR/CCL. RIH. Set EZSV @ 8522'. POH & RID SWS. Test casing to 4000 psi. Leak on inner annulus valve. Call DSM to set V.R. plug & replace valve. P/U whipstock BHA, orient, upload, shallow test @ 500 gpm @ 600 psi. Test casing to 4000 psi for 30 min, OK. P/U BHA, drill collars & HWDP, P/U BHA to 1031'. RIH running speed = 34-40 see per jt. RIH P/U drill pipe. Fill pipe @ 3000' intervals. Service top drive. Orient whipstock 84 degrees left. Set bottom anchor @ 8531' with 20K down weight. Pull up 10K to check, set 45K down to shear off of whipstock. Displace well to 9.0 ppg LSND mud. Pump @ 510 gpm @ 1330 psi. II Mill window in 95/8" 47#, casing. Window top@8509',bottom @ 8525'. Milled formation to 8,537'. HWT = 195K, SWT = '155K, RWT = 175K. Pump @ 442 gpm @ 1100 psi. Torque off btm = 6-7K, on btm = 7-12K. Recovered 160 # of metal cuttings. Pump super sweep, CBU @ 515 gpm @ 1340 psi. Perform FIT test with 9.0 ppg mud. Leaked off to formation @ 1120 psi, shut down pump & close in, pressure bled off to 1000 psi and stablized. Pumped 3.8 bbl and got 2 bbl back when bled off. LOT = 12.21 ppg. EMW. Monitor well. Pump dry job. Cut & slip drill line. Cut & slip drill line. Check brakes. Remove top drive blower hose. POH from 8487' to 1031'. POH, UD drill collars & whipstock assy. Mills full gage. Service wear ring. Flush out stack and all surface equipment. MU Drilling BHA - orient tools. RIH wi HWDP. Shallow test MWD tools. RIH picking up 5" DP. Break circ every 3,000'. Service top drive. RIH to 8,465'. Base line ECD tests - Orient 85 L - slide through window @ 8,509' to bottom @ 8,537'. Dir. Drill from 8,537' to 9,200'. AST 2.16 hrs, ART 4.44 hrs, UP 200K, ON 150K, RT 175k, TO Off 7.5K, TO ON 10k, ECD = 10.45 ppg. Dir. Drill from 9,200' - 10,169'. UP 2 160k, RT 190K, TO ON 10K, TQ OFF 7K, 5 M @ OFF 1,890 psi, ON 2,430 psi. RPM 7 140/240 fph. ECD = 10.2 ppg. Pump hi eep around and circ hole clean - 500 gpm - psi - flow check. Short trip to 95/8" window @ 8,509'. No problems. Flow check. Service top drive. RIH f/8,509' to 10,169'. No problems. Start raising mud wt. to 11.0 ppg @ 10,169'. Dir. Drill from 10,169' to '.10,462'. ECD's = 12.25 ppg. Condion mud to 11.0 ppg and mix Resinex I soltex. ECD = 11.9 ppg. 14:30 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 21 :00 1.00 STWHIP P 2.00 STWHIP P WEXIT WEXIT 8.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P WEXIT WEXIT WEXIT 1.00 STWHIP P WEXIT 5.50 STWHIP P IWEXIT 1.00 STWHIP P 0.50 STWHIP P WEXIT WEXIT 0.50 STWHIP P 0.50 STWHIP P 3.50 STWHIP P 2.00 STWHIP P 2.00 STWHIP P 2.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 2.50 STWHIP P 0.50 STWHIP P 2.00 STWHIP P WEXIT WEXIT WEXIT 9.00 DRILL P LNR1 13.50 DRILL P LNR1 1.00 DRILL P LNR1 1.00 0.50 P LNR1 Printed: 8129/2005 7:28:58 AM 14-21 (PTD # 1820860) Internal Waiver Cancellation ) ) Subject: 14-21 (PTD #1820860) Internal Waiver Cancellation From: "Dube, Anna T" <Anna.Dube@BP.com> Date: Mon, 08 Aug 2005 09:34:58 -0800 To: "AOGCC - Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. jim _regg@admin.state.ak.us CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Luckett, Ely Z~ (VECO)" <luckez@BP.com> ~1' '[ {q to t5: '~^Je~Qj- Winton and Jim, The internal BP waiver for rapid TxlA communication on well 14-21 (PTO #1820860) has been cancelled. The well will remain shut-in and classified as a trouble well in preparation for a rig sidetrack later this month. The application for cancellation of sundry #303-289 has also been sent by mail. Please let us know if it is not received in the next couple of days. Well 14-21 will also be removed from the Monthly Injection Report given the cancelled sundry and waiver. An AOGCC witnessed MIT-IA is scheduled post initial injection into the new sidetrack. Please let me know if you have any questions. Thank you, jInna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 }"'),,','," ((" l:A\ \î'~, k-\\ (,F: (1;"': II); 'J C' 2 r¡ q I:] ~.~ð"-'~G ,,~~!.'tJ\.i_~'1' !i (~.~ ~¡ ..I¡. "w, ~ 1 of 1 8/9/2005 8:41 AM - . ) ) RECEIVED AUG 0 9 Z005 BP Exploration (Alaska) Inc. Attn: W ell Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 Alaska Oil & Gas Cons. Commission Anchorage August8,2005 Mr. Winton Aubert, P. E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 14-21 (PTO 1820860) Application for Cancellation of Sundry #303-289 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-289. The sundry was for continued water injection with rapid TxlA communication. The well will remain shut-in in preparation for a rig sidetrack. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. An AOGCC witnessed MIT -IA will be scheduled post initial injection into the new sidetrack. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, , s:)~f~ Anna Dube Well Integrity Coordinator SCANNED AUG 0 9 2005 Attachments Application for Sundry Cancellation form 10-404 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION . REPORT OF SUNDRY WELL OPERATI~FIVED 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 Repair WellD Plug PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D Stimulate D AUG 0 9 2~tJ'lXI CANCEL WaiverD Time ExtensionD SUNDRY Alas~.Q~ti ~&M~3.Wél'f!)1i~$ion 5. PerrAQ&~~i5I\I~ber: 182-0860 6. API Number 50-029-20756-00-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development D ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicD 9. Well Name and Number: 14-21 10. Field/Pool( s): Prudhoe Bay Field / Prudhoe Oil Pool Service ŒI 71.00 8. Property Designation: ADL-028314 11. Present Well Condition Summary: Total Depth measured 13060 feet true vertical 9640.7 feet Effective Depth measured 13018 feet true vertical 9609.1 feet Casing CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: Length 110 2477 11997 1254 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 Plugs (measured) 12435 Junk (measured) 13050 MD TVD Burst Collapse 41 151 41.0 151.0 1490 470 40 - 2517 40.0 - 2516.5 4930 2670 39 - 12036 39.0 - 8877.3 6870 4760 11762 - 13016 8681.7 - 9607.6 8160 7020 Measured depth: 12091 -12112,12202 -12208,12215 -12221,12224 -12264,12464 -12624,12632 -12642,12648 -12698,12714 -12764, 12816 - 12866, 12894 - 12914 True vertical depth: 8918 - 8933, 9001 - 9005,9010 - 9015,9017 - 9047, 9196 - 9315, 9320 - 9328, 9332 - 9369, 9381 - 9419, 9457 - 9495, 9516 - 9531 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 PC 4-1/2" 12.6# L-80 PC 4-1/2" 12.6# L-80 @ 37 @ 11725 @ 12395 11725 11804 12451 Packers & SSSV (type & measured depth): 5-1/2" Baker FB-1 Packer @ 11707 4-1/2" BKR FB-1lsolation PKR @ 12395 5-1/2" CAM BAL-O SSSVN @ 2156 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl SHUT-IN SHUT-IN Representative Dailv AveraQe Production or Iniection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 13 Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders / Anna Dube WAG D GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 303-289 Printed Name ~nnatpube ____ Signature '- ~~('Á .( ., LJ~l~ Title Phone Well Integrity Coordinator 659-5102 Date 8/8/05 RBDMS 8FL AUG 1 0 20U5 Form 10-404 Revised 4/2004 I~, ,ír /'~ I,' -17, Œ:! , r: : ß~ : I t I I~I I I 'II I! II I' I i III i \ I I ~ L-l ' c".¡ ) :1l1 '¡!,--;;:::Jr'. ~/!~~/\ \, rl ,¡/,ll\\, :(@,\ i'l~n,/,I/,r'\1" i U : Ii,' ilJ" il!.L '\, ' ") ') I ~~ 1\ / H \ I I, I " "i" I I, " '10 Li ,I, 1~' I~Ulj;Qd) U \J¡ln \ ) AIßASKA OILA5D GAS CONSERVATION COMMISSION / / I I I J FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Phil Smith Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 I ?) J-- D~b Re: Prudhoe Bay 14-21 Sundry Number: 305-182 SC}\NNED JUL ~~ 0 2005 Dear Mr. Smith: 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. Please provide at least twenty-four (24) hours 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 oliday or weekend. A person may not appeal a Commission decisio 0 Superior Court unless rehearing has been requested. ,9 DATED this/~ay of July, 2005 Encl. Summary by Month: Individual Well Injection / Disposal Well Name: PRUDHOE SAY UNIT 14-2] API: 50-029-20756-00-00 Permit to Drill: ]820860 Operator: SP EXPLORATION (ALASKA) INC FieldlPool: PRUDHOE BAY, PRUDHOE OIL Sales Cd: 60 Acct Grp: 3]4 Final Status: ]-OIL Current Status: ]WINJ 2004 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Days 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 0 0 Gas 0 0 0 0 0 0 0 0 0 0 0 0 2004 Totals: Water 0 Gas 0 Cum Wtr 19,593,419 Cum Gas 9,366,600 2005 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Shut-In Shut-In Wtr Inj Wtr Inj Wtr Inj 0 0 26 30 2 ~ Days Wtr 0 0 ] 77,025 28],]64 22,580 Gas 0 0 0 0 0 2005 Totals: Water 480,769 Gas 0 Cum Wtr 20,074,188 Cum Gas 9,366,600 - ÇÇ-/ \l0~\\ ~c::, ~~~ ~ ~ ~\ "'-~~ I (J "> \4\((- "s. 0 '::.úSJt-( (-f'.. \t~-r~ct-~ \ \Y\ ~ tc:\--W"J "\10 { o,\r--. ì~~'J"~-\-l \OS~-, .,- ~K ~ ~~ Ç'û ~ 'B ~ ~ ~ Wednesday, July 13, 2005 Page 4 Date: To: From: Subject: ) ) July 13, 2005 File Jane Williamson Prudhoe Well 14-21 O· P6 f.¡; 15~~ ~, BP is requesting approval to plugback PBU injector 14-21 to allow for later sidetrack. The well has corroded tubing. BP has indicated that sidetrack to the peripheral Zone 4 location will provide the best support of offset producers. A production and injection plot is attached. I recommend approval of the P&A for sidetrack. --- --- 05 99 2000 ---- -~~--_.--- Date 98 97 96 95 94 93 92 91 ---------~29207560000:150 Oil Rate (CD) (Mbbl/d ) Water Rate (CD) (Mbbl/d ) ~ Gas Rate (CD) (MMcf/d ) Water In] Rate (CD) (Mbbl/d ) ----- 90 89 88 87 86 I I ~ !I ----------" PRUCHOE BAY. PRUDHOE OIL PBU_DS14 PRUDHOE BAY 14-21 85 84 1982 83 0.1 J 0.5 5 10 50 100 4}Ì'S" 7(1:5/~ . ) STATE OF ALASKA C/l1 }-/S--O.5 RECEfVe""/ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVAL JUL 12 2005' 7ft; 20 MC 25.280 Alaska Oil 8« Ga8 ConI. Commission ^nchorsgo 1. Type of Request: II Abandon [J Suspend [J Operation Shutdown [J Perforate [J Other [J Alter Casing [J Repair Well [J Plug Perforations [J Stimulate [J Re-Enter Suspended Well [J Change Approved Program [J Pull Tubing 1:1 Perforate New Pool [J Waiver [J Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic B Service 99519-6612 9. Well Name and Number: 71' 8. Property Designation: 5. Permit To Drill Number 182-086 6. API Number: 50- 029-20756-00-00 PBU 14-21 ADL 028314 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ,." r:1ct:::cE' "'N' , "';~^'t:L"";;e' ..' 0.· 'N' ,.D·'I~I;O·'" I.:"C,I":"M' '1I.:~ÀHv:I"'>':¡'I,J":;::II''''I>·:II:,I'I"",':'II",;il:,' :1,' ,I'll. ":"¡.'.',' .', ',1.':.',"',1,1"': !. ,,'..,. 1:":'1 .,,'¡'" .;,:,: l'II"I.{7:~,,~~~, : ';', ":,I','I,,,,'V,:V:I,~ :~:,':', I ,,,, I :' !"',:, I, I ~~"" Y,~'I ,,'~'Hor:~~,,'~"i,I::',1 ,.!':,. '!:'III:'I,~" I.,I".!.':!"I.), !',;I"I"":I,\I"'lh"'I'.::IIIII,I,,~ ,1,,1 'I:I,II:,;:'~I',: I", I:' ,:,1: Ih '~',':·\I:' II".',':'~:"",I,'I :,'II",','~:I'':'' I,I!,:' II:,';' ,"0,~ ,I ,:I;¡,:,,:;'! ~:(): ;:I:;~,: ::: ';':: Total Depth MD (ft): 13060 'Cåslng.', Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9641 12435 9174 12435 .'.'.Lér:lgth . Size"" "MO" ,TVD"'Burst'"" Junk (measured): 13050 , ,. Cdllapse 111 ' 20" 111' 111' 2517' 13-3/8" 2517' 2517' 12036' 9-5/8" 12036' 8877' 1298' 7" 11762' - 13060' 8682' - 9641' Perforation Depth MD (ft): Perforation Depth TVD (ft): 12091' - 12914' 8918' - 9531' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'FB-1' packer; 5-1/2" Cameo 'Bal-O' SSSV Nipple 1490 4930 6870 470 2670 4760 8160 7020 Tubing Size: 5-1/2", 17# x 4-1/2", Tubing Grade: Tubing MD (ft): L-80' 11804' Packers and SSSV MD (ft): 11707'; 2156' 12. Attachments: a Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development B Service July 21, 2005 Date: 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ 16. Verbal Approval: Commission Representative: 17. I hereby certify that the.f,. Oregoin~e,and correct to the best of my knowledge. Printed Name '?lIIls~¡:Jcsorr· ,( C._.. ~ I ¡-If Title Senior Drilling Engineer Signature ...~~._.../~~.~..----, "Phone" 56~L(8í'1 Date Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ~IUg Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance o Plugged BWINJ o Abandoned o WDSPL Contact Jeff Cutler, 564-4134 Phil Smith, 564-4897 ~ / Prepared By Name/Number: 7//2/6; Terrie Hubble, 564-4628 Sundry Number: .30~ -/ð' ~ \>((: r ;)C)~t~·,S_:~- 'S ,J<15<.o'-'Ð \<.... ~)\.~) o,~, u.~ C1..~ ~~~~ ~ ~ ~O~'> ~c;,~"~ c-.. ~«~\\-\a~ \.~ RBDMS BFL JUL 19 2Ð05 APPROVED BY THE COMMISSION Dateddr£' U~~I~~icate COMMISSIONER rf'~ 'U l-r 2 ·t 1\ V\11 I LV 1\ I Q " I'HiL ) ) ·G','.',',",,',',',·',.,.',",,', ',,' ,,",',"',",,",,',"',': . BB (;7!illeJ'. To: Winton Aubert - AOGCC Date: July 11, 2005 From: Jeff Cutler - BPXA GPB Rotary Drilling Subject: Reference: 14-21 A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20756-00 Approval is requested for the proposed P&A of PBU well 14-21. A PDS caliper run in October 1999 indicated damage severe enough to warrant a tubing replacement to put the well back into service. Since the current injector is out of zone, a sidetrack of this wellbore as a peripheral Ivishak Zone 4 injector is seen as the best way to maintain offtake from this drainage area, and maximize value from the wellbore. The sidetrack is currently scheduled for Nabors rig 2ES, beginning around August 10th 2005, after the completion of the 14-30A RST. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: ./ POS Caliper 10/7/99 shows 70% of joints with 40%+ wallloss. ./ LOL 9/21/99 shows leak. at ~565'MD. 1 BPM LLR @ 2500psi. .¡' Confirmed TxlA integrity with MITOA to 3000 psi on 5/26/05. ./ Open perforations from 12,091' to 12,264' ./ 4-1/2" Magna-Plug set at 12,435' ./ OMIT passed to 3,000 psi on 6/6/05. Scope Pre-Ria Work: 1. R/U SL and drift tubing, tag up on Magna Plug @ 12,435' MD 2. RU e-line, run gyro surveys from surface to 12,435' 3. RU SL and set 4-1/2" DPB plug body @ 11,764' SLM. Perform CMIT to 4,00.9 psi. RIH with SL and pull plug /Q\L..~?)vr 4. RU CT and RIH and P&A the 14-21 well bore. Pump -194 fP (34.5 bbl) 15.8 ppg Class G cement leaving TOC in the tubing tail at -11300'md. 5. Drift the 5112" tubing to 8,900' md to confirm clear to the required cut depth of 8,700' md. R/U E-line and RIH with the appropriate jet cutter, cutting the 5 112" tubing in the center of a full joint at -8,700' md. ,,6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. 7. Freeze protect to -2,200' MD with diesel. 8. Test the 9 5/8" pack-off and tubing hanger seals to 5,000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 9. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. MI I RU Nabors rig 2ES 2. Pull BPV and circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 4,000 psi. 4. R/U. Pull 5Y2" tubing from the cut at -8,700' MD and above. 14-21 A Application for Sundry ) ) R/U E-line. M/U 8.5" gauge ring I junk basket I CCL. RIH and tag tubing stub . POOH. RIH with HES EZSV on E-line. Set bridge plug at -8,524', as required to avoid cutting a casing collar while milling the window. POOH. RID E-line. Pressure-test the 9 5/8" casing to 4,000psi for 30 minutes. Record test. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. LJisplace the well to 11.0ppg LSNIJ based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at ± 8,500' MD, plus approximately 20' beyond middle of window. \ Circulate well bore clean. \) -c... 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. ~ #J 12. M/U 8%" Dir/GR/PWD assembly. RIH, kick off and drill the 8%" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. rlr.4" 13. Run and cement a 7",26.0#, L-80 intermediate drilling liner. \ ~ \( 14. R/U eline and run USIT on 7" liner 15. M/U 6-1/8" Dir/GR/Res assembly. RIH to the landing collar. 16. Test the 9 5/8" casing X 7" liner to 4,000psi for 30 minutes. Record the test. 17. Drill out the 7" liner float equipment and cement to the shoe. 18. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 19. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to TD per directional proposal. 20. Circulate well bore clean, short trip to shoe, circulate. POOH. 21. Run and cement 4%", 12.6#, L-80 solid production liner. POOH. 22. RIH with 2 7/8" perf guns and perforate ±500'. 23. R/U and run a 4%", 12.6#, L-80 tubing completion, stinging into the 4Y2" liner tie back sleeve. 24. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 25. Set a TWC. 26. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC 27. Freeze protect the well to -2,200' TVD. Set BPV and secure the well. 28. Rig down and move off. \..~ ~ 5. ~'" 6 ~t\~: 9. Post-Ria Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. 3. Perform static step rate test Estimated Pre-rig Start Date: 7/21/05 Estimated Spud Date: 8/05/05 Jeff Cutler Operations Drilling Engineer 564-4134 14-21 A Application for Sundry ) TREE = GRAY GEN 2 WELLHEAD = ~RAY ACTUA TOR = AXELSON KB. ELEV == 71' BF. ELEV = KOP= Mix Angle = Datum tv'D = Datum lVD= 2800' 56 @ 9600' 12027' 8800' SS 1 13-318" CSG, 72#, L-80, ID = 12.347" H 2517' 1 Minimum ID = 3.750" @ 11796' 4-1/2" CAMCO DB NIPPLE 14-21 - ~ ~ L ) SAFETY NOTES: "**RAPIDTxlACOMM. OPERATING LIM ITS: M AX lAP = 2000 PS~ MAX OAP = 1000 PSI (10/22/03 WAlVER)***FLOWL INE FROZEN, CORROSION DAMAGE, TWI~EDWlTH 14·17. 2156' H 5-1/2" CAM BAL-OSSSV NIP,ID =4.562" GAS LIFT M6.NDRELS ST tv'D lV D DEV TV FE V LV LA Ta-t PORT ()I.\ TE 1 3552 3513 26 MM-I RK 2 5746 5011 52 MM-I RK 3 7869 6302 52 MM-I RK 4 9928 7530 54 MM-I RK 5 11375 8418 49 MM-I RK 6 11523 8517 47 MM-I RKP 8: &---I 11707' H 9-518" X 5-1/2" BKR FB-1 PKR \ J 11709' H 5-1/2" BAKERSBEASSY 11725' H 5-1/2" X 4-1/2" XO 1 5-112" TBG-PC, 17#, L-80, .0232 bpf,lD =4.892" H 11725' 1 TOP OF 4-1/2" TBG-PC H 11725' hop OF 7" LNR H 11762' -, I I I PERFORATION SUMI\M RY REF LOG: BHCS ON 08/07/82 ANGLE A TTOP PffiF: 42 @ 12091' I\bte: Refer to Ftoduction DB for historical perf data SIZE I SFF I INTERVAL I OpnlSqz I DATE Sa:: PA GE 2 FOR PffiFORA TION ()I.\ TA I 9-5/8" CSG, 47#, L-80. ID= 8.681" H 12036' rAI 14-1/2" TBG-PC. 12.6#, L-80, .0152 bpf, ID= 3.958" I-i 11804' ITOP OF 4-1/2" TBG H 12395' 14-1/2" lBG-PC, 12.6#, l-80. .0152 bpf, ID = 3.958" H 11805' 4-1/2" 1BG.12.6#. l-80, .0152 bpf. D =3.958" H 12451' ~ 13018' 1 7" Lt'R, 29#, l-80, .0371 bpf,lD =6.184" H 13060' ~ I 11796' H 4-1/2" CA weo DB NIP ID = 3.75" ~ 11804' H 4-1/2" TT W/ BA KER WlEG 1 11781' H ELtv'D TT lOGGED 02105188 12395' H 7" X 4-1/2" BKR FB-1IS0 PKR 12435' H 4-1/2" MAGNA PLUG 1 12441' I- 4-1/2" CAtvCO DB NP ID = 3.687" W/BLANKlNG PLUG 12449' H 4-1/2" TT W/BAKER WlB3 13050' H CA-RKEDW/O PRONG 13055' H 22' PER= GUN & CCl 3-1/8" PRLDH:>E BAY LNIT WELL: 14-21 PERMIT I\b: 1820860 A A No: 5O-029-20756~O SEC 9. 1l0N, R14E 1364.03 FB.. 4846.25 FN.. BP Exploration (Alas ka) D6.TE REV BY COrvtJl8llTS DATE REV BY COMfv£NTS 08113182 ORIGINAL COM PLETION 01125188 LAST WORKOVER 02122,{)1 S6-lG REVISON 01,{)8,{)2 RNITP CORRB:TONS 02120,{)3 n-lH W AW ffi SA. FETY NOTE 11/HAJ3 TJR'PAG WAWffi SA.FETY NOTE TREE = GRA Y GEN 2 I WE~LHEAD = GRAY ÄCiÙÄrOR; ,·,'ÄXELSÒN 1<8.' ãEV; ., '71; BF. ELEV = Rop;'", Max Angle = Datum MD = ÖaìUmTV"Ö;;; aá6ööss ) ~ )Y NOTES: 14-21A Proposed .... ..." ...""."............ 2800' 13-3/8" CSG, 72#, L-80. ID = 12.347" 1-1 2517' Minimum ID = 3.725" @ 11467' 4-1/2" XN NIPPLE 18350' - Top of Liner 8500' 1-19 5/8" Window 1 I 5-1/2" 17#, L-80 tubing cut @ 1-1 8700' Top of Cerrent 1-1 11300' 1 I 11707' 1-1 9-5/8" X 5-112" BKR FB-1 PKR 1 I TOP OF 7" LNR l-i 11762' 9-5/8" CSG. 47#, L-80. ID = 8.681" l-i 12036' I 12435' l-i 4-1/2" MAGNA PLUG I I PBTD 1-1 13018' 1 7" LNR, 29#. L-80, .0371 bpf. ID = 6.184" 1-1 13060' . j 2200' 1-1 4-1/2" X Nipple (3.813" ID) J GAS LIFT MANDRELS ~ ST MD ¡YD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 5 L l J 1 11407' 1-141/2" X Nipple (3.813" ID) 1 I 11417' 1-17" x 4 1/2" Baker S3 Packer 1 I 11437' 1-141/2" X Nipple (3.813" ID) 1 I 11457' 1-14 1/2" XN Nipple (3.725" ID) 1 11467' - 41/2" Hanger /liner top packer 11467' - 41/2" WLEG I 11617' 1-17" 26# L-80 (6.276" ID) 141/2" 12.6# L-80 Liner PBTD 1-1 12,380' 1 I 11709' 1-1 5-1/2" BAKERSBEASSY 1 . ~ PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE ~ ) ~ . DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/82 ORIGINAL COMPLETION 01/25/88 LAST WORKOV ER 02/22/01 SIS-LG REVISION 01/08/02 RNfTP CORRECTIONS 02/20/03 ITLH WA IV ER SA FErY NOTE OS/26/05 JNC PROPOSED SIDETRACK COMP PRUDHOE BAY UNIT WB...L: 14-21 A PERMIT No: "'1820860 API No: 50-029-20756-01 SEC 9, TION, R14E 1364.03 FEL 4846.25 FNL BP Exploration (Alaska) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1/ P.I. Supervisor <'Zf[t e:lI4-{ Ù·; DATE: Wednesday, June 08, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) lNC 14-21 PRUDHOE SAY UNIT 14-21 tJ~ ~~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Sup rv ..:::.fI3fb-' Comm Well Name: PRUDHOE BAY UNIT 14-21 Insp Num: mitJJ050606154212 Rellnsp Num: NON-CONFIDENTIAL API Well Number: 50-029-20756-00-00 Permit Number: 182-086-0 Inspector Name: Jeff Jones Inspection Date: 6/6/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well'¡' 14-21 Type Inj.I' N i TVD _1-8643 ! IA 460 -3ÕÕÕ----¡ 2950 I 2925 _~:_ 11820860 TYp.;Testl-šPT-T~st psIJ 2160:75T OA 30 3S 1--35 :--~-: Inter'Y-ª_L___~~Qv~_______P1F ____. P _______!'ubing I 410 2850 1.___ 2830 I 2810 Notes: This well has known tubing x IA communication, and is on a two year test cycle required by variance. A TTP was set at 11,796 MD to facilitate the CMIT. 13.2 BBLS of methanol was pumped with the tubing pressure tracking the IA pressure and the OA pressure constant during the test. . ß) iüG5 ~\Mr::l\ ì, ~~OV (J @ S(ìI\~'II.\~~t...t;...J "" Wednesday. June 08, 2005 Page 1 of 1 ~ .' ../ ¡ .~ Tr'f:? Sr,::~r5/;;c,/(,)ç @ n/1q~ MO F'ðrZ.. C Y'/\ IT \ 111804' 1-l4-1/2"TTW/BAKERWLEGI 1 11781' 1-1 EUvD TI LOGGED 02/05/88 1 12395' l-l 7" X 4-1 /2" BKR FB-1 ISO PKR 1 12435' I-{ 4-1/2" MAGNA PLUG 1 12441' 1- 4-1/2" CAI\iCO DB NP ID= 3.687" W/BLANKING PLUG .., , lREE = GRA Y GEN 2 WELLHEAD = GRAY ACTIJA TOR = AXELSON K8.·Ëi2J~ ..'....-..···-...71'· 'SF. !:LEV = 'KOP";'''''''-- . 'rv1:ix'A'n'i;iie '''; .. bä Ú.JiïïMS'; baiuiïï'wÖ::: 14-21 2800' "sä@'g6oo'" ,... "o'12Ò27" . q"'-ääöö"ss' ~ ~ 1 13-3/8" CSG, 72#, L-80, 10= 12.347" l-l 2517' ~ ~ L Minimum ID = 3.750" @ 11796' 4-1/2" CAMCO DB NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 ==4.892" 1-1 11725' ITOP OF 4-1/2" TBG-PC l-i 11725' lTOP OF 7" LNR 1-1 11762' :8: &--I \ J : æ PERFORATION SUMI'vtô.RY REF LOG: BHCS ON 08/07/82 ANGLE A TTOP PffiF: 42 @ 12091' Note: Refer to A'oduction DB for historical perf data SIZE I SFr I INTERVAL I Opn/Sqz I DATE I - SEE PAGE 2 FOR PffiFORATION DA TA I 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 12036' rJ 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I-{ 11804' ITOP OF 4-1/2" TBG H 12395' 14-1/2" TBG-PC, 12.6#.L-80, .0152 bpf, 10=3.958" 1---1 11805' 4-1/2" 1BG, 12.6#, L-80. .0152 bpf. 0 ==3.958" H 12451' lrem I-{ 13018' 7" LNR. 29#. L-80. .0371 bpf. 10:: 6.184" H 13060' W DATE REV BY COMMENTS DATE REV BY 08/13/82 ORIGINAL COM PLEfION 01/25/88 LAST WORKOVER 02/22/01 SS-LG REVISON 01/08/02 RN/1P CORRECTONS 02/20/03 rru-I WAN ffi SA FEíY NOTE 11 117 /03 TJA'PAG WAIVffi SAFEíY NOTE COMMENTS ) SAFErY NOTES: ***RAPIDTxIA COM M. OPERATING LlM ITS: M AX lAP = 2000 PSI, MAX OAP = 1000 PSI (10/22/03 WAIVER)***FLOWLlNEFROZ8'J, CORROSION DAMAGE, TWlf\l'JEDWITH 14-17. 2156' H 5-1/2" CAM BAL-O SSSV NIP, 10 = 4.562" :~ GAS LlFf I'vtô.NDRB.S ST MD lVD D8J TYÆ VLV LATCH PORT DATE 1 3552 3513 26 MMH RK 2 5746 5011 52 MMH RK 3 7869 6302 52 MMH RK 4 9928 7530 54 MMH RK 5 11375 8418 49 MMH RK 6 11523 8517 47 MMH RKP 11707' 1-1 11709' l-l 11725' 1-1 9-5/8" X 5-1/2" BKR FB-1 PKR 5-1/2" BAKER SBE ASSY 5-1/2" X 4-1/2" XO 1 1 11796' 1-1 4-1/2" CAI\iCO DB NIP 10 = 3.75" I 12449' 1-1 4-1/2" TT W/BAKER WLEG I 13050' l-l CA-RKED W/O PRONG 1 13055' l-l 22' PERF GUN & CCL 3-1/8" 1 PRUDHOE BAY UNIT WELL: 14-21 PffiMfr!\b: 1820860 AA No: 50-029-20756-00 SEC 9. TlON, R14E 1364.03 ÆL 4846.25 FNL BP Exploration (Alaska) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: 14-21 (PTD 1820860) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 and Application for Sundry Approval form 10-403 for Well 14-21. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with known Tubing by IA communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments Alaska Oil & Gas So,Is. APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon r-~ suspend ~] Operation Shutdown ~] PerforateF~ Variance[] AnnuarDisposalr'-~ AlterCasin.q C~ RepairWell [--] Plu.qPerforations [~ Stimulate[-1 Time Extensionr"~ Otherr--] Chan.qe Approved Program [~ Pull Tubing r-] Perforate New Pool [~ Re-enter Suspended Well['-] H20 INJ VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development ~--1 Exploratory~] 182-086/ 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphicr-~ Service[] 50-029-20756-00-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 71.00 14-21/'" 8. Property Designation: 10. Field/Pool(s): ADL 028314 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4-1/2" Plug @ None 13060 9641 12360 (1010711999) 9119 12435' Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 110 20" 30'- 151' 30' - 151' 40K 520 Surface 2487 13-3~8" 30' - 2517' 30' - 2517' 80K 2670 Production 12006 9-5/8" 30' - 12036' 30' - 8877' 80K 4760 Scab Liner 1298 7" 11762' - 13060' 8682' - 9641' 80K 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: I Tubing Grade: Tubing MD (ft): 12091' - 12914' 8918' - 9531' 5-1/2" 17#, 4-1/2" 12.6# L-80 11804 Packers and SSSV Type: Packers and SSSV MD (ft): 9-5~8" x 5-1/2" BKR FB-1 PKR; 5-1/2" Cam BAL-O SSSV PKR @ 11707', SSSVLN @ 2156' 12. Attachments: Description Summary of Proposal l~ 13. Well Class after proposed work: Detailed Operations Program r-1 BOP Sketch E] Exploratory[]] Developmentr"l Service[] 14. Estimated Date for I } 15. Well Status after proposed work: Commencin~l Operation: ~· IrC~ 0 '~ Cilia] GasE] Pluggedr"] AbandonedF-~ 16. Verbal Approval: Date: WAGE] GINJ r--~ WINJ ~[~ WDSPLE] Commission Representative: Prepared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders Printed Name JCe A?,ers Title GPB Well Integrity Engineer Signature /fg~,'~,,_~,'~¢,J5~ Phone 907~ 659-5102 Date 09/10/2003 Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness _~'O~" Plug Integrity D BOP TestD Mechancial Integrity TestD Location ClearanceD Subsequent Form Required: Aiaska 0ii & Gas Cons,, uomrmss~o Anchorage Approved by: COMMISIONER THE COMMISSION Date: ,, Form 10-403 Revised 2/2003 ORIGINAL SUBMIT IN DUPLICATE 14-21 Description Summary of Proposal 09112103 Problem Injector with Rapid Tubing by IA communication. Current Sundry requirements are not aligned with Sundry Matrix. Well History and Status Well 14-21 (PTD 1820860) is an injector with Tubing by IA communication. CMIT-TxIA's pass, demonstrating competent production casing. Current Sundry requirements are not aligned with the Sundry Matrix dated 5/13/03. This proposal updates the Conditions of Approval to the current requirements. Pertinent well events: > 12/07/99: Sundry #399-248 issued for T x IA comm > 05/29/01: SL set TTP, CMIT TxIA passed to 3000 psi, pulled TTP > 05/12/03: Set TTP @ 11762' > 05/15/03: State witnessed CMIT TxlA to 3000 psi- Pass > 05/21/03: SL pulled TTP This request is to cancel the existing Tubing by IA Sundry and issue a new Sundry for Tubing by IA communication using current Conditions of Approval. The following supports the request: · A CMIT-TxIA passed on 05/21/03 to 3000 psi, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · A CMIT-TxlA will be conducted every 2 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform CMIT-TxIA every 2 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 71 BF. ELEV = · KOP = 2800' Max Angle = 56 @ 9600' Datum MD = 12027' . Datum TV D = 8800' SSI 14-21 S~?--ry NOTES: WAIVERED WELL. ***T x IA C~~ UNICATION AT 5566' (02/07/03 WAIVER)*** FLOWLINE FROZEN, CORROSION DAMAGE, TWINNED WITH 14-17, 2156' I-~ 5-1/2" CAM BAL-O SSSV NIP, ID=4.562" I GAS LIFT MANDRFI S 13-3/8" CSG, 72#, L-80, ID: 12.347" Id 2517' IMinimum ID = 3.750" @ 11796' 4-1/2" CAMCO DB NIPPLE [ 5-1/2"TBG-PC, 17#,L-80,.0232bpf, ID=4.892" Id 11725' ITOPOF4'I/2''TBG'Pc Id 11725' ITOPOFT" LNR I--~ 11762' PERFORATION SUMMARY REF LOG: BHCS ON 08/07/82 ANGLE AT TOP PERF: 42 @ 12091' Note: Refer to Production DB for historical perf data SiZE I SPFI INTERVAL I Opn/Sqz I DATE SEE PAGE 2 FOR PERFORATION DATA I 9-5/8" CSG, 47#, L-80, ID= 8.681" Id 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID= 3.958" 12036' ~ 11804' ITOP OF 4-1/2" TBG Id 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID= 3.958" Id 12395' 11805' [ 4-1/2"TBG, 12.6#,L-80,.0152bpf, ID=3.958" Id 12451' ~-~-~ ~ 13018' I 7"LNR, 29#,L-80,.0371bpf, ID=6.184" I--~ 13060' 11707' I-I 11709' I-t 9-5/8" X 5-1/2" BKR FB-1 PKR I 5-1/2"BAKERSBEASSY J 11725' Id 5-1/2"x4-1/2"x°l 11796' Id 804' Id 11781' Id 12395' Id 12435' Id 4-1/2" CAMCO DB NIP ID = 3.75" 4-1/2" TI'W/BAKERWLEG I ELMD TT LOGGED 02/05/88 7" X 4-1/2" BKR FB-1 ISO PKR I 4-1/2" MAGNA PLUG 12441' [1 4-1/2"CAMCODBNIPID=3.687" }W/BLANKiNG PLUG 12449' Id 13050' Id 13055' Id 4-1/2" 'iq' W/BAKER WLEG I CA-RKED W/O PRONG 22' PERF GUN & CCL 3-1/8"I DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/82 ORIGINAL COMPLETION 01/25/88 LAST WORKOVER 02/22/01 SlS-LG REVISION 01/08/02 RN/TP CORRECTIONS 02/20/03 /TLH WA IV ER SA FETY NOTE PRUDHOE BAY UNIT WELL: 14-21 PERMIT No: 1820860 APl No: 50-029-20756-00 SEC 9, TION, R14E 1364.03 FEL 4846.25 FNL BP Exploration (Alas ka) WELLHEAD = GRAY, -- , ACTUATOR = AXELSON KB. ELEv: 71' -- -- ~ .... I BF. ELEV = ~ KOP = 2800' Max Angle = 56 @ 9600' ~ Datum MD = 12027'~ ~ :, Datum TVD = 8800' SS ! , PERFORATION SUMMA RY REF LOG: BHCS ON 08/07/82 ANGLE AT TOP PERF: 42 @ 12091' Note: Refer to Production DB for historical perf data SIZE SPF! INTERVAL Opn/Sqz DATE 3-3/8" 4 12091 - 12112 O 12/20/89 3-3/8" 6 12202 - 12208 O 02/05/88 3-3/8" 6 12215- 12221 O 02/05/88 3-3/8" 6 12224 - 12264 O 02/05/88 3-1/8" ' 4 12464 - 12624 O 11/14/82 3-1/8" 4 12632- 12642 i O 11/14/82 3-1/8" 4 12648- 12698 O 11/14/82 3-1/8" 4 12714- 12764 O 11/14/82 3-1/8" 4 12816- 12866 O 11/14/82 3-1/8" 4 ~ 12894- 12914 O 11/14/82 PERFORATION SUMMARY REF LOG: BHCS ON 08/07/82 ANGLE AT TOP PERF: 42 @ 12091' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12091 - 12112 O 12/20/89 3-3/8" 6 12202 - 12208 O 02/05/88 3-3/8" 6 12215- 12221 O 02/05/88 3-3/8" 6 12224 - 12264 O 02/05/88 3-1/8" 4 12464 - 12624 O 11/14/82 3-1/8" 4 12632- 12642 O 11/14/82 3-1/8" 4 12648- 12698 O 11/14/82 3-1/8" 4 12714- 12764 O 11/14/82 3-1/8" 4 12816- 12866 O 11/14/82 3-1/8" 4 12894- 12914 O 11/14/82 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/82 ORIGINAL COMPLETION 01/25/88 LA ST WORKOV ER 02/22/01 SlS-LG REVISION 01/08/02 RN/TP CORRECTIONS 02/20/03 /TLH WAIVER SAFETY NOTE DATE REV BY COMMENTS DATE REV BY. COMMENTS PRUDHOE BAY UNIT 08/13/82 ORIGINAL COMPLETION ~ WELL: 14-21 01/25/88 LAST WORKOVER PERMIT No: 1820860 02/22/01 SlS-LG REVISION APl No: 50-029-20756-00 01/08/02 RN/TP CORRECTIONS SEC 9, TION, R14E 1364.03 FEL 4846.25 FNL 02/20/03 /TLH WAIVER SAFETY NOTE I BP Exploration (Alas ka) 14-21 T~O Plot 4,00O e Tbg 3,000 2,000 0 ~ 9/9/2002 11/9/2002 1/9/2003 3/9/2003 5/9/2003 7/9/2003 9/9/2003 ~ OA OOA e OOOA BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: 14-21 (PTD 1820860) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 and Application for Sundry Approval form 10-403 for Well 14-21. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with known Tubing by IA communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments RECEIVED SEP '1 '/2OO,. Alaska 0il & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr~ Suspendr-] Operation Shutdown[~ PerforateE] varianceE] Annuar Disposal[-'] After Casin.qF1 RepairWellr-] Plug Pefiorations~ Stimulate~ Time Extension~ Other~ Change Approved Program~ Pull Tubing~ Pedorate New Pool~ Re-enter Suspended Well~ CANCEL 10403 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement ~ Exploratow~ 182-086 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic~ Se~ice ~ 50-029-20756-00-00 7. KB Elevation (fi): 9. Well Name and Number: 71.00 14-21 8. Prope~y Designation: 10. Field/Pool(s): ADL 028314 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summaw: Total Depth measured 13060 feet true vertical 9641 feet Plugs (measured) 4-1/2" Plug set ~ 12435'. Effective Depth measured 12360 feet Junk (measured) true vertical 9119 feet Casing Length Size MD ~D Burst Collapse Conductor 110' 20" 151' 151' 40K 520 S u dace 2487' 13-3/8" 2517' 2517' 80K 2670 Intermediate 12006' 9-5/8" 12036' 8877' 80K 4760 Liner 1298' 7" 11762'-13060' 8682'-9641' 80K 7020 Pedoration depth: Measured depth: Open Peds 12091'-12112', 12215'-12221', 12224'-12264' Peds Below Plug 12464'-12624', 12632'-12642', 12648'-12698', Peds Below Plug (continued) 12714'-12764', 12816'-12866', 12894'-12914'. True ve~ical depth: Open Peds 8918'-8933', 9010'-9015', 9017'-9047' Peds Below Plug 9196'-9315', 9320'-9328', 9332'-9369' Perfs Below Plug (continued) 9381'-9419', 9457'-9495', 9516'-9531'. Tubing: ( size, grade, and measured depth) 5-1/2" 17¢ L-80 TBG ~ 11725'. 4-1/2" 12.6¢ L-80 TBG ~ 11804'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker FB-1 Packer ~ 11707'. 5-1/2" Camco BAL-O SSSV Landing Nipple ~ 2156'. 12. Stimulation or cement squeeze summary: '~ Inte~als treated (measured): ,,~aska 0~ & Gas Cons. Com~ssio~ Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. AEachments: 15. Well Class after proposed work: Exploratory~ Development~ Service~ Copies of Logs and Surveys run ~ 16. Well Status after proposed work: OilD GasD WAGD GINJD WlNJ~ WDSPLD Daily Report of Well Operations ~ prepared by DeWayne R. Schnorr 564-5174 ,17. I hereby ceAi~ that the foregoing is true and correct to the best of my knowledge, lSundry Number or N/A if C.O. Exempt: Contact Joe Anders ~ 399-248 Printed Name Joe Anders Title GPB Well Integrity Engineer Signature ~(~ ~~ 0 ~ ~ ~ i k~h~e~ 907, 659-5102 Date Sept 10. 2003 Form 10-404 R d 2~2003 ~ , ~ ~ I I ~ I I ~ \' \'J ~ ....:> fi:-\ \. 'j c Summary of Sundry Changes 09/12/03 Well Request 10-403 10-404 04-45 Align Conditions of Approval with Sundry XX XX Matrix 09-12 Align Conditions of Approval with Sundry XX XX Matrix 11-10 Align Conditions of Approval with Sundry XX XX Matrix 11-29 Align Conditions of Approval with Sundry XX XX Matrix 14-21 Align Conditions of Approval with Sundry XX XX Matrix A-31 Align Conditions of Approval with Sundry XX XX Matrix P1-01 Align Conditions of Approval with Sundry XX XX Matrix P-14 Cancel Sundry XX Y-03 Cancel Sundry XX Contact Joe Anders or John Cubbon with questions. (907) 659-5102 L 1« ~ - ðf(P Comments Wellis L TSI Well is L TSI SCANNED OCT 1 0 2D04 MEMORANDUM State of Alaska ~'/~~Alaska Oil and Gas Conservation Commission TO: Randy Reudrich ~J',,'-'-t--- DATE: May 15, 2003 Commissioner ~~'"~).~,,.~,.,~,' SUBJECT: Mechanical Integrity Tests THRU: Jim Regg~<,,,,~.,~u~ · BPXA P.I. Supervisor DS-14, S,M,D Pads 14-17A, 14-21, S-215, M-29A, D-24 FROM: Jeff Jones PBU Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I14-17A I Typelnj. I GI T.v.~. I~ I ~u~,.,I ~oI ~1 ~1 ~1Interval 4 P.T.D.I 2030010 I TypetestI P I TestpsiI 21301 CasingI 2701 35001 34401 34201 P/FI P Notes: Test fluid 6.9 bbls 60/40 meth~,"fbl w~,,I ~-2~ I*y~.,ni.I S ~.V.D.I ~ I ~u~,~l ~01 ~0~01 ~0~01 30101,nterval2N P.T.D.I 1820860 I TypetestI P /TestpsiI 1500 I Casingl 4001 30401 30101 30001 P/FI P Notes: Test fluid 17 bbls 60/40 methanol. 2 year CMIT TxlA: TBG leak ~ 5566 MD; TTP set (~ 11762 MD we,IIs-215 i~,~,~.1 ~ I~-V.D. I ".~'1~u~'~ I ~o~ol ~o~ol ~o~ol ~o~ol Interval I P.T.D.I 2021540 I Type testI P I Test psiI 1500 I Casing I 8801 20401 19001 18401 P/FI P Notes: Test fluid 1 bbl 60/40 methanol w~,,I M-~A I T~,~,~.I ~ IT'V'~' I TM I ~'~1 ~°1 ~1 ""°1 ~°l'~'e~l P.T.D.I 2000990 I TypetestI P I TestpsiI 3500 I Casingl 5601 35201 35001 35001 P/FI P Notes: Test fluid 3.2 bbls 60/40 methanol We,,I D-24 I Type,nj.I N I~.v.~. I~o~ I Tu~,~,I ~1 ~i ~1 ~1 Interval O P.T.D.I 1852990 I Type testI P I Test psiI 2010 I Casingl 60l 22401 21501 21251 P/FI P Notes: Test fluid 4.6 bbls 60/40 methanol. (MITIA post-patch set on a category B-3 well) We,,ID-24I T~,.,~j.I N I~.v.~.l ~0,~ I "'1 ~1 ~01 ~01 22301'nterval OI P.T.D.I 1852990 I Typetestl P I Testpsil 3000I OAI 851 30001 28801 28401 P/FI P Notes: Test fluid 2.3 bbls 60/40 methanol (MITOA on a cata~or~ B-3 well) Type INJ. Fluid COdes F = FRESH WATER INJ. O = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) May 15, 2003: I traveled to BPXA's Prudhoe Bay Field wells 14-17A, 14-21, S-215, M-29A and D-24 to witness Mechanical Integrity Tests. JeffRea was the BPXA representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with each well passing the MIT. Well 14-21 has a known tubing leak at 5566' 1VID and a tubing tail plug was set at 11762' lvlD to accomplish a successful 2 year interval combination Tx IA MIT for Sundry #399-248. Well D-24 is a BPXA designated catagory B-3 well and both the IA and the OA passed the MIT. Five well houses were inspected with no exceptions noted. Summary: I witnessed successful MIT's on BPXA's Prudhoe Bay Field wells 14-17A, 14-21, S-215, M-29A and D-24. Five well house inspections conducted. M.l.T.'s performed: 6 Number of Failures: 0 Total Time during tests: 7.5 hrs Attachments: wellbore schematics (5) cc: MIT report form 5/12/00 L.G. MIT PBU 14-17A,14-21,S-215,M-29A,D-24 5-14-03 JJ.xls 5/20/2003 JUN 1 .~ 2003 TREE= GRAY GEN 3 WELLHEAD = CALICO F ACTUATOR = AXB_SON KB. ELEV = 71' BF. REv' = KOP = 2900' Max Angle = 96 @ 11658' Datum rVD = 10562' Datum TVD = 8800' SS I 13-3/8"CSG, 72#,L-80,1D:12.347" Id 2500' IlVlinimum ID,~ 2.372" @ 10713' .XO TO 2-7/8 STL LINER I5-1/2" TBG-IPC, 17#, L-80, 0.0232 bpf, ID: 4.892" H ]TOPOF 4-1/2"TBG-IPC Iq ITOP OF 7"LNR H 4-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 3-1/2"TBG, #,L-80,.0000bpf, ID=2.992" Jq I 9-5/8"CSG, 47#,L-80, D=8.681" Id ITOP OF WHIPSTOCK Iq ITOP OF WINDOW Iq PERFORATION SUMMARY REFLOG: 14-17A SPERRY MWD ON 01/17/03 ANGLE AT TOP PERF: 93 @ 11900' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 " 4 1 t897 - 12447 Opn 01/18/03 2" 4 12497- 12547 Opn 01/18/03 JTOP OF 4-1/2" TBG-IPC ITOPOF BRDGEPLUG Jq J4-1/2" TBG-IPC, 12.6/¢, I. 7" LNR, 29#, L-80, 0.0371 bpf, ID: 6.184" Id 14-17A SAFETY NOTES: H2S W ELL I 10149' 102 02' 10243' 10492' 10492' 10588' 10589' H 5-1/2 "CAMBAL-O SSSV NIP, ID:4.562" I 5-1/2" BAKER LOC SEALASSY J 9-5/8"X 5-1/Z' BKR PERM FKR I 5-1/2" X 4-1/Z' XO I 10185' 1~3-1/2" DEFLOYMENTSLE~VE, ,D= 3.0O" 10204' H3-1/2" HOWCONO-GOXN NIP, D =2.750" 10231' H 10242' I--I 10234' H 4-1/2" OTIS XN NIP, ID= 3.725" 4-1/2" BKR SHEAROUT SUB WLEG 4-1/2" TUBINGTAIL I R MD TT LOGGED 05/16/91I 10350' IdTOPOFCBVIENT ] 10559' Id3-1/2"X3-3/16"XO, D=2.800"I 10713' I-~3-3/16" X 2-7/8" XO, ID = 2.441" I 10838' 10848' 10849' 11358' 11400' 11400' 3-3/16"LNR, 6.2#,L-80, Id 10713' .0000 bpf, ID = 2.80" ( 12585' H2-7/8'' LNR, 6.16#,L-80, .0000 bpf, D =2.441" I I-tTUBING TAIL I DATE REV BY COMIVENTS DATE REV BY OOIv~ENTs 05/23/82 ORIGINAL COMFLE-rlON 01/18/03 TMrVVTP CTD HORIZONTAL SIDETRACK 02/24/03 TH/KAK PERFCORRECTIONS ,,. PRUDHOE BAY UNIT WFIL: 14-17A PERMIT No: 1810210 APl No: 50-029-20562-01 SEC 9 T1 ON R14E4282.68' FEL & 1 682.64' FNL BP Exploration (Alaska) TREE= GRAY GEN2 SAFETY NOTES: WAIVB~EDWELL. ***T x IA 14 21 ACTUATOR = AXELSON '~i EL~ = 71 FLOWt. INEFROZEN, CORROSION DAMAGE, TWINNED WITH 14-17. BF. ELEV= ,,, KOP = 2800' MaxAngle= 56@960(j'; I 2156' ~--~ 5-1/Z'CAMBAL-OSSSV NIP, ID'=4.562" 'Datum IVD = 12027, Datum TVD = '§800' SS ~ GAS LIFT MANDRELS ST IVD TVD DEV TYPE VLV LATCH PORT DATE 1 3552 3513 26 MIVH RK I ~-~'~"°~,~#,~-~°,'~= ~.~4~,, Id 2s~r I i k ~ ~4~ ~0~ ~ ~ ~.~r._~.__ ~--~'L 5 113758418 49 MIVH RE '5~G=/'H'~ 6 115238517 47 Urvl-I RKP Minimum ID = 3.750" @ 11796' 4-1/2" CAMCO DB NIPPLE ><: :>< I~ 11707' ~ 9-5/8"X5-1/2"BKRFB-1PKR I 5-1/2"TBG-PC, 17#,L-80,.0232bpf, ID=4.892" I--{ 11725' t /Ir 11709' ]-~ 5'I/2''BAKERSBEASSY I ITo~OF,~,~'.~-PC I--[ .~25'~ . .' =~,25" I--I ~-~'2"x~-~'~"x°l ITOPOF?'LNR ~ 11702' i~i~j PERFORATION SUMMARY I i r L 11796' ]"'~ 4-112"CAIV~2,0DB~IPlD=3.75"I REF lOG: BH~ ON 08107182 ANGLEATTOP PERF: 42 @ 12091' Note: Refer to ProduclJon DB for historical perf data ,, S~ZE I s~=l INTERVAL IOpn/SqzI DATE SEE PAGE 2 FOR PERFORATION DA TA 14.1/2,'TBG'PC'12.6#'L'80,'0152bpf'ID=3.958.' I"-I 11804' ] ) \ [11804' Id 4'I/2"TTW/BAKERWLEGI 4'1/2'' TBG'PC'12.6#' L'o0, '0152 bpf' ID = 3.958.' Id 11805' X] ~ [12395' Id 7"X4-1/2"BKRFB-11SOPKR I ~ I i24a~' I-I 4-1/2" MAGNA PLUG I "~ ~'. [ 12441' ]-~ 4-1/2" CA~CO DB NP ID = 3,68~" / W/BLANKING PLUG E~-1/2.'TBG,12.6#,L-8°,.°ls2bpf,D=3.958.' H 12451, I [~--~-q ~,o~' I ----4 ~oso' id, °^-~°~° ~ I [ 7"C~R, 2O#,C-80,.O371bpf, ID:~.184" ~-~ 15060' ] DATE R~q BY CO~'vll~lS DATE REV BY GOM~NTS FRLDHOE BAY UNIT 08/13/82 ORIGINAL OD~LEI'ION WELL: 14-21 01125188 ' LAST WOF~OVI~ PEI~II No: 18208~0 02122101 SIS-/G I~=VISION API~o: 50-020-2075g-00 01/08/02 RN/IP ODRREGIION$ SEC ~, TION, R14E 1364.03 FEL 4848.25 02/20/03 /'II_H WAIV ER SAFETY NOTE BP Explo ration (Alas ka) DATE REV BY COrviVIENTS DATE REV BY COMIVENTS 08/13/82 ORIGINAL COIVPLETION 01/25/88 LAST WOF~OV ER 02/22/01 SIS-LG REVISION 01/08/02 RN/TP CORRECTIONS 02/20/03 /ltH WAIV ER SAFETY NOTE TREE: CIW 4-1/16" 5M WELLFEAD = FMC GEN ~ S 215SAFETY NOTES: 4-1/2" CHROME'rBG. :ACTUATOR = ' ....... aa , 'KB. ELEV = 72 I~1:~ ~= 41 KOP = 2238, , Max Angle = 50 @ 3723' DatumMD= 6256' · k--I 114' I'-I 20"X 34"215.5 b/ft, A53 ERWINSULATED'J Datum'l'VD = 5000; SS · ." '.~-~ 976' H TAM PORTCOLLAR J I I t 2224' J-j 4-1/2"HESXNIP, ID=3.813"I H _ ST MD TVD BEV TYPE VLV LATCH PORT DATE ~"~-- -- -T' 347'-'~' 320~ 5'-'~- KBG-2 R~ BK -- '08/16/02 , / Minimum ID = 3.725" @ 5648" -- i 4-112" HES XN NIPPLE ~ J 5535' ~" 4-1/2"BKRCMDSLIDINGSLV, W/4-1/Z' X NIP, ID = 3.813" NOTE: SHIFT SLEEVE DOWN TO OPEN, ~ SHIFT UP TO CLOSE - 04/28/03 ~z~ '> ~] ~ ~ 5599' HT"X 4-1/2"BKRPRMPKR, ID=3.87*'I I I t H 4-U2"HESXNNP,,D=3.725"J I I 5651' H ELmTT LOGGED 03/31/03 J PEI~ORATION SUMMA RY REF LOG: SPERRY rVfWD ON 08/06/02 I ANGLE AT TOPPERF: 45° @ 6098' Note: Refer t~ Production 1313 for historical perf data .SIZE SPF INTERVAL Opn/Sclz DATE 2-7/8 2 6098- 6110 = O 05/06/03~ 5741' 'H 2-7/8" 2 6120-6130 ! O 05/06/03 I' I~ J 7" MARKER JOINT II 2-7/8" 2 6150- 6170 O 05106/03 I1 2-7/8" 2 6240- 6260 O 05106/03 2-7/8" 2 6265- 6280 O 05106/03 I 6204' I II 7" MARKER JOINT' I 2-7/8" 2 6302- 6342 O ! 05106/03 I I--I I 2-7/8" 2 6335- 6380 0 05106/03 2-7~8" 2 6430- 6450 O , 05/06/03 2-7~8" 6 ' , 6505- 6525 O ' 03/31/03 2-7~8" 2 6525- 6545 O 05/06/03 2-7/8" 2 6585- 6595 O 05/06/03 I I J DATE REV BY COMk~NTS DATE I REV BY COMIVENTS POLARIS UNIT 06/16/02 DAV/KK ORIGINAL COMFLETION J WELL: $-215 03/14/03 JJ/TLH CORRECTION ~ PERMIT No: 2021540 03/31/03 CAO/3]_H ADPERF APl No: 50-029-23107-00 04/08/03 DRS/TP TVD/IVD CORRECTIONS SEC 35, T12N, R12E, 3276' NSL & 4563' WEL 04/28/03 RL/TP NOTEA DDED TO SSLV-5535' 05/06/03 BJM/KK ADPEI:~S BP Exploration (Alaska) PERI:ORATION SUMMA RY REF LOG: SPERRY rVfWD ON 06/06/02 ANGLE AT TOPPERF: 45° @ 6098' Note: Refer t~ Production 1313 for historical 3err data .SIZE SPF INTERVAL Opn/Sclz DATE 2-7/8" 2 6098 - 6110 O 05/06/03 2-7/8" 2 6120 - 6130 O 05/06/03 2-7/8" 2 6150 - 6170 O 05/06/03 2-7/8" 2 6240- 6260 O 05/06/03 2-7/8" 2 6265- 6280 O 05/06/03 2-7/8" 2 6302- 6342 O 05/06/03 2-7/8" 2 6335- 6380 O 05/06/03 2-7/8" 2 6430- 6450 O 05/06/03 2-7/8" 6 ' . 6505- 6525 O 03/31/03 2-7/8" 2 6525- 6545 O 05/06/03 2-7/8" 2 6585- 6595 O 05/06/03 DATE REV BY COMNENTS DATE REV BY COMIVENTS 06/16/02 DAV/KK ORIGINAL COMFLETION 03/14/03 JJ/TLH CORRECTION 03/31/03 CAO/%H ADPERF 04/08/03 DRS/TP TVD/Iv[) CORRECTIONS 04/28/03 RL/TP NOTEA DDED TO SSLV-5535' 05/06/03 BJM/KK ADPEI:~S TREE = 7-1/16" CIW WELLFF_.A D = McEVOY M 29A SAFETY NOTES: SLTD LNR 10696' ' 10761' ' 70° ACTUATOR = OTIS w @ 9744' & 90° @ 9847' KB. ~ = 56.i ;i . BF. ELEV -' 28.11 ' KOP= 3189" DatumMaX Angle =MD = 103@9917'105~1 ~ ~-- i'lII 2098' H7" OTIS SSSV LA NDING NP, ID = 5.'962" I DatumTVD = 8800' SS I I-I i Minimum ID = 2.37" @ 8648' I ~TOP OF 2-7/8" LINER I~,',~.~,~,.-.o-.~cc,.o~.,,,o=~.~,, H0498'~ -\ /'--~! 8498' HT"X 5'1/2" XO I I~o,o.~-~,~"~Id'8498' ------- -- I Fi-i-] I 85°"' I-I~-~'~" °~ XA ~"~ ~"v"~ = ~:~" I I II I8631' I~ 5-1/2" OTIS X NP' ID = 4'562" I I.o.o.~-~".~.1-I 8648'I ,.~ t 8~48' I-lo~.-o¥~.~'~u. I i,o.o.~,,.,, i_i S720, ITO~OFr'BAKEaW.PS*OC~ I-q 9Sa0' ~_ X ~'X .... ~ ~" ~ 10t~40'~- H~ QBP (04/18/03) ~~ , ,, PBTD 10256' ~ ' """ """ ,. , ~~-~ ~ ',, ' ~.~lTOP OF 2_7/8.. CNR I- .. , / xx .~~,~,.<~>~.~/~,,~,[~s PERFORATION SUMMARY ..:.o~: ~¥ ~wo,~..oO. o.,~,oo AI~IEATIOPFt~RF: 80 @ 10145' IL_80,.0058 bpf, ID=2.44- Note: Refer to Production DB for historical pod data ' SIZE SPF NTERVA L Opn/Sqz DATE 2 6 10145- 10170 O 04/18/03 2 6 10245 - 10270 O 04/18/03 , 2-7/8" 10696 - 10761 SLID 07/21/00 I DATE REV BY COMIVENTS DATE REV BY OOMMENTS PRUDHOE BAY UNIT · 02/04/89 INITIAL COIVPL AS NJECTOR WELL: M-29A 07/18/00 ! JCM CTD SIDETRACK FERMIT No: 2000990 01/15/01 SIS-MD INITIAL REDRAW APl No: 50-029-2190~01 i..03/08/02 RN/TP CORRECTIONS ,,, SEC 1,,,T11 N, R12E 04/18/03 DDW/TLH ADD PERF & CIBP , ..... BP Exploration (Alaska) ,,,, FERFORATION SUMMARY RB: LOG: SFERRY MWD/GR ON 07/16/00 ANGLEATTOP FERF: 89° @ 10145' Note: Refer to Production DB for historical perf data SIZE SPF NTERVA L Opn/Sqz DATE 2 6 10145- 10170 O 04/18/03 2 6 10245 - 10270 O 04/18/03 2 6 10350- 10375 O 04/18/03 2-7/8" 10696 - 10761 SLTD 07/21/00 D 24 ' A CTUA TOR= OTIS , KB. ELEV = 71.6'r BF. ELEV = 44.32 I KOP -- 1650'I Datum TVDss= 8800' ST IVD TVD i DEV TYPE SIZE LATCH ' ' 6 33881 3119 40 OTIS-LBD' 1-1/2" RA : m ~. 5 5412~ 4619 44 OIIS"LBD 1-1/2" 4 7328 5~0 41 OTIS"LBD 1-1/2" 2 9310 7554 30 OTIS"LBD 1-1/2" (~ ~'~') 19548 7761 29 OT,S-LBD 1-1/2" RAI Minimum ID: 2.970"@ 7545' ~ I5'1/2.' TBG'17#' L'80, '0232 bPf' ID = 4'892'' Id 9920' ]~--I I I..~2' IdELMD-'R'-DATENOTAVAILABLEI FERFORATION SUMMA RY REF LOG: SWS"BHCS ON 12/26/85 i ANGLE AT TOPPERF: 19 @ 10833' Note: Refer to Production DB for historical perf data ! SIZEISPF INTERVAL Opn/Sqz, DATE : [] 4" 4 10833- 10843 S 01/01/90 4" 4 10856 - 10873 S i 01/01/90 4" 4 10878 - 10891 S I 01/01/90 ~,' MACKIt[ JOINI 3-3/8" 4 10840- 10842 O 03/07192 3-3/8" 4 10856- 10873 O i 01/04/91 3-3/8" 4 10878- 10891 0 01104191 3-3/8" 4 10894- 10900 O 01/04/@1 DATE ~ BY ODMMI~qTS DATE R~ BY COMMENTS FRLDHOE BAY UNII 12/30/85 ORIGII~L COMPLEIION WI~.L: D-24 05/19/01 RIxI/'I~ CORI~CTIONS PERMIT No: 1852990 05/06/03 BdM~KK SET 5-1/2" ECl. IFBEPKR APINo: 5O-O29-21508-00 05/11/03 BJM/KK S ET 5"'1/2" ECLIPSE PKR SEC 23, 111 N, R13F_ BP Exploration {Alaska) PERFORATION SUMMA RY REF LOG: SWS"BHCS on 12/26/85 ANGLE AT TOPPERF: 19 @ 10833' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10833- 10843 S 01/01/90 4" 4 10856 - 10873 S 01/01/90 4" 4 10878 - 10891 S 01/01/90 3-3/8" 4 10840- 10842 O 03/07/92 3-3/8" 4 10856- 10873 O 01/04/91 : 3-3/8" 4 10878- 10891 O 01/04/91 3-3/8" 4 10894- 10900 O 01/04/91 DATE REV BY COMMBqTS DATE REV BY COMMENTS 12/30/85 ORIGINAL COMPLETION 05/19/01 RN/TP CORRECTIONS 05/06/03 BJM/KK SET 5-1/2" ECLIPSEPKR 05/11/03 BJM/KK SET 5"'1/2" ECLIPSEPKR ,, STATE OF ALASKA f' 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 _ Vadance X Perforate_ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ¢" ¢' ~/ 2714' FNL, 1560' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 992' FSL, 1221' FEL, SEC. 16, T10N, R14E, UM At effective depth At total depth 4846' FNL, 1364' FEL, Sec. 16, T10N, R14E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic _ Service X -- 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-21i 9. Permit number / approval number 82-86 10. APl number 50-029-20756 v''/ 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" S u trace 2446' 13-3/8" Production 11965' 9-5/8" Liner 1298' 7" Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 13060 9641 12360 9119 feet Plugs (measured) feet ¢/ feet Junk (measured) feet Cemented 350 Sx PF II 2500 Sx AS III & 400 Sx AS II 500 Sx Class G & 300 Sx AS II 400 Sx Class G PBTD tagged @ 12360' MD (10/07/1999) Isolation Packer @ 12395' MD. 0RiG/ AL Measured Depth True veAical Depth 110' 110' 2517' 2517' 12036' 8893' 13O6O' 9641' 12091'-12112'; 12202'-12208'; 12215'-12221'; 12224'-12264'. RECEIVED .... 1999 8918'- 8933'; 9001'- 9005'; 9010'- 9015'; 9017'- 9047'. AlasKa 0i~ & Gas Cons. 60minisstof 5-1/2", 17#, L-80 PCT @ 11725' MD; 4-1/2", 12.6#, b-80 PCT @ 11805' MD. Anchorage 9-5/8" X 5-1/2" BAKER FB-1 PACKER @ 11708' MD; 7" x 4-1/2" Baker FB-1 Isolation Packer @ 12395' MD. 5-1/2" CAMCO BAL-O SSSV @ 2157' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation Immediately 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas ~ Suspended Service WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jerry J~ethlefs Questions? Call Brandon France @ 265-6937. Date /':~/~.~ Prepared by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~40~.. I~,l¢,.~,,r.,e,~ _c,.~:::~e~ I Location clearance __ ~;ll~r.~ ~..'~\~,, ~\~.~.. I Plug integrity __ BOP Test __ Mechanical Integrity Test __ Approved by order of the Commission Form 10-403 Rev 06/15/88 · Subsequent form required 10- ORIGINAL SIGNED'BY /~~ ~ Robe~ N. Chdstenson OO9~ Commissioner Date ~rowe6 Return to:~~4~ SUBMIT IN TRIPLICATE DS 14-21 WAG Injection Well SUNDRY NOTICE 10-403 VARIANCE REQUEST 12/04/99 DISCUSSION Well 14-21 is a water-alternating-gas (WAG) injection well that has tubing x 9-5/8" annulus communication. The AOGCC was notified on 8 / 15 / 99, and diagnostic testing was initiated. On 9 / 21 / 99 a Leak Detect Log was performed, finding a leak in the tubing mid-joint at 5566' MD in the 5- ~/2" L-80 tubing. A caliper survey of the tubing 10 / 7 / 99 indicates significant enough damage to not be considered a good patch candidate. On 12/1/99 a passing combination MIT (CMIT T x IA) was performed to 3000 psi against a tail-plug (test form attached). The ARCO engineering staff has determined the economics and benefits of a rig workover do not justify the expense to replace the tubing. This variance request is for AOGCC approval to continue injection of produced water into the well (no MI allowed). The request is supported by the following: · A passing combination MIT (T x IA) was performed on 12/1/99 to 3000 psi against a tubing tail plug showing 9-5/8" casing integrity. · The normal wellhead injection pressure is approximately 1000 psi at 5,000 bwpd; the maximum wellhead injection pressure was 2500 psi at 20,000 bwpd rate prior to shut-in. · The wellhead has integrity per packoff testing on 8/6/99. RECEIVED ACTION PLAN , ,c 101999 1. Allow well to continue water-only injection; nlu~.lill~(lll&0~la0ffia.~ 2. Perform an annual CMIT T x IA to 3000 psi against a ~. s, ~~ 3. Record wellhead pressures and rates daily; 4. Submit monthly reports to the AOGCC of daily injection rate, tubing and annulus pressures; 5. Shut-in the well should MIT's or injection rates and pressures indicate further problems, and notify the AOGCC. ARCO ALASKA, INC. Tubing-PC Casing Casing Gas Lift Mandrel/Dummy Valve 1 Gas Lift Mandrel/Dummy Valve 2 Gas Lift Mandrel/Dumrny Valve 3 Gas Lift Mandrel/Dummy Valve 4 Gas Lift Mandrel/Dummy Valve 5 Gas Lift Mandrel/Dummy Valve 6 PKR SBE Tubing-PC XO 11796' MIN tD = 3,750" (4-'1/2" Camco DB Nip) ' Liner WLREG Perf Perf Perf '," Perf ISOPKR 12435, MIN iD = 0:~0i" "' (4~1/2" Magna Plug) PLUG WLREG Perf ........................ I Perf Perf ' , ISO Perf-..' FISH FISH APl: 500292075600 SSSV Type: Annular Fluid: Diesel/SW Reference Log: BHCS Last Tag: 7951' SLM Last Tag Date: 8/17/99 Well Type: INJ D~PthiAr~ta~ons Depth Comment 11796 11796' MIN ID = 3.750" (4-112" Camco DB Nip) 12435 12435' MIN ID = 0.001" (4-1/2" Magna Plug) :Gene!~a!~iN~tes Date Note Prudhoe Bay t4-2t Odg Compltn: 8/13/82 .... Angi~'@' fDi' '4i' deg @ 13060' Last W/O: 1/25/88 Rev Reason: Tag Ref Log Date: 8/7/82 Last Update: 9/28/99 RKB: 71 ff TD: 13060 ftKB Max Hole 56 deg @ 9600 Angle: Angle @ TS: 41 (leg @ 12197 TTL ELM @ 11781: ELM Tubing Tail (Logged 02~05~88) Dateru~i !9~2;0~T.!.3 ............ :: Ot~i~i {i~!i~gs;:: eq~iiii~::;; etc;) ..JEWELRY Depth TVD Type Description 2156 2156 SSSVNIP 5-1/2" Camco BAL-O SSSV Nipple 11707 8643 PKR 9-5/8" x 5-1/2" Baker FB-1 Packer 11709 8645 SBE 5-1/2" Baker SBE Assembly 11725 8656 XO Crossover 5-1/2" x 4-1/2" 11796 8706 NIP 4-1/2" Camco DB Nipple 11804 8711 WLREG 4-1/2"TT w/BakerW/L Re-entry Guide 12395 9145 ISOPKR 7"x4-1/2" Baker FB-1 Isolation Packer 12435 9174 PLUG 4-1/2" Magna Plug 12441 9179 PLUG 4-1/2" Camco DB Nipple ID=3.687" w/Blanking Plug 12449 9185 WLREG 4-1/2" TT w/Baker W/L Re-eh[fy Guide 4.562 0.000 0.000 0.000 3.750 0.000 0.000 0.001 0.001 0.000 Depth Description Comment Date 13050 FISH CA-RKED W/O Prong 6/16/89 13055 FISH 22' Perf Gun & CCL 3-1/8" 11/9/82 Size Weight Grade Top Btm Feet Description 9,625 47,00 L-80 0 12036 12036 Casing 13.375 72.00 L-80 0 2517 2517 Casing 7.000 29.00 L-80 11762 13060 1298 Liner Size Weight Grade Top Btm Feet Description 5.500 17,00 L-80 0 11725 11725 Tubing-PC 4.500 12.60 L-80 11725 11805 80 Tubing-PC Stn MD TVD Man Man V Mfr VType VOD Latch Port TRO Date VIv Mfr Type Run Commenl 1 3552 3512 MMH CA RD 1.5 RK 0.000 0 6/14/89 2 5746 5011 MMH MC VR-D 1.5 RK 0.000 0 8/25/89 3 7869 6302 MMH CA RD 1.5 RK 0.000 0 6/9/89 4 9928 7530 MMH CA RD 1.5 RK 0.000 0 6/14/89 5 11375 8418 MMH CA RD 1,5 RK 0,000 0 6/14/89 6 11523 8517 MMH CA RKED 1.5 RKP 0.000 0 8/25/89 Interval TVD Zone 12091 - 12112 8918 - 8933 SAG 12202 - 12208 9001 - 9005 ZONE 4 12215- 12221 9010 - 9015 ZONE 4 12224 - 12264 9017 - 9047 ZONE 4 12464 - 12624 9196 - 9315 ZONE 4,ZONE 3 12632 - 12642 9321 - 9328 ZONE 3,ZONE 2 12648 - 12698 9332 - 9369 ZONE 2 12714 - 12764 9381 - 9419 ZONE 2 12816 - 12866 9458 - 9495 ZONE 2 12894 - 12914 9516 - 9531 ZONE 2 Status Feet SPF Date Type 0 21 412/20/89 APERF O 6 6 2/5/88 APERF O 6 6 2/5/88 APERF O 40 6 2/5/88 APERF O 160 4 11/14/82 IPERF O 10 4 11/14/82 IPERF O 50 4 11/14/82 IPERF O 50 4 11/14/82 IPERF O 50 4 11/14/82 IPERF O 20 4 11/14/82 IPERF COmment Interval Date Type Comment 12464-12914 5/15/88 ISO CHOKE PACKER WITH PLUG RECEIVED Mil~ HANICAL INTEGRITY TEST (M('~, W L .O.I FORM WELL TYPE (Circle one): Prod Prod A/L MI SWl ~Wl'hW Disp MIT TEST TYPE: I"/~ /~ ~ I (i.e., IA {9 5/8"}, OA {13~3/8"}, Tx IA combo, etc...) REQUIRED TEST PRESSURE: I ~ ~1 (For Ann Comm or injection well work, please consult the ACE if there's any question: x5102 ! pgr 1-154). FLUID TYPE(S) USED TO PRESSURE TEST: I ~/~/'~7~ I Record All Wellhead Pressures before and durin Test./2 I /~,:~,~ PRE MIT INITIAL I~I'IT 15 MINUTE 30 I~IlNUTE PASS __1/'a PRESSURES PRESSURES PRESSURES PRESSURES OR T START TIME: E (PSI) (PSI) (PSI)* (PS1)** FAIL S TUBING /~e r~00 ,,~ ~0~ ~~ ~.~ T IA or {9-5/8"} /~'C~ ..~/00 .~9~ ~2~ ~" OA or {13-3/8"} ~,,.~ ~ ~ 17Q,.~ ' I PRE Mil INIIIAL Mil 15 MINUIE $0 MINUIE PASS T START TIME:.I... PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA or {9-5/8"} OA or {13-3/8"} 2 COMMEN1 I PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME: ... PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) FAIL S TUBING T IA or {9-5/8"} OA or {13-3/8"} 3 COMMEN1 IMISC COMMEi~ TEST *Start the MIT over if press loss is · 5?/o @ 15 minutes. **Repeat the MIT if press loss is · 10% @ 30 minutes. FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!I! r""'"l -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION N -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. r""~ -- NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: l ~'~ ,~. J RECEIVED [:,~C 10 1999 cc: ACE 10/22/95 ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 December 4, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: DS 14-21 Sundry Notice Variance Request Dear Mr. Wondzell: Attached is a Sundry Notice 10-403 variance request for well 14-21. The request is for approval for continuing PWI injection into the well with known tubing by annulus communication. Details of the proposed monitoring and testing routines are attached, as well as field test forms and a wellhead schematic. If you require any additional information or clarification, please feel free to contact either Joe Anders or me at (907) 659-5102. Sincerely, J~rrv D et/-~'~hl e~s~~ ARCO Problem Well Specialist Attachments '" !999 _Cons. 14-21 Status Subject: 14-21 Status Date: Wed, 22 Sep 1999 16:51:02-0900 From: "PRB Problem Wells" <P 1041 @mail.aai.arco.com> To: B lair_Wondzell~admin, state.ak.us CC: "PRB Problem Wells" <P 1041 ~mail.aai.arco.com> Blair: This is the email sent to Lou Grimaldi August 15, 1999 about 14-21 T x IA communication. Since then, an MITIA failed, and an LDL was was performed 9/21/99 which showed a leak in the tubing between collars @ 5566' md. Our plan now is to caliper the tubing to see if it is repairable, and then patch, repair, or RWO as needed. Call me if you have any questions. Jerry Dethlefs Problem Well Specialist 14-21 Status: On 8/5/99, I received a call from the DS 14 Drill Site Operator concerning 14-21. The Tubing x 9-5/8" annulus pressure had equalized with the tubing injection pressure of 2500 psi. The well was injecting MI at the time. During initial diagnostic work, we bled the annulus to 1000 psi and it build back up to 1800 psi in one hour. Confusing EchoMeter readings indicated oil may be in the annulus. We stopped MI injection and switched the well to produced water, current rate is 7000 BWPD at 700 psi. Our plan is as follows: 1. Continue produced water injection. This will displace MI from around the wellbore and allow safer well operations, 2. Pull a deep gas lift valve and use produced water to flush any oil out of the annulus, 3. Replace the deep valve and GLV #2, the suspected leak point, 4. Conduct an MIT on the Tubing x 9-5/8" annulus. The annulus circulation is scheduled for Tuesday. Give me a call if you have any questions. We will keep you informed of any developments. Joe Anders Problem Well Specialist 659-5102 1 of 1 9/23/99 8:21 AM Memory Mult Finger Caliper Log Results Summary Company: ARCO Alaska Well: 14-21 Log Date: Oct. 7, 1999 Field: Prudhoe Bay Log No.: 1021 State: Alaska Run No.: I APl No.: 50-029-20756-00 Pipe Desc.: 5.5" 17 lb. Buttress Top Log Intvl: Surface Pipe Use: Tubing Bot. Log Intvl: 11,718 Ft. (MD) Inspection Type: Corrosive Damage Inspection COMMENTS: This survey was run to assess the condition of the tubing with respect to corrosive damages. The caliper recordings indicate that most of the tubing is in poor condition with respect to corrosive wall penetration. Over 70% of the joints logged indicate wall penetrations in excess of 40% wall thickness, and only 5 joints indicating penetrations of less than 20% wall thickness. Possible holes are recorded in Joint Numbers 108 and 109, with 86% and 88% wall penetrations recorded. The corrosion mostly appears in the form of scattered pitting above Joint No. 65 and transitions to a Line of Corrosion on the Iow side from this point down to the bottom of the logged interval. No areas of significant cross-sectional wall-loss were recorded throughout the logged interval, with the worst case recorded in Joint 262, representing only a 10% reduction in wall area. MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion (88%) Jt. 109 @ 4,562' MD Line Corrosion (86%) Jt. 108 @ 4,520' MD Isolated Pitting (70%) Jt. 59 @ 2,499' MD Line Corrosion (70%) Jt. 282 @ 11,678' MD Line Corrosion (69%) Jt. 85 @ 3,611' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall-loss (in excess of 10%) were recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: A Minimum ID of 4.07" is recorded in Joint No. 90 @ 3,800' MD, and appears to be paraffin/asphaltine deposits that extend for about 4 ft. (3,800' - 3,804' MD). Other, less restrictive, intervals of similar deposits are recorded in 30 other joints between Jt. 82 (3,417') and Jt. 263 (10,850'). An interval of frequently occuring deposits runs from Jt. 238 (9,792') to Jt. 263 (10,850'). The caliper tool was almost completely impaired by paraffin deposits during a recent previous attempt to log this well. This log was performed after a hot oil treatment was performed on the tubing. I Field Engineer' R. Richey/S. Adcock Analyst: Joey Burton Witness: Jerry Middendoff ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (28:1) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA $ondex Caliper Overview Body Region Analysis Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99494 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nom.OD Nom. ID Nom.Upset 5.5 ins 17 ppf L-80 Buttress 5.5 ins 4.892 ins 5.5 ins Penetration and Metal Loss (% wall) penetration body ~;~ metal loss body 0to 1to 10to 20to 40to above 1% 10% 20% 40% 85% 85% Number ofjoints analysed (total = 301) Pene 1 0 4 75 219 2 Loss 3 297 0 0 0 1 Damage Configuration ( body ) isolated general line dng hole / poss pilling corrosion corrosion corrosion ible hole Num bet of 65 18 2t3 0 2 Damage Profile (% wail) penetration body ~ metal loss body 0 5O 0 GLM 6 92 GLM 5 GLM 4 GLM 3 GLM 1 Bottom of Survey = 282.2 100 Analysis Overview page 2 Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA $ondex Caliper Overview Upset Region Analysis Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99494 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nom.OD NomJD Nom.Upset 5,5 ins 17 ppf L-80 Buttress 5.5 ins 4.892 ins 5,5 ins Penetration and Metal Loss (% wall) penetration upset 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Numberofjoints analysed (total= 301) Pene 216 1 4 47 33 0 Loss 301 0 0 0 0 0 Damage Configuration ( upset ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 83) 38 44 0 1 0 Damage Profile (% wall) penetration upset 0 5O 0 GLM 6 92 GLM 5 GLM 4 GLM 3 GLM 1 Bottom of Survey = 282.2 100 Analysis Overview page 3 SONDEX CA~ER JOINT TABULATION ET Pipe: 5.5 ins 17 ppf L-80 Buttress Well: DS 14-21 Wall thickness. Body: 0.304ins Upset = 0.304ins Field: PRUDHOE BAY Nominal ID: 4.892 ins Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Penetration Comments PUP Isolated PUP Isolated shallow PUP Corrosion. Isolated shallow pitting. penetration Loc metal loss bcd,, Damage profile (% wall) 50 10( Isolated pitting, Isolated pitting. Line corrosion. Isolated i~in,q. Isolated Line corrosion. Line corrosion. Line corrosion. Isolated pitting. Line corrosion. Isolated pitting: Line corrosion, 4.85 Isolated 3 I 0 4.85 I Isola~ ted pitting Line corrosion. Line corrosion. 45 i 0 I .20 Isolated pitting 3 I 0 I .021 4.90 I Corrosion. 4 I 0 .011 4.90 / Line corrosion. [--_~_~.._ .Q_.....__! ......... ?_~.__.5_~ 3 0 .03 4.86 Isolated pitting Pipe Tabulations page t SONDEX CA~ER JOINT TABULATION ET Pipe: 5.5 ins 17 ppf L-80 Buttress Well: DS 14-21 Wall thickness. Body: 0,304ins Upset = 0.304ins Field: PRUDHOE BAY Nominal ID: 4,892 ins Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Penetration Upset i Comments penetration boc metal loss bcd, I Damage profile (% wall) 50 10( PUP Isolated pitting_ SSSV PUP 52 I 0 Isolated pi_tt_!~ Isolated I~ittin,q Line corrosion. Line corrosion. Corrosion, 0 I .46 .031 Isolated pittin~l Isolated pitting Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, Line corrosion. 4.82 Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Corrosion. Line corrosion. DEPOSITS Line corrosion. Line corrosion. PUP Isolated pitting PUP General corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. DEPOSITS Corrosion. DEPOSITS Line corrosion. Line corrosion. Line corrosion. Pipe Tabulations page 2 SONDEX CA~ER JOINT TABULATION ET Pipe: 5.5 ins 17 ppf L-80 Buttress Well: DS 14-21 Wall thickness. Body: 0.304ins Upset = 0,304ins Field: PRUDHOE BAY Nominal ID: 4.892 ins Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 122 I 0 .O4 i Penetration Upset inches Comments 4.70 Corrosion. DEPOSITS Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. POSSIBLE HOLE. POSSIBLE HOLE. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, 4.86 i Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. PUP Line corrosion. PUP Line corrosion. Line corrosion. Line corrosion. Line corrosion. penetration bo( metal loss bcd,, Damage profile (% wall) 5O 10( Pipe Tabulations page 3 SONDEX CA~ER JOINT TABULATION ET Pipe: 5.5 ins 17 ppf L~80 Buttress Well: DS 14-21 Wall thickness. Body: 0.304ins Upset = 0.304ins Field: PRUDHOE BAY Nominal ID: 4.892 ins Company: ARCO ALASKA, INC, Country: USA Date: OCT, 7, 1999 Penetration Upset I inches Comments Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. DEPOSITS Line corrosion. DEPOSITS Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. 4.89 I Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. DEPOSITS Line corrosion. 4.89 I Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. PUP Corrosion. PUP Corrosion. penetration bo( metal loss bcd, Damage profile (% wall) 50 10( Pipe Tabulations page 4 SONDEX CA~ER JOINT TABULATION ET Pipe: 5.5 ins 17 ppf L-80 Buttress Well: DS 14-21 Wall thickness. Body: 0.304ins Upset = 0,304ins Field: PRUDHOE BAY Nominal ID: 4.892 ins Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Penetration .13 I .14 .O21 .14 .04! 4.87 .04! 4.84 .13 Comments Line corrosion. Line corrosion. Line corrosion, Line corrosion. Line corrosion, Line corrosion, Line corrosion. DEPOSITS Line corrosion. DEPOSITS Line corrosion. 4.77 I Line corrosion. Line corrosion. Line corrosion. DEPOSITS 4.74 I Line corrosion. DEPOSITS Corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, Line corrosion, Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, Line corrosion. DEPOSITS Line corrosion, Line corrosion, Line corrosion, Line corrosion. Line corrosion~ Line corrosion. DEPOSITS Line corrosion, Line corrosion. Line corrosion. Line corrosion. Line corrosion. DEPOSITS Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, DEPOSITS Line corrosion. DEPOSITS Line corrosion, DEPOSITS penetration Loc metal loss bod~ Damage profile (% wall) 50 10( Pipe Tabulations page 5 $ONDEX CA~ER JOINT TABULATION ~EET Pipe: 5.5 ins 17 ppf L-80 Buttress Well: DS 14-21 Wall thickness. Body: 0.304ins Upset = 0.304ins Field: PRUDHOE BAY Nominal ID: 4,892 ins Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 4.88 Penetration Comments PUP Corrosion. DEPOSITS PUP Isolated pitting. Line corrosion. DEPOSITS Line corrosion. DEPOSITS Line corrosion. DEPOSITS Line corrosion. DEPOSITS Line corrosion. Line corrosion. Line corrosion. Line corrosion. General corrosion. Line corrosion. DEPOSITS Corrosion. DEPOSITS Corrosion. DEPOSITS Corrosion. DEPOSITS Corrosion. DEPOSITS Line corrosion. Line corrosion. DEPOSITS penetration bo( metal loss bcd,, · Damage profile (% wall) 5O 10( Isolated Line corrosion. DEPOSITS Line corrosion. DEPOSITS Corrosion. DEPOSITS Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. PUP Isolated pitting PUP Corrosion. Line corrosion, Line corrosion. Line corrosion. PUP Isolated ~t.~Ln~q GLM 1 PUP Isolated p_i_t.t_Ln_.q Line corrosion· Line corrosion. Line corrosion. Line corrosion. Pipe Tabulations page 6 SONDEX CAI" JOINT TABULATION EET Pipe: 5.5 ins 17 ppf L-80 Buttress Well: DS 14-21 Wall thickness. Body: 0.304ins Upset = 0.304ins Field: PRUDHOE BAY Nominal ID: 4.892 ins Company: ARCO ALASKA, INC. ~ penetration boc Country: USA I metal loss bod, Date: OCT. 7, 1999 Joint Penetration Metal Prdection Minimurr Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inche; inches D 50 1C 282.2 0 0 13 100 0 .49 3.95 X-Over Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exc, eeds 60% of circumference, but depth range does not exceed I * pipe ID Line - damage depth range exceeds 12 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds I * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 12 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 20 thou inches deviation in body, 60 thou in upset. Modal line length = 0.133 feet. Pipe Tabulations page 7 Well: DS 14~21 Field: PRUDHOE BAY Company: ARCO ALASKA, tNC. Country: USA Tubing: 5.5 ins 17 ppf L-80 Buttress Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99494 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J, Burton Cross section for Joint 109 at depth Tool speed = 52 Nominal ID = 4.892 Nominal OD = 5.500 Remaining walt area = 96 % Tool deviation = 50 ° 4561,7 ft Finger 3 Penetration = 0.268 ins Deepest Penetration Recorded = 0.27 In. or 88% Cross-Sections page 1 Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Tubing: 5.5 ins 17 ppf_ L-80 Buttress Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No. 99494 Tool Size: 2.75 In. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 108 at depth 4519.84 ft Tool speed = 50 Nominal ID = 4.892 Nominal OD = 5.500 Remaining wall area = 97 % Tool deviation = 50 ° Finger 3 Penetration = 0.26 ins 2nd Deepest Penetration Recorded = 0.26 In. or 86% Cross-Sections page 2 Well: DS 14~21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA ~: 5.5 ins 17J~p_~ L~80 Buttress $ondex Caliper Sections Survey Date: OCT, 7, 1999 Tool Type: PDS MFC40 No. 99494 Toot Size: 2.75 In. No. of Fingers: 40 Analysed: J, Burton Cross section for Joint 85 at depth Tool speed = 50 Nominal ID = 4.892 Nominal OD = 5.500 Remaining wall area = 98 % Tool deviation = 22 ° 3611.05 ft 1 / Finger 17 Penetration = 0.21 ins 3rd Deepest Penetration Recorded = 0.21 In, or 69% Cross~Sections page 3 Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Tubing: 55 ins 17 ppf L~80 Buttress Sondex Caliper Sections Survey Date: OCT. 7, 1999 Tool Type: PDS MFC40 No 99494 Tool Size: 2~75 In No of Fingers: 40 Analysed: J Burton Cross section for Joint 90 at depth Tool speed = 45 Nominal ID = 4892 Nominal OD = 5500 Remaining wall area = 100 % Tool deviation = 27 ° 3800.25 ft Finger 36 Projection = -0587 ins Most Restricted interval, MIN ID = 407 In Cross-Sections page 4 SONDEX( \LIPER JOINT TALLY SHE(, Pipe: 5.5 ins 17 ppf L-80 Buttress Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches .1 32.39 3.23 4.919 Pup .2 35.62 5.98 4.896 Pup .3 41.60 8.12 4.928 Pup I 49.72 38.89 4.908 2 88.61 40.86 4.912 3 129.47 41.47 4.929 4 170.94 40.37 4.929 5 211.31 41.53 4.937 6 252.84 41.52 4.932 7 294.36 41.41 4.930 8 335.77 41.41 4.935 9 377.18 37.77 4.921 10 414.95 39.38 4.929 11 454.33 39.65 4.921 12 493.98 41.52 4.924 13 535.50 38.78 4.929 14 574.28 39.45 4.929 15 613.73 41.44 4.925 16 655.17 41.47 4.924 17 696.64 41.79 4.929 18 738.43 41.37 4.929 19 779.80 41.35 4.920 20 821.15 41.50 4.930 21 862.65 41.35 4.937 22 904.00 41.50 4.924 23 945.50 41.41 4.929 24 986.91 41.47 4.935 25 1028.38 41.44 4.925 26 1069.82 41.49 4.925 27 1111.31 41.49 4.921 28 1152.80 41.15 4.932. 29 1193.95 41.37 4.918 30 1235.32 41.44 4.931 31 1276.76 40.93 4.920 32 ' 1317.69 41.42 4.924 33 1359.11 41.43 4.930 34 ,1400.54 41.32 4.929 ............... 35 1441.86 41.52 4.925 36 1483.38 41.40 4.922 37 1524.78 40.56 4.926 ............ 38 1565.34 41.03 4.926 39 1606.37 41.12 4.926 40 , 1647.49 40.83 4.930 41 1688.32 41.34 4.918 42 1729.66 41.09 4.917 43 , ,1770.75 41.50 4.938 44 1812.25 41.09 4.928 45 1853.34 41.23 4.935 46 1894.57 40.16 4.946 47 1934.73 41.32 4.920 48 1976.05 41.48 4.924 Joint! Depth Length Measured Type No. ID feet feet inches ,,, 49 2017.53 41.43 4.915 50 2058.96 41.46 4.923 51 2100.42 41.30 4.917 51.1 2141.72 10.13 nominal Pup 51.2 2151.85 18.16 nominal SSSV , , 51.3 2170.01 10.08 4.896 Pup 52 2180.09 41.21 4.936 53 2221.30 41.29 4.937 54 2262.59 41.42 4.914 55 2304.01 41.14 4.936 56 2345.15 41.50 4.934 57 2386.65 41.44 4.927 58 2428.09 41.16 4.938 59 2469.25 41.07 4.929 60 2510.32 41.25 4.920 61 2551.57 41.17 4.935 62 2592.74 41.37 4.917 63 2634.11 41.07 4.937 64 2675.18 41.17 4.934 65 2716.35 41.20 4.922 66 2757.55 41.10 4.923 67 2798..65 41.17 4.918 68 2839.82 41.15 4.936 69 2880.97 41.40 4.928 70 2922.37 41.44 4.929 71 2963.81 41.17 4.937 72 3004.98 40.94 4.925 73 3045.92 41.15 4.917 74 3087.07 41.12 4.933 75 3128.19 41.27 4.922 76 3169.46 41.19 4.929 77 3210.65 40.59 4.924 78 3251.24 42.02 4.91.6 79 3293.26 4t .47 4.933 80 3334.73 41.20 4.927 81 3375.93 41.25 4.921 82 3417.18 4!;06. 4.93,6 83 3458.24 41.49 4.926 84 3499.73 41.13 4.940 84.1 3540~86 13.05 4.899 PuD 84.2 3553.91 8.98 nominal GIm 6 84.3 3562.89 10.16 4.896 Pup 85 3573.05 41.29 4.928 86 3614.34 41.42 4.927 87 3655.76 41.31 4.923 88 3697.07 39.88 4.923 .... 89 3736.95 41.28 4.9!4 90 3778.23 41.75 4.902 91 3819.98 41.34 4.929 , , 92 3861.32 41.47 4.936 93 3902.79 41.00 4.934 Joint Tally page 1 SONDEX( \LIPER JOINT TALLY SHE( Pipe: 5.5 ins 17 ppf L-80 Buttress Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches 94 3943.79 41.50 4.931 95 3985.29 41.24 4.934 96 4026.53 38.73 4.910 97 4065.26 41.33 4.924 98 4106.59 41.54 4.932 99 4148.13 41.19 4.922 100 4189.32 41.52 4.937 101 4230.84 41.38 4.936 102 4272.22 41.41 4.936 103 4313.63 41.41 4.924 104 4355.04 41.32 4.947 105 4396.36 41.44 4.931 106 4437.80 41.41 4.934 107 4479.21 39.61 4.920 108 4518.82 41.47 4.928 109 4560.29 41.35 4.934 110 4601.64 41.15 4.936 111 4642.79 41.36 4.933 112 4684.15 42.27 4.932 113 4726.42 40.80 4.923 114 4767.22 41.39 4.935 ...... 115 4808.61 41.42 4.938 116 4850.03 41.35 4.938 117 4891.38 41.22 4.928 118 4932.60 41.04 4.933 119 4973.64 41.15 4.940 120 5014.79 40.85 4.945 121 5055.64 41.61 4.926 t22 5097.25 41.45 4.935 123 51 38.70 41.39 4.930 124 5180.09 41.26 4.927 ,,, 125 5221.35 41.28 4.930 126 5262.63 39.77 4.919 127 5302.40 39.57 4.918 128 5341.97 39.48 4.910 129 5381.45 38.86 4.917 130 5420.31. 39.11 4.927 131 5459.42 39.41 4.913 132 5498.83 39.59 nominal 133 5538.42 39.79 nominal 134 5578.21 39.35 4.922 135 5617.56 39.78 4.924 136 5657.34 39.37 4.914 137 5696.71 39.89 4.918 137.1 5736.60 13.33 4.891 Pup 137.2 5749.93 8.56 nominal Glm 5 137.3 5758.49 10.07 4.860 Pup ! 38 5768.56 39.56 4.920 139 5808.12 39.65 4.922 140 5847.77 39..65 4.921 141 5887.42 39.56 4.919 Joint Depth Length Measured Type No. ID feet feet inches 142 5926.98 37.94 4.921 143 5964.92 39.64 4.926 144 6004.56 39.86 4.924 145 6044.42 39.58 4.920 146 6064.00 39.70 4.925 147 6123.70 38.94 4.924 148 6162.64 39.63 4.926 149 6202.27 39.54 4.926 150 6241.81 39.20 4.917 151 6281.01 39.29 4.921 152 6320.30 36.52 4.910 153 6356.82 39.35 4.911 1 54 6396.17 39.84 4.928 155 6436.01 39.61 4.927 156 6475.62 39.73 4.919 157 6515.35 39.51 4.922 158 6554.86 39.89 4.937 159 6594.75 39.30 4.920 160 6634.05 39.18 4.919 161 6673.23 39.77 4.920 162 671.3.00 39.53 4.926 ......... 163 6752.53 39.51 4.924 164 6792.04 39.70 4.918 165 6831.74 38.69 4.914 166 6870.43 39.60 4.928 167 6910.03 41.34 4.929 168 6951.37 41.33 4.930 169 6992.70 41.38 .4.947 170 7034.08 41.26 4.927 171 7075.34 41.22 4,931 172 7116.56 41 ..41 4.941 173 7157.97 41.40 4.938 174 7199.37 41.51 4.937 175 7240.88 41.17 4.951 176 7282.05 41.27 4.939 177 7323.32 41.38 4.926 178 7364.70 ... 41.47 4.936 179 7406.17 41.08 4.945 180 7447.25 41.50 4.932 181 7488.75 41.09 4.936 , , 182 7529.84 41.06 4.936 183 7570.90 41.45 4.935 164 7612.35 41.32 4.932 ,, , 185 7653.67 41.40 4.932 186 7695.07 41.19 4.933 187 7736.26 41.50 4.930 ............. 188 7777.76 39.85 4.946 189 7817.61 41.44 4.934 189.1 7859.05 12.59 4.908 Pup 189.2 7871.64 8.28 nominal Giro 4 189.3 7879.92 10.60 4.901 Pup Joint Tally page 2 SONDEX (' \LIPER JOINT TALLY SHE( '- Pipe: 5.5 ins 17 ppf L-80 Buttress Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches 190 7890.52 41.47 4.944 191 7931.99 41.44 4.928 192 7973.43 39.55 4.925 193 8012.98 39.57 4.926 194 8052.55 39.75 4.926 195 8092.30 39.68 4.927 196 8131.98 38.45 4.928 197 8170.43 40.36 4.925 198 8210.79 40.01 4.931 199 8250.80 39.50 4.929 200 8290.30 39.46 4.932 201 8329.76 39.31 4.933 i202 8369.07 38.55 4.926 !203 8407.62 38.61 4.934 ..... 204 8446.23 39.25 4.933 205 8485.48 38.78 4.927 206 8524.26 39.06 4.927 207 8563.32 39.10 4.934 208 8602.42' 39.38 4.932 209 8641.80 39.70 4.924 210 8681.50 39.81 4.931 211 8721.31 39.45 4.929 212 8760.76 39.68 4.922 213 8800.44 39.45 4.923 214 8839.89 41.03 4.955 215 8880.92 39.51 4.932 216. 8920.43 39.26 4.923 217 8959.69 39.40 4.927 218 8999.09 39.61 4.927 219 9038.70 39.54 4.928 220 9078.24 39.67 4.931 '221 9117.91 39.68 4.927 222 9157.59 39.64 4.922 223 919'7.23 39.58 4.923 224 9236.81 39.05 4.927 225 9275.86 38.67 4.928 226 9314.53 . .39.32 4.926 ....... 227 ' 9353.85 39.25 4.931 228 9393.10 39.38 4.923 229 9432.48 38.59 4.924 ..... 230 9471.07 39.52 4.937 231 9510.59 37.96 4.941 232 9548.55 39.51 4.935 233 9588.06 41.42 4.926 234 9629.48 41.18 4.951 235 9670.66 39.10 4.931 236 9709.76 41.46 4.947 237 9751.22 4! .01 4.952 238 9792.23 41.53 4.928 239 9833.76 41.26 4.952 240 9875.02 41.54 4.948 ,,, Joint Depth Length Measured Type No. ID feet feet inches 240.1 9916.56 12.67 4.908 Pup 240.2! 9929.23 8.76 nominal GIm 3 240.3 9937.99 10.52 4.920 Pup 241 9948.51 41.36 4.946 .,, 242 9989.87 38.22 4.949 243 10028.09 39.53 4.934 244 10067.62 39.22 4.926 245 10106.84 39.88 4.941 246 10146.72 40.99 4.917 247 101.87.71 41.57 4.961 248 10229.28 41.36 4.945 249 10270.64 41.27 4.928 250 10311.91 41.34 4.935 251 10353.25 41.25 4.960 252 10394.50 41.25 4.934 253 10435.75 41.42 4.964 254 10477.17 40.64 4.945 255 10517.81 41.46 4.956 256 10559.27 41.28 4.930 257 10600.55 41.14 4.967 258 10641.69 40.87 4.962 259 10682.56 39,07 4.920 260 10721.63 41.13 4.945 261 10762.76 40.68 4.934 262 10803.44 46.04 4.923 263 10849.48 39.88 4.970 264 10889.36 39.24 4.962 265 10928.60 37.36 4.934 266 10965.96 39.52 4.954 267 11005.48 38.24 4.924 268 11:043.72 40.59 4.925 269 11084.31 38.79 4.962 270 11123.10 40.40 4.956 271 11163.50 40.00 4.934 272 11203.50 38.39 4.962 273 11241.89 39.67 4.930 274 11281.56 40.07 4.926 275 11321.63 41.50 4.963 275.1 11363.13 12.37 4.930 Pup. 2,75.2 11375.~50 9.27 nominal GIm 2 275.3 11384.77 10.16 4.924 Pup 276 11394.93 38.90 4.932 277 11:433.83 37.30 4.961 278, 11471.13 38.66 4.935 i278.1 1i509.79 13.29 4.923 Pup 278.2 !1523.08 8.48 nominal G!m 1 278.3 11531.56 9.53 4.918 Pup 279 11541.09 41.36 4.958 280 11582.45 39.50 4.932 281 11621.95 38.42 4.955 282 11660.37 37.89 4.930 Joint Tally page 3 SONDEX('~ \LIPER JOINT TALLY SH~'' Pipe: 5.5 ins 17 ppf L-80 Buttress Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: DS 14-21 Field: PRUDHOE BAY Company: ARCO ALASKA, INC. Country: USA Date: OCT. 7, 1999 Joint Depth Length Measured Type No. ID feet feet inches 282.1 11698.26 6.05 4.927 282.2 11704.31 unknown 4.894 Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 4 14-21 Status Subject: 14-21 Status Date: Sun, 15 Aug 1999 15:39:27 -0900 From: "PRB Problem Wells" <P 1041 ~mail.aai.arco.com> To: lou_gfimaldi@admin.state.ak.us, larry_wade@admin, state.ak.us, blair_wondzell~admin, state.ak.us 14-21 Status: On 8/5/99, I received a call from the DS 14 Drill Site Operator concerning 14-21. The Tubing x 9-5/8" annulus pressure had equalized with the tubing injection pressure of 2500 psi. The well was injecting MI at the time. During initial diagnostic work, we bled the annulus to 1000 psi and it build back up to 1800 psi in one hour. Confusing EchoMeter readings indicated oil may be in the annulus. We stopped MI injection and switched the well to produced water, current rate is 7000 BWPD at 700 psi. Our plan is as follows: 1. Continue produced water injection. This will displace MI from around the wellbore and allow safer well operations, 2. Pull a deep gas lift valve and use produced water to flush any oil out of the annulus, 3. Replace the deep valve and GLV #2, the suspected leak point, 4. Conduct an MIT on the Tubing x 9-5/8" annulus. The annulus circulation is scheduled for Tuesday. Give me a call if you have any questions. We will keep you informed of any developments. Joe Anders Problem Well Specialist 659-5102 1 of 1 8/23/99 8:29 AM GeoQuest 500 w. International Airport Road An;horage, AK 99518-1199 ATTN: Sherrle RECEIVED 4 't995 JAN 2 1995 ~~b°~s ~ Oil &Ancho~eGas Cons. Commission NO. 9211 Company: 1/23/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description BL RR Sepia RF Sepia Mylar , D.S. 1-3 POGLM SETTING RECORD (12-23-94) . ~'i -~'~1 , D.S. 1-3 POGLM RECORD (1-3-95) ..v-1 ,. vl ;-D.S. 1-25 LEAK DETECTION (1-3-95) v'l v' 1 · D.S. 3-27 BAKER IBP RECORD (12-31-94) v-I ~"1 D.S. 4-7 ST I PERF RECORD (!2-30-94) ~'1 . ~1 , D.S. 4-22A PROD PROFILE (12-26~94) ~,'1. . . ·,D.S. 6-4 .PERF RECORD (12-25-94) ,,'1 --1 [D.S. 6-14A PERF RECORD (12-26-94) ,,1 ,,'1 D.S. 9-4A PERF RECORD (12 23-94) ~ ~ D.S. 9-30 ST PERF RECORD (1-2-95) V'l iD.S. 9-32 PERF RECORD (12-25-94) ..~'. 1 ~1 D.S. 11-16 ST I LEAK DETECTION (12-31-94) . ,-1 . . ~,'1 D.S. 11-23A PERF RECORD (12-21-94) ~'1 .... ~1 ... ~D.S. 13-15 SBHPS & INJEC PROFILE (12-29-94) ,-T ~1 . ~O.S. 13-33 LEAK DETECTION (12-30-94) I 1 I D.S. 13-33 BAKER INFLAT BRIDGE PLUG RECORD (1-3-95) ',1 ;D.S. 14-21 SBHPS & INJEC PROFILE (12-23-94) ~1 '"1 ~'D.S. 15.7A DUAL BURST TDT-P (12-27-94) . v'l ,~1 . ID.S. 15-30 LEAK DETECTION (12-27-94) v,1 ~,-1... D.S. 15-30 DUAL BURST TDT-P (CT/E-.LINE) (12'-30-94) ~ .... D.S. 18-9A DUAL BURST TDT-P (12-22-94) .. ,'1 ~. D.S. 18-27 DUAL BURST TDT-P (CT/E-LINE) (12-29-94) "' '~I ' ,'1 SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~' "'~:'~ 'JUN 1--1 1~91 DATE:. 6-i 3-9i . " ,~- ,' ' . .... '.-~--~:~ ................~ Oil ~ ~s ~s. Cemmi~ia~ ....... "~'E'R~5 ..... ~RCO C~SED HOLE FZN~LX ~.- ~'9 6-t-9t COLLAR-F'ERF RUN t, 5" ATLA2 ...... t3~2A .....6-2-?t --~ ..... COLLAR-PERF-~ ...... ~ ............... <;-.' ......RUN-.t-,--5~--~. A~LA~ t 4-f7 5-t 6-9t '~'.,.'- INJ F'ROF ' '~-?~? ~-"~'~ .... RUN t, 5" CAMCO _ :-t 4-2t' 5-~ 6-.9t .... Y---'=-INJ F'ROF'- .... :=~=.' ....................... ~=.t .............. RUN-'-t, -5" ........ CAMCO t4-25 5-t6-9t =' INJ PROF-GR': ' .~- ' RUN t, 5" CAMCO ..... :..- ~--t 4-36 ..... 5-t 6-9 t .... *--.tNJ _PROF ....... ._,, ~..--.~UN .-.t ~ ~-5" ............ ~AMCO . ~[~' , . t 5-f 5 5-t 7-9t ::~.',.PROD -pROF" -.:.~'~-;-. ..... ' ..... -~=;-"..:--. RUN .t', -"'~ · - · CAMCO . t&-~i-t ....... 5-23-9t ......... ?.INJ..PRO~ - . .......................................... RUN t~-.5" .CAMCO -~ RUN t, 5' CAMCO ~i -t6 ~ 5-23-9t PROD PROF -'-:". 't6~24 .... 5-t9-9t;=- ....~...PROD .PRO~ ..... '""'- ............. . Z~=~;:=.,~RUN:-.-t. ;.=75" ':CAMCO . . :, ¢ =....~? - ._ .... '"..~'~t 7~ ~=''~ 5-8-9t "';:~:.~j::~LEAK ~'gETE~.; v CO . .. ,:~ '.:~. ': . . -- -tT.'t ~ . 5-27-?t "::~ ~'LEAK "DETECT~.>~.~'''''?~ 0 I ~'2:'~::.;:.~?;'- 5- t '2-9 t ;:;¢~¢~:~'I NJ - . . F'LE~SE ;;]~N ~ND RETURN THE ~TT¢~CHED COPY ~S RECEIPT OF-D~T~ ' .. ~:. . . . . ' RECEIVED ~Y --. ... ............................. . .... ,:~:.... ..... ............ H~VE ~ A. NICE D~Y ~- ." .:.,.~..,,. ..... '.' .' .:;:':~.:':.',-.:;~"':'.~ --"" -,L.:~. -' : ::, :'~,.:v'?.:' -,. .... . ....~, , . ...... . ...... ~. -... ..,-.... , ~ :.,. -,. . .... ' "- ."';.¢-:' .~ CHEVRON .......... ....................... D & M R..&-D .......................................................... ~ EXTENSION EXPLORATION ~ BF'X ......................... :'.~ .EXXON ' ' MARATHON TEXACO .... .... - ..,;r ......... ~ -MOBIL ..................................................................... ,~. .............................. .............................................. ........ : .... ........... RI 'C[IV D .............. .-, ..................... ........ I~J ...................................................... ~ ........... ~'-'-=.~..~: ~.-.~.:.:. ............. _ - ~la~-'~,~'~..<,?..~ ..._~-~]-~lssio~ . - " , · '- ................ /~S!: ....... ~:~'~'-- . . ARCO ALASKA, INC. F'.O. BOX 180360 ANCHORAGE, ALASKA DATE' 3-9-90 REFERENCE' ARCO F'RE$~'URE DATA 3-4 ~ -6-90 BHP--$TATIC GRADIENT CAMCO 3-18 t-6-90 BHP--£TATIC GRADIENT CAMCO 9-.t5 t-~5-90 BHP--$TATIC GRADIENT CAMCO 9-t9 ~-~5-90 BHP--$TATIC GRADIENT CAMCO ~ t-t t-5-90 BHF'--$TATIC HR$ J J .-~ 6 ~ -5-90 BHP--$TATIC HR$ t ~ "~' -7- ~'-~3 t ~0 BHP--$TATIC I-IRS i2-29 t-t3-90 BHF'--$TATIC GRADIENT CAMCO 1 3-32 t4-2t t-3-90 EHf'--FLOWING GRADIENT CAMCO t4-36 t-3-90 BHP--FLOWING GRADIENT CAMCO t6-tt ~-~3-90 " BHP--$'TATIC GRADIENT CAMCO t8-3 tt-29-89 BHP--$TATIC GRADIENT CAMCO t8-9 ~-29-89 BHF'--£TATIC GRADIENT CAMCO t8-t6 tt-29-89 BHP--£TATIC GRADIENT CAMCO t 8-20 t t "'29-89 BHF'--$TATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY HAVE A NICE DAY! EAL. LY HOFFECKER AT0'-t529 RE-CEI¥-ED MAR 1 ~ !990 /2 Alaska. 0il & G~s Cons. Comtilissi~ APPROVEDTRAN$~ 9(.~,fO~-~- ~chomge DISTRIBUTION CENTRAL FILES ""-,. IbHILLIF',S' CHEVRON PB WELL. F'ILE$ D & M ~ ~ R & D ' EXTENSION EXPLORATION ~' ~ BF'X STATE OF ALASKA EXXON ~' MARATHON ~ ~ TEXACO MOBIL /CC/ ARCO AI_A~KA~ INC. F'.O. BOX iO~-JS60 ANCHORAGE, ALASKA 995 i ¢3 DATE' · ~ ~-7-90 REFERENCE' ARCO CASED HOLE FINALS ~ i 6 i --,..-o(.~ 4-27 i 2-28-89 ;-~.~. i -5-90 9-i t -8-9 -~ i 3-°SA~. i -i i -9,~ i 4-6 i -4-96, iS.-i~= i-iE~-9(} i 8.-24 i -i 6,-96, INJECTION PROFILE INJECTION PR'OFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION F'ROFILE PITS INJECTION PROFILE INUECTZON F'ROFILE PRODUCTION F'F~OF'ILE PRODUC'f'i ON F'ROF:' l LE '~F'I_EASE SIGN AND RETURN '¥~'~ffl ATTACHED COPY AS R. ECEIF'T AF'F'ROVED ~..~~. ~_ TRANS.~ 90 OF UE~.TRAL FILES CHEVRON · D&M EXTENSION EXF'LORATION EXXON MARATHON MOBIL :, THE CORRECTED WELL NUMBER IS i 3;.-23A, · "'.,,. PHILLIPS" PB WELL FILES R & D ~~ BF'X ~' STATE OF ALASKA ~- i'EXACO NOT i 3-2J. RUN I , RUN i, RUN i, RUN i, RUN 3, F,'UN t , RUN i, RUN I , RUN i , F-.:UNi , DATA CAMCO CAMCO C A M C 0 C A M C 0 CAMC'n ",.." ~-t i i C: A h ':.'.]]: 0 CAMCO CAMCO L: A M C 0 ARCO ALASKA, INC. F:' .. ID. BOX t 0r~.360 ANCHORAGE., ALASKA 995tC) DATE' t-5-89 RFFERENCE' ARCO CASED HOLE FINAl_,? -,....' t,-_ ~..,_ 89 L. ULLAF~,, F EI-,,F F;,'UN~ , ._,'~'" '2'--2~) t 2-':29'--89 COi..I..AR RUN t, 5" 4-2t t 2-2(')-89 COL. LAR/F:'[~RF RUN t, .'.'5" 4-28 t2--25-89 CPET RUN t, t" ':1 .... ,,.'-'8 t 2-26-89 I"iF:'C; RLIN i , _.:-':'" 4"-28 i~-.."~-')5-'89,... SF' I NNER/i'EMP RUN i , ~.."'~, ....~.~ ~r_,.. '4"-~->8.. t 2-26-89 YERTILOG RUN ~, ..~':" F'LFASE :,;IGN AND RETURN I'HE A'f'TACI-41ED COF:'Y A,S' RI::CE:/.F'I" OF' DATA, .~;,' A L. I... Y HOF:FECKER ATO-t 52'? JAN 1990 Alaska Oil '8;. Gas Cons. Anchorage DISTRIBUTION CENTRAL FILES -'. " I -~ · L, HE'~/Rr)N D & M EXTE:NS,'ION EXP ~" L. C. R A "1' I 0 N EXXON MARATHON MOBIL A P P R O V E D "~f~ .... 'f'RAN$:~. 9~.:~) t 6) :~ F' H I L L I F:' S PB WEI...L F:IL. ES R & D · ,'"' BF'X :~ ;i.;.'TA'f'E OF' AL. AS'KA ~: T E X A C O ALASl~ REPOR STATE OF ALASKA ')IL AND GAS CONSERVATION OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing ~ , ,, Plugging Perforate X '~ Alter casing ~ Repair well O~her ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 992' FSL, 1221' FEL, Sec. 16, T10N, R14E, UM At effective depth At total depth 432' FSL, 1347' FEL, Sec. 16, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-21 9. Permit number/approval number 82-86/9-1027 10. APl number 50 - 029-20756 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 13060 feet Plugs(measured) 9641 feet Effective depth: measured 13018 feet true vertical 9609 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 110' 20" 350 sx Permafrost II 110' Sudace 2446' 13-3/8" 2500 sx AS III & 400 sx AS II 2517' Production 11965' 9-5/8" 500 sx Class G & 300 sx ASII 12036' Liner 1298" 7" 400 sx Class G 13060' True vertical depth 110' 2517' 8893' 9641' Perforation depth: measured 12090-12111', 12202-12208', 12215-12221', 12224-12264' true vertical 8917-8933", 9016-9020', 9029-9030', 9032-9062' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 11725'; 4~12", 12.6#, L-80, PC tubing w/tail @ 11805' Packers and SSSV (type and measured dePth) Baker FB-1 Packer @ 11707'; Baker FB-1 Isolation Packer @ 12395', 5-1/2" Camco BaI-O SSSV Nipple @ 2156' ,~, ,~. 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) Treatment description including volumes used and final pressure Reoresentative Daily Averaae.Produmion or Ini~ion Data _ .- ,., .~ ,. OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ...... 2451 --- 117 Subsequent to operation 2212 --- 25 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil..__ Gas __ Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Operations Engineering Manager Form 10-404 Rev 06/15/88 Date I~~ SUBMIT IN DUPLICATE DS 14-21 { SAG RIVER ADD PERF PROCEDURE REPORT OF WELL OPERATIONS PROCEDURE: WORK PERFORMED 12/20/89 1. RIG UP E/L AND TEST LUBRICATOR 2. RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS 3. PERFORATE SAG INTERVAL 12091'-12112' MD (BHCS 8/7/82) TO ATTAIN 4 SPF WITH RUNS AS REQUIRED POOH. 4. RD AND RELEASE E/L. 5. RETURN WELL TO INJECTION STATUS STATE OF ALASKA . 0 ~ ALASK~ LAND GAS CONSERVATION C( MISSION APPLICA 'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program Opera,on shutdown Plugging ~ Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 992' FSL, 1221 ' FEL, Sec. 16, T10N, R14E, UM At effective depth At total depth 432' FSL, 1347' FEL, Sec. 16, T10N, R14E, UM Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 71 ' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-21 9. Permit number 82 - 86 10. APl number 50 - 029 - 20756 11. Field/Pool P ru, d_hoj ,,S y,Oj 12. Present well condition summary ~ L [., ~ I V ~ Total depth: measured 13060 feet Plugs(measured) true ve,ical 9641 feet ~'~0V 2 8 Effective depth: measured 13018 feet true ve~ical 9609 feet Junk(measured) 'J;~;J(~ 0~J & GaS Cons. Anch0r~ Casing ,, Length Size Cemented Measured depth TrueveHical depth Conductor 110' 20" 350 sx Permafrost II 110' 110 Sudace 2446' 13-3/8" 2500 sx AS III & sx AS II 2517' 2517' Production 11965' 9-5/8" 500 sx Class G & 12036' 8893' 300 sx AS II Liner 1298' 7" 400 sx Class G 13060 ' 9641 ' Perforation depth: measured 12202- 12208 ', 12215-12221 ', 12224- 12264' true vertical 9016-9020 ', 9029- 9030 ', 9032- 9062' Tubing (size, grade, and measured depth) 5 1/2 ", 17#, L-80, PC tubing @11725 '; 4 1/2 ", 12.6#, L-80, PC tubing w/tail @ 11805 ' Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 11707 '; Baker FB-1 Isolation Packer @ 12395 ', 5 1/2" Camco BaI-O SSSV Nipple @ 2156' 13. Attachments Description summary of proposal x~ Detailed operations program BOP sketch x 14. Estimated date for commencing operation I December 1989 16. If proposal was verbally approved Oil x Gas Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,-~<- r~ ~':~.~~~ Title Operations Engineering Manager FOR COMMISSION H~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test , Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH 15. Status of well classification as: Suspended Date J Approval No.?_..//~,c~ q p, pproved CoPY Returned C_.~~r Date J/~~~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PROPOSED PERFORATING DS 14-21 ARCO Alaska proposes to add perforations in the DS 14-21 Injector in the Sag River formation of the Prudhoe Bay Unit. All wire line work will be done through 5000 PSI working pressure BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The purpose of the proposed perforating will be to provide effective drainage of the Sag River reserves. Ref: BHCS 18/7/82 Proposed Perforation Interval: 12091-12112' MD 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. ,5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF · i H ] REL ! NE BOP EOU ! PId£NT, I liB!I IIIIII IIIII I I III I I I I I II I' I ARCO ALASKA, P.O. BOX JO0360 ANCHORAGE, ALASKA 995 i (~ DATE' ' t ~-i 7-89 REFERENCE' ARCO CASED HOLE FINALS i-5 t¢,-tt-89 COLLAR/F'ERF' RUN t, 5' ._-4 -"' t O-t 3-89 PDK-t O~ RUN t 5" 3-28 i~-i3-89 F'DK-i~ RUN t, 5" 4-3 t0-6-89 GR/CCL & PERF RECORD RUN t, 5' ~6-t3 9-27-89 PRODUCI'ION PROFILE RUN t, 5' 6-2t 9-28-89 PRODUCTION PROFILE RUN t, 5' 9-t7 9-29-89 INJECTION PROFILE RUN i, 5' 9-26 t~-t4-89 F'DK-~e~ RUN i, 5" ~ti-t8 i~-t3-89 COLLAR/F'ERF RUN t, 5' i4-i i~-8-89 COLLAR/PERK RUN l, 5' i4 i6 9 ~4-25/8~ LEAK DETECTION RUN i , i' t4-2i 9-3~-89 INJECTION PROFILE RUN i, 5' iT-t() 9-3e-89 INJECTION F'ROF'ILE RUN t 5' iT-te 1e-5-89 COLLAR/PERF RUN i, 5' i7-I3 t~-5-89 COLI_AR RUN i, 5' i8-9 9-29-89 PITS RUN t, 5' SIGN AND RETURN THE ATTACHEI) COPY AS REC;EIPI' OF' DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-t 52<? & Gas Cons. Com ssiO , /x2 ATLAS ATLAS ATLAS SCH CAMCO CAMCO CAMCO ATLAS ATLAS ATLAS CAMCO CAMCO CAMCO Al'LAS ATLAS CAMCO DISTRIBUTION ~' CENTRAL FILES ~-~' F'HILLIF'S '"'..- CI"IEYRON PB WELL FILES D & M R & D · .II. ~- EXTENSION EXRLORATION ~' BF'X · '" EXXON "~ ' '~ ' . STATE OF 14LA~,KA 'II' MARATHON ~ TEXACO .-'- MOBIL APPLICATION FOR SUNDRY APPROVALS CONVERSION OF DRILL SITE 14 PR ODUCERS TO SEAWATER INJECTION SERVICE WELLS: DS 14-17 DS 14-21, PERMIT NO. 81-21 PERMIT NO. 82-86 SUMMARY OF PROPOSED OPERATIONS' 1. Disconnect wells DS 14-17 and DS 14-21 from production manifold and tie-in to SWI header. . . . Wash and test flowlines. Perform mechanical integrity test on tubing/casing annulus in each well. Commence seawater injection on DS 14-17 and DS 14-21. RECEIVED JUN o Alaska Oil & Gas Cons, Commission Anchorage KRF 6/89 STATE OF ALASKA APPLICA. ION Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 992' FSL, 1221 ' FEL, Sec. 16, T10N, R14E, UM At effective depth At total depth 432' FSL, 1347' FEL, Sec. 16, T10N, R14E, UM Plugging Pull tubing Variance 5. Type of Well Development ;X Exploratory Stratigraphic Ser~ce Re-enter suspended well Time extension Stimulate Perforate Other X 6. Datum of elevation(DF or KB) 71 ' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14 - 21 9. Permit number 82 - 86 10. APl number 50 - 029 - 20756 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 13060 feet Plugs(measured) 9641 feet Effective depth: measured true vertical 13018 feet 9609 feet Junk(measured) Casing Length Conductor 110' Surface 2446' Production 11965' Liner 1298' Size Cemented Measured depth 20" 350 sx Permafrost II 110' 13-3/8" 2500 sx AS III & sx AS II 2517' 9-5/8" 500 sx Class G & 12036' 300 sx AS II 7" 400 sx Class G 13060' True vertical depth 110' 2517' 8893' 9641 ' Perforation depth: measured 12202- 12208 ', 12215-12221 ', 12224- 12264' RECEIVi]D true vertical 9016-9020 ', 9029- 9030 ', 9032- 9062' JUN 0 Tubing (size, grade, and measured depth) 5 1/2 ", L-80, 11725 '; 4 1/2 ", L-80, 1180~jaska Oil & Gas Cons. ComlllJs:al~. Anchorage Packers and SSSV (tYpe and measured depth) Baker FB-1 Packer at 11707 ', Baker FB-1 Isolation Packer at 12395 ', 5 1/2" Camco BaI-O SSSV Nipple at 2156' 13. Attachments Description summary of proposal ~ Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 7/1/89 16. If proposal was verbally approved Oil ~ Gas Suspended Name of approver Date approved Service 17. I hereby c~ify that the~!oregoing i..s true and correct to the best of my knowledge. Conditions of approval: NotEy com~i~ion so representative may w~ness J Approval No. Plug integrEy BOP, Test Location clearance Mechanical Integr~y Test ~ Subsequent form required 10- D J ~pproved CoPY I Returned ~ ORIGINAL SIGNED BY u~- ~ ~ ~ ~ ? / Approved by order of the ~mmissioner LO~INIE ~ SMITH Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO ALASKA, INC, F:'~O, BOX i(')0360 ANCHORAGE, ALASKA 995i :. DATE · 4-26-89 REFERENCE' ARCO PRESSURE DAFA 2-i0 4-i-89 BHP---SI'AI'IC GRAI)IFNI' OTIS · 4-'29 2-22-89 BHF ....FLOWING GRAD.[EMI' L, AH.,t.) 5-i8 3-27-89 BHP--SI'AI'IC GRADIENT CAMCO 6-3 4-i .-89 BHP--~'FATIC GRADIENT CAMCO ti-t6 4-t7-89 BHP--~TAI'IC GRADIENI' CAMCO " :k"' ' ' CAMCO ti-iT 4-i7-8~ BHF ....~FAFIC GRADIENT ii-'J8 4-i7-8~ BHF ..... SI'ATIC GRADIENT CAMCO i i-24 S-2~-89 BI-IF ..... Y'FAI'IC GRADIENT CAMCO i'2-.i 8 4-.i G--89 BHF: ....... STATIC GRADIENT CAMCO t2-26 J-30-89 BHF ..... ~TATIC GRADIENT O'FI~ t3-t 4-"2-89 BHF ..... SI'AI'IC GRADIENT OTIS :~ ' " C l S-t 0 4"~'-89 E HF-"T~ I ATI GRADIENT OTIS t4-it 4-t-89 BHF' .... STATIC GRADIENT OTI,~' t4'-t2 4-3-89 BHP--SFATIC GRADIENT O'FIS t 4 · =t 4-'4-'89 BHF ..... SI'ATIC GRADIENT CAMCO,. i 5'-i OA 4-2-89 BHF ..... ~'I'A'I'IC GRADIENT CAMCO · ~ .... ~ · i5-i9 4-2-89 BHF ....STATI., GRADIENT CAM.;O t5-22 4-2-89 BHF ..... S'FATIC GRADIENT CAMCO i5-25 4-'~-89 BHF ....STATIC GRADIENT CAMCO i8-4 ~-29-8~ BHF'--STAI'IC GRADIENF OTI,~ i 8'-8 3-o ~-.8~ BHF ...... SI'AI'IC GRADIENT CAMCO iS-ti 3..-~-8~ BHP--STATIC GRADIENt OTIS t 8-i "F 3-29-89 EHf ...... ,$ TA'FIC GRADIENT CAHCO p f.,. i8-23 3-29-89 BHF'--~TAFIC GRADIENT PLEASE SIGN AND REI'URN THE ATTACHEI) COF'Y AS RECEIF'I' OF I)ATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKFR A'FO'- i 529 ~__..~ka Oil & G.~s Col~s. Commissioll 'FRANS.- 89 ¢77 Anchorage DISTRIBUI'ION CENTRAL FILES ~ ~ PHIl_LIPS CHEVRON F'B WEL. L FILES · ,,-D & M ~ R & D FXTEN$ION EXF'LORAI'ION ~-'"'BPX ~ EXXON ~ ~ ~ STATE OF' ALASKA MARAI'HON .~: I'FXACO ~ MOB IL i .4 .--. '.'? -':; ::-':: .... :i ::::: ----::::: :::,' Alaska 011 & Gas Cons. Commission Iai: Ci ;. :.anchorage ES' "./".:: f'"t ]":i :':':': !:;: A '!" i-.[ i'"l i"..J :i[: '.'."d f'", 'f:-,: T ! ARCO ANCHORA[;E, AI._A,.~KA 99.5t (.) PATE: 4-27-88 REFERENCE: ARCO CA~'ED HOI...E FINAl.., 4- t 0-88 CCI..-TEMF E.~ ATIJRF.. LOG RI.IN t, 5 · PLEASE SIGN AND RETURN THE ATTACHED COPY AS' R~FCFIPT OF ]DATA, HAVE n NTC, E ~ AID$~J Oil & Gas Cons. P .F..G(iY BENNETT I'RANS ~88264 ~ APPROVED ........ CAMCO CENTRAl,,. FI~I.,.EE CHFVRON D & H EXTENEION EXF't,,ORATTQN. EXXON . . MARATHON MOBIl.... · .'""' F H l I...I....T P,~ F'R WFI_L. F.T.I,..E,~ ~~ TEXACO WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~] WATER SOURCE . 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 82-86 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20756 4. Location of well at surface 9. Unit or Lease Name' 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit 10. Well Number At Top Producing Interval 992' FSL, 1221' FEL, Sec.16, TION, R14E, UM 14-21 At Total Depth 11. Field and Pool 432' FSL, 1347' FEL, Sec.16, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool RKB 71 ' ADL 28314 07/18/82 . 08/07/82 08/23/82*I '"" feet MSL I 1 17. TotalDepth(MD+TVD) 18. PIugBack'bel~th(MD~TVD)19'.'Di;ectionalSurvey i 20. Depth where SSSV set 121. Thickness of Permafrost 13060'MD, 9641'TVD 13018'MD, 9609'TVD YES[~ NOI--I I 2156' feetMO. I 1900' (approx) 22, Type Electric or Other Logs Run D IL/BHC/GR/SP, CDL/CNL/GR/Cal, GR/CNL, CBL, Gyro .'23, . ....... CASING, LINER, AND CE.M,ENTING REC. O.R.D' .............. SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20~ ~)l.b# H-40 Surf ...... 111'" ~'~J;i" 350 sx PF'II 13-3/8" 72# L-80 Surf 25i7" "17-1'~2" '2500 sx AS l il & 400 ex. AS II 9-5/8" 47# L-80/ Surf ' 12036' ~2'-~/4" ' 500 sx Class G & 300 s:~ AS II Soo-95 7". . .'29# L-80 11362' !3060'...'. '8-1/2" 400 sx Class. G 2'4. 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) Perforated w/4 spf 5-1/2"/4-1/2" ' ' 12451' 11'707' & 12395' ,, , , . , 12464'-12624'MD 9212'-9331'TVD 12632'-12642'MD 9337'-9344'TVD '26. ' "ACID, FRAc~URE~ cEMENT SQUEEZE, ETC. 12648'-12698'MD 9349'-9387'TVD DEPTH INTERVAL (MD) AMOUNT & KI:ND OF MATERIAL USED 12714'-12764'MD 9399'-9436'TVD 12260'-12264' 125 sx Class G 12816'-12866'MD 9474'-9512'TVD [1557'-11659' See ~tt~ched ~drlP_nrh~m. 12894'-12914'MD 9532 '-9547 'TVD ~/5/$8, t: .... ~A job 11557'-11659'MD 8540'-8610'TVD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 11/24/82J Gas Lift '"Da~e of Tes~ hou'r~; Tested pRODUCTIoN FOR oiL[-BB[' ' GAS-Mci~ WA~i~R:BBL C'HoKE S,'ZE '1 'G/~S-OIL RATIO 11/25/82 14 TEST PERIOD I~ -- 3850 7000 t ~low Tubi~ "' C'asi"ng Pressure C'AL~ULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 750 1950 24-HOUR RATE I~ __ 6600 12000 -- 28. CORE DATA B~ief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. ,Submit core chj~s,. ~.~ None h~sk~ Oil & G~s Cons. commissio~ *Note: Perforated well 11/14/82. Workover performed 1/25/88. Form 10-407 wC,b//:DAN I Submit in duplicate Rev. 7-1-80 CONTINUED O'N REVERSE SIDE NAME Top Sadlerochit O/W Contact Base Sadlerochit MEAS. DEPTH 12197' 12306' Not reached TRUEVERT. DEPTH 8997' 9078' Include interval tested, pressure data, all fluids recovered and gray ity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/5/88) 32. II erebyce :ify Signed I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~,07 ADDENDUM WELL: 1/06/88 1/07/88 1/08/88 1/27/88 14-21 RIH w/8' of 2-5/8" stem, oil jars & spangs, set dn @ 2158'; unable to latch, POH. TIH; stopped again @ 158'. Pmp 100 bbls diesel. RIH; unable to latch, POH. RIH, latch & pmp 4 bbls; unable to pull, POH, change out oil jars. RIH; unable to work jars, POH & replace jars. RIH, latch & jar on slv w/no movement, POH. RIH, continue jarring on slv, POH slow. TIH w/pulling tl; stopped @ 2178', POH. RIH w/GR; unable to pass 2178', POH. RIH w/4.4" GR w/same problem, POH. RIH w/3.9" GR, pass thru to SSSV, POH. RIH w/4.40" GR; unable to pass thru SSSV, POH. RIH w/4.25" broaching tl, made run to 11,650', POH. RIH w/retrv'g tl; stuck in SSSV. Wrk loose, POH. Rn 4.375" broaching tl, wrk tl thru SSSV area, POH. RIH w/retrv'g tl; stuck @ 2175', jar tl free, POOH. RIH w/4.50" broaching tl; unable to get past 2175', POH. RIH w/4.375" broaching tl, wrk thru SSSV, POOH. RIH w/4.50" broaching tl; unable to get past 2175', POH. PU 5.5" GR, ck BPV setting area in tbg hgr f/scale & debri; unable to get to tbg hgr. MU dummy perf gun, RIH to 11,150'; no obstructions, POH, RD Otis. Secure well. ,, RU Gearhart, perf 11,557'-11,659' w/4 SPF. Tbg &'csg pressure equalized @ 515 psi, POH, RD Gearhart. Secure well. RU BJ, pmp 5 bbls diesel @ 2 BPM, 500 psi. Pmp 5 bbls 15% HC1 @ 1BPM, 500 psi. Pmp 5 bbls 15% HC1 @ 1BPM, 500 psi. Pmp 5 bbls 15% HC1 @ 1BPM, 500 psi. Pmp 10 bbls 15% HCL @ i BPM, 500 psi. Displ acid w/47 bbls 100° hot diesel @ 3 BPM, 700 psi. RD BJ. Secure well. Att to stab BPV; unable to pass swab vlv. RD lubr & secure well. / Retrv broken T-bar stem f/BPV in tree. Att to retrv BPV; frozen in place. Drilling Supervisor ARCO Alaska, Inc./ [~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 3, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: DS 14-21 Approval Number- 8-11 Enclosed is the Report of Sundry Well Operations and Well Completion Report detailing work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/SKA/sd Enclosures CC' Standard Alaska Production Company J. Gruber, ATO 1478 File' Pl(DS14-21)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. -. 3. Address Post Office Box 100360, Anchora~]e, AK 99510 4. Location of well at surface 2715'FNL, 1562'FEL, Sec. 9, TION, R14E, UN At top of productive interval 992'FSL, 1221'FEL, Sec. 16, TION, R14E, UM At effective depth 459'FSL, 1341'FEL, Sec. 16, T10N, R14E, UN At total depth 432'FSL, 1347'FEL, Sec. 16, TION, R14E, UN 11. Present well condition summary Total depth: measured true vertical 13060 feet Plugs (measured) feet 9641 5. Datum elevation (DF or KB) 71 ' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 14-21 8. Approval number R-11 9. APl number 50-- 029-20756 10. Pool Prudhoe Ba~, Oil Pool Effective depth: measured true vertical 13018 feet Junk (measured) 9609 feet Casing Conductor Intermediate Production Liner Length Size Cemented Measured depth True Vertical depth 20" 350 Sx PF II 110' 110' 13-3/8" 2500 Sx AS III & 2517' 2517' 400 SX AS II 9-5/8" 500 Sx C1 G & 12036' 8877' 300 Sx AS II 7" 400 Sx C1 G 13060' 9641' Perforation depth: measured 12202-12208' 12215-12221' 12224-12264' 12464-12624' 12632-12642', 12648-12698' 12714-12764' 12816-12866' 12894-12914' true vertical 9000-9531' 12. Stimulation or cement squeeze summary 13. Tubing (size, grade and measured depth) 5½", L-80, 11704', 4½" tubing tail, L-80, 11805' Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 11707'MD and Baker FB-1 isolation packer @ 12395', Camco Bal-0 S$SV @ 2156' RECEIVED Intervals treated (measured) NA Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 500 20000 -- 369 473 488 11807 -- 297 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed ~~-~~~ ~~~ Title Operations Engineering Manager Date Form 10-404 Rev. 12-1-85 14-21/STAT17 Sharon K. Allsup-Drake (263-4247) Submit in Duplicate ALASK IL AND GAS CONSERVATION MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Oil Producer 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-86 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20756 4. Location of well at surface 9. Unit or Lease Name 2715'FNL, 1562'FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 992'FSL, 1221'FEL, Sec. 16, T10N, R14E, UM 14-21 ,. At Total Depth 11. Field and Pool 432'FSL, 1347'FEL, Sec. 16, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' RKBI ADL 28314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 07/18/82 08/07/82 08/23/82 N/A feet MSLI 1 17. Total DePth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directionai Survey 20. Depth where SSSV set i 21. Thickness of Permafrost 13060'MD, 9641'T~D 13018'MD, 9609'TVD YE~ NO [] 219 feet MDI 1900~ ~. Type Electric or Other Logs Run DIL/BHC/GR/SP, CDL/CNL/GR/Cal~ GR/CNL~ CBL 23. CASING, LINER AND CEMENTING RECORD ~' SETTING DEPTH MD ......... CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20,,' 91.5~ ~-40 Surf. "iTM 30- 3~0 ..~ v~.~,~f~o..~ T~ 13-3/8" 72.0~f L-80 Surf. 2517' 17%" 2500 sx AS III & 400 .~x aS IT .. 9-5/8" 47.0~ L-80 & Surf. 12036' 12~" 500 .~x Cl~.m~ G & %~o .~ ~R TT S00-95 '~< · , , 7" 29.0~ L-80 11762' 13060' 8%. 400 sx Clas~ G 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) Ref: BHCS 8/7/82 5~' 11~o/,, ]]7.07' 12202-12208'MD 6 spf 12816-12866'MD 4 spf ('bnt~'nm .5~" thE) 12215-12221'MD 6 spf 12894-12914'MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12224-12264'MD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12464-12624'MD 4 sDf 9000-9531'TVD N/A . . 12632-12642'MD 4 spf ....... 12648-12698'MD 4 spf .... . .. 1271/~-1276~,'~ /+ .~.pf .............. 27. PRODUCTION TEST Date First Product on I Method of Operation '(Flowing, gas lift, etc.) 11/24/82 I Gas Lift Date Of'Test' ' Hours Tested PRODUCTION` F°R OIL-BBL GA$-MCF WATER,BBL cHOKE S~ZEI GAS2OII~'RA~rlO 2/28/88 12 TEST PERIOD ~ 237 2z~. 6, qn/. ~n[ Flow Tubing CaSing Pressure cALCULATED` OIL.BBL GAS-MCF WATERBB-L 0IL (~F~AvITy-ApI (c%-r~')" .... Press. 297 -' 24-HOUR RATE I~ 473 488 11807 NA 28.' CORE DATA ' Brief desCription of'lithology, porosity, fractures, apParent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 12197' 8997' O/W Contact 12306' 9078' Base Sadlerochit Not Reache¢ NA , . 31. LIST OF ATTACHMENTS , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · · Signed ..~~~ Title Opt. Engr. Mgr. ' Date INSTRUCTIONS General: This form is designed for submitting a complete and correct'well completion report and log on · all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state, in item 16, and in item 24 show the producing intervals for only the interVal reported in item 27. SUbmit a separate form for,each additional interval to be seParately produced, showing the data pertinent to such interVal. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 2.7' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, 'Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Began perforating operation on 2/5/88. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 12244-12264'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 12224-12244'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 12215-12221'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, misfired. RIH w/gun #4, shot interval 12202-12208'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #5, shot interval 12215-12221'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Secured well. R.D. Ref. BHCS 8/7/82 STAT17:SN 4-29 ARCO ALASKA, INC, F'.O. BOX ANCHORAGE, ALASKA DATE: 2-23-R8 REFERENCE: ARCO CARED HOLE FINAl.. 2-,3.-88 t-25-88 2-4-88 COLLAR/PERFORATION RUN t, 5' £ONAN RHN t, 5' COI..LAR/PERFORATInN RI.IN 2-5-88 COLLAR/PERFORATION RI.IN i-22-88 F'RO~:LTON PACKER RUN t, F'LEAS'E £IGN AND _ F1PY~T OF DATA., ;~i~s~ Oit & Gas Cons. commts~Tc., PEGGY BENNETT AT0-t529 TRAMS ~88t26 APPROVED DI£TRIBI. JTTON ATI..A2 ATL. A2 ATI...A.~ ATI. A.~ ATI...A2 CENTRAl.,. FILES CHEVRON D&M EXTEN£ION EXPLORATION EXXON MARATHON .. MOBIl_ ~',,.PHILLIPS F'R WELL FII..E2 ~' .~,.2APC ~i?~5'TATE OF AL'A.~KA ' TEXACO STATE Of ALASKA ALAS OIL AND GAS CONSERVATION COM ..,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~. Stimulate ,.-1 Plugging ~ Perforate ~ Pull tubing Alter Casing ~.. Other,~ WORKOVER 2. Name of Operator 5. ARCO ^laska, Inc, 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, TION, R14E, UM At top of productive interval 992' FSL, 1221' FEL, Se¢.16, TION, R14E, UM At effective depth 458' FSL, 1341' FEL, Sec.16, TION, R14E, UM At total depth 432' FSL~ 1347' FEL; Sec.16; TION~ R14E~ UM Datum elevation (DF or KB) RKB 71 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-21 8. Approval number 7-1~2R 9. APl number 50-- 029-20756 10. Pool Prudhoe Bay 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13060'MD feet Plugs (measured) None 9641 ' TVD feet 13018'MD feet Junk (measured) None 9609 ' TVD feet Casing Conductor Surface Length Size Cemented Measured depth 76' 20" 350 sx PF II 111'MD 2482' 13-3/8" 2500 sx'AS III & 2517'MD 400 sx AS II 12003' 9-5/8" 500 sx Cl ass G & 12036'MD 300 sx AS II 1298' 7" 400 sx C1 ass G 13060'MD Production Liner True Vertical depth 111 'TVD 2517 'TVD 8892 ' TVD 9641 'TVD Perforation depth: measured 12816 ' -12866 ', 12984 ' -12914 ' true vertical 9212'-9331 ', 9337',9344',' 9349"-9387' 9474 '=9512 ', 9532 ' -9547 ' Tubing (size, grade and measured depth) 5-1/2"/4-1/2", L-80 tbg w/tail ~ 12451' Packers and SSSV (type and measured depth) FB-1 pkrs ~ 11707' & 12395', & Ba]-O SSSV ~ 2156' 12. Stimulation or cement squeeze summary 12464'-12624' 12632'-12642', 12648'-12698' 12714'-12764' , 9399'-9436', Intervals treated (measured) 12260'-12264' Treatment description including volumes used and final pressure 125 sx C]ass G A~%horage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well History) Daily Report of Well Operations j~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ S~.L ~AJ Form 10-404 Rev. 12-1-85(~ Title Associate Engineer Date (Dani) SW03/48 Submit in Duplicate ARCO Oil and Gas Company,~,'~' Well History - Initial Report - Daily Inatructiene: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District Field ARCO Alaska, Inc. ICounty, parish or borough ..... NORTH SLOPE-PRUDHOE BAY Lease or Unit ADT,: 28314 Title WORKOVER PRUDHOE BAY FIELD Auth. or W.O. no. AS1801 I Sta~K I Well no. DS 14-2~ API: 50-029-20756 Operator ARCO Spuddecl or W.O. begun IOate /Hour ACCEPT I 01/09/88 2700 Date and depth aa of 8:00 a.m, 01/09/88 ( TD:13060 PB:13018 SUPV:JH/BB 01/10/88 ( TD:13060 PB:13018 SUPV:JH/BB 01/11/88 ( TD:13060 PB:13018 SUPV:JH/BB 01/12/88 ( TD:13060 PB:13018 SUPV:JH/BB 01/13/88 ( TD:13060 PB:13018 SUPV:JH/BB 01/14/88 ( TD:13060 PB:13018 SUPV:RS/JE 01/15/88 ( TD:13060 PB:13018 SUPV:RS Complete record for each day reported WESTWARD RIG 1 HRS IARCO 22.0000 Prior status if a W.O. CIRC. TO KILL WELL MW: 8.5 SEAWATER MOVED RIG FROM DS 5 TO DS 14. ACCEPTED RIG @ 2200 HRS, 1/8/88. PULLED BPV. RU & CIRC. WELL WITH SEAWATER DOWN TUBING TAKING RETURNS UP THE ANNULUS. DAILY:S33,400 CUM:$33,400 ETD:S33,400 EFC:$675,000 ATTEMPT TO SHEAR PBR MW: 8.5 SEAWATER CIRC. SPOTTED 100 BBLS LCM PILL. SET BPV. ND TREE. NU BOPE& TESTED. SPOTTED 50 BBLS LCM PILL. ATTEMPTED'TO SHEAR PBR. DAILY:S25,690 CUM:$59,090 ETD:S59,090 EFC:$675,000 POH W/5-1/2" TBG MW: 8.5 SEAWATER ATTEMPTED TO SHEAR PBR. RU DRESSER. RIH, CUT TUBING @ 11680'. ATTEMPTED TO WORK HANGER THROUGH HYDRIL-UNSUCCESSFUL. C/O & TEST ANNULAR PREVENTER. POH, LD HANGER & 5-1/2" TUBING. REPAIRED SCR. POH, LD 5-1/2" TUBING. DAILY:S42,683 CUM:$101,773 ETD:S101,773 EFC:$675,000 RIH MW: 8.5 SEAWATER SLIPPED & CUT DRILL L~NE. SERVICED RIG. FINISHED POH & LD 5-1/2" COMPLETION ASSEMBLY. TESTED PIPE RAMS. PU FISHING TOOLS & 3-1/2" DP; TIH. DAILY:S25,950 CUM:$127,723 ETD:S127,723 EFC:$675,000 RIH W/BURNING SHOE MW: 8.5 SEAWATER RIH. SPOTTED 50 BBLS LCM PILL. ENGAGED FISH; SHEARED PBR. POOH. CO FISHING ASSEMBLY. RIH WITH BAKER RET. TOOL, ENGAGED PBR BARREL. ROTATE OUT OF K- ANCHOR. POH. LD PBR. PU PKR MILL OVER ASSEMBLY. RIH. DAILY:S27,165 CUM:$154,888 ETD:S154,888 EFC:$675,000 MILLING PACKER MW: 8.5 SEAWATER RIH WITH MILLING BHA. MILLED PACKER F/11728'-11729'. TRIPPED FOR NEW MILL. MILLED PACKER F/11729'-11729.5' DAILY:S24,952 CUM:$179.840 ETD:S179,840 EFC:$675,000 POH W/ TOP PACKER MW: 8.5 SEAWATER MILLED PACKER FROM 11729.5'-11731'. PUSHED PACKER TO 11735'. POH. RIH WITH OVERSHOT, ENGAGED PACKER & POH. DAILY:S27,562 CUM:$207,40.2 ETD:S207,402 EFC:$675,000 The above is correct Signature I Date For form preparation and/¥istributlon, see Procedures Manual, ~'ection 10, Drilling, Pages 86 and 87. Associate Engineer ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. l County or Parish IState ARCO Alamka. Inc. NORTH ~LOPE-PRUDROR RAY AK I Lease or Unit IWell no. · VTV. T.D ADT..- ?R~I 4 DS 14-9! Complete record for each day while drilling or workover in progress 01/16/88 ( TD:13060 PB:13018 SUPV:RS 01/17/88 ( TD:13060 PB:13018 SUPV:RS 01/18/88 ( TD:i3060 PB:13018 SUPV:RS 01/19/88 ( TD:13060 PB:13018 SUPV:RS 01/20/88 ( TD:13060 PB:13018 SUPV:RS 01/21/88 ( TD:13060 PB:13018 SUPV:JH .o) .1) .2) L3) WESTWARD RIG 1 RIH WITH SPEAR MW: 8.5 SEAWATER POH WITH TOP PACKER. LD & PU NEW 6" MILL ASSEMBLY. RIH, MILLED PACKER. POH. NO PACKER. LD MILL & SPEAR~ PICKED UP NEW BHA WITH NEW SPEAR & RIH. DAILY:S25,444 CUM:$232,846 ETD:S232,846 EFC:$675,000 POH W/BOTTOM PACKER MW: 8.5 SEAWATER FINISHED RIH WITH SPEAR. TAGGED PACKER & PUSHED TO BOTTOM. POH. NO FISH. CHANGED ASSEMBLIES. RIH WITH TAPERED TAP, TAGGED FISH & POH. NO FISH. CHANGED ASSEMBLIES AGAIN. RIH WITH PACKER RETRIEVING TOOL, TAGGED FISH. BREAK CIRC. ENGAGED FISH & POH. DAILY:S27,188 CUM:$260,034 ETD:S260,034 EFC:$675,000 RIH W/MILL & SCRAPER MW: 8.5 SEAWATER POH WITH PACKER RECOVERY TOOL. NO FISH. LAY DOWN ASSEMBLY. PU FTA (SPEAR & 2 EXTENSIONS) & RIH. ENGAGED PACKER TAILPIPE & POH. LD PACKER & FISHING BHA. RIH WITH 6" MILL & CASING SCRAPER. DAILY:S26,092 CUM:$286,126 ETD:S286,126 EFC:$675,000 RIH W/ TBG AND DP MW: 8.5 SEAWATER FINISH RIH W/ 6" MILL AND SCRAPER. CLEAN OUT TO 12,996'. POOH. RIG UP DRESSER W/L. RIH W/ CMT RETAINER TO 12,300' AND SET. TEST CSG TO 2500 PSI. PERF W/ 4" GUN AT 4 SPF F/ 12,260' TO 12,262'. POOH. UNABLE TO PUMP. RIH AND PERF F/ 12,262' TO 12,264' W/ 4 SPF. POOH. PREPARE TO RIH W/ CMT SQUEEZE ASSEMBLY. DAILY:S70,394 CUM:$356,520 ETD:S356,520 EFC:$675,000 RIH W/ CMT BHA MW: 8.5 SEAWATER RIH W/ DP AND 2-7/8" TBG AND STINGER TO PERFS. RIG UP AND PUMP 5 BBLS 15% HCL W/ 10% MUSOL, SHUT IN AND SQUUEZE INTO . PERFS. FOLLOWED HCL W/. 5 BBLS 15% HCL W/ 10% MUSOL, 10 BBLS MUD ACID, 10 BBLS NH4CL2. DISPLACE TO PERFS AND SQUEEZE. BATCH MIX 125 SX CLASS G CEMENT AND SET BALANCE PLUG. POOH 11 STANDS AND SQUEEZE 26 BBLS INTO PERFS. REVERSE OUT DP. POOH W/ DP. LAY DOWN 2-7/8" TBG. PU 8-1/2" DRLG ASSEMBLY. DAILY:S61 534 CUM:$418,054 ETD:S418,054 EFC:$675,000 MW: 8.5 SEAWATER RIH TO 11750'. POOH. LD PU 6" BHA. RIH. DRL CMT F/ [TD:$443,304 EFC: $ 6,%~e9~[ g, DRLG CMT SERVICE. RIG. PU 8-1/2" BHA. 8-1/2" BHA. SERVICE HYDRIL. 12141' TO 12222' DAILY:S25,250 CUM:$443,304 The above is correct Signature I Date For form preparation and distj, fyution see Procedures Manual Secti~l~ 10. Drilling, Pages 86 and 87 Title /_~_~ Associate Engineer ARCO Oil and Gas Company Uaily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final*' form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field p R Tlr~ T-I~I~. Date and depth as of 8:00 a.m. County or Parish Lease or Unit , '~T~..T,I') n.q 1 4-?,1 complete record for each day while drilling or workover in progress 01/22/88 ( TD:13060 PB:13018 SUPV:JH 01/23/88 ( TD:13060 ?B:13018 SUPV:JH 01/24/88 ( TD:13060 PB:13018 SUPV:JH WESTWARD RIG 1 L6) IState AK NORTR SLOP~-PRUDROR RAY DISP WELL W/ SEAWATER MW: 8.5 SEAWATER SERVICE RIG. DRLD CMT F/ 12222' TO 12310'. CIRC. TEST CSG TO 1000 PSI. POOH. LD SCRAPER. CHANGE OUT BITS. RIH. DRLD CMT RETAINER. CHASE JUNK TO 12981'. CIRC. DISPLACE WELL W/ FILTERED SEAWATER. DAILY:S26,738 CUM:$470,042 ETD:S470,042 EFC:$675,000 01/25/88 ( TD:13060 PB:13018 SUPV:JH GIH WITH PKR ON DP MW: 8.5 SEAWATER DISPLACE WELL WITH FILTERED SEAWATER. LOG CASED. RIH AND SET 7" PACKER @ 12395 . MU 9 5/8 FB-1 PACKER AND GIH ON 3 1/2" DP. DAILY:S47,625 CUM:$517,667 ETD:S517,667 EFC:$675,000 MW: 8.5 SEAWATER FIH WITH PACKER AND SET @ 11684'. POOH. LDDP. TEST RAMS TO 5000 PSI. RIH WITH 5 1/2" COMPLETION ASSEMBLY. no. L7) DAILY:S25,250 CUM:$542,917 ETD:S542,917 EFC:$675,000 CO PISTON IN HYDRILL MW: 8.5 SEAWATER RUN 5 1/2" AB MOD COMPLETION ASSEMLBY. 3 JTS. OF 4 1/2" 12.6 'L-80 AB MOD BTC TUBING + 282 JTS. OF 5 1/2" 17# L-80 AB MOD I?C TUBING. TAIL @ 12451'. TEST TUBING TO 3000 PSI. SET B?V. REPAIRING HYDRILL. DAILY:S180,984 CUM:$723,901 ETD:S723,901 EFC:$675,000 The above is ce rrect Signature _ I Date For form preparation and distrj~Jtion see Procedures Manual Section/10. Drilling, Pages 86 and 87 ~/ Associate Engineer ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. DiStrict ICounty or Parish NORTE. SLOPS-?RODEOE SAY Lease or Unit ADL: 28314 Title NORKOVER I Accounting cost center code Stat~,( DS 14_~Nell no. ARCO Alaska, Inc. Field PRUDEOE BAY FIELD Auth. or W.O. no. ASl801 Operator I A.R.Co. W.I. ARCO I 22. 0000 Spudded or W.O. begun ~Date ACCEPT I 01/09/88 01/26/88 Date and depth as of 8:00 a.m. TD:13060 PB:13018 SUPV:JH Complete record for each day reported WESTWARD RIG 1 API: 50-029-20756 Iota l number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well I our ~Prior status if a W.O. 22°O ERS I RIG RELEASED MW: 8.5 SEAWATER CO PISTON IN HYDRILL. ND BOPE. NU GRAY GEN II 5 1/2" TREE. TEST TREE TO 5000 PSI. SECURE WELL'~ RELEASE RIG @ 2300 MRS 1/25/88. MOVING RIG TO NGI-6. DAILY:S46,747 CUM:$770,648 ETD:S770,648 EFC:$675,000 Old TD Released rig New TD Date PB Depth Kind of rig Classifications (oil, gas, etc.) Producing method Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected .. The above is correct Signature ~¢.~ [~r~,,/~ (,..,, ~f~,_/~/.,t.¢_,~.~/ For form preparation and distri~jtion, see Procedures Manual, Sectidt~/10, Drilling, Pages 86 and 87. IDate ITitle Associate Engineer ,, ~]'^'i'E OF ~,O,I'.E, ]nspec~ton P,~.port Permit #__ ~- ~_ , '-"' ~ ,~'~'~' '~ ' k ~ t Loeation; :~:, ~ ~.i R/~ ,~ ~,~,,~ 7 Casing $~t ~ /JO~O ft . ' . ,~ },~ ~~ ~ _c_o n.,t__~.~?~ ....... ~L)~_cL~ ,.'_-_.,z ~ r.,~_:~ .?i~ ~- !_~ ~,~. =, ~ ~, ~ ~ t i v ~_ ~ n.,&. ~..0__ ~ . .. W~il S_t.~., ACCUHULATOR SYSTD'i , · Rig. Audio Flow M.onieor ~ [! '" · ' Tas[ ?ressu_r._q li, C. R Valve ~,a ~ .Trip ... '" Pie Gauge".' Full Charge Pressure~ psis, Pressure After Closure /~O_O ....... psis Pump incr. clos. pres. 200 ps£g ......... · ,., ,.min..q;') Full Charge Pressure Aeeained: Corttrol~: }faster Re.lo~e /' Blinds switch cover ge : of failed equipmen~ to be made within C:~'~'~:':,ai$~ion o ..... $Ce notified ~1 Type C}, ~t,'.~' Manifold l'~o. Valves_.. Adjustable Cboke.s / Hydrc:~ica!!y oEp~bT.~, choke days and Inspect'or/ otis,,.- AO&GCC '~e'"';..:- Operator - Supervisor "1 ARCO Alaska, Inc. ( Prudhoe Bay ~.,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 8, 198% C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-21 Permit No. 82-86 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SKD/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(D8 14-21)W1-3 RECEIVED JAN 0 8 !988 Nasim 0il & ~as Cons. C0mmissl0ff Anchorage WELLS2/52 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C t( STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION COMk( ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ;- Alter casing Time extension .~ Change approved program G Plugging G Stimulate ~ Pull tubing Q Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 992' FSL, 1221' FEL, Sec. 16, T10N, R14E, tiM At effective depth 459' FSL, 1341' FEL, Sec. 16, T10N, R14E, UM At total depth 432' FSL, 1347' FEL, Sec. 16, Ti0N, R14E, UM 5. Datum elevation (DF or KB) 71' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 14-21 feet 8. Permit number 82-86 9. APl number 50-- 029-207,56 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 13060 feet 9641 feet Plugs (measured) Effective depth: measured true vertical Casing Conductor Intermediate Length 13018 9609 Size 20" 13-3/8" Production 9-5/8" Liner 7" feet feet Junk (measured) Cemented Measured depth WueVerticaldepth 350 Sx PF II 76' 76' 2500 Sx AS III & 2517' 2517' 400 Sx AS II 500 Sx C1 G & 12036' 8877' 300 Sx AS II 400 Sx Cl G 13060' 9641' Perforation depth: measured 12464-12624'; 12632-12642'; 12648-12698'; true vertical 9196-9531' Tubing (size, grade and measured depth) 5~", L-80, 11746', 4~" tubing tail, N-80, 11812' Packers and SSSV (type and measured depth) Baker SAB @ 11735' MD; Camco Bal-0 SSSV ~...2200' 12.Attachments JAN 0 8 ]~88 Alask~ Oil & Gas Cons. Commissip~l Anchora,g.(~ Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 12, 1988 14. If proposal was verbally'approved Name of approver Date approved 15. I hereby,,certify that the foregoing is true and correct to the best of my knowledge Signed ~///~~~~ Title Operations Engineering Manager Commission Use Only Date Conditions of approval Approved by ORIGINAL 816NED BY LONNIE 13, Notify commission so representative may witness [] Plug integrity ~ BOP Test ~ Location clearance Approved Copy Returned/,.~ _ Commissioner Form 10-403 Rev 12-1-85 WELLS2/52 S. K. Allsup-Drake, 263-4244 IApproval No. by order of the commission Date Submit in triplicate/ DS 14-21 PROPOSED INITIAL PERFORATIONS ARCO Alaska, Inc. proposes to make initial perforations within the Sadlerochit interval in Well 14-21. The proposed perforation intervals are as follows: Existing Perforations Proposed Perforations 12464-12624' MD 12632-12642' MD 12648-12698' MD 12714-12764' MD 12816-12866' MD 12894-12914' MD 12202-12208' MD (6') 12215-12221' MD (6') 12224-12264' MD (40') Ref: BHCS of 8/7/82 A 5000 psi WP wireline lubricator and BOP, tested to 4000 psi working pressure prior to the job, will be utilized for this operation. RECEiYEI) JAN 0 8 ~.$~ _Alaska Oil & Gas Cons. Commissio~ Anchorage WELLS2/52 m I 3 i' ' ,I ii i, . ii 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) .5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PMENT ....... ~m~O ~ I 51008 0 REV. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ,~ Operation Shutdown [] Re-enter suspended well Q Alter casing Time extension E~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order ~ Perforate,~ Other 2. Name of Operator ARCO Alaska~ Inc . . . 3, Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, TION, R14E, UM At top of productive interval 992' FSL, 1221' FEL, 5ec.16, TION, R14E, UM At effective depth 458' FSL, 1341' FEL, 5ec.16, TION, R14E, UM At total depth 432' FSL, 1347' FEL, 5ec.16, TION, R14E~ UM 11. Present well condition summary Total depth: measured 1 3060 ' MD feet Plugs (measured) true vertical 9641 ' TVD feet 5. Datum elevation (DF or KB) RKB 71 ' feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-21 8. Permit number 9. APl number 50-- n2~-~n75fi 10. Pool Prudhoe Bay 0il Pool Effective depth: measured 1 301 8 ' M D feet true vertical feet 9609'TVD Casing Length Size Conductor 76' Surface 2482' Production 12003' Liner 1298' Perforation depth: measured true vertical 20" 13- 3/8" 9-5/8" 7" Junk (measured) None "-'~'~-' ~ .... ::' Cemented Measured depth '~:~ True ~r~a40~epth 350 sx PF I I 111'MD 111 'TVD 2500 sx AS III & 2517'MD 2517'TVD 400 sx AS II 500 sx Class G & 12036'MD 8892'TVD 300 sx AS il 400 sx Class G 13060'MD 9641'TVD 1 2464 ' -1 2624 ' 1 2 12816'-12866' 12 9212' 9331 ' 9337 632'-12642' 12648'-12698' 12714'-12764' 894'-12914' '-9344', 9349'-9387', 9399'-9436', 947n~' -951 2 ' 9532 ' -9547 ' Tubing (size, grade and measured de..h) ' 5-1/2" 17#, L-80 11746'MD, 4-1/2" 12.6#, N-80 tbg tail 11746'-11812' & 12306'-12325'MD Packers and SSSV (type and measured depth) 9-5/8" SAB pkr ~ 11735'MD, 7" FB-1 pkr ~ 12306'MD, 5-1/2" Bal-O SSSV nipple @ 2200' 12.Attachments Description summary of proposal ~ Detailed operations program [] 13. Estimated date for commencing operation BOP sketch November 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~--J~~ ~_~J,//..f/tJ Title Associate Enaineer ~ Commission Use Only ( ) LWK . Date SA2/123 Conditions of approval Approved by Form 10-403 Rev~-l~:t~,~ Notify commission so rePresentative may witness I Approval No. ~,~ [] Plug integrity ,~ BOP Test [] Location clearance '~" ' Commissioner the commission Date/~)~'¢:~('/"(~ '"'J Submit in triplicate DS 14-21 PROCEDURE SUMMARY 1) MIRU WW1. ND tree. NU BOPE and test. 2) POOH w/tubing and PBR seals. 3) RIH. Latch PBR barrel. POOH. 4) RIH and mill SAB packer. CBU. POOH LD packer/tailpipe. 5) RIH and mill FB-1 packer. CBU. POOH LD packer/tailpipe. 6) RIH and squeeze cement across all perforations. 7) Test casing. 8) TIH w/bit and clean out to 12975'. CBU. Test squeeze. 9) PU new completion assembly consisting of: o 4-1/2" tailpipe with "No-Go" nipple at +11802'. ° 9-5/8" permanent packer with seal assembly at +11700'. ° 5-1/2" tubing w/GLMs. ° 5-1/2" SSSV at +2200'. 10) Land tubing and set packer. Test tubing and annulus. 11) Release rig. 12) Perform long-term tubing test. 13) Reperforate for pre-production. Set BPV. ND BOPE. NU tree and test. LWK/IO 10/7/87 ANNULAR PREVENTER § PIPE RAHS 5 BLIND RAHS 4 TUBING HEAD 1. 13-:3/8" CASING HEAD 2. 9-15/8" CASING HEAD :3. 5000 PSI TUBING HEAD 4. 13-5/8" - 5000 PSI BLIND Rarls 5. 13-5/8" - 5000 PSI PIPE I~AMS 6. 13-5/8" - 5000 PSI ANNULAR ACCUMULATOR (;APAI;ITY TEST I. CHECK ANO FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :3000 PSI WITH 1500 PSI DCN/NSTREAI'I OF THE REGtJLATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SII'IULTANEOUSLY AND RECORD THE TIME AND PRESSURE REHAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REHAINING PRESSURE. ~OP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN $CP, EWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, CLOSE ANNULAR PREVENTEP, AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. §. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAI~: PRESSURE TO ZERO PSi TO TEST VALVES. TEST I~EMAINING UNTESTED MANIFOLD VALVES. IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTP, EAM. BLEED SYSTEM TO ZERO PSI, 9. OPEN PIPE ,qAMS. BACKOFF t~.UNNtNG JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000. PSi FOR !0 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 PSt. 12. TEST KELLY COCKS AND INSIDE BOP TO S000 PSi WITH KOOMEY PUMP 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. AND SEND TO DRILLING SUPEP. VISOR. !4 PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER-21 , 1986 ARCO Alaska, In(' Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Cased Hole Finals D.S. 3-6~-' D.S. 3-19 D.S. 3-22 ~ D.S. 6-10f D.S. 7-3--- D.S. 7-18~ D.S. 7-24' D.S. 9-18 D.S. 12-15'-~ D.S. 12-18~ D.S. 13-1/' D.S. 13-10''~' D.S. 13-12--- .... D.S. 13-16~' ~ ~ ~_ ~D.S. 13-27 ~'' ............... D.S. 13-28 D.S. 13-28~~ D.S. 13-28~' D.S. 13-33~'' D.S. 13-33/~ D.S. 14-3~ D.S. 14-21' 6-10-84 Diff Temp 5-25/26-84 Spinner Survey 6-29-84 Spinner Survey 7-4-84 Temp Log 7-6-84 Temp Survey 7-4/5-84 Spinner 4-19-84 Spinner 6-21-84 Diff Temp 4-13-84 Spinner 4-14/16-84 Spinner 6-17-84 Diff Temp 6-22-84 Temp Log 6-18-84 Diff Temp 5-31-84 CFS/Spinner 4-12-84 Diff Temp 6-2-84 CFS/Spinner 6-3-84 CFS/Spinner 6-3-8~4 Temp Survey 7-8-84 Temp Log 6-22-84 Diff Temp 6-23-84 Spinner Log 6-30-84 Diff Temp 7-7-84 Caliper Log D.S. 14-24j 3-25-84 Caliper Log D.S. 14-34-" 5-19-84 Spinner Log D.S.~ 17-10j 6-17-84 Diff Temp · ~se sign and return the attached copy data. Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Go Run 1 5" Camco Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 4 5" Camco Run 1 5" Camco Run 1 5" Camco as receipt of Kelly McFarland ATO-1429F · Trans. #301 D I STRIBUT ION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob L ~ Mobil E & P ,~!as~a 0il ~ Gas Cons. Commissio~ Anchorage Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. ( Post Office BS'~ 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 26, 1983 Reference: Arco Pressure Data D.S. 7-6 J 4-9-83 D S 9-6 ~' . 4-17-83 4-17-83 D.S. 14-6 ?" 4-3-83 4-3-83 D.S. 14-11/ 3-24-83 D.S. 14-17 j' 3-27-83 · D.S. 14-21 / 3-25-83 D.S. 15-3 / 5-6-83 Static Survey DA Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up DA Pressure Build-up Survey Report Pressure Gradient Survey Otis Pressure Build-up Sch Pressure Build-up Sch Static survey DA se sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans· # 351 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY STATE OF ALASKA DALLAS "~-,,, ".Z'--~ -~-~,~ CAROL]:NE SMITR~ '..,,,,.?o. -~ ~,~ ARCO Alaska, Inc. [. Post Office Bo~"360 Anchorage. Alaska 99510 Telephone 907 ;!77 5637 May 26, 1983 Reference: Arco Cased Hole Finals D.S. 2-lA 11-28-82 D.S. 4-15 / 4-1-83 D.S. 5-7 - 4-14-83 D.S. 6-3 -- 4-13-83 / D.S. 7-3 12-3-82 D.S.. 7-11J 12-4-82 D.S. 7-14 j 12-5-82 D.S. 7-18'~ 1-9-83 D.S. 7-19 1-28-83 D.S. 12-1'~ 12-2-82 D.S. 12-18" 1-11-83 . D.S. 13-18' 3-23-83 D.S. 13-34~-- 4-2-83 D.S. 14-17 ~' 3-27-83 D.S. 12-9-82 D.S. 3-25-83 CN/MSN/GR CH CNL CH CNL CH CNL CN/MSN/GR CN/MSN/GR CN/MSN/GR ACBL/VDL/GR ACBL/VDL/GR CN/MSN/GR ACBL/VDL/GR EPL TDT EPL CN/MSN/GR EPL Run 7 5" DA Run 8 5" Sch Run 10 5" Sch Run 7 5" Sch Run 3 5" DA Run 8 5-" DA Run 8 5" DA Run 1 5" DA Run 1 5" DA Run 3 5" DA Run 1 5" DA Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch sign and return the attached copy as r'eceipt of data. Kelly McFarland AFA-403 Trans. # 361 NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON MOBIL GETTY D &,M STATE OF ALASKA DALLAS I MITH '~' ~ / ARCO Alaska, in~mmm) Post Officemm~'x '360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 11~, 1983 Reference: Arco Cased Hole Finals D.S. 1-18~ 11-13/14-82 D.S. 13-6- 12-4~82 D.S. 9-4/ 12-8-82 D,S. 13-13 ~"11-12-82 D.S. 11-3~ 12-16-82 D.S. 11-6/ 11-6-82 'D.S. 12-9-- 12-2-82, D.S. 13~6-- 12-3-82 D.S 14-15~-12-21-82 D.s 11-,-82 D.S. 15-13~11-28-82 Spinner 5" Camco Diff Temp Log Run 1 5" GO CH CNL Run 6 5" Sch Collar Log Run 4 5" GO Spinner 5" Camco CCL & Perf~Log Run 1-3 5" GO C~L/GR/CCL (CH) Run 3 5" Sch CBL/VD Run 1 5" Sch Spinner 5" Camco CCL & Perf Log Run 1-4 2" & 5" G£ Spinner 5" Camco CFS/Spinner Run 1 5" GO · ase sign and return the attached copy as receipt ~f data. Kelly McFarland AFA-403 Trans. ~ 035 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBILE ,~? DRILLING GETTY PHILLIPS D & M SOHIO STATE OF ALASKA MARATHON DALLAS CHEVRON ARCO Alaska. Inc. ill II SuDllidiar¥ of AtlenticRichfiel¢JComl)an¥ A~aska, Inc. ( Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 22, 1982 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- D.S. 14-17 Permit No. 81-21 D.S. 14-21 Permit No. 82-86 Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/lmi Enclosures cc' Sohio Petroleum Co. RECEIVED DEC2 9 1982 0}{ & Gas Cons, CommJssjo;) Anchorage ARCO Alaska, Inc. Is a Subsidiary of AflantlcRIchfleldCompany ALASKA- -- AND GAS CONSERVATION C , MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL J][]~ GAS[]] SUSPENDED J-J ABANDONED l-1 SERVICE J~J 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-86 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o- 029-20756 4. Location of well at surface 9. Unit or Lease Name 2715' FNL,1562' FEL, Sec. 9, T10N, R14E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 992' FSL, 1221' FEL, Sec. 16, T10N, R14E, UM 14-21 At Total Depth 11. Field and Pool 432' FSL, 1347' FEL, Sec. 16~ T10N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKB ., ADL 28314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 07/18/82 08/07/82 08/23/82J N/A feet MSLJ 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey ~2/~0. DepthwhereSSSVset I 21.ThicknessofPermafrost 13060' MD, 9641' TVD 13018' MD, 9609' 1 ~l~s [:)( NO [] 21 feet MD ] 900' 22. Type Electric or Other Logs Run D]~L/BHC/GR/SP, CDL/CNL/GR/Cal, GR/CNL. CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9].5~ H-4(1 .~rf 7R' q¢1" "~1~ cv D .... -~v.,,.,,,...l- TT 13-3/8' 72.0~ !-80 SlJrf_ 2617' !7½" ?~nnsx AS TT! & ~.O0SX ASII 9-5/8" 47.0~ I-gO& S~Jrf l?rl.~¢;, !2¼" 500sx C!~e~ r. ~. ~nn sx AS!! S00-95 7" 29.0..' L-80 11762' 1.~n~n' ~½,' 400sx Class G 24. Perforations open to Prod'~]otion (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Ref' BHCS 8/7/82 5_~' 12464-12624'MD 12632-12642'MD 9125,9460TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '12648-12698'MD ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12714-12764 'MD 12816-12866 'MD 12894-12914 'MD ~ . 27. N/A PRODUCTION TEST Dat~_~.~s~r?~cti°n JMeth°d°f?i~crati°n(Fl°wing, gaslift, etc')Gas L Dateof.Test )Hours Tej. t~d PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO 11:/25/8; ~ TEST PERIOD 'J~ 385(] 7000 FioTM Tubing Casing Pressure CALCULATED~' jj~ O1L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 750 ' 1950 24-HOUR RATE' 6600 12000 28. CORE DATA Brief description of lithology, porositY, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RE£EJVED DEC2 Alaska 0ii & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE MEAS. DEPTH 12197' 8997' 12306' 9078' Not reache 'op Sadlerochit )/W Contact ~ase Sadlerochit Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. ( Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248' Donald F. Scheve Regional-Operations Engineer December 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- D.S. 14-17 D.S. 14-21 Permit No. 81-21 Permit No. 82-86 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/TKKW/1 mi Attachments cc- Sohio Petroleum D£C2 9 982 AIaska 0it & Gas Cons Cornmissim Anchorage &Rr"~ AlmekA Im~' IA A ~;~,h~l~iqrv Of Atl~tlcRIchfl~IdCttmDmrt¥ ALASKA LAND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Na o~f_Op~r_ator 7. Permit No. "~[;U Alaska, Inc. 82-86 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 5o- 029-20756 OTHER [] 4. Location of Well 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UN (Surf) 992' FSL, 1221" FEL, Sec. 16, T10N, R14E, UN (Top Prod) 432' FSL, 1347' FEL, Sec. 16, T10N, R14E, UN (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 71' RKB ] ADL 28314 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [-~ Altering Casing E~ Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25,105-170). SEE ATTACHED SHEET RECEIVED DEC2 9 1982 Alaska 0il & Gas Cons. ~;0rnmLssio~ . Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .......... /' Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ^~as~a, Inc. Post Office, F~ox 360 Anchorac~f' laska 99510 Telephon~--,,,J7 277 5637 December 3, 1982 RE' ARCO Pressure Surveys D.S. 2-14 D.S. 4-8 D.S. 4-5 D.S. 4-11 D.S. 11-3 ~D.S. 12-3 JD.S. 14-12 D.S. 14-21 O.S. 16-9 9-5/6-82 11-12-82 11-15-82 Static Survey 10-17/18-82 Pressure Build-Up 11-11-82 Static Survey 11-13-82~ Pressure Bui 1 d-Up 10-9'82 Pressure Build-Up 11-14-82 Static Survey 9-15-82 S tati c Survey D.S. 16-11 10-8/11-82 Pressure Build-Up si§n and return the attached copy as receipt of data. Pressure Bui ld-Up Camco Pressure Build-Up (Water Injection Well) Schlumberger Dresser Atla Camco Gearhart Dresser Atla Gearhart Gearhart Camco Becky Benedi ct AFA-403 Trans., #636 DISTRIBUTION NORTH GEOLOGY R'& D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA An:..:hora~o Inc. is a Sub~i~diar¥ o! Allal~licRlchfi~tdC. omoanv Began perforating operation 11/7/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot &'~~'MD 4spf (20' ref. CBL 8/11/82). POH-all shots fired. RIH with gun #2, shot 12846-~'MD 4spf (20' ref CBL 8/11/82). POH, all shots fired.~RIH with gun #3, shot 12826-12846'MD 4spf(20' ref. CBL 8/11/82)- POH all shots fired. RIH with gun #4, shot ~.~1~12826'MD and 12754-~MD 4spf (10' and 10' ref CBL 8/11/82). POH. Gun stuck in isolation packer on way out of hole. Rig up pump truck. Pump down diesel to free gun. Rig down pump truck. Work wireline. Pulled free. Recovered wire, left gun and CCL in hole. Rig down perfora~i~ng unit. Rig up perforating unit 11/10/82. RIH with dummy gun to bump fish in hole. POH. Rig down perforating unit. Rig up perforating unit 11/13/82. RIH with gun #5, shot 12734-12754'MD 4 spf (20' ref CBL 8~11/82). POH, 'all shots fired. RIH with gun #6, shot ~-12734'MD 4spf (ref CBL 8/11~82).. POH - all shots fired. RIH with gun #7, shot t2678-~9~MD 4spf (20' ref CBL 8/11/82). POH, all shots fired., RIH with gun #8, shot 12658'-12678' MD .4spf (20' ref CBL 8/11/82). POH all shots fired. RIH with gun #9, sho~ ?~6~-12658'MD and 12632-~'MD 4spf (10~' and 10' ref. CBL 8/11/82. POH all shots fired. RIH with gun #10, shot 12604~MD 4spf (20'~' ref CBL 8/11/82). POH one shot misfired. RIH.with g6~ #11, shot 12584-12604'MD 4spf (20' ref CBL 8/11/82). POH all shots fired. RIH with gun #1'2, shot 12564-12584'MD 4spf (20'ref CBL 8/11/82). POH all shots fired. RIH with gun #13, shot 12544-12564'MD 4spf (20' ref CBL 8/11/82). POH,~all shots fi~ed. RIH with gun #14, shot 12524-12544'MD 4spf ~(20' ref CBL 8/11/82). POH all shots fired. RIH with gun #15, shot 12504-12524'MD 4spf (20' ref CBL 8/11/82). POH all shots fired. RIH with gun #16, shot 12484- 12504'MD 4spf (20' ref CBL 8/11/82). POH, one shot misfired. RIH with gun #17, shot ~12484'MD 4spf (20' ref CBL 8/11/82). POH all shots fired. Ran stat~'c~HP. RD. secured welt 1~1/14/82. Post Office Box 300 Anchorage~ Alaska 99510 Telephor~"~ ')7 277 5637 October 27, 1982 Reference' ARCO Magnetic Tapes with listings D.S. 13-16 9-30-82 DIL/BHC/LDT/CNL/CH CNL Run 1 Mag. Tape //ACC 65654 D.S. 6-23 10-17-82 Open Hole 'Run 1 Mag. Tape #65735 D.S. 14-9B 4-10-82 (Corrected) GR-CN, BHC AL,- CDL Mag. Tape #ECC 1275 D.S. 14-21 7-7-82 CN/CDL, DIFL-BHC/AL Pass 1 & 2 Mag. Tape #ECC '1400 e sign and return the attached copy as receipt of data. SCH SCH D/A D/A Becky Benedi ct AFA - 403 Trans. #586 Note- Please see attached letter from Dresser/Atlas regarding the corrected tape on D.S. 14-9B. DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA · CHEVRON D~L~ LAS NOV 0 5 .','!~OZ Alask2 Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc.s~ Post Office I~ ,t60 Anchorage, Alaska 99510 Telephone 907 277 5637 October 25, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re: D.S. 13-9 - Permit No..81-158 D.S. 13-24 - Permit No. 82-65 D.S. 13-25 - Permit No. 82-91 D.S. 14-6 - Permit No. 78-65 D.S. 14-11 - Permit No. 80-131 D.S. 14-17 - Permit No. 81-21 D.S. 14'~i~- Permit No. 82-86'~ D.S. 13-21 - Permit No. 82-53 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS-TKKW'lmi Attachments cc- Sohio Petroleum Co. L, RE£EIVED NOV 0 21§82 Alaska 0ii & Gas C0ns~ C0mmJs~ic~ Anchora. ge ARCO Alaska, Inc. is a subsidiary of 'AtlanticRichfieldCompany ALASKA ~L AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 4. Location of Well 2715' FNL, 1562' FEL, Sec. · · 992' FSL, !221' FEL, Sec. 432' FSL, 1347' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) -- 7!' RKB 12. 99510 9, TION, R14E, UM (Surf) 16, TION, R14E, UM(Top Prod) 16, TION, R14E, UM(TD) I6. Lease Designation and Serial No. APL 283]4 7. Permit No. 82-86 8. APl Number 50- 029-20756 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-21 11. Field and Pool Prudhoe Bay Fi el d Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~]] Alter Casing [] 'Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to Perforate selected intervals within the Sadlerochit Sand below the oil-water contact for use as a water supply well in the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the.conclusion of the perforating and clean-up operation. Intended Perforation Intervals' 12464'-12624 12632'-12642 12648 '-12698 12714"-12764 12816'-12866 12894 '-12914 MDV Ref: BHCS 8-7:82 NOV 0 2 1982 A~ska 0~1 & Gas. Cons, CJ~m,~ Anchorage 14. I herebyj;~rtify that the foregoing is true and correct to the best of my knowledge. Signed _~~~~--~J/ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved .:2opY Date · Approved by. Form 10-403 ORIG'HAL "SIGNED' BY H~flR¥ W. KUGI. Eil Returned = By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1 ~80 and "Subsequent Reports" in Duplicate ARCO Alast(a, Inc' Post Office Box 360 Anchorage. "a 99510 Telephone 907~ . 7 5637 September 9, 1982 Reference: Arco Cased Hole Finals D-S. 6-19 8-8-82 CBL/VD D.S. 6-19 8-5-82' CBL/VD D.$_~ 8-11-82 D.S. 14-21 8-11-82 CBL/VD CCL-& Perf Record Run 3 5" Run 2 5" RUn 1 5" Run 1 5" Sch Sch Sch Sch /Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 458 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOaIO CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DALLA~ ARCO Alaska, Inc. ~' Post OfficeB~,, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 15, 1982 V Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Dear Mr. DS 14-21 Well Completion Report Chatterton- Enclosed are the well completion report and gyroscopic survey for DS 14-21. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG'sm Enclosures GRU1/L96 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ALASK .L AND GAS CONSERVATION C~*' MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-86 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20756 4. Location of well at surface LO(~ATIONS · 9. Unit or Lease Name 2715' FNL,1562' FEL, Sec. 9, T10N, R14E, UM VERIFIED Prudhoe Bay Unit At Top Producing Interval Surf. ~- [ 10. Well Number 992' FSL, 1221' FEL, Sec. 16, T10N, R14E, UM i B.H. ~~1 14-21 At Total Depth 11. Field and Pool 432' FSL, 1:347' FEL, Sec. 16, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKBI ADL 28:314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 07/18/82 08/07/82 08/23/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey ~ 20. Depth where SSSV set 21. Thickness of Permafrost 13060'MD,9641 'TVD 13018'MD, 9609'TVD YES ~ NO ~I 2194feet MD 1900' (approx) 22. Type Electric or Other Logs Run D IL/BHC/GR/SP, CDL/CNL/GR/Cal, GR/CNL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf 76' 30" 350 sx Permafrost II 13-3/8" 72.0~ L-80 Surf 2517' 1..7-1/2" 2500sx AS iii & 400 sx AS II 9-5/8" 47.0~ L-80& Surf 12036' 12-1/4" 500sx Class G & 300 sx A~ II S00-95 7" 29.0~ L-80 11762' 13060' 8-1/2" 400sx Class G 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) None 5-1/2" 11812 11735' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED N/A ., 2~A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested , PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST.PERIOD Flow Tubing Casing Pressure . CALCULATED~ OlL-BBL. GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,, GRU1/WC32 NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad]erochit 12197' 8997' 0/W Contact 12:~06' 9078 ' Base Sad]erochit Not Reached N/A 31. LIST OF ATTACHMENTS Drilling History~ G)~roscopic Survey (2 cbpies) 32. I hereby certify that the foregoing is true and correct to the best of my knoWledge Signed /~'~'"'~~" Title Area Dri]] ing Engineer)ate _ ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where nOt otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24:'Show the producing intervals for only the interval reported in item 27. Submit a separate 'form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DS 14-21 DRILLING HISTORY NU 20" .Hydril & diverter. Spudded well @ 1030 hr~"~' 07 Drld 17-1/2" hole to 2530'. Ran 64 jts 13-3/8" 72#/ft, L-80,~bT6-e~-g~w/shoe @ 2517'. Cmtd 13-3/8" csg w/2500 sx AS III & 400 sx AS II. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 12055'. Ran 287 jts 9-5/8" 47#/ft, L-80/SO0-95, BTC, csg w/shoe @ 12036'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new .form. Tstd form to 12.4 ppg EMW - ok. Drld 8-1/2" hole to 13060' TD (08/07/82). Ran DIL/BHC/GR/SP f/TD to 9-5/8" shoe. CDL/CNL/GR/Cal f/TD to 9-5/8" shoe, & GR/CNL f/9-5/8" shoe to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 52 bbls AS I, & 125 bbls Arctic Pack. Ran 40 jts 7" 29#/ft, L-80, BTC csg f/11762'-13060'. Cmtd 7" lnr w/400 sx Class G. Drld cmt to 13018' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Ran CBL. Make up isolation pkr & RIH on wireline. Set @ 12306'. Ran 5-1/2" completion assy w/tail @ 11812' & pkr @ 11735'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Set packer w/2500 psi. Tstd tbg to 2500 psi_~k. Nipple for SSSV @ 2194'. Secured well & released rig @ 1230 hr§"~'"'~13/82..~ Gyroscopic survey ra~?08/23/82 ........ JG:llm 09/01/82 GRU/DH38 ARCO ALAS~A~INC~ DS 14~ WELL NOI 21 GMS JO~ NOI AO882G0457 PRUDHOE ~AY~ NORTH SLOP£~ ALASKA GMS, 0-12950 MD, SURVEYORSI D F'EFFERKORN/D MILLER DATE RUN; 2~-AUG-82 CAMERA NO,~ !644, 1,572 ,5-90 DEGo A/U NO; 1,562 FORESIGHT1 S GYRO NO: 6~2 · VERTICAL SECTION CALCULATED IN PLANE OF PROPOSAL- DIRECTION; S 2 DEG¥ RECORD OF SURVEY RADIUS OF CURVATURE METHOD ~RCO ALASKA, INC. )S 14, WELL NO; 21 GMS :'RUDHOE BAY, NORTH SLOPE, ALASKA dOB NO; A088280457 ' COMF'UTATION TIME DATE 15142109 09-SEP-82 F'AGE NO · 1 TRUE IEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N 8 U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET · FEET D M DG/IOOFT O, 0 0 0 0 100, 0 15 S 7 0 E 200, 0 0 0 0 300, 0 0 0 0 400. 0 30 S 65 0 E O. 0.00 0.00 -71.00 0.00 100. 100.00 0.22 · 29.00 -. 0.22 S 100. 200.00 0.43 129.00 0.43 S 100. 300.00 0.43 229.00 0.43 S 100. 400.00 0.63 329.00 0.62 S 0.00 0.00 0 0 0.03 E 0.22 S 7 0 E 0.05 E 0.43 S 7 0 E 0.05 E 0.43 S 7 0 E 0.45 E 0.76 S 36 4 E 0.00 0.25 0.25 0.00 0.50 500. 600. 700. 800. 900. 0 0 0 0 0 30 S 64 0 E 0 15 N'56 0 E 0 30 S 48 0 E 0 15N39 0 E 100. 500.00 0.83 429.00 0.80 S 100. 600.00 1.04 529.00 0.99 S 100. 699.99 1.02 628.99 0.95 S 100. 799.99 1,08 728.99 0.99 S 100. 899.99 1.06 828.99 0.94 S 0.84 E 1.24 E 1.86 E 2.47 E 3.05 E 1,16 S 46 32 E 1,58 S 51 16 E 2.09 S 63 1E 2,66 S 68 8 E 3,20 S 72 49 E 0.50~ 0.50 0.43 0·50 0.57 1000. 0 0 0 0" 1100. 0 0 0 0 1200. 0 0 0 0 1300. O- 0 0 0 1400. 0 0 0 0 1500. 1600. 1700. 1800. 1900. 2000. 2100. 2200. 2300. 2400. 100. 999.99 0.89 928.99 0.78 S 3.19 E 100 1099 99 0.89 ~J~: 1.028.99 i;~? 0,78 19 E 100. 1199.99 ..... ~ 0,89 i128;99 "0', 78 3.19 E 100. 1299.99 10,89' i!~,1228,99 0,78':S 3.19 E 100 1399.99 0.89~ 1328 ?i: ~0,78 S ~i'~i::. 3.19 E · ",: · .:. d~c.: 3.28 S 76 20 E 3.28 S 76 20 E 3.28 S 76 20 E 3.28 S 76 20 E 3.28 S 76 2O E 0 45 N 19 0 W 100. 1499.99 0.27 1428.99 0.16 S 2.98 E 2.98 S 86 59 E 0 45 N 51 0 'W 100, 1599,98 -0,82 1528,98 0,90 N 2,23 E 2,41 N 68 2 E 0 15 N 34 0 E 100. 1699.97 -1.61 1628.97 1.69 N 2.12 E 2.71 N 51 26 E 0 15 S 50 0 E 100. 1799.97 -1.65 1728.97 1.74 N 2.50 E 3.05 N 55 9 E 0 15 N 54 0 E 100. 1899.97 -1.62. ,1828.97 ~. 1.73.N 2.91E 3,38 N 59 16 E 0 30 S 64 0 E I 45 S 38 0 E 2 0 S 26 0 E 2 45 S 19 0 E 2 45 S 15 0 E 100. 1999.97 100. 2099.95 100. 2199.89 100, 2299,81 100. 2399.69 -1,65 1928,97 1,78 N -0,37 2028,95 0,56 N 2,46 2128,89 2.21 S 6.34 2228.81 6.04 S 10,98 2328,69 10.63 S 3.53 E 5.04 E 6.77 E 8.36 E 9.76 E 3,95 N 63 12 E 5,07 N 83 41E 7.12 S 71 53 E 10,31 S 54 8 E 14.43 .S 42 34 E 0.25 0.00 0.00 0.00 0.00 0.75 0,41 0,77 0.37 0.31 0.44 1.32 0.46 0.80 0.19 2500· 3 15 S 15 0 E 2600. 4 45 S 21 0 E 2700. 7 0 S 24 0 E 2800. 8 45 S 20 0 E 2?00, 12 45 S 10 0 E 100. 2499.55 100. 2599.31 100. 2898.78 100. 2797.83 100. 2896,05 16.08 2428,55 15,68 S 11.11 E '22.79 2528,51. 22,31S 13,27 E 32.38 2627.78 31.77 S 17,18 E 45.26 2726,83 44.47 S 22,32 E 63.42 2825.05 , 62.46 S 27,14 E 19.22 S 35 19 E 25.96 S 30 44 E 36.12 S 28 25 E 49.75 S 26 39 E 68.10 S 23 29 E 0.50 1.56 2.27 1,83 4,40 iRCO ALASKA, INC. 14, WELL NO1 21 GMS :'RUDHOE BAY, NORTH SLOPE, ALASKA JOB NO~ AO882G0457 COMPUTATION TIME DATE 15142109 09-SEF'-82 'PAGE'NO° 2 TRUE -. tEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG I)EPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET ~ FEET - · FEET FEET D M DG/100FT 3000, 14 45 S 10 0 E 3100, 16 30 S 6 0 E 3200. 18 30 S 5 0 E 3300. 19 45 S 4 0 E 3400, 21 30 S 4 0 E 100, 2993.18 86,96 2922,18 85,87 S 31,26 E 100, 3089,48 113,75- 3018,48 112.53 S 35,01E 100, 3184.85 143,76 3113,85 142,46 S 37.89 E 100, 3279,33 176,50 3208,33 175,12 S 40.46 E 100, 3372,92 211,70 3301,92 210,26 S- 42.92 E 91,38 S 20 0 E 117,85 S 17 17 E 147,42 S 14 54 E 179.74 S 13 I E 214,60 S 11 32 E 2,00 2.05 2.02 1,29 1,75 3500, 23 30 S 4 0 E 3600, 26 15 S 4 '0 E 5700, 28 15 S 6 0 E 3800. 30 0 S 6 0 E 3900. 33 0 S 6 0 E 100, 3465.30 249,95 3394,30 248.43 S 45,59 E 252,58 S 10 24 E 2,00~ 100, 3556.01 291,99 ~ 3485,01 290.39 S ~. 48,52 E 294,42 S 9~ 29 E 2.75 100. 3644,91' 337,71 3573,91 336,00 S 52,51 E 340,08 S 8 53 E '2,20 100, 3732,26 386.27 3661,26 584,40 S 57.60 E 388,69 S 8 31 E 1,75 100. 3817,52 438,39 -~3746,52 -~436,36 S 63,06 E 440,89 S 8 13 E 3,00 4000. 36 0 S 7 0 E 4100, 39- 0 S 6 0 E 4200. 42 45 S 7 0 E 4300. 45 45 S 8 0 E 4400, 49 0 S 8 0 E 4500, 52 0 S 8 0 E 4600, 52 30 S 9 0 E 4700. 52 45 S 8 0 E 4800, 53 15 S 9 0 E 4900. 52 45 S 8 0 E 5000, 53 0 S 8 0 E 5100, 53 15 S 8 0 E 5200. 53 0 S 7 0 E 5300. 53 0 S 8 0 E 5400. 52 30 S 8 0 E 100,1 5899,92 494,86 3828,92.~, 492,63 S 69,47 E 497,51 S 8 2 E 100'4054,85 398Z;:85~ E 623,77 S 7 43 E 690i25 !, :5 687.29 ' i92.8m £ 693:.54 s 7 [ 100. 4257.78 840.18 4186,78 8~6,55 S 11~,85 E 844,26 S 7 45 E 100~ 4~19,00 918~76 4248,00 914.74 S 125~54 E 92~52 S 7 49 E 100. 4~79.71 997~7~ 4~08,71 995,~4 S 1~7.29 E 1002.78 S 7 52 E 100~ 44~9,89 1077~10 4568,89 1072~5~ S 149~09 E 1082.64 S 7 55 E 100. 4500.07 1156.47 ~4429.07 1151~51 S 160.90 E 1162,50 S 7 57 E 100, 4560,42 1235,78 4489,42 1230,27 S 171,99 E 1242,23 S 7 58 E 100, 4820,43 1315.35 4549,43 1309,48 S 183,13 E 1322,23 S 7 58 E 100, 4680,44 1394.99 4609,44 1388.79 S 193.57 E 1402.21 S 7 56 E 100, 4740,62 1474,50 4669,62 1467,97 S 203,99 E 1482,07 S 7 55 E 100. 4801,15 1553,69 4730,15 1546,80 S 215'07 E 1561,68 S 7 55 E 3,05 3,06 3,81 3.08 3,25 3,00 0,94 0.83 0.94 0.94 0.25 0,25 0,84 0,80 0,50 5500, 52 45 S 8 0 E 5600, 52 45 S 6 0 E 5700, 52 15 S 7 0 E 5800. 52 30 S 6 0 E 5900o 51 50 S 7 0 E 100, 4861,85 1632,74 4790,85 1625,49 S 226,13 E 1641,15 S 7 55 E 100o 4922,38 1712,04 4851.38 1704,50 S 235,8~ E 1720,73 S 7 53 E 100. 4983,26 1791,15 4912.26 1783,32 S 244.81 E 1800,05 S 7 49 E 100. 5044.31 1870.11 4973.31 1862.01 S 253.78 E 1879,23 S 7 46 E 100, 5105,87 1948,68 5034,87 1940,50 S 282,70 E 1958,01 $ 7 45 E 0.25 1.59 0.94 0.83 1.27 ~RCO ALASKA, INC. OS 14, WELL NO: 21 GMS F'RUDHOE BAY, NORTH SLOPE, ALASKA JOB NO: AO882G0457 COMPUTATION TIME [mATE 4~.09 09-SEP-82 'F'AGE'NO. ~ TRUE - .. ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOFT 6000. 52 45 S 7 0 E 6100. 53 0 S 7 0 E 6200. 53 15 S 7 0 E 6300. 52 45 S 7 0 E 6400, 53 0 S 7 0 E 100. 5167,27 2027,33 5096.27 2018,65 S 272,32 E 2036,93 S 7 41E 100, 5227,62 2106,78 5156,62 2097,79 S 282.03 E 2116,66 S 7 39 E 100, 5287.63 2186,48 5216,63 2177,19 S 291.78 E 2196.65 S 7 38 E 100, 5347.81 2266,05 5276,81 2256.45 S 30!.52 E 2276,51 S 7 37 E 100, 5408,17 2345,50 5337,17 2335,60 S ~.~311.23 E 2356,24 S 7 35 E 1,25 0,25 0.25 0,50 0,25 6500, 53 0 S 7 0 E 6600, 53 0 S 7 0 E 6700, 53 15 S 6 0 E 6800. 52 45 S 7 0 E 6900, 52 45 S 4 0 E 100, 5468,35 2425.07 5397,35 2414,87 S 320,97 E 2436,10 S 7 34 E 100, 5528,53 2504,.65 5457,53 2494,13 S -. 330,70 E 2515,96 S 7 33 E 100, 5588,54 2584,40 5517.54 2573,61S 339.75 E 2595,94 S 7 31E 100, 5648,72 2664,03 5577,72 2652,96 S 348,79 E 2675,79 S 7 29 E 100. 5709.25 2743.48 5638.25 2732o18 S 356,42 E 2755,34 S 7 26 E 0,00 0,84 0,94 2.39 7000. 52 15 S 4 0 E 7100. 52 15 S 4 0 E 7200. 52 45 S 3 0 E 7300, 52 30 S 4 0 E 7400. 52 45 S 3 0 E 7500, 52 15 S 4 0 E 7600J 52 0 S 3 0 E 7700, ~51 45 S 3 0 E 7800, 52 0 S 4 0 E 7900. 51 45 S 4 0 E 8000. 50 45 S 4 0 E 8100. 51 30 S 4 0 E 8200. 50 15 S 4 0 E 8300, 50 30 S 5 0 E 8400. 51 0 S 5 0 E 100, 5770,12 2822,78 5699,1 2811,33 S 361,96 E 2834,53 S 7 20 E 100. 5831.35'"2901080 ~5760,35 2890,20 S 367,47 E 2913,47 S 7 15 E 100, 5892,o~_ 2981,11 ~ ~,~~°~ ~ 2969'39 S 372,32 E 2992,64 S 7 9 E 100. 5952,92 3060,56~C5881,92.~.!;;3048071S 377,17 E 3071,95 S 7 3 E 100. 6013.63 314°~01.~! 5942,63'.~3128~03 s ,382.02 E 3151.27 S 6 58 E 100, 6074,50 3219,32 6003.50 3207,22 S 386,86 E 3230.47 S 6 53 E 100, 6135,90 3298,23 .6064,90 3286.01S 391,68 E 3309.27 S 6 48 E 100. 6197.64 3376.88 6126.64 3364.56 S 395.80 E 3387.76 S 6 43 E 100, 6259,37.' 3455,52 6188,37 3443.08 S 400,60 E 3466,30 S 6 38 E 100. 6321,11 3534,15 6250,11 -3521.55 S 406,09 E 3544,89 S 6 35 E 100, 6383.70 3612,09 6312,70 3599.35 S 100, 6446.47 3689,90 6375,47 3677,01 S 100, 6509.57 3767,44 6438,57 3754.40 S 100, 6573,34 3844,39 6502,34 3831,19 S 100. 6636.61 3921,74 6565.61 3908.33 S 411,53 E 3622,80 S 6 31 E 416.96 E 3700.58 S 6 28 E 422,37 E 3778,08 S 6 25 E 428.41 E 3855,06 S 6 23 E 435.16 E 3932.48 S 6 21E 0.50 0.00 0.94 0.83 0.83 0.94 0,83 0.25 0.83 0,25 1,00 0,75 1.25 0.81 0.50 8500, 51 45 S 4 0 E 8600. 52 15 S 4 0 E 8700, 52 30 S 4 0 E 8800, 53 0 S 3 0 E 8900, 53 45 S 2 0 E 100. 6699.03 3999.79 6628.03 3986.21 S 441.29 E 4010.56 S 6 19 E 100, 6760,60 4078,55 6689,60 4064,82 S 446.79 E 4089,30 S 6 16 E 100, 6821.65 4157,71 6750.65 4143,83 S 452,31 E 4168.44 S 6 14 E 100, 6882,18 4237,29 6811,18 4223.28 S 457.17 E 4247.95 S 6 11 E 100o 6941,84 4317,54 6870,84 4303,46 S 460,68 E 4328,04 S 6 7 E 1.08' 0,50 0.25 0.94 1,10 4RCO ALASKA, INCo DS 14, WELL NO; 21 GHS ?RUDHOE BAY, NORTH SLOPE, ALASKA JOB NO;' AO882G0457 COHPUTATION TINE DATE 15142109 09-SEP-82 F'AGE NO. ~' TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET - FEET FEET D M DG/IOOFT 9000. 54 0 S 2 0 E 9100. 54 30 S 2 0 E 9200, 55 0 S 2 0 E 9300, 55 30 S 2 0 E 9400, 55 30 S 2 0 E 100, 7000,79 4398,31 6?29,79 4384,18 S 465.49 E 4408,62 S 6 2 E 100, 7059.22 4479.47 6988.22 4465,29 S 466.33 E 4489.58 S 5 58 E 100, 7116.93 4561.13 7045.93 4546.90 S 469.18 E 4571.05 S 5 53 E 100, 7173.93 4643.30 7102.93 4629.02 S ,472.04 E 4653.03 S 5 49 E 100, 7230.57 4725,71 , 7159,57, -4711.38 S 474,92 E 4735,26 S 5 45 E 0,25 0,50 0,50 0.50 0,00 9500, 55 45 S 2 0 E 9600, 56 0 S 3 0 E 9700, 55 30 S 2 0 E ?800. 55 15 S 4 0 E 9900, 55 0 S 4 0 E 100. 7287.03 4808.25 7216.03 47?3.87 S 477.80 E 4817.62 S 5 42 E 100. 7343.13 4891.02 . 7272.13 4876.57 S 481.41 E 4900.28 S 5 38 E 100, 7399.41 4973.68 7328.41 4959,15 S 485,02 E 4982.81 S 5 35 E 100. 7456,23 5055.95 7385,23 5041.32 S 489.32 E 5065.01 S 5 33 E 100. 7513,41 5137.95 7442.41 '5123.17 S 495,05 E/ 5147,03 S 5 31 E 0.25~'~ 0.86 0,97 1,68 0,25 ::10000, 53 45 S 4 0 E 10100, 54 0 S 4 0 E 10200, 54 15 S 4 0 E 10300. 53 15 S 2 0 E 10400, 52 45 S 2 0 E !910500. 53 0 S 2 0 E 10600. 53 0 S 2 0 E 10700, 52 30 S I 0 W 10800, 52 15 S 4 0 W '~10900. 52 0 S 6 0 W 11000, 50 45 S 7 0 W 11100. 50 0 S 8 0 W 11200. 4? 15 S 11 0 W 11300, 48 45 S 11 0 W ~11400, 48 45 S 11 0 W 100, 7571,66 5219,19' 7500.66 5204,25 S 100. 7630.61 5299.93 ~97559.61 :i~5284,.83 S 100, 7689,21 5380o91~ 7618,'21 5365,66 S _ 100, 7748,34 54&1,54 ~ 7677,34 ~5446,19.S 100. i 7808.52 5541',40 7737°52-::!!5526.00 S 100. 7868.88 5621.14 7797'.88 5605,69 S 100. 7929.06 5701,00 7858,06 5685,51 S 100. 7989,59 5780.56 7918.59 5765.10 S 100. 8050.64 5859,50 7979.64 5844.21 S 100. 8112,03 5937.82 8041,03 5922,85 S 100, 8174,45 6015,06 8103,45 6000,46 S 100. 8238,23 6091,00 8167.23 6076,83 S 100, 8303,01 6165.62 8232,01 6151,96 S 100, 8368,61 6239.12 8297.61 6226.04 S 100, 8434.55 6312,34 8363,55 6299,84 S 500,72 E 5228,28 S 5 30 E 506.35 E 5309,03 S 5 28 E 512,00 E 5390.03 S 5 27 E 516.22 E 5470.60 S 5 25 E 519,01E 5550,32 S 5 22 E 521.79 E 5629,92 S 5 19 E 524.58 E 5709.66 S 5 16 E 525,28 E 5788,98 S 5 12 E 521,82 E 5867,46 S 5 6 E 514.94' E 5945,19 S 4 58 E 506,10 E 6021,77 S 4 49 E 496.05 E 6097,04 S 4 40 E 483.47 E 6170,92 S 4 30 E 469.07 E 6243.68 S 4 19 E 454.73 E 6316.23 S 4 8 E 1.25 0.25 0.25 1.90 0,50 0.25 0,00 2,44 2,39 1.60 1.47 1.08 2.41 0,50 0,00 11500. 47 30 S 11 0 W 11600. 46 45 S 11 0 W 11700. 46 0 S 11 0 W 11800, 45 0 S 12 0 W .'11900, 44 15 S 11 0 W 100, 8501,30 6384,86 8430,50 6372,93 S 100, 8569,34 6456,23 8498,34 6444,87 S 100, 8638.33 6526,72 8567.33 6515.93 S 100. 8708,42 6596.04 8637.42 6585.82 S 100o 8779,59 6664o31 8708.59 6654,65 S 440.52 E 6388,14 S 3 57 E 426,54 E 6458,97 S 3 47 E 412,73 E 6528,99 S 3 37 E 398.51E 6597.86 S 3 28 E 384°50 E 6665°75 S 3 18 E 1.25 0.75 0.75 1.23 1o03 ~RCO ALASKA, INC. DS 14, WELL N05 31 GMS :'RUDHOE BAY, NORTtt SLOPE, ALASKA JOB NOI AOB82G0457 · COMF'UTATION TIME DATE 15542509 09-SEF'-82 'PAGE°NO. 5- TRUE · tEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOFT 12000, 44 15 S 11 0 W 12100. 42 0 S 13 0 W ~i~12200. 41 15 S 15 0 W 12300, 41 45 S 15 0 W 12400, 42 0 S 14 0 W 100, 8851,22 6732,27 8780,22 6723,15 S 371,19 E 6733,39 S 3 10 E 100, 8924,20 6798.56 8853,20 6790.01S 356.97 E 6799,39 S 3 i E 100. 8998,95 6862,57 8927,95 6854,46 S 340,91 E 6862,93 S 2 51 E 100. 9073.85 6925.70 9002.85 6918.46 S 323.76 E 6926.03 S 2 41 E 100. 9148.31 6989.66 9077. o31 6983.08 S 307.04 E 6989.83 S 2 31 E 0.00 2.63 1.53 0.50 0.71 12500. 41 45 S 13 0 W 12600, 42 45 S 12 0 W .12700. 41 45 S 12 0 W 12800. 41 45 S 12 0 W 12900, 41 15 S 12 0 W 12950, 41 15 S 11 0 W F'ROJECTED TO 13018 MD. ~13018. 41 15 S 11 0 W PROJECTED TO T[~, 100. 9222.77 7053.95 9151.77 7047.99 S 291.46 E 7054.01 S 2 22 E 100. 9296.79 7119,00 9225.79 7113.63 S 276.91 E 7119.02 S 2 14 E 100, 9370,81 7184,21 9299.81 7179,40 S 262,93 E 7184,21 S 2 6 E 100, 9445,42 7248,79 9374,42 7244,53 S 249,09 E 7248,81 S 1 58 E 100, 9520,31. 7313,05 .9449,31 .7309,34 S 235,31 E 7313,13 S 1 51 E 50, 955.7.90 7345,09 6,90 7341,65 S ~ S I 47 E ~8,74 E 7345,21 68. 9609.03 7388.7 ,.~' 9538,03- !~'7385.66~ S . ~.., ~ .. .~ : ;.' 220.18 E 7388.94 S I 42 E 0.71~ 1.20 1.00 0.00 0.50 1.32 0,00 13060. 41 15 S 11 0 W 42. 9640.61 7415.72 9569.61 7412.84 S 214.90 E 7415.96 S I 40 E 0.00 FINAL CLOSURE - DIRECTION: DISTANCE5 S 1DEGS 39 MINS 38 SECS E 7415,96 FEET ARCO ALASKA,' INCo IlS 14, WELL NOI 21 GMS JOB NOI AO882G0457 PRU[IHOE BAY, NORTH SLOPE, ALASKA GMS, 0-12950 H[I, SURVEYORS: D PEFFERKORN/D HILLER [lATE RUN: 23-AUG-82 CAHERA NO: 1644,~ 1572 GYRO NO~ 632 5-90 DEGo A/U NO~ 1562 FORESIGHT°' S 6 W '~.. :. RECOR[,.OF"INT£R?OLA. T£[~ SURg~EY' ~RCO ALASKA, INC, :~S' 14, WELL NO: 21 GMS ~RUDHOE BAY, NORTH SLOPE, ALASKA JOB COMPUTATION TIME DATE 15:48:49 09-SEP-82 PAGE NO, MARKER ....... CODE NAME TRUE SUBSEA MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL DEF'TH DEPTH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOP SAG RIVER TOP SHUBLIK A TOP SHUBLIK B TOP SHUBLIK C TOP SADLEROCHIT- 12091.00 8917,63 3173.4 8846,63 6783,99 S 358.25 E 6793,44 S 3 1 E 12112.00 8933,1.7 3178,8 8862.17 6797.74 S 355.05 E 6807,01 S 2 59 E 12131.00 8947,38 3183,6 8876.38 6809.99 S 351,99 E 6819,08 S 2 58 E 12153.00 8963,82 3189,2 8892,82 6824,17 S 348,46 E 6833,06 S 2 55 E 12197,00 8996o71 3200.3 8925.71 6852,52 S 341,39 E 6861.02 S 2 51 E HOT O/W CONTACT TOP ZONE 3 TOP ZONE 2 TOP ZONE lB 12263.00 9046,14 3216o9 8975,14 6894.78 S 330,10 E 12306.00 9078.31 3227.7 9007.31 6922°34 S 322o75-E 12514.00 9233,13 3280,9 9162,13 7057.18 S 289.42 E 12633,00 9321.22 3311,8 9250,22 7135.33 S 272,30 E 12926,00 9539,86 3386,1 9468.86 ~7326.14 S 231.89 E 6902,68 S 2 44 E 6929°86 S 2 40 E 7063.11 S 2 21E 7140,53 S 2 11E 7329,81 S I 49 E PBTD TD 13018,00 9609,03 3409,0 9538~03 7385.66 S 220.18 E 13060.00 9640 61 3419~4~ 9~69o61 ~7 !~o84.S 214,90 E 7388,94 S 1 42 E 7415,96 S 1 40 E ' ' ~ ~ I i , , ~ , , . iii ! Eastman Whipstock A PETROLANE COM~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY DS 14, Well Number: 21 WELL NAME Prudhoe Bayw North Slopew Alaska LOCATION JOB NUMBER A0682D0317 SURVEY BY B Magos TYPE OF SURVEY Directional Single Shot R E C E I'V E D AUG 2 6 1~82 A!a~a 0]1 & Gas Cons. Commission Anchorage OFFICE Alaska DATE 09-Aug-82 Eastman Whi pst oc=_k (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 August 11, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99510 Well Nm~e.r= DS 14-21 Location= Prudhoe Bay, North Slope, Alaska Type of Survey= Directional Single Shot Date= 09-Aug-82 Method of Computation= Radius of Curvature Surveyor= B Magos Job Number= A0682D0317 Attn= Bob Hines Dear Mr. Hines, We are enclosing the origina/and one copy of the Directional Single Shot survey .run on the above mentionedwell. To date, the following diStribut_ion has been accomplished: 'A;"0 copies telecopied to E/WNorth Slope office for delivery toARCO field representives. B;''I copy delivered to drilling for in-house distribution. . , C;''3.. copies for E/Wpermanent well files. We wish to take thsi opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, i District Operations Manager cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentais/Sa~es/Worldwide ARCO ALASKA~ INC· [iS 14, WELL NO: 21 DSS F'RUDHOE BAY, NORTH SLOF'E, ALASKA ' [ISS, 0-13000 MD, DRILLER: BOB MAGOS JOB NOI AO&82D0317 RIG: PARKER 191 DECLINATION; 30 1/2 DEG EAST FILE IS SINGLE SHOT/TELECO CORRECTED DATA Whipstock A PETROLANE C, OMPANY RECORD DF SURVEY RADIUS OF CURVATURE METHOD ARCO ALASKA, INC. F'RUDHOE DAY, NORTH SLOPE, ALASKA · . COHF'UTATION PAGE NO, ' '~ 1 _J.O~__J~O; AO682D0317 TT_I~E .. r!ATE ..... ,- 10: 35: 48 11-AUG-82 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A'R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TUG C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY · FEET .........l;k. F! .... D M ..... F_E_E__T E~ET FEET FEET FEET . FEET [' M . .DG/!OOFT O. 0 0 0 0 O. 0o00 __2 o ~ o~.24 2323,o 2478. 2 30 S.14 30 E 154, 2477,12 2571. 3 30 S 18 0 E 93. 2569,99 2664. 4 45 S 24 0 E 93. 2662.74 0,00 -71,00 0,00 49,41 2252,26 48,9'6 S 55,77 2406,12 55,46 S 60,69' , 2498,99 60.13 S 67.01 .~591.74.. .6..6,,,37 S 0,00 13,12 E 14,83 E 16,19 E 18,57 E 0,00 0 0 0,00 50,69 S 1,.5.'0 E 0011 57,41 S 14 58 E 0,01 62,27 S 15' 4 E 1,07 68 · 9'3 S 15 39' E I 2756. 7 0 S 25 0 E 72. 2754,26 2940, 12 30 S ? 30 E 91. 2935,92 3031. 14 30 S 10 0 E 91, 3024.40 .__3110, ..... ltJ5 S 9 0 E .. Iii. 3139.00 3307. 19 0 S 5 30 E 3396, 21 0 S 5 30 E 3520. 23 0 S 7 0 E 3644. 26 15 S 6 30 E 3796. 29 30 S 8 0 E 3952. 33 30 S 9 0 E 4105, 38 0 S 9 30 E. 153, 3991.18 75.72 2683,26 74,94 S 22,49 E 78,24 S 16 42 E 2,'""~,~ 87,09 2775.43 86.13 S 27,71 E.. 90.47 S 17 50 E 1,~. 102,86 2864,92 101.73 S 32.55 E 106,81 S 17 45 E 5.55 o.~ 66 S 36,15 E 127,88 S 16 25 E 2,20 123,91 2953,40 1-.:.~, 155,70 3068.00 ..154.27 S · .41,44 E 159,74 S 15 2 E ..1,?0 157~l~l~288,41Ll~_..~,~red~~7,~4~ 202,06 S 47,52 E 87~B;372,04/r~,~..~r-~-~~j~r.~ 2.~m~m~m~i~; 44 E i5~. 3e~7,04 483,~4 3Z~~eOa~~~N~ 82,58 Z 572.32 3920,18 569.13 S 96.94 E 207,58 S 13 14 E 237,77 S 12 15 E 284,01 S 11 16 E 335,53 S 10 34 E 406,49 S 10 0 E 1,59 2,25 1,68 2,63 2,19 487,96 S 9 45 E 577,32 S 9 40 E 2.59 2,95 . 4259, 43 30 S 11 0 E 4414, 48 30 S 10 0 E _~ 4505, .51 15 S 10 0 E 154, 4107,80 155, 4215.44 91, 4274.08 671,79 4036,80 782.06 4144,44 850.98 4203,08 668.01 S 114,82 E 777,60 S 135,14 E 846,12 S 147,22 E 677,80 S 9 45 E 787.26 S 9 52 E 858,83 S 9 52 E 3,63 3,26 5 . 3. 4625. 53 15 S 8 0 E 5084; 53 15 S 8 30 E 120. 4347.54 945.17 4276,54 739,82 S 459. 46~.~° 17 1310,83 4551,17. 1303.79. S 5550. 53 0 S 7 30 E 5887. 52 30 S 7 0 E 6260, 53 15 S 6 0 E 466, 4901,81 1681,62 4830,81 1672,92 S 337. 5105.79 1948,81 5034.79 1739,03 S 373. 5330,92 2245.34 5257,92 2234,52 S 162,06 E 953,69 S ? 47 E 214,83 E 1321,37 S 9 21 E 266,71E 1694,04 S 9 3 E 300,56 E 1962,19 S 8 49 E 334.23 E 2259,38 S 8 30 E 2,12 0,09 0,18 0,19 0,29 6828. 53 15 S 4 0 E 6953. 53 0 S 4 0 E 7348. 53 0 S 4 0 E 7887. 52 0 S 5 30 E 8135, 50 30 S 5 0 E 568. 5670.77 '2677.85 5599.77 2687.88 S 373.89 E 2713,76 S 7 55 E 0,28 125. 5745,77 2799.79 5674,77 2787,62 S 380.87 E 2813.52 S 7 47 E 0.20 395, 5983,49 3115,08 5912,49 3102,31 ~ ...... 4~2;87 EI 3128'",3&'" S''7 2~"E" 0;00 539. 6311.61 3542.23 6240.61 3528,45 S 438,28 E 3555,57 S 7 5 E 0,29 248, 6466,83 3735,35 63?5,83 3721,04 S 455,?8 E 3748,88 S 6 59 E . 0,62 ARCO ALASKA, INC. DS 14, WELL NO; '21 DSS , . , COMPUTATION JOB NO; AO682D0317 TIME DATE' P~GE ND. '~ 2 PRUDHOE BAY, NORTH SLOPE, ALASKA TRUE 10;35148 11-AUG-82 HEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DO L E " DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD FEET D M D M FEET FEET FEET FEET C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET FEET D M DG/IOOFT 8375. 50 30 S 5 0 E 8756. 52 30 S 5 0 E 240. 6619.49 3920,30 6548,49 3905,53 S 381. 6856.66 4218,08 ' 6785,66 4202,55 S 472,12 E 3933,96 S 6 54 E 498,10 E 4231,97 S 6 46 E 0,00 0,52 9164. 54 45 S 4 0 E 9349. 55 30 S 3 0 E 9668, 55 30 S 3 30 E 408. 7098,61 4546,27 7027,61 4530,01 S 185, 7204,40 4698,00 7133,40 4681,50 S 319, 7385°08 4960,85 7314,08 4943,98 S 523,88 E 4560.,21 S 6 36 E 533o14 E 4711,76 S 6 30 E 548,05 E 4974,26 S 6 20 E 0,59 0.60 0.13 9951. 54 30 S 3 0 E 10140. 54 0 S 3 0 E 2~3o 7547.40 5192,62 7476,40 5175,42 S 189, 7657.82 5345.98 7586,82 5328,60 S 561.19 E 5205,76 S 6 11 E 569.22 E 5358.91 S 6 6 E 10385. 10644, 10861. 53 OS I OE 52 4'5 S 0 30 W 52 0 S 5 30 W 245, 259. 217. 7803,55 5542,91 7732,55 5525,41 7959,87 5749,32 7888,87 5731,92 8092.35 5920,45 8021,35 5903,49 576.09 E 5555,36 S 5 57 E 576,99 E 5760,88 S 5 45 E 568.00 E 5930,76 S 5 30 E 0,77 0.47 1.86 11061. 50 30 S 9 30 W 11302. 49 0 S 12 0 W 11552. 11799. 12005. 47 30 S 12 30 W 45 30 S 13 30 W 44 0 S 14 0 W 13000. 41 30 S 15 30 W 547,65 E 6082,80 S 5 10 E 6259,88 S 4 42 E 6438,50 S 4 13 E 6609.84 S 3 46 E 6748,29 S 3 23 E 1.73 1.01 0,62 0.86 0.75 7393,04 S 1 46 E 0,27 FINAL CLOSURE - DIRECTION; DISTANCE; S I DEOS 45 MINS 36 SECS E 7393.04 FEET t DRIFT CHART'S RELATED DATA FILE ARCO AI. ASNA, INC. DS 14~_~ WELL,NO; 2I ,[!SS F'RUDHOE BAY, NORTH SLOPE, ALASKA JOB NO;...AO682D0317 ",. SURVEY FILE NUMBER 317 BOTTOM HOLE ASSEMBLY VALUES USED FOR DEPTH ARE MD DEPTH DESCRIPTION 0.00 2530°00 4555.00 8~0.00 94J7.00 10078.00 11121.00 12055.00 ~.~.~.o.~,,= .~ Eastman ANGLE B~I~D AS~' Y m ~~ ~,~o~ ~~ Whtpstock ANGLE DROP ASSE ANGLE DROP ASSEMBLY A~TRO~NE~NY PACKED HOLE ASSEHBLY DRILLING DAYS VALUES USE[m FOR [mEF'TH ARE MTJ DAY lIEF'TH 2378.00 2530 3694 .00 ,00 ,00 5 6 7 4960 5972 7038 o00 o00 ,00 7493 8535 9360 .00 , O0 , O0 9566 0078 0320 .00 o00 o00 1 0751 1121 1895 .00 o00 o00 17 18 19 2055 2055 2607 ,00 ,00 o00 Eastman Whtpstock A PETROLAIVE COMPANY 20 13000.00 WEIGHT ON BIT WEIGHT IS GIVEN PER 1000 POUNDS VALUES USE[I FOR DEPTH ARE HD DEF'TH WEIGHT 0,00 70°00 2530 4555 8220 .00 .00 .00 70,00 65,00 65,00 9437 i0078 j1121 ,00 ,00 .00 65,00 70.00 70.00 12055,00 50,00 REVOLUTIONS PER MINUTE VALUE~E[! FOR DEF'TH .(k~l~ MF,! 2,530.00 4555.00 8220.00 140.00 100.00 100.00 94J7.00 10078.00 _11~.2!_,90 100.00 100.00 100.00 ].2055.00 100.00 Eastman Whtpstocl~ A PETROLANE COM~NY DC. 12V4' 5.33 DEPTH ~0" ~ .~'~.~,fI DATE "/-20- ~'Z Purpose of Assy.~o A~u~ SURVEYS FOR THIS ASSY. DRILLWITH ' WEIGHT ........ ~:;:~/70 RPM-. /,f'O PUMP /,~00 ~,,r ," s' ~%. Bit typ~_~ (./-Z4 ~.~) & Knozzle Size Hours on Bit · - DEPTH DATE Purpose of Ass),. SURVEYS FOR THIS ASSY. 2324' - S~/$~ - 2~° · 2,f75" - ~,s~ -z~° DRILLWITH · RPM 14o PUMP git Bit type ~_e & Knozzle Size Hours on 5.4,/ -- · zg.H DEPTH 4~$' '7'~ ~'Z'~..O' _ DATE 7-23 -~';.. Well ~ Os /~-~1 . Purpose of Assy. ;/.,D ~ ?;~c,,.~ SURVEYS FOR THIS ASSY. , DRILLWITH ' WEIGHT ~D / ~ · RPr~ PUMP Bit typ~-9 & Knozzle Si~- ~'~ Hours on w 48¥ ii i · · · · . . · · · · · .DC DATE "/- ,,~ 9" g2 E~3~s'- ~o~e - S~ 9/r,,4' - s~ ~ - $4~ · DRILLWITH RPM LOo PUMP ~J~O0 & Knozzle $izc- Hours on - e 1,00 .6,10 u 8'"' Purpose of Assy.CD~.~ t}, ~.B~ SURVEYS FOR THIS ASSY. DRILI. WITH ' WE,~.~. PUMP & Knozzl~-~izc' Hours on 27.~Z ~q ~0.(~ DEPTH Purpose of Assy.~)llo~ ~ ~ ~14 T_~,__~ SURVEYS FOR THIS ASSY ,, · DRILLWITH RPM _ /00 PUMP ' ~'.%"'~C~ Bit type & Knozzle Size Hours on Bit- · Z~.,4o C)~. x~ gTAB 8" Z~.?~ PC ~.gz $"~ STAB L DEPTH DATE we~-~ ~ D~ 14-z/ · Purpose of Assy.~~ ~~ w7 SURVEYS FOR THIS ASSY. /Z~o$' - ~40 - $14 ~ DRILLWITH RPM /00 PUMP, ' ;~ F"z.~) . Bit type & Knozzle Size Hours on Bi~ ?:69 7.7o -- JLL 3'.97 DATE _ ,, 8°'~'° 8'2' We1*1 ~ DS 14-~! :Purpose of ~ssy.~/~_~__~ ¢~ %. ~s~ SURVEYS FOR THIS,Ass, Y-_ DRILLWITH RPM _ ,, PUMP _ Bit typ~ & Knozzle Size Hours on · '" i ! 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';' .... fl ..... .........................~' t i ....... --.--~ ..... ~ .... ~---.- .............. ? ..........................Jr-- T ..... ~._-._ ' :--_ :..L:-_: :. : I ........... ..... --~-~ ................... t ...... ~:. ............... _ ............. -l-- .......... '-f-- ............................... 'I' ....................... r ': : :: :'::: :' :'~ :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::'F~:::: :'--::' :::'-":,::::.:_'..:. '.:_'::i_:.:----:::'----::i 1---:-: ! ~' ~ ' [! ~ ............. r .............. ..... "~ '~ ..... ~:' -'~ ........ :'::~ ~!'~::!i"i'-'L i":.- :-'i~?.L_'-.-~:! ! :.:iS..--:-i I- :.: :': ..i":':.':-~::-: :' ,=~ ................... ~ .......... ,~..:'.. :::.:::: !' ::::::::::::::::::::::::::::::::::::: ; :.!::.t:::: ::::::::::::::::::::: :.:::I:.:: :::::::::::::::::::::::::::::::: Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: ~-- ~ Date Required Date Received Remarks .. Ccmpletionj: Report Yes ~ ..? Well. History. . Yes _Samples /~//~_ ~/ ' , _ , ,, ~ . ' · Core Chips ////: :CC)-. ~ ~, , Core Description . ~ Registered Survey~Pl~t~. , Inclination Survey ?: Directional Survey y~>~_..~ · , . v . , Drill Stem Test Reports ~//~ ///'~.-~i , . Prcduction Te. st Reports · Logs Run. Yes ARCO Alaska, Inc. Post Office~1~ 360 Anchorage, Alaska 99510 Teleph'one 907 277 5637 September 10, 1982 Mr. C. V. Chatterton. Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for August on these drill sites' 1-19 13-32 1E-30 2-23 13-34 1G-1 2-26 14-21 1G-2 6-19 18-3 1F-5 6-20 18-6 WSW-2 6-21 1E-17 Also enclosed is a well completion report for Kuparuk 1E-16. Surveys for 2-22 and 6-18 are being reran; completion repor.ts for these wells will' be submitted when approved surveys are' received. Sincerely, . P. A. VanDusen District Drilling Engineer PAV/JG'llm Enclosures GRU1/L93 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ' STATE OF ALASKA ' ' ALASKA{r" L AND GAS CONSERVATION C~'~' ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well J~]X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-86 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20756 4. Location of Well 9. Unit or Lease Name atsurface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UN Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 71' RKBI ADL 28314 10. Well No. DS 14-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of. August ,19 82 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hfs, 07/18/82. Drld 17-1/2" hole to 2530'; ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 12055'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 13060' TD, ran open hole logs; ran & cmtd 7" lnr. Ran CBL. Set isolation pkr. Ran 5-1/2" completion assembly. Secured well & released rig ~ 1230 hfs, 08/13/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 9!.5#/ft, H-40, weld conductor set ~ 76'. Cmtd w~350 sx Permafrost II. 13-3/8", 72#/ft, L-80, BTC csg w/shoe @ 2517'. Cmtd w/2500 sx AS Ill & 400 sx AS 9-5/8", 47#/ft, L-80/S00-95, BTC csg w/shoe @'12036'. Cmtd w/500 sx Class G. 7", 29#/ft, L-80, BTC csg f/11762'-13060'. Cmtd w/400 sx Class G. SEE DRILLING HISTORY II. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHC/GR/SP f/TD to 9-5/8" shoe. CDL/CNL/GR/Cal f/TD to 9-5/8" shoe. GR/CNL f/9-5/8" shoe to 13-3/8" shoe. CBL 16. DST data, perforating data, shows of H2S, miscellaneous data N/A SEP 1 4 i982 " A!~.ska Oil & Gas Cons. Commission Anch0rag~ -17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED YJ~~ TITLE Area Dri 11 i ng Engi neet DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-~-80 GRU1/MR24 DS 14-21 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1030 hrs, 07/18/82. Drld 17-1/2" hole to 2530'. Ran 64 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2517'. Cmtd 13-3/8" csg w/2500 sx AS III & 400 sx AS II. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 12055'. Ran 287 jts 9-5/8" 47#/ft, L-80/SO0-95, BTC, csg w/shoe @ 12036'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.4 ppg EMW - ok. Drld 8-1/2" hole to 13060' TD (08/07/82). Ran DIL/BHC/GR/SP f/TD to 9-5/8" shoe. CDL/CNL/GR/Cal f/TD to 9-5/8" shoe, & GR/CNL f/9-5/8" shoe to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 52 bbls AS I, & 125 bbls Arctic Pack. Ran 40 jts 7" 29#/ft, L-80, BTC csg f/11762'-13060'. Cmtd 7" lnr w/400 sx Class G. Drld cmt toI113018' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Ran CBL. · Make up isolation pkr & RIH on wireline. Set @ 12306'. Ran 5-1/2" completion assy w/tail @ 11812' & pkr @ 11735'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Set packer w/2500 psi. Tstd tbg to 2500 psi - ok. Nipple for SSSV @ 2194'. Secured well & released rig @ 1230 hrs, 08/13/82. JG: 1 lm 09/01/82 GRU/DH38 ARCO Alaska, Inc.~ Post Office ~... 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 26, 1982 Reference: Arco Open Hole Finals D.S. 14-21 8-8-82 D.S. 14-21 8-7-82 D.S. 14-21 8-7-82 D.S. 14-21 8-7-82 D.S. 14-21 8-7-82 Do S. 14-21 8-8-82 Prolog 5" DA BHC Acoustilog/GR Run 1 2" & 5" DA DIFL Run 1 2" & 5" DA FDC/GR Run 1 2" & 5" DA FDC/CNL/GR Run 1 2" & 5" DA CNL Run 1 5" DA sign and return the attached copy as receipt of da~a. Kelly McFarland Trans. ~/ 419 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY ARCO Alaska, Inc.~ Post Office ., 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 18, 1982 Reference: Arco Directional Survey D.S. 14-21 8-9-82 Single Shot EW ~ease~sign and return the attached copy as receipt of data, Kelly McFarland Trane, # 397 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ~!aska OiJ & Gas Cons. Commission D&M Anch0rag0 GEOLOGY DALLAS '*'ARCO Alaska, Inc~ Post Office.El 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 9, 1982 Mr. C..V. Chatterton Commissioner State of Ala§ka Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton Enclosed are monthly reports for July on these drill sites: 2'25 13-25 18-3 2-26 13-30 1E-15 6-17 13-33 1H-3 6-18 ...~i~ 1H-4 6-19 18-2 Also 1H-5 enclosed are three subsequent sundry reports and completion reports for: 13-21 15-k 13-24 18-1 13-26 1E-14 14-17 1H-5 14-22 for Kuparuk The gyroscopic survey.for DS '2-22 plet.ion report for~this well will survey is received. needs to be reran; a be submitted when the com- approved Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:sm Enclosures GRU1/L61 ARCO Alaska, In(:. is a subsidiary of AtlanticRichfieldCompany ' ~ STATE OF ALASKA -' ALASKA~..... L AND GAS CONSERVATION C~ ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~] Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address ?. 0. Bo× 360, Anchorage, AK 99510 4. Location of Well at surface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 71 ' RKB ADL 7. Permit No. 82-R6 8. APl Number 50- 029-:20756 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 14-21 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of July ,19__8_2,_ ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems., spud date, remarks ~pudded well @ 1030 hrs, 0.7/18/82. Dr. ld .I_7~'-i/.2" hole. to 2530'; ran, cm.td & tstd 13-3/8" csg. Drld 12-1/4" hole. 'to. 1.04.4S' as of 07~3!~./82.. See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H~-40,. weld, 'conductor s.et @ 76', Cm.td. Wj/.350 13-3/8", 7.2#/ft, L-80, .BTC .csg W:/shoe @ .251.7"., Cm.td. W._~.2500 400 sx AS II. sx Permafro'st, I.I .sx. AS II.I & 14. Coring resume and brief description None. 15. Logs run and depth where run None to date. RECEIVED AUG 1 0 1982 ,1 6. DST data, perforating data, shows of H2S, miscellaneous data , N/A Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :SIGNED TITLE Area 'Dri,!'ling: Hngi.ne%~TE /~ ~ ..... , NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in dupi'icate Rev. 7-1-80 DS 14-21 DRILLING HISTORY NU 20" H.ydril & diverter. Spudded well @ 1030 hrs, 07/18/82. Drld 17-1/2" hole to 2530'. Ran 64 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2517'. Cmtd 13-3/8" csg w/2500 sx AS III & 400 sx AS II.· ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. ~rld FS & 10' new form. Tstd form to 12.5 ppg £MW - ok. Drld 12-1/4" hole to 10445' as of 07/31/82. A[i 10 982 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of ALASKA OIL AND GAS CONSERVATIO~ COM~4ISSION TO: C.~~'~~ert°n Thru: Lonnie C. Smith Commissioner Ed~r W. Sipple, Jr.~_~ FROM: ~trole~ Ins~ctor- DATE: July 27, FILE NO: 108/P TELEPHONE NO: Alaska 1982 SUBJECT: Witness BOPE Test on ARCO's DS 14-21 Sec. 9, T10N, R14E, MUM Permit No. 82-86 Parker Drilling Rig No. 191 ~_Wg__dnesday, July_ 20,__ !98~2 - Mike Minder and I left Kuparuk ball valve testing to go to ARco's DS 14-21. Parker Drilling Rig 191 was in the process of f~nishing the hole. Thursday., _July_.2!, !98_2 - The BOPE test commenced at 3:00 a.m. and was concluded at 3:50 p.m. There were three failures. Both kill line manual valves and one inside valve on casing head leaked. They were removed and replaced, all three valves tested to 5000 psi. I filled out the A.O.G.C.C. BOPE test report which is attached. In summzT, Mike Minder and I witnessed the BOPE test on ARCO's DS 14-21, Parker Drilling Rig 191. There were three (3) failures, the valves 'were removed and replaced and were tested to 5000 psi. AL~SK~ , & CAS CO, HoE, R%AI.[~ :l CCt, t~-tISSION B.O.P.E. Ins[~ction l{eFx~rt Operator ~. ('o Well IV-~.,l__ Location: Sec ~ Fril linq ~n~a~or Location, -Genera] Well Sign . ~)~ Cenera 1 HoUSekeeping Reserve pit -- -' .... .---':.' ------"-- -' . .--L z ':.-' ......................... Representative '-/o ~ ~ / TI~R /,~[Hq~ /3~Casing Set @~/2 ft. Full CJ~arge Erossure ~ !Oo psig Pressure After closure I~L~L~ psig. Eu~,l) incr. clos. pres. 200 psig ~.. min~ sec. FuJi Ch~e Ere~sure~ttaind: N ~'~r J"a . D3,,l g' ,~17_.~ " ~1,~ ,~ . psig Remo. te_~G_ Bli_.._.._.. n_ds.._switd. L.qgver O .~' Test Pressure Kelly and Floor Safety Valves. ._~ ~ ~ Upper Kelly ~ ~'"~'"'f" ' , _:'z'esn Pressure__ _~-a ~ 0 ~:: Lo~r Kelly Test Pressure ~-~ 5--~ o ,~, Bal 1 ~;pe '~' k''''~'' Test Fressure ~ ~ .... Inside gOP~ ?~7 Test PressaregJ~rK. oK~, ] ~f~,l~,~ ~,~[ ~-~ ~ ~ Choke ~nifold Test Pr~e{Sure 5% va ws /I ,-" ~"~ ~ ~ No. f ]a.ngeS~ - '___-~__ ~ _=:._.._ --. =_...-. ______~i~fdrauically operated choke J_ Repair or Replacement of failed ~quipn~nt-- to be made'within A//~> days and Inspector/Ccmmigsion office notified. Remarks· (}P.~,~:.~ I.,q~,~. 0:~ ~-.~ ~:' ".~ ' , [,,f~ ,( ; - , ...... ~,.r- DiStr~ut ion :" orig. - cc - ~rator cc - Su~sor Ins July 9, 1982 Br. ~ark A. ~ajor Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 369 Anchorage, Alaska 99510 Re= Prudhoe Bay Unit DS 14-21 ARiX) Alaska, Inc. Pemit No. 82-86 Sur. Loc. 2?I$*FNL, 1562'FEL, See. 9, T19N, R14E, ~. Bt~ole Loc. 5ZS'FSL, 1291'F~, Sec. 16, T10N, RI4E, ~. Enclosed is the approved revised' application for permit to drill the above referenced well, The provisions of the cover letter, dated June ?, 1982, accompanying the original approved permit are in effect for this revision. Very truly' C. V. Chatterton C~ai rman of Alaska Oil a~d ~as ~nserva~lon Enc 1 o su re Department of Fish a Game, Habitat Section w/o encl. Department of Bnvi]~onmental Conservation w/o encl. CVC: he ARCO Alaska, Inc. {(' Post Office Bt · 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 6, 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-21 Revised Permit to Drill Application Dear Mr. Chatterton' Due to a change in the bottomhole location, we are resubmitting our application for permission to drill well 14-21. Attachments include a drawing of the proposed wellbore, a proximity map and a sketch and description of both the surface hole diverter system and the BOP equipment. Since we estimate spudding this well on July 14, 1982, your earliest approval would be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG- 11 m Attachments GRU1/L43 RECEIVED J U L - ? 1982 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ALASKA ~'~l STATE OF ALASKA O,/,, L AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UN At top of proposed producing interval 1320' FSL, 1320' FEL, Sec. 16, TION, R14E, UN RECE!¥EO J U L - ? 1982 9. Unit or lease name Prudhoe Bay Unit 10. Well number Drill Site 14-21 At total depth Alaska Oil & Gas Cons. Commission 528' FSL, 1291' FEL, Sec. 16, T10N, R14E, UN Anchorage 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 71' RKB I ADL 28314 12. Bond information (see 20 AAC 25.025)~ Federal insurance Company Type Statewide Surety and/or number #8088-26-27 11. Field and pool Prudhoe Bay Field Prudhoe Bay Oil Pool 15. Distance to nearest drilling or completed well 120' ~ surface feet Amount $500,000 18. Approximate spud date 07/14/82 3720 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 6 Miles NE Deadhorse miles ] 3960 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 12961 ' MD, 9611 ' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures . psig@___~Surface KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 51 ol (see 20 AAC 25.035 (c) (2) 4600 psig@. 9611 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole I Casing 30" J20" 7'1/2" I 13-3/8" '2-1/4" / 9-5/8" / 8-1/2"/ 7" 22. Describe proposed Weight 94# 72# 47# CASING AND LINER Grade Coupling Length H-40 I Welded L-80 /Butt L-80 [Butt 111798' S00-95 L-a0 [Butt I 1463' 29# program: MD TOP TVD 110' O' I O' 2500' O' I O' 01 I 0I I 11498' 18692' I MD BOTTOM TVD 110'l 110' 2500' 12500' 11798' 18880' l 12961' !9611' I (include stage data) 275sx PF II to Surf 2300sx AS III 400ASI 250sx G, 1st Stage 300sx PFI, 2nd Stage 400sx Class G ARCO Alaska, Inc., proposes to directionally drill this well.to 12961' MD (9611' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi, RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A surface diverter system will be installed and operationally tested prior to spud and at least daily thereafter. A separate Sundry Notice will be submitted when the well is to be perforated. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~. '~ t~ TITLE Area Dri l ling Engineer The space below for con'mission ~ ~ CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number []YES ~O I-lYES /~O ~,~ES I-]NO Permit number SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY A p_.~p r ova/J date/ ,COMMISSIONER by order of the Commission DATE Form 10-401 GRU1/PD4 Rev. 7-1-80 Submit in triplicate SURFACE HOLE D I VE RTE R ARCO ALASKA SYSTEM INC. SCHEMATIC I0" HYD. OPR. BALL VALVE WE,L,L BORE (SEE DE'lA IL) .,/" /'"'m IO HYD. OPR. BALL VALVE // ,/""/'/ I ALL 90° TURNS ARE "TEE" ~ I CUSHZON I -~ ~Mi I SUB BAS~ I ~4ELL QBORE I I RESERVE ! PIT I AREA ! I ! i I ! NOTE · I I I I I ., FLOWL INE DR ILL IN6 RISER L r- i 20" 2000 PSI 'WP I ANNULAR PREVENTOR I '~ r.-! ' ~10" HYDRAULIC - DRILLING ' - - - ' Valves on diverter lines open automati- cally when the annular preventer is closed. ~0" CONDUCTOR PIPE , "DETA IL" 2026010203 13-5/8" BOP STACK DIAGRAM / ANNULAR PREVENTER BLIND RAMS PIPE RAMS DRILLING SPOOL PIPE RAMS 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 simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test l. Fill BOP stack and manifold with a non-freezing liquid. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat' in wellhead. Run in lock down.screws. 3. ClOse annular preventer and chokes and bypass valves on manifold.. 4, In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. $. Open annular preventer and close too set of ~ipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres~ sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi &. hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at' least 3 minutes. 9. Test remaining untested manifold valves {if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15'o Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and~[~'~,~ ~ functionally operate BOPE daily. . . 51.13181 '~:~ .... f' Oil & Gas (;;o-.~s,._ .. June ?, 1982 Mr. Mark A. ~iaJor Area Dr i I 1 i nt~' t~ngi neet ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 : Prudhoe Bay Unit DS 14~d~/ ARCO Alaska, Inc. Permit No. Sur. Lee. 2?IS'FNL, 1562'Pf~L, Sec. 9, T10N, R14E, Btiuhole Loc. 1757'FSL, 1996'Fl/L, Sec. 16, TIOE, 1114E, U~f. Dear {~,r. Enclosed is the approved application for posit to drill the above referenced wel I. Well samples and a mud log are not required. A continuous directional survey is-required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized 1o~ info~mtton shall be submitted on all lo6s for copyin~ except e~peri~ntal logs, velocity surveys and di~ete~ surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or raigration of anadrou~us fish. Operations in these areas are subject to AS 1.6.05.870 and the relictions promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal-Water Pollution Control Act, as amended. Prior to c~mencing operations you may be contacted by a representative of the Department of Bnviron~ental Conservation. To aid us in scheduling field work, we ~vould appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Commission may be present to witness Mr. ~rk A. ~Jor Prudhoe Bay Unit DS 14-21 -2- (' June ?, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandor~nent, please ~ive this of floe adequate advance notifioation so that we may have a wi tness present. Very truly yours, / C. V. Chat ter'~ton Cha i rman of 8Y ORDER OF THE CO~.~r~llSSlON Alaska Oil and Gas ~nse~ation ~issien Eno 1 o sure l)epart~ent of Fish & Game, Habitat Section w/o enclo Departn~ent of Envtromr~ental Conservation w/o enel. CVC~ be ARCO Alaska, Inc. Post Office BI~ .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 lqay 28, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-21, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 14-21 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's posi- tion to the nearest well drilled; a sketch and description of the BOP equipment and testing procedures; and a sketch of the surface diverter. Since we estimate spudding this well on June 12, 1982, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG' 1 lm Enclosures GRU1/L5 RECEIVED JUN - 2 1982 0i% & Gas Oons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC L_~ REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE ~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of well at surface 9. Unit or lease name 2715' FNL, 1562' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 1980' FSL, 1980' FEL, Sec. 16, T10N, R14E, UM Drill Site 14-21 At total depth 11. Field and pool 1757' FSL, 1996' FEL, Sec. 16, T10N, R14E, UM Rrudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Rrudhoe 0il Pool 71' RKBIADL 28314 12. Bond information (see ~0 AAC 25.025) federal Insurance Co. Type Statewide Surety and/or number 8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or ~completed 6 Mi NE Deadhorse miles 3300 feet we~ 120 ~ ~IJLr~O~C~,. feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 11783'MD 9171' TVD fe~t 2560 06/12/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3720 psig@ .......... Surface KICK OFF POINT 2700 feet. MAXIMUM HOLE ANGLE48 oI (see 20 AAC 25.035 (c) (2) 4503 psig@9171 ft. TD (TVD) 21 Proposed Casing, Liner'and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30 20 94# H-40 ~/elded 110 0 I 0 110~I 110 275sx PF II to Surf 17-1/~ 13-3/8 72# L-80 Butt 2500 0 I 0 2500I 2500 2300sxASIII-400ASI 12-1/t 9-5/8 47# L-80 Butt 11340 0 , 0 11340 I 8876 250sx G, 1st Stage S00-95 ~1 I 300sx PFI, 2nd Stage 8-1/2 7 29# L-80 Butt 743 11040 ~, 8676 9171 1111783 400sx Class G 22. Describe proposed program: ARCO Alaska, Inc., proposes to direetionally drill this well to 11,783'MD (9171'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi, RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uneemented annuli within the permafrost interval. The packer will be set above the Sadleroehit. A separate Sundry Notice will be submitted when the well is to be perforated. ' RECEIVED JUN - 2 .23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~ Alaska Oil & Gas Cons. Commws,on S,GNED T~TLE Area Drilling~r~~ner DATE The space below for Commission use CONDITIONS OF APPROVAL _ Samples required Mud Icg required Directional Survey required APl number []YES [;~NO []YES '~NO ~]YES []NO s0- 039-30?56 Permit number Approval date ~'-~.~ 0B/0'//82 I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY f ~~"~~~4~m~ ,COMMISSl O NER DATE JU~e ?, i982 ~ ,/c L ~-~'~~'~ by order of the Commission / Form 10-401 [ Submit in triplicate Rev. 7-1-80 4000' ¥- RECEIVED x -- d,-r4.~ 24).,4.9". L~"r. = 'TO" 14: 0~,. - ' '- Anchorage/ -.., ~ _. ~ . ~~ ~ ~z4 Y-. % '~ ~,~:-..4L '/ ~(:t~¢'~T ::f:~ED A~j"~ ~ ~ , [o 1~ . . ~ . . . ~.~,~ ;,,~AD~ t3f ME. AND l~A~ ,q~ ~ - - . . and Gas Comoanv () .IDA:rE' 1DR:AWING ALASKA DISTRICT- PRUDHOE ~AY' ~ /z/~/~'. ~ ~1~ :::I ::*~*':* ~: ................ *'-' .... ':: ................ 1 ~ t~"*'" ' ; ''~ ..... ~* ' .......... 1 ......... : : ;:~::::; :: ::': :,* ...................................... 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JUN - 2. 1982--:' Alaska Oil & Gas Cons, commission 'Anchorage 13-5/8" BOP STACK DIAGRAM ANNULAR PREVENTER BLIND RAMS 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 simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test PIPE RAMS DRILLING SPOOL 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. PIPE RAMS 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure t~.,3g~o~Psi and hold for a minimum of 3 minutes.' Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves {if any} with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed Pressure to .zero.' Open bottom s~t of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- 17.functionallyPerf°rm completeoperateBOPEBoPE teStdaily.Once a week Rev. SURFACE HOLE D ZVERTER ARCO ALASKA SYSTEM INC. SCHEMATZC --F ~ IO" HYD. OPR. BALL VALVE ~ ........---- WE,L,L BORE ( SEE DE'FA IL ) ./' /~'...-.-'-- I0' HYD. OPR. BALL VAL,V,E /' ./" f I ALL 90° TURNS ARE "TEE ~ icu'sHz°N I I ___ __~:. _!_. RECEIVED JUN - 2 i982 Oil & ~s Cons. Commission · Anchorag~ WELL ! --. (o) BORE I i RESERVE PIT AREA NOTE' ~) . FLOWL INE DR ILL ING RISER [ , 20" 2000 PSI WP ANNULAR PREVENTOR '%1 ,, i/ _~~.~ ~._ ~ERA=D BALL VALES ~ IO" DIVERTER LINE~ ~ :: ~es o~en autom~t~- ~0" ;':~' cal~y w~e~ t~e a~u~a~ ~DUCT~ ""DETAIL" ~eve~te~ ~s c~osed. PIPE 2026010203 CHECK LIST EOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 11) (4) · · 3. 4. 5. 6. 7. 8. 9 10 11 Casg ~'~ ) ~ ~'~-' 12 (12 thru 20) 13 14 15 16 17 18 19. 20. YES NO Is the permit fee attached ........................................ Is well to be located in a defined pool ........................... Is well located proper distance from property line ................ Is well located proper distance from other wells .................. Is sufficient undedicated acreage available in this pool .... IS well t° be deviated and is well b°re plat included1.' iii[ii'ii ''i![. ' Is operator the only affected party ................. . Can permit be approved before ten-day wait .......... [ . . [ · Does operator have a bond in force .................................. · Is a conservation order needed ...................................... · Is administrative approval needed ................................... · Is conductor string provided ........................................ · Is enough cement used to circulate on conductor and surface ......... · Will cement tie in surface and intermediate or production strings ... . Will cement cover all known productive horizons ..................... · Will surface casing protect fresh water zones ....................... · Will all casing give adequate ~ safety in collapse, tension and burst. · Is this well to be kicked off from an existing wellbore ............. Is old Wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... REMARKS (21 thru 24) (6) Add: /C~'~ )~'-~%.. ,,, 21. 22. 23. 24. 25. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to _~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: ~ /4'-L2- /.~.~J/ ~- ~.t. . ~-.~o~.. ~ Geology: Engi~e_rSng: HWK __~ LC~ BEW z-~[' WVA -- JK~,~--:'.~"~AD / .... reu: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE _ o CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITeM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin ~/6~._. (4 thru 1. Is the permit fee attached ........................... .. 2. Is well to be located in a defined pool ............. ''' 3. Is well located proper distance from property line . '.'. 4. Is well located proper distance from other wells .. 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ..... .7. Is operator the only affected party ....................... 8. Can permit be approved before ten-day wait ................ (4) e 10. 11. (5) Casg ~z~z~.¢~. ~- ~-~--- 12. (12 thru 20) 13. 14.' 16. 17. 18. 19. 20. (21 thru 24) 22. 23. 24. · · · · eeeeee ce.lee YES NO .... Is conductor string provided ........... - ............................. Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones .... .................. Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ......... · .... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating -Test to ._~> psig .. Does the choke manifold Comply w/AP1 'RP-53 (Feb.78) .................. R~MARKS (6) Add:~~. ~r-~-~ 25. Additional requirements ............................................. ~ _ Additional Remarks: c k-lC 1"' Geology: Engineering BEW re4:' 01/13/8 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S. 14-21 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 7-7-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale AC1 Acoustic BHC/AL PASS 1 150 - 50 GR2 Gamma Ray 2 " 0-100, 100-200 , SP1 Spontaneous Potential " 0-150, 150-300 AC Acoustic BHC/AL PASS 2 150 - 50 GR1 Gamma Ray 1 " 0-100, 100-200 , , SP Spontaneous Potential " 0-150, 150-300 RFC1 Resistivity Focused DIFL PASS 1 .2 - 2000 RLM1 " Medium " " RLD1 " Deep " " , RFOC " Focused DIFL PASS 2 " , RILM " Medium " " RILD " Deep " " CN ~Compensated Neutron CNL/CDL 60 - 0 GR Gamma Ray " 0-100, 100-200 DENP Density Porosity ~-C~/~J;~ " 60 - 0 , "ul/o ,. DEN Dens i ty " 2 - 3 '~laska 0il & ffas Coo~ r,.~ . CAL Caliper " 6 - 16 v~,i/~ ""~'horage rOissIoo PA6E 1 PAGE 2 PAGE 3 PAGE PAGE 5 PAGE 6 PAGE 7 PAGE PAGE 9 _ ARCO Ai..ASKA_~ ................................................................................................................................................................. ~-- ,. PAGE ARCo A L A S K ~_iNC_._ D,S- _1~.21 PAGE 11 ::::::::::::::::::::::::::::: PAGE AR£n Al A~KA IN£._ PAGE ~,.:..~R;l IS RU,.~ WIT_H_.O~_L._.1.19.7_Q.-l_~5~ ..... GRfz_. !S RUN .J4~ITH D!4ZL '~-~0. PA~E 14 ARCO ALASKA PAGE 15 PAGE AR, CD LASKA PAGE PAGE 18 ,~=_R C 0 ~S_KA_ I PAGE ARCh Al.. ASKA I PAGE ARCO ALASKA INC_,_ PAGE