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195-187
11111 PTD Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday,January 18, 2018 3:31 PM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: RE: [EXTERNAL]RE: KRU 3R-26(PTD 195-187)IA Sustained Casing Pressure Report Follow Up Flag: Follow up Flag Status: Flagged • Victoria, The current plan forward is to do diagnostic wellwork to troubleshoot the source of the IA pressurization and from that determine the remedial repair options. Based on initial diagnostics at surface,we suspect there is also an obstruction or ice plug in the tubing which could impede our wellwork diagnostics,so the plan includes a provision to use coil tubing(or another appropriate method)to remove the obstruction if encountered. Please let me know if you have any other questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,January 17,2018 9:48 AM To:NSK Well Integrity Supv CPF3 and WNS<n2549@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3R-26(PTD 195-187) IA Sustained Casing Pressure Report Rachel, Thanx for the notification. Please provide the plan forward when developed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa_alaska.ciov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loery@alaska.gov 1 110 From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent:Sunday,January 14, 2018 5:27 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden(c conocophillips.com> Subject: KRU 3R-26(PTD 195-187) IA Sustained Casing Pressure Report Victoria, Kuparuk producer 3R-26(PTD 195-187) has developed sustained casing pressure exceeding 2000 psi in the IA. At present,the pressure appears to settle at^'2350 psi. The well has 5-1/2", 17 lb/ft, L-80 grade production casing,which has a burst pressure rating of 7,740 psi. CPAI will continue to monitor the well's condition while a plan forward is developed. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Gravel Pack 2 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development D Exploratory❑ 195-187 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: Alaska 99510 50-029-22626-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3R-26 ADL 25513,ADL 355023 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8,866 feet Plugs measured None feet true vertical 6,782 feet Junk measured 8640 feet Effective Depth measured 8,788 feet Packer measured NONE feet true vertical 6,729 feet true vertical NONE feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 " 121' MD 121 TVD RECEIVED SURFACE 5,120 feet 7 5/8" 5,161' MD 4096 TVD PRODUCTION 8,818 feet 5 1/2 " 8,857' MD 6775 TVD JAN 162018 Perforation depth Measured depth 8540-8550,8560-8580,8592-8622,8592-8612 feet . True Vertical depth 6553-6560,6568-6582,6590-6612,6590-6604 feet AOGCC Tubing(size,grade,measured and true vertical depth) 2 7/8 L-80 8,462' MD 6,498'TVD Packers and SSSV(type,measured and true vertical depth) PACKER= NONE SSSV: =TRMAXX-5E SAFETY VLV 1979 MD 1786 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: scANNED JAN e I ZI1l8 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: SHUT-IN - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development CI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-386 Contact Name: Marshall Brown Authorized Name: H.Marshall Brown Contact Email: H.Marshall.Brown@cop.com Authorized Title:Sr.Wells Engineer i,..<4. Qq � J o I,,,\.4. Pe i cc.eContact Phone: (907)265-6218 Authorized Signature: Pi:A?: ' fc r M,A r k ql 16 ro,,,,,Date: 1/16 L1$ / VTL //74'h£? Form 10-404 Revised 4/2017 / / RB DMS I " J,"; 1 6 2a18 Submit Original Only • 3R-26 GRAVEL PACK JOB DTTMSTAI JOBTYP SUMMARYOPS 11/6/17 MISC BRUSH n' FLUSHED & DRIFTED DWN TO D-NIP @ 8398' RKB; SET 2.25" CA-2 PLUG RES SURV (OAL 25") @ 8398' RKB; SET CATCHER W/GUTTED JD (OAL 59") @ 8398' RKB; PULLED OV(ah 8339' RKB. LRS TO PERFORM CIRC-011T_ IN PROGRESS_ 11/6/17 MISC PUMPED 133 BBLS INHIBITED SW DOWN TBG UP IA FOR CIRC OUT ( JOB RES SURV COMPLETE) PUMPED 42 BBLS DSL DOWN TBG FOR FREEZE PROTECT/U-TUBED TxIA FOR 45 MIN ( JOB COMPLETE) CMIT TxIA to 2500 PSI ** PASSED**( JOB COMPLETE) 11/7/17 MISC SET OV @ 8339' RKB. PULLED CATCHER &2.25" CA-2 PLUG @ 8398' RKB. IN RES SURV PROGRESS. 11/8/17 MISC ATTEMPT TO RUN DMY DRIFT& LOWER J LATCH ROCK SCREEN ASSEMBLY, UNABLE RES SURV TO FALL FREE PAST 1900' SLM ( ENCOUNTERED CRUDE ) BRUSH N FLUSH/DSPL WELL W/50 BBLS DSL. MITT TBG AGAINST CAT SV TO 4000 PSI ( PASS ) SET 40' LOWER ROCK SCREEN ASSEMBLY @ 8440' RKB. IN PROGRESS. (( GR PIN RETAINER LEFT IN HOLE )) 11/9/17 MISC ATTEMPT TO RECOVER MISSING PINNING RING WITH MAGNETS. UNABLE TO RES SURV OBTAIN PIC WITH LIB. PULLED ROCK SCREEN ASSEMBLY& RECOVERED PINNING RING. IN PROGRESS. 11/10/17 MISC SET LOWER ROCK SCREEN ASSEMBLY @ 8279' SLM. STUNG MIDDLE ROCKSCREEN RES SURV ASSEMBLY INTO LOWER ASSEMBLY @ 8240' SLM. LD DUE TO WIND SPEEDS. IN PROGRESS. 11/11/17 MISC WITH CMDFRE! SET 113.8' ROCK SCREEN ASSEMBLY(TOP OF ASSEMBLY @ 8486.3' BTM OF ASSEMBLY 8600' RKB/DID NOT TAG ASSEMBLY READY FOR CTU. RES SURV RKB & @ ) 12/6/17 MISC PERFORMED FULLBORE GRAVEL PACK. PUMPED 5000 LBS WANLI 20/40 PROPPANT RES SURV DOWNHOLE WITH AN ESTIMATED 500 LBS INTO FORMATION AND 4500 LBS OF PROPPANT IN SCREEN ANNULUS AND TUBING. FREEZE PROTECTED WITH 4.9 BBLS OF DIESEL AND ESTIMATED TOP OF SAND IS 7783 ftKB. READY FOR COIL FCO. **PUMP REPORT TO BE ATTACHED** 12/10/17 MISC RIH WITH DJN TAG SAND TOP AT 7535'RKB, CLEANED OUT DOWN TO 8485' RKB, RES SURV POOH PICK UP FLUTED NO GO, TAG CAMCO D NIPPLE @ 8398' RKB, PAINT WHITE AND RED FLAG, OOH STACK BACK FOR THE NIGHT. JOB IN PROGRESS. 12/12/17 MISC RIH WITH 1" STINGER TO CLEAN OUT ALONG SIDE ROCK SCREEN, CLEANED OUT RES SURV DOWN TO 8498' RKB, READY FOR ELINE 12/17/17 MISC MADE 2 RUNS WITH DUMP BAILER, PLACE -3.2 GAL OF SLB ULTRA SHEAR CLASS G RES SURV CEMENT FROM 8492'TO 8498' RKB, WOC 48 HOURS BEFORE ATTEMPTING TO SHEAR SAND HEIGHT CONTROL VALVE. 12/21/17 PUMPING PUMP 10 BBLS DIESEL DOWN TBG @ 3500 PSI MAX PRESSURE AND 0.3 BPM. VERIFY TRACKING SAND HEIGHT CONTROL VALVE IS SHEARED. JOB COMPLETE HANDOVER TO OPS ONLY TO BOL. 1. KUP MITD 3R-26 Conoc©Phillips S Well Attribu ., Max AngISD TD Alaska Ii 1G, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(RKB) Act Btm(RKB) gip, 500292262600 KUPARUK RIVER UNIT PROD 46.78 5,599.90 8,866.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3R-26,1/15/2018 215'58 PM SSSV:TRDP 120 12/24/2012 Last WO: _ 11/10/2013 12/17/1995 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:RKB 8,613.0 9/23/2017 Rev Reason:GLV C/O SET ROCK SCREEN pproven 1/12/2018 HANGER,36.6 1%. ,irrr, ASS,PUMPED GRAVEL PACK,SEE NOTES Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread €I CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED asing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SCURFACE 7 5/8 6.875 41.0 5,160.7 4,095.6 29.70 L-80 BTC-MOD lI ,i- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 11 :1 •D 5 5x4.5@8451' Tubing CONDUCTOR;42.0. 121.0 •III Tubing Strings String MKS) Set th / / ade Top Connection :0 EUE 8rd Completion Details SAFETY VLV; 1,979.2 E_ Nominal ID ill Top(ftKB) Top (TV )(ftKB) Top Inc!(1 Item Des Com (in) 36.6 •III 36.6 0.10 HANGER FMC GEN IV TBG HANGER 2.992 39.8 39.8 0.11 XO Reducing 3-1/2",9.3#,L-80,EUE 8rd x 2-7/8",6.5#,L-80,EUE 8rd, 2.441 B x P CROSSOVER Gas Lift;3,073.4 I 1,979.2 1,786.5 39.30 SAFETY VLV 2 7/8"X 2.313"TRMAXX-5E"X"PROFILE SSSV 2.313 1. 8,398.1 6,451.4 43.48 NIPPLE CAMCO D"NIPPLE 2.250 Id 8,448.9 6,488.1 43.83 LOCATOR BAKER GBH-22 MODIFIED LOCATOR SUB w/3-ft 2.990 SPACE OUT Gas Lith 4,738.9 8,450.2 6,489.0 43.84 SEAL ASSY BAKER 80-40 LONG SEALS(11.85')LENGTH 2.990 IOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(RKB) (RKB) ('I Des Com Run Date ID(in) 8,486.3 6,515.1 44.09 ROCK 113.8'ROCK SCREEN ASSEMBLY(TOP OF 11/11/2017 0.000 SCREEN ASSEMBLY @ 8486.3'RKB 8 BTM OF ASSEMBLY • ASSEMBLY @ 8600'RKB/DID NOT TAG ASSEMBLY) SURFACE;41.0. 5,160.7- 8,640.0 6,624.4 45.21 FISH 2.20"x0.98'3 bladed junk mill 7/23/2013 I Perforations&Slots Gas Lit,6,150.2 _ : Shot Dens Top(ND) Btm(ND) (shots/Top(RKB) Btm(RKB) (RKB) (RKB) Zone Date R) Type Com Id 8,540.0 8,550.0 6,553.5 6,560.6 A-3,3R-26 10/26/1999 4.0 APERF 21/8"EnerJet,180 deg ph,90 deg orient from low side Gas Lit;7,183.6 8,560.0 8,580.0 6,567.8 6,582.0 A-2,3R-26 10/3/2005 6.0 APERF 2-1/8"Spiral EJ,45 deg phase III 8,592.0 8,622.0 6,590.5 6,611.7 A-1,3R-26 2/4/1996 4.0 IPERF 21/8"EnerJet,180 deg. ph;90 deg orient,F/Low Side Gas Lm,7,9329 , i 8,592.0 8,612.0 6,590.5 6,604.7 A-1,3R-26 10/26/1999 4.0 RPERF 21/8"EnerJet,180 deg Ill ph,90 deg orient from low side Stimulations&Treatments IProppant Designed(lb) I Proppant In Formation(Ib) (Date Gas Lit;8,339 -:.0 ', 5/20/2001 IIIStimulations&Treatments 11 Vol Clean Pump Stg# Top(RKB) Btm(RKB) Date I StimRreat Fluid I (bbl) Vol Slurry(bbl) 1 8,540.0 8,622.0 5/20/2001 NIPPLE;8,398.1 Mandrel Inserts at ti 1! N Top(ND) Valve Latch Port Size TRO Run Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,073.4 2,605.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,319.0 12/16/2013 2 4,738.8 3,797.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,313.0 12/16/2013 LOCATOR;8,4486 arl 3 6,150.3 4,797.4 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,306.0 12/16/2013 SEAL ASSY;8,450.1 I=-1 4 7,183.6/ 5,553.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 12/14/2013 - 5 7,933.0' 6,108.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,323.0 12/13/2013 4 I 6 8,339.0 6,408.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 1/7/2018 Notes:General&Safety End Date Annotation IF 11/2/2007 NOTE: SURFACE CSG PATCH set;ties into Mandrel Hgr to 10"from 1st Collar ROCK SCREEN 8/13/2009 NOTE:View Schematic w/Alaska Schematic9.0 APERF,6,540.0. � ' ASSEMBLY,8,486.3 8,550.0 -8.600.0,11/11/2017 12/6/2017 NOTE:EST.500 LBS INTO FORMATION AND 4500 LBS OF PROPPANT IN SCREEN ANNULUS AND 1121 TUBING APERF,8,560.0. 580.0 ate§ e, 12/6/2017 NOTE:PERFORMED FULLBORE GRAVEL PACK.PUMPED 5000 LBS WANLI 20/40 PROPPANT FRAC;8,540.0 $lk lab 12/17/2017 NOTE:PLACE-3.2 GAL OF SLB ULTRA SHEAR CLASS G CEMENT FROM 8492'TO 8498'RKB RPERF;8,592.0- ii 12/29/2017 NOTE:TUBING X IA COMMUNICATION 8,612.0 • IPERF;8,592.0- 8,622 0 - 8,622.0 FISH;8,640.0 PRODUCTION 5.5x4.508451';38.8 -8,856.7 � T-D 195-- IS . Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday,January 14, 2018 5:27 PM To: Loepp,Victoria T(DOA) Cr Senden, R.Tyler Subject: KRU 3R-26(PTD 195-187)IA Sustained Casing Pressure Report Follow Up Flag: Follow up Flag Status: Flagged Victoria, Kuparuk producer 3R-26(PTD 195-187) has developed sustained casing pressure exceeding 2000 psi in the IA. At present,the pressure appears to settle at 2350 psi. The well has 5-1/2", 17 lb/ft, L-80 grade production casing,which has a burst pressure rating of 7,740 psi. CPAI will continue to monitor the well's condition while a plan forward is developed. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED 1 • S ���\I%%ys,, THE STATE Alaska Oil and Gas ofLAsKA Conservati®n Cornmissl®n ',Ott 333 West Seventh Avenue , t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OA Main: 907.279.1433 ALES"- Fax: 907.276.7542 www.aogcc.alaska.gov H. Marshall Brown Sr. Wells Engineer ConocoPhillips Alaska, Inc. sweep SEP 0 12_017, . P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 3R-26 Permit to Drill Number: 195-187 Sundry Number: 317-386 Dear Mr. Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Commissioner DATED this 1 day of August,2017. RBDMS IN An 3 0 2017 . , • • i) Vd w5 ,tea ZZ" A. r..7 1 1 4. II IF .. 0.4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION f J APPLICATION FOR SUNDRY APPROVALS ! "R, `" Z�G ' 20 AAC 25.280 r 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Gravel PackU 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development p . 195-187 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22626-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes ❑ No E 1 KRU 3R-26 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513+ 355.0 23 Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,866' 6,782' 8788 6728 IS-6 NONE 8640 Casing Length Size MD ND Burst Collapse Conductor 79' 16" 121' 121' Surface 5,120' 10" 5,161' 4,096' Production 8,818' 6" 8,857' 6,775' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8540-8550 MD,8560-8580 MD,, 6553-6561 TVD,6568-6582 ND, 3 1/2 x 2 7/8 L-80 8,462' 8592-8622 MD,8592-8612 MD ' 6590-6612 TVD,6590-6605 ND Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKERS=NONE N/A SSSV: =TRMAXX-5E • 1979 MD and 1786 ND 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 8/21/2017 15.Well Status after proposed work: Commencing Operations: OIL E r WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: H.Marshall Brown Contact Name: Marshall Brown Authorized Title: Sr.Wells Engineer Contact Email: H.Marshall.Brown@cop.com ��,��,f� 'f�� ) Contact Phone: (907)265-6218 Authorized Signature: it rt' * Date: /�/1��/ L 1`"` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No E/ RBDMS (,l. AUG Spacing Exception Required? Yes o No Z Subsequent Form Required: /b 464- W J 2017 APPROVED BY Approved by: 9a4.1.44...._ COMMISSIONER THE COMMISSION Date: S-e5ii.-- /7 ?ictl $/h/ii- rf e/Z4-/17- 0RIGINAL ,o, #§67 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Procedure: Coiled Tubing &Slickline: (FCO, Injectivity test, Drift &Tag) Have slick line on standby for Drift& Tag immediately following FCO 1) Hold pre-job safety meeting and identify hazards 2) MIRU coiled tubing and auxiliary equipment, pressure test as required 3) RIH to tag depth and perform FCO to as deep as possible a. Previous hard tag @ 8,581 ft. SLM b. Previous FCO tag @ 8,645 ft. c. When on bottom, circulate 2 bottoms up with gel sweeps d. Attempt to obtain returns of 1:1 or less to help prevent debris fill in e. Use Nipple 8,398 to correlate depth 4) Pull above top perf @ 8,540 ft. and perform injectivity test thru coil @ .5, 1, 1.5 BPM a. Record corresponding pressure for each rate. 5) POOH while circulating @ 1:1 returns, attempting to prevent debris fill in 6) Immediately following FCO, MIRU Slickline 7) RIH to as deep as possible with 2" bailer and tag a. Use nipple @ 8,398 for depth control 8) If bailer comes back with debris, RIH with coiled tubing and venture; attempt to clean out to bottom perf @ 8,622 ft. 9) POOH, RDMO coiled tubing and slickline 10)Shut-in well DSL: (Set Screen) **Ensure screen BHA length is customized to most recent slickline tag depth** 1) Hold pre job safety meeting and identify hazards 2) MIRU DSL and auxiliary equipment, pressure test as required 3) RIH w/a 2.225" Gauge run to 8,603'; tag PBTD. Note any tight spots encountered during gauge run. POOH. • i 4) RIH w/the following BHA and set J-Latch Anchor @ 8,440ft.: a. BHA will be broken into 3 sections and will be latched together downhole b. Use previous slickline D Nipple tag data to correlate and ensure correct setting depth. OD ID LENGTH DEPTH (Feet) (Feet) PBTD 8,603.00 A 2-7/8"J-Latch Anchor 2.130 /////// 3.10 8,599.90 B Combination Bull Plug, 1"NU 10Rd x 5/8" SR 2.054 /////// 0:33 8,599.57 C 1"NU 10Rd Bow Spring Centralizer 2.063 1.049 2.56 8,597.01 D 1-1/4" NU LORD Premium Screen(3 Jts.) L-80 2.050 1.049 30.00 8,569.57 2.050" O.D. x 1.380" I.D. 4.131bs/ft 10.00ft Long H 2 3/8"4.7#Polished Bore receptacle w/ 1"NU 2.110 1.000 1.30 8,568.27 10RD connection Total Length Left in Well Bore 37.29 I 2-3/8" 4.7# Deployment Sub for PBR 5/8" SR 2.110 N/A .71 Total BHA Length 74.11 Note:BHA weight is 150 lbs 5) RIH w/40 ft. section of BHA at a maximum in-hole rate of 60' per minute to 8,440 ft. Pickup and slack-off until the actuator is taking weight. Jar down to release from PBR. POOH. DO NOT JAR during the trip in. a. Record pick-up, neutral and slack-off weights every 1,000'. b. Anchor will be in the J-slot, once picked up and slacked off. To reset the J-Latch, pick-up after taking weight from the slack-off and slowly slack-off again until no stacked weight is seen. c. The top of the PBR will be at±8,403 6) RIH hole with the following WL bottom hole assembly: Note:BHA weight is 250 lbs LENGTH DEPTH OD ID (Feet) (Feet) Top of PBR 8,568.27 2-7/8" 7.9# Latch Seal Assembly 1-1/4" NU A lORD Box x 1.250" Seal Bore (pinned up to 2.050 1.190 1.35 8,567.94 12,000 lbs) B 1-1/4"NU 10Rd Bow Spring Centralizer 2.063 1.380 2.56 8,565.38 C 1-1/4"NU LORD Premium Screen(3 Jts.) L-80 2,050 1.380 30.00 8,535.38 2.050" O.D. x 1.380" I.D. 4.131bs/ft 10.00ft Long ' D 1-1/4"NU 10Rd Sand Height Control Valve 2.054 1.166 0.60 8,534.78 (Pinned up 1,100 psi) E 1-1/4"NU 10Rd Bow Spring Centralizer 2.063 1.380 2.56 8,532.22 F 2-7/8" 7.9# Polished Bore receptacle w/ 1-1/4" 2.110 1.310 1.30 8,530.92 NU lORD connection Total Length Left in Well Bore 38.37 G 2-7/8" 7.9# Deployment Sub for PBR 5/8" SR 2.110 /////// 0.71 Total BHA Length 39.08 • • 7) RIH w/40 ft. section of BHA at a maximum in-hole rate of 60' per minute to 8,415 ft. Pickup and slack-off until the actuator is taking weight. Jar down to release from PBR. POOH. DO NOT JAR during the trip in. a. Record pick-up, neutral and slack-off weights every 1,000'. b. Anchor will be in the J-slot, once picked up and slacked off To reset the J-Latch, pick-up after taking weight from the slack-off and slowly slack-off again until no stacked weight is seen. c. The top of the PBR will be at±8,365 ft. 8) RIH hole with the following WL bottom hole assembly: a. Note: BHA weight is 98 lbs—388 lbs after engagement OD ID LENGTH DEPTH (Feet) (Feet) Top of PBR 8,530.92 2-7/8" 7.9# Latch Seal Assembly 1-1/4" NU A lORD Box x 1.250" Seal Bore (pinned up to 2.050 1.190 1.35 8,530.59 10,800 lbs) B 1"NU 10Rd Box x 1-1/4"NU 10Rd Pin 1.660 1.050 0.33 8,530.26 Crossover C Blank Pipe, 1"NU 10 RD w/ 1.660" OD collars 1.315 1.049 26.00 8,504.26 D Bow Spring Centralizer, w/ 1"NU 10 RD 1.760 1.049 2.56 8,501.70 E Vent Screen, 1" 10 NU RD Wire Wrapped 316 1.760 1.049 1.50 8,500.20 screen F 1.375"Fish Neck Sub 1"NU Box 1.660 /////// :33 8,499.87 Total Length Left in Well Bore 103.13 (32.07)* G Wire-line Adapter Kit for Vent screen 1.810 /////// 1.05 H Wire-line Setting Tool 1.690 /////// 6.23 Total BHA Length 110.41 (24.36)* 9) RIH w/vent screen BHA and sting into PBR @ 8,531 ft. a. Pick up on S/L and note increase on weight indicator to assure seals are engaged. b. Max running speed of 60 ft/min 10)Continue to pick up to reset J-Anchor and continue to RIH to bottom at 8,603ft. 11)Activate the setting tool and release the Vent Screen assembly. POOH 12)RDMO DSL . • 1.5" Coiled Tubing: (Pump Gravel Pack, FCO) • 1) Hold pre job safety meeting; identify hazards 2) MIRU Coiled tubing and support equipment; pressure test as required 3) RIH w/full wash nozzle to 8,200 ft. and establish injection rate. a. Establish .5, 1, 1.5 BPM injection rate b. Note corresponding pressure for each rate 4) Pump gravel pack per pump schedule attached.' 5) Pump the slurry at highest rate allowed until sand out is achieved (Sand Height Control valve set to shear @ 1,100 psi) POOH a. If screen out occurs before total slurry volume is pumped away, circulate out excess slurry volume. b. If Sand out is not achieved, create a second batch and continue to pump batches until sand out is achieved c. The other option is to rig up dump bailers and top off with proppant 6) Pick up the following BHA and RIH, washout excess proppant around the vent. POOH a. Vent cap @ +/- 8,500 ft. b. Spend extra time washing over gas lift mandrels while POOH OD ID LENGTH (Feet) A 1.315" O.D. x 1.049" I.D. Wash Stinger 1.050 1.049 20.00 B Handling pup 2.000 1.218 1.00 C Hydraulic Disconnect 2.190 0.690 1.00 D Sealed tubing swivel 2.130 1.100 1.00 E Dual Flapper Check Valve 2.130 1.050 1.00 Total BHA Length 25.00 7) Wash out excess sand down to±8,518'. Circulate two bottoms up. a. Gel sweeps optional. b. Short Trip 1,000'. RIH and verify that the top of the sand is±8,518'. POOH 8) RDMO Coiled tubing DSL (Pull Vent Cap, Dump Cement, Install GLD) 9) RIH w/ 1.000" x 20' + 2.130" x 20' bailer filled with 3.00 gallons of high shear bond cement to 8,518 ft. and dump cement a. 19 ft. below top of vent b. DO NOT COVER THE VENT SCREEN WITH CEMENT. c. 2 Runs total TOC =8,511' (±6 ft. Cement Cap) • • 10) RIH and set plug and catcher on 2.25" Camco C Nipple @ 8,398 ft. 11) RIH and install GLD as follows: a. Gas Lift Design to come 12)Test each valve as they are set to ensure proper seal 13)RIH and retrieve catcher and plug @ 7,497 ft. 14)RDMO Slickline 15)Turn well over to operations to be brought online 48 HOURS AFTER CEMENT IS PLACED **Bring well on slowly with gradual rate increases over time allowing for gravel pack to set** Pump Schedule: Company ConocoPhillips AK 0 API 0 Formation Kuparuk Zone#1 Temperature 155 °F Fluid Perfs 8,540- 8,622 System: 11011900 Stage Fluid Fluid Prop Cone Prop Slurry Vol Slurry Stage Pump Volume Blender Total Rate Time {gal) (pgg) (lbs) (tis) (bpm) (h miresec) 1 Displacement 1680 40.0 1.0 0:40:00 2 2.0 ppa 20/40 Ceramic 5000 2.00 10000 129.8 2.0 0:6430 3 Flush/Circulate 2500 59.5 2.0 0:29:45 Total 9;180 0,000 229.3 2:14:15 . 0 0 KUP PROD 3R-26 Conoco hi$lips2 . i4„,,,,4 Wel Aterf a tea Max A B MD TO 1:43.4. ,3 2 a` rrrmv.+r`,-W >`4a ram kMlaree stzt. 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December 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 vv2.cii2°15 K.BENDER RE: Multi Finger Caliper(MFC): 3R-26 Run Date: 10/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3R-26 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22626-00 SCANNEO PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: r,�.5- • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 15, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 to/t3/2oi5 M.K.BENDER Anchorage, Alaska 99501 rt OCT 0 8 2015 RE: Multi Finger Caliper(MFC24) : 3R-26 Run Date: 8/24/2015 ,0 cl . The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3R-26 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22626-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 SCA"ED FRS_ANC@halliburton.com Date: Signed: valzadscat STATE OF ALASKA RECEIVED E ALA. .OIL AND GAS CONSERVATION COMN„__,ION REPORT OF SUNDRY WELL OPERATIONS NOV 21 2013 1.Operations Performed: Abandon r Repair w ell 17• Rug Perforations r Perforate r Other f `' Alter Casing r Pull Tubing r 'Stimulate-Frac r Waiver r Time Extension e,, ���•'a �` Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 195-187 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22626-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513. 3R-26 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool . 11.Present Well Condition Summary: Total Depth measured 8866 feet Plugs(measured) 8466 true vertical 6782 feet Junk(measured) none Effective Depth measured 8788 feet Packer(measured) none P ( ) true vertical 6728 feet (true vertical) none Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5120 7.625 5161 4096 PRODUCTION 8818 5.5 8857 6775 Perforation depth: Measured depth: 8540-8550, 8560-8580, 8592-8622 True Vertical Depth: 6554-6561,6568-6582,6591-6612 JAN 2 JA 7 2014 Tubing(size,grade,MD,and ND) 2.875, L-80,8462 MD,6498 TVD Packers&SSSV(type,MD,and ND) no P acker SSSV-TRMAXX-5E SSSV @ 1979 MD and 1787 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development P' Service r Stratigraphic r 16.Well Status after work: Oil 17_ Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NONE Contact Theresa Lee 263-4837 Email Theresa.M.Lee@conocophillips.com Printed Name �/ Theresa e Title Wells Engineer Signature //�/ Phone:263-4837 Date ' t - Z.(,— '3 sE.mt, NOV 2 1 1, G--, ,,,,. .%.''' Form 10-404 Revised 10/2012 l /` `� ��„ �G� Submit Original Only r KUP PROD 3R-26 ConocoPhillips 0; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl I°) MD(kKB) Act Btm(ftKB) LNkps 500292262600 KUPARUK RIVER UNIT PROD 1 46.78 5,599.90 8,866.0 omoro ••• Comment H2S(ppm) Date Annotation 'End Date KB-Grd(ft) -Rig Release Date 3R-26.11/18/2013211.36 PM SSSV:TRDP 120 12/24/2012 Last WO: I 11/10/2013 12/17/1995 VertKal schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,709.0 7/23/2013 Rev Reason:WORKOVER haggea 11/18/2013 HANGER',36.6 _1 r f doh Casing Strings Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED 1i Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread �7 SURFACE 75/8 6.875 41.0 5,160.7 4,095.6 29.70 L-80 BTC-MOD k Casing Description OD lin) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)...WtlLen(I...Grade Top Thread .7�PRODUCTION 512 4.653 38.8 8,856.7 6,775.3 17.00 L-80 LTC-MOD III 5.554.5 @8451' • • Tubing Strings Tubing Description String Ma...ID(in) Top(kKB) Set Depth(k..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;42.0-121.0 TUBING WO 27/8 2.441 36.6 8,462.01 6,497.61 6.501 L-80 !Top 8rd Completion Details SAFETY VLV;19782 , Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Corn (in) 36.6 36.6 0.10 HANGER FMC GEN IV TBG HANGER 2.992 111111 39.8 39.8 0.11 XO Reducing 3-1/2",9.3#,L-80,EUE 8rd x2-7/8",6.58,L-80,EUE 8rd, - 2.441 B x P CROSSOVER 1,979.2 1,786.5 39.30 SAFETY VLV 2 7/8"X 2.313"TRMAXX-5E"X"PROFILE SSSV 2.313 Gas Lie;3.073.4 8,398.1 6,451.4 43.48 NIPPLE CAMCO D"NIPPLE 2.250 II 8,448.9 6,488.1 43.83 LOCATOR BAKER GBH-22 MODIFIED LOCATOR SUB w/3-ft - 2.990 SPACE OUT t ■ 8,450 2I 6,489.0 43.84 SEAL ASSY BAKER 80-40 LONG SEALS(11.85')LENGTH 2.990 Gas Lift.4,7388 II Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc( Top(MK8) 1 (ftKB) (.) 1 Des 1 Corn I Run Date I ID(in) 8,466 4 6,500.8 43.95 PLUG BAKER INFLATABLE BRIDGE PLUG 11/7/2013 0.000 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/f SURFACE;41.05,160.7+ Top(ftKB) Btm(kKB) (kKB) (kKB) Zone Date t) Type Com 8,540.0 8,550.0 6,553.5 6,560.6 A-3,3R-26 10/26/1999 4.0 APERF 2 1/8"EnerJet,180 deg ph,90 deg orient from low side Gas Lift;6,1502 8,560.0 8,580.0 6,567.8 6,582.0 A-2,3R-26 10/3/2005 6.0 APERF 2-1/8"Spiral EJ,45 deg phase - • 8,592.0 8,622.0 6,590.5 6,611.7 A-1,3R-26 2/4/1996 4.0 IPERF 2 1/8"EnerJet,180 deg. ph;90 deg orient,F/Low Side t _ Gas Lift 71836 In 8,592.0 8,612.0 6,590.5 6,604.7 A-1,3R-26 10/26/1999 4.0 RPERF 21/8"EnerJet,180 deg ph,90 deg orient from I low side Stimulations&Treatments Min Top Max Btm i II Depth Depth Top(ND) Btm(ND) (k Gas Lie;7,832.9 KB) (ftKB) (kKB) (kKB) Type Date Corn 8,540.0 8,622.0 6,553.5 6,611.7 FRAC 5/20/2001 A-SAND RE-FRAC,157,0004 16/20&12/18 I CARBOLITE,9.7 PPA ON PERFS Mandrel Inserts • St ati c Gas Lift;8,339.0 No Top�) Valve Latch Port Size TRO Run m _ Top(ftKB) (kKB) Make Model OD((n) Sery Type Type (in) (psi) Run Date ll 1 3,073.4 2,605.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2013 2 4,738.8 3,797.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2013 a 3 6,150.3 4,797.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2013 4 7,183.6 5,553.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2013 NIPPLE;8,398.1 : i' 5 7,933.0 6,108.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/92013 6 8,339.0 6,408.3 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 11/9/2013 DCK-2 Notes:General&Safety End Data Annotation 11/2/2007 NOTE: SURFACE CSG PATCH set;ties into Mandrel Hgr to 10"from 1st Collar ' - 8/13/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;8,448.9 SEAL ASSY.8,450.1 PLUG',8.466.4 APERF;0,540.04.550.0 y APERF;0,56(108.580.0 FRAC;8,540.0 - RPERF;8,502.0$812.01 IPERF;8,592.0-0,622.0 1 PRODUCTION 5.50.508451'; 38.8-8,856.7 3R-26 Pre-Rig Well Work Summar, DATE SUMMARY 7/11/2013 (AC EVAL)TIFL- FAILED DUE TO PRESSURE INCREASE DURING MONITOR PERIOD. (IA FL UNREADABLE) 7/23/2013 PULLED TBG STOP& K-VALVE @ 513' RKB; BRUSH n' FLUSH TBG &TAGGED TD @ 8709' SLM (EST. 140' OF RAT HOLE). IN PROGRESS. 7/24/2013 SET 2.31 XN STANDING VALVE @ 8846' RKB; REPLACE OV IN KIND @ 8409' RKB (TBG TEST FAILED); RAN HOLEFINDER& LEAK APPEARS TO BE BETWEEN 8112'— 8134' RKB; PULLED DV @ 8120' RKB& ATTEMPT TO SET EXTENDED PACKING DV @ SAME. IN PROGRESS. 7/26/2013 SET EXTENDED PACKING DV @ 8120' RKB (TBG TEST FAILED). W/HOLE FINDER VERIFY LEAK CONTINUES TO BE BETWEEN 8113' RKB —8131' RKB; CAT SV @ 8446' RKB; MEASURED BHP @ 8581' RKB; SET 2.31 XN PLUG @ 8446' RKB (GOOD DRAW DOWN TEST). SET CATCHER ON PLUG @ 8446' RKB. TURNED OVER TO DHD AWAITING PLAN FORWARD. 8/16/2013 (PRE-RWO): T POT(PASSED), T PPPOT(PASSED), IC POT(PASSED), IC PPPOT(PASSED), FT LDS (ALL FUNCTIONED PROPERLY). 8/22/2013 LOAD T&IA FOR CMIT TxIA WITH 38.2 BBL OF DIESEL. 8/23/2013 (PRE RWO): CMIT-TxIA PASSED TO 3000 PSI. MIT-OA PASSED TO 1800 PSI. 9/22/2013 PULLED OV @ 8409' RKB & LEFT POCKET OPEN. PULLED GLVs @ 7455', 6662', 5304' &3218' RKB & SET DVs. PULLED CATCHER @ 8446 RKB. IN PROGRESS. 9/23/2013 PULLED 2.31"XN PLUG @ 8446' RKB. READY FOR BPV • ConocoPhiIIips Time Log & Summary We/Mew Web Reporting Report Well Name: 3R-26 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/6/2013 3:00:00 PM Rig Release: 11/10/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11/06/2013 24 hr summary Rig move from 3K to 3R-26. Rig accept 15:00 hrs. Spot rig and support equipment. Rig up hard lines, rig up kill tank and containment. Pressure test all surface lines to 3500 psi. Pull BPV, load KWF, and record well pressures. SITP 1600 psi/IA 1700 psi/OA 70 psi. 03:00 15:00 12.00 MIRU MOVE MOB P Move rig&camp from 3K to 3R-26. 15:00 17:00 2.00 MIRU MOVE RURD P Rig accept 15:00 HRS. Lay down secondary containment,spot rig over well, rig up support equipment. 17:00 19:00 2.00 MIRU WHDBO MPSP P R/U and test lubricator, Pull BPV. SITP 1600 psi, SICP 1700 psi, OA 70 psi. 19:00 00:00 5.00 MIRU WHDBO RURD P Spot kill tank, rig up hard line to kill tank. KWM arrived @ 22:00 hrs, start taking on fluid. Rig up kill lines to well head, pressure test kill lines &hard line to Kill tank to 3000 psi. 11/07/2013 Begin killing well with 9.6#brine. Pumped 1.5 times well volume,9.6#in/out-shut in well. Pressure built up to 650 psi.Continue to circulate well through gas buster, no change on BHP with 9.6 Brine. New KWF calculations requires 12.#mud.Rig up E-line and set IBP @ 8470'COE.Test 3000 psi/30 minutes,draw down test-successfull. POOH&RD E-line. 00:00 01:30 1.50 MIRU WELCTI CIRC T Continue offloading KWF&dust up to 9.6#. Delay on Fluid trucks due to mechanical failures while transporting fluid.Called in Peak truck to haul second load. 01:30 04:30 3.00 MIRU WELCTI KLWL P PJSM-well kill-SITP 1600/IA 1700. Bleed gas cap down to 800 psi. Start pumping 2 bpm 1500 psi, reverse circ. 50 bbls taking returns to kill tank. Stop pumping. SITP 800 psi, SICP 890 psi. Start pumping long way @ 2bpm, 1400 psi.gas to surface. Pump total of 270 bbls-clean 9.6 brine to surface. Shut down,monitor well for 15 minutes,stap Kill tank- 295 bbls in tank,blow down line to kill tank. Pressure built up to 620 psi. in 15 minutes. 04:30 06:00 1.50 MIRU WELCTI KLWL P Line up to gas buster-start pumping 200 bbls @ 3 bpm/900 psi taking returns to the pits. Pump wellbore volume to sweep gas from tubing holding 70 psi choke pressure. FCP -950 psi. Page l of 5 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 06:00 07:00 1.00 MIRU WELCTL OWFF T Monitor well pressure SITP=680 psi, SICP=640 psi. 07:00 08:00 1.00 MIRU WELCTL OTHR T Bullhead 5 bbls of 9.6 ppg brine into perfs @ 1 bpm @ 980 psi-monitor SIP's of 750 psi for 30 minutes and SIP's fell off to 650 psi in 30 minutes. 08:00 09:30 1.50 MIRU WELCTL CIRC T Circulate 252 bbls @ 3 bpm @ 950 psi w/60 psi back pressure w/2 bbl losses. 09:30 12:00 2.50 MIRU WELCTL OWFF T Monitor well SITP=700 psi; SICP= 670 psi 12:00 17:00 5.00 MIRU WELCTL ELNE T RIG up Eline Unit.Test surface equipment to 3500 psi. First run- dummy run/CCL log,down to depth of 8600'. +5ft correction. 17:00 21:00 4.00 MIRU WELCTL PACK T RIH with IBP-WHP-650 psi, RIH down to 8510',TIE in+5 ft correction. P/U to setting depth of CCL-8446'- COE-8470'. Inflate element for 30 minutes. Chart and test 3000 psi/30 minutes,draw test-good. 21:00 00:00 3.00 MIRU WELCTL ELNE T POOH with Eline-keep well open to while TOOH to monitor for no-flow check. Rig down E-line. 11/08/2013 ND tree, NU BOPE,test 250/4000 psi. Fail/pass low pressre tests with lower VBR's,changed out to solid body ram. Pass-Complete BOPE test. Pull test plug& BPV, P/U landing joint and BOLDS.Tubing hanger pulled 100K,seals came free 115K, string weight 105K. Circulated B/U-No-flow,TOOH sideways with completion string. 00:00 01:00 1.00 'MIRU WELCTL CIRC P Circulate well volume of 9.6#brine with 1%safe lube to ensure all gas is out of wellbore.3 BPM @ 1000 psi. 01:00 02:00 1.00 'MIRU WHDBO MPSP P Set BPV-test to 1000 psi 02:00 03:00 1.00 MIRU WHDBO NUND P PJSM-ND Tree. 03:00 05:00 2.00 MIRU WHDBO NUND P PJSM-Inspect lift threads. Install Blanking plug. NU BOPE. Page 2 of 6 Time Logs. Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:00 15:00 10.00 MIRU WHDBO BOPE P Start Initial BOPE test @ 250/4000 psi on rams and 250/3,500 psi on Annular. 24 hr Notice was given to AOGCC @ 18:00 hrs on 11/5/13 and Right to witness was waived by Jeff Jones @ 20:30 hrs on 11/5/13. BOPE was tested with 2-7/8 and 3-1/2 test joints with 11"donuts. 1)Kill Line, Blind Rams,Top Drive Manual,3-1/2 8rd FOSV,Choke Manifold 4, 11 & 12--Good test 2)Blind Rams, Kill HCR,Top Drive Hyd., Choke Manifold 3,7, 9&10 -- Good Test 3)Blind Rams, Kill Manual, Choke Manifold 2,5&8 —Good Test 4)LPR(VBR's)w/3-1/2 testjt., 3-1/2 IF Dart Valve. --Good Test 5)Annular w/3-1/2 test jt., Manual Kill, Choke Manifold 2, 5&6 @ 3,500 psi(70%of the 5,000 rated working pressure) --Good Test 6)UPR(VBR's)w/3-1/2 test jt., 3-1/2 IF FOSV, Manual Kill, Choke Manifold 1,2, 5,&6--Good Test 7)UPR(VBR's)w/2-7/8 test jt., Manual Kill&Manual Choke--Good Test 8)UPR(VBR's)w/2-7/8 test jt., Manual Kill&Hyd. Choke --Good Test 9) Annular w/2-7/8 test jt., Manual Kill&Hyd. Choke @ 3,500 psi(70% of the 5,000 rated working pressure) --Good Test 15:00 19:00 4.00 MIRU WHDBO BOPE T Start Initial BOPE test @ 250/4000 psi on rams and 250/3,500 psi on Annular. 24 hr Notice was given to AOGCC @ 18:00 hrs on 11/5/13 and Right to witness was waived by Jeff Jones @ 20:30 hrs on 11/5/13. BOPE was tested with 2-7/8 and 3-1/2 test joints with 11"donuts. 10) LPR(VBR's)w/2-7/8 test jt.-- Failed on low test--Change out rams @ 14:30 hrs. Re-test-good test.Complete BOPE test. Page 3 of Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:00 20:00 1.00 COMPZ RPCOM MPSP P Pull blanking plug&BPV. 20:00 22:00 2.00 8,450 COMPZ RPCOM PULL P M/U Landing joint-BOLDS-P/U on tubing string-Hanger broke over 100K, seals pulled free 115K,string weight 105K. Circulate B/U with Hi-visc sweep. Establiosh SCR, ICP 2 bpm @ 460 psi, Increase rate to 4 bpm @ 1580 psi. FCP 1620 psi 4 bpm. 22:00 22:30 0.50 8,420 8,420 COMPZ RPCOM SFTY P No-flow check for 30 minutes-PJSM for TOOH with decompletion string. 22:30 00:00 1.50 8,420 6,500 COMPZ RPCOM PULL P TOOH sideways with 3.5" decompletion string. 11/09/2013 TOOH with decompletion.Tally completion string, P/U and TIH with 2 7/8"completion string down to 8440'. P/U weight 83K, Down weight 70K. Circ B/U, RIh engange seals at 8442', no-go 8454'. P/U and space out, P/U tubing hanger,test SSSV control line to 6500 psi. Pump 105 bbls of corrosion inhibitor,followed 30 bbls of 9.6 brine. Land tubing hanger with 2.5'seal assembly space out. 00:00 08:00 8.00 6,500 0 COMPZ RPCOM PULL P TOOH with decompletion, kicking pipe out every 1000ft&monitor well. Found corrision @ jt 258-8,061-ft± to 8,453-ft. Lay down seal assy. 08:00 10:30 2.50 0 0 COMPZ RPCOM OTHR P Clean and clear work floor and pipe shed. Load completion and Control line spooler. 10:30 20:00 9.50 0 8,442 COMPZ RPCOM PUTB P PU, MU and RIH w/2-7/8",6.5#, L-80 EUE 8rd AB Mod completion and RIH to 6,479-ft and PU SSSV, mu control line and continue to RIH PU 2-7/8"completion tubing while banding in the hole to 8445' 20:00 22:00 2.00 8,442 8,453 COMPZ RPCOM CIRC P Circulate B/U 3 bpm @ 900 psi. SLowly roll pumps as sting into seal assembly @ 8442'-Stop pumping. P/U-bleed off pressure-P/U weight 83K,down weight 70 down. Sting into PBR dry,bottom out @ 8453'- set down 10K-P/U and space out. 22:00 00:00 2.00 8,442 8,453 COMPZ RPCOM THGR P P/U tubing hanger,test SSSV control to 6500 psi-good test. ***total of 66 bands run*** Circulate 105 bbls of corrosion inhibited 9.6 Brine.Chase with 25 bbls of 9.6 Brine. Sting into seal assembly with 2-3 ft space out. 11/10/2013 Test Tubing then IA 3000 psi/30 minutes.Good. Bleed down and shear SOV @ 2400 psi. Set BPV-test, ND BOPE, NU tree.test 250/5000 psi. Pull BPV,test SSSV to 1000 psi from below-good. Freeze protect well, close SSSV,set BPV,dress tree and secure cellar. RDMO ***Rig release 12:00 HRS*** 00:00 03:00 3.00 8,454 8,454 COMPZ RPCOM PRTS P Set up&test tubing 3000 psi/30 minutes-good test. Test IA 3000 psi/30 minutes-good test Bleed to zero-SOV 2400 psi Set BPV-test to 1000 psi. Page 4 of 6 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T ! Comment 03:00 05:30 2.50 8,454 0 COMPZ WHDBO NUND P ND BOPE,change out lower 2 7/8" rams to 3.5"rams. NU tree. Hook up surface lines to SSSV. 05:30 08:00 2.50 0 0 COMPZ WHDBO MPSP P Pull BPV and Install TWC. Test 7-1/16"5M adapter and tree @ 250/ 5,000 psi for 15 minutes each session. --Good test. 08:00 09:30 1.50 0 COMPZ WELCTL PRTS P Pull TWC-test SSSV to 1000 psi from below. Open SSSV-prepare to freeze protect well. 09:30 11:00 1.50 COMPZ RPCOM FRZP P Reverse circulate 80 bbls of diesel @ 2 bpm @ 1,050 psi. RD LRS and allow well to swap. 11:00 11:30 0.50 COMPZ RPCOM OTHR P Close SSSV and set BPV. Dress tree and secure cellar. 11:30 12:00 0.50 COMPZ MOVE RURD P PJSM, Pull rig off well, clean cellar with the super sucker. Clean location. Release Nordic rig 3 @ 12:00 hrs. Page 6 of 6 ~~~ . . ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 4 ;~.~~~~~~, t~~'i.` ~- ~~ ~~~~ Dear Mr. Maunder: ~a5"~~~ ~- 3R, ~-6 ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped starting March 13, 2008 and the corrosion inhibitor/sealant was pumped starting November 10, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~Pe M.J. oveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11!12/08 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 36-10 185-114 >25' 6.00 6'6" 10/30/2008 7.65 11/12/2008 3K-32 197-076 11' 1.80 12" 10/3/2008 2.00 11/12/2008 3R-11D 192-016 6" 1.00 11/10/2008 3R-12RD 192-014 16' 1.90 18" 10/6/2008 4.25 11/10/2008 3R-14 192-045 20" 4.50 11/10/2008 3R-17 192-005 20" 4.25 11 /12/2008 3R-18 192-017 14' 2.10 20" 10/6/2008 4.25 11/12/2008 3R-20 192-022 9'4" 1.50 16" 9/11/2008 2.80 11/12/2008 3R-21 192-043 SF 1.70 11/12/2008 3R-22 192-039 14" 1.70 11 /12/2008 3R-26 195-187 13' 1" 2.25 11" 3/13/2008 2.25 11/10/2008 r~ LJ ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~ N~V ~ ~ 2~0~ November 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Alaska qil & Gas Cons. Gommissi~r~ ~~. anchorage ~~~~~~ N~V ~. ~ 200? ~ ~~ 1 Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 3R-26 (PTD 195-187, Sundry #307-199). The report records the successful Surface casing patch job Please call M.J. Loveland at 659-7043 or Jon Arend/Roger Winter at 659-7506 if you have any questions. Sincerely, n Arend Well Integrity Field Supervisor ~~1~~ • ';~~ ~l NOV 6 2007 STATE OF ALASKA Alaska Oil & Gas Cons. Commission ALASKA OIL AND GAS CONSERVATION COMMISSION Anchorage REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 195-187 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22626-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' ~ 3R-26 ~" 8. Property Designation: 10. Field/Pool(s): ADL 25513 AKL 2554 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8866' ~ feet true vertical 6782'- feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 5109' 7-5/8" 5161' 4096' PROD. CASING 8399' S-1/2" 8451' 6489' PROD. CASING 401' 4-1/2" 8852' 6772' Perforation depth: Measured depth: Intervals from 8540 to 8662' true vertical depth: Intervals from 6553 to 6561 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8455' MD. Packers &SSSV (type & measured depth) Baker SBE SBE- 8455' SSSV= NIP SSSV= 514' 12. Stimulation or cement squeeze summary: WCG.I,IS~ S~~CfC S fs "O~? Intervals treated (measured) ~('a•ruA ! ~• •v`` Treatment descriptions including volumes used and final pressure : \~~ ~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na na na na na Subsequent to operation na na na na na 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-199 Contact Printed Name J Title Well Integrity Field Supv. Signature Phone 659-7506 Date 11/5/07 ~~ ~~~ ~~ 2~07~~,,~ p R I G I NA L Form 10-404 Revised 04!2004 Submit Original Only • 3R-26 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Purged OA & IA with nitrogen prior to starting. Using Wachs casing saw cut and removed 2 - 18" x 24" windows on conductor casing near top of mandrel hanger. Using Wachs casing saw cut and removed 2 - 18" x 24" windows on conductor casing near bottom of excavation. Chipped cement out of top of conductor via casing window cut outs. ~ ~ Remove 12' 8 1/2" of conductor. The hole in the casing is 1' 1 1/4" the mandral hanger. From the bottom of the mandral hanger to the top of the collar is 4' 2 1/2". Clean surface casing with grinder wire wheel for Kakivik. Notified State Man Lou Grimaldi that the SC and damage has been exposed and that he could witness damage. No indication from him as to when and/or if he would. SC patch weld -Complete. Purge nitrogen while welding 4'9" SC patch. Top of patch ties into Mandrel Hanger. Bottom of patch end's 10" from first Collar. Patch Welded as per M.E. SPECS. MITOA SC repair passed. Pressure up OA to - 600 psi wait for 5 minutes no leaks, pressure to 1200 psi wait for five minutes no leaks, pressure to 1800 psi started MITOA, Initial T/I/O = 0/0/0, start = 0/0/1800, 15 min. = 0/0/1760, 30 min. = 0/0/1740, 45 min. 0/0/1730, 60 min. = 0/0/1730. Bleed down OA to 0. Final T/I/O = 0/0/0. Then wrapped SC with Denso wrap. 11/4/2007 Installed 13' of 16" conductor w/ ru ture roove back to on final height. 3~z a ~ • • 3~-acs ~~s - ~~'~ • • ^ 3 2-a ~ ~~s- ~~~. • • • ~~~ 1, s -' `~~ • • I~~ ~~~ tate of Alaska ~~--~ MEMORANDUM S Alaska Oil and Gas Conservation Commission '~ ~ ~ i ~~~? DATE: October 25, 2007 TO: Jim Regg ~~~~~ P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Casing Corrosion Petroleum Inspector ConocoPhillips KRU 3R-26 Kuparuk River Unit October 25, 2007: I inspected ConocoPhillips well # 3R-26 in the CPF-3 area of the Kuparuk River Unit. This well has had the conductor removed from around the surface casing to approximately 15 feet below ground level. Just below the surface casing hanger there is severe corrosion resulting in at least one hole through the surface casing. I did not observe any other corrosion problems below this area. Attachments: Surface Casing Corrosion KRU 3R-26 a 10-25-07 LG.jpg Surface Casing Corrosion KRU 3R-26 b 10-25-07 LG.jpg `, ~ NOV ~ ~ 20D7 KRU_3R-26_Surf Csg_corrosion_2007-1025_lg.doc r ~., . .,,:.. :* ~` =~~~ ~~;~ ~..~ : ~~ ~.. -~ '° • • Surface Casing Corrosion -KRU 3R-26 Photos by AOGCC Inspector Lou Grimaldi October 25, 2007 ~~.~` , ~- ~_ti~ ~ -. ~ r ~~ a ~x"~ e ~~ ., u ~ 3.d K,.'+~~. KRU 3R-26 Surface Casing Corrosion - ~ ~ ~~ . ~Xr, y +~ · . ~ 1r ~ 1r Œ (ill ~ ~ ~ ~ ~ [ß ~~ / SARAH PALIN, GOVERNOR AIßASIiA. OIL AND GAS I CONSERVATION COMMISSION / 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Well Integrity Supervisors ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 fl5"" \lb1 ~\ Re: Kuparuk River Field, Kuparuk Oil Pool, 3R-26 Sundry Number: 307-199 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ,.,.,..."".11::n.. J'ÚN ~ 62.0U7 i~'"'''''''' DATED this Lff. day of June, 2007 Encl. . . RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 4 2007 APPLICATION FOR SUNDRY APPROVAL ,ð¡laska Oil & Gas Cons. COO1mission A . P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D No 0 3R-26 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25513 AKL 2554 RKB 52' Kuparuk River Field/ Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8866' 6782' Casing Length 1. Type of Request: D D D 20 MC 25.280 Suspend D Operational Shutdown 0 Repair well 0 Plug Perforations D Pull Tubing D Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Perforate D Waiver D Other D Stimulate D Time Extension D Re-enter Suspended Well D Exploratory D Service D 5. Permit to Drill Number: 195-187 6. API Number: 50-029-22626-00 8. Well Name and Number: Burst Collapse CONDUCTOR 121' SUR. CASING 5109' PROD. CASING 8399' PROD. CASING 401' Size MD TVD 16" 121' 121 7-5/8" 5161' 4096 5-1/2" 8451' 6489 4-112" 8852' 6772 Perforation Depth MD (ft): Perforation Depth TVD (ft): Intervals from 8540 to 8662' Intervals from 6553 to 6561 Packers and SSSV Type: Packers and SSSV MD (ft) Baker SBE SBE- 8455' SSSV= NIP SSSV= 514' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 15, 2007 Oil 0 Gas D 17. Verbal Approval: Date: WAG D GINJ D Commission Representative: / 18. I hereby certify that the foregoing is true and co~rect the best of my kn edge. Printed Name MJ Loveland Signature /,Ø/'J/,?'uðr / v / Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Other: ~C\t\-.~{L",~t'-L\-o~ Ò'~ ~\\.~ f'-. .~ >-~'\~<> ~ ¢- rnpo.l r'~ ~0 \ 2J ~~ s..~ ~ M-\ \\e:'J 5'",""0' Fo,," R",;"" 1.-\!J4 /751,;j Approved by: (f~ /. ~ISSIONER Form 10-403 Revised 06/20°l.JetPL i6!\I I:. Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 8455' , Service D Plugged 0 WINJ D AbandOned D WDSPL D Contact: MJ Loveland/Jerry Dethlefs Title: Well Integrity Supervisors Phone 659-7043 Date 6/12/07 Sundry ÃÕ~ ' I 0;0; " Location Clearance D , ?\;-..o\.c ~ÜL~~~\a..\\Ù~ ~.ç \Q.&l. RBDMS BFl JUN 1 9 20D7 APPROVED BY THE COMMISSION Date: 673 "ðl' Submit in Duplicate . . ConocoPhillips Alaska, Inc. Kuparuk Well 3R-26 (PTD 195-187) SUNDRY NOTICE 10-403 APPROVAL REQUEST June 12,2007 This application for Sundry approval for Kuparuk well3R-26 is for inspection and repair of the surface casing due to corrosion. The well is producer, drilled and completed in 1995. It was previously reported as having a surface casing leak near surface. This request is for approval to excavate, and repair the leak. With approval, inspection and repair of the surface casing will require the following general steps: 1. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection ofthe casing damage. 7. QAlQC the repair welds· and MIT -IA to verify integrity. 8. Install anti-corrosion coating on exposed surface casing. 9. Replace the conductor and top offvoid with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. f' ,1" t , 3R-26 PTD # 195-187 T X IA Comm. Failed TIFL . . Subject: 3R-26 PTD # 195-187 T X IA Comm. Failed TIFL From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 13 Mar 200714:25:45 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, 3R-26 PTD # 195-187, gas lift producer, failed a TIFL this afternoon. Pressures before the TIFL was TlI/O = 122/323/0 psi. The well has been shut in and is scheduled for a freeze protect. I've added the well to the Sustained Casing Pressure report and will schedule slick line to troubleshoot the problem. A schematic is enclosed. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com «3R-26.pdf» Content-Description: 3R-26.pdf 3R-26.pdf Content.. Type: application/octet-stream Content-Encoding: base64 .C\. ~~ ~J ~'~ ~,'tC 1 of 1 6/18/200711:57 AM 3R-26 (PTD 1951870) report ofSC leak reoccurrence . . Subject: 3R-26 (PTD 1951870) report ofSC leak reoccurrence From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 06 Mar 200714:14:36 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim_regg@admin.state.ak.us> Tom & Jim, On 3/29/06, 3R-26 (PTD 1951870) a Kuparuk gas lifted producer, had been reported to AOGCC as having a SC leak with communication from the OA to the conductor after diesel was observed seeping from the conductor top. An OA shoe was pumped and an MITOA passed with no additional fluids seeping from the conductor in April 2006. Diagnostics could not be performed to confirm the surface casing leak and evaluate for a possible excavation repair as the leak had stopped. The conductor and cellar spill containment drum and pit liner has been monitored regularly to watch for surface casing leak reoccurrence. The surface casing leak finally reoccurred today, 3/6/07. Fluids were found dripping into the cellar spill containment drum after the OA thermaled up to 600 psi during a scale inhibitor squeeze displacement. Diagnostics will be scheduled to evaluate the surface casing leak for repair options and to confirm well integrity barriers. The well pressures prior to 51 for today's scale inhibitor sqz treatment were: TIIIO = 156/1128/160. Attached is a 90 day T/I/O plot and schematic. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com «3R-26.pdf» «3R-26 90 day TIO plot 3-06-07.gif» Content-Description: 3R-26.pdf 3R-26.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 3R-26 90 day TIO plot 3-06-07.gif 3R-26 90 day TIO plot 3-06-07.gif Content-Type: image/gif Content-Encoding: base64 Ð~~· .?\~ ~\' ~\cc 1 of 1 6/18/200711:58 AM 3R-2690 1'10 Ix768 ¡ of! AM e ¡¡:;-;:JlJi æ. rmnu. 16 . n. ; I .' Ii II ! r' II . lUJ LA Lrt.J L.:=¡ e ALASKA OIL A1Q) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~ \~1 \~ Re: Kuparuk River Field, Kuparuk Oil Pool, 3R-26 Sundry Number: 306-132 Dear Ms. McConnell: r.; (,. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this Uay of April, 2006 Enc!. · cm t\-' \7/ û&' e STATE OF ALASKA e ~ ~~ APR 06 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas APPLICATION FOR SUNDRY APPROVAL AncÍ1or,:WIZ 20 MC 25.280 " RECEIVE 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0- Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 195-187 .- 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22626-00 ., 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' 3R-26 , 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit' /f1:>1.. Z~~/3 ..;!Þ &/./1.01. Kuparuk River Field 1 Kuparuk 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): 8866' 6782' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 5109' 7-518" 5161' 4096 PROD. CASING 8399' 5-1/2" 8451' 6489 PROD. CASING 401' 4-1/2" 8852' 6772 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Intervals from 8540 to 8622 Intervals from 6553 to 6561 3-1/2" X 2-7/8" L-80 8455' Packers and SSSV Type: Packers and SSSV MD (ft) Baker SBE SBE = 8455' SSSV= NIP with K-valve SSSV= 514' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 1, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: 03/30106 A~ ,/ WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best my knowledge. Contact: Marie McConnell 1 MJ Loveland Printed Name Marie McConnell,,' ~_ ¿/ Title: Problem Well Supervisor Signature ///~"'.;/#/~ .-?ð Phone Date: 3/31/06 /Z //,. ,/, ¿£/./ Commission Use Only ~' sundl?1Djer: t6~ Conditions of approval: Notify Commission so that a representative may witness ' U- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: W RBDMS 8Ft APR .~ 3 2006 Subsequent Form Required: ~ ~ Date: 4- ..../ '2.. - D 6 j I ~t1 COMMISSIONER APPROVED BY Approved by: THE COMMISSION V ~ORIGIN ~,.¿:~ l.f .//-1:>6 Form 10-403 Revised 7/2005 Su' it in Duplicate AL ;Jl ~fr~¿ "' , e e ConocoPhillips Alaska, Inc. Kuparuk Well 3R-26 (PTD 1951970) SUNDRY NOTICE 10-403 REQUEST 3/31/06 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kuparuk producing we1l3R-26. The cement shoe is required to stop a fluid leak to surface through an apparent hole in the surface casing into the conductor casing. 3R-26 was drilled in 1995 and has been in production since that time. A surface casing cement shoe was not pumped at the time of original completion. On March 29, 2006, Operations personnel reported "wet gravel" around the wellhead and found diesel seeping fÌom the ./ conductor top. Bleeding pressure fÌom the Outer Annulus (OA) stopped the leak. When the bleeding was shutdown the OA slowly recharged to 300 psi and the seep started again. It is apparent that some pressure support is originating from the open-ended surface casing. Isolating the surface casing from formation pressure with cement will allow the OA to be kept at zero pressure eliminating the leak to surface. The proposed plan includes pumping a cement shoe to shut-off the pressure support and leak to the surface. Subsequent diagnostics will verify the existence, depth and severity of the leak in the surface casing. Should a leak be conftrmed, the AOGCC will be contacted about a proposed II" repair plan. NSK Problem Well Supervisor 08/23/04 RE: 3R-26 (195-187) SC leak Report & request for emt shoe verbal... e e Tom, Thanks for the quick response. I'll probably be sending the 10-403 in the same envelope with the 10-404 report. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, March 30, 2006 7:57 AM To: NSK Problem Well Supv Subject: Re: 3R-26 (195-187) SC leak Report & request for cmt shoe verbal approval. Good morning Marie, It is acceptable to proceed with the cementing the shoe of the surface casing annulus. According to ./ the matrix, this operation needs a sundry so please send that in with it noted that you had verbal approval. Good luck with the operation. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 3/29/2006 9:02 PM: Tom, A surface casing leak was discovered on 3R-26 today. Diesel was found seeping from the conductor into the gravel around the wellhead from a small channel in the conductor cement top. The OA has an open shoe and can not be bleed down to stop the seep. It maintains 300 psi and repressures within 1 hr of bleeding to zero. Absorb and pit liner have been wrapped around the conductor to contain the seeping diesel. Verbal approval is requested to pump an OA cement shoe so the OA can be bleed to zero to stop the seep. One the cement shoe is pumped, additional diagnostics will be performed to determine the leak depth and evaluate for excavation repair. Attached is a 90 day trend plot and schematic. Marie McConnell Problem Well Supervisor 659-7224 «3R-26 TIO 90 day plot 3-29-06.gif» «3R-26.pdf» 1 of 1 4/6/20062:55 PM e e STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS IVED APR 0 6 2006 Repair Well 0, Pull Tubing D Operat. ShutdownD 1, Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 52' 8. Property Designation: Kuparuk River Unit 11, Present Well Condition Summary: Total Depth measured 8866' 6782' true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR CASING PROD. CASING PROD. CASING Length Size 121' 5109' 8399' 401' 16" 7-5/8" 5-1/2" 4-1/2" Perforation depth: Measured depth: Intervals from 8540 to 8622 true vertical depth: Intervals from 6553 to 6561 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Stimulate D Waiver D 511: Other Time Extension Re-enter Suspended Well 5. Permit to Drill Number: Exploratory D Service D 195-1871 6, API Number: 50-029-22626-00 9. Well Name and Number: 3R-26 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 121' 5161' 8451' 8852' 121' 4096' 6489' 6772' 'IN''\"''f' G::. (/'L~P...t )~"l) ~~tt\ill\.iJ.;.~ ..1. ') Tubing (size, grade, and measured depth) 3-1/2" x 2-7/8", L-80, 8455' MD. Packers & SSSV (type & measured depth) Baker SBE SBE = 8455' SSSV= NIP with K-valve SSSV= 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13, Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl N/A N/A Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubin Pressure 15. Well Class after proposed work: Exploratory D Development 0 Service D 16, Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Verbal A roval b Tom Maunder 3/30/06 ./ Daily Report of Well Operations _X Contact Marie McConnell / MJ Loveland Marie McConnell Printed Name Signature Form 10-404 Revised 04/2004 Casin Pressure WDSPL D Title Phone Problem Well Supervisor (907) 659-7224 Date 4/5/2006 1 Z006~5;" ~{, .þ '1./(.0," Su~t Ori~.nal Only ~F{ ý/II,z~ e 3R-26 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 4/1/2006 Pumped 25 bbls of 15.6 ppg cement w/ 61 bbls diesel freeze protect down the OA (7/5/8" annulus. Cement to 4161' MD RKB for a 1000' cement column. 4/4/20061MITOA - Passed at 1800 psi. See attached MITOA report .. MECHANICAL.TEGRITY TEST (MIT) FORMe WELL NO.: 3R-26 I DATE: 14-4-06 WELL TYPE: prod AIL i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: ¡MITOA I i.e., Tbg, IA /9-5/8", OA /13-3/8", T x fA combo, etc. REQUIRED TEST PRESSURE: 11800 I psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: IDiesel R d II W IIh d P b f d d . T t ecor a e ea ressures e ore an unna es. START TIME: 108:30 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)- (PSI)* (PSI)** FAIL S TUBING SI SI SI SI T IA 125 125 125 125 PASS OA 250 1800 1750 1740 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING T IA OA 2 COMMENTS: STARTTIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA OA 3 COMMENTS: rSC COMMENTS, * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes, Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D.... FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: ¡Arend / Sauvageau - ASRC cc: PWS 6/3/00 ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 26, 2005 (;:~VED [:...~ .... OCT 2 '7 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 II.~. Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 3R-26 (APD 195-187 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation activity on the Kuparuk well 3R-26. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, fill .I1Þ~) M. Mooneý Wells Group Team Leader CPAI Drilling and Wells SCANNEf) OCT $ 1 2005 MM/skad 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 52' 8. Property Designation: ADL 25513, ALK 2554 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Perforation depth: measured 8866' feet true vertical 6782' feet measured 8673' feet true vertical feet Length Size MD 121' 16" 121' 5109' 7-5/8" 5161' 8399' 5-1/2" 8451' 401' 4-1/2" 8852' .E(~E'\/ED OCT 2 7 Z005 REPORT OF SUNDRY WELL OPERA TIONSL~",,, ..,1,. ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION :".;W¡j$.. Gonuniss~on Repair Well D Pull Tubing D Operat. ShutdownD Other Am:; ffiil'a ge Time Extension D Re-enter Suspended Well D Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development 0 Stratigraphic D Exploratory D Service D 5. Permit to Drill Number: 195-1871 6. API Number: 50-029-22626-00 9. Well Name and Number: 3R-26 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4096' 6490' 6772' Measured depth: 8540'-8550',8560'-8580',8592'-8622' Intervals treated (measured) true vertical depth: 6553'-6561', 6568'-6582', 6590'-6611' $tANNEI.) OC1 ~ 1 Z005 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Tubing (size, grade, and measured depth) 3-1/2" 12.875", L-80, 8455' MD. Packers & SSSV (type & measured depth) no packer SSSV= K-valve SSSV= 514' 12. Stimulation or cement squeeze summary: 13. Treatment descriptions including volumes used and final pressure: not applicable n~O'~)¡íUS BFi :, ~qJ~h a~rg'l" .~, (] CT 90 8 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1534 136 1196 144 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Oil-Bbl 415 416 Casinç¡ Pressure Tubinç¡ Pressure 290 250 WDSPL D Mike Mooney @ 263-4574 Mike Mooney J ~.J.' !lþf¡~ \ /1 r ._) Form 10-404 Revised 04/2004 Printed Name Signature Wells Group Team Leader ':'oj Date /t; 2' 7);; Precared bv Sharon Allsup-Drake 263-4612 Title Phone ORIGINAL Submit Original Only ) ) 3R-26 Well Events Summary Date Summary 10/03/05 PULL SLIP STOP AND K-VALVE @ 514' RKB. PUMPED 75 TOTAL BBL'S DIESEL DOWN TBG. READY FOR PERFS. [SSSV Work] 10/04/05 PERFORATED 20' WITH 2-1/8" SPIRAL ENERJET, RDX 6 SPF, 45 DEG PHASED. PERFORATED INTERVAL: 8560' - 8580'. 121 SHOTS FIRED. 10/05/05 BRUSH NIPPLE @ 514' RKB SET K-VALVE (SERIAL # K-315 CHG DOME 150 PSI @ 60 DEGREES) OAL=42.5",SET SLIP STOP ON TOP OF K-VALVE. JOB COMPLETE. [SSSV Work] PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 July 24, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3R-26 (195-187) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 3R-26. If there are any questions, please contact me at 263-4574. Sincerely, Staff Engineer Phillips Drilling MM/skad RECEIVED JUL 2 5 2001 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1843' FNL, 2886' FEL, Sec. 9, T13N, R9E, UM At top of productive interval 1644' FNL, 2819' FEL, Sec. 16, T13N, R9E, UM At effective depth At total depth 1950' FNL, 2814' FEL, Sec. 16, T13N, R9E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 520699, 6031517) (asp's 520793, 6026442) (asp's 520799, 6026132) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3R-26 9. Permit number / approval number 195-187 / 10. APl number 50-029-22626 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8866 feet Plugs (measured) 6782 feet Effective depth: measured true vertical 8758 feet Junk (measured) 6707 feet Casing Length CONDUCTOR 121' SUR. CASING 5109' PROD. CASING 8399' PROD. CASING 401' PROD. CASING Size Cemented Measured Depth True vertical Depth 16" 200 sxAS ~ 121' 121' 7-5/8" 920 sx AS III, 320 sx Class G 5161' 4096' 5-1/2" 16o sx C~ass G 8451' 6490' 4-1/2" (included above) 8852' 6772' Perforation depth: measured 8540'-8550',8592'-8622' RECEIVED true vertical 6553' - 6561', 6590' - 6611' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) JUL 2 5 2001 3.5" / 2.875", 9.3#/6.5#, L-80 tubing to 8455' MD ~t~a~ka Oil & Gas Cons. Commission Anchorage No packer K-VALVE (#K316, 150 PSI DOME) ON 2.81 CS LOCK 6/27/01CSLIP STOP ABOVE SET 6/27/01 @ 514' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 580 Subsequent to operation 830 Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl 1422 95 1581 307 Casing Pressure Tubing Pressure - 277 307 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil__ X Gas__ Suspended__ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Michael Mooney Form 10-404 Rev 06/15/88 · Title Wells Group Supervisor Questions? Call Mike Mooney 263-4574 Prepared by Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 3R-26 Event History 05/14/01 PULLED SLIP STOP & K-VALVE @ 514' RKB, TAGGED FILL @ 8723' RKB, REPLACED GLV W/DV @ 3218', PULLED GLV'S @ 5304', 7455' RKB, IN PROGRESS [SSSV WORK, TAG, GLV] 05/15/01 SET DV'S @ 5304' & 7455' RKB, PULLED OV @ 8409' RKB, LOADED CASING W/75 BBL'S SEA WATER, SET DV @ 8409' RKB, PT TBG & CASING TO 3500# PULLED 2.31" XN PLUG @ 8446' RKB [GLV, PT TBG- CSG, OPEN-CLOSE A SAND] 05/20/01 PUMPED A SAND RE-FRAC. SAW TSO AT 53 MINUTES INTO JOB, THEN HAD PRESSURE DROP OFF 1600 PSI BEFORE STARTING TO BUILD BACK UP. HAD NWBSO WITH 9.7 PPA 12/18 ON PERFS, 157M# BEHIND PIPE. PLACED 73% OF DESIGN, LEFT 24M# IN WELLBORE. [FRAC-REFRAC] 05/21/01 PREFORMED A POST FRAC FCO TO 8748'. APROX. 126' RAT HOLE. RETURNS 1-1 ALL DAY. WELL FREEZE PROTECTED TO 2000' . READY FOR GLV DESIGN. [FCO] 05/23/01 TAGGED FILL @ 8758' RKB. EST 136' RATHOLE. INSTALLED OV @ 8121' RKB. OPEN GLM @ 7455' RKB. IN PROGRESS. [GLV, TAG] 05/24/01 COMPLETED GAS LIFT DESIGN, SET K-VALVE @ 514' RKB. SET SLIP STOP ABOVE @ 514' RKB. [GLV, SSSV WORK] 06/27/01 SET K-VALVE ON 2.81" CS LOCK @ 514' RKB (DOME SETTING 150 PSI @ 60 DEGREES). SET SLIP STOP ON TOP OF LOCK. [SSSV WORK] Page I of I 7/23/01 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 02/25/98 RUN RECVD 95-187 7092 95-187 ARC 5 95-187 CBL 95-187 ARC 5 10-407 DAILY WELL OPS ~.~R~OMPLETION DATE p/ c//~/ R >k/0~/Q~7 TO ~ Are dry ditch samples required? yes~ ~_And received? 01/26/96 02/27/96 02/27/96 01/26/96 Was the well cored? yes ~.~Analysis & description received? Are well tests required? yes ~ ~.. Received? Well is in compliance "- .... ~' In ial COMMENTS T ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 29, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3R-26 (Permit No. 95-187) Well Completion Report Dear Mr. Commissioner: Enclosed is the revised well completion report for the completion on KRU 3R- 26. The date spudded and date t.d. reached has been revised. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED Alaska 0il & Gas Cons. O0mraissi0n Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 26, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3R-26 (Permit No. 95-187) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 3R- 26. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALA,Sr,,A OIL AND GAS CONSERVATION COMMk.,,51ON WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS E~ SUSPENDED [~ ABANDONED [] SERVICE [--"-] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-187 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22626 4 Location of well at surface ~:r..._: .......... 9 Unit or Lease Name 1849' FNL, 2395' FWL, Sec. 9, T13N, RDE, UM,., ..... ,,, i L;¢-'~r: L'L";';' ~i"i"' i'"" ' '----" -- ' ' '~r., ~i~i~ i Kuparuk River Unit At Top Producing Interval ~,~¢:~_.. '_.~__~ 10 Well Number At Total Depth ~ .... ~..~.~ ~_~.~. ~ 11 Field and Pool 1950' FNL, 2466' FWL, Sec 16, T13N, RDE, UM '~'~-*~' ..... ~'~'"'-'""-~*~¢ ........ - ...... .~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 41', Pad11'I ADL25513 ALK2554 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions December 9, 1995 December 15, 1995 04-Feb-96 (perrd) NA feet MSLI 1 ,9 8866' MD &6781'TVD 8788' MD & 6728'TVD YES X~J NO LJI NA feetMDI = 1380'ss APPROX 22 Type Electric or Other Logs Run ARC5/GR,GR/CCL/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECOFID 16" 62.5# H-40 SURF. 121' 24" +_200 sx AS I 7.625" 29.7# L-80 SURF. 5161' 9.875" 920 sx AS III Lead, 320 sx Class G Tail 5.5#/4.5" 17#/12.6# L-80 4057' 8852' 6.75" 160 sx 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) 3.5" 8455' 8451' ¢'op of PBR) 8592' MD - 8622' MD 4SPF 6590' - 6611'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8592' - 8622' 185512# total: put 160000# behind pipe and left 22512 in wellbore. 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) Mar-96I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO March 12, 1996 4.8 TEST PERIOD ¢ 281 105 8 0I 373 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 186 741 24-HOUR RATE ¢ 1 403 523 40 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 0 RI GIN AL Alaska Oil & Gas Oons, Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8520' 6539' Bottom Kuparuk C 8528' 6545' Top Kupark A 8531' 6547' Bottom Kupark A 8668' 6644' ORIGINAL [:<ELi:iVED APR :5 0 iDg Alssk¢. Oil & Gas Cons. Commission 31. LIST OF ATTACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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 PA~-~ NO, AFC AK 839Z APt .WELL COMPANT ARCO ALASKA~ INC, WELL NAME 3R-26 LOCATION ! ~UPARUX LOCATION 2 ALASKA HAGNETIC DECCINA?ION 2Z,98 ~RID CONV~R~NC£ AN~LE 0,00 DATE: 16-~£C-95 WELL HEAD LOCATION: LA?(N/-S) 0o00 D~P(E/-W) 0,00 AZIMUTH FROM ROTART TABLE TO TARGET IS 197,41 T!~ IN POINT(TIP) : MEASURED D~PTH 121,00 TRUE VER~ DEPTH 121,00 INCLINATION 0,00 AZIMUTH 0,00 LATI?UDE(N/-S) 0,00 DEPARTURE(~/-W) 0,00 RECEIVED SURVEY CALCULATIONS ******~***w** CIRCULAR ARC MEASURED ~EP?H ft 12!,00 I47,6! 277,03 371,60 463,60 INTERVAL VERTICAL DEPTH ft ft 0,0 !2!,00 26,6 147,61 t29,4 276,97 94,6 371,13 92,0 46i,93 TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft deg deq ft 0,00 0.00 0,00 0,00 -O,OZ 0.41 333,47 0,09 0,99 2,94 262,69 0,08 5.35 7,48 254,47 -1.88 13.92 10.94 24?,94 -6,48 DEPARTURE DISPLACEMENT at ft ft 0,00 -0,04 0,10 -3,54 3,54 -!1,88 12,03 -25,86 26,66 AZIMUTH DLS deg/ deq lOOft 0.00 O.OO 333,47 1,54 271,25 2,19 261+01 4,85 255,93 554,15 646,86 738,72 831,66 :...12 90,6 550,45 92,7 640,35 ot,? 728,83 92.9 817,79 91,5 904,43 27.02 13,39 238,75 - -14,87 45,38 t4,96 : 228,07 -28,44 67,43 16,25 :220,26 -46,!7 93,I7 17.5! 207,91 -68,46 i22,29 19,93 198,08 -95.44 -42.90 45,40 250,88 3,74 -60,98 67.29 245,00 3,28 -78,11 90,74 239,41 2.68 -93,06 1!5.53 233,66 4.08 -!04,35 141,41 227.55 4,34 1015,18 I107.35 1!97.89 1293,72 1384,44 92,! 990,54 92,2 !075,57 90,5 1157,54 95,8 1241,99 90.7 1319.21 154,71 2!.56 188,72 -127.09 189.72 23,83 !86,18 -162,35 227,t? 26,44 !82,92 -200,67 270,67 29,95 179.91 -245,91 qlA.2Z ~o ~ -293,49 = . ~.~ !8t.65 -111,78 169.26 221.33 4.01 -1!6,36 199,74 215,63 2,66 -119,35 233.48 210.74 3.26 -120.40 273.81 206,0? 3.95 -121.08 317+48 202.4~ 3.86 !477,33 1569,40 1664,45 1756,84 1849,48 92,9 1395.62 92,i i469,58 95,0 i544.31 92,4 1615,6i 92,6 367,17 35,97 182,22 -346,27 420,05 37,14 181,90 -401,07 476,53 39,18 181~21 -459,77 532,89 39,81 180,10 -518,52 589,85 40,06 180,71 -577,98 -122,88 367.42 199,54 2,86 -124,84 420,05 197,29 1.29 -126.43 476.84 195,38 2.19 -!27o4! 533,94 193,80 O,ZZ -!28,14 592,02 192,50 0.27 2034,42 2092.6I 2124,67 22i2+76 2307,30 184,9 1829,30 58.2 !874.66 32.! i899,64 88.! !967,65 94.5 2040,60 702,65 38.98 181,00 -695,65 737,59 38,58 180,83 -732,09 756,89 39+07 181,50 -752.19 8!0,83 39,85 !82.33 -808,!3 868,85 39,!6 I81,93 -868,24 -129o89 707.68 190.58 0.59 -130,47 743,63 190,11 0.71 -!30,88 763,49 189.87 2,01 -132,76 818,97 189,33 1.07 -135,00 878,67 188,84 0,77 2402,62 2491,54 2584,78 2764.61 95,3 88,9 93,2 ?0,9 2!14,06 2181,85 2252,09 2319,34 2384,6! 927,22 40,01 180,76 -928,97 982,23 40,64 179,9I -986.51 1040,42 4!,59 !78,23 -i047,80 109),03 43,00 !77,28 -1108,94 1154.69 42~54 177.07 -1169.24 -!36.42 938.93 188,35 1,I8 -136,75 995,94 187,89 0,94 -135.75 1056.56 187,38 1~56 -133,35 1116.93 186.86 1,71 -130,38 1176,49 186,36 0~54 2950,97 3227,65 3596.45 3963,05 433!,13 186,4 276,7 368.8 368,1 25!?,05 27t6,59 2983,34 3247,28 3509,0I !274,70 45.12 i74,71 -1297.94 !453,58 43,76 !74,97 -1490,87 !690,03 43,59 176,25 -1744,78 !930,39 44,33 180,34 -I999,04 2175.40 45,04 t76.98 -2257.73 -121.08 1303,57 185.33 1,64 -103,66 1494,46 183.98 0.50 -84.15 1746.8! !82,76 0,24 -76,64 2000.50 I82.20 0.80 -70o54 2258,83 181.79 0,67 4704,52 5090,33 5320,78 5599,89 5787,30 373.4 385,8 ~n.4 279,1 !87,4 3772,74 4045,70 4209,43 4404,37 4534,94 2423,23 45,09 177,13 -2521,72 2677,10 44.85 174,92 -2793,69 2825,48 44,62 172,31 -2954,85 3003,94 46,78 169,24 -315i,95 ~3,57 44,90 ~71,34 -3x8.,44 -56,96 2522,36 181,29 0.03 -38.07 2793.95 180.78 0,41 -20,05 2954.92 180,39 0,80 12.06 3151,97 179.78 1,10 34.77 3284,62 179,39 1,29 RECEIVED McARU~ED INTERVAL DEPTH DEPTH ft ft ft 5970,24 !83,0 4446,I5 4158,14 187,9 4803,I8 ~o~ !9 187,0 4940,24 6624,72 279,5 5!43,81 6903,01 278,3 5344,!7 7454,t0 274,8 5753,I4 7724,03 27t,9 5954,49 8004,72 278,7 6!61,75 8560,74 277,t 8763,!5 202,4 6710,47 SURVH¥ PROJECTHD TO 8866,00 I02,~ 6781,72 SURVEY CALCULATIONS **~**~***~** CIRCULAR ARC METHOD*w***~** TARGHT STATION AZIHU!H LATITUDH SECTION INCLN, N/-S ft deg deg ft 3240,07 43,49 !75,45 -3411,09 3360,99 42.87 179.54 -3539,50 3483,14 42,90 182,80 3667,92 43.62 181,4! 3851,70 43,08 181,74 -4049,11 4030,59 41,95 !79,79 -4235,81 4204,I0 42,65 i74,79 -4420,40 4374,37 4t,82 177,46 -4602,72 4548,5~ 42,09 !75,8I -4788,71 4725,2! 42,6? 179,05 -4974,48 4906,44 44,60 !78,48 -5167,70 5043,08 44,15 179,4! -5311.73 5!!3,62 46,!5 179,41 -5385,90 DEPAR?)JRH DISPLACEM£N? at AZIMUTH ft ft deg 49,28 3411,44 179,17 54,49 3539,93 179,11 52,!0 3667,10 179,19 45,08 385B,42 179.33 39,83 4049.31 179,44 37,30 4235,97 179,50 44,0? 4420,64 179,40 58,48 4603,09 179,27 69,42 4789,21 179,17 77,82 4977,09 177,10 81,96 5168,35 179.09 84,59 53!2,40 179,09 DLS deg/ 100ft 1,81 1,45 0,43 0,21 0,63 1,25 0,73 0,41 0,81 0,70 0,83 65,34 5384,57 179.09 0,03 RECEIVED MAR ? 7 199G k.,.(:~. / ,~ ~.. . Alaska 0il & <-~:~ r ...... ·comrn ssion Date- 3/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3R-26 RIG:PARKER 245 WELL ID: AK8397 AFC' AK8397 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/09/95 START COMP: BLOCK: FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ OM/ 1390M API NUMBER: 50-029-22626-00 12/09/95 (1) TD: 548'(548) SUPV:RLM DAILY: 12/10/95 ( 2) TD: 4548'(4000) SUPV:RLM DAILY: 12/11/95 ( 3) TD: 4135'( 0) SUPV: RLM DAILY: 12/12/95 ( 4) TD: 5172'(1037) SUPV'RLM DAILY' 12/13/95 ( 5) TD: 5172' ( 0) SUPV:dL DAILY: 12/14/95 ( 6) TD' 7520'(2348) SUPV:DL DAILY: 12/15/95 ( 7) TD' 8866'(1346) SUPV:DL DAILY: 12/16/95 ( 8) TD: 8866'( 0) SUPV'DL DAILY' MW: 9.1 PV/YP: 26/28 APIWL: 12.4 DRILLING Move rig from 3R-25 to 3R-26. Function test diverter. Directional drill 9-7/8" hole from 121' to 548' $89,365 CUM: $89,365 ETD: $0 EFC: $89,365 MW' 10.0 PV/YP' 21/23 APIWL: 8.8 DRILLING Directional drill 9-7/8" hole from 548' to 4548'. $85,182 CUM: $174,547 ETD: $0 EFC' $174,547 MW: 10.0 PV/YP: 18/20 APIWL: 7.4 DRILLING Directional drill 9-7/8" hole from 4548' to 4598'. POOH, tight. RIH, hit bridge at 2052'. Sidetracked at 2132' Directional drill 9-7/8" hole from 2130' to 4135' -- $90,269 CUM' $264,816 ETD: $0 EFC: $264,816 MW: 10.0 PV/YP: 22/18 APIWL: 5.8 POOH Directional drill 9.875" hole from 4135' to 5172'. POOH from 5172' to 4707', tight hole work pipe and pull slow. Back ream. POOH. $74,531 CUM: $339,347 ETD: $0 EFC: $339,347 MW: 10.0 PV/YP: 20/14 TEST BOPE Run 7-5/8" casing to 5161'. Test BOPE. $179,955 CUM: $519,302 ETD: $0 EFC' APIWL: 6.8 $519,302 MW: 9.0 PV/YP: 5/ 4 APIWL: 15.8 DRILLING Test BOPE 300/3000 psi. Drilling from 5182' to 7520'. $179,955 CUM: $699,257 ETD: $0 EFC: $699,257 MW' 10.0 PV/YP: 21/11 POH TO RUN CSG Drilling from 7520' to 8866'. POH. $85,455 CUM: $784,712 ETD: $0 EFC: MW: 10.0 PV/YP: 15/11 PREP TO ND BOP RIH with 4-1/2" and 5-1/2" csg. Cement. $100,106 CUM: $884,818 ETD' $0 EFC' APIWL: 4.6 $784,712 APIWL' 4.8 $884,818 RECEIVED Date: 3/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 12/17/95 ( 9) TD: 8866' ( 0) SUPV:DL DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/3-1/2" COMPLETION EQUIP. Test BOPE breaks and 5-1/2" csg to 3500 psi/30 min. Freeze protect annulus. RIH w/3-1/2" and 2-7/8" completion equip. $146,372 CUM: $1,031,190 ETD: $0 EFC: $1,031,190 12/18/95 (10) TD: 8866' ( 0) SUPV-DL DAILY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish running completion. Test casing to 3500 psi/30 min. Swap out mud with seawater. Sting into polished seal bore, PU and space out. Freeze protect top 2000' of well. Land completion string and pressure test tubing and annulus to 2500 psi. Install packoff, tubing spool and master valve. RDMO Parker. Release rig @ 1930 hrs. 12/17/95. $136,969 CUM: $1,168,159 ETD: $0 EFC: $1,168,159 2/04/96 (11) MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 TD: 8866' ( 0) PERFORATED SUPV: Perforated "A" sand @ 8592'-8622' w/2-1/8" enerjet gun big hole charges 4 jspf orientation ±90° from the low side of hole. Depressured WHTP to 0 psi for initial shot, built up to 500 psi after perfing. End of WellSummary for Well:AK8397 RECEIVED Oil.. ..[~. ,~,.:..,.., c,m,;...., commission ARCO Alaska, Inc. Date' January 3i, 1996 Transmittal #: 9328 RETURN TO: ARCO Alaska, Inc. Attn.' Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open/cased hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~'2.--- 0~91H-08 q 3 -o-72,. 1Y-24 c¢~%.[.?? 3R-26 c/%.,-! 7~, 2X- 12A ~ 5'- ~-~.3A-04 Dual Burst TDT-D Dual Burst TDT-D ARC's ARC's Dual Burst TDT-D O2/05/95 01/07/95 12/15/95 11/25/95' 01/09/96 50-029-20763-00 50-029-22371-00 5172-8866 5797-8640 50-029-21433-00 Acknowledged' D at e: DISTRIBUTION' · Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Clifton Posey Geology ATO - 1251 ,~aska Oil & '~ ,.,o?,.~. C-~mmJSSjO,,'l ARCO Alaska, Inc. Date' January 31, 1996 Transmittal #: 9327 RETURN TO: ARCO Alaska, inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. q~- l~ 3R-25 (CBT) Cement Bond Log ~.F'-' t~"7 3R-26 (CBT) Cement Bond Log Receipt .~ ~~.~~~ Acknowledge' 01/02/96 5400-71 94 01/02/96 7700-8698 Date' DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-12O5 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 Gas Cons. gnch,,orage chlumberger I GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 AT'I'N: Sl~errie NO. 10004 Company: 1/24/96 Alaska Oil 87 Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, Al( 99501 Field: Kuparuk (Open/Cased ttole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1H-08 )2 -c)¢/5 95064 DUAL BURST TDT-P (BORAX) 950205 I I "' 1 1Y-24 ¢¢,~ ~ 0 72, 95036 DUAL BURST TDT-P (BORAX) 950107 I I ,~c/ 3R-26 Y~-~ I~)'? 95406 ARCS 951215 I I · I ¢ 2X-12A ?~'-f"7(. 95382 ARCS 951125 I 1 I ~'~ ...... 3A-04 ~',Y- 2. ~ "/ 95038 DUAL BURST TDT-P (BORAx) ,, 950109 I I I 6 ,, ........ , , SIGNED: Please si.qn and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J o j3~..~-{~ DATE: Chairman December 9, 1995 THRU: BlairWondzell, ~ FILE NO: P. !. Supervisor ECXJLHCD.DOC FROM: Lou Grimaldi, ~;,-,- SUBJECT: Petroleum Inspector Diver[er inspection Parker rig 245 Arco well # 3R-26 Kuparuk River field PTD # 95-187 Saturday, December 9, 1995: I witnessed the Diverter function test on Parker rig 245, drilling Arco well # 3R-26 in the Kuparuk River field. The function test went well. I found the vent lines and preventer to be properly laid out. The vent line extended approximately 80' from the sub-base towards the off side of the pad. The vent line was well secured with two weighted pilings. Prevailing winds were in such a direction as to preclude blowback towards the rig. A recharge on the accumulator took 3 minutes and 2 seconds which is normal for this rig's accumulator system. The area surrounding the rig was clean and orderly. The good rigup that I found has become a routine for this rig and although that finding all items in compliance is as it should be, it is done consistently by this rig. SUMMARY: I witnessed the Diver[er function test on Parker rig 245 in the Kuparuk River field. Ail equipment was in compliance. Attachments: ECXJLHCD.XLS cc:Mike Zanghi Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Parker Arco Alaska inc. 3R-26 T. 13N R. Operation: Rig No. Oper. Rep.: Rig Rep.: 9E Development 245 PTD # Date: X Exploratory: 95-187 Rig Ph. # Bobby Morrison 12/8/95 659-7670 Dearl Gladden/Fred Herbert Merdian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: N/A (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: P Drlg. Rig: P Flare Pit: N/A 20 in. P P 16 9O N/A P P N/A in. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 30OO 1400 0 min. 31 3 min. 2 Five Bottles psig psig sec. sec, MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: 2300 Average psig Light Alarm P P GAS DETECTORS: Methane Hydrogen Sulfide: P P P P Light Alarm P P P P DIVERTER SCHEMATIC North Wind Non Compliance Items NONE Repair Items Within Remarks: GOOD RIGUP Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c - Inspector AOGCC REP.' OPERATOR REP.' ECXJLHCD.XLS Louis R. Orimaldi Bobby Morrison DVTRINSP.XLT (REV. 1/94) 7¸. TONY KAIOWLE$, GOVEBNOF~ ALASKA OILAND GAS CONSERVATION COM~H$SION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14,33 FAX: (907) 276-7542 November 29, 1995 Michael Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 3R-26 ARCO Alaska, Inc. Permit No: 95-187 Sur. Loc. i849'FNL, 2395'FWL, Scc: 9, T13N,'R9E, UM Btmhole Loc. 1957'FNL, 2455'FWL, Sec. 16, TI3N, R9E. UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to drill the above referenced xvell. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffEnclosurcs cc; Department of Fish &Gamc, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA5, ~ OIL AND GAS CONSERVATION COMMISSI~I PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r~ lb Type of Well Exploratory E] Stratigraphic Test E] Development Oil X Re-Entry D Deepen [~ Service E] Development Gas E] Single Zone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 11' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25513, ALK 2554 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2O AAC 25.025) 1849' FNL, 2395' FWL, Sec. 9, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1738' FNL, 2448' FWL, Sec. 16, T13N, R9E, UM 3R-26 #U-630610 At total depth 9, Approximate spud date Amount 1957' FNL, 2455' FWL, Sec. 16, T13N, R9E, UM 12/7/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVO) property line 3R-14 8940' MD 1738 ~ TD feet 24.4' ~ surface feet 2560 6837' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 44.3° Maximum surface 2428 psig At total depth (TVD) 3600 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD -I'VD MD TVD (include stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 5115' 41' 41' 5156' 41 02' 850 Sx Arcticset III & 320 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 8459' 41' 41' 8500' 6500' 160Sx ClassG 6.75" 4.5" 12.8# L-80 EUE8rdM 440' 8500' 6500' 8940' 6837' Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural !~.. Conductor Surface Intermediate !,: ~'.; ',.. ...... Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify the: the foregoyg is true and correct to the best of my knowledge {~,~jt[, ~.j~~ Title Drill Site Develop. Supv. Date { [~ ~'~ Commission Use Only Permit Number r' !/._~ // ' '~' ] Approv/~ly.~,d.~.~/~_...~- ]See cover letter for ?~- ,-/~'~p 150- 4::~'2~- ..~-..~_.. ~::~ ...~-., ~ Iother requirements Conditions of approval Samples required E] Yes ~;~ No ° /Mud Io{;i required E] Yes J~ No Hydrogen sulfide measures ~ Yes D No Directional survey required ~ Yes E] No Required working pressure for BOPE E] 2M ~ 3M E] 5M r-~ 1OM E] 15M Other: David Original W. Signed Johnston Byby order of Approved by Commissioner the commission Date t/ ._. Form 10-401 Rev. 7-24-89 S/ubmi~ in triolicate ARCO Alaska, Inc Post O.¢f .... Box 100360 Anchorage, Alaska 99510-0360 Teiephone 907 276 '1215 November 20, 1995 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Annular Pumping Operations for Well KRU 3R-26 Dear Mr. Johnston: The request for approval of annular pumping operations on KRU 3R-26 is enclosed as part of the submitted Permit to Drill application. Please note that the request has been adjusted from previous applications to reflect the latest version of the AOGCC draft annular pumping regulations, 20 AAC 25.080. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Sincerely, ~~l~-~ghi Drill Site Development Supervisor AR3B-6003-93 242-2603 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3R-26 . o 4. . . 1 , 9, 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (5,156')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (8,940') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. ,. DRILLING FLUID PROGRAM Well KRU 3R-26 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,428 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3R-26 is 3R-14. As designed, the minimum distance between the two wells would be 24.4' @ surface. Drillin~ Area Risks- Risks in the 3R-26 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3R-26 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3R-26 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped dudng the production cement job to cover the formation. It is requested that 3R-26 be permitted for annular pumping occurring as a result of the drilling project on DS 3R, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3R surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. Please reference the enclosed directional drilling plan for other formation markers in this well. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi 3R-26 Max Pressure = 4060 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD VVt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4 2 42 7000 5950 ARCO ALASKA, Inc. Pad 3R 26 slot #26 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by- Baker Hughes [NTEQ Your ref : 26 Version #8 Our ref : prop1417 License : Date printed : 10-Nov-95 Date created : 22-Sep-95 Last revised : lO-Nov-95 PGMS Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nTO 30 8.305,w149 51 1.222 Slot location is n70 29 50.117, w149 49 50.723 Slot Grid coordinates are N 6031513.268, E 520696.291 Slot local coordinates are 1849.00 S 2395.00 E Reference North is True North Main calculation performed with Travelling Cylinder method Object wellpath PGMS <O-8760'>,,15,Pad 3R PGMS <O-9036'>,,19,Pad 3R PGMS <0-8150'>,,18,Pad 3R PGMS <0-7520'>,,22,Pad 3R PMSS <0-3191'>,,11,Pad 3R PGMS <0-7180'>,,17,Pad 3R <3100-8280'>,,0lik Pt 2,Pad 3R PGMS <0-9750'>,,0lik Pt 2A,Pad 3R PGMS <0-7750'>,,12,Pad 3R PGMS <O-9049'>,,14,Pad 3R PGMS <0-8075'>,,10A,Pad 3R PMSS <4724-10601'>,,lO,Pad 3R PGMS <0-8775'>,,21,Pad 3R PGMS <0-10775'>,,20,Pad 3R 25 Version #6,,25,Pad 3R Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 18-Jun-92 49.6 240.0 8620.0 21-Jul-92 122.3 1175.0 7440.0 27-May-92 112.8 1075.0 1075.0 18-Jun-92 223.5 300.0 875.0 17-Feb-92 115.1 120.0 475.0 27-May-92 96.9 950.0 8600.0 8-Dec-91 319.5 3820.0 3840.0 8-Dec-91 331.8 3840.0 3840.0 20-May-92 90.8 0.0 0.0 18-Jun-92 24.4 0.0 8940.1 28-May-92 140.4 220.0 220.0 28-May-92 140.4 220.0 220.0 21-Jul-92 199.5 0.0 0.0 27-May-92 174.2 0.0 825.0 7-Nov-95 74.9 375.0 375.0 Creo[ed by : jones For: D PETI~SH Dote potted : 1D-Nov-g5 Plot Reference is 26 Version ~18. ICoordinotes are in feet reference spot ~26. tTrueVerUcal Depths ere reference EKE (Porker ~245). 400 _ c) O c5 - O CN 0 _ .. ~) 400 _ _ o if) - 800 _ 1200_ I I V 1600_ _ 2000_ - 2400_ _ 2800_ _ 3200_ _ 3600_ 4000_ _ 4400_ _ 4800_ _ 5200_ _ 5600_ _ 6000_ _ 6400_ _ 6800_ 72OO ARCO ALASKA, Inc. Structure : Pad 5R Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska S .59 DEG E 5169' (TO TARGET) ***PLANE OF PROPOSAL*** .... East --> 400 0 400 Begin Turn to 'forget 800 I RKB ELEVATION: 52' KOP TVD=300 TMD=500 DEP=O 3.00 6.00 8.28 BEGINTURN TO TARGET -rVD=566TMD=567 DEP=6 9.63 11.61 13.95 16.5o 3 DEG /100' DLS 19.19 21,9,5 24.76 27.61 30.49 33.39 36.30 39.22 B/ PERMAFROST TVD=1702 TMD=1809 DEP=444 42.16 EOC WD=1828 TMD=1979 DEP=557 .. ] SURFACE LOCATION: 1849' FNL, 2395' FWL SEC, 9, T13N, RUE T/ UGNU SNDS TVD=2732 TMD=3242 DEP=1439 B/ W SAK SNDS TVD=5902 TMD=4877 DEP=2581 T/ W SAK SNDS WD=3462 TMD=4262 DEP=2152 TARGET LOCATION: 1738' FNL, 2448' FWL Bose Permafrost EOC Top Ugnu Sands Top West Sak Sands Bose West Sok Sands 7 5/8 Casing Pt _ 800 _1200 .1600 _2000 0 _ (- _2400 _ _2800 I _5200 J V _3600 _4000 SEC. 16, T13N, RUE _4400 CSG PT TVD=4102 TMD=5156 DEP=2776 ~ TARGET 7 5//8" vN~ TVD=6576 - 'x TMD=8599 xN DEP=5169 _4800 ~ SOUTH 5169 t Bose HRZ ~ EAST 53 ~-1 Marker _ ~ / ,[ '~Top Unit O (EOD) %, TARGET - T/ Unit C~ J ITop B Unit 5200 Bose Kup Sands MAXIMUM ANGLE ~ k, t / - 44.31 DEG ~ ~ _]6°° ~ Ilg57' rNL' 2455.rwL ~ ~13N, RgE B/ HRZ TVD=6242 TMD=8147 OEP=4865 %.. BEGIN ANGLE DROP TVD=6540 TMD=8284 DEP=4961 '% , 4400 DROP 2 DEC / 100 -' '~~-b'~P=TG~z %. ~;2.oo , · T/ UNIT D (EOD) ~-8500 DEP:5106 ~ ~ ~'/Z," ~,~r'/~# ~0 ~'"¢ ~_..8¢-~::~/~ TARGET - T/ UNIT C TVD=6576 TMD=8599 DEP=5169 T/ UNIT S WD--6589 TMD=8616 DEP=5180 T/ UNIT A TVD=6592 TMD=8620 DEP=5183 TD -"~ 1/g" CSG PT TVD=6§37 TMD=8940 DEP=538§ 4o0 0 ~00 soo ~200 ~ 600 2000 240o 280o ~200 3600 4oo0 44oo 48o0 5200 5eoo Scole] : ~00.00 Vertical Section on ~79.41 azimufh wHh reference 0.00 N, 0.00 E from slot #~6 !Created by : jones For: D PETRASH Date plotted : 10-Nov-95 iPIot Reference is 26 Version !Coordinotes ore in feet reference slot ~26. jTrue Verticol Depths ere reference EKB (Porker ~245). o 8O 120 160 200 240 280 _ I -- 520 _ - ARCO ALASKA, Inc. Structure : Pad 3R Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 360 _ 400 440 480 _ 520 _ 560 _ _ 600 _ <~- West Scole 1- 20.00 400 360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 I I I I I I I I I I II II II I II II [I I I II 5300 1300 1500 17OO 1300 1100 1500 1300 4700 _ 2300 4100 _ 80 O0 200£~700 - _ 120 33®~--~ 4~0 ] 160 f '~ _ 320 1500 -- 520 600 8O ca 4-0 " 0 0 0 0 _ 4-0 I I I I I I I I I I I I I I I I I I I I I I J I I I I I I I I I 400 .360 320 280 240 200 160 120 80 40 O 40 80 120 1 60 200 240 280 < W e s f ~co,~1 .20.00 0 I I V ._ LIPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 6 I4 I 5 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 , 6 13 5/8" 5000 PSiSTACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELl_HEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL ~PONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO3-1'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 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 3(X)0 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSi X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8"- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR WELL PERMIT,._CHE ,KLIST C0M~ANY ,, PROGRAM: exp [] dev~ redrll [] serv [] 0N oF ADMINISTRATION ENGINEERING 1- 2. 3. 4. 5. 6. '7. 8. 9. -- 10. 11. 12. 13. Permit fee attached .................. ~ Y Lease number appropriate ............... t Y Unique well name and number .............. Well located in a defined pool ............. /.Y Well located proper distance from drlg unit boundary.. ~Y Well located proper distance from other wells ..... .IY Sufficient acreage available in drilling unit ..... ./Y If deviated, is wellbore plat included ........ Operator only affected party .............. /.Y Operator has appropria~e bond in force ........ f .Y Permit can be issued without conservation order .... k Y Permit can be issued without administrative approval. % .Y Can permit be approved before 15-day wait ....... . APPR~ D~__~ GEOLOGY 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs'. ....... ¢ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long str±ng to surf csg . . i~¢ 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~-~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ~Y~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to psig. Y~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ......... .... ~ N 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: .,.~ ·? - ~ TAB ,'~'",- Comments/Instructions: Z 0 HOWf]o - A:~ORMS%cheldist rev' 0,.3/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER SCHLUMBERGER COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE AP1 NUMBER REFERENCE NO ~~?~:~"';~ ' ~'"'~. I~'~.~ ,~/'~ : ARCO ALASKA, INC, : 3R - 26 : KUPARUK : NORTH SLOPE : ALASKA : 50-029-22~26-00 : 95406 LIS Tape Ver|~icat|on L|st|ng Schlumberger Alaska Computing Center 24-JAN-1996 09:10 **,* REEL HEADER SERVICE NAME : EDIT DATE : 96/el/24 ORIGIN : FLIC REEL NAME : 95406 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ KUPARUK 3R-26~ API #5~-029-22626-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 96/e~/24 ORIGIN : FLIC TAPE NAME : 954e6 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.~ KUPARUK 3R-26~ API ~50-029-22626-00 TAPE HEADER KUPARUK MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3R - 26 50e292262600 ARCO ALASKA~ INC. SCHLUMBERGER WELL SERVICES 24-JAN-96 BIT RUN 1 BIT RUN 2 BIT RUN 3 JOB NUMBER: 95406 LOGGING ENGINEER: CGT/AVK OPERATOR WITNESS: LUTRICK # SURFACE LOCATION SECTION: 9 TOWNSHIP: 13N RANGE: 9E FNL: [849 FSL: FEL: FWL: 2395 ELEVATION(FT FROM MSL KELLY BUSHING: 52.00 DERRICK FLOOR: 52.0e GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) IST STRING 6.750 7.625 5160.0 2ND STRING PAGE: LIS Tape VerJfica%Jon Lis%lng Schlumberger Alaska Compu%Jng Cen~er 24-JAN-~996 09:10 3RD STRING PRODUCTION STRING REMARKS: Well drilled 12-DEC %hrough 13-DEC-95 wish ARC5 only. All da~a was collec%ed in a single bi~ run. No MAD daSa was collected, $ $ **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : DATE : 96/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shif%ed and clipped curves. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 8864.5 5~95.5 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD 88888.0 8729.5 8660.5 8629.5 8619.0 8588.0 8570.5 8564.0 8558.0 8526 0 8466 5 8411 0 8365 5 8314 5 8262 5 8245.0 8i32.0 8114.5 88887.0 8728.5 8660.0 8628.5 8618.5 8587.5 8570.0 8563,5 8556.5 8525.~ 8465.5 8410.5 8364.0 8314.0 8261.5 8244.5 8130.5 8113.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1996 09:Z0 8106.5 8106.0 8096.5 8098.5 8094.5 8094.0 8051.0 8050.0 8037.0 8037.0 8030.5 8029.5 7997.0 7996.0 7986.5 7985.0 7974.5 7973.0 7960.5 7959.5 7945.5 7944.0 7935.5 7933.0 7908.5 79~7.0 7895.5 7893.5 7883.5 7881.0 7875.0 7874.0 7856.0 7854.5 7847.0 7845.5 7750.~ 7748.0 7727.0 7725.0 100.~ 98.0 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE $ REMARKS: The depth adjustments shown above reflect the MWD GR to the CBL GR logged by SWS. All other MWD curves were carried with the GR, Only one Bit Run was made, $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JAN-1996 09:10 PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ** NAME DEPT SERV ID UNIT SERVICE AP1 AP1 AP1 API FILE NUMB NUMB SIZE REPR ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE FT eO 000 00 0 I 1 1 4 68 PROCESS (HEX) ROP MWD FET MWD GR MWD RPXX MWD RPX MWD RPS MWD RPM MWD RPD MWD F/HR 00 ~ee ee 0 1 1 1 4 68 HR 00 e00 00 0 I 1 1 4 68 GAPI 00 000 eO 0 I I I 4 68 OHMM ~0 00~ 00 ~ 1 1 I 4 68 OHMM 00 000 ~0 0 I I I 4 68 OHMM 0~ 000 00 0 1 1 1 4 68 OHMM 00 000 ~0 0 I 1 1 4 68 OHMM ~0 000 00 0 I 1 1 4 68 DATA DEPT. RPXX.MWD RPD.MWD DEPT. RPXX.MWD RPD.MWD DEPT. RPXX.MWD RPD.MWD DEPT. RPXX.MWD RPD.MWD DEPT. RPXX.MWD RPD.MWD 8864.500 ROP.MWD 68.276 FET.MWD 6.e31 3.8e6 RPX.MWD 4.039 RPS.MWD 4.166 4,e19 8750.000 ROP.MWD 110.000 FET.MWD ~.269 2.588 RPX.MWD 2.737 RPS.MWD 2.775 2.760 7000.000 ROP.MWD 180.000 FET.MWD e.169 2.428 RPX.MWD 2.554 RPS.MWD 2.555 2.527 5250.000 ROP.MWD 180.000 FET.MWD 0.100 3.220 RPX.MWD 3.438 RPS.MWD 3.465 3.368 5095.5ee ROP.MWD 180.000 FET.MWD 0.000 231.569 RPX.MWD 1000.000 RPS.MWD 1000.~00 GR. MWD RPM. MWD GR. MWD RPM.MWD GR. MWD RPM. MWD GR. MWD RPM. MWD GR. MWD RPM. MWD 99.258 4.127 112.446 2.749 108.809 2.508 89.793 3.385 10.495 1000.000 ** END OF DATA ** LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen~er *,** FILE TRAILER FILE NAME : EDIT .OO1 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 24-JAN-1996 09:10 PAGE: · *** FILE HEADER FILE NAME : EDIT .OO2 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header da~a for each bi~ run in separa%e files, BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD $ LOG HEADER DATA 5997.0 8866.9 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 15-DEC-95 49B16 49BB93 MEMORY 8866.9 5295.0 8866.9 47.9 TOOL NUMBER ARC5 RESISTIVITY $ ARC5-475 LIS Tape VerJ~|cat|on Listing Schlumberger Alaska Comput|ng Center 24-JAN-1996 09:10 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 6.750 5160.0 WATER BASED 10.00 56.0 3.450 72.0 2.630 72.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 200~0 REMARKS: ****BIT RUN ONE********** DRILLED INTERVAL 5172~ TO 8866~ BIT TO GR: 47.67~, BIT TO 42.77~ SOFTWARE IDEAL 40BBO3/SPM 40BOS/TS 40B16/DH 40B09 LOG DEPTH SHIFTED TO SWS CBL 2-JAN-96 AT AK ICS WELL TD~D 13-DEC-95. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 $ 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 LIS Tape Veri~|cat|on Listing Schlumberger Alaska Computing Center 24-JAN-~996 09:10 PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 0 66 1 SET TYPE - CHAN ** NAME SERV ID UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT ROP LW1 FET LW1 GR LWl RPXX LW1 RPX LW1 RPS LW1 RPM LWl RPD LWl FT eO 00e 00 0 2 1 1 4 68 F/HR 00 e00 00 0 2 1 1 4 68 HR 00 000 00 0 2 1 1 4 68 GAPI 00 000 0~ 0 2 1 1 4 68 OHMM 00 000 00 0 2 1 1 4 68 OHMM 00 0~0 ~ 0 2 1 1 4 68 OHMM 00 ~0 00 0 2 1 1 4 68 OHMM 00 ~0~ 00 0 2 1 1 4 68 OHMM 00 0~0 ~0 0 2 1 1 4 68 DATA DEPT. RPXX.LW1 RPD.LWl DEPT. RPXX.LWl RPD.LWl DEPT. RPXX.LWl RPD.LWl DEPT. RPXX.LW1 RPD.LW1 8864.5~0 ROP.LW1 68.276 FET.LW1 6.031 3.806 RPX.LW1 4.039 RPS.LW1 4.166 4.019 8750.000 ROP.LW1 110.000 FET.LW1 0.269 2.588 RPX.LW1 2.737 RPS.LW1 2.775 2.760 7000.000 ROP.LW1 180.000 FET.LW1 0.169 2.428 RPX.LW1 2.554 RPS.LW1 2.555 2,527 5250.000 ROP.LW1 180.000 FET.LW1 ~.1e0 3.220 RPX.LW1 3.438 RPS.LW1 3.465 3,368 DEPT. 5095.500 ROP.LW1 180.000 FET.LWl 0;~0~ RPXX.LW1 231.569 RPX.LW1 1000.000 RPS.LW1 1000.000 RPD.LW1 1000.~00 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 GR.LWl RPM.LW1 99.258 4.127 112.446 2.749 108.809 2.508 89.793 3.385 10.495 1000.000 END OF DATA LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen~er 24-JAN-~996 09:10 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/01/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 96/01/24 ORIGIN : FLIC TAPE NAME : 95406 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 3R-26, AP1 #50-029-22626-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 96/01/24 ORIGIN : FLIC REEL NAME : 95496 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 3R-26, API #59-929-22626-99
