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196-080
Keu 2,�-t - 3s Regg, James B (CED) Prb rtw From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, June 13, 2020 11:24 AM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay, Brooks, Phoebe L (CED); Wallace, Chris D (CED) Subject: KRU 1 M pad SW MITIA's 6-12-20 Attachments: MIT KRU 2M PAD pg 1 06-12-20.xlsx; MIT KRU 2M PAD SI WELLS 06-12-20.xlsx All, Attached are the 10-426's for the SW MITIA's performed on 2M pad 6-12-20. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM Canoor�CNrps STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reoa2"salaska.aov AOGCC.InsoectorstFtalaskaccv phoebe. brooksealaska.00v OPERATOR: ConocoPhillips Alaska Inc FIELD / UNIT / PAD: Kuparuk / KRU / 2M Pad DATE: 06/12/20 OPERATOR REP: Beck / Green AOGCC REP: 60 Min. chris.wallaceLWalaska. aov Well 21M-30 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fort PTD 1920840 Type Inj N Tubing 1500 1500 1500 1500 N = Not Intact, - Type Test P Packer TVD 5980 BBLPump 3.0 IA 350 3300 3230 3210 Interval V Test psi 3000 BBL Return 3.0 OA 180 180 180 180 Result P Notes: MITIAto maixinum anticipated injection pressure per A102C. 045 Well 2M-35 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1960800' Type Inj N Tubing 1 1225 1225 1225 1225 — Type Test P Packer TVD 6192 BBL Pump 2.3 IA 550 2000 ' 1960 1960 Inteival 4 Test psi 1548 BBL Return 2.3 OA 400 430 - 430 430 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test 1=Initial Test P=Pass G=Gas O= Other(describe in Notes) 4=Four Year Cycle F=Fort S=Slurry V= Required by Variance 1=lnconGusive I = Industrial Wastewater O = Other (describe in notes) N = Not Intact, - Form 10-426 (Revised 01/2017) MIT KRU 210 PAD SI WELLS W-12-20 i • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J DATE: Friday,May 19,2017 Jim Regg Q� P.I.Supervisor J 5 I Lid( 7 SUBJECT: Mechanical Integrity Tests (( 6 CONOCOPHILLIPS ALASKA INC 2M-35 FROM: Lou Laubenstein KUPARUK RIV UNIT 2M-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-35 API Well Number 50-103-20243-00-00 Inspector Name: Lou Laubenstein Permit Number: 196-080-0 Inspection Date: 5/16/2017 Insp Num: mitLOL170516170835 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-35 Type Inj G TVD 1 6192 , [Tubing 3647 - 3647 - ( 3643 3640 PTD 1960800 Type Test SPT Test psi l 1548 ' IA 570 , 2000 - 1970 1960 ----- -------- -------- -- BBL Pumped: 2A -BBL Returned 2.4 OA 200 220 - 220 230 Interval 4YRTST P/F P v Notes: SCANNED JUi, : 20 ; Friday,May 19,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Regg P.I.Supervisor c (15/it., SUBJECT: Mechanical Integrity Tests I CONOCOPHILLIPS ALASKA INC 2M-35 FROM: Jeff Jones KUPARUK RIV UNIT 2M-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry c_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-35 API Well Number 50-103-20243-00-00 Inspector Name: Jeff Jones Permit Number: 196-080-0 Inspection Date: 6/3/2016 Insp Num: mitJJ160608074327 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-35 Type Inj N TVD 6192 • Tubing 2250 - 2450 - 2450 . 2425 - PTD 1960800 Type Test SPT Test psi 1548 - IA 570 2900 . 2840 - 2840 Interval 4YRTST P/F P OA 70 70 70 • 70 Notes: 1 well inspected,no exceptions noted. - SCANNED DEC 2 9 2016 Thursday,June 09,2016 Page 1 of 1 • ZCIA O ai WELL LOG TRANSMITTAL#903059864 To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED y Anchorage, Alaska 99501 IV 'S' M BENDER FEB 10 2015 C RE: Multi Finger Caliper, Jewelry Log: 2M-35OGC Run Date: 1/15/2016 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 2M-35 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20243-00 Multi Finger Caliper, Jewelry Log (Field Log) 1 color log-each 50-029-20243-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating E1 Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:1 /)`/4 4ia-h.0L. I5 .e.iaaC Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~ ~ .O~File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages' Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~incent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si MEldI®RANDUlVi To: Jim Regg '7 P.I. Supervisor ~~j ~ b~~~l ~rU FROM: Jeff Jones Petroleum Inspector State Df Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 SUBJECT: Mechanical Inteo ity Tests CONOCOPHILLIPS ALASKA INC 2M-35 KUPARUK RIV UNIT 2M-35 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~(~ Comm Well Name: KUPARUK RN UNIT 2M-3s API Well Number: 50-103-20243-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ08061 O 13 t 103 Permit Number: 196-080-0 Inspection Date: 6/2/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j _zM-3s (Type Inj %~ i TVD _ 6192 IA Iooo !~ zozo ~ zolo ~ zolo P.T. i 1960 TypeTeSt SPT j TCSt pSl ~ 1548 /~ OA 780 i 910 920 ~ 9~0 ~ '- ---- 4YRT Interval __ST __ -P/F____ P '~ Tubing ~ zs9s i zs9s t- zs9s ~ zs~s 1 -_ Notes: 1.6 BBLS diesel pumped; no exceptions noted. _ ___ ___ ~. ~A1etN~~ JUL ~ s~ 2008 Wednesday, .lone l 1, 2008 Page 1 of 1 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 22, 2008 12:20 PM To: 'Gober, Howard B (ConocoPhillips)' Cc: 'Jerome Eggemeyer; Regg, James B (DOA) Subject: 2M-35 (196-080) Howard and Jerome, I am copying this to both of you as a start. 1 suspect there may be others that you will copy. I am reviewing the 404 report for the tubing workover conducted in March 2008. It appears that the work went well. When the new tubing string was run on March 12, the tubing and annulus were pressure tested #0 2500 psi. Whlle 2500 psi is in excess of the required IA pressure test of .25 psilft x T'VD, the value seems low and in fact is 500 psi less than the MIT conducted on 4/22. The 2500 psi also is less than the pressure tests conducted on new wells. Does CPAI have a standard pressure test value for tubing and IA tests? Is there a difference whether a well is new versus a workover? Also, since this well is listed as WAG, it seems that the tubing pressure on MI could be greater than 2500 psi. If a tubing. leak were to develop on MI, it seems plausible that the IA could also see pressure in excess of 2500 or even 3000 psi. What standard does CAPI have with regard to tubular pressure-tests that possibly will be less than the ultimate operating pressure. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC SCANNEp MAY 2 2 2008 5/22/2008 sf RECEIVED STATE OF ALASKA ~ (VIQY ~ 1 2~~8 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOa Oi18 Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ~ ( Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ~ ~ Perforate New Poot ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work:. 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 196-080 / ' 3. Address: Stratigraphic ^ Service ^~ 6. API Number. P. O. Box 100360, Anchora e, Alaska 99510 50-103-20243-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 106' 2M-35 ' 8. Property Designation: 1 O. Field/Pool(s): ADL 25589 - - Kuparuk River Field / Kuparuk Oit Pool 11. Present Well Condition Summary: Total Depth measured 14908' - feet true vertical 6478' - feet Plugs (measured) 14480' Effective Depth measured 14703' feet Junk (measured} true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 3975' 9-5/8" 4016' 2791' B-SAND LINER 3949' 7" 14895' 6469' Perforation depth: .Measured depth: , 14562'-14595', 14630'-14660' true vertical depth: 6254'-6275', 629T-6316' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 14490' MD. Packers & SSSV (type & measured depth) pkr= Baker FHL retriev. Pkr, BAKER'SAB-3' PERM. 4463' Camco'DS' nipple @ 47T 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 797 14. Attachments 15. WeII Class after work: Copies of Lags and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^Q 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. 308-066 Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature Phone Date ~l ~lp~j h ke 63-4 1 Form 10-404 Revised 04/2006 nRIGINAL KC3l~VI~ tit't~ MAY 2 2 ZDD9 ~~ ~2 Submit Original Only - ConotoPhil~ips Time Log Summary WruvJew Web Reporting Well Name: 2M-35 Job Type: RECOMPLETION Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/07/2008 15:00 17:00 2.00 MIRU MOVE DMOB P Moved Nordic 3.rig off of 1 R-04. Move Nordic 3 rig from 1 R pad to the 1 R exit on S ine road 17:00 1'9:00 2.00 MIRU MOVE WOCC P Wait on Kuparuk Field change out. 19:00 00:00 5.00 MIRU MOVE MOB P Road rig from 1R exit to 2C Pad. 03/08/2008 00:00 02:30 2.50 MIRU MOVE MOB P Continue rig move from.1R Pad to 2M Pad. Status: Rig moving from 2C pad to CPF 2 02:30 03:30 1.00 MIRU MOVE OTHR T Clear snow drifts from road to 26 Pad 03:30 10:00 6.50 MIRU MOVE MOB P Continue rig move from 1R Pad to 2M Pad. Status: Moving rig ftom CPF 2 to 26 Pad. Hang tree in cellar. Spot and level rig. Berm up cellar, spot cutting box, drop tarps. RU hardline to kill tank. Accept rig Nordic. 3 @ 10:00 3-8-2008. 10:00 13:00 3.00 COMPZ MOVE RURD P Move camp from 1 R pad to 2M pad and set up. 24 hr Notice given to AOGCC for BOP test @ 10:30 am. -Camp on location @ 13:00 hrs. Continue to RU. Attempt to load 9.6# brine from tanks but valve froze. 13:00 15:30. 2.50 COMPZ RPCO NUND P Set heater and thawed line. Transfered 9.6# brine to pits. RU lubricator and uli BPV. Monitor weil, 600 psi SITP- 600 si SIAP. OA 150 si. 15:30 19:00 3.50 COMPZ RPCO CIRC P PJSM onwelikill Contact DSO, CPF 2 control room and KRU Security of venting gas. Pressure test lines. Bleed pressure from wellhead to 0 psi. Circulate out the diesel in the wellbore and replace it with 9.6# ppg brine with 0.6% SafeLube. Circ @ 5 bpm @ 1,000 si. 19:00 19;30 0.50 COMPZ RPCO OWFF P Monitor well for flow (Dead). 19:30 20:00 0.50 COMPZ RPCO OTHR P Blow down lines to kill tank 20:00 20:30 0.50 COMPZ RPCO OTHR P . Install BPV 20:30 22:30 2.00 COMPZ RPCO NUND P Mark and take pictures of tree for ro er orientation and install. ND Tree 22:30 00:00 1.50 COMPZ RPCO NUND P !VU BOPE and instal131/2 Upper Pipe rams. 03/09!2008 00:00 01:30 1.50 COMPZ RPCO NUND P NU BOPE --- Rage 1 of 3 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/09/2008 01:30 09:00 7.50 COMPZ WELC BOPE P Witnessing of BOP test waived by John Crisp (AOGCC) @ 1:10 am. Pressure test BOPE to 250/4000 psi and the annular to 250/2500 psi. All tests ood. 09:00 10:00 1.00 COMPZ RPCO NUND P Pull test plug. Pull $PV. MU landing.:. 't in han er. BOLDS. 10:00 11:00 1.00 COMPZ RPCO OTHR P Pulled hanger out of bowl, PU to max wt. 200K (166K, 80% of yield plus block wt. 35K). Worked pipe up and down attem tin to break loose still solid. Kicked on pump circulate @ 5 BPM w/850 psi. Worked pipe up and down while pumping with no movement. 11:00 13:00 2.00 COMPZ RPCO CIRC P Pulled 200K and set brake,. circulate 5 BPM wl850 psi while waiting on E-line, worked pipe up and down every 5 min. Came loose and pulled hander to ri floor with 44 .Monitor well for flow, no flow, well dead. 13:00 00:00 11.00 14,423 b,665 COMPZ RPCO PULD P ND hanger and landing jt. POOH laying down 3-1/2" tubing and jewelry. ( Located patch @ 224 jts from surface.) Two visible holes in middle of the 't with atch. 03/10/2008 00:00 09:00 9.00. 5,665 COMPZ RPCO PULD P Continue to POOH laying down 3-1/2" tubing and jewelry. Out of hole with 14.11' of jt cut with'chem cutter. Good clean cut: 09:00 10:00. 1.00 COMPZ RPCO PULD P Complete Clearing pipe shed kicking out old completion and preying pipe shed for new i e. 10:00 00:00 14.00 COMPZ RPCO OTHR P Load i e shed with 14 450' of new 3-1/2' L-80 EUE tubin .Drift and strap same. 03/11!2008 00:00 03:00 3.00 COMPZ RPCO OTHR P Continue to Load pipe hed with 14,450'. of new 3-1/2' L-80 EUE tubin .Drift and stra same. 03:00 03:30 0.50 COMPZ RPCO SFTY P PJSM on PU and Rih w/ 31/2 Com letion 03:30 13:30 10.00 0 6,350 COMPZ RPCO RCST P PU and Rih w/ 31/2 Completion 13:30 22:30 9.00 6,350 14,412 COMPZ RPCO RCST P Continue PU and Rih w/ 31/2 Completion to 14,412' 105k up wt. 68k do Block wt. 35K 22:30 23:30 1.00 14,412 14,421 COMPZ RPCO RCST P Located top of stub @ 14,445' and seen 5k shear on overshot and pogo 14,421'. Pump down IA to verify 210 si off stub and 450 si overstub. 23:30 00:00. 0.50 14,421 14 COMPZ RPCO CIRC P Reverse circulate 10 bbls of 1°~ MI ConCore (corrosion inhibitor) and follow w/ 370 bbls of-9.6 ppg brine. 2.5 b m 310 si. 03/12/2008 00:00 02:00 2.00 14 14 COMPZ RPCO CIRC P Continue to reverse circulate. and spot. 10 bbl pill of MI ConQoi• (corrosion Inhibitor Rage2n: a ~~ Time Lo s Dat From To Dur S. D th . De th P e Cod Subcode T O 03/12/2008 02:00 02:30- 0.50 14 14 COMPZ RPCO PACK P Pressure to 2,500 psi and set FHL acker 44,333 ; PB , Bottom of overshot @ 14,420 w/Top of stub @ 14,415'. Shear out of PBR @ 10k osw and bleed off pressure to 450 psi. Pulf seals from PBR and locate the top. Open bleeder and Rih andveri to of PBR. 02:30 03:30 .4.00 14 0 COMPZ RPCO HOSO P S ace out and MU han er and Rih to top of PBR. Up`wt 102K Dwn wt 65K Block wt 35K. 03:30 04:00 0.50 COMPZ RPCO SFTY P PJSM on circulating seawater containing 1 % MI ConQor (corrision inhibitor) and displacing kill fluid. and MSDS sheet location orrthis new roduct. 04:00 05:30 1.50 COMPZ RPCO CIRC P Circulate seawater w/1% MI ConQor (corrosion inhibitor) and displaced 9.6# kill fluid. A5:30 06:00 0.50 COMPZ RPCO HOSO P Up wt 102K Dwn wt 65K Block,wt 35K. Land han er and RILDS. 06:00 09:00 3.00 COMPZ RPCO DHEO P PJSM. RU manifold to test tbg and. casing. Pressured tubing to 2500 psi for 15 min (charted}. Bled tubing pressure to 1750 psi.. Pressured to to 2500 si for 30 min jcharted). Bled tubing pressure to O psi shearing SOV @ 4498`. Bled lA off to 0 psi. Flushed lines and blow down same. Back out and LD landin 't. Set BPV. 09:00 16:30 7.50 COMPZ RPCO SFEQ P ND BOP stack. NU 3-118" 5M tree. Pull BPV, set test plug. Pressure test tree. to 250/5000 psi. Test packoff to 250/5000 si. PuN tree test lu . 16:30 20:00. 3.50 COMPZ RPCO FRZP P RU LRS. Pumped 106 BBIs diesel down annulus for freeze protect taking returns. from tubing to kill tank. Hook up jumper hose from IA to tubing and allow diesel to equalize freeze protecting to 3113' MD (2500' TVD) RD Cellar lines. 20:00 21:00 1.00 COMPZ RPCOti OTHR P Set BPV and Shut well in. Opsi on tbg, IA and OA. Release rig @ 21:00 hrs on 3-12-08 Pane 3 of 3 CvnocoPhllips Alaska, Inc. KRU 2M-35 2M-35 Pre-Rig and Post-Rig: Events DATE SUMMARYOPS 12/30/07 T-POT -PASSED, T-PPPOT -FAILED, LDS FUNCTION TEST -PASSED 2/24/08 PRESSURE TEST CA-2 PLUG @ 14480' RKB TO 2500 PSI (GOOD TEST ). DUMP BAIL 3' OF SLUGGiTS ONTOP OF CA-2 PLUG @ 14480' RKB. (( IN PROGRESS )). 2/25/08 PULLED DGLV FROM STA# 5 @ 13417 RKB (LEFT POCKET EMPTY ). 3/2/08 SHOT A 1 STRAND 80gr PRIMACORD STRING SHOT FROM 14428' TO 14440' CUT 3 1/2" TUBING AT 14438' WITH A 2 1/8" EXTENDED REACH CHEMICAL CUTTER 3/4/08 (PRE RWO) IC POTlPPPOT-(PASSED). 3/20/08 PULLED SOV @ 4498' RKB, SET bV @ 4498' RKB, PASSED MITIA TO 2500, , PULLED CAT SV @ 14,375' RKB, BAILED ON PLUG @ 14,431' SLM, IN PROGRESS. 3/21/08 BAILED FILL FROM 14,434' SLM TO 14,437 SLM, HAD MARKS ON BAILER BOTTOM. LOOKS LIKE POSSIBLE 13/4" FISH NECK FROM CA-2 PLUG. IN PROGRESS. 3/22/08 PULLED EQ-PRONG FROM CA-2 PLUG @ 14,480' RKB, IN PROGRESS. 3/23/08 TAGGED HYDRATES @ 3317 SLM. UNABLE TO PUMP INTO WELL. RDMO. 3/27/08 REMOVE ICE PLUG FROM 3320' CTMD TO 41'..90' CTMD.DRIFT TUBING DOWN TO 6000' CTMD / 3410' TVD.LEFT WELL SHUT AND FREEZE PROTECTED FOR .UPCOMING SLICKLINE WORK. 3/28/08 TAGGED ICE IN TREE. PUT HEATER ON TREE. IN PROGRESS. 3129/08 ATTEMPTED PULL CA-2 @ 14480' RKB; UNABLE TO LATCH UP. BAILED INJECTION .RESIDUE OFF PLUG. IN PROGRESS. 3/30/08 PULLED 2.25" CA-2 @ 14480' RKB. TAGGED @ 14705' RKB, EST. 45' RATHOLE. COMPLETE. 4/20/08 MITIA- PASSED (PRE INTIAL STATE WITNESSED POST RWO). 4/22/08 MITIA- PASSED (STATE WITNESSED, ROBERT NOBLE) MEMORA.NDUNI i To: JimRegg ~~~;~~ ~ ~Z~?~~~c:,, P.I. Supervisor ~~ ~ t~ Fxolvt: Bob Noble Petroleum Inspector State of Alaska • Alaska OiI and Gas Conservation Commission DATE: Thursday, Apri{ 24, 2008 SUBJECT: Mechanical [ntegrity Tests CONOCOPHILLIPS ALASKA PVC 2ti1-35 KUPARUK R1V UNIT 2M-35 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~:5~~ Comm Well Name: KUPARUK RN UMT 2M-3~ Insp Num• mitRCN080423083506 Rel Insp Num: API Well Number: 50-I03-20243-00-00 Inspector Name: Bob Noble Permit Number: 196-oso-o Inspection Date: ~i22i2oo8 Packer Depth Pretest Initial 15 Min 30 Min. 45 Min. 60 Min. - -- -- -- Well zN[-3s ~iTYPe Inj. w TVD i, 6>>z IA '~ iaao 3000 ~~ a96o z96o 3000 ~' i00 900 900 P.T i96oaoo !TypeTest sPr ' Test psi ~. BOA - -_- _ - ~~ 900 j ~ Interval tNtTAL P/F r Tubing z3zs ~ ?3as ~, 2325 X325 Notes: c~~~ ~~-~ ~ ~ Z~a~ Thursday, April 24, 2008 Page I of 1 • • ...~ ~ sa RAH PALIN, GOVERNOR ~~ O~ t~i`L ~ 333 W. 7th AVENUE, SUITE 100 CO1~S~R~A7'I011T COI~IIrIISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Group Engineer ConocoPhillips Alaska, Inc. d PO Box 100360 Anchorage, Alaska 99510 1 b~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M-35 Sundry Number: 308-066 ~~~ MAR ~ `~ 200 Dear Mr. Gober: 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, ~~~ Darnel T. Seamount, Jr. // Chair DATED this 2-~~da'yl of February, 2008 Encl. • • ~~ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 25, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage, Alaska 99501 1=~ ~ 2~1~ Alaska Cliff ~ ~~ mans, ~nmmissian Anchorage Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2M-35 (PTD# 196-080)_ Injecting well 2M-35 has been shut-in since May of 2006 because of annular communication due to a tubing leak. The tubing leak was patched, but the patch is leaking. The leak rate is approximately 0.4 bpm at 2500 psi. The well passed a combo MIT on 9/15/06 to 3000 psi. The purpose of the proposed workover is to pull the existing 3-112" L-80 tubing string and replace' it with a new 3-1/2" L-80 tubing string. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220 Sincerely, Howard B. obey Wells Engineer CPAI Drilling and Wells • ORIGINAL ~~ z~ ,D~ STATE OF ALASKA ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIV FFR 2 7 7 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Gornrn~ssion 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver n «~~ Other ^ Alter casing ^ Repairwell Q Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 196-080 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20243-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 2M-35 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25589, ALK 2675 RKB 41', Pad 106' ~ Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total. depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 14908' - 6478' 14703' 14480' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 121' 121' SUR. CASING 3975' 9-5/8" 4016' 2791' PROD. CASING 14851' 7" 14895' 6469' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14562'-14595', 14630'-14660' 6254'-6275', 6297'-6316' 3-1/2" L-80 14490' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- BAKER'SAB-3' PERM. pkr= 14463' Camco 'DS' nipple @ 483' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 10, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Group Engineer Signature Phone 263-4220 Date Z~Z~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: j~q'vtifl ~ ` ('Z ^ ~ ~.5'~" G' .S ~ ~j ' ~~~~~ ~ ~t"~! ~ ~ 200f1 ~ Subsequent Form Required: ~~ ' APPROVED BY ~~Z~/ Approved by: C M ISSIONER THE COMMISSION Date: 6 Form 10-403 ~tevised 06/2006 ' 1 K' ~ I ~\! [~ ~ ~~ it in Dupli to t. Z? ~~ • • Well: 2M-35 API: 501032024300 t~t`1~Ct`~11~~1~15 Field: Kuparuk PTD: 196-080 2008 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3'/2' EUE BPV: 3" FMC ISA Model: FMC Gen 4 CONDUCTOR 16", 62.58 ppf, H-40 SURFACE CASING 9-5/8", 40 ppf, L-80 PRODUCTION CASING 7", 26 ppf, L-80 TUBING 3%", 9.3 ppf, L-80, 8rd EUE Mod, 0' - 14438' (new this workover) 3-1/2", 9.3 ppf, L-80, EUE-8rd Mod, 14438' - 14490' (existing) 14,463' NIPPLE 3-1/2" Camco 2.75" 'D' Nipple with 2.25" nipple reducer @ 14480' RKB PERFS 14562' - 14565', 4 spf 14565' - 14590', 8 spf 14590' - 14595', 4 spf 14630' - 14660', 4 spf E NEW COMPLETION A: Landing Nipple: 2.875" DS profile 500' M D B: Gas Lift Mandrel: No. MD TVD TYPE 1 4500 2945 1" KBMG 2 -14305 6298 1" KBMG C: PBR, stack packer, and poorboy overshot @ 14,372' RKB D: Nipple: 3%" with 2.813" DS profile E: Poorboy overshot F: Nipple: 3%2" with 2.813" W-1 profile G: Nipple: 3%2' with 2.75" D profile and 2.25" nipple reducer Last Tag: 7/31/06 Tag Depth: 14,703' RKB Fill: 43' rathole TD: 14,908' RKB Last Updated: 18-Feb-08 Updated by: HBG • Sundry RWO Procedure 2M-35 Kuparuk Injector Repair Tubing Leak PTD# 196-080 • Procedure Outline 1. Pressure test plug @ 14480' RKB to 2500 psi and bleed down pressure to 0 psi for negative pressure test. 2. Dump bail 3'-5' CaC03 on top of plug. 3. Pull DV @14409' RKB. Leave open pocket. Load well with 9.6 ppg brine containing 0.6% SafeLube. 4. Chemical cut tubing @ 14438' RKB in the middle of the first full joint above the packer. 5. Set BPV. 6. MIRU Nordic #3. 7. Ensure well is dead. ND tree, NU and test BOP. NU 11", 5M BOPE with 2 sets of pipe rams for 3.5" tubing. Pressure test BOPE to 250/4000 and annular to 250/2500 psi. Maximum anticipated surface pressure is 3745 psi based on SBHP of 4374 psi at 14600' RKB (6278' TVD) obtained 7/27/06. ~ ~3<~-t ~.M~ 8. Pull 3-1/2" tubing and lay it down. .~~ ~a~~sSwe~c~.~ ~~~~ w~~d:~N.v ~ ~~,~~~ 9. Run FHL packer and PBR with poorboy overshot on new 3-1/2" L-80 tubing. Locate tubing stub +(~.SS~ with poorboy overshot. , a ~o ~~ 10. PU and circulate corrosion inhibited brine. RIH and go over stub with poorboy overshot. Set FHL packer. ~~~ 11. Shear PBR. Space out and land completion. ~~~~~~~~~ `~~ ~~~l~sz ~ 12. Pressure test tubing and IA. 13. ND BOP, NU and test tree. 14. Freeze protect well. 15. RDMO Nordic #3. ~.. G- ~~'~ 16. Pull ball and rod. Pul! SOV and run DV. PuII RHC body. Bail CaC03 from on top of plug. Pull plug and nipple reducer at 14480' RKB. • • ~! • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 JAN 0 8 ZOOS Alaska Oil & Gaa Conn, OQ~rian January 6, 2008 Ancharaga Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 (~~ Anchorage, AK 99501 ~~~!' ~~ 1~N ~ ~ ~~~~ Deaz Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annulaz void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annulaz 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 top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similaz manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ,~ Perry ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Well Name PTD # Initial top of Vol. of cement Final top of Cement top cement um ed cement date 2M-01 192-103 ft 21' 7" bbls 3.0 ft 12" na 12/25/200 2M-10 191-131 4" na 4 ~~ 2M-11 191-137 13" na 13" na 2M-12 192-090 6" na 6" na 2M-13 191-142 12" na 12" na 2M-15 191-033 24" na 24" na 2M-21 191-129 2M-24 192-050 8' 6" 1.1 12" " na 12/25/200. 2M-25 191-021 30" na na 6 30" na 2M-31 196-077 SF na g~~ na 2M-32 192-104 10' 4" 1.5 12" na 12/25/2007 2M-33 196-072 SF na g~~ 2M-34 196-0 SF na g~~ na 196-080 SF na g" na ~ ~ ~~~ na „ ~'°" / A 8/7/2007 Corrosion Corrosion inhibitor/ 6 8 5.5 3 5.5 6 4 5.5 11 1 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~~f ~~~ { ~~~~ ~~e'l;i~ ~ ~ ~? ';; . ~ ~ ,. ~r..T3~iii~~~0~? September 30, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~, NG~ ~ 9 20D7 ~ ~CU~ ~3 .~ laska, Inc. presents the proposals as per AIO 2B, Rule 9, to apply for Administrative lls lI~-16A (PTD 201-209) and 3A-11 (PTD 185-2 main in water only injection service wl annular Also attached is a 10-404 Report of Sundry Operations for 2M-35 (PTD 196-080, Sundry # 306-390) for an OA cement shoe. Given that the MITOA pressure test failed to pass, a supplementary 10-404 will be filed if additional remediation is completed to attain a passing test. If you need additional information, please contact me at 659-7043, or Brent Rogers / Perry Klein at 659-7224. Sincerely, f;- i,- MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments -~~ ~ - - ~ ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~- ~ ~~ ~~~~ REPORT OF SUNDRY WELL OPERATIONS , ~~r .~ ; ,, -_~„_. ~n,~~„M~w~ 1. Operations Performed: Abandon ^ Repair 1Nefl Q Plug Perforations ^ Stimulate ^ Other ^ V 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: COnOCOPhIIIIpS Alaska, InC. Development ^ Exploratory ^ 196-080 / 306-390 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20243-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 147' 2M-35 8. Property Designation: 10. Field/Pool(s): ADL25589 ALK 2675 Kuparuk River Field / Kuparuk Oil Pool 11, Present Well Condition Summary: Tota! Depth measured 14908' feet true vertical 647'8' 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 3869' 9-5/8" 4016' 2791' PROD. CASING 14748' 7" 14895' 6469' Perforation depth: Measured depth: 14562'-14.595', 14630'-14660' true vertical depth: 6254'-62i'5', 6297-6316' Tubing {size, grade, and measured depth) 3-1/2" , L-80, 14490' MD . Packers &SSSV (type & measured depth) pkr= BAKE:R'SAB-3' PERM. pkr= 14463' SSSV= N1P SSSV= 483' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured) Treatment descriptions including volumes used and final pressure: ~p~ ~{ ~ ~ ~ ~~D~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: 306-390 contact M J Loveland / Perry K ein Printed Name M J Lovel ,~ Title Problem Well Supervisor Signature G'Y( '' ~~~°' Phone 659-7043 Date 9/30/2007 Form 10-4 4 Revised 04/2004 ~ ~ ~ ~ i ~ A ~ ~~d't~ Submit Original Only .. ~ .. ~ • 2M-35 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/2/2007 8/5/2007 PUMPED OA CEMENT SHOE WITH 42 BBLS OF 15.8 CLASS G AND CemNET. DISPLACED WITH DIESEL AND LEFT 1180 PSI ON OA State W itnessed (Robert Noble) MITOA failed. Pressured up OA with 2 bbls diesel. T/I/0= 500/500/1800. Pressure fell off rapidly @ 40 psi per min @ 1800 psi. Re-pressured OA with additional .2 bbls diesel. Pressure fell off @ same rate. Repeated test one additional time with same results. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~ ~, ~ ~~~I~~ DATE: Aug 5, 2007 P. f. Supervisor ~ ~ FROM: Bob Noble Petroleum Inspector SUBJECT: MIT Combo KRU 2M-35 CPA PTD - 196-080 Aug 05, 2007: Witnessed a MIT combo on KRU 2M - 35. Well has known tubing to IA communication. Well also had a new cement job done on OA shoe. CPA pressured up the OA to 1800 psi. It had a leak off rate of 40 psi a min. at 1800 psi. They then tried aTubing/IA X OA MIT. Pre T/I/0=450/450/500, Initial T/I/0=2875/3010/975, 15 min T/I/0=2860/3000/950, 30 min T/I/0=2840/2970/940, 45 min T/I/0=2840/2960/935. Attachments: MIT-OA; CMIT IAxOA I~~~~ ~Q'f ~ X007 2007-0805_MIT_KRU_2M-3 5_summary_bn. doc MEMORANDUM . State of Alaska • Alaska Oil and Gas Conservation Comm~ss~on ,,,., DATE: Friday, September 07, 2007 TO: Jim Regg ~- I'e,~/;.~'' ~' ~%',~~I~ SUBJECT: Mechanical Integrity Tests P.I. Snpervisor CONOCOPHILLIPS ALASKA INC 2M-35 FROM: Bob Noble KUPARUK 12IV UNIT 2M-3s Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~--'~='~-- Comm Well Name: KUPARUK RIV UNIT 2M-35 API Well Number: 50-103-20243-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070806132814 Permit Number: 196-080-0 Inspection Date: 8/5/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well '~ 2M-3s Type Inj. ~ N I TVD I - 6I9z ~ IA j aso~ soo j ; _ I 1960800 SPT~ -t P.T.Dj jTypeTest ! i Test psi - 1800 QA ~ 0 ~ 1800 ~ I ' j I ~ Interval OT1~R PJF F / ^. ~ '_ Tubing's aso i soo - NOtes' They were doing aMIT-OA on the well as they just recemented the OA shoe. We did not com plete the test becouse OA was loosing 40 psi a min at 1800 psi. Friday, September 07, 2007 Page 1 of 1 MEMORANDUM • To: Jim Regg ~~j, ~ i~ ! ~y~ l~ 7 P.I. Supervisor 1 FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, September 07, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-35 KUPARUK RIV UNIT 2M-35 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.,_ Comm Well Name: KUPARUK RIV UNIT 2M-35 API Well Number: 50-103-20243-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070806133436 Permit Number: 196-080-0 Inspection Date: 8/5/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2M-35Type Inj. ~ N ~ T~ I 6192 I jA ! 450 ~ 3010 ~ ~ 3000 2970 '~ 2960 I P.T.D{ 1960800 ~TypeTOSt ~ SPT ~ 'l'est pS1~~3010 'i OA ~ 500 ~ 975 ~ 950 i 940 ~ 925 Interval OTI~R P~' ~~ Tubtng~ 45Q ~ 2875 ~ 2860 ~ 2840 I 2840 ~ Notes' Well has known Tubing to IA communication. Well has had a recemented shoe that did not pass MIT-OA. I did not put pass or fail as the well has problems. Friday, September 07, 2007 Page 1 of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg '-;? { I P.I.Supervisor ¡jr2t1 g i(., 07 DATE: Thursday, August 09, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 2M-35 KUP.A.RUK RIV UNIT 2M-35 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv..:::B,L Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-35 Insp Num: mitRCN070806I32814 Rei Insp N um: API Well Number: 50-103-20243-00-00 Permit Number: 196-080-0 Inspector Name: Boh Nohle Inspection Date: 8/5/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 2M-35 ¡Type Inj. I N 1 TVD ! 6192 VilA ! 450 ! 500 I i I I P.T. 1960800 [TypeTest 1 SPT i Test psi i 1800 /1 OA: 0 i 1800: I I Interval OTHER P/F F /' Tubing i 450 : 500 Ii! I Notes: They were doing a MIT-OA on the well as they just recemented the OA shoe. We did not complete the test becouse OA was loosing 40 psi a v min at 1800 psi. ~CANNED AUG 232007 Thursday, August 09, 2007 Page I of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor l<c7'l 'b jlblOJ ¡ DATE: Thursday, August 09,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-35 KUP ARUK RIY UNIT 2M-35 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-35 Insp Num: mitRCN070806133436 Rei Insp N urn: API Well Number: 50-103-20243-00-00 Permit Number: 196-080-0 Inspector Name: Bob Noble Inspection Date: 8/5/2007 Packer Depth / Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6192 I IA 450 i 3010 i 3000 ! 2970 I 2960 I I I i I I -1-. I 3010 i OA I 500 I 975 I 950 I 940 I 925 i I I Tubing I 450 I 2875 I 2860 I 2840 I 2840 ! I -- I Well I 2M-35 P.T. ! 1960800 Interval ¡Type Inj. I N i TVD I !TypeTest I SPT i Test psi i P P/F OTHER Notes: Well has known Tubing to IA communication. Well has had a recemented shoe that did not pass MIT-OA. I did not put pass or fail as the well has problems. ¡V\J.1- ,~,-tël: \eJ r:r A11G 2, 31JØS\ SCAANþ.~ V Thursday, August 09, 2007 Page 1 of I ;. . SARAH PALIN, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IMISSION i 333 W. 7th A VENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F~'!( (907) 276-75423 Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 fJ" ~ .~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M-35 Sundry Number: 306-390 ~f3 Dear Ms. McConnell: 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 this6day of December, 2006 Encl. . ~/ ConocoPhillips Alaska . P.O. BOX 100360 . ANCHORAGE, ALASKA 99510-0360 RECEIVED DEC 1 3 2006 December 12, 2006 Alaska Oil & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7ili Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 A lications for Sundry Approval for ConocoPhillips .ltAlaska, Inc. well 2M-35 (PTD 196-080) and 3K-30 (PTD 197-113) to seal the outer L' annulus open shoes Wit cemen. As noted on the application, verbal approval was granted for 3K-30 on 12/11/06. Please call Perry Klein or me at 659-7224 if you have any questions. Sincerely, ~?¡ ;Ø~ß"~ Marie McConnell Problem Well Supervisor Attachments 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 WaivJ'nC~ge . Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 r''-'~ Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 C~ h.. 2. Operator Name: 4, Current Well Class: 5. Permit to Drill Number: ~;. ,\,~ .. ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 196-080 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20243-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes n No 0 2M-35 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit RKB147' 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): 14908' - 6478' - Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 3869' 9-5/8" 4016' 2791 PROD. CASING 14748' 7" 14895' 6469 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Intervals between 14562 - 14660' Intervals between 6254 - 6316' 3-1/2" L-80 14490' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER 'SAB-3' PERM. pkr- 14463' SSSV= NIP SSSV= 483' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 1, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: W~ GINJ 0 WINJ ,2l WDSPL 0 Commission Representative: ~;; N--I 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marie McConnell / Perry Klein Printed Name Marie McConnell ~///;:.".ð· Title: Problem Well Supervisor .://.;1"~. ~ >Ø Signature '-<"J" ./ Phone 659-7224 Date 12/12/06 '/ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~IJ" õqO Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 'H. \'\ C b... Other: ":t::bf ~O R90MS Sf~r :" '~rìn"'~; --;<j Subsequent Form Required: 1 ;; ZullO <= .~... . -r -/_ . rÆ· t _. ..-; ,".'-".' APPROVED BY Date: I~ -IS" ,. ð6 Approved by: COMMISSIONER THE COMMISSION Form 10-403 Revised 06/20~ ~ or 1\ ~_ ? Submit i~.ßicate c ¿ 'f" 12 ' /1 ,~ (l7:f ./2-/t4-/-, r' . ~¡rrl¡-It-Oro. /{J RECEIVED STATE OF ALASKA ï~ '1. ALASKA Oil AND GAS CONSERVATION COMMISSION DEC 1 3 Z006 APPLICATION FOR SUNDRY APPROV ~~k·· O. & 20 MC 25.280 8S a II Gas Cons. Commission ~¿(ÍtÄ , . . ConocoPhillips Alaska, Inc. Kuparuk Well 2M-35 (PTD 1960800) SUNDRY NOTICE 10-403 REQUEST 12/12/06 The purpose of this Sundry Notice is to notify the AOGCC of Co no coP hill ips Alaska, Inc., intent ,/ to pump a cement shoe in the surface casing of Kuparuk wag injection well2M-35. A surface casing cement shoe was not pumped at the time of original completion in 1996. 2M-35 has been shut-in since a tbg leak resulted in a failed MITIA. The cement shoe is required in order to pressure test the surface casing to verify the surface casing as a secondary barrier after an attempt to patch the tbg leak on 8/12/06 was unsuccessful. The well's primary barrier is the production casing and packer. If the cement shoe is successful, resulting in a passing MIT -OA, an administrative relief request will be submitted for approval to return the well to water only ~ injection. With approval, the OA cement shoe will require the following general steps: 1. Bleed tbg and IA to < 100 psi. (TTP was set on 9/15/06.) 2. Pump 42 bbls of Dowell "Tail" system 15.8 ppg cement into the OA. 3. Displace cement with 85 bbls of water and diesel freeze protection for a calculated cement top at 3016' MD. 4. Wait 48 hrs on cement 5. MITOA to 1800 psi. 6. Submit 10-404 to AOGCC. NSK Problem Well Supervisor 12/12/2006 RECEIVED 09/11/06 SEP 1 2 2006 SC~.~IPger ......... Oil & Gas Cons Commission NO. 3955 ..-a . Anchorage SCANNED SEP 1 4 200B Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 . '--/\ lC'~<O-OOO UJ-'-- Field: Kuparuk Well Log Description Date Color CD Job# BL 2M-35 11213795 lDl 08/16/06 1 1Y-24A 11213786 SBHP 07/25/06 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1 D-06 11249948 INJECTION PROFilE 08/26/06 1 1A-10 11216318 INJECTION PROFILE 08/28/06 1 1J-184 11249951 PRODUCTION PROFilE 08/29/06 1 1 J-127 11249953 PRODUCTION PROFILE 08/31/06 1 1 J-170 11249954 PRODUCTION PROFilE 09/01/06 1 1 G-04 11216321 INJECTION PROFilE 08/31/06 1 1D-12 11216322 PRODUCTION PROFilE 09/01106 1 2F-06 11216320 FLOWING BHP SURVEY 08/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . ~illips Alaska RECE\VED SEP 0 6 2006 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 3,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 1 3 ZDOG Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 2M-35 (pTD 196-080, Sundry #306-232). The report records the unsuccessful tubing patch job. Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. ~/µ MJ Loveland Problem Well Supervisor Attachments i0ro - œo . . RE-CE.\VE.[) SE.P 0 6 LÛ\J¿ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Of .' "",m,"SI ì 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Mas~a QtÞ& Ga\u~:~'" Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Exte~~ ~ Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 196-080 1 3. Address: Stratigraphic 0 Service 0' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20243-00 7. KB Elevation (ft): 9. Well Name and Number: RKB147' 2M-35 8. Property Designation: ~5~ p'(.? 1>1.0 10. Field/Pool(s): Kuparuk River Unit APt.. Kuparuk River Field 1 Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 14908' . feet true vertical 6478' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 3869' 9-5/8" 4016' 2791' PROD. CASING 14748' 7" 14895' 6469' Perforation depth: Measured depth: 14562-14595, 14630-14660 true vertical depth: 6254-6275,6297-6316 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 14490' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SA B-3' PERM. pkr= 14463' SSSV= NIP SSSV= 483' 12. Stimulation or cement squeeze summary: NA RBDMS 8FL SEP 1 1 2006 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation 0 2000 2000 Subsequent to operation 0 2000 2000 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 . Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GlNJ 0 WINJ0 WDSPL 0 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: 306-232 Contact McConnell / Klein Printed Name M~eland ~Title Problem Well Supervisor V?/06 signatur/Ø"1 ~ _ ... Phone 659-7043 Date .~ "/If v - , Form ¿4 :evised 04/2004 0 ~(~ , ~ '1·1·öb I Submit Ori inal 0 RIGINAL g~~ , . 2M-35 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/1/2006ISet 2.75"x2.25" nipple reducer in D profile @ 14480' RKB 8/2/2006ITested tubingl/A with 2.35" CAT Valve - CMIT passed 8/12/2006 Set 3.5" Unique machine pE~rmanent patch with top element @ 7155' and bottom element @ 7176.5'. Patch ID is 2.360" 8/13/2006IMITIA (post patch) Failed 8/16/2006 Perform LD log -locate leak at bottom of patch @ 7176.5' 8/30/2006 Video log known leak at bottom of patch. Unclear whether the leak is an additional hole or whether the bottom seal of the patch is bad. I Well left SI for further diagnostics and planning Re: 2M-35 sundry #306-232 - revise to permanent patch e e Thanks Marie, I will place this message in the file. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 7/14/2006 1 :42 PM: Tom & Jim, If possible, I'd like to make a minor revision for sundry approval #360-232 to patch a tbg leak in injection well 2M-35 (1960800). A permanent patch will be installed rather than a retrievable. Please scratch out the patch type listed in step 1 of the repair plan. At the time I submitted the 403, it was not known if a permanent or retrievable would be used and I had meant to delete the word "retrievable", but missed it. Engineering completed a review of future CTD sidetrack potential and has decided that a permanent patch can be installed without limiting future well bore utility. The post patch 10-404 report will note the patch type as permanent. Thanks, Marie McConnell Problem Well Supervisor 659-7224 10fl 7/17/20069:14 AM ._e ".... r-". . :1 ~ !P U .e ! .! i J ¡ FRANK H. MURKOWSKI, GOVERNOR .J ! /' AIASIiA OIL AND GAS / CONSERVATION COMMISSION / ,i 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Marie McConnell Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2M-35 Sundry Number: 306-232 Dear Ms. McConnell: '~r- ßi. \1 ~ 'c"" ';)v. ,¡ ~ ''\!,¡.". tJ n 'ì ínfH', _., ~, _ -".- 0-.- -oJ 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. DATED this-.l:day of July, 2006 Encl. IS C, ---tfóô .... 1) 'l s 7~5Jb.()(, RECEIVED (jf 1,3 e STATE OF ALASKA e 1-'1 JUN 2 9 Z006 ALASKA OIL AND GAS CONSERVATION COMMISSION > APPLICATION FOR SUNDRY APPRO V A~laska Oil & Gas Cons. Commission 20 MC 25.280 Anchorage 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Peñorate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Peñorations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Peñorate 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 0 196-080 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20243-00 , 7. KB Elevation (ft): 9. Well Name and Number: RKB147' 2M-35 8. Property Designation: ,At>l. 'ZSS"fff' P ".'Z/i.Pb 1 O. Field/Pool(s): Kuparuk River Unit 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): 14908' , 6478' . Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121' SUR. CASING 3869' 9-5/8" 4016' 2791' PROD. CASING 14748' 7" 14895' 6469' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14562-14595,14630-14660 6254-6275, 6297-6316 3-1/2" L-80 14490' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'SAB-3' PERM. pkr= 14463' SSSV= NIP SSSV= 483' 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: 07/01/2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: McConnell 1 Klein Printed Name ~(MC~?nnell // 'tf... ~ Title: Problem Well Supervisor Signature Þ.i ~/~/;X #;!'~;7~¿('/ / Phone 659-7224 Date 06/26/2006 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness l~(.Q .,~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other: \5 CJ \7 Cc.. '\.."ü\ ~ ~~ "'-. -\ ~ ~ \ d "Cd S- \ d&'l RBDMS BFl JUL 0 6 2006 Subsequent Form Required: ~lm ) ~ '¡s(06 -r-} f/f& APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V '><;' I ~ ,. Z"·Þt. Form 1 0-403 Revised 712005 0 R II.] I N A L Submi' Du 'c te i~ ~ ,r~ .,~'Jµ e e ConocoPhillips Alaska, Inc. Kuparuk We1l2M-35 (PTD 196 - 080) SUNDRY NOTICE 10-403 TUBING REPAIR 06/26/2006 This sundry request is for approval to repair ConocoPhillips (CPA) Kuparuk We1l2M-35 with a . tubing patch. On May 10, 2006, the AOGCC was notified of a failed MITIA . Subsequent diagnostics identified a tbg to IA leak. An E-line spinner LDL located the leak in the tbg at 7168'. The plan is to patch the tubing with a 20' patch centered over the leak. Following a successful MITIA, the well will be returned to nonnal WAG injection. . REPAIR PLAN 1. Set a 20' long, 3.5" retrievable patch from 7158" -7178' centered over the leak at 7168'. 2. MITIA as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post repair. NSK Problem Well Supervisor , . e e ConocoPhilUps Alaska, Inc. KRU 2M-35 2M-35 API: 501032024300 Well Type: INJ Angle @ TS: 51 dea (éj) 14545 SSSV Type: Nipple Orig 6/4/1996 Angle @ TD: 48 deg @ 14908 NIP (483-484, Comoletion: 00:3.500 ) Ø1 Annular Fluid: LastW/O: Rev Reason: TAG FILL, set PLUG, TBG LEAK Reference Loa: Ref Log Date: Last Update: 6m2006 Last Taa: 14585 TO: 14908 ftKB Last Taa Date: 5/28/2006 Max Hole Anole: 73 deg @ 8324 Casino Strino - ALL STRINGS Gas Lift .. DescriPtion Size Top Bottom TVD Wt Grade Thread mdrel/Oummy CONDUCTOR 16.000 0 121 121 62.58 H-40 Valve 1 (4162-4163, SUR. CASING 9.625 0 4016 2791 40.00 L-80 00:5.390) PROD. CASING 7.000 0 14895 6469 26.00 L-80 Tubina Strina - TUBING .... Size I Top I Bottom I TVD I Wt I Grade I Thread Gas Lift . 3.500 I 0 I 14490 I 6209 I 9.30 I L-80 I EUE 8RD MOD mdrel/Oummy Perforations Summary Valve 2 Interval TVD Zone Status Ft SPF Date Tvoe Comment (7782-7783, 00:5.390) 14562 ~ 14595 6254 - 6275 A-4 C 33 0 3/25/1997 Sqz 21/8" EnerJet; Phasing 1(+/-) 90 FI Lowside of Hole 14630 ~ 14660 6297 - 6316 A-3 30 4 8/14/1996 APERF 21/8" EnerJet; 180 deg. Gas Lift .; phasing; 90 deg. CW FI mdrel/Oummy Lowside Valve 3 Gas Lift MandrelsNalves :10379-10380, 00:5.390) St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 4162 2837 Camco KBMM DMY 1.0 BK 0.000 0 11/29/2001 Gas Lift . 2 7782 3965 Camco KBMM DMY 1.0 BK5 0.000 0 12/22/2001 mdrellOummy 3 10379 4769 Camco KBMM DMY 1.0 BK 0.000 0 12/15/2001 Valve 4 "4 12215 5341 Cacmo KBMM DMY 1.0 BK 0.000 0 12/15/2001 :12215-12216, 5 13417 5718 Camco· KBMM DMY 1.0 BK5 0.000 0 3/20/1997 00:5.390) 6 14409 6159 Camco MMM DMY 1.5 RK 0.000 0 12/26/2001 Other ( luos, eauip., etc.) - JEWELRY Note: Correlated Tbg Tail to GR is 14,465') Depth TVD Tvpe Description 10 Gas Lift .: 483 483 NIP Camco 'OS' Nipple NO GO 2.812 mdrel/Oummy 14463 6192 PKR Baker 'SAB-3' Perm. 3.000 Valve 5 :13417-13418, 14480 6203 PLUG 2.75" CA-2 PLUG set 5/29/2006 0.000 00:5.390) 14480 6203 NIP Camco '0' Nipple NO GO 2.750 14489 6209 SOS Baker WRG 2.992 14490 6209 TTL 2.992 Gas Lift .. General Notes .ndrel/Oummy Date Note Valve 6 ~ 1/30/2001 LOST 2 KICKSPRINGS DOWNHOLE FROM KOT. :14409-14410, 00:5.968) .' 2/25/2001 OBSTRUCTION MAY HAVE FALLEN IN ONE OF TWO GLMS @ 13417' RKB OR 14409' RKB 6/2/2006 TUBING LEAK @ 7168' PKR :14483-14464, 00:6.151) " PLUG I6J :14480-14481, 00:2.750) TUBING (0-14490, ~ 00:3.500, 10:2.992) SOS :14489-14490, 00:3.500) - ~ Perf ~~ ~ :14565-14590) Perf ~ :14562-14595) =~ = ~þ = 1== ~~ 1== F= =;; " ~ = ~ - ~ - - Ë - = : Perf :14830-14660) - ~ - - - - RE: 2M-35 (PTD 196-080) Failed MITIA e e Tom, Sorry about the omission of the schematic. I forgot to attach it to the previous e-mail. It is enclosed as well as the 90 day TIO plot. 2M-35 has been shut in since 06/2/05. Let me know if you need any additional information. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, May 11, 2006 7:55 AM To: NSK Problem Well Supv Cc: jim_regg@admin.state.ak.us Subject: Re: 2M-35 (PTD 196-080) Failed MITIA Perry, Would you please provide a well drawing and 90 day no plot? Thanks in advance. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/10/2006 7:02 PM: Tom, 2M-35 (PTD 196-080) produced water injector failed a MITIA 05/10/06. Wireline is scheduled to troubleshoot the dummied off gaslift string. The pre and post well head pressures can be found below. Initial T/I/O= 1950/1700/150 Final T/I/O= 1950/1700/150 Let me know if you have any questions Perry Klein Problem Wells Supervisor lof2 7/3/20069:08 AM 2M-35 90 loft no , 1264x764 05-1 452 OUTER ANNULUS PRES 2M-35 (PTD 196-080) suspect failed MITIA e e Tom, 2M-35 (PTD 196-080) produced water injector, shut in 05/02/05 because of surface water handling equipment issues, was brought online 05/05/06. The IA pressure failed to stabilize past the point of what we expect from thermal expansion effects. The well was shut in 05/06/06. Historically the well passed a state witnessed MITIA 08/12/05. 2M-35 is scheduled for an MITIA this coming week. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «2M-35.pdf» Content-Description: 2M-35.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 7/3/20068:58 AM ') ') MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~I " G'; ~) ) ./ P.I. S upervisor 1......~1 I '"'1 ¡;':; Chuck Scheve Petroleum Inspector DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-35 KUPARUK RIV UNIT 2M-35 ~,; tJq·p \0\ FROM: Src: Inspector Reviewed By: PJ. Suprv :.TB2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-35 Insp Num: mitCS050812204713 Rei Insp Num: API Well Number: 50-103-20243-00-00 Permit Number: 196-080-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Well I 2M=j5-lType Inj. I Ni TVD -l------6ï92---1 IA .~~!.:. 1-1 96080~_.l TYP:T~st--T Sl'T ! !_~;t--p-~i- ! __~~~J..~ Á- Interval 4YRTST P/F p Tubing I .._________.._________ ...__.L Notes: Pretest pressures observed for 30+ minutes and found stable. Pretest Initial 1240 i 2300 160 r- 160 -- ...--..--.-j----..... - 1820 ! 1820 L_____ 15 Min. 160 30 Min. 45 Min. 60 Min. 230õ·----r-=-'--1-·---== 160 I . __ I ___.J_ __...~_~~O~__ ..____.1______ 2300 1820 .'- i·'·: \;,~I.<..~I::::~ \I.... C D ìWil~!ï..It.ß t :nH!::;.¡...' ,)~.. ¡ C1; -I: 'ì 0\ n I:; l~; J.. I..,. .. ",) ,J Wednesday, August 17,2005 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 147 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 5162' FNL, 4863' FEL, Sec. 27, T11 N, R8E, UM (asp's 488256, 5948986) 2M-35 At top of productive interval 9. Permit number / approval number 841' FNL, 1833~.i~i;.i.~;i~;~i~i~;.~i~i~i~i.ii~i~`~i~i.~i.i~iii`~i~i.:'.:'.i~.i~i~ii~i~i~i`:~::~..i~?~iiiii~`:'~::~i.i.~i~i~i~i~i~i~?:~i~.i.~i~i~:'~i~i~:~i~i.i..i~i..i.i~:~`~.i!.i~i 196-080 At effective depth 10. APl number ::::::::::::::::::::::::::::::::::::::: {" ::~i:i'"i':":i" :i:i:i:i::":i'i':'!':'::i::'!~: :'"'"'::"::i'!:::: ::::::::::::::::::::: :ii' ::':::':'::' ::' i:::' '"' ':'::"' '::: :': "'" :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :': 50-103-20243 At total depth 11. Field / Pool 1097' FNL, 3544' FEL, Sec. 9, T1 ON, R8E, UM (asp's 484301, 5937222) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 14908 feet'/~ Plugs (measured) true vertical 6478 feet Effective depth: measured~:?iiiiii!~.i:.iiiii~:!ii!~i!ii!:;~:i:!i?:!??iii:!ii~.i!i~i~ii feet Junk (measured) ::::::::::::::::::::::::::::::::::::::: :.: :::::::::::::::::::::: :.:.:.: :,:.:.:. Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" ~ ........................................................ ..................................................... ' SUR. CASING 3869' 9-5/8" ;~-~i~iiiii~i;~!~i~i~!;~:;;i;iiii: 4016 ......... PROD. CASING 14748' 7" :- ~4~i~i~i~ii::::~i~:::i~:;~! iiii! ::ii~-i i!!:~:~.i :::?.::~.i:.~ii~:?i;?~i~: 14895' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :i:i:!:!:!: :!:!: :i:: :i:i:i:i:i:!:!:!:!:!:i:: :i:i:i: :i:i:!:!:!:!:: :i:i:i: :i:!: :!:}:!:!: ::i:i:i: :i:i' .......... F-.IVED Perforation depth: i:ii: :!:!:i:i:i:ii: i:S!:!:!:i:i: Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 Tbg @ 14490' MD. ~:~il~~ ~::~ Packers & SSSV (type & measured depth) BAKER 'SAB-3' PERM. @ 14463' MD. CAMCO 'DS' @ 483' MD. 14. Estimated date for commencing operation 15. Status of well classification as: December 15, 2001 17. I hereby cedi~ that the foregoing is true and corre~ to the best of my ~owledge. Questions? Call Jeff Spencer 659-7226 Signed ~ i e: Production Engineering Supe~isor ' Date ~ff A. Spen~r . Prepared b~ Robed Christensen 659-7535 e FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so representative may witness.[ Plug integd~ __ BOP Test __ Location clearance~ re,.,red Approved by order of the Commission ~ ~Ni Ta~ Commissioner Date Form 10-403 Rev 06/15/88 · ORIGINAL SCANNED JUl. ~ ,9 200;) SUBMIT IN TRIPLICATE 2M-35 DESCRIPTION SUMMARY OF PROPOSAL i :.' Phillips Alaska ia: reqUe~ting'C0~iss!°~ !aPPrOval:to convert 2M,35 to WAG Injection :.. ':.::::::! t0:-:sfipp6rt.:re::se:.~e, caPt:ure:~fo~:~e:[ii::i2K!27!.i~:.!!:i:!:::i' :i::::.i · ; ...': ' ;: .: ~' : · :.:. t.' ::: :' : '..'. :::. .' : . · . . . . · · .. . · . . . . . . . . . . . . . .. . sevice SCANNED JUL 1 9 MEMORANDUM TO: Camille Taylor Chair THRU- Tom Maunder P.i. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission John H. Spaulding FROM: Petroleum Inspector NON- CONFIDENTIAL DATE' January 10, 2002 SUBJECT: Mechanical Tests Integrity PAl ~ 2N 2N-302, 2N-348 KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2N-302 Type lnj. J G J T.V.D. 15186 ! Tubing t=~ !,~0 I=~0 l=~0 l lnterval[ P.T.D.1 2011150 TypetestI S ITestpsii 1297 I CasingI 1653 J 3083 J 3073I 3067I P/F [ -PI Notes: .initial MIT, conversion from producer 1 WellI 2N-348 Type lnj.] G t T.V.D. I 4377 I Tubing ! 3200 ! 3200 I 3175 J 3225 ]IntervalI ! P.T.D.! 2011420 TypetestI P ITestpsiJ 1094 I Casin§J 2284 J t519 ] 1527 ! 1531! P/F [ P Notes: Initial MIT: draw down due to high initial IA pressures WellI 2M-35 Type lnj.] S t T.V.D. ]6192 I Tubing ] 2205 ! 2205 ! 2205 ]2205 ]Interval P.T.D.I 1960800 Typetest] P ]Testpsi] 1548 I Casing] t025 ] 1625 I 1625 ! 1625 Notes' " Notes: P.T.D.] Notes: 2C-07 183096 Type testI P t Testpsil 1439 ICasingi 1000I 2420 J 2350I 2310I P/F I -P Type inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Well 2C-07 failed a previous MIT-reported to the AOGCC. MITT with bridge plug set in the tubing @ 6165' Presurred up the tubing and the IA and held for 3.5 hours. The sharp increase in psi from 2600 psi to 2875 psi was due to a guage change. PAi will be filing a Sundry for continued operations. All other wells noted above passed their respective MIT's and are in comploiance with area injection orders. M.I.T.'s performed' 4 Number of Failures: 0_ Total Time during tests' _5 Attachments' none cc: none SCANNED JUN 1 2002 .MIT report form 5/12~0O L.G. MIT KRU cpf-2 1-10-02js.xts 3/7/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. .. Development X RKB 147 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic Anchorage, AK 99510-0360 Service Kuparuk Unit 4. Location of well at surface 8. Well number 5162' FNL, 4863' FEL, Sec. 27, T11 N, R8E, UM (asp's 488256, 5948986) 2M-35 ,At top of productive interval 9. Permit number / approval number 841' FNL, 1833' FWL, Sec. 9, T10N, R8E, UM 196-080 / ,At effective depth 10. APl number 50-103-20243 At total depth 11. Field / Pool 1097' FNL, 3544' FEL, Sec. 9, T10N, RSE, UM (asp's 484301, 5937222) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 14908 feet Plugs (measured) true vertical 6478 feet Effective depth: measured 14806 feet Junk (measured) true vertical 6411 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 14o sxAS I 121' 121' SUR. CASING 3869' 9-5/8" 75o sxAS ~ & 75O sx C~ass e 4016' 2791' PROD. CASING 14748' 7" 400 sx Class G 14895' 6469' .~ ~).:. ,,?-~- _.,. 1,~¢--.- .~, 't'"' '""-' - ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::!:!:!-!:--i::: :?!:;:::!3 :i:?!:!'-:--:.:.:.:.:;' 5=: +-::::::.:-:--- .:.:_:.-::.:. _:.-.-.-. :.._....:.:.:. -_:. :_..:_:_-,:_-_:. :.._..._:.:_-. :.:.-_..:_:.-...:+ ..:.:....:..:.:.:.:_....:.:.:...:.:_-_ ..-:-.-:.:_:.:...:.:-..:_-.-.- :...:- .,.:...:.......:.:........:.:................, .......:.:...........,.¢ true ve rtl c al?~8~:7;5~!i~:9~65::~!6?if::!f::?: :-::'!'i~!~:-:::;?_:-!::.::f.-i~!-!:!:! Tubing (size, grade, and measured depth) :~..~:::~:~i~::~;i~:i;~:::::::::::::::::?:::::::::::::::::::::?:::?:::::::: i::':-?::::-'-¥i-'_-:i:::!~::--:':-i-':!i::':'-.:-:'::-:i::::':':--:-i!i:::::i!~!{:: :-:-:::::::::'::! i- ::-::-::~.-!:-;;'-:L::iE!:i:!:: 13. Stimulation or cement squeeze summary -:::.:..:...::.::.:..:-:.,.:::.:.:..:.::.:-:.:.:...- -::..:::. :.:::..:.:.:::,:.:.-.:...::.:..::. , ::::::::::::::::::::::::::::::::::::::::::::::: Treatment description including volumes used and final pressure .......... w:-.:- 14. Representative Daily Avera.qe Preduction or Injection Data ....................... 0!l;B..b_I ..................................... ........ . ....... ....... -. _ .-..... - . .:_:...:..... -_: :_..-..... :.: .:.:.:...... :.:...-.-..-.._,....... _. _ :.. :.:......: ...,....: :..........: ....................... .... ....:... .... . ... :... ......... . ............:..........:.:.. 15. Attachments Copies of Logs and Surveys run ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed ~"~"~¢~, ~'~ Title Production Engineering Supervisor Date ~¢?. /7/' ~,-4)~ ~_~ Jeff A. Spencer Prepared by Robert Christensen 659-7535 SUBMIT IN DUPLICATE 2M-35 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/7/02J Conversion from Oil producer-t° WAG.Injector complbted: Commenced-WAG:Injection: Service. : ...:' ';..i: '..-'.::...-.: -...: :.'- '-.i':'i. ' -' : : ""i "' ' I ON OR BEFORE C:LOP, lXl~ILNg'DOC P E RM I T DATA 96-080 CDR-MD 96-080 CDN-MD 96-080 7442 96-080 CBL AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~L 4020-14860 ~L 3930-12680 ~T'-4016-14905 CDR/CDN ~ 14000-14775 Page: 1 Date: 07/21/98 RLTN RECVD FINAL 09/05/96 FINAL 09/05/96 1 09/05/96 FINAL 09125/96 10-407 ~r~OMPLETI ON DATE ~/~'~/? ~.'.'/ DAILY WELL OPS R 5-/2 ~//~ / TO _,,~.,/~//.~ 70 / Are dry ditch sampleS required? yes' ~n~'~_~ And received? / ~ ,/~// yes ..... -no Was the well cored? Are well tests required? yes ~ ....... Received? Well is in compliance Initial COMMENTS yes ~ ..... _Analysis & description received? yes~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 115' FSL, 416' FWL, SEC 27, T11N, R8E, UM At top of productive interval 841' FNL, 1833' FWL, SEC 9, T10N, R8E, UM At effective depth 1389' FNL, 1764' FWL, SEC 9, T10N, R8E, UM At total depth 1462' FNL, 1738' FWL, SEC 9, T10N, R8F, UM 12. Present well condition summary Total Depth: measured true vertical I 4908 feet 6478 feet 6. Datum elevation (DF or KB) RKB 41 7. unit or Property name Kuparuk River Unit 8. Well number 2M-35 9. Permit number/approval number 96-80 10. APl number 50-103-20243-00 11. Field/Pool feet Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 14806 feet true vertical 6 41 1 feet Junk (measured) None Casing Length Size Cemented Measured depth True vedical depth Structural Conductor 8 0' 1 6" 140 Sx AS I 121' 121' Surface 3978' 9 5/8" 750 Sx AS III & 4016' 2791' Intermediate 750 Sx Class G Production 1 4 8 5 9' 7" 400 Sx Class G 14895' 6469' p eLifnoerration depth: measured 0 RIG 14562'-14595', 14630'-14660' true vertical 6255'-6273', 6297'-6316' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 14490' Packers and SSSV (type and measured depth) Packer: Baker SAB3 @ 14463'; SSSV: None, nipple @ 483' 13. Stimulation or cement squeeze summary Reperforated 'A' sands on 3/25/97. Intervals treated (measured) 14562'-14595' Treatment description including volumes used and final pressure Perforated w/2-1/8" EJ guns & DP charges @ 4 SPF, final pressure = 2000 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure NAL Tubing Pressure Prior to well operation 1 7 6 18 82 1036 262 Subsequent to operation 1 76 1 8 82 1 036 262 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Form 10-401'4 Rev ~ Title Wells Superintendent Date-~/~ SUBMIT I~1 DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT __ WELL SERVICE REPORT K1(2M-35(W4-6)) WELL JOB SCOPE JOB NUMBER 2M-35 FRAC, FRAC SUPPORT 0214971623.4 DATE DAILY WORK UNIT NUMBER 03/25/97 REPERFORATE "A" SAND DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR 9 (ii:) © NoI ® © No CHAN Y FIELD AFC~ CC,~ DAILY COST ACCUM COST ' "' ' " '"' si¢~?~// ~ Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann ',I Final Outer.,, 2000 PSI 2000 PSI 650 PSI 650 PSiI 250 PSII ~o PSI DAILY SUMMARY IREPERFORATED THE "A" SAND INTERVAL OF 14562' - 14595' W/2-1/8" ENERJETS, DP CHGS, 4 JSPF. NO WHTP CHANGES WHEN PERFD. TIME LOG ENTRY 09:00 MIRU SWS E/LINE AND APC PUMP TRK. 11:00 11:30 12:00 14:00 16:00 17:15 HELD SAFETY MEETING (7 ON LOCATION) ARMED GUNS AND PT'D LUBRICATOR AND SURFACE LINES TO 3500 PSI. RIH W/1-11/16" HEAD (1-3/8" FN), 1-11/16" SWIVEL, 2-1/8" SINKER BAR (TWO 6' SECTIONS), 1-11/16" CCL, 2-1/8" MPD, AND 22' OF 2-1/8" ENERJET W/DEEP PENETRATING CHGS 2 SPF PHASING +90 FROM THE LOW SIDE OF THE HOLE. ASSISTANT FROM PUMP NEEDED TO GET TOOLS THRU HIGH DEVIATION FROM 2000' THRU 14000', PUMPED DIESEL @ 1.5 BPM. TIED IN TO SHORT JTS AND TBG JEWELRY. PERF'D INTERVAL FROM 14573' - 14595' RKB AND STARTED CCH. ON SURFACE AND ALL SHOTS FIRED. RIH W/1-11/16" HEAD (1-3/8" FN), 1-11/16" SWIVEL, 2-1/8" SINKER BAR (TWO 6' SECTIONS), 1-11/16" CCL, 2-1/8" MPD, AND 11' OF 2-1/8" ENERJET W/DEEP PENETRATING CHGS 2 SPF PHASING +90 FROM THE LOW SIDE OFTHE HOLE. ASSISTANT FROM PUMP NEEDED TO GET TOOLS THRU HIGH DEVIATION FROM 2000' THRU 14000', PUMPED DIESEL @ 1.5 BPM. 19:30 TIED IN TO SHORT JTS AND TBG JEWELRY. PERF'D INTERVAL 14562'- 14573' RKB AND STARTED CCH. 21:30 ON SURFACE AND ALL SHOTS FIRED. 22:15 RIH W/1-11/16" HEAD (1-3/8" FN), 1-11/16" SWIVEL, 2-1/8" SINKER BAR (TWO 6' SECTIONS), 1-11/16" CCL, 2-1/8" MPD, AND 22' OF 2-1/8" ENERJET W/DEEP PENETRATING CHGS 2 SPF PHASING -90 FROM THE LOW SIDE OF THE HOLE. ASSISTANT FROM PUMP NEEDED TO GET TOOLS THRU HIGH DEVIATION FROM 2000' THRU 14000', PUMPED DIESEL @ 1.5 BPM. 00:30 TIED IN TO SHORT JTS AND TBG JEWELRY. PERF'D INTERVAL 14573' - 14595' RKB AND STARTED CCH. 03:30 ON SURFACE AND ALL SHOTS FIRED. 04:15 RIH W/1-11/16" HEAD (1-3/8" FN), 1-11/16" SWIVEL, 2-1/8" SINKER BAR (TWO 6' SECTIONS), 1-11/16" CCL, 2-1/8" MPD, AND 11' OF 2-1/8" ENERJET W/DEEP PENETRATING CHGS 2 SPF PHASING -90 FROM THE LOW SIDE OF THE HOLE. ASSISTANT FROM PUMP NEEDED TO GET TOOLS THRU HIGH DEVIATION FROM 2000' THRU 14000', PUMPED DIESEL @ 1.5 BPM. 06:30 TIED IN TO SHORT JTS AND TBG JEWELRY. PERF'D INTERVAL 14562' - 14573' RKB AND STARTED CCH. 08:30 ON SURFACE AND ALL SHOTS FIRED. 09:30 RDMO SWS AND APC PUMP TRUCK. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $2,058.00 . $8,100.00 $13,850.00 APC i - , DIESEL ~' $1,700.00 $1,700.00 DOWELL $0.00 $4,444.00 HAl I IBU RTON ' · $0.00 $20,110.00 LITI'LE RED $0.00 $13,318.00 SCHLUMBERGER .: ' - '~: . . $23,182.00 $23,182.00 TOTAL FIELD ESTIMATE ' $32,982.00 $78,662.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 115' FSL, 416' FWL, SEC 27, T11N, RSE, UM At top of productive interval 841' FNL, 1833' FWL, SEC 9, T10N, R8E, UM At effective depth 1389' FNL, 1764' FWL, SEC 9, T10N, RSE, UM At total depth 1462' FNL, 1738' FWL, SEC 9, T10N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 4908 feet 6478 feet 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-35 9. Permit numbedapproval number 96-80 10. APl number 5o-103-20243-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 1 4806 feet true vertical 6 4 1 I feet Junk (measured) None 13. 14. Casing Length Size Cemented Structural Conductor 8 0' I 6" 140 Sx AS I Surface 3978' 9 5/8" 750 Sx AS III & Intermediate 750 Sx Class G Production 1 4 8 5 9' 7" 400 Sx Class G Liner Perforation depth: measured 14562'-14595' true vertical 6255'-6273', 14630'-14660' 6297'-6316' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 14490' Packers and SSSV (type and measured depth) Packer: Baker SAB3 @ 14463'; SSSV: None, nipple @ 483' Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 3/26/97. Intervals treated (measured) 14562'-14595', 14630'-14660' . Treatment description including volumes used and final pressure '" Measured depth 121' 4016' 14895' True vertical depth 121' 2791' 6469' ORIGINAL 0R.I-GINAL. Pumped 240.5 Mlbs of 20/40, 12/18, & 10/14 ceramic proppant into form., final pressure - 4600 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation I 7 6 18 82 1036 262 Subsequent to operation 433 36 291 1044 243 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'O(' ~.~.¢J~/V Title Wells Superintendent Form 10-4~, REP'S/15/88 Date ¢(/¢~''~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~' K1 (2M-35(W4-6)) WELL JOB SCOPE JOB NUMBER 2M-35 FRAC, FRAC SUPPORT 0214971623.4 DATE DAILY WORK UNIT NUMBER 03/26/97 "A" SAND FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 10 (~) Yes O No (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC~ CC_~ DAILY COST ACCUM COST SigP'~d l// "~ /~u~'~'a~ ESTIMATE 998547 230DS36ML $1 46,968 $225,630 Initial Tb.q Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Out'er Ann 2250 PSI 2500 PSI 675 PSI 850 PSII 200 PSII 4,O~PSl DAILY SUMMARY "A" SAND FRAC COMPLETED THRU FLUSH. INJECTED 240484 LBS OF PROP IN FORMATION W/ 12 PPA OF #10/14 @ PERF'S. MAX PRESSURE 9400 PSI, F.G. (.83) . FREEZE PROTECTED TBG W/34 BBLS DIESEL. TIME 09:00 11:00 12:30 13:30 14:45 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL UNIT. HELD SAFETY MEETING (15 ON LOCATION) PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG AS NEEDED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9500 PSI. PUMP BREAKDOWN W/50# GW & 50# DELAYED XL GW @ 38 TO 40 BPM. VOLUME PUMPED 471 BBLS. USED 1837 LBS OF #20/40 PROP FOR SCOURING. MAX PRESSURE 9450 PSI AND ENDING PRESSURE 5100 PSI. S/D AND OBTAINED ISlP OF 2425 PSI AND F.G. (.83). PULSED FOR CLOSURE AND MONITORED WHTP. PUMP DATAFRAC W/50# DELAYED XL GW & STRAIGHT WATER @ 5 TO 20 BPM. VOLUME PUMPED 245 BBLS. MAX PRESSURE 6800 PSI AND ENDING PRESSURE 5200 PSI. S/D AND OBTAINED ISIP OF 2379 PSI AND F.G. (.82). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 20 BPM. COMPLETED THRU FLUSH. VOLUME PUMPED 1589 BBLS. MAX PRESSURE 6600 PSI AND ENDING PRESSURE 4600 PSI. S/D AND OBTAINED ISlP OF 3377 PSI, MONITORED WHTP FOR 5 MINS.INJECTED 241941 LBS OF PROP ( 16379 LBS OF #20/40, 215101 OF #12/18, 10461 LBS OF #10/14 ). PUT 240484 LBS IN FORMATION W/ 12 PPA OF #10/14 @ PERF'S. LEFT 1457 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED TBG W/34 BBLS DIESEL. 17:00 STARTED R/D. DEPRESSURED THE INNER CSG AND R/D HOT OIL UNIT. 17:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D R/D COMPLETE. WELL SECURED AND NOTIFIED DSO OF STATUS. 18:30 , . SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $2,058.00 APC $5,650.00 $19,500.00 DIESEL $500.00 $2,200.00 DOWELL $138,179.00 $142,623.00 HALLIBURTON $0.00 $20,110.00 LITTLE RED $2,640.00 $15,958.00 SCHLUMBERGER $0.00 $23,182.00 TOTAL FIELD ESTIMATE $146,969.00 $225,631.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 30, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2M-35 (Permit No. 96-80) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2M-35. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development ORIG I AL WSI/skad RECEIVED ~-,!OV 0 1 1996 Alaska 0il & 6~s Cons. commissio~ Anchorage STATE OF ALASKA :~ , ' ALASK,-, OIL AND GAS CONSERVATION C..,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1. Status of Well ClassifiCation of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-080 ., 3. Address 8. APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 50-103-20243 ....... ; ..... "~ :-- ..... 9. Unit or Lease Name 4. Location of well at surface ~ ~:,'_~Li?LC~';:'~'~f ? :~- ............ ~.. ~ ~r,,.~,, ~ ..... ~ Kuparuk River Unit 115' FSL,416' FWL, Sec. 27, T11N, R8E, UM At top of productive interval ~' ~':-'"'~ ...... ~ :10. Well Number 41, Sec. UM ;. Attotal depth;.~~-..-'. .....~ ,~.;~~~ 11: Fiel'd and pool ... 1102' FNL, 1738' FWL, Sec. 9, T10N, RDE, UM ........... -.~- ~'~?~ ~~ .. Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) ]6. Lease Designation and Serial No. ,i~ ,K, 4~' ,~d 10~' ~2. g.t~ Spudded S,24/~.i~' D~t~ T.D. Re.ohe~ S/~ ,. , J ~4' Cate C°mp" Sump" °" Aba~d'l~S' Water ~pth' i' °~sh°r~ ~/2~,~ N/A MSLjJ16' No. of Completions One 17. Total Depth ~MD+TVD)~ 18. Plug BaCk D~pth (MD+TVD)]19. Directional SurveyS20. Depth where SSSV set~l. Thickness of Permafrost . ~490~ .... 6~8. F~ 14806 6411 F~ ~Yes ~No j N/A M~/ ~ 380' (Approx.) !22. Type Electric or Other Logs Run G~ODR/CDN, G~COUSLT-J ~23. "CASING, LINER AND CEMENTING RECORD ~' cA~iNG ] SE~NG DEPTH ~ HOLE ........... _. s,z, ....... ~. ~. F~. ~_~ _.[ ~~M S,Z.C.M.N~,N~ R.oo.~ AMO~ P~.~ ...... 16" 151.5~ X-65 SURF. ~ 121' 24" 140sxASl 9.625" 40~ L-80 SURF. 4016' 12.25" 750 sx AS III, 750 sx Class G 7" 26~ '-' .......... L:~O ........ SURF. 14895' - -8.5" .... 40b-SX O-I-~s~-~ ............................................................................................................ .... 24. Pedorations open to Production (~D+TVD of Top'and BottOm 25. TUBING RECORD and interval, size and number) ....................................................................................... SIZE DEPTH SET (MD) PACKER SET (MD) 4 spf 3.5" - ........ 1-~-~ O' ............................. i-~-~-' ................. MD TVD MD TVD ............................................................................................. 14630'-14660' 6297'-6316' - ............................ 14565'-14590' 6256'-6272' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , DEP~ INTERVAL (MD) AMOU~ & KIND OF MATERIAL USED ..... ~-'~--T~6~-b¥:1-~-~-0' - .... ~0~i- pr~-p~n~ pumped 7i 856~ (i0311~ ~- & 14565,-14590, ¢20/40 and 61545¢ of ¢12/18) - .......................... 2) 14630'-14660' 59000¢ proppant behind pipe & 29692¢ left ..... & i--4565Ci4590' in tubing, used 33099¢ 20/4© &55593¢ 12/18 ....... .. ~7. PRODUCTION TEST Date First'broductio~" iMeth0d of OPerati0'~ (Flowing, ga~ lift, etc.) .... 9/13/96 i Gas Li~ Date of Test iHours Tested PRODUCTION F~]OIL-BBL GAS-~F ~WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 1 0/12/96 ~ 24 TEST PERIOD' ~ 1 87 88 59 0 j 41 23 ~-~-~-T~5-15~ c-~-i-~---~-~-b-¢~~C~L-8bL-~5--; ...... i-O~L:~L ............ i~X~:~-6~ .......... W-~fE~:-BB-L- .......... OiE~-~-~if~:A-PI (~5~) ................................. ?ress. 0~ 1178 ~4-HOUR RATE ] .... ?7 .. i .... 88 ..... 59 =24° . 28. CORE DATA Brief description of li{~ology, porosity, fra~ures, apparent d~ps and presenc~"of oil, gas or water. Submit core chips. RECEIVED Alaska 0il & Gas Cons. Commission Anchor~.ge ................. Form 10-407 Rev. 07-01-80 Submit In Duplicate Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 14545' 6243" .... Bottom Kuparuk C 14560' 6253' Top Kuparuk A 14560' 6253' Bottom Kuparuk A 14560' 6253' FREEZE PROTECTED ANNULUS WITH DIESEL , , 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. ~ ,~. __ L ~';,~.__*. ~. ~.~,,~.._._- Title ~,~ll3.t.~.r4l.. ~r4f~i4EE=, ...... Date I{~ / ~'1 °l(~ Prepared By Name/Number: 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 welt should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 · .. Date: 9/25/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:2M-35 RIG:NORDIC WELL ID: AK8509 AFC: AK8509 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD'05/24/96 START COMP' BLOCK' FINAL' WI: 0% SECURITY:0 AFC EST/UL:$ 1670M/ 2004M API NUMBER: 50-103-20243-00 05/24/96 ( 1) TD' 645' ( 645) SUPV: DCL DAILY: 05/25/96 (2) TD: 4027' (3382) SUPV: DCL DAILY: 05/26/96 (3) TD: 4027' ( 0) SUPV: DCL DAILY: 05/27/96 ( 4) TD: 7160' (3133) SUPV:DCL DAILY: 05/28/96 (5) TD: 9690' (2530) SUPV'RLM DAILY' 05/29/96 { 6) TD'12503' (2813) SUPV:RLM DAILY: 05/30/96 (7) TD-14550' (2047) SUPV:RLH DAILY: 05/31/96 (8) TD'14908' ( 358) SUPV:RLM MW: 9.1 PV/YP: 20/25 APIWL: 12.4 DRILLING Move rig from 2M-34 to 2M-35. Accept rig @ 1300 hrs 5/24/96. Function test diverter. Drill 12.25" hole from 121' to 645' $83,281 CUM: $83,281 ETD: $0 EFC: $1,753,281 MW: 10.0 PV/YP: 18/14 APIWL: 7.4 RIH W/9-5/8" CSG Drilling and MWD survey from 645' to 4027' Pump out of hole at 1370' due to swabbing. Hole in good condition. $100,771 CUM: $184,052 ETD: $0 EFC: $1,854,052 MW: 8.4 PV/YP: 1/ 0 APIWL: 20.0 FIT RU to run 9-5/8" csg. Held pre-job safety meeting. Cement casing. NU BOPE. Test BOPE to 300/3000 psi. $196,312 CUM: $380,364 ETD: $0 EFC: $2,050,364 MW: 9.2 PV/YP: 13/17 APIWL: 6.2 WIPER TRIP AT 7652' Drill green cement to 3892' Test casing to 2000 psi for 30 min. OK. Drill out FC, cement, FS and 10' of new formation to 4037' Perform FIT. Drilling and MWD survey from 4037' to 7160' $95,019 CUM: $475,383 ETD: $0 EFC: $2,145,383 MW' 9.4 PV/YP: 14/16 APIWL' 6.4 DRILLING AT 10700' Directional drilling 8.5" hole from 7160' to 9690'. $82,002 CUM: $557,385 ETD' $0 EFC' $2,227,385 MW' 9.1 PV/YP: 14/24 APIWL' 6.8 DRILLING AT 13300' Directional drill 8.5" hole from 9690' to 12503' $93,884 CUM' $651,269 ETD: $0 EFC' $~,321,269 MW: 10.5 PV/YP: 17/24 APIWL: 4.8 DRILLING AT 14660' Directional drill 8.5" hole from 12503' to 14550' $115,344 CUM: $766,613 ETD' $0 EFC' $2,436,613 MW: 10.9 PV/YP: 20/20 APIWL: 4.6 POOH Directional drill 8.5" hole from 14550' to 14908' Saw steady increase in oil while drilling a sand with minor connection gases. Breathing problems continued. Circulate condition prior to wiper trip. Due to minor connection gases and oil in mud it was decided to increase wt. to 10.6 prior to wiper trip. On bottoms up, a significant increase Date: 9/25/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 DAILY: 06/01/96 ( 9) TD:14908' ( 0) SUPV:RLM DAILY: 06/02/96 (10) TD:14908' ( 0) SUPV:RLM DAILY: 06/03/96 ( 11} TD:14908' ( 0) SUPV:RLM DAILY: 06/04/96 (12) TD:14908' ( 0) SUPV:RLM DAILY: in gas was noticed. 180 bbls mud were lost while weighting up. Well was flowing with pumps off with gas breaking out in the bell nipple. Circulate condition and build volume. No discernible increase in gas or oil on bottoms up. Weighted up in increments to 10.9. $108,191 CUM: $874,804 ETD: $0 EFC: $2,544,804 MW: 11.3 PV/YP: 20/14 APIWL: 5.4 CIRCULATE AT SHOE Continue to have well control problems. Weighted up in increments to 11.3 ppg. $100,568 CUM: $975,372 ETD: $0 EFC: $2,645,372 MW: 11.3 PV/YP: 21/15 APIWL: 6.5 RUNNING 7" CASING Held pre-job safety meeting. Run 7" casing. Lost returns going in hole at 2200' $237,479 CUM: $1,212,851 ETD: $0 EFC: $2,882,851 MW: 0.0 PV/YP: 23/20 APIWL: 8.4 LAYING DOWN DRILL PIPE Run 7" casing to 14895' Cement casing. No returns while cementing. CIP at 1300 hrs. 6/3/96. Install packoff and test to 3000 psi. Freeze protect 9-5/8" x 7" annulus with diesel. $121,510 CUM: $1,334,361 ETD: $0 EFC: $3,004,361 MW: 0.0 PV/YP: 0/ 0 RIG RELEASED Release rig at 12:00 hrs. 6/4/96. $37,877 CUM: $1,372,238 ETD: $0 EFC: APIWL: 0.0 $3,042,238 Date: 9/25/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:2M-35 RIG:NORDIC WELL ID: AK8509 AFC: AK8509 TYPE' -- STATE'ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD' KUPARUK RIVER UNIT SPUD:05/24/96 START COMP' BLOCK: FINAL: WI: 0% SECURITY'0 AFC EST/UL:$ 1670M/ 2004M API NUMBER: 50-103-20243-00 07/27/96 ( 13} TD:14908' PB:14806' SUPV:ME DAILY: 07/28/96 (14) TD:14908' PB:14806' SUPV:ME DAILY: 07/29/96 (15) TD:14908' PB:16231' SUPV:ME DAILY: 07/30/96 (16) TD:14908' PB:16231' SUPV:ME DAILY: LOAD TUBING IN PIPE SHED MW: 8.5 SW Moved rig from 2M-33. Accepted rig @ 00:30 7/27/96. ND tree. NU BOP. Function tested BOP to 250/3500 psi. Pulled test plug. $20,147 CUM: $1,412,532 ETD: $0 EFC: $3,082,532 PICKING UP 3.5" TUBING MW: 0.0 Pressure tested 7" casing to 3500 psi. Lost 50 psi in 30 minutes. RIH with tubing. $32,932 CUM: $1,478,396 ETD: $0 EFC: $3,148,396 CIRC BALL TO SHEAROUT SUB Continue RIH with 3.5" tubing to 14009' GR-CCL-SLTJ. RIH w/packer. Dropped ball. MW: 0.0 RIH with $183, 190 CUM' $1,844,776 ETD' $0 EFC' $3,514,776 RIG RELEASED MW: 0.0 Pressured tubing to 2500 psi to set packer @ 14463' . Pressure tested tubing to 2500 psi. Lost 50 psi in 30 minutes. Bled tubing to 500 psi and tested annulus to 2500 psi. Lost 50 psi in 30 minutes. Pressured tubing to 4500 psi with no indication of ball shearing. Bled off tubing. Pressured annulus to 2800 psi and sheared DCR in GLM @ 14408' Freeze protect tubing and casing. ND BOP. NU tree. Set test plug. Tested tree to 250/5000 psi. Released rig @ 1500 hrs. 7/29/96. $34,449 CUM: $1,913,674 ETD: $0 EFC: $3,583,674 End of WellSummary for Well:AK8509 KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2M-35(W4-6)) WF.! I. JOB SCOPE 2M-35 FRAC, FRAC SUPPORT DATE 08/28/96 DAILY WORK PERFORATE DAY OPERATION COMPLETE 5 YES Initial Tbg Press 700 PSI DAILY SUMMARY JOB NUMBER 0815960822.2 UNIT NUMBER [SUCCESSFUL [ KEYPERSON SUPERVISOR YES SWS-SCHWARTZ ELLIS Fina~ Tbg'Press [ Initial Inner Ann ! Final Inner Ann I Initial Outer Ann [Final Outer Ann 1300 PSI 1300 PSI 1300 PSI 300 PSI 500 PSI PERFORATED THE A SAND FROM 14565 TO 14590' W/4 JSPF. TIME 13:30 14:00 14:45 15:15 16:30 17:00 18:00 20:45 22:00 22:30 23:30 00:15 02:00 LOG ENTRY MIRU SWS E-LINE UNIT. TGSM - JOB PLAN & SIMULTANEOUS OPERATIONS. MU 2-1/8" ENERJET GUNS & CCL. PRESSURE TESTED LUBRICATOR TO 3100 PSI. RIH W/PERF GUNS PUMPING SW @ 1.5 BPM DOWN TUBING TAKING RETURNS OUTTHE 3-1/2" X 7" ANNULUS. CORRELATED & PERFORATED THE A SAND FROM 14565' TO 14590' (25') 2 JSPF W/BIG HOLE CHARGES ORIENTED 90 DEGREES CW FROM LOW SIDE. POH W/PERF GUNS. AI.I. SHOTS FIRED. LOADED GUNS & RIH W/2-1/8" ENERJET GUN & CCL PUMPING SW DOWN THE 3-1/2" TUBING @ 2 BPM TAKING RETURNS OUT THE 3-1/2" X 7" ANNULUS. GUNS STOPPED (~ 10545'. INCREASED RATE TO 4 BPM & CONTINUED R1H. CORRELATED CCL & PERFORATED THE A SAND FROM 14565 TO 14590' (25') 2 JSPF W/BIG HOLE CHARGES ORIENTED 90 DEGREES CCW FROM LOW SIDE. POH W/PERF GUNS. ALL SHOTS FIRED. FREEZE PROTECTED THE 3-1/2" TUBING FROM SURFACE TO 2500' BY BULLHEADING 25 BBLS INTO TBG 2 BPM @ 2400 PSI. FREEZE PROTECTED THE 3-1/2" X 7" ANNULUS FROM SURFACE TO 2500' BY BULLHEADING 65 BBLS INTO CASING 2 BPM @ 2400 PSI. RD SWS E-LINE UNIT. KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(2M-35(W4-6)) WEII. JOB SCOPE JOB NUMBER 2M-35 PERFORATE, PERF SUPPORT 0804961335.3 UNIT NUMBER DATE DAILY WORK 08/14/96 PERFORATE A SAND DAY OPERATION COMPLETE [ SUCCESSFUL 2 YES I YES Initial Tbg Press [ Final Tbg Press [ Initial Inner Ann 0 PSII 200 PSI[ 0 PSI DAILY SUMMARY KEY PERSON SWS-BAILEY SUPERVISOR GOLDEN Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSII 0 PSI] 0 PSI PERFORATED A SANDS F/14630'-14660' (4 SPF, 180 DEG PHASING, 90 DEG CW F/LOW SIDE, BIG HOLE CHARGES). TIME LOG ENTRY 09:45 MIRU SWS E-LINE, APC DHP. TGSM - PERFORATING. 10:45 ATI'EMPrED TO PT LUBRICATOR - UNSUCCESSFUL. O-RING FAILURE ON CONNECTION BETWEEEN BOPS AND PUMP- IN SUB. CHANGE OUT 0 -RING. 11:30 PT LUBRICATOR TO 3000 PSI - GOOD.RIH W/HEAD, WB, CCL, MPD, 30' 2-1/8" ENERJET (2 SPF, BIG HOLE CHARGES, 90 DEG CW F/LOW SIDE OF HOLE). 13:00 SAT DOWN AT 7500'. LINE UP TO INJECT DOWN TUBING TAKING RETURNS ON BACKSIDE, WILL TRY TO PUMP GUNS DOWNHOLE. ESTABLISHED INJECTION AT 1 BPM. CONTINUED RIH. SAT DOWN AT 9700'. INCREASED INJECTION TO 2 BPM. WORKED TO 14400'. UNABLE TO PASS BTM GLM. 14:30 19:00 21:30 23:30 POOH TO 13000'. SHUT IN INJECI1ON. ABLE TO WORK PASS BTM GLM.TIED INTO SLTJ LOG DATED 7/28/96.PERFORATED 14630'-14660'. WHP (BEFORE) = 1000 PSI, WHP {AlZTER) = 1000 PSI.POOH. ASF. PT LUBRICATOR TO 3000 PSI - GOOD.RIH W/HEAD, WB, CCL, MPD, 30' 2-1/8" ENERJET (2 SPF, BIG HOLE CHARGES, 90 DEG CCW F/LOW SIDE OF HOLE). PUMPED GUNS DOWN HOLE AT 2.0 BPM. TIED INTO SLTJ LOG.PERFORATED 14630'-14660'. WHP (BEFORE) = 300 PSI, WHP (AlZTER) = 300 PSI.POOH. ASF. RD SWS. FREEZE PROq'ECFED BACKSIDE W/80 BBLS DSL. UNABLE TO SUSTAIN INJECTION INTO FORMATION AT 2500 PSI. FREEZE PROTECTED FLOWLINE W/20 BBLS DSL. TOTAL FLUIDS PUMPED 442 BBLS DSL. RD APC. !',:,,) 0 1 ~.ggo Alaska Oil & (,m; Oor~s. Commission ARCO Alaska, Inc. Date: September11, 1996 Transmittal #: 9735 RETURN TO: ARCO Alaska, Inc. Attn.: Bethany Lilly Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3G-25 Cement Bond Log 07-25-96 3F-19 Cement Bond Log 07-27-96 3F-1 8 Cement Bond Log 07-26-96 3F-17 Cement Bond Log 07-27-96 2M-35 Cement Bond Log 07-28-96 2M-34 Cement Bond Log 07-31-96 Receipt ~~)~ Acknowledge Date' DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 2700-3520 7460-7876 6000-6770 6~60-7045 14000-14775 16240-1656O Chapman/Zuspan NSK Wells Group NSK69 8/27/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10347 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2M-35 961 72 CDR/CDN 960602 2M-35 96172 CDR 960602 1 2M-35 961 72 CDN 960602 I ~ .____. I ..-- SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: S EP 0 5 '199ro Alaska Oil & Gas Cons. ~omm~sstor, Anchora¢le ALASKA OIL AND GAS CONSERVATION COMMISSION Mav 2, 1996 J TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi, Dflg Engr Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re~ Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2M-35 ARCO Alaska, Inc. 96-080 114'FSL, 417'FWL, Sec 27, T1 IN, R08E, UM 1183'FNL, 1663'FWL, Sec 09, T10N, R08E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were nm. The documentation submitted should assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. 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. David W. JoX~E_,n Chairman BY ORDER OF THE COMMISSION ljb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS OONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry ~--~ Deepen r~ Service ~] Developrnent Gas [~ Single Zone X UultipleZone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 106' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ~ADL 25589, ALK 2675 4, Location of well, at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 114' FSL, 417' FWL, Sec. 27, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 955' FNL, 1741' FWL, Sec. 9, T10N, RSE, UM 2M-35 #U-630610 At total depth 9. Approximate spud date Amount 1183' FNL, 1663' FWL, Sec. 9, T10N, R8E, UM 5/3/96 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line 2M-18 15065' MD 1663 @ TD feet 10.5' @ 850' feet 2560 6561' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum holeangle 71.94° Maximurnsu~face 1652 pslg At total depth (TVD) 3200 pslg 18. Casing program Seltir~l Depth size Specifications Top Bottom Quantity/of cement Hole Casing Weight Grade Coupling Length ME) TVD IVE) TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625' 40.0# L-80 BTC 3945' 41' 41' 3986' 2791' 730 Sx Arcticset III & HF-ERW 760 Sx Class G 8.5" 7" 26.0# L-80 BTCMO£ 15024 41' 41' 15065' 6561' 170SxClassG HF-ERW Top 500' above Kuparuk lg. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured dept,h. True Vertical depth Structural ~'~'~Ci~ i~\/ Conductor ~i'% ~. I-- ~ Sudace Intermediate Production fl ~"~ R 'i ~ '1 '~ ~ ~ Liner Perforation depth: measured ~,~S!':P~ 0i~ & P~a$ Con3, Co~: true vertical 20. Attachments Filing fee X Property plat E] BOP Sketch X DiverterSketch X Ddlling program X Drilling fluid program X Time vs depth plot D Refraction analysis C] Seabed report E] 20 AAC 25.050 requirements X 21. I hereby certify that the forj~going is t~ e and correct to the best of my knowledge SignedJ~''~~, ~CommissionTitleuse Onl~Drill Site Develop. Supv. Date ~'"' Perm, Number I APl numb/~w'" i ^,,rev., i See cover'e"er for C~ ~ - 0 ~O I 50- I ~) '~ - ~[, 0 ~ ~f ~ --(50 . ~/~ other recluirements Conditions of approval Samples required [] Yes [~ No Mud log required [] Yes [~' No Hydrogen sulfidemeasures ~' Yes [~ No Directional surveyrequired [~ Yes D No Required working pressure for BOPE D 2M ~ 3M [~ 5M D 1OM D 15M Other: .~-~'~na! Signed Dy ~)avid W. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate I , , . . . w . . , 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2M-35 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3,986')according to directional plan. Run and cement 9-5/8" 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 8-1/2" hole to total depth (15,065') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (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 #2. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer 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. RECEIVED APR '1 8 199 ~ , ir. ri Aisska 0il & G~t.,s Cons,. Comm,~o,on Anchors',.3e DRILLING FLUID PROGRAM Well KRU 2M-35 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 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 10.3 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.O33. 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 1,652 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2M-35 is 2M-18. As designed, the minimum distance between the two wells would be 10.5' @ 850' MD. Drilling Area Risks' Risks in the 2M-35 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. 7" casing will be topset above the Kuparuk and Nordic Rig #2 will drill out a 6-1/8" hole, and run a 5" 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 10.3 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" 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. RECEIVED APR 1 8 1996 Ai~,ska 0il & r3a~ C ]n~,. C~,mmission ANNULAR PUMPING OPERA'ilONS WELL KRU 2M-35 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). ('Note that cement rinseate will not be in!ected down the dedicated disposal well but will be recycled or held for an open annulus.~ The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2M-35 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 during the production cement job to cover the formation. It is requested that 2M-35 be permitted for annular pumping occurring as a result of drilling operations, 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. Please reference the enclosed directional drilling plan for other formation markers in this well. 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 200-300' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set _+100' vertical below the base of the West Sak into the heart of the shales. 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 Max Pressure - 3242 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 Wt Conx Collapse 85% of Burst 85% of (in) (lb/(t)Grade Range Type (psi) Collapse (psi) Burst , 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). RECEIVED ARCO ALAS~, [nc. Pad ~ 35 slot #35 Kuparuk River Unit North SLope, ALaska CLEARANCE REPORT Baker Hughes !NTEQ Your ref : 35 Version #8 Our ref : prop1542 License : RECEIVED Date printed : lO-Apr-96 Date created : 8-Feb-96 Last revised : lO-Apr-96 APR '1 8 '199~ Alaska 0il & Gas Cons. Commission Anchorage FieLd is centred on nTO 16 18.576,w150 5 56.536 Stracture is centred en nTO 16 17.458,w150 5 54.03 Slot location is n?O 16 18.579,w150 5 41.890 Slot Grid coordinates are N 5948985.332, E 488257.649 Slot local coordinates are 114.00 N 417.00 E Reference North is True North Main caLcuLation performed with 3-D Minim~mn Distance method Object wet tpath 33 Version #11,,33,Pad 2M 2M-C Version #5,,34,Pad 2M 9A Versic~ #7,,9A,Pad 2M PflSS <354~-4022'>,,9,Pad 2H PGNS <O-12177'>,,gSt,Pad 214 PflSS <O-3464~>,,23,Pad 2M PGNS <O-?11~'>,,12,Pad 2M PflSS <O-10399'>,,6,Pad 2M PGMS <O-9810'>,,14,Pad 2M PGMS <O-7947'>,,17,Pad 2M PMSS <157~-3318'>,,1,Pad 2M PGMS <O-9800'>,,1A,Pad 2M PGMS <O-7'855'>,,27, Pad 2M PGMS <O-9835'>,,28,Pad 2M PGMS <O-6765'>,,26,Pad 2M PGMS <O-74~5'>,,25,Pad 2N PGNS <0 - 9130~>,,19,Pad 2H PGHS <O-7510,>,,3,Pad 2H PGHS <0 - 10598~>,,21,Pad 2N PGNS <0 - 7926~>,,18,Pad 2N PGNS <0 - 12125~>,,13,Pad 2M PGNS <O-7020~>,,15,Pad 2N PGNS <O-S931~>,,5,Pad 2N PGNS <O-(~070~>,,20,Pad 2N PGNS <O-7800~>,,10,Pad 2N PGHS <O-7450~>,,2~,pad 2M PGNS <0 - 9515~>,,11,Pad 2N PGNS <O-6848~>,,16,Pad 2M PGNS <O-10340,>,,7, Pad 2N Ctosest approach with 3-D minirrzmn distance method Last revised Distance M.D. Diverging from M.D. 9-Apr-96 50.0 300.0 300.0 lO-Apr-96 25.0 700.0 700.0 5-Apr-96 1295.1 5000.0 5020.0 11-Nov-92 293.0 0.0 1900.0 5-Apr-96 293.0 0.0 1900.0 2?-Apr-92 112.0 360.0 15060.0 11-Nov-92 218.9 1225.0 5460.0 11-Nov-92 338.0 0.0 12400.0 22-0ct-92 113.0 0.0 0.0 22-0ct-92 33.7 580.0 580.0 5-Jan-93 398.0 0.0 0.0 5-Jan-93 398.0 0.0 0.0 11-Nov-92 413.0 20.0 825.0 22-0ct-92 425.1 620.0 620.0 22-0ct-92 176.9 120.0 120.0 1-Ju[-91 162.0 0.0 9820.0 3-Apr-92 12.0 0.0 15060.0 9-Apr-92 450.2 600.0 600.0 3-Apr-92 62.0 100.0 15065.1 3-Apr-92 10.5 850.0 15020.0 3-Apr-92 132.7 620.0 14680.0 9-Apr-92 79.4 1025.0 12400.0 30-Ju[-92 336.6 1150.0 9820.0 30-Ju[-92 37.0 0.0 15065.1 3-Apr-92 252.7 1200.0 15065.1 30-Ju[-92 136.1 300.0 300.0 3-Apr-92 252.0 540.0 15065.1 1-Ju[-91 53.6 975.0 15060.0 22-Feb-93 323.0 0.0 9860.0 PGMS <0-85~. ~, ,22,Pad 2M PG~IS <O-13385'>,,~2,Pad 2M PGMS <O-9350'>,,30,Pad 2M PGMS <O-11003~> , ,2.Pad 2M PMSS <1078~-13015'>,,29,Pad 2M PflSS <O-11241>,,29,Pad 21,1 PC, MS <O-12151,,8,Pad 2M PGMS <O-12370'>,,4,Pad 2M 31 Version #6,,31,Pad 2M 2M-G Version ~k~,,~M-G,Pad 2M 2M-F/M Version #~,,2~I-F/M,Pad 2M 3-Aug-94 18- Feb-93 11 - Nov- 92 11 - Nov-92 8-Dec-95 1 - Feb-93 6-Jan-93 11 - Nov-92 1 -Apr-96 13-Mar-96 13-Mar-96 513.0 482.9 383.0 468.0 468.0 307.1 368.0 100.0 125.5 71.2 20.0 0.0 200.0 0.0 120.0 120.0 220.0 20.0 700.0 600.0 925.0 320.0 0.0 ZO0.O 9820.0 12220.0 12220.0 3900.0 5640.0 700.0 9820.0 925.0 ARCO ALASKA, inc. Structure : Pad 2M Well : 35 Field : Kuparuk River Unit Location '. North Slope, Alaska I I ~750 I , 3000 2250 ! I I I Wesf s .... ~ : 375.oo 1500 750 0 750 750 _ _ 1500_ O- - r~ 2250_ u - ._O. 3000_ 3750_ 4500_ I I ~ V s25o_ 60O0_ 6750 750 Created by :jones For: D PETRASH~ iDate plotted : lO-Apr-g6 Plot Reference is 35 Version ,!Coordinates are in feet reference slot '=Tr~e Vertical Oepthe ore reference RKB (Porker S 18.79 DEG W 12283' (TO TARGET) SURFACE LOCATION: 114' FSL, 417' FWL SEC. 27, T11N. R8E Bose Permafrost/ Top West Sok Sand? / J EOC Bose West Sak Sands/ 9 5/8 Casing Pt / ComP/Tabasco Sands TARGET ANGLE 50 DEG TARGET LOCATION: 955' FNL, 1741' FWL SEC. 9, TI ON, RSE TARG~ / (;40 'TVD=6358 TMD= 14750 D£P= 12283 EIVED RKB ELEVATION: 147' / APR 1 8 1996 i3.00 KOP TVD=700 TMD=700 DEP=O 9.00 BUILD 3DEG/ 100' 15.00 ' - ' ~'21.00 B/ PERMAFROST TVD=1417 TMD=1435 DEP=140 /C35 Alaska 0~1& ~as Cons.C0mmissi, ~27.00 T/ UGNU SNDS WD=144-7 TMD=1467 DEP=152 / Anchorage ',.Ak,39.33'00 / 39 O0 %4500 r/ W SAK SNDS WD=2025 TUD=2162 DEP=552 'IBegi g p "~-~'1 .oo / '~. 57GQ~. '"~.~b~.O0 EOC TVD=2516 TMD=5098 DEP=1518 /HRZ Midpoint -'"---..,~-,~ B/ W SAK SNDS WD=2691 TMD=3663 DEP=1855 ./'Base HRZ ~ 9 5/8" CSG PT WD=2791 TMD=3986 DEP=2162 /-'-'~K-I Marker Cam~ Sst.~'~-~ TABASCO SNDS TVD=2976 TMD=4582 DEP:2729 ( ~ 185' FNL. 1663' FWL MAXIMUIvl ANGLE "-'"""-'"-'-~c. 5o SEC. 9, TION, RBE 71.94 DEG "--'"-----.~o~~ BEGIN ANGLE DROP TVD=5751 TMD=13532 OEP=Il237 HRZ MIDPOINT I'VD=5933 TMD=14005 DEP=l1671 BASE HRZ TVD=6102 TMD=14553 DEP=11955 K-1 MARKER TVD=6200 TMD=14501 DEP=12091 T/ UNIT C - EOD TVD=6280 TMD=14629 DEP=12191 T/ UNIT A .-VD=6511 TMD=14677 DEP=12227 TARGET - T/ A3 TVD=6358 TMD=14750 DEP=12283 B/ KUP SNDS WD=6432 TMD=14865 DEP=12372 TD - 7" CSG PT TVD=6561 TMD=I5065 DEP=12525 750 750 1500 2250 3000 3750 _ 4500 _ 5250 _ 6000 _ 6750 _ _ 7500 _ _ 8250 _ _ 9000 _ n9750 _ 10500 _11250 _ 2000 2750 -"---. C35 ~- "'"~ 7o.00 -'~64.00 DROP 2 DEG --%58.00 ~-~2.00 \+ I I I I i I i I I i I ! i I I I I I I I I I I I I I I I I I I I 750 i 500 2250 5000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 Scale 1 · 375.00 Vertical Section on 198.79 azimuth wiih reference 0.00 N, 0.00 W from slot #35 0 I I V / lOO' Created by :jones For: D PETRASH'. Date plotted : 10-A~r-96 Pint Reference is 35 Version 28. Caordinotes ere in feet reference slot ~5. :True VerlScal D~p[he ore reference RKB (Parker ~245). I I ¥ ARCO ALASKA, Inc. Structure : Pad 2M Well ; ,55 Field : Kupnruk River Unit Location : North Slope, Alaska~ < West ~o,~,. ~o.oo 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 / ~- / -x. 3500 ~/ co ' ~o~ '~~° ~/~,~oo /~ooo / /,,oo ~ % ~o V' /f~o0 ~ocV ~/ 800 co / 200_ ~0 , 0 _ 220_ 240_ _ 260_ _ 280_ 1 300_ 320 i 240 220 200 , 11oo / / 1600 1200 / , / / / 700 13oo / 1.,~0 ] ~0 140 '~ 20 1 O0 80 RECEIVED APR '1 8 1996 Alaska 011 & ~n~ Cons. Commission Anchorage 1200 ~ 1300 '\ 6 4 _ 0 20 -tO Wesf Scale ] ' 10.00 140 0 I I V Created by : iones For: D PETRASH Dote plotted : 10-,~r-96 Plot Reference is Coordinotes ore in feet reference slot #55. True Vertical Depths ore reference RgB (Por~er ~245). ARCO ALASKA, Inc. Structure : Pad 2M Field : Kuparuk River Unit Well: 55 Location : Nodh Slope, Aloskol < W e s f ~oo,~ ~ . ~o.oo 560 520 480 440 400 560 520 ~ 280 240 200 160 120 80 40 0 40 80 280 15 1 .-i 560 1400 1400 400 !500 1,50o ~j~ / ~,oo r'~oo t 1~0 / 1600 5~0 oo 1800 8~ 720 760 8oo1 840 _ 880 _ -- 920 _ _ 960 _ _ 1000_ _ 1040 2300 / / 1900 / / I 410 560 3~0~u 240 2~0 160 12 ¢ 4'0 80 <-- West ~o,~,. ~o.oo 1900 ~ 2000 o 40 280 320 360 40O 440 48O 52O 560 600 0 640 _~_ '120 II V 76O 800 840 88O 920 960 1000 1040 ~UPARUK RIVER UN,, 20" DIVERTER SCHEMATIC 6 I4 I 5 3 2 ID ' DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 2. 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) RECEIVED APR '! 8 199~ 1. 16" CONDUCTOR, 2. SLIP-ON WELD STARTING HEAD. Alaska 0il & (~s Cons. Commissio~ 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. Anchorage 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 COND,q'IONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 I I I 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. 1 3-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNUl_AR 13 5/8" 5000 PS., BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH 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. o_ CHEC~ THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. AIL OTHERS OPEN. 4. TEST AIL COMPONENTS 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. CCNTINUE 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. P, OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BoI-roM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3(X)O 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 BOPETEST ~E A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. APR 1 g 1996 Naska Oil & Gas Cons. commission Anchorage WELL PERMIT CHECKLIST F, .LD FOOL ? 0 l Or,) ADMINISTRATION ENGINEERING 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party ............... 10. Operator has appropriate bond in force ......... ll. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ........ REMARKS 14. Conductor string provided ............... .~ N 15. Surface casing protects all known USDWs ........ ~Y~ N 16. CMT vol adequate to circulate on conductor & surf csg.. ~ ,~N 17. CMT vol adequate to tie-in long string to surf csg . Y 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. %Y ~' 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 ............ ~ '_i~ ..... ~ N 26. BOPE press rating adequate; test to~(~-/ psig. N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of ~2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide me?~~ . . .Y N 31. Data presented on potential~ones . .... Y N 32. Seismic analysisof?~~g~s zones. ....... Y N 33. Seabed con ' survey (if off-shore) ......... Y N 34._~_Ce~name/phone for weekly progress reports ..... Y N [exploratory only] ENGINEERING: COMMISSION: BEW DWJ-~ HOWBjb - A:~FORMS~cheklist rev 11/95 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 simpl, ify 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 : ARCO ALASKA INC. WELL NAME : 2M-35 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 501032024300 REFERENCE NO : 96172 RECEIVEIJ $ EP 0 5 199(} Alaska Oil'& Gas Cons. Commission Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC REEL NAME : 96172 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., KUPARUK 2M-35, API #50-103-20243-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC TAPE NAME : 96172 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2M-35, API #50-103-20243-00 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2M-35 501032024300 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 20-AUG-96 BIT RUN 1 ......... 96172 R UMINER D. LUTRICK BIT RUN 2 BIT RUN 3 27 liN 8E 114 417 145.60 145.60 104.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 4 O16.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 3RD STRING PRODUCTION STRING REMARKS: THE DATA CONTAINED HEREIN IS THE LOGGING WHILE DRILLING ACQUIRED CDR AND CDN FOR ARCO ALASKA'S 2M- 35 WELL. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 0 O1 CO1 DATE ' 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0. 5000 FILE SUMMARY LDWG TOOL CODE CDR CDN $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4016.0 14905.0 4016.0 12688.0 BASELINE DEPTH 88888.0 14747.5 14727.0 14719.5 14706.0 14685.5 14673.5 14663.0 14656.0 14646 5 14642 5 14634 5 14617 0 14588 5 14578 0 14571 5 14569 5 14567,5 .......... EQUIVALENT UNSHIFTED DEPTH .......... CDR/CDN 88885.5 14745.0 14726.5 14720 0 14707 5 14687 0 14675 0 14665 0 14658 5 14649.5 14644.5 14636.5 14619.0 14589.5 14578.5 14572.5 14570.0 14568.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: 14557.0 14553.0 14549.0 14525 5 14520 0 14510 0 14502 0 14474 5 14467 5 14453 5 14412 5 14395 5 14391 0 14380 0 14372 0 14358 5 14353 0 14315 0 14304 5 14291 5 14289 0 14281 0 14267 0 14248 0 14241 0 14233 0 14230 0 14228 0 14210 5 14190 5 14186.0 14181 0 14172 0 14170 0 14155 5 14124 5 14115 5 14089 0 14080 0 14071 5 14060 5 14055 0 14047 0 14032 5 14007 0 13999 5 13987 0 100 0 $ MERGED DATA SOURCE LDWG TOOL CODE $ 14558.0 14554.0 14549.5 14527.0 14521.0 14512.0 14504.0 14476.0 14467.5 14454.0 14412.0 14394.5 14389.0 14380.0 14372.0 14359.0 14354.0 14315 0 14305 0 14290 5 14288 0 14280 0 14265 0 14246 5 14238 5 14231 5 14228 0 14225 5 14209 0 14190 5 14187 5 14181 5 14173 5 14171 0 14156 0 14125 0 14116 5 14090 5 14082 0 14072 0 14059 0 14054 5 14046 5 14033 0 14007 5 14000 0 13987 5 100 5 BIT RUN NO. MERGE TOP MERGE BASE LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: REMARKS: THIS FILE CONTAINS LOGGING WHILE DRILLING ACQUIRED CDR AND CDN DATA. ONLY ONE BIT RUN OF DRILLING DATA WAS ACQUIRED. THE CDR AND CDN DATA HAS BEEN DEPTH CORRECTED TO THE CEMENT BOND LOG GAI~4A RAY ACQUIRED ON 28-JUL-96. THE CDN TOOL FAILED AT 12783'. NO DATA WAS RECOVERED BEYOND THIS DEPTH. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN KUPARUK RIVER Field Name WN 2M-35 Well Name APIN 501032024300 API Serial Number FL 0114' FSL & 0417' FWL Field Location SECT 27 Sec t i on TOWN 11 N Town ship RANG 8E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN D. LUTRICK Witness Name SON 37951 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 145.6 Above Permanent Datum EKB FT 145.6 Elevation of Kelly Bushing EDF FT 145.6 Elevation of Derrick Floor EGL FT 104.6 Elevation of Ground Level TDD FT 14908. Total Depth - Driller TDL FT 14908. Total Depth - Logger BLI FT 14905. Bottom Log Interval TLI FT 4016. Top Log Interval DFT LSND Drilling Fluid Type DFD G/C3 10.4 Drilling Fluid Density DFPH 8.5 Drilling Fluid Ph DFV S 43. Drilling Fluid Viscosity RMS OHIO4 2.365 Resistivity of Mud Sample MST DEGF 78. Mud Sample Temperature RMFS OH~ff4 2.042 Resistivity of Mud Filtrate S MFST DEGF 78. Mud Filtrate Sample Temperatu TLAB 10:26 31-MAY-96 Time Logger at Bottom BHT DEGF 145. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION FET TIRIE AFTER BIT GR Gamma Ray RHOB Bulk Density DRHO Del ta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity DCAL Differential Caliper GRCH GA~VA RAY IN CASING ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 · LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: 6 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 37951 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0tfl~37951 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~M37951 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~M37951 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~ff~37951 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~M37951 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 37951 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 37951 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 37951 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 37951 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 37951 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD 'BN/E 37951 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 37951 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 37951 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 37951 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI 37951 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 14905.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.I4WD -999.250 DER.MWD -999.250 ROP.MWD 68.699 FET.MWD -999.250 GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 CAL1V. MWD -999.250 NPHI.MWD -999.250 DCAL.MWD -999.250 GRCH.CBT -999.250 DEPT. 3926.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 CALN.MWD -999.250 NPHI.MWD 52.700 DCAL.MWD -999.250 GRCH. CBT -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lqUM~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NOWZ~ER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CDR 4016.0 14908.0 CDN 4016.0 12688.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWN-HOLE 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 CDR RESISTIVITY CDN DENS/NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 2-JUN-96 FAST-2$BO05 V4. OC MEMORY 14908.0 4016.0 14905.0 7O 0.8 73.0 TOOL NUMBER RGS059 NDS086 8.500 4016.0 LSND 10.40 43.0 LIS Tape Verl£'ication Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: MUD PH: 8.5 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 365 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 042 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: LWD RUN 1 RGS059 V4. OC-RES TO BIT: 42.3 ' GR TO BIT: 52.72' NDS086 V4. OC-DEN TO BIT: 95.3 ' NEUTRON TO BIT: 102.28' DRILLED INTERVAL 4027' TO 14908' THIS FILE CONTAINS THE RAW CDR AND CDN LOGGING WHILE DRILLING DA TA . $ LIS FORMAT DATA 78.0 78.0 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN KUPARUK RIVER Field Name WN 2M-35 Wel 1 Name APIN 501032024300 API Serial Number FL 0114' FSL & 0417' FWL Field Location SECT 27 Sec t i on TOWN liN Township RANG 8E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN D. LUTRICK Witness Name SON 37951 Service Order Number PDAT MSL Permanent da Cum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 145.6 Above Permanent Datum EKB FT 145.6 Elevation of Kelly Bushing EDF FT 145.6 Elevation of Derrick Floor EGL FT 104.6 Elevation of Ground Level LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: 9 TUNI VALU DEFI TDD FT 14908. TDL FT 14908. BLI FT 14905. TLI FT 4016. DFT LSND DFD G/C3 10. 4 DFPH 8.5 DFV S 43. RMS OPff/~4 2.365 MST DEGF 78. RMFS Otff4~ 2. 042 MFST DEGF 78. TLAB 10:26 31-MAY-96 BHT DEGF 145. Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Drilling Fluid Ph Drilling Fluid Viscosity Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Time Logger at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY DER DIELECTRIC RESISITIVTY ROPE RATE OF PENETRATION TABR TIME AFTER BIT GR Gamma Ray RHOB Bulk Density DRHO Del ta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER TNPH Thermal Neutron Porosity TABD TIME AFTER BIT DENSITY DPHI Density Porosity DCAL Differential Caliper ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: 10 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 37951 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OP~4~I 37951 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~M37951 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 0H~4~37951 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW! F/HR 37951 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 HR 37951 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 37951 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 37951 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 37951 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW1 BN/E 37951 O0 000 O0 0 2 1 1 4 68 0000000000 CALNLW1 IN 37951 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW1 PU 37951 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 37951 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU 37951 O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW1 IN 37951 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14908. 000 ATR. LW1 -999. 250 PSR. LW1 -999. 250 DER. LW1 ROPE. LW1 68. 699 TABR. LW1 -999. 250 GR. LW1 -999. 250 RHOB. LW1 DRHO.LW1 -999.250 PEF.LW1 -999.250 CALN. LW1 -999.250 TNPH.LW1 TABD.LW1 -999.250 DPHI.LW1 -999.250 DCAL.LW1 -999.250 DEPT. 3926. 000 ATR. LW1 -999. 250 PSR. LW1 -999. 250 DER. LW1 ROPE. LW1 -999. 250 TABR. LWl -999. 250 GR. LW1 - 999. 250 RHOB. LW1 DRHO.LW1 -999.250 PEF.LW1 -999.250 CALN. LW1 -999.250 TNPH.LW1 TABD.LW1 -999.250 DPHI.LW1 -999.250 DCAL.LW1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 52.700 ** END OF DATA ** LIS Tape Verm~ication Listing Schlumberger Alaska Computing Center 20-AUG-1996 14:12 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 96/08/20 ORIGIN : FLIC TAPE NAME : 96172 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~4ENT : ARCO ALASKA INC., KUPARUK 2M-35, API #50-103-20243-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC REEL NAME : 96172 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2M-35, API #50-103-20243-00
