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Home My WebLink About197-205Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-419 50-103-20483-00 910080528 Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-25 0 12 2P-429 50-103-20378-00 910080397 Kuparuk River Multi Finger Caliper Field & Processed 8-Jun-25 0 13 2T-38A 50-103-20229-01 910106462 Kuparuk River Plug Setting Record Field- Final 8-Jun-25 0 14 2Z-07 50-029-20946-00 910026798 Kuparuk River Plug Setting Record Field- Final 10-May-25 0 15 3K-20 50-029-23019-00 910080196 Kuparuk River Packer Setting Record Field- Final 18-May-25 0 16 3N-12 50-029-21582-00 910080396 Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-25 0 17 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 3-Jun-25 0 18 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 4-Jun-25 0 19 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 6-Jun-25 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40597T40598T40599T40600T40601T40602T40602T40602T40602204-017201-102197-205183-064201-088186-0796/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:47:18 -08'00'197-2052T-38A50-103-20229-01 910106462Kuparuk RiverPlugSetting RecordField- Final8-Jun-2501 ORIGINATED TRANSMITTAL DATE: 1/27/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5265 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5265 2T-38A 50103202290100 Plug Setting Record 25-Jan-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 197-205 T40023 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.28 10:10:43 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 1972050 E-Set: 34416 • ConocoPhillps P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ~C~11/ED ~1~sska OA & Gas Cans. Cemr~tissinn ~ncf~araae Iq~~ 3~P Enclosed please fmd 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. These voids were filled with corrosion inhibitor, engineered to prevent water~from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped July 11th, 12th, 13th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, 1 Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7116/10 ~T zu oen ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date --, -.. . Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2T-22 50103202240000 1950860 8" n/a 8" n/a 3.8 7/12/2010 2T 23 50103202160000 1950320 8" n/a 8" n/a 2.1 7/12/2010 2T-27A 50103202170100 2090900 7" n/a 7" n/a 1.7 7/12/2010 2T-32 50103202180000 1950490 36" n/a 36" n/a 11.9 7/12/2010 2T 37 50103202270000 1951010 22" n/a 22" n/a 2.5 7/11/2010 -38A 50103202290100 1972050 8" Na 8" Na 1.7 7/11/2010 2T-203 50103205200000 2051970 22" n/a 22" Na 5.1 7/13/2010 2T-208 50103205180000 2051870 13" Na 15" Na 2.5 7/13/2010 2T 210 50103202730000 1982030 18" Na 18" n/a 5.1 7/12/2010 2T-217A 50103203340100 2000740 8" n/a 8" n/a 1.7 7/12/2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q pert patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate [] Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhilllps Alaska, Inc. Development ~ Exploratory ^ 197-205 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20229-01 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 113', Pad 81' 2T-38A 8. Property Designation: 10. Field/Pool(s): ADL 25568 ' Kuparuk River Field !Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13360' . feet true vertical 6079' feet Plugs (measured) Effective Depth measured 13251' feet Junk (measured) true vertical 6015' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 4593' 9-5/8" 4630' 2864' PROD. CASING 12109' 7" 12144' 5386' LINER 1368' 3-1/2" 13360' 6079' Perforation depth: Measured depth: 12937-12967, 12949'-12951', 13004'-13014~1~y~~~~~ ~(~N ~ ~ 2008 true vertical depth: 5834'-5851', 5850'-5852', 5873'-5879' Tubing (size, grade, and measured depth) 3-1l2" , L-80, 12029' MD. Packers & SSSV (type & measured depth) pkr-- BAKER 'C-2 ZXP' MECHANICAL ISO PKR pkr-- 12006' Camco nipple'DS' landing nipple @ 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 98 ~ 1180 91 -- 235 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 ~ -4C 'C~ Printed Name Guy Schwartz Title - 3 Wells Engineer Signature Phone Date ~-~~ ~ ~g P a b Sharon A/I u Drake 263-4612 ~ e ~ ~ F~. ~uF~ ~ ~ ~ s:~'°8 Form 10-404 Rev ed 04/2006 7~Q~ Submit Ori ' al O ~~~~~~ 2T-38A Well Events Summary • DATE SUMMARY 8/3/07 TAGGED ICE @ 1784' WLM 8/5/07 Perform Jet Ice, Rih with 1.75 DJN, Pumped 120 degree diesel, RIH to 12,944 CTMD, Jet top of TTS Sleeve, Freeze protected Well, Left S/I, Turned over to W/L. 8/9/07 ATTEMPT TO PULL FRAC SKIRT @ 12926' RKB AND ENCOUNTERED FRAC / FORMATION SAND. BAILED FRAC /FORMATION SAND FROM ONTOP OF FRAC SKIRT. 8/10/07 BAILED APPROX. 4 GALLONS OF FORMATION SAND @ 12921' RKB (APPROX 5' OF FILL ONTOP OF FRAC SKIRT @ 12926' RKB ). 8/11/07 BAILED (FRAC /FORMATION SAND) DOWN TO AND TAGGED FRAC SKIRT W/ 2.5 BAILER @ 12924' RKB. 8/12/07 LATCHED TTS FRAC SKIRT 12924' RKB, BEAT UP FOR 1.25 HO ,~I~ @ 1900 LBS W/ NO MOVEMENT. 8/15/_07 BAILED FILL FROM INSIDE FISH NECK OF FRAC SKIRT @ 12924' RKB. SET BAIT SUB, 2' STEM, AND 3-1/2 GS IN FRAC SKIRT AND BEAT UP FOR 1.25 HR, NO MOVEMENT. IN PROGRESS. 8/16/07 ATTEMPTED PULL FRAC SKIRT Cad 12924' RKB. BEAT UP FOR 3 HOURS, NO MOVEMENT. ATTEMPTED SHEAR BAITED GS, UNABLE TO SHEAR AFTER 1 HOUR OF JARRING DOWN. BAIT SUB 8~ GS ENGAGED IN FRAC SKIRT (35" OAL). 8/21/07 ATTEMPT TO PULL GS BAITED FRAC SKIRT AT 12924' RKB. BEAT UP WITH 2.13" BAKKE HAMMER FOR 5 HOURS. UNABLE TO PUMP OUT OF G SPEAR. DROP BALL AN_D HYDRAULICALLY DISCONNECT. ABLE TO PUMP THROUGH HAMMER AT 2 BPM AT 4600 PSI WITH WEIGHT STACKED OUT- NOT CONCLUSIVE WEATHER 5K RUPTURE DISK BURST. 2" GS PROFILE BOX LOOKING UP. (TOTAL LENGTH OF WF FISH LEFT IN HOLE 13.0' -NOT INCLUDING ~65" OF BAITED FRAC SKIRT.) 8/26/07 Attempt to pull GS baited frac skirt & 13' coil fish RIH with Jars & 2.5 GS, Second attempt appeared to latch, 19k over pull, 1 jar lick, PUH 3k over pull No fish surface, Heavy formation sand on tools, Will return in A.M. to clean out & Fish. 8/27/07 Attempt to pull GS baited frac skirt & 13' coil fish, Made first run with 1.75 JSN, cleaned fishing neck & tubing, POOH, installed Jars & 2.5 GS, Latched on first attempt, hit 16 up jar licks, Lost jar action, max pump rate is 0.1 BPM, Dropped ball, No success with disconnect, Dry watch, return in A.M. 8/28/07 Attempt to unlatch from fish, Continue to bleed off coil pressure ~ pump up to 7k to get ball to disconnect, Rigged up cement pump, Pumped 9k, third attempt disconnect activated, POOH. Well left S/I 8~ Freeze protected. 10/27/07 DRIFTED TBG & TAGGED FILL IN TBG .12882' WLM 11/6/07 PERFORM FILL CLEAN OUT FROM 12800' CTMD TO TOP OF LOST TOOL STRING Cad 12933' CTMD.LEFT WELL SHUT IN AND FREEZE PROTECTED.RETURN IN AM TO START FISHING OPERATION.JOB IN PROGRESS. 11/7/07 RUN #1=MU AND RIH WITH 2.70" WASH PIPE WITH TATTLE TALES AND WASH DOWN TO TOP OF FRAC SKIRT @ 12943' CTMD. RUN #2=MU AND RIH WITH D.A. JAR AND 2.125" G SPEAR AND LATCH TOP OF LOST BHA @ 12940' CTMD.MADE SEVERAL ATTEMPT TO PULL FISH WITH NO SUCCESS.LEFT WELL SHUT IN AND FREEZE PROTECTED.WILL RETURN IN AM TO CONTINUE WITH FISHING OPERATION.JOB IN-PROGRESS. 11/8/07 MU AND RIH WITH A 4' SECTION ON WASH-OVER PIPE WITH A 2.125" G SPEAR AND MADE SEVERAL ATTEMPT TO LATCH FISH WITH NO SUCCESS. RUN #2.MU AND RIH WITH SAME SPEAR AND A 2.60" OS CENTRALIZER AND LATCH THE TOP SECTION OF LOST BHA @ 12941' CTMD AND PULLED THE BAKER DISCONNECT AND THE 2.5" SPEAR.WILL RETURN IN THE AM TO CONTINUE WITH FISHING OPERATION. 2T-38A Well Events Summary 11/9/07 MU AND RIH WITH D.A. JARS AND 2.125" G SPEAR AND RETREIVE ALL THE LOST TOOL FROM TOP OF FRAC SKIRT.ALL TOOL WAS COVER WITH FRAC SAND.WILL RETURN IN AM TO PERFORM FCO BEFORE TRYING TO FISH FRAC SKIRT. 11/10/07 RUN #1 - MU AND RIH WITH SLIM BHA AND CLEAN OUT FRAC DOWN TO TOP OF FRAC SKIRT Ca)_ 12955' CTMD.SEEN GOOD INDICATION OF JETTING ACTION INSIDE SKIRT FROM INCREASE OF TUBING PRESSURE WHILE CLEANING OUT FILL. RUN #2 - MU AND RIH WITH WEATHERFORD 3.5" G-SPEAR AND 2.125" IMPACT TOOL AND MADE SEVERAL ATTEMPT TO LATCH FRAC SKIRT @ 12961 CTMD WITH NO SUCCESS.LEFT WELL SHUT AND FREEZE PROTECT FOR ONE MORE TRY IN AM.JOB INCOMPLETE. 11/11/07 MADE SEVERAL ATTEMPTS TO LATCH FRAC SKIRT WITH NO SUCCESS. LEFT WELL S/I FREEZE PROTECTED FOR SLICKLINE TO TROUBLE SHOOT TOP OF FRAC SKIRT. 2/10/08 DRIFTED TBG TO 4500' WLM WITH 1.60" DRIFT. TOOLS NOT FALLING WITHOUT ROLLER STEM. PATCH ID @ 12926' TOO SMALL TO PASS ROLLER -STEM. JOB ABORTED. 4/3/08 TAGGED @ 12911' SLM WITH 2.66" CENTRALIZER & 1.5" DD BAILER. NO RECOVERY IN BAILER. I~AETAL MARKS ON CENTRALIZER INDICATED FULL _ BAILER PENETRATION OF PATCH. IN PROGRESS. 4/5/08 AGGED PATCH @ 12927' SLM WITH 10' x 1.5" BAILER. RECOVERED SMALL SAMPLE OF CARBOLITE. MARKS ON CENTRALIZER INDICATE FULL BAILER PENETRATION OF PATCH. READY TO PERF PATCH. 4/22/08 PERFORATED EXISTING PATCH IN PLACE OVER THE C4lA3 SAND PERFS. SHOT 9 TUBING PUNCHER HOLES FROM 12949' - 12951'. WHP DROPPED FROM 900 TO 850 PSI WHEN GUN FIRED AND SLOWLY BUILT BACK UP. ,, Wellbore APpUWI FiaYd Name WellSbtus 501032022901 KUPARUK RIVER UNIT PROD Comment H23 (ppm) Dab Annobtlon End Date Well l;onfig. - 2T-38A, 4!?7l.L008 12.36--_ NIPPLE Camco'DS' 30 10/1&2000 Last WO: Sr_hemalC-AG(u2 Annobtlon Depth ptKB) End Date Amwbtlon Last Tag: ~ 13,251.0 8/16/2006 Rev Reason: ADD PERFORATION u,: awn :.x'~•i`~~ ..~ t' ~ Casing Desorlptbn OD (In) ID (in) ToP (TtK6) Set Depth (ftKB)SSet De { i ~ F~ I CONDUCTOR 16 15.062 0.0 121.0 SURFACE 9 SIS 8.697 0.0 4,630.0 CONDUCTOR ~ E PRODUCTION 7 , 6.151 0.0 12 144.0 1 t ' LINER 3 112 2.992 11 992.0 13 360.0 ( a / 4 P 32T-38A . r~„ i I,L~:~. DePih (ftKB) 13.360.0 2elease Date 8/5/1995 Pate 4/26/2008 Too Thread SSSV, 512- i - Tubing Desedp0on OD (In) ID Iin1 ~ Top (StlIB) Set Depth (Ml8) Set Depth IIVD/ If11(B) Wf (IbsNt) ~ C+rede ToP Than j (, TUBING 3 1/2 i __ 0.0 12,029.0 ~-1.71 9 30 L-P~0 Ei E 4i.D P,nJD GAS LIFT, 3,084- , SURFACE GAS LIFT, 6,133 GAS LIFT, 8,618 GAS LIFT, 10,537 GAS LIFT, 11,943-- NIP, 11,989 TIEBACK 11,992 1 I SEAL, 11,998 /~ ` 1 t PKR. 12,008 ,1 i PRODUCTION PATCH, 12,928 .e (OAL 13.71' 1 625 MIN ID QD 12939' 11/15/2006 PERFORATED ON 4/2212008 ' ,k sna cal~`B ~ Top (TVD) Btm (TVD) Dens Shot Top (ftK6) Btm (ftK8) (itl(B) Imce) Typa Tons (shot... Tobl Dab Comment 12,937.0 12,947.0 5,643.0 5,848.8 APERF C-4, 4.0 40 4/1211998 180 deg. phasing, no orient; 2 1/2" 2T-38A BH 2T-38A TD (2T-38A), 13,360 . . KI::. t.; tJ V t.: U STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION .Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage JUL 3 1 Z007 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate 0 I Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 197-2051 / 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20229-01 / 7. KB Elevation (ft): 9. Well Name and Number: RKB 113', Pad 81' 2T -38A ..- 8. Property Designation: 10. Field/Pool(s): ADL 25568, 'ALK 2666 Kuparuk River Field 1 Kuparuk Oil Pool / 11. Present Well Condition Summary: Total Depth measured 13360' / feet true vertical 6079' / feet Plugs (measured) Effective Depth measured 13251 ' feet Junk (measured) true vertical 6015' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 4593' 9-5/8" 4630' 2864' PROD. CASING 12109' 7" 12144' 5386' LINER 1368' 3-1/2" 13360' 6079' Perforation depth: Measured depth: 12937'-12967',13004'-13014' SCANNED AUG 1 ,42007 true vertical depth: 5834'-5851',5873'-5879' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12029' MD. Packers & SSSV (type & measured depth) pkr- BAKER 'C-2 ZXP' MECHANICAL ISO pkr= 12006' Cameo 'OS' landing nipple @ 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13004-13014' MD Treatment descriptions including volumes used and final pressure: pumped 95334# of 16/20 carbo-lite 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation SI -- Subsequent to operation 108 / 915 417 -- 275 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development 0/ Service D Daily Report of Well Operations _X 16. Well Status after work: oil0 / GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John pei~ Title Wells Group Engineer 7/3oll!>7 Signature ~,4~ ,~- Phone Date Prenared bv Sharon AI/sun-Drake 263-4612 I 7 ~ - ~ 8·fl·t:J7 Form 10-404 Revised 04/2006 0 R t GIN A L RBDMS BFL AUG 13100~<'£f\. S~~,7 . 2T-38A Well Events Summary . DATE Summary 10/26/06 ATTEMPT TO DRIFT TBG W/22' X 2.74" BUT WIRE JUMPED TOP SHEAVE @ 2130' SLM. ORDERED UP MAN LIFT & PUT WIRE BACK IN THE SHEAVE AND POOH. JOB IN PROGRESS. 10/27/06 DRIFTED TBG W/22' X 2.74" W/ NO PROBLEMS TO D NIPPLE @ 11984' RKB. UNABLE TO GET DRIFT PAST D NIPPLE W/ PUMP ASST. TBG PRESSURED UP W/ DRIFT IN THE NIPPLE-HAD TO WORK DRIFT BACK OUT OF THE NIPPLE. JOB SUSPENDED. 11/2/06 DRIFT TGB W/20 DUMMY PATCH (2.72" ON TOP & BTM W/ SPACER PIPE) TO 13020' SLM, NO PROBLEMS. IN PROGRESS. 11/3/06 BRUSHED & FLUSHED BETWEEN 12900' TO 13000' SLM. 11/8/06 ATTEMPT TO SET TTS PACKER INCOMPLETE. TEMPORARILY STUCK IN D NIPPLE AT 11989', ABLE TO WORK FREE WITH A 800# OVERPULL (D NIPPLE ID= 2.75", MAX PACKER OD= 2.7205"). ** UPDATE: LATER DISCOVERED THAT TTS SETTING ADAPTOR WAS OVERSIZED. 11/11/06 SET TTS PARAGON II PATCH LOWER PACKER WITH MID ELEMENT AT 12973' ELMD. TTS CROSS FLOW SETTING ADAPTER USED, SHEAR DISK PINNED TO 3200 PSI. WELL LEFT SHUT IN. 11/14/06 SET PATCH SPACER (SNAP LATCH, SPACER PIPE, PBR; OAL: 33.5',1.625" MIN ID) @ 12971'. IN PROGRESS. 11/15/06 SET SNAP LATCH, SPACER, & 3" TTS PACKER (OAL 13.71',1.625" MIN ID @ 12939'. TEST PKR 3500 PSI, GOOD. SHEARED CERAMIC DISC @ 12976'. WELL READY FOR FRAC. 7/5/07 TAG PATCH ASSY @ 12926' RKB WITH 2.72" GAUGE RING.SET TTS FRAC SKIRT @ 12926' RKB 7/13/07 ATTEMPT TO FRAC A2 SAND. PUMPED 95334# OF 16/20 CARBO-LITE PLACING 60278# BEHIND PIPE. SCREENED OUT WITH 11950# OF 10 PPA STAGE IN PERFS. UNABLE TO FLUSH WELLBORE, LEAVING 35056# IN TUBING. 7/15/07 Late start due to previous days cement job. RIH w/ slick seawater and biozan sweeps. Took heavy returns of frac sand starting at 500' CTMD. Continued FCO down to 6000'. Good 1 to 1 returns. Chase Bio sweep out while POOH, RB CTU for night to complete FCO in the AM. 7/16/07 FINISH FCO FROM PREVIOUS DAY. STARTED CLEAN OUT AT 6000', RIH W/ SLICK SEAWATER AND BIOZAN GEL SWEEPS. SAW BETTER THAN 1 FOR 1 RETURNS WITH FRAC SAND, SAWWHP INCREASES INDICATING WELL STIMULATED BY FRAC. TAGGED PATCH OVER UPPER SANDS AT 12947' CTMD. POOH, CLEANED BELLY AT 6274'. FREEZE PROTECT FROM 4000' TO SURFACE. 7/17/07 GAUGED TBG TO 2.70" TO PATCH @ 12926' RKB. IN PROGRESS. 7/18/07 SET CATCHER SUB @ 12926' RKB. PULLED DVs @ 11943', 10537',8618',6133' & 3084' RKB. IN PROGRESS. 7/19/07 SET GLVs @ 3084',6133' & 8618' RKB, DV @ 10537' RKB, OV @ 11943' RKB. IN PROGRESS. 7/20/07 VERIFIED OV SET @ 11943' RKB. PULLED EMPTY CATCHER SUB @ 12926' RKB. COMPLETE. . . 2T-38A Well Events Summary 7/28/07 GAUGED TBG TO 2.5' TO 12878' WLM, NO INDICATION OF PACKOFF. THICK FLUID, SLOW PROGRESS. R/D FOR TBG WASH PRIOR TO PULLING PATCH. . . ConocoPhillips Alaska,lnc. KRU 2T -38A API: 501002022901 Well Tvoe: PROD Angle@TS: 54dec@12œ1 W SSSV Type: Nipple Orig 12/2/1997 Angle @ TD: 54 deg @ 13360 NIP (512-513, Comcletion: OD:3.500) Annular Fluid: Last W/O: Rev Reason: GLVC/O TUBING Reference Loa: Ref Loa Date: Last Uodate: 7/22/2007 (0-12029, Last Tac: 13251' RKB TD: 13360 ftKB OD:3.500, LastTac Date: 8/16/2006 Max Hole Ancle: 72d&6274 ID:2.992) ~ ~ DescrlDtion Size TOD Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 121 121 62.58 H-40 MandrelNalve SUR. CASING 9.625 0 4630 2864 40.00 L-BO 1 (3084-3085, PROD. CASING 7.000 0 12144 5386 26.00 L-BO LINER 3.500 11992 13360 13360 9.30 L-BO EUE AB " MOD Gas Lift ... Size TOD Bottom I t Wt I Grade I rhread MandrelNalve 3.500 I 0 I 12029 I 5333 I 9.30 I L-80 L EUE 8RD MOD 2 '1111111"';+ (61~134. Interval TVD Zone Status Ft SPF Date Type Comment 12937 - 12947 5834 - 5840 C-4 10 4 4/12/1998 APERF 180 deg. phasing, no orient; 2 1/2" BH W 12947 - 12967 5840 - 5851 A-3 20 4 12/8/1997 IPERF 180 OOg. phasing; 21/2" Gas Lift HCC MandrelNalve 13004 -13014 5873 - 5879 A-2 10 6 8/22/2006 APERF 2.5" HSD PowerJet HMX 60 3 d ohasino (8618-8619. St MD TVD Man Mfr Man Type VMfr V Type VOD Latch pon TRO Date Run VIv Cmnt 1 3084 2364 Cameo KBUG GLV 1.0 BK 0.188 1407 7/19/2007 Gas Lift M 2 6133 3369 Cameo KBUG GLV 1.0 BK 0.188 1398 7/19/2007 I ndrel/Dummy Valve 4 3 8618 4171 Cameo KBUG GLV 1.0 BK 0.188 1388 7/19/2007 10537-10538, 4 10537 4791 Cameo KBUG DMY 1.0 BK 0.000 0 1 0/5/2006 OD:5.390) 5 119"293 Cameo MMM OV 1.0 RK 0.188 0 7/19/2007 DeDth TVDe Description 10 Gas Lift 512 512 NIP Cameo 'DS' Landino Niocle 2.812 MandrelNalve 11989 5314 NIP Cameo 'D' Nicole NO GO 2.750 5 11992 5316 TIE-BACK Baker 5.250 11943-11944, 00:6.018) 11998 5318 SEAL Baker 'GBH-22' Seal Assv 3.000 12006 5322 PKR Baker 'C-2 ZXP Mechanical Iso Pkr 5.000 12926 5828 PATCH SET SNAP LATCH, SPACER (OAL 33.5') w/SHEAR DISC" & 3" TIS 1.625 PACKER (OAL 13.71', 1.625" MIN ID @ 12939'. 11/15/2006 NIP ~ 11989-11990, OD:3.500) TIE-BACK ... r: 11992-11993, OD:5.938) lid SEAL ~ '11998-11999, OD:3.984) PKR 12006-12007, OD:6.151) Perf -= I-- 12937-12947) - f-- PATCH - '12926-12973, .....---. .......... OD:2.720) Perf - - 12947-12967) - - - - Perf - - 13004-13014) - - - - - - - f--- . . RECEIVED SEP 1 5 200b STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commis: 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 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 0 197-2051 , 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20229-01 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 113', Pad 81' 2T -38A 8. Property Designation: 10. Field/Pool(s): , ADL 25568, ALK 2666 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13360' feet true vertical 6079' feet Plugs (measured) Effective Depth measured 13251 ' feet Junk (measured) true vertical 6015' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 4593' 9-5/8" 4630' 2864' PROD. CASING 12109' 7" 12144' 5386' LINER 1368' 3-1/2" 13360' 6079' Rtl\NNer! <:çp 2 C" Zf,r;E Perforation depth: Measured depth: 12937'-12967',13004'-13014' I,,¡i ·c. ." / :"J~~ -c' ~I ~IIJ - true vertical depth: 5834'-5851',5873'-5879' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12029' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'C-2 ZXP' MECHANICAL ISO PKR pkr= 12006' Cameo 'DS' landing nipple 512' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casina Pressure Tubina Pressure Prior to well operation SI Subsequent to operation SI' 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: oil0 . GasO WAG 0 GINJO WINJO WDSPL 0 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: Contact Howard Gober Printed Name Howard Gober Title Wells Group Engineer ~ ~ Signature ""-;;;>..A ¿o? Phone Date 1 If o(p ! PreDared bv Sharon Al/suD-Drake 263-4612 thct¡)-V ,£b f'.'f .0(:.. Form 10-404 Revised 04/2004 ORIGINAl RBDMS 8Ft SEP 2 8 2û06 SUbm~.it inal onl~. . ~ 90;/rtJ . 2T-38 Well Events Summary . DATE Summary 8/16/06 TAGGED @ 13251' RKB, EST. 284' RATHOLE. ATTEMPTED DRIFT TBG WITH 10' x 2.50" SPENT DUMMY GUN. UNABLE TO WORK PAST 8870' WITH 1-1/2 BPM PUMP ASSIST. 8/19/06 BUSHED AND FLUSHED TBG TO 13214' RKB. IN PROGRESS. 8/20/06 DRIFTED TBG TO 13100' RKB WITH 10' x 2.50" DUMMY GUN WITH 3' ROLLER STEM TOP & BOTTOM. 8/22/06 PERFORATED THE INTERVAL 13004'-13014' WITH 2.5" HSD, LOADED W/2506 POWERJET HMX AT 6 SPF, 60 DEG PHASING. API PENETRATION: 18.7". ENTRANCE HOLE: 0.34". DID NOT TAG TD, WELL LEFT SHUT IN. . ConocoPhillips Alaska, Inc. . KRU 2r -38A ,)T "". ^ API: 501032022901 Well Type: PROD Anç¡le lCì) TS: 54 dea lCì) 12931 SSSV Type: Nipple Orig 12/2/1997 Angle @ TD: 54 deg @ 13360 NIP (512-513, Completion: OD:3.500) Annular Fluid: Last W/O: Rev Reason: APERF TUBING Reference Loa: Ref Loa Date: Last UDdate: 8/26/2006 (0-12029, Last Taç¡: 13251' RKB TD: 13360 ftKB OD:3.500, Last Taa Date: 8/16/2006 Max HOleA~6274 ID:2.992) Casi Description Size Top Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 121 121 62.58 H-40 MandrelNalve SUR. CASING 9.625 0 4630 2864 40.00 L-80 1 PROD. CASING 7.000 0 12144 5386 26.00 L-80 (3084-3085, LINER 3.500 11992 13360 13360 9.30 L-80 EUE AB MOD Size I Top I Bottom I TVD 1 Wt I Grade Thread Gas Lift 3.500 I 0 I 12029 I 5333 I 9.30 I L-80 EUE 8RD MOD MandrelNalve 2 (6133-6134, Interval TVD Zone Status Ft SPF Date Type Comment 12937 - 12947 5834 - 5840 C-4 10 4 4/12/1998 APERF 180 deg. phasing, no orient; 2 1/2" BH 12947 - 12967 5840 - 5851 A-3 20 4 12/8/1997 IPERF 180 deg. phasing; 21/2" Gas Lift HCC MandrelNalve 13004 - 13014 5873 - 5879 A-2 10 6 8/2212006 APERF 2.5" HSD Power Jet HMX 60 3 dea. Dhasina (8618-8619. Ga~ St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3084 2364 Cameo KBUG GLV 0.0 BK 0.156 1245 5/2/1998 Gas Lift 2 6133 3369 Cameo KBUG GLV 0.0 BK 0.188 1274 5/2/1998 MandrelNalve 3 8618 4171 Cameo KBUG GLV 0.0 BK 0.188 1268 5/1/1998 4 10537-10538, 4 10537 4791 Cameo KBUG GLV 0.0 BK 0.188 1258 5/1/1998 OD:5.390) 5 11943 5293 Cameo MMM OV 0.0 RK 0.156 0 5/1/1998 I Other (I )Iuc IS. ,nui ...tt' I C\AlCI !:IV Depth TVD Type Description ID Gas Lift 512 512 NIP Cameo 'OS' Landina Nipple 2.812 MandrelNalve 11989 5314 NIP Cameo 'D' Nipple NO GO 2.750 5 11992 5316 TIE-BACK Baker 5.250 11943-11944, 11998 5318 SEAL Baker 'GBH-22' Seal Assy 3.000 OD:6.018) 12006 5322 PKR Baker 'C-2 ZXP' Meehanicallso Pkr 5.000 NIP :11989-11990. OD:3.500) TIE-BACK !=II 11992-11993. OD:5.938) ~ SEAL 11998-11999, OD:3.984) PKR 12006-12007. OD:6.151) I Perf ~ f---- 12937-12947) - f---- Perf - f---- 12947-12967) - f---- LINER - I----- 11992-13360, OD:3.500. - - Wt:9.30) - - Perf - - 13004-13014) - - - f---- - f---- - f---- THE MATERIAL UNDER THIS COVER HAS BEEN- MICROFILMED · . ON OR BEFORE JANUARY 03 2001 P L M ATE THIS W IA L UNDER M A R K E R C:I..,ORBIVIFILM.DOC Well Report RIV UNIT 2T-38A ~omomp. 01 / 12 / 1998 Completion Status: 1-OIL Current Status 103-20229-01 197-205-0 ARCO MD 1336gTVD 06079 Name Interval Sent Received BO 8201 ~ SPERRY MPT/GR/EWR4 12/17/97 12/17/97 DGR/EWR4-MD ~/~-~I~AL 12132-13360 12/23/97 12/24/97 DGR/EWR4-TVD ~AL 5399-6079 12/23/97 12/24/97 MWD SRVY ~ SPERRY 12059.- 13360. 12/19/97 12/24/97 · MWD SRVY ~ 12058.96-13360. 1/29/98 2/4/98 Was the well cored? yes ~ Comments: Are Dry Ditch Samples Required? yes ~_~d Received?-'~o--~ Analysis Description Receiv ~[2~ample~ '~-~' Monday, January 10, 2000 Page 1 of 1 STATE OF ALASKA -~: ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development _X. 41' RKE 3. Address: Exploratory . 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 65' FSL, 556' FWL, Sec 1, T11 N, R8E, UM 2T-38A At top of productive interval: 9. Permit number/approval number: 2429' FNL, 901' FWL, Sec 10, T11N, R8E, UM 97-205 At effective depth: 10. APl number: 2197' FNL, 586' FWL, Sec 10, T11N, R8E, UM 50-103-20229-01 At total depth: 1 I. Field/Pool: 2149' FNL, 522' FWL, Sec 10, T11N, R8E, UM Kuparuk River Field / Oil Pool 12, Present well condition summary Total Depth: measured 13360 feet Plugs (measured) None true vertical 6079 feet Effective Deptl measured 13262 feet Junk(measured) None true vertical 6022 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 103 Sx AS I 115' 115' Surface 4593' 9-5/8" 870 Sx AS III & 4630' 2864' 810 Sx Class G Production 12109' 7" 230 Sx Class G 12144' 5386' Liner 1368' 3.5" 256 Sx Class G 13360' 6079' Perforation Depth measured 12937'-12967' ,, true Medical 5834'-5851' · Tubing (size, grade, and measured depth) · 3.5", 9.3 Ib/ft, L-80 @ 12029' Packers and SSSV (type and measured depth) :-'i::~t:.:~ :-,: ...... ~i' :"~.'. '~:; Packer: Baker LT w/tie back @ 11992'; SSSV: None, nipple @ 512' /;,i'~,Z~;~!~'Y" 13. Stimulation or cement squeeze summary Perforate "C" sands on 4/12/98. Intervals treated (measured) NAL 12937'-12947' OR!Gl Treatment description including volumes used and final pressure Perforated using 2.5" guns w/BH charges @ 4 spt, 180 deg phasing, no orientation, fp was 1000 psi. 14. Representitive Daily Average Production or Injection Data · OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 216 947 2 775 325 Subsequent to operation 211 831 2 1112 298 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Production Engineering Supervisor Date ~/Z-Z,, Form 10-404 R~ V ~)o'~15/88 SUBMIT IN DUPLICATE. ... AFI~:O Alaska, Inc. ](UPARUK RIVER UNIT '[ "--~ELL SERVICE REPORT '~' K1(T-38A(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-38A FRAC, FRAC SUPPORT 0407981020.12 DATE DAILY WORK UNIT NUMBER 04/1 2/98 PERFORATE - FRAC SUPPORT, REPERFORATE A SANDS 2128 DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O No] (~) Yes ~) No BARTZ JONES FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE KD2050 230DS28TL $9,725 $14,140 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann ~ Final Outer,~nn 350 PSI 1000 PSI 750 PSI 750 PSII 0 PSII 0 PSI DALLY SUMMARY SWS (BARTZ & CREW)PERFORATED A SANDS WITH 10', 2.5", BH, 4 SPF, 180 DEC PHASED, NO ORIENTATION FROM TIME LOG ENTRY 10:00 SWS (BARTZ & CREW) SPOTED EQUIPMENT, WAIT ON LRS. LATE START, ROAD BLOCKED. 11:00 LRS MIRU, PUMPED DOWN TBG W/3 BBLS METHANOL & 50 BBLS HOT DIESEL @ I BPM, 1200#. SWS RIGGED UP DURING PUMPING. 12:15 SECURED RADIO SILENCE, HELD TGSM. MU GUN & PT LUBRICATOR TO 3000#. 13:30 RIH W/10', 2.5" PERF GUN, BH, 4 SPF, 180 DER PHASE, NOT ORIENTED W/2.5" PERTALINE ROLLERS ABOVE & BELOW GUN, SWIVEL & GUN GR, FELL FREE TO 10,700'. HAD TO PUMP DOWN W/HOT DIESEL @ 1.5 BPM, 1250#. CORRILATE &.PERFORATE FROM 12,937' TO 12,947'. 16:30 POH TO 500' W/NO RESTRICTIONS. 17:30 WAIT ON FRAC CREW (USING RADIO'S). 18:00 POH & LD GUN, ALL SHOTS FIRED. 18:30 RIG DOWN & MOVE OFF. RETURNED WELL TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $1,105.00 $1,588.50 APC $250.00 $1,855.00 HALLIBURTON $0.00 $1,227.00 LITTLE RED $1,540.00 $2,640.00 SCHLUMBERGER $6,830.00 $6,830.00 TOTAL FIELD ESTIMATE $9,725.00 $14,140.50 ~' STATE OF ALASKA '-~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 41' RKE 3. Address: Exploratory~. 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 65' FSL, 556' FWL, See 1, T11N, R8E, UM 2T-38A At top of productive interval: 9. Permit number/approval number: 2429' FNL, 901' FWL, Sec 10, 1'11N, FI8E, UM 97-205 At effective depth: 10. APl number: 2197' FNL, 586' FWL, Sec 10, T11N, R8E, UM 50-103-20229-01 At total depth: 11. Field/Pool: 2149' FNL, 522' FWL, Sec 10, T11N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 13360 feet Plugs (measured) None true vertical 6079 feet Effective Depfl measured 13262 feet Junk (measured) None true vertical 6022 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 103 Sx AS I 115' 115' Surface 4593' 9-5/8" 870 Sx AS III & 4630' 2864' 810 Sx Class G Production 12109' 7" 230 Sx Class G 12144' 5386' Liner 1368' 3.5" 256 Sx Class G 13360' 6079' Perforation Depth measured 12937'-12967' true vertical 5834'-5851' . Tubing (size, grade, and measured depth) 3.5", g.3 Ib/ft, L-80 @ 12029' Packers and SSSV (type and measured depth) ' Packer: Baker LT w/tie back @ 11992'; SSSV: None, nipple @ 512' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 4/19/98. Intervals treated (measured) 12937'- 12967' Treatment description including volumes used and final pressure Pumped 91,000 lbs of 16/20 and 12/18 ceramic proppant into formation, fp was 8800 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 216 947 2 775 325 Subsequent to operation 211 831 2 1112 298 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __ZX Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~/~'/~ -"-'---- Title: Production Engineering Supervisor Date ~/ZZ.,/~ ct Pnrm 1N-/1NZt F.)~/~/1 /P,,~, ql IRI~AIT INI i-hi IDI ARCO Alaska, Inc. (UPARUK RIVER V 'ELL SERVICE REPORT '~' K1(T-38A(W4-6)) __ WELL JOB SCOPE JOB NUMBER 2T-38A FRAC, FRAC SUPPORT .0407981020.12 DATE DAILY WORK UNIT NUMBER 04/1 9/98 PUMP "A" SANDS RE-FRAC . DAY OPERATION COMPLEI E I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes (~') NoI (~ Yes O No DS-YOKUM JOHNS ESTI MATE KD2050 230DS28TL $100,563 $130,215 '- Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann J Initial Out 874 PSI 0 PSI 500 PSI 500 PSI DALLY SUMMARY PUMPED "A" SANDS RE-FRAC , WITH 91,000# TO 12/18 PROP , 7.2 PPA. TO PERFS. SCREENED OUT EARLY, LEFT 33,0130 # PROP IN PIPE. ( DESIGN FRAC 254,000# ) TIME 07:00 07:45 08:20 08:47 08:48 10:46 12:41 13:12 '13:19 14:02 15:00 LOG ENTRY MIRU DOWELL FRAC EQUIP. , LITTLE RED PUMP AND APC SUPPORT. HELD SAFETY MEETING. ATTEMPT TO PT, LEAK IN MISSLE VALVE , SHUTDOWN TEST TO REPAIR LEAK. PRESSURE TEST SURFACE LINE TO 10,200 PSI , OK. PUMP BREAKDOWN , 25 BPM 8200 PSI AND 100 BBLS 50# GEL ,. PUMP 2000# 16/20 PROPPAN~' AT 1 PPA , PUMP 50 BBLS FLUSH 15 BPM , PUMP 5700# 16/20 PROP AT 2 PPA. PUMP 75 BBLS 50# GEL. PUMP 144 BBLS SEAWATER , 15 BPM AND 6514 PSI. SHUTDOWN AND PULSE TEST. PUMP 250 BBLS FLUIDS FOR DATA FRAC AND FLUSH , 15 BPM AND6880 PSI. SHUT DOWN FOR ISIP 2325 PSI AND CLOSURE CALCULATION. ~ PUMP 255 BBLS , 50 # GEL AT 5 TO 15 BPM 7400 PSI. FOR PAD. PUMP 7719# 16/20 PROPPANT , 2PPA', 15.BPM AND 6939 PSI. PUMP 108,983 # 12/18 PROPPANT 6 TO 9 PPA , 15 BPM AND 6000 PSI AVG. , SCREENED OUT FRAC , WITH 91,000 # TO 12/18 7.2 PPA AT PERFS. MAX. PRESSURE 8800 PSI. SHUT DOWN , LEFT 33,983# PRopPANT IN PIPE. ~ NOTE: LEFT SOME RUBBER FROM TREE SAVER IN TOP OF TREE, CTU CAN LOOK FOR IT DURING CLEANOUT. E~T. BHP = 3100 PSI. SERVICE COI~IPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $2,189.50 APC $7,800.00 $9,655.00 ,, ARCO $500.00 $500.00 DOWELL $90,263.00 $90,263.00 HALLIBURTON $0.00 $8,513.00 LITTLE RED $2,000.00 $12,265.00 SCHLUMBERG ER $0.00 $6,830.00 TOTAL FIELD ESTIMATE $100,563.00 $130,215.50 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T~38A (Permit No. 97-205 & 397-191) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 2T-38. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad ,. .t ~ ~! Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS [~ SUSPENDED [~] ABANDONED~ SERVIOE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-205, 397-191 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20229-01 ~ -4 Location of well at surface ......... ~_ 9 Unit or Lease Name 65' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ~ .... ?: .~_._~..~/¢_ ....~ I, Kuparuk River Unit At Top Producing Interval ~ ' ~--~'~ 10 Well Number 2365' FNL, 801' FWL, Sec. 10, T11N, RSE, UM ~?L,-~ i~:i[. ~i , ~,~i1'~,.1 2T-38A At Total Depth i .... ~_~ ..~~ ~ 11 Field and Pool 2158' FNL, 520' FWL, Sec. 10, T11N, R8E, UM .[ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No~ ~ Kuparuk River Oil Pool RKB 113', Pad 81'I ADL 25568 ALK 2666 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 26-Nov-97 28-Nov-97 01-Dec-97 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+I-VD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 13360' MD & 6079' TVD 13262' MD & 6022' TVD YES X~J NO U NA feet MD 1465' APPROX 22 Type Electdc or Other Logs Run GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 151.5# X-65 SURF. 121' 36' 103 sx AS I 9.625' 40.0# L-80 SURF. 4630' 12.25' 870 sx AS III & 810 sx Class G 7' 26.0# L-80 SURF. 12144' 8.5' 230 sx Class G 3.5' 9.3# L-80 11992' 13360' 6.125' 256 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) ;PACKER SET (MD) 3.5' 12029' 11999' 12947'-12967' MD 5840'-5851'TVD 4 spt 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12947'-12967' 133000# of proppant in formation w/9.1 # ppa of #12/18 @ the parts 27 PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.) 12/21/97 Gas Lift Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1/21/98 12 TEST PERIOI: 20 260 3 124I 3003 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 361 1395 24-HOUR RATE: 36 524 6 24° 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate r~ev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GE)R, and time of each phase. Top Kuparuk C 12931' 5831' Bottom Kuparuk C 12947' 5840' Top Kuparuk A 12947' 5840' Bottom Kuparuk A 13120' 5940' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) ....... · .... Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1G407 Date: 1/14/98 ARCO ALASKA INC. WELL SUMNLARY REPORT Page: 1 WELL:2T-38A RIG:NORDIC WELL_ID: AK9101 TYPE: AFC: AK9101 AFC EST/UL:$ 850M/ 1000M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: BLOCK: SPUD:il/26/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20229-01 11/15/97 (D1) TD:13264' (13264) SUPV:RWS DAILY:$ 11/16/97 (D2) TD: 0'( 0) SUPV:RWS DAILY:$ 11/17/97 (D3) TD: 0'( 0) SUPV:RWS DAILY:$ 11/18/97 (D4) TD: 0'( 0) SUPV:RWS DAILY:$ 11/19/97 (D5) TD:12823' (12823) SUPV:RWS/MC DAILY:$ 11/20/97 (D6) TD:12823' ( 0) SUPV:RWS/MC DAILY:$ 11/21/97 (D7) TD:12510' ( SUPV:RWS/MC o) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CIRC & DISPLACING WELL TO MUD Began move 8 midnight, icy road ~ north end of 1E pad, rear wheel of rig slid off of road. Secure rig with cats, crib up rig and drive back onto road. No spills or damage. Continue move to 2T-38A. Accepted rig @ 1800 hrs. 11/15/97. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 54 PV/YP: 14/19 APIWL: 9.8 Circ and condition mud. Thaw out hardline f/choke manifold to 2T-14 flowline. ND tree. NU test stack. Test BOPE to 300/3500 psi. Pump cement. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 45 PV/YP: 8/18 CONTINUE L/D 3.5" CMT CONT TBG Pull 3.5" tubing. 0 CUM:$ 0 ETD:$ 0 EFC:$ APIWL: 10.4 MW: 9.4 VISC: 32 PV/YP: 5/ 8 APIWL: 16.0 RIH W/DRLG BHA Safety meeting. Continue to lay down 3.5" tubing. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 45 PV/YP: 10/ 7 APIWL: 21.0 POOH W/3.5" DP TO PU CMT BHA Safety meeting. RIH with 3.5" DP. Tag top of cement @ 12823' 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.5 VISC: 41 PV/YP: 9/ 9 APIWL: 32.0 POH F/PACKER MILLING BHA ASSY Pre-job safety meeting. Pump cement slurry. RIH with packer. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 40 PV/YP: 9/10 APIWL: 30.0 STANDING BACK MILLING BHA Continue RIH w/ 3.5" DP and bridge plug to 5397', gauge ring hung in coupling damaging bottom slips on bridge plug. Unable to continue RIH. POH w/damaged bridge plug. Bridge plug hung @ 4954' and sheared off. RIH to mill up bridge Date: 1/14/98 DAILY:$ 11/22/97 (D8) TD:12510' ( SUPV:RWS/MC 0) DAILY:$ 11/23/97 (D9) TD:12510' ( SUPV:RWS/MC 0) DAILY:$ 11/24/97 (D10) TD:12144' ( 0) SUPV:RWS/MC DAILY:$ 11/25/97 (Dll) TD:12173' ( 29) SUPV:MC DAILY:$ 11/26/97 (D12) TD:12360' (187) SUPV:DW/MC DAILY:$ 11/27/97 (D13) TD:13177'(817) SUPV:DW/MC DAILY:$ 11/28/97 (D14) TD:13360' (183) SUPV:DW/MC DAILY:$ 11/29/97 (D15) TD:13360' ( 0) SUPV:DW/MC DAILY:$ ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT plug. Tag top of bridge plug @ 4952' Milled 1'+ bridge plug dropped downhole. RIH chasing bridge plug to top of cement plug @ 12510' 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 40 PV/YP: 9/10 APIWL: 30.0 RIH W/3.5" DP RO RUN SCH. CCL RIH with bridge plug #2. Bridge plug taking weight unable to continue. Pull plug to surface. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.6 VISC: 80 PV/YP: 19/26 APIWL: 7.0 MAKING UP WHIPSTOCK & PREP RIH RIH w/Schlumberger CCL to 6295' Cable drag stopped tool. Tag bridge plug @ 12509'. RIH w/Schlumberger CCL. Log to T.D. POH left CCL tool & 300' e-line in hole. POH 24 stands wireline & CCL tool stuck in DP. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 71 PV/YP: 14/37 APIWL: 7.0 MILLING WINDOW, 15' CUT RIH with Whipstock assembly to 12447' MD. Mill window in 7" casing. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 60 PV/YP: 15/33 APIWL: 8.0 PREP TO RIH W/6.125" PDC BIT Continue milling window from 12150' to 12173'. Perform FIT to 13.0 ppg EMW. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 9.4 VISC: 60 PV/YP: 15/35 APIWL: 4.5 DRILLING AHEAD Test BOPE to 300/3500 psi. Slide thru window to 12171' Slide and rotate from 12171' to 12360' 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 11.4 VISC: 46 PV/YP: 19/23 APIWL: 4.0 TD HOLE @ 13360' POOH TO SHOE Continue directional drilling 6.125" hole from 12360' to 13177', sliding and rotating as needed. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 11.4 VISC: 55 PV/YP: 18/24 APIWL: 4.0 RIH W/3.5" LINER TO 13360' Continue drilling from 13177' to 13360'. RIH w/3.5" liner. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 11.4 VISC: 46 PV/YP: 16/29 POOH L/D 3.5" DP RIH w/3.5" liner. Pump cement. Set packer. 0 CUM:$ 0 ETD:$ 0 EFC:$ APIWL: 4.0 Date: 1/14/98 11/30/97 (D16) TD:13360' ( 0) SUPV:DW/MC DAILY:$ 12/01/97 (D17) TD:13360' ( 0) SUPV:DW/MC DAILY:$ 12/02/97 (D18) TD:13360' ( 0) SUPV:DW DAILY:$ ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 11.4 VISC: 46 PV/YP: 16/19 APIWL: 4.0 R/U TO RUN 3.5" PROD TBG POOH 3.5" DP. Load 3.5" production tubing in pipe house. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 MW: 11.4 VISC: 48 PV/YP: 16/29 N/D BOPS AND N/U TREE Run 3.5" production tubing w/jewelry. 0 CUM:$ 0 ETD:$ 0 EFC:$ APIWL: 4.0 MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED @ 1700 HRS. 12/2 Freeze protect well. N/D BOPE. N/U tree. Test packoff to 5000 psi, test tree to 250/5000 psi. Move rig off well. Release rig @ 1700 hrs. 12/2/97. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 End of WellSummary for Well:AK9101 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2T-38A(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-38A RIG SIDETRACK, SIDETRACK SUPT 1206971540.3 DATE DAILY WORK 12/08/97 RIG SIDETRACK, SIDETRACK SUPT DAY OPERATION COMPLETE I SUCCESSFUL 2 YES I YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 450 PSII 350 PSI 0 PSI DAILY SUMMARY KEY PERSON DECKERT UNIT NUMBER 8337 SUPERVISOR CHAN EY/BLACK Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 0 PSII 0 PSI lLOGGED GR/CCL WITH ROLLERS FROM 13261 (TD)-11850. PERF'D 2-1/2" HCC, BH CHGS, 4JSPF @ 12947-12967. WHTP DROPPED 900 PSI WHEN SHOT. TIME LOG ENTRY 06:00 MIRU SWS UNIT 8337, DECKERT,LEVY&HUSEMAN-HELD SAFETY MTG. 10:00 TEST LUBRICATOR 4000#-RIH WITH GR/CCL TOOLS 32'-12' X 2.5" ROLLER, 6' X1 11/16 HD WT, GR/CCL. TAG TD @ 13261, CORRELATED TO SPERRY SUN LOG DATED 11/28/97. LOGGED 13261-11850. DID NOT PUMP TOOLS DOWN. 12:30 COMPLETED LOGGING & POOH. 16:30 RIH W/TOOL STRING=6' X2.5" ,PETROLINE ROLLER, CCL, & *20' GUN CONSISTING OF 2-1/2" HCC, BH CHGS(CHARGE TYPE 35B ULTRA PACK, .61 EH, 6.6 PENE.), 2JSPF 118 DEGREES CCW FROM THE HIGH SIDE OF THE HOLE & 2JSPF 62 DEGREES CW FROM THE HIGH SIDE OF THE HOLE., 180 DEGREE PHASING. 18:45 NO NEED TO PUMP GUN STRING DOWN-@ 11300' GUN STRING SET DOWN, PICKED UP ONCE AND TOOLS WENT DOWN NOT STOPPING. CORRELATE TO GR/CCL - POSITION GUN WHILE KEEPING 1200 PSI ON TUBING-PERFORATED @ 12947'- 12967'. WHTP PRESSURE DROPPED 900 PSI WHEN SHOT. 18:50 POOH 20:35 RIG DOWN, ALL SHOTS FIRED. 21:35 RELEASE RADIO SILENCE & MOL. WELL SECURED AND DSO NOTIFIED OF STATUS. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC KRU / 2T-38A 501032002901 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 112897 MWD SURVEY JOB NUMBER: AKMM80015 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12058.96 5355.45 5242.45 62 37 S 72.92 W .00 2590.60S 9651.80W 6501.55 12058.98 5355.46 5242.46 62 37 S 72.92 W .00 2590.61S 9651.82W 6501.57 12144.00 5394.69 5281.69 62 24 S 73.24 W .42 2612.56S 9723.98W 6548.71 12291.28 5469.06 5356.06 57 17 N 89.22 W 10.85 2630.65S 9849.25W 6641.87 12385.15 5521.06 5408.06 55 27 N 84.64 W 4.51 2626.50S 9927.27W 6708.59 12479.76 5574.82 5461.82 55 25 N 74.89 W 8.48 2612.69S 10003.79W 6779.54' 12572.72 5628.04 5515.04 54 53 N 63.53 W 10.04 2585.70S 10074.93W 6853.50 12668.76 5685.02 5572.02 52 24 N 56.15 W 6.71 2546.96S 10141.76W 6930.53 12763.46 5741.67 5628.67 54 7 N 53.16 W 3.11 2503.05S 10203.64W 7006.39 12856.60 5796.18 5683.18 54 14 N 53.26 W .16 2457.82S 10264.12W 7081.84 12950.96 5851.14 5738.14 54 31 N 53.77 W .53 2412.21S 10325.79W 7158.50 13046.01 5906.06 5793.06 54 53 N 53.38 W .51 2366.15S 10388.21W 7236.03 13141.31 5960.95 5847.95 54 46 N 53.61 W .23 2319.80S 10450.83W 7313.87 13237.05 6016.33 5903.33 54 32 N 53.80 W .28 2273.57S 10513.78W 7391.93 13268.67 6034.73 5921.73 54 16 N 53.66 W .96 2258.36S 10534.51W 7417.63 13360.00 6088.06 5975.06 54 16 N 53.66 W .00 2214.43S 10594.23W 7491.72 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 10823.19 FEET AT SOUTH 78 DEG. 11 MIN. WEST AT MD = 13360 VERTICAL SECTION RELATIVE TO WELL HEAD' VERTICAL SECTION COMPUTED ALONG 304.39 DEG. TIE-IN SURVEY AT 12,058.96' MD TIP OF WHIPSTOCK AT 12,144.00' MD PROJECTED SURVEY AT 13,360.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC KRU / 2T-38A 501032002901 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 112897 JOB NUMBER: AKMMS0015 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12058.96 5355.45 5242.45 13058.96 5913.51 5800.51 13360.00 6088.06 5975.06 2590.60 S 9651.80 W 2359.83 S 10396.72 W 2214.43 S 10594.23 W 6703.51 7145.45 441.94 7271.94 126.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA iNC KRU / 2T-38A 501032002901' NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 112897 JOB NUMBER: AKMM80015 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12058.96 5355.45 5242.45 2590.60 S 9651.80 W 6703.51 12182.49 5413.00 5300.00 2621.02 S 9756.74 W 6769.49 65.98 12370.87 5513.00 5400.00 2627.50 S 9915..51 W 6857.87 88.38 12546.55 5613.00 5500.00 2594.63 S 10055.47 W 6933.55 75.69 12715.07 5713.00 5600.00 2526.00 S 10172.13 W 7002.07 68.51 12885.38 5813.00 5700.00 2443.85 S 10282.83 W 7072.38 70.31 13058.08 5913.00 5800.00 2360.26 S 10396.14 W 7145.08 72.70 13231.31 6013.00 5900.00 2276.34 S 10510.00 W 7218.31 73.23 13360.00 6088.06 5975.06 2214.43 S 10594.23 W 7271.94 53.63 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D F:! I I--I--I N ~ S I=: FI~JI C: E S 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Updated Surveys please destroy prior distribution Re: Distribution of Survey Data for Well 2T-38A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 12,058.96' MD Window / Kickoff Survey: 12,144.00' MD Projected Survey' 13,360.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALA~,¢~A OIL AND GAS CONSERVATION COMMIS-~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate m. Repair well 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 65' FSL, 556' FWL, SEC 1, T11N, R8E, UM At top of productive interval 2429' FNL, 901' FWL, SEC 10, T11N, R8E, UM At effective depth 2197' FNL, 586' FWL, SEC 10, T11N, R8E, UM At total depth 2149' FNL, 522' FWL, SEC 10, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 3360 feet 6079 feet 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-38A 9. Permit number/approval number 97-205 10. APl number 50-103-20229-01 11. Field/Pool feet Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 1 3262 feet true vertical 6022 feet Junk (measured) None 13. 14. Casing Length Size Cemented Structural Conductor 8 0' I 6" 103 SX AS I Surface 45 9 3' 9 5/8" 870 Sx AS III & Intermediate 810 SX Class G Production 1 21 0 9' 7" 230 SX Class G Liner 1 36 8' 3.5" 256 SX Class G Perforation depth: measured 12947'-12967' true vertical 5840'-5851' OR INAL Tubing (size, grade, and measured depth) 16 3.5", 9.3#/ft., L-80 @ 12029' Packers and SSSV (type and measured depth) Packer: Baker LT w/tie back @ 11992'; SSSV: None, nipple @ 512' Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 12/18/97. Measured depth True vertical depth 115' 115' 4630' 2864' 12144' 5386' 13360' 6079' RECE!VED jAil £9 1998 Intervals treated (measured) 1 2 9 47'- 1 2 9 6 7' Alaska 0i! & C~as Cons. Treatment description including volumes used and final pressure Anchorage Pumped 133 Mlbs of 20/40 and 12/18 ceramic proppant into formation, final pressure = 8000 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 200 1200 Subsequent to operation 220 439 4 725 350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 1~7. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned Form 10-40 Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~ KUPARUK RIVER UNIT ~' WELL SERVICE REPORT '~ K1(T-38A(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-38A FRAC, FRAC SUPPORT 121 1 970718.1 DATE DAILY WORK UNIT NUMBER 12/1 8/97 "A" SAND FRAC DAY OPERATION cOMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O No (~) Yes O No DS-YOAKUM CHANEY,;' . ~ FIELD AFC.,~ CC.,~ DAILYCOST ACCUMCOST Signedk /~, ( ~.-_~/'...':'-------~ ESTIMATE 999111 230DS28TL $1 12,052 $115,212 -".~f ..... ~ ..... - Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann · 800 PSI 500 PSI 350 PSI 450 PSII 0 PSII .75 PSI DAILY SUMMARY "A" SAND FRAC COMPLETED. SCREENED OUT, INJECTED 133000 LBS OF PROP IN THE FORMATION W/9.1# PPA OF #12/18 @ I THE PERF'S. MAXIMUM PRESSURE 8000 PSI & F.G. (.78). UNABLE TO FREEZE PROTECT WELLBORE. TIME LOG ENTRY 13:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL TRUCK, & APC VAC TRUCK. HELD SAFETY MEETING/20 LOCATION). 15:45 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9800 PSI. 16:50 17:35 18:45 PUMP BREAKDOWN W/50# DELAYED XL GW @ 28 BPM TO 15 BPM. VOLUME PUMPED 375 BBLS. USED 2011 LBS OF ~Y20/40 PROP. MAXIMUM PRESSURE 8700 PSI AND ENDING PRESSURE 2600 PSI. STEPPED DOWN RATE AT END OF STAGE. S/D AND OBTAINED ISIP OF 1960 PSI W/F.G @ (.78). PULSED FOR CLOSURE AND MONITORED WHTP. CLOSURE TIME +-15 MINS @ 1690 PSI PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 200 BBLS. MAXIMUM PRESSURE 6500 PSI AND ENDING PRESSURE 4200 PSI. S/D AND OBTAINED ISIP OF 2069 PSI W/F.G. @ (.80). STOOD-BY AND MONITORED WHTP FOR CLOSURE. CLOSURE TIME +-11 MINS @ 1830 PSI. PAD VOLUME = 455 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 BPM TO 15 BPM. VOLUME PUMPED 1380 BBLS. SCREENED OUT. MAXIMUM AND ENDING PRESSURE 8000 PSI. PUMPED 152087 LBS OF PROP (13590 LBS OF ~20/40 AND 152087 LBS). INJECTED 133000 LBS OF PROP IN THE FORMATION W/9.1# PPA OF #12/18 @ THE PERF'S. LEFT 32677 LBS OF PROP IN THE WELLBORE. WAS UNABLE TO FREEZE PROTECT WELLBORE. 21:00 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL TRUCK. 22:00 23:00 REMOVED TREESAVER (50% OF CUPS LOST). CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED OF STATUS. ~ERVlCE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $6,250.00 $6,250.00 DIESEL $500.00 $500.00 DOWELL $102,443.00 $102,443.00 HALLIBURTON $0.00 $2,750.00 LITTLE RED $2,860.00 $3,270.00 TOTAL FIELD ESTIMATE $112,053.00 $115,213.00 STATE OF ALASKA AL~,~KA OIL AND GAS CONSERVATION COMMI~:,~¢ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 65' FSL, 556' FWL, SEC 1, T11N, R8E, UM At top of productive interval 2429' FNL, 901' FWL, SEC 10, T11N, R8E, UM At effective depth 2197' FNL, 586' FWL, SEC 10, T11N, R8E, UM At total depth 2149' FNL, 522' FWL, SEC 10, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 3360 feet 6079 feet 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-38A 9. Permit number/approval number 97-205 10. APl number 5o-103-20229-01 11. Field/Pool feet Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 1 3 2 6 2 feet true vertical 6022 feet Junk (measured) None 13. 14. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 103 SX AS I 115' 115' Surface 4593' 9 5/8" 870 SX AS III & 4630' 2864' Intermediate 810 SX Class G Production 1 21 09' 7" 230 Sx Class G 12144' 5386' Liner 1 3 6 8' 3.5" 256 Sx Class G 1 3 3 6 0' 6079' Perforation depth: measured 12947'-12967' true vertical 5840'-5851' 0RIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3#/ft.,L-80 @ 12029' Packers and SSSV (type and measured depth) Packer: Baker LT w/tie back @ 11992'; SSSV: None, nipple @ 512' Stimulation or cement squeeze summary Perforate 'A' sands on 12/8/97. Intervals treated (measured) 12947'-1 2967' Treatment description including volumes used and final pressure Perforate using 2-1/2" HC guns w/ BH charges @ 4 SPF, final pressure = 1200 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 200 1200 Subsequent to operation 220 439 4 725 350 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 10-40~8 Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~. K1(T-38A(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-38A RIG SIDETRACK, SIDETRACK SUPT 1206971540.3 DATE DAILY WORK UNIT NUMBER 12/08/97 RIG SIDETRACK, SIDETRACK SUPT 8337 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR Yes O No (~) Yes O No DECKERT CHANEY/BLACK I 2 FIELD AFC~ CC~ DAILY COST ACCUM COST Signed/' ' ESTIMATE AK9101 230DS28TG $20,724 $38,152 -.~/~! ._/~. ~ . _~~ ..--- Initial Tbq Press Final Tb_(:l Press Initial Inner Ann Final Inner Ann ] Initial Outer Ann ] Final Outer Ann 450 PSI 350 PSI 0 PSI 0 PSII 0 PSII ':?0 PSI DALLY SUMMARY LOGGED GR/CCL WITH ROLLERS FROM 13261 (TD)-11850. PERF'D 2-1/2" HCC, BH CHGS, 4JSPF @ 12947-12967. WHTP DROPPED 900 PSI WHEN SHOT. TIME LOG ENTRY 06:00 MIRU SWS UNIT 8337, DECKERT, LEVY&HUSEMAN-HELD SAFETY MTG. 10:00 TEST LUBRICATOR 4000#-RIH WITH GR/CCL TOOLS 32'-12' X 2.5" ROLLER, 6' Xl 11/16 HD WT, GR/CCL. TAG TD @13261, CORRELATED TO SPERRY SUN LOG DATED 11/28/97. LOGGED 13261-11850. DID NOT PUMP TOOLS DOWN. 12:30 COMPLETED LOGGING & POOH. 16:30 RIH W/TOOL STRING-6' X2.5" ,PETROLINE ROLLER, CCL, & *20' GUN CONSISTING OF 2-1/2" HCC, BH CHGS(CHARGE TYPE 35B ULTRA PACK, .61 EH, 6.6 PENE.), 2JSPF 118 DEGREES CCW FROM THE HIGH SIDE OF THE HOLE & 2JSPF 62 DEGREES CW FROM THE HIGH SIDE OF THE HOLE., 180 DEGREE PHASING. 18:45 NO NEED TO PUMP GUN STRING DOWN-@11300' GUN STRING SET DOWN, PICKED UP ONCE AND TOOLS WENT DOWN NOT STOPPING. CORRELATE TO GR/CCL - POSITION GUN WHILE KEEPING 1200 PSI ON TUBING-PERFORATED @ 12947'- 12967'. WHTP PRESSURE DROPPED 900 PSI WHEN SHOT. 18:50 POOH 20:35 RIG DOWN, ALL SHOTS FIRED. 21:35 RELEASE RADIO SILENCE & MOL. WELL SECURED AND DSO NOTIFIED OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $50.00 APC $3,950.00 $9,950.00 BIOZAN $0.00 $800.00 DIESEL $0.00 $355.00 DOWELL $0.00 $5,642.00 HALLIBURTON $0.00 $2,326.83 LI'FTLE RED $3,740.00 $5,995.00 SCHLUMBERGER $13,034.00 $13,034.00 TOTAL FIELD ESTIMATE $20,724.00 $38,152.83 0 F! I I_1--11M G S ~:: I::! L~ I r" E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Consewation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 23, 1997 2T-38A, AK-MM-80015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of 2 Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2T-38A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20229-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20229-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F:t I I--CI I~ G S I:::: F! ~./I r' I=: S 19-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-38A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 12,059.00' MD Window / Kickoff Survey: 12,144.00' MD Projected Survey: 13,360.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri I~t I I__1__ I I~ G WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~i./~ -' RE: MWD Formation Evaluation Logs 2T-38A, AK-MM-80015 December 17, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~-G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20229-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 6. 1997 Michael Zanghi Drilling Superintendent ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-38A ARCO Alaska. Inc. Permit No. 97-205 Sur. Loc. 65'FSL. 556'FWL. Sec 01. TI 1N. RSE. UM Btmnhole Loc. 2156'FNL. 516'FWL. Sec. 10. T1 IN. RSE. UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance xvith 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given m field inspector on the North Slope pager at 659-3607. ... · BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,~TATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X I b Type of Well Exploratory r'~ Stratigraphic Test r-I Development Oil X Re-Entry D Deepen D Service D Development Gas D Single Zone X Multiple Zone D, 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 113', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorac, le, AK 99510-0360 ADL 25568, ALK 2666 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 65' FSL, 556' FWL, Sec. 01, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2342' FNL, 786' FWL, Sec. 10, T11N, R8E, UM 2T-38A #U-630610 At total depth 9. Approximate spud date Amount 2156' FNL, 516' FWL, Sec. 10, T11N, R8E, UM 11/12/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-1 4 13,360' MD 2938' @Tarc, let feet 12.5' @ surface feet 2560 6075' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 12,1 66' feet Maximum hole angle 54.5° Maximum surface 2751 psig At total depth (TVD) 3400 psig 18. Casing program Settinc~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD IVlO TVD (include stac~e data/ 6-1/8" 3-1/2" 9.3# L-80 EUE-rnod 1345' 12015' 5327' 13360' 607,6' 25,6 sxs Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. ~ C F Present well condition summary Tolal depth: measured 13363 fe et Plugs (measured) true vertical 6095 feet ~('~.,..;. ,.. i"~ ~':'~ f'i Effective depth: measured 13264 feet Junk (measured) 0~ ~:~s true vertica 6029 feet :~1~..~." :: v Casing Length Size Cemented Measured'~dJ~l~0raft9 True Vertical depth Structural Conductor 80' 1 6 ' 103 sx AS I 121 ' 121 ' Surface 4589' 9-5/8· 870 sx ASIII, 810 sx Class G 4630' 2871' Intermediate Production 13312' 7 · 230 sx Class G 13353' 6088' PedoratioLindelpth: measured 13018'-13030' MD 0RI( INAL true vertical 5866'-5874' TVD ~--z~-,-~,~ /,J)(~.,.tp- 20. Attachments Filing fee X Property plat r'] BOP Sketch X Diverter Sketch E] Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis D Seabed report E~ 20 AAC 25.050 requirements X 21.1 hereby certify that ~e for.~/oingiis true and correct to the best of my knowledge (Contact William Isaac. son at 263-4622 with questions.) J// ( Title Drillin~ Superintendent Date /~ ~ ~ '-~ /' ~i~r~d . ~ Corem,ss,on Use Only ~ermit Number Ih~PI nu~r ~ I Approval date ~ ~. · I See cover lelter for ~ :~ - _~_ 43 ,~- 15 o'~'~/o 3- '~- ° ~- Z-- ~ - ° i I II/bic? ' ) I°therrequiremonts Conditions of approval Samples required D Yes I~ No Mud leg req[~ire~ E] Yes !~ No Hydrogen sulfide measures '~ Yes D No Directional survey required ~ Yes E] No nequired working pressure for BOPE E] 2M ~ 3M E] 5M D 1OM D 15M Other: Original Signed Dy by order of Approved by 9avid W, Johnston Commissioner the commission Date///R(,hmif ~ in ~nlir~. F'nrm 1N-4N1 Rnv 7-24-R~ REDRILL PLAN SUMMARY Well 2T-38A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 65' FSL, 556' FWL, SEC 01, T11N, R8E, UM 2342' FNL, 786' FWL, SEC 10, T11 N, R9E, UM 2156' FNL, 516' FWL, SEC 10, T11N, R9E, UM 13,360' 6075' Nordic Rig 2 11-12-97 11 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casin~ 9.4 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Ddlling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/'rbg 3-1/2", 9.3#, L-8O, EUE-Mod Tubing 3-1/2", 9.3#, L-80, EUE-Mod Length Top (MD/TVD) Btm (MD/I'VD 1345' 12,015'/5327' 13,3607 6075' 11,986' 29'/29' 12,015'/5327' Cement Calculations: Casing to be cemented: 3-1/2" in 6-1/8" open hole Volume = 255 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 53%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,751 psi and is calculated using a gas column to surface. The expected leak-off at the window cut in the 7" casing is estimated at 14.0 pl3g EMW. With an expected formation pressure in the Kuparuk of 3400 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 2,751 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: Directional- KOP: Max hole angle: Close approach: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 2T-38A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The 7" casing is expected to have good quality cement up to and above the planned kick-off window, which should isolate the K-10 and K-5 from the sidetrack operations. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set ddlling data shows that wells in the area of 2T-38A have been ddlled to TD with 11.4 ppg mud and no loses. The kick-off point in 2T-38A is below any zones which would be of pressure concem prior to weighting up for the Kuparuk interval. 12,166' MD / 5396' TVD 54.5° (in sidetrack portion) 72.4° (in odginal portion) No Hazards Page 2 Lo_a_ain_~ Pro_aram: Open Hole Logs: GR Cased Hole Logs: GR/CCL Notes: All drill solids generated from the 2T-38A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 2T-38A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU slickline unit. RIH and pull odfice valve from bottom GLM at 12,823' MD RKB, leaving an open pocket. Dummy off all other GLM's. . RU E-line unit. RIH with 3-1/2" Baker 'N-2' bddge plug for 9.3#/ft tubing and set at 12,863' MD RKB (5' above the 'W-I' landing nipple).Once bddge plug is set, bleed wellhead pressure to 0 psi and verify positive set of bridge plug. RIH with chemical cutter. Cut 3-1/2" tubing +/-5' above the 'N-2' bddge plug (as close as possible to top of bddge plug). RDMO E-line. ./- WORKOVER RIG WORK: 1. 2. 3. 4. . 9. 10. 11. MIRU Nordic Rig 2. Lay hard-line to tree. Verify well is dead. Load pits w/water. Circulate well to water. Set BPV. ND tree. NU and test BOPE. Screw in landing joint. Pull tubing hanger to dg floor. Spot a 250' cement plug on top of permanent~ production packer and bridge plug in 3-1/2" tubing. Pull above cement plug top and reverse circulate tubing clean. POOH standing back tubing and laying down all jewelry. 5. PU Baker 7" 'N-I' permanent bddge plug on DP. RIH and set bddge plug at 12,195' MD RKB. Release from bridge plug and test wellbore to 3500 psi, testing bddge plug and cement plug to ensure isolation from perforations. POOH standing back DP. 6. MU and RIH with bottom tdp whipstock and window milling assembly. Tag bridge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 7" casing. POOH LD milling assembly. 7. RIH w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. Run 3-1/2" liner to TD w/150' of ovedap to top of milled window. Cement liner. Set liner hanger and liner top packer. POOH w/DP. Pressure test casing and liner lap to 3500 psi for state test. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 12. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 13. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 9 days Expected Case: 11 days Upper Limit: 17 days No problems milling window, ddlling new hole, or running completion. Difficulties encountered milling window, or drilling new hole. WSI 10/28/97 Page 4 ICreoted by finch For: B ISAACSON Dote plotted : 29-0ct-97 Plot Reference [s 5~~, Version #§. Coordinates ore in feet reference slot True Verticel Depths ore reference RKB. TD LOCATION: 2156' FNL, 516' FWL SEC. 10, T11N, RSE 304.39 AZIMUTH 7165' (TO TARGET) ***Plane of Proposo[*** 5200 5300 ARC0 ALASKA, Inc. Structure : Pad 2T Well : 38A Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 10900 10800 10700 10600 10500 10400 10500 10200 10100 10000 9900 9800 9700 I I I I I I I I I I ~ I I I I ,I I I I I I I [ , ~ 2200 [~l._ ~,.TD I TARGET LOCATION: I i "%~ I 2342' FNL, 786' FWL ~ I SEC. 10, T11N, RSE "'x, Bose Kup Sands TARGET ~ 2300 -"%.A1 W0=5841 i ~ TMD=12597 '"~A3 DEP=7165 "-,~TARGET - T/ Unit C4 SOUTH 2407 F 2~CO ~ WEST 10330 L vO'-o~n K-1 Marker 1 2700 2800 2900 ISURFACE LOCATION: 65' FSL, 556' FWL SEC. 1, T11N, R8E 5400 5500 5600 5700 5800 5900 I V 6000 6100 6200 KOP - SIDETRACK PT TVD=5396 TMD=12166 DEP=6561 61.09 57.80 55.51 DLS: 10.00 de9 per 100 ft 54...38 AVERAGE ANGLE 54.48[oc TVD:5634 TMD=12601 0EP--6875 54.5 DEG K-1 MARKER TV0=5739 TMD=12781 DEP=7022 - T/ C4 TVI)=SB4t ~D=129§7 DEP=716§ A3 '1V0=§858 TMD--12986 DEP=7189 ^2 TVD=5888 TMD=15058 DEP=7251 TVD=5938 TMD-13124 DEP=7301 ~ B/ KUP SNDS TV0=5959 TMD=13160 [~'P=7330 TARGET ANGLE 54.5 DEG 'I'D TVD=607§ TMD=13360 DEP=7493 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 6400 6500 6600 6700 6800 6900 7000 71 O0 7200 7300 7400 7500 7600 Verficol Section (feet) -> Azimuth 304.39 with reference 0.00 N, 0.00 E from slol #38 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST ,I I . PIPE Rm ~ I Li 5 BLIND RAM~}=, MUD ~ CROSS 4 I ' 3 P,P~ Rm ~ / 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT 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 TIlE tADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'FI'OM PIPE RAMS. TEST BO'I-I'OM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSi WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11"- 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16"- 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER NORDIC RIG LEVEL z Li.I 73'-6' 25'-0' I ~ I ] ~ SPIRAL n' STAIRS _ ::2 EMSCO F-800 ~ o c.) TRIPLEX MUD~' ~ PUMP .. · ~'nRES: 4O--57 41>--57 RI~OVAB~ BOP ENCLOSURE 12'-4" EMSCO F-800 TRIPLEX MUD PUMP SPIRAL STAIRS 'lco.s° I'4ORDIC RIG 4g'2~ LEVEL 2 t 80 HP CLEAVER BROOKS BOILE. R [ ~-,?uPSl _ _ MODULE MCC PANEL 4 PARTS I ' BINS .],. NORDIC RIG LEVEL ~ SPIRAL CHOKE DRILUNO US[ER AIR HEATER STAIRS MANIFOLD DOG'HOUSE OFFICE UNE .UD TANK {~ 750 BBLS ,, I SPOOL I R^~ I HYDRAUUC ~__. RAI~ · 1~'-7' ' - 5°-6- - ~ 15'-6' - ~ Z4.'--.G' ~ 1.¥-6' : 7'-11''---'~ 84.'-0' 12Y--O' Nov, 5, [99? il'4[AM ARCO ALASKA INC / WELL 2T-38 PRODUCER APl # 5010320229 SURFACE LOCATION: 65' FSL, 556' FWL, SEC 1, T11N, RSE, UM TOP KUPARUK: 2544' FSL, 682' FWL, SEC 11, T11N, RSE, UM ALL DEPTHS MDFIKB (RKB=36') TREE: WKM/FMC 3-1/8" 5000 PSI 16.: 62.5# H.40 @ ,21. ~ L 9,625~: d0# L-80 @ 4630' SPUD: 07/27/g5 COMPLETION: 0g/23/g5 NIPPLE: CAMCO DS 2.812' ID @ 509' GLM1:2238' / 1,0"CAMCO KBUG/GLV GLM2:6041' / 1.0"CAMCO KBUG/GLV GLM3:8683' / 1.0"CAMCO KBUG/ DV GLM4:I0568' ! 1.0"CAMCO KBUG/GLV 71° 720 NIPPLE; CAMCO W-1 2.812" ID @ 12868' BAKER SAB-3 PKR: @ 12B77' GLMS:11869' ! 1,0"CAMCO KBUG/DV 63' GLME:128~2' /1.$"CAMCO MUM / OV 49 · 'GAS LI~ DESIGN RUN 12/Oe/gs** CAMCO D NIPPLE; 2.750" ID SHEAR OUT: BAKER @ 12892' "' ROCK SCREEN ON 2,75 CR LOCK IN D NIPPLE"** SET 05/09!97 3,5" 9.3# L-80 ABMOD, TT @ 12902' 7': 26# L-80 @ 13,353' -~ VOLUME; 0,0382 BBL/FT ~k Pi~'I'D: 13~264' HOLE ANGLE ACROFx~ KUPARUK = 49 DEGREES MAX. HOLE ANGLE -- 72 DEGREES @ 4~50' @ 6~00' ]~ ~ @ 10,400~ ~OM LOW LAST TA~- Revision: 05/09197 DMS/HES Reach: SET ROCK ~'~I~3=N Post-It* Fax Note 7671 Phong'==~T--~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~iON APPLICATION FOR SUNDRY APPROVALS 1. Type ol ReClUeSt: Abandon .~. Suspend_ Dilatation ShUtdown _ Re-ente'r SUSl~ended well_ ' Aller casing _ Reg~r well _ Plugging X Time e~en~i~ _ Stimulate ~ P~e~ ~rt Change approved pr~mm _ Pull tubing _ Vad~nce _ Pedomte _ O~er ~Redrill 2. Name of Operator- 5. Type of Wall: 6. Oa~ election (DF or Devel~men[ ARCO Alaska,..Inc. E~lora~ _ 1~2' RKB. pad 81' ~eet 3. A~m~ S[rafigr~hic _ 7. Unit or Pro~ name P. O. Box 100360, Anchorage, AK 99510 Sewice _ Kupamk River Unit ~. Location of'well at eudace 8. Well numar 65' FSL. 556' ~L, Sec. 1, T11N, RS~ UM 2T-38 _ At lop ol p~uc~ve intewal 9. Pmmi[ numar 95-112 At e~[ective depth 10. APl ~mber 50~103'~0229 At total dep[h 11. 2487' FSL~ 442' ~L, Sec. 1_0~ T11N~ RSE, UM Kuparu~, River 12. Present well condition sum~ Total Dep~: measured 13363 fee~ Plugs (mes~red) N~e (a~mx) tree ve~ical 6095 fee[ Effective depth: meaaur~ 13264 teat J~ (appmx) tree veRical 6029 feet ~ng Length Size Cemented Measured depth T~e ve~ical dep~ Cond~tor 80' 1 6 ' 103 sx AS I 1 21 ' 1 21 ' Su~ce 4589' 9.625' 870 sx AS III 4630' 2871' In~e~ediate & 810 SX Class G Pr~uct{on 13312' 7" 230 ex Class G 13353' 6088' Liner ,, , .. ,, - Pedomtion aleph: measu~ ' :'~ 13018'-13030' Tuang (size, grade, and measured dap[h) ~J ~' ~ ~ ~/-'-'~ ~ ~ 3.5', L~0, tbg w/~il ~ 12902' "~?~' ''';: Pa~ers and SSSV (~pe and measur~ depa~) -~"'"'~- gaker SABL~ Pe~{ Packer ~ 128~' MD , - 13. A~tachments Desc~p~on summa~ of proposal ~ Dats{l~ operation program ~ BOP sketch _ ~n~ct William Isaacson a{ 263-4622 wilh sn7 ~uesfiona. , 14. Estimated d'ate for commenci~ operation 15. Sta~s o~ well classificati~ Oil X _ Gas ~ Suspended ~ctober 28. 1997 15. If pmpos~ w~ venally approved N~e of appmver Date approved Service 17, I hereby cecil / ~hat the~foregoing is ~e and c~ect to the best ol ~y knoW,ge. Signed ~ ~ ~ ~Ue Drillin~ Superintendent Date /~ ~ ~MI~I~ ~E ~LY ,, - ~ondiaons of approval: ~ CommJssi~ so representalive may ~{n~s I~p~ No, / ~ / Plug integ~ly _ BOP Test_ L~on clea~ce~ I , M~hani~l Integri~ Test_ Subsequent form requi~e l O-~ Approved by the o~er of the Commission Commis~er Date , ' el Form 10-403 Rev 06/15/88 SUB · WELL PERMITCHECKLIST COMPANY /¢,",-' WELL NAME ,/~,~Z~_ .~___.~7"'-,~"4 PROGRAM: exp [] dev/~redrll~serv [] wellbore seg ~ ann. disposal para req [] FIELD & POOL ? ~d2/~ tO INIT CLASS ~)~-.~ ,'2-4:2,~ ?// GEOL AREA ~ .~ ~ UNIT# /'/'/._../"~'~ ~ ON/OFF SHORE , C'2 0 ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. !~ DA-E 12. 3. / , Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N ENGINEERING A.~ DATE 14. Conductor string provided ................... Y N"'"~ 15. Surface casing protects all known USDWs ........... YV t'AJ 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ (~/Y"NN 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ... N 25. BOPEs, do they meet regulation ...... N 26. BOPE press rating appropriate; test to "~'~ ' ' 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. REMARKS GEOLOGY 31. Data presented on potential overpressure zones ........ N 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. Y N 34. Contact name/phone for we.ekly ,progress re[:)o, rts ..... .// Y N lexp~oratory omyj GEOLOGY: RPC..~ ENGINEERING: COMMISSION: BEW("~6J).~'~. ¢,~'/,7-~ DWJ~ JDH__~-~' RNC~ '""- CO ~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Dec 10 10:33:41 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... [Z%VK_NOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-80015 K. FERGUSON D. WESTER Date~~~,~ 27-38A 501032022901 ARCO ALAS~, INC. SPE~Y-S~ DRILLING SERVICES 10-DEC-97 1 liN 08E 65 556 112.90 111.40 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 12144.0 PRODUCTION STRING 6.125 13360.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) I/NLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND BILL ISAACSON OF ARCO ALASKA, INC. ON 09 DECEMBER, 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13360'MD, 6079'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NI/MBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SI/MMARY PBU TOOL CODE START DEPTH GR 12100.0 ROP 12132.5 RPD 12140.0 RPM 12140.0 RPS 12140.0 RPX 12140.0 FET 12144.5 $ STOP DEPTH 13304.0 13360.5 13311.0 13311.0 13311.0 13311.0 13311.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 12132.0 13360.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPM MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OPIM~ 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 12100 13360.5 12730.2 2522 GR 49.2668 487.575 148.333 2409 RPM 1.027 2000 6.53979 2343 ROP 10.5579 1834.43 88.2241 2457 RPX 1.5032 2000 6.23917 2343 RPS 1.4952 2000 6.37608 2343 RPD 1.5076 2000 8.6768 2343 FET 0.7768 43.5893 2.38027 2334 First Reading 12100 12100 12140 12132.5 12140 12140 12140 12144.5 ,Last Reading 13360.5 13304 13311 13360.5 13311 13311 13311 13311 First Reading For Entire File .......... 12100 Last Reading For Entire File ........... 13360.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/10 Maximum Physical Recordo.65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12100 0 13304.0 ROP 12132 5 13360.5 RPD 12140 0 13311.0 RPM 12140 0 13311.0 RPS 12140 0 13311.0 RPX 12140 0 13311.0 FET 12144 5- 13311.0 $ LOG HEADER DATA DATE LOGGED: 28-NOV- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.4 MAXIMUM ANGLE: 62.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: ISC 5.06 DEPII 2.17F / SP4 5.03 MEMORY 13360.0 12132.0 13360.0 TOOL NUMBER P0875SP4 P0875SP4 6.130 6.1 LSND MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth units ....................... Datum Specification Block sub-type...0 11.40 46.0 9.7 1100 4.0 1.550 .795 1.050 2.000 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 ,16 5 20 6 24 7 28 8 61.7 Name Min Max Mean DEPT 12100 13360.5 12730.2 GR 49.2668 487.575 148.333 RPX 1.5032 2000 6,23917 RPS 1.4952 2000 6.37608 RPM 1.027 2000 6.53979 RPD 1.5076 2000 8.6768 ROP 10,5579 1834.43 88.2241 FET 0.7768 43.5893 2.38027 First Last Nsam Reading Reading 2522 12100 13360.5 2409 12100 13304 2343 12140 13311 2343 12140 13311 2343 12140 13311 2343 12140 13311 2457 12132.5 13360.5 2334 12144.5 13311 First Reading For Entire File .......... 12100 Last Reading For Entire File ........... 13360.5 ~0~ I~OTsXMd OT~T~UeTOS 'A~qTq 8UT~TZM $Iq S~S ................. s~uauauoo NMONDINi1 ........... aure~ leah I0'" .... ~equraX UOT~nuT~uoo S~S ................... uT~T~O ~6~SIq ............. ~u ~OTA~S ~eTT~ Iee~ SOOTAZOS I~OTUqOa& 5UT~T~ SIq S~S ................. s2uaum~oo NMON-HNi1 ........... aur~ ad~& I0 ...... ~equrnx uoT~enuT~UOO bL~ON-~N_rl ................ aure~ s~s ................... UT~T~O OI/EI/£6 ..................... ~6ASIq ............. sm~u ~alT~ £00'~IqSLS ........... a~mM aIT~ qxaN 0q ................ ed~ eIT~ §£§~9''pzooeH Ie2TSXq& uromTXe~ OI/EI/£6 ........ uoTqexaueD ~o eqe~ O'O'I''- ......... zeqmnx UOTS~eA '''eure~ IOAO~ qns so,AleS ~aIT~L aIT~