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Home My WebLink About198-067Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_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#12AͲ04 50Ͳ103Ͳ20026Ͳ00 909593518 Kuparuk River Plug Setting Record FieldͲFinal 29ͲSepͲ24 0 122AͲ05 50Ͳ103Ͳ20030Ͳ00 909524907 Kuparuk River Plug Setting Record FieldͲFinal30ͲAugͲ24 0 132AͲ11 50Ͳ103Ͳ20057Ͳ00 909594128 Kuparuk River Multi Finger CaliperField & Processed 4ͲOctͲ24 0 142AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 152AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Packer Setting Record FieldͲFinal 24ͲAugͲ24 0 162GͲ10 50Ͳ029Ͳ21140Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 23ͲAugͲ24 0 172MͲ07 50Ͳ103Ͳ20178Ͳ00 ALSL765Ͳ008 Kuparuk River Multi Finger CaliperField & Processed 15ͲSepͲ24 0 182NͲ329 50Ͳ103Ͳ20257Ͳ00 909593520 Kuparuk River Packer Setting Record FieldͲFinal 20ͲSepͲ24 0 192ZͲ10 50Ͳ029Ͳ21378Ͳ00 909593519 Kuparuk River Multi Finger CaliperField & Processed 25ͲSepͲ24 0 110 3IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Leak Detect Log FieldͲFinal 5ͲOctͲ24 0 1PLEASE 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:T39689T39690T39691T39692T39692T39693T39694T39695T39696184-053184-067186-003186-004184-106192-080198-067185-137186-055T3969710/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:49:24 -08'00'2NͲ32950Ͳ103Ͳ20257Ͳ00 909593520KuparukRiverPackerSettingRecordFieldͲFinal20ͲSepͲ2401T39695192 080198-067185 137 ORIGINATED TRANSMITTAL DATE: 9/4/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5024 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 5024 2N-329 50103202570000 Plug Setting Record 27-Aug-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 198-067 T39515 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.04 10:11:52 -08'00' 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 tom.osterkamp@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 2N-329 (PTD 198-067) IA Pressure Exceeding DNE Date:Monday, August 26, 2024 7:32:34 AM From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, August 20, 2024 1:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: 2N-329 (PTD 198-067) IA Pressure Exceeding DNE Hi Chris, KRU 2N-329 (PTD #198-067) is a gas lifted producer that has been shut in due to a failed SSV testing on 7/7/24 and leaking master valve on subsequent tree valve testing. To secure the well to change out the tree, the tubing patch was pulled on 8/19/24 allowing TxIA communication. The IA pressure increased to 2350 psi and has leveled off at 2200 psi, above DNE of 2000 psi. Slickline is up next to set a tail pipe plug and circulate out the IA and tubing to clean fluid. After the tree is swapped, the patch will be replaced and the well will be put back on production. The burst rating of the 7” 26# L-80 production casing is 7240 psi (45% is 3339 psi). Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9690'feet 9217'feet true vertical 5452' feet None feet Effective Depth measured 9307'feet 8900'feet true vertical 5180' feet 4894' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 8948' 4926' Packers and SSSV (type, measured and true vertical depth) 8900' 511' 4894' 511' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Other: Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 928 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packers: TTS SSSV: CAMCO DB NIPPLE Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718Well Intervention Engineer 9150-9200', 9260-9310' 5069-5104', 5147-5182' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Well Remains Shut-In Gas-Mcf MD 1550 Size 109' ~ ~~ 60 2505730 ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-067 50-103-20257-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL380054 Kuparuk River Field/ Tarn Oil Pool KRU 2N-329 Plugs Junk measured Length 9652' Casing 5445'9680' 3255' 109'Conductor Surface Production 16" 9-5/8" 80' 3283' 2295' Burst Collapse Fra O s 6. A PG , C Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 8:59 am, Apr 25, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.04.24 13:17:27-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor WELLNAME DTTMSTART JOBTYP SUMMARYOPS 2N-329 3/27/2023 OPTIMIZE WELL EQUALIZED 3.66" TTS RBP @ 9222' RKB, IN PROGRESS 2N-329 3/28/2023 OPTIMIZE WELL PULLED 3.66" TTS RBP @ 9222' RKB. READY FOR E-LINE. 2N-329 4/3/2023 OPTIMIZE WELL SET QUADCO 3.66" SCHP PIIP RPB AT 9220' (MID- ELEMENT) PERFORM CMIT TxIA TO 2500 PSI (PASS) JOB IN PROGRESS, READY FOR PERFORATIONS 2N-329 4/4/2023 OPTIMIZE WELL PERFORATE WITH 2-7/8" GEO RAZOR, 6 SPF, 60 DEG PHASED PERF GUNS PERFORATE INTERVAL: 9175' - 9200' PERFORATE INTERVAL: 9150' - 9175' JOB IN PROGRESS, READY FOR SBHPS & LOWER PACKER FOR POGLM 2N-329 4/5/2023 OPTIMIZE WELL PERFORM 30 MIN STATIC BOTTOM HOLE PRESSURE SURVEY AT 9150' (5068' TVD, MAX BHP = 2889 PSI, MAX BHT = 134 F) AND 15 MIN STATION 9008' (4968' TVD, MAX BHP = 2842 PSI, MAX BHT = 131 F) SET 3.76" QUADCO PIIP LOWER PATCH PACKER AT 8904' (MID-ELEMENT) READY FOR SL TO SET UPPER POGLM ASSEMBLY Page 1/8 2N-329 Report Printed: 4/13/2023 Well History API / UWI 5010320257 Legal WellName 2N-329 Field Name TARN PARTICIPATING AREA Well Type Development Original KB/RT Elevation (ft) 148.80 Well Status PROD Daily Operations Start Date Legal WellName Last 24hr Sum AFE / RFE Rig Supervisor 4/5/2023 2N-329 PERFORM 30 MIN STATIC BOTTOM HOLE PRESSURE SURVEY AT 9150' (5068' TVD, MAX BHP = 2889 PSI, MAX BHT = 134 F) AND 15 MIN STATION 9008' (4968' TVD, MAX BHP = 2842 PSI, MAX BHT = 131 F) SET 3.76" QUADCO PIIP LOWER PATCH PACKER AT 8904' (MID-ELEMENT) READY FOR SL TO SET UPPER POGLM ASSEMBLY WORTHINGTON, BRYCE,Wells Supervisor 4/4/2023 2N-329 PERFORATE WITH 2-7/8" GEO RAZOR, 6 SPF, 60 DEG PHASED PERF GUNS PERFORATE INTERVAL: 9175' - 9200' PERFORATE INTERVAL: 9150' - 9175' JOB IN PROGRESS, READY FOR SBHPS & LOWER PACKER FOR POGLM WORTHINGTON, BRYCE,Wells Supervisor 4/3/2023 2N-329 SET QUADCO 3.66" SCHP PIIP RPB AT 9220' (MID-ELEMENT) PERFORM CMIT TxIA TO 2500 PSI (PASS) JOB IN PROGRESS, READY FOR PERFORATIONS WORTHINGTON, BRYCE,Wells Supervisor 3/28/2023 2N-329 PULLED 3.66" TTS RBP @ 9222' RKB. READY FOR E-LINE. ZEMBA, EDDIE,Wells Supervisor 3/27/2023 2N-329 EQUALIZED 3.66" TTS RBP @ 9222' RKB, IN PROGRESS FERGUSON, SID,Wells Supervisor 3/4/2023 2N-329 STANDBY FOR LRS TO COMPLETE CMIT, CMIT FAILED WITH AN ESTIMATED 13 GPM LLR, DISCUSS WITH CWG AND DECISION MADE TO PERFORM LDL. PERFORM SPINNER LDL FROM TOP OF PLUG TO SURFACE. PUMP DIESEL DOWN TUBING TAKING RETURNS TO FORMATION, MAINTAIN 2500 PSI ON TUBING AND NO SPINNER MOVEMENT OBSERVED ABOVE PLUG. LLR WAS INTERMITTENT, DECISION MADE TO INCREASE TO 3000 PSI AND ATTEMPT TO ESTABLISH CONSISTENT LLR, PERFORM STATION STOPS ABOVE PLUG AND LOG TO SURFACE, LLR TOO SMALL/INCONSISTENT TO OBSERVE WITH SPINNER TOOLS, LLR VARIED FROM 3.8 GPM TO 0.3 GPM. JOB COMPLETE, READY FOR A PLAN FORWARD WORTHINGTON, BRYCE,Wells Supervisor 3/3/2023 2N-329 CIRC-OUT WELL TO DIESEL, CMIT-TxIA TO 2500 PSI CMIT TxIA FAILED SEE LOG KRUCPF2LRS WORTHINGTON, BRYCE,Wells Supervisor 3/3/2023 2N-329 SET QUADCO 3.66" SPECIAL CLEARANCE PIIP RBP MID-ELEMENT AT 9225' (SN: CPSCHP45007), CCL TO CE = 10.1', CCL STOP DEPTH = 9214.9' READY FOR LRS TO PERFORM DIESEL CIRC-OUT AND CMIT-TxIA JOB IN PROGRESS WORTHINGTON, BRYCE,Wells Supervisor 2/10/2023 2N-329 .RECOVERED E-LINE TOOLSTRING @ 9206' RKB; PULLED 4 1/2" RBP @ 9221' RKB; BRUSH n' FLUSH RBP INTERVAL @ 9225' RKB & TAG TD @ 9298' RKB. READY FOR E- LINE. WORTHINGTON, BRYCE,Wells Supervisor 2/9/2023 2N-329 SET 4 1/2" BAIT SUB ON 3.5" BELL GUIDE W/ 1.90" OVERSHOT & 1" GRAPPLE (39" OAL) ON FISH @ 9206' RKB JARRED ON FISH FOR 20 MIN., SHEARED TOOL, & UNABLE TO RE -LATCH; RAN 3" BAILER & RECOVERED 1/2" GALLON OF SCALE FROM TOP OF BAIT SUB; RE-LATCH BAIT SUB @ 9206' RKB AND JARRED ON FISH FOR 45 MIN W/ NO MOVEMENT. IN PROGRESS. ZEMBA, EDDIE,Wells Supervisor 1/27/2023 2N-329 ATTEMPT TO SET 3.66" PIIP RBP @ 9224.5', CCL TO MOE = 11.2', CCL STOP = 9213.3', CORRELATED TO RST LOG DATED 12/31/22. INDICATION OF GOOD SET AT SURFACE (LINE TENSION FELL OFF AS EXPECTED), UNABLE TO PULL UP HOLE (STILL ATTACHED TO PLUG), PULLED MAX SAFE ON LINE, WORKING FOR A WHILE BEFORE DECISION MADE TO PULL OUT OF CABLEHEAD. PULLED OUT CLEAN FROM CABLEHEAD AND RECOVERED ALL LINE TO SURFACE. FISH IN HOLE. JOB NOT COMPLETE. CONNELLY, JEFF,Wells Supervisor 12/31/2022 2N-329 PERFORM RESERVIOR SATURATION LOG IN SIGMA AND C/O MODES. TAG TD AT 9302', LOG SIGMA MODE AT 30 FPM FROM 9302' TO 8945'. LOG 3 PASSES IN C/O MODE OVER SAME INTERVAL AT 3 FPM. JOB COMPLETE. UPLOAD DATA FOR RUSH PROCESSING. CONNELLY, JEFF,Wells Supervisor 9/16/2022 2N-329 PULLED 3.76" P2P POGLM PATCH ASSEMBLY @ 8883' RKB; DRIFT W/ 10' X 3" BAILER & 5' X 2.625" STEM DOWN TO TD @ 9307' RKB. READY FOR E-LINE PERF. ZEMBA, EDDIE,Wells Supervisor 5/21/2022 2N-329 NES WELDER, WELDED 12"H x 16"D x 0.375" WALL CONDUCTOR TO EXISTING CONDUCTOR. MOUSER, ROGER,WI Field Supervisor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,307.0 2N-329 12/16/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP, Perforate, Set Lower Packer for POGLM 2N-329 4/5/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Well has a 12" conductor extension 5/29/2022 bsgreen Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.9 109.0 109.0 WELDED SURFACE 9 5/8 8.83 27.9 3,283.0 2,295.2 40.00 L-80 BTC PRODUCTION 7"x4.5" @ 8953' 7 6.28 28.2 9,680.3 5,445.0 26.00 L-80 BTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.8 Set Depth 8,948.0 Set Depth 4,926.2 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.8 25.8 0.02 HANGER 10.800 FMC GEN V 5M TUBING HANGER 4.500 510.8 510.7 2.24 NIPPLE 5.570 CAMCO DB NIPPLE 3.875 8,846.2 4,857.4 48.93 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/ CAMCO 3.812" DB PROFILE 3.812 8,885.4 4,883.5 47.83 GAS LIFT 5.985 CAMCO KBG-2-9 3.650 8,928.8 4,913.0 46.59 NIPPLE 5.000 CAMCO DB NIPPLE NO GO 3.750 8,945.4 4,924.4 46.12 SEAL ASSY 4.750 BAKER 80-47 CASING SEAL ASSEMBLY w/LOCATOR SUB 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,889.0 4,885.9 47.73 LEAK - GLM #1 EL LDL - LOCATED LEAK AT 8889' RKB, IN GLM 1 10/8/2019 3.960 8,900.0 4,893.3 47.41 PACKER - PATCH - LWR 3.76" PIIP LOWER PATCH PACKER MID-ELEMENT AT 8904', OAL 4.89' TTS PIIP CPP4 5046 4/5/2023 2.000 9,217.0 5,116.2 44.88 RBP 3.66" PIIP SCHP RBP MID- ELEMENT AT 9220', OAL 7.88' TTS PIIP CPSC HP45 007 4/3/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,885.4 4,883.5 47.83 1 GAS LIFT Open Open 1 10/25/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,150.0 9,200.0 5,068.8 5,104.2 S-5, 2N-329 4/4/2023 6.0 APERF 2-7/8" GEO RAZOR, 6 SPF, 60 DEG PHASED 9,260.0 9,280.0 5,146.7 5,160.9 S-5, 2N-329 12/10/2005 10.0 APERF 9,280.0 9,310.0 5,160.9 5,182.1 S-5, 2N-329 7/4/1998 4.0 IPERF 2.5" HC, BH, 180° ph, no orient Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,260.0 9,290.0 1 FRAC 7/2/1998 0.0 0.00 0.00 9,260.0 9,280.0 1 RE-FRAC 12/10/2005 0.0 0.00 0.00 2N-329, 4/13/2023 9:34:46 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 8953'; 28.2-9,680.3 FLOAT SHOE; 9,678.5-9,680.3 FLOAT COLLAR; 9,589.5- 9,590.9 IPERF; 9,280.0-9,310.0 FRAC; 9,260.0 APERF; 9,260.0-9,280.0 RE-FRAC; 9,260.0 RBP; 9,217.0 APERF; 9,150.0-9,200.0 SEAL ASSY; 8,945.4 CSR; 8,933.6-8,953.9 NIPPLE; 8,928.8 PACKER - PATCH - LWR; 8,900.0 LEAK - GLM #1; 8,889.0 GAS LIFT; 8,885.4 SLEEVE; 8,846.2 SURFACE; 27.9-3,283.0 FLOAT SHOE; 3,281.3-3,283.0 FLOAT COLLAR; 3,201.8- 3,203.3 STAGE COLLAR; 1,435.9- 1,438.7 NIPPLE; 510.8 CONDUCTOR; 28.9-109.0 HANGER; 28.2-30.2 HANGER; 27.9-29.5 HANGER; 25.8 KUP PROD KB-Grd (ft) 35.32 RR Date 5/6/1998 Other Elev 2N-329 ... TD Act Btm (ftKB) 9,690.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032025700 Wellbore Status PROD Max Angle & MD Incl (°) 67.03 MD (ftKB) 7,008.04 WELLNAME WELLBORE2N-329 Annotation Last WO: End DateH2S (ppm) 80 Date 12/15/2019 Comment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y Samantha Carlisle at 7:54 am, May 02, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( Q#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ '/% ; 3KRWR GRFXPHQW EHIRUH DQG DIWHU '6597/ ; GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.05.03 09:23:22 -08'00' RBDMS SJC 050422 32%2; $1&+25$*($/$6.$ 0D\ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 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Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2N-329 Run Date: 11/19/2020 19 80 -07 3 193 7 January 16, 2020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-329 Digital Data in LAS format, Digital Log Image file 50-103-20257-00 1 CD Rom RECEIVED JAN 21 2020 A®CCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@haRiburton.com Date: 0�/Vmo Signed: Originated: 5cmumberger, PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760 fax Delivered to: AOGCC � ATTN: Natural Resources Technician II r Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -a% Anchorage, AK 99501 198067 TRANSMITTAL DATE TRANSMITTALA ORDER1383 WELL NAME 1F-14 API $1 50-029-21022-00 SERVICE # DWUJ-11034 FIELD NAME DESCRIPTION KUPARUK RIVER WL DELIVERABLE DESCRIPTION PPROF DATATYPE FINAL FIELD DATELOGGED Prints 12 -Oct -19 Co's 1 3Q-04 50.029.22219.00 DWUJ-00133 KUPARUK RIVER WL SCMT FINAL FIELD 11 -Oct -19 1 16-03 50-029.20588-00 DWUJ-00136 KUPARUK RIVER WL PPROF FINAL FIELD 13 -Oct -19 1 1D -04A 50-029.20416-01 DWUJ-00132 KUPARUK RIVER WL LDL FINAL FIELD 11 -Oct -19 1 31-08 50-029-21550-00 DWUJ-00137 KUPARUK RIVER WL LDL FINAL FIELD 14 -Oct -19 1 1D -04A 50-029-20416-01 EDWI.00025 KUPARUK RIVER WL CALIPER FINAL FIELD 17 -Oct -19 1 2N-329 50-103-20257-00 DWUJ-00143 KUPARUK RIVER WL CALIPER FINAL FIELD 21 -Oct -19 1 AeGee 7 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package r have been verified to match the media noted above. The specific Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. return via courier or sign/scan and email a copy to Schlup�6erger and CPAI. Auditor - Schlumberger -Private Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC . ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 . Anchorage, AK 99501 TRANSMITTAL OATIE TRANSMITTAL# i 9 8067 WELL NAME API d SERVICE ORDER q FIELD NAME DESCRIPTION SERVICE DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's 50-103-20257-00 02-00 KUPARUK RIVER 'I 7a Please return via courier or sign/scan and email a copy /Lo l/;A Transmittal Receipt signature confirms that a package (box, `" envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this lumberger and CPAI. point. com SLB Auditor '3' Schlumberger -Private Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~/~' ~ '~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Damtha~'~n L~II TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Damtha Nathan Lowell Date: Is~ ,§),, I %' /''s THE STATE Akaska Oil and Gas °ALASKA Conservation Commission r GOVERNOR SEAN PARNELL 333 West Seventh Avenue tip �, Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Tq ti s 1 Fax: 907.276.7542 SCOMED 2,071 Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 c,� C)6/7 Anchorage, AK 99510 ! U Re: Kuparuk River Field, Tarn Oil Pool, 2N -329 Sundry Number: 313 -312 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. erster Chair 34- DATED this day of June, 2013. Encl. • it .4: �,. ° ' j ,* . i STATE OF ALASKA p7's p G 2a . -> AA OIL AND GAS CONSERVATION COMMSION \,x''21 I F 201 5 APPLICATION FOR SUNDRY APPROVALS b' V 20AAC25.280 AC , + 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Conductor Extension l✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory r 198 -067. 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20257 -00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2N 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380054 • Kuparuk River Field / Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9690 •5452 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108' 108' 1640 630 SURFACE 3255 9 -5/8 3283' 2295' 5750 3090 PRODUCTION 8925 7 8953' 4930' 7240 5410 PRODUCTION 727 4 -1/2 9680' 5445' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9260 -9280, 9280 -9310 • 5146 -5161, 5161 -5182 4.5 L -80 8945 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER 80 -47 CASING SEAL ASSEMBLY - MD = 8945 ND = 4924 CAMCO DB NIPPLE + MD = 511 TVD = 511 12. Attachments: Description Summary of Proposal , r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r ■ Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil F , Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Email: N1878acop.com Printed Name Martin Walters Title: Well Integrity Projects Supervisor Signature /4.9 / /� Phone: 659 -7043 Date: 06/16/13 �" Commission Use Only Sundry Number: ) a� -i D.. Conditions of approval: Notify Commission so that a representative may witness ✓ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBFINIS JUN 26 20t3 Other: Spacing Exception Required? Yes ❑ No [ v ] � Subsequent Form Required: `D — ,/ � APPROVED BY Approved by: 24 r �(, .„. G f�MIS NER THE COMMISSION Date: G —21-- /3 ` :• • f• c T,,•�� 'N �aOkIG ii r sVd Oi m onthsf1o,n tlisdal.cu approval. Form 10-403 (Revised 10/2012) V I N A L Submi Form and Attachments in Duplicate 1 b 4 i L N Conoco Philli s p , C .,;"! CU Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 16, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N -329, PTD 198 -067 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, /A Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -329 (PTD 198 -067) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 16, 2013 This application for Sundry approval for Kuparuk well 2N -329 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 21 1 /2 ". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10 -404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor e `, KUP 1111_ 2N -329 Conoco Phillips Well Attributes Max Angle & MD TD T Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Alaska Inc c 501032025700 TARN PARTICIPATING AREA PROD 67.03 7,008.04 9,690.0 lonocoPhrnips Y9 Comment H2S (ppm) Date Annotation End Date KB-Ord (R) Rig Release Date "' SSSV: NIPPLE 65 10/17/2011 Last WO: 35.32 5/6/1998 Well Confic: - 2N -329, 6/25/2012 4'.14'.38 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,311.0 6/24/2012 Rev Reason: TAG ninam 6/25/2012 Casing Strings ° Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 26 ; < r CONDUCTOR 16 15.062 27.9 108.0 108.0 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 . ' SURFACE 9 5/8 8.835 27.9 3,283.0 2,295.2 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 28.2 9,680.3 5,445.0 26.00 L -80 BTC -MOD 7 "x4.5" @ 8953' _ Tubing Strings i Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD( ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 25.8 _ 8,948.0 4,926.2 1 12.60 L -80 NSCT Com r letion Details Top Depth (TVD) Top Intl Nomi... CONDUCTOR, Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 28 25.8 25.8 -0.22 HANGER FMC GEN V 5M TUBING HANGER 4.500 ; ' 510.8 510.7 2.17 NIPPLE CAMCO DB NIPPLE 3.875 8,846.2 4,857.5 48.95 SLEEVE BAKER CMU SLIDING SLEEVE w/ CAMCO 3.812" DB PROFILE 3.812 8,928.8 4,912.9 46.16 NIPPLE CAMCO DB NIPPLE NO GO 3.750 NIPPLE 511 -- 8,945.4 4,924.4 45.96 SEAL ASSY BAKER 80 -47 CASING SEAL ASSEMBLY w /LOCATOR SUB 3.875 Perforations & Slots Shot lit Top (TVD) Btm (TVD) Dens T op (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eb... Type Comment 9,260 9,280 5,146.7 5,160.9 S -5, 2N -329 12/10/2005 10.0 APERF 9,280 9,310' 5,160.9 5,182.1 S -5, 2N -329 7/4/1998 4.0 IPERF 2.5" HC, BH, 180 deg ph, no orient Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 9,260.0 9,280.0 5,146.7 5,160.9 FRAC 12/10/2005 269,000 LBS 16/20 CARBOLITE, 10 ppa ON PERFS Notes: General & Safety End Date Annotation 7/27/2009 NOTE: ZONES NOT LOADED INTO WELLVIEW YET 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, . I . 28 -3,283 SLEEVE, 8,846 GAS LIFT, 8.885 NIPPLE, 8,929 if , . ► SEAL ASSY � - 8,945 Mandrel Details APERF, Top Depth Top Port 9,260-9,280 (TVD) Inci OD Valve Latch Size TRO Run FRAC, 9,260 Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (In) (p si) Run Date Conn... 1 8,885.4 4,883.4 46.70 CAMCO KBG - 2 - 9 1 GAS LIFT OV BTM 0.313 0.0 12/28/2005 IPERF, 9,280-9,310 - PRODUCTION Tk4.5" 5 8953', 28.9,680 TD, 9,690 . . Conoc~illips Alaska RECEIVED SEP 1 2 2007 A'ukt Oi\ & Gas Cons. Commission "nchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 'ŒJ/CJIo1~~ \V\ ~~" scANNED SEt> 12 2001 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 on September 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, J5?~- ~. ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft Qal 2N-327 207-069 12" n/a 12" n/a 3.5 9/8/2007 2N-329 198-067 24" n/a 24" n/a 6 9/8/2007 2N-331 198-117 26" n/a 26" n/a 2 9/8/2007 2N-332 200-079 8" n/a 8" n/a 2 9/8/2007 2N-333 206-025 29" n/a 29" n/a 8.5 9/8/2007 2N-349 200-139 3" n/a 3" n/a 1 9/8/2007 2N-350 201-175 11" n/a 11" n/a 4.5 9/8/2007 2P-438 201-082 4' 10" n/a 4' 10" n/a 2 9/8/2007 Date 9/9/2007 e e Mike Mooney Wells Group Team Leader Drilling & Wells ConocóÃ,illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 6, 2006 RECEn/ED JAN 1 0 ?OUR Alaska Oil & Gas Anchor. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2N-329 (APD # 198-067) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2N-329. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, /1. JI!~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells ~t~r¿It;[J 1 2006 MM/skad e STATE OF ALASKA e RECEIVED JAN 1 0 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA Tlo~ska Oil & Gas Cons. Commission . 1 . Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other U Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. ShutdownD 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 0 198-067 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20257-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', Pad 121' 2N-329 8. Property Designation: 10. Field/Pool(s): ADL 380054, ALK 4602 Kuparuk River Field 1 Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 9690' feet true vertical 5452' feet Plugs (measured) Effective Depth measured 9301' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 3255' 9-5/8" 3283' 2295' PRODUCTION 8905' 7" 8933' 4916' PRODUCTION 9652' 4-1/2" 9680' 5445' Perforation depth: Measu red depth: 9260'-9310' true vertical depth: 5147'-5182' Tubing (size, grade, and measured depth) 4-112" , L-80, 8948' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 510' 12. Stimulation or cement squeeze summary: RBDMs 8Ft JAfv 1 Q 2006 Intervals treated (measured) refer to attachment Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinç¡ Pressure Tubinc Pressure Prior to well operation 1904 2586 1048 -- 270 Subsequent to operation 2961 2736 3358 -- 293 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 GasD WAG 0 GINJD WINJD 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 Mike Mooney @ 263-4574 Printed Name ;;jMOd~~ Title Wells Group Team Lead ~ Signature Phone Date ¡ G 10(;; PreDared bv Sharon AI/sun-Drake 263-4612 l j AL . . Form 10-404 Revised 04/2004 OR\G\N Submit Onglnal Only NIP (510-511, 00:5.570) TUBING (0-8948, 00:4.500, 10:3.958) 'ROOUCTION (0-9680, 00:4.500, Wt:12.60) ConocoPhillips Ala!., Inc. 2N-329 e KRU a-.J-329 API: 501032025700 SSSV Type: NIPPLE Annular Fluid: Rev Reason: Post FCO TAG, reset OV Last U date: 1/2/2006 TVD 108 2295 4916 5445 Wt Grade Thread 0.00 WELDED 40.00 L-80 BTC 26.00 L-80 BTC MOD 12.60 L-80 NSTC SLEEVE ---... (8846-8847, 00:5.625) Thread NSTC 'ROOUCTlON (0-8933, 00:7.000, Wt:26.00) Zone Status Ft SPF Date T e Comment 20 10 12/10/2005 RPERF 2.5" HJ 2506 30 4 7/4/1998 IPERF 2.5" HC, BH, 180 deg ph, no orient Comment 269,000 LBS 16/20 CARBOLlTE, 10 Gas Lift _._on_ MandrelNalve 1 (8885-8886, NIP (8928-8929, 00:5.000) SBE (8945-8946, 00:4.750) FRAC (9260-9280) Perf (9260-9280) Perf (9260-9310) FLOAT COLLAR (9590-9591, 004.500) TRO Date Run o 12/28/200 CAMCO 3.812, DB rofile CAMCO "DB" NIPPLE, NOGO Baker 7" Casin SA, size 80-47 PBTD ID 3.875 3.810 3.750 3.875 3.958 > DATE 11/14/05 11/15/05 11/16/05 11/17/05 11/18/05 11/19/05 11/20/05 11/21/05 11/22/05 11/24/05 11/25/05 11/26/05 11/27/05 11/28/05 11/29/05 11/30/05 12/1/05 12/2/05 12/3/05 12/4/05 12/5/05 12/6/05 12/7/05 12/7/05 e 2N-329 Well Events Summary e Summaryops TAGGED @ 9332' RKB, EST. 22' RATHOLE. CUT PARAFFIN TO 5000' RKB. RAN 2.5" x 22' DUMMY GUNS TO 9332' RKB. IN PROGRESS. GAUGED TBG. SET 3.75" PLUG @ 8928' RKB. TESTED PLUG 3500 PSI, GOOD. IN PROGRESS. PULLED OV FROM 8885' RKB. LOADED IA WITH DSL. ATTEMPTED SET DV WITHOUT SUCCESS. IN PROGRESS. BRUSHED & FLUSHED GLM @8585' RKB. ATTEMPTED SET DV, STUCK TOOLS, LOST DV WORKING TOOLS FREE. RAN LIB, CONFIRMED GLM EMPTY. IN PROGRESS. STUCK PUMP BAILER @ 8929' RKB ATTEMPTING TO RECOVER LOST DV. DROPPED CUTTER BAR W/1.5" GO DEVIL; RECOVERED ALL WIRE. IN PROGRESS. RECOVERED CUTTER BAR & TOOL STRING; BAILER FULL. ATTEMPTED BAIL FILL & LOST DV, STUCK PUMP BAILER @ 8929' RKB. DROPPED CUTTER BAR w/ 1.5" GO DEVIL. RECOVERED ALL WIRE. IN PROGRESS. JOB START DELAYED BY COLD WEATHER. RECOVERED CUTTER BAR. IN PROGRESS. ATTEMPTED TO RECOVER TOOL STRING, NO SUCCESS. IN PROGRESS. RETRIEVED ENTIRE TOOL STRING FROM 8885' RKB. 1" DV STILL REMAINING ON TOP OF PLUG. IN PROGRESS. FCO TO TAG ON CATCHER SUB AT 8926'. SWEEP HOLE WITH 20 BIO. UNABLE TO DETECT SOLIDS IN RETURNS. 1:1 RETURNS. FREEZE PROTECT TO 3000'. 1.75" CT USED. BAILED ON PLUG @8928' RKB, IN PROGRESS BAILED ON PLUG @ 8928' RKB, IN PROGRESS BAILED TO & DOWN INSIDE OF PLUG @ 8928' RKB, IN PROGRESS SET CATCHER ON TOP OF PLUG @ 8928' RKB, ATTEMPT TO SET DV, IN PROGRESS FOUND MISSING DV, PARTIALLY SET @ 8885' RKB. OOH W/ VALVE. IN PROGRESS. SET DV @ 8885' RKB. PT TBG & IA TO 3500#. BOTH TESTS GOOD. BAILED FILL ON CATCHER @8928' RKB. IN PROGRESS. PULLED CATCHER SUB @ 8928' RKB. BAILED ON PLUG. UNABLE TO PULL PRONG. IN PROGRESS. PULLED PRONG FROM PLUG @ 8928' RKB. UNABLE TO PULL PLUG. IN PROGRESS. BAILED & BRUSHED & BEAT ON PLUG @ 8928' RKB. UNABLE TO PULL. IN PROGRESS. BAILED, BRUSHED & BEAT ON PLUG @ 8928' RKB. UNABLE TO PULL. PLANTED 4.5" PRS W/4.5" BAIT SUB W/ "G" F/N. (OAL=48"). IN PROGRESS. READY FOR CTU. Make up BHA. Attempt to press test, no go, leaking choke manifold. Shut down operations for night due to low temp. In progress. PULL 3.75" BAITED Z6 PLUG FROM 8950 FT RKB CTMD WITH 1.75" COILED TUBING. FREEZE PROTECT WELL TO 2600 FT. PREP UNIT FOR CHFR LOG, SWAP TO 0.39 CABLE, REBUILD BOP'S, CHECK TOOLS.. PERFORATED 9260-80 6 SPF 2.5 HJ 2506 12/8/05 12/9/05 12/10/05 12/11/05 12/12/05 12/13/05 12/14/05 12/15/05 12/16/05 12/17/05 12/20/05 12/27/05 12/28/05 e 2N-329 Well Events Summary e RAN A CASED HOLE RESISTIVITY LOG FROM 9114' TO 9311' -- HAD TROUBLE GETTING DOWN THROUGH LOGGING AREA AND TOOL ELECTRODES COULD NOT MAKE GOOD ELECTRICAL CONTACT WITH THE CASING AT MANY OF THE STATIONS, SUSPECT SCALE AND OR CORROSION PROBLEMS. ATTEMPTED FRACTURE TREATMENT. HAD PROBLEMS WITH DENSITOMETERS ON POD, UNABLE TO TROUBLESHOOT IN FIELD. JOB ABORTED, WILL RETRY AFTER POD IS REPAIRED. PUMPED FRACTURE TREATMENT. PLACED 269,000 LBS 16/20 CARBOLlTE BEHIND PIPE, 10 PPA ON PERFS. PUMPED TREATMENT AS DESIGNED, FLUSHED TO COMPLETION. LEFT -1600 LBS SAND IN WELLBORE. SAW INDICATIONS OF TSO IN 10 PPA STAGE. ALL TREESAVER RUBBERS RECOVERED. SPOT AND RIG UP EQUIPMENT IN PREPARATION FOR FCO TO COMMENSE IN THE AM. FCO FROM 9330' TO 9555'. VERY SMALL AMOUNT OF FRAC- AND FORMATION SANDS IN RETURNS. LOST RETURNS SEVERAL TIMES WHILE POOH. UNABLE TO BRING SUFFICIENT VOLUME OF SANDS TO SURFACE. USED 1.75" CT, N2, SLlCK- & GEL DIESEL. BAILED FRAC SAND FROM 6673' RKB TO 6683' RKB. IN PROGRESS. BAILED FRAC SAND FROM 6680 TO 6695'. IN PROGRESS. CLEANED WELL TO 9570', HARD TAG, BIO AND N2, 1:1 RETURNS THROUGHOUT, LARGE AMOUNTS OF FRAC SAND AND FORMATION SAND. DISPLACED WELL TO DIESEL. LEFT WELL SHUT IN. TAG FILL @ 9011' RKB. EST 299' FILL. ATTEMPT TO PULL DMY VLV IN STA#1 @ 8885' RKB. PUMPED 155 BRLS DIESEL TO FLUSH FRAC SAND FROM TUBING. IN PROGRESS. SET 1" (.313" PORT) BTM LATCH OV IN STA#1 @ 8885' RKB. JOB COMPLETE. FCO WITH NITROGEN, DIESEL AND GELLED DIESEL TO HARD TAG @ 9578'. .8:1 RETURNS ONCE ALL PERFS WERE UNCOVERED. TAG HARD BTM @ 9301' RKB. EST 9' OF FILL OVER BTM PERF. SET 3.75" CATCHER SUB @ 8928' RKB. PULLED BADLY ERODED 1" OV W/ BTM LATCH MISSING @ 8885' RKB. ATTEMPT TO SET 1" OV @ 8885' RKB, NO SUCCESS. IN PROGRESS. SET 1" X .313" OV @ 8885' RKB. RECOVERED BTM LATCH THAT WAS FLOW CUT OFF OF OV THAT WAS PULLED 12-27-05. PULLED CATCHER SUB @ 8928' RKB; RECOVERED PACKING FROM THE FLOW CUT VALVE. JOB COMPLETE, WELL READY FOR PRODUCTION. Field: Well Job # Log Description Date BL 1Y-19 11144040 PIEZO SONA TOOL 11/19/05 1 1 Y -27 11072935 PRODUCTION PROFILE WIDEFT 11/22/05 1 2D-09 11072933 SBHP SURVEY 11/18/05 1 1 R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE WIDEFT 09/10/05 1 10-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 N/A GLS & 6HP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 /CfR..OfDl 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE WIDEFT 11/30/05 1 10-09 11141233 INJECTION PROFILE 12/02/05 1 36-16 N/A INJECTION PROFILE 12108/05 1 10-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE WIDEFT 12/15/05 1 10-101 11144044 MDT 11/24/05 Schlumberger RECEiVED Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ('\r'í".' 2 1.. zo!n~ ur:..t.JV'~ ~ en &. Gas Cons, Ccn',fi:.:dcn Ancl1ürage -~. -~ SIGNED: SÇANNED J~\N 3 0 2006 12/20/05 NO, 3615 t~~-¡)loÎ Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: Kuparuk Color CD 1 DATEb~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10/31/05 Schlumbergep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 SCANNED NOV 2 3 2005 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: - Kuparuk ~-~ Well Job# Log Description Date BL Color CD 1 R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1 D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 /2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 ~ 2C-04 11022934 INJECTION PROFILE 10/14/05 1 '~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01 A 11072922 INJECTION PROFILE 10/26/05 1 1 R-1 0 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 10/19/05 1 1 J-154 11022931 US IT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 SIGNED: ~ (91LJ DATE: 18 dU~ if À.òt1- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. \ qoc_~c__~(_ Î MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Dan Seamount, d,~/Z~~ Commissioner ~, Blair Wondzell, ~ P. I. Supervisor 'l~~(°~ FROM: John Crisp? ~,/u~ C,, SUBJECT: Petroleum Iffspector DATE' July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc; NON-CONFIDENTIAL SVS Tarn KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2N Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L~ Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code G~Sor 2N-307 1990170 2N-308 1990100 94 70 651 P P OIL 2N-309 1990210 , 2N-313 1980910 94 70 70 P P O~ 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970~ 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 2N-323 1980710 94 70 70 P P OIL 2N-325 ~. 1981630 2~;329 ' ' 1980670 94 70' 70 P P OIL 2N-331 1981170 2N-335 1982040 94 70 70~ P P OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% ~ 9o my Remarks: 7/?7/00 Page 1 of 1 SVS Tarn KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2L-305 1982400 94~ 70 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P OIL "~2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% 7390 Day Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc'xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular b~jection during the second quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 8654 12533 CDI-19 33933 100 0 34033 0 34033 1C-25 34216 100 0 34316 I 0 34316 CD1-40 12071 100 0, 12171]l 0 12171 1C-23 9505 100 0 [ 9605 l, 0 9605 Total Volumes into Amzuli for which b~jection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1 D- 10 35473 100 0 35573 Open, Freeze Protected 2N-323 32696 100 0 32796 Open, Freeze Protected 2N-343 17895 100 0 17995 Open, Freeze Protected 2N-329 9 100 0 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendv Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files 5. ?: ¢?. {? 7. ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 4, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-329 (Permit No. 98-67) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-329. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad I ECEIVED b'o ©G 1998 oil & ~as Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well O~L I~1 GAS I~ SUSPENDED i--I ABANDONE© SERVICE r-I 2 Name of Operator !7 Permit Number ARCO Alaska, Inc 98-67 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20257 4 Location of well at surface ~ '~;77~.-.'~_-.~, ; 9 Unit or Lease Name 89' FNL, 880' FEL, Sec. 03, T9N, R7E, UM i ~,:'., J !~ i,~,,~1~ Kuparuk River Unit At Top Producing Interval ! Z¥.~_..~_/'.~¢~ !?~. ~~ [_ 10 Well Number 726' ESL, 2575' FEE, Sec. 33, T10N, R7E, UM I ~j~J~JE~ ~ 2N-329 At Total Depth I ...... '/~r~'~ ...... ~ 11 Field and Pool 4463' FNL, 2965' FEL, Sec. 33, T10N, R7E, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. Tam Oil Pool RKB 28', Pad 121'I ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 26-Apr-98 03-Ma~/-98 06-May-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9690' MD & 5452' TVD 9590' MD & 5381' TVD YES M NO U NA feet MD 1050 APPROX 22 Type Electdc or Other Logs Run Dipole Sonic/FMS, GR/Res, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.58# H-40 SURF. 108' 24' 10 yds High Eady 9.625' 40# L-80 SURF. 3283' 12.25' 361 sx AS III, 350 sx Class G, 60 sx AS 7' x 26# L-80 SURF. 8934' 8.5' 356 sx Class G 4.5" 12.6# L-80 8934' 9680' 8.5' (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5' 8948' 8934' (CSR) 9260'-9310' MD 5147'-5182' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC :DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9260'-9310' injected 96,872# of prop into the formation w/21# ppa at the perfs 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 7/14/98 Flowing Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/~ 8~98 6 TEST PERIOI: 22,5~ 931 10 176 548 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 5O0 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AL VED Form 10-407 Submit in duplica,te Rev. 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 GOR, and time of each phase. Top Reservoir (T3) 9128' 5053' Base Reservoir (T2) 9397' 5254' Annulus left open - freeze protected with diesel. 31. LIST OF AI-rACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,~ ~ Title ~, ~ 7~/~ ,Z ~-'~,. DATE ~ ~/~ 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". Form10-407 Date: 7/7/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-329 WELL_ID: AK9389 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:04/26/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY:0 API NUMBER: 50-103-20257-00 BLOCK: FINAL: 04/25/98 (D1) Tm: 0'( SUPV:RWS 0) MW: 9.8 VISC: 108 PV/YP: 14/ 0 DRILLING SURFACE HOLE APIWL: 12.4 Prep rig for move. Secure well. N/U diverter system. Rig accepted @ 1800 hrs. 4/25/98. Function test diverter. 04/26/98 (D2) TD: 1160' (1160) SUPV:RWS 04/27/98 (D3) TD: 2970' (1810) SUPV:RWS 04/28/98 (D4) TD: 3290' (320) SUPV:RLM 04/29/98 (D5) TD: 3290'( SUPV:RLM o) 04/30/98 (D6) TD: 4002'(712) SUPV:RLM 05/01/98 (D7) TD: 6353'(2351) MW: 10.1 VISC: 91 PV/YP: 21/36 DRILLING 12.25" @ 1658' APIWL: 9.2 Pre-spud meeting. Drilled from 108' to 594'. Replace main cuttings conveyor electric motor - rig downtime. Drilled from 594'-1160' MW: 10.3 VISC: 65 PV/YP: 27/28 WIPER TRIP F/CASING APIWL: 4.8 Continued drilling from 1160'-2970' MW: 10.4 VISC: 51 PV/YP: 21/18 NIPPLE DOWN DIVERTER APIWL: 5.8 Directional drill from 2970' to 3290' Run 9.625" casing. Start first and second stage cement. MW: 9.0 VISC: 41 PV/YP: 8/12 WASH TO BOTTOM PRE-CAUTIONARY APIWL: 12.0 Finish with pumping cement. Nipple down diverter. N/U BOPE and test. Drill out cement from 1429', stage collar at 1436', clean out to 1459' MW: 9.2 VISC: 42 PV/YP: 15/17 DRILLING APIWL: 2.0 Test casing from 1459' to 3013', OK. Drilled cement, baffle at 3164', cement, float collar at 3202', cement to 3260' Drilled cement and float shoe at 3283' Drilled 20' new hole to 3310'. Performed LOT to 12.35 ppg. Directional drill from 3310' to 4002' MW: 9.1 VISC: 44 PV/YP: 13/16 DRILLING. APIWL: 5.8 SUPV:RLM 05/02/98 (DS) TD: 8363' (2010) SUPV:RLM 05/03/98 (Dg) TD: 9690'(1327) SUPV:RLM 05/04/98 (D10) TD: 9690' ( 0) SUPV:RLM 05/05/98 (Dll) TD: 9690' ( 0) SUPV:RLM 05/06/98 (D12) TD: 9690'( 0) SUPV:RLM PJSM. DIRECTIONAL DRILL - MWD F/4002 T/5333' DIRECTIONAL DRILL - MWD F/5333 T/5519' DIRECTIONAL DRILL - MWD F/5519 T/6353' MW: 9.3 VISC: 13 PV/YP: 13/16 APIWL: 4.8 DRILLING. DIRECTIONAL DRIL F/6353 T/6559' - F/7559 T/77123' - 7713 T/8363' MW: 9.8 VISC: 47 PV/YP: 18/24 APIWL: 4.0 RIH. DIRECTIONAL DRIL F/8900 T/9106' PJSM, PLANNED OPS. CIRC HOLE CLEAN, 40 UNITS MAX GAS ON BOTTOMS UP. MW: 9.9 VISC: 49 PV/YP: 20/22 APIWL: 4.4 RUNNING PROD. CSG STRING Run 4.5" x 7" tapered production string. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUNNING 4.5" COMPLETION Continue running 4.5" x 7" production casing to 9680' Cemented casing. Run 4.5" tubing. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED FROM THIS WELL. PJSM. RUN COMPLETION. RELEASED RIG. FREEZE PROTECTED 9-5/8" X 7" ANNULAS W/70 BBLS DIESEL (PUMPED BY HOT OIL) AFTER RIG RELEASE. ARCO Alaska, Inc. UPARUK RIVER UNIT W -ELL SERVICE REPORT K1(N-329(W4-6)) WELL JOB SCOPE 2N-329 FRAC, FRAC SUPPORT DATE O7/O2/98 DAY 2 DALLY WORK INITIAL FRAC OPERATION COMPLETE | SUCCESSFUL (~ Yes (~ N~o~ (~ Yes (~) No InitialTbgPress I FinalTbgPress IlnitialinnerAnn JOB NUMBER 0625982012.12 UNIT NUMBER KEY PERSON SUPERVISOR DS-GALLEGOS CHANEY Final Inner Ann I Initial Outer Ann I Final Outer Ann 1500 PSII 500 PSII 500 PSI DAILY SUMMARY IINITIAL FRAC COMPLETED. SCREENED OUT EARLY. INJECTED 96872 LBS OF PROP IN THE FORMATION W/21# PPA @ I I THE PERF'S. MAXIMUM PRESSURE 5200 PSI & F.G. (.66). UNABLE TO FREEZE PROTECT THE TBG. [Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (18 PEOPLE ON LOCATION). 09:30 PT'D BACKSIDE LINES AND EQUIP. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9000 PSI. 10:15 PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 10 BPM. SLURRY VOLUME PUMPED 253 BBLS. MAXIMUM PRESSURE 4450 PSI AND ENDING PRESSURE 1650 PSI. S/D AND OBTAINED ISIP OF 1126 PSI W/F.G. @ (.66). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 11 MINS @ 870 PSI. PAD VOLUME = 400 BBLS. 11:50 PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 BPM. SLURRY VOLUME PUMPED 635 BBLS. USED 10060 LB OF # 20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 3500 PSI AND ENDING PRESSURE 2600 PSI. STEPPED RATE DOWN AND S/D. OBTAINED ISIP OF 892 PSI W/F.G. @ (.62). PULSED TO DETERMINE CLOSURE AND MONITORED WHTP. 13:45 SLICK PAD W/20# GW @ 15 BPM. VOLUME PUMPED 450 BBLS. MAXIMUM AND ENDING PRESSURE 3200 PSI. 14:15 PUMP FRAC W/50# DELAYED XL GW @ 15 BPM. SCREENED OUT EARLY (HAD PROBLEMS WITH BLENDER & PROP CON SPIKED UP TO 21#). MAXIMUM & ENDING PRESSURE 5200 PSI. SLURRY VOLUME PUMPED 1176 BBLS. PUMPED 129672 LBS OF PROP ( 16900 LBS OF #20/40 & 112772 LBS OF #12/18). INJECTED 96872 LBS OF PROP IN THE FORMATION W/21# PPA @ THE PERF'S. LEFT 32800 LBS OF PROP IN THE WELLBORE, ESTIMATE TOP OF FILL @ 5674' W/BHP OF 2200 PSI. UNABLE TO FREEZE PROTECT THE TBG. 15:50 17:00 18:00 START R/D. DEPRESSURED THE INNER CSG BACK TO 1500 PSI AND R/D LRS HOT OIL UNIT. REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-329(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-329 PERFORATE, PERF SUPPORT 0522981905.4 DATE DAILY WORK UNIT NUMBER 06/26/98 PERFORATE - SBHP 2128 DAY OPERATION COMPLETE I SUCCESSFUL 1 YES J YES Initial Tbg Press Final Tbg Press I Initial Inner Ann 200 PSI 100 PSII 25 PSI DAILY SUMMARY KEY PERSON THORNHILL SUPERVISOR JONES Final Inner Ann Initial Outer Ann Final Outer Ann 25 PSI 180 PSI 180 PSI ISWS FINISHED PERFORATING FROM 9260' TO 9290' WITH 2.5" HC, BH, 4SPF, 180 DEG PHASED NO ORIENT. SBHP @ 9285' FOR 30 MIN = 2375 PSI AND DROPPING. TIME LOG ENTRY 10:30 12:00 SWS (THORNHILL & CREW) MIRU, HELD TGSM, SECURED RADIO SILENCE, ARMED GUN & PT LUB TO 3000#. MIH W/20' - 2.5" HC, BH, 4 SPF, 180 DEG PHASED, NO ORIENT W/2.5" PETROLINE ROLLERS ABOVE & BELOW, 2 1/8" WB, CCL. CORR TO SWS GR/CCL LOG 6-25-98 & PERFED WITH 350# WHP FROM 9270' TO 9290'. 14:40 POH & LD GUN, ALL SHOTS FIRED. 14:45 MU GUN & PT LUB TO 3000#. MIH W/10' - 2.5" HC AS ABOVE, CORR TO ABOVE LOG & PERFED W/350# WHP FROM 9260' TO 9270'. 16:30 POH & LD GUN, ALL SHOTS FIRED. 17:45 MU CPLT & PT LUB TO 3000#. MIH W/CPLT, GR, CCL & 2 1/8" WB. CORR & OBTAIN A SBHP @ 9265' FOR 30 MIN = 2375 PSI AND STILL DROPPING. 19:30 POH & LD TOOLS. 20:30 RIG DOWN. 21:00 RELEASED SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-329(W4-6)) WELL 2N-329 DATE O6/26/98 DAY 1 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK GR/CCL LOG & PERFORATE OPERATION COMPLETE I SuccEssFUL NO I YES Initia! Tbg Press 100 PSI Final Tbg Press 100 PSI Initial Inner Ann 2O PSI KEY PERSON THORNHILL JOB NUMBER 0522981905.4 UNIT NUMBER 2128 SUPERVISOR JONES Final Inner Ann I I 20 PS! Initial OuterAnn I I 180 PSI Final Outer Ann 180 PSI DALLY SUMMARY SWS RAN GUN GR/CCL PASS FROM 8780' TO 9550'. PERFORATED 9290' TO 9310' W/2.5" HC, 4 SPF, BH, 180 DEG IN 1 RUN. TIME LOG ENTRY 17:30 WAITED FOR DOYON 141 TO FINISH CMT JOB. SWS (THORNHILL & CREW) MIRU, HELD TGSM, SECURED RADIOP SILENCE & ARMED GUN. 20:30 MIH W/20' - 2.5" HC, 4 SPF, BH, 180 DEG PHASED, NO ORIENT W/2.5" PETROLINE ROLLERS ABOVE & BELOW, GUN GR/CCL. LOGGED GR/CCL OM 9550' TO 8760' & CORR TO SPERRY SUN MWD 5-4-98. WELLHEAD PRESS 450 PSI, PERFED FROM 9290' TO 9310'. 23:30 POH & LD GUN, ALL SHOTS FIRED. 01:00 RIG DOWN. LEFT EQUIP SPOTTED TO FINISH 6-26-98. 02:00 RELEASED SWS. Well Compliance Report File on Left side of folder 198-067-0 MD 09690 TVD 05452 KUpARyK ~ U~ARN 2N-329 502 i0~22'0'~5~:00" ~0 '~mpletion Date: 5/~/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D SPERRY MPT/GR/EWR4/CNP/SLD OH 7/8/98 7/8/98 OH 7/15/98 7/15/98 OH 7/15/98 7/15/98 OH 7/15/98 7/15/98 D 8453 ~ L DGR/CNP/SLD-MD ~"~L 108-9690 L DGR/CNP/SLD-TVD ~'~AL 108-5451 L DGR/EWR4-MD ~ 108-9690 L DGR/EWR4-TVD k-~AL 108-5451 OH 7/15/98 7/15/98 ~/'~ (~/~ ~ CH 5 7/24/98 7/24/98 L STAT PRES/TEM ~AL 9100-9285 R SRVY CALC ~'3.52-9690. OH 8/5/98 8/6/98 Daily Well Ops!J'/f?!7~ -7/t~t/~¢'2/ Are Dry Ditch Samples Required? ye[~, And ~q~etqvt~--:gt~ no Was the well cored? yes ~-, Analysis Description Recedtv~d~ Comments: Monday, May 01, 2000 Page 1 of 1 ' SURVEY CALCULATION AND FIELD WORKSHEET ~ i Job No. 0450-97414 Sidetrack No. Page __1___ of 5 I'-[l[~:l:~-"~l Company ARCO ALASKA, INC. Rig Contractor& No. DOYON- 141 Field TARN DEVELOPEMENTFIELD Well Name & No. TARN DRILLSITE 2N/329 Survey Section Name P-1 BHI Rep. KIRT CHRISTENSEN WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -88.10 Grid Correction 0.000 Depths Measured From: RKB ~] MSL ~ SS~ Target Description Target Coord. F_./W Slot Coord. E/W -879.77 Magn. Declination 27.100 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft[~ 30m~ 10mE~ Vert. Sec. Azim. 277.10 Magn. to Map Corr. 27.100 Map North to: OTHER · SURVEY DATA Survey ~ , I ....... ] -- Date Tool i Survey I Incl. I Hole CourseI Vertical Total Coordinate I Build Rate i Walk Rate ' Depth I Angle i Direction Length TVD Section N(t)F.r)/S(-) I E(+)/W(-) DL I Build (+) Right (+) Comment Type (FT) I (DB)---q----(--D-D) (F-T) (F'F) [ __ (FT) (Per ~00 F'~_{ Drop (-) Left (-) I MWD 0.00 i 0.00I 0.00 -- '~.00 0.00 0.00I 0.00 · - ' ' ! I I TIE IN POINT 2~-~-98 MWDI 153.52 0.11 i 33.93I 153.52 153.52i -0.07 0.12 0.08 0.07i 0.07 121/2"HOLE ' -- ' ' '~6-'-~-~)'8 ' M 251.39 j 0.36 J 82.49 I 97.87 251.39 ~ -0.41 0.24 0.44 0.31 0.26 26-APR-g8 MWD 343.66 ~ 0.31 i 130.78I 92.27 343.661 -0,89 0.12 0.92 0.301 -0.05 ' I 435.61 i 0.60 ] 294.20 91.95 435.61 -0,64 0.15 0.67 0.98 i 0.32 ............... J. t : ....... I , 26-APR-98 MWDI 526,79 i" 2.59 il, 315.45_ 91.18 526.75__ 1.43 1.81 I -1.22 2.24 2.181 26-APR-98I MWD I 617.97 4.97I 306.28 91.18 617.72 6.50 5,62 -5.85 2.68 2.61 --, 26-APR-98 WDI 715,43 I 9,31 292.23 97.46 714,41 17.80 11,10 -16.55 4.77 4.45 -14,42 26-APR-98 MWDt 797.60 . 14.11 i 288.32 82.17 794.85 I 34.05 16.77 -32.22 5.92 5.84 -4.76 26-APR-98I, MWD 889.62 j 16,73 i 285.69I, 92.02 083.55.._. i 58.15 23.00t -55.63 2.95! 2.85 -2.86 26-APR-98 ', MWD i 980.21 I 21.31 , 283.04 i 90.59 969.17 i 87.43 31.12 -84.23 5.14 ! 5.06 , -2.93 27-APR~98 ! MWD [ 1070.93 ' 27.16 i 285.88 i 90.72 1051.86 i 124.32 40.52 -120.24 6.57 i 6.45 I 3.13 27-APFt-98 MWD il 1260.53 Ii 35.~7 ,i 290.99 91.11 1213.37 221.04 73.13 -213.64 4.671 4.62 1.27 "~!~ - 27'AISR-98 I MwDt 1353.09138.76 291.18 92.56 1286.98 275.48 93.31 -265.99 3.12, 3,12 0.21 27-APR-98 MWDI 1435.84 40.88 290.42 82.75 1350,53 I 326.96 112.12 -315.52 2.63 2.56 -0.92 27-APR-98 MWD i, 1540.65 45.51 ] 286.37 104.81 1426.94I 397.28 134.64 -383.58 5,15 4,42 -3.86 27-APR-98 MWD I 1631.28 50.84I 283.31 90.63 1487,36 464.18 151,85 -448.85 6.40 5.88 -3.38 i 27-APR-98 MWD 1725.16 54.82 I 281.23 93.88 1544.07 538.66 167.71 -521.93 4.59 4.24 -2.22 27-APR-98 MWD 1817.58 I 56.25 283.74 92.42 1596.38 614.51 184.20 -596.31 2.72 1.55 2.72 27-APR-98 MWD 1911.20I 57.45 283.90 93.62 1647.57 692.35 202.92 -672,43 1.29 1.28 0.17 27-APR-98 MWD 2004.37 t 56.76 i 283,18 93.17 1698.17 770.09 221.24 -748.48 0.98 -0.74 -0.77 27-APR-98 MWD 2096.69 I' 57.36I 282.08 92.32 1748.37 847.20 238.18 -824,08 1.19 0.65 -1.19 27-APR-98 MWD 2184.33 58.49 280.85 87.64 1794.91 921.25 252.93 -896.86 1.75 1.29 -1.40 -- 111 i j i ii i ii i i i .11111 I II I I ii i i ~j SURVEYCALCULATJONAND FJELDWORKSHEET JobNo. 0450-97414 S,detrackNo~__ Page 2 of 5 Company ARCO ALASKA. INC. Rig Contractor & No. DOYEN - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/329 Survey Section Name P-1 BHI Rep. KIRT CHRISTENSEN , IJ~'rJ~ WELL DA'IA Target TVD (FO Target Coord. N/S Slot Coord. N/S -88.10 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS?_ Target Description Target Coord. E/W Slot Coord. E/W -879.77 Magn. Declination 27.100 Calculation Method MINIMU.M CURVATURE Target Direction (DP) Build\Walk\DL per: 100fti~ 30m~ lOmE~ Vert. Sec. Azim. 277.10 Magn. to Map Corr. 27.100 Map North to: OTHER · SURVEY DATA ...... ~ J Total Coordinate I Build Rate Walk Rate Survey Survey i Incl. Hole Course Date Tool Depth jangle Direction Length TVD I Vertical . , Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment .... I Type (FT) { (DD) (DD) (IT) (F-"T) (FT) (FT) Drop (-) : Left (-) j 27-APR-98 MWDJ 2277.1~--'~ 6~-00.0~ [ 280.81 92.80 1842.32 1000.85 267.92 -975.22 1.70 I 1.70 -0.041 ' -27-APR-98 I ' ' [ J MWD12371.16161.321 278.50 94,03 1888.35 1 1082.76 281.66 -1056.04 ....... 2,52 1.33 -2.46 27-APR-98 MWD . 2463.49 i 62.57 i 278.94 I 92.33 1931.77 I 1164.21 294.02 -1136.58 1.42 i 1.35 0.48 ........... ~ 'r .... ~ .......... JI -- 27-APR-98 L MWDjt 2556.13 ' 65.94 i_ ~ . i 276.46 92.64 1972.01 { 1247.62 305.17 ! -1219.25 4.36 3.64 -2.68I., 27-APR-98I MWD ! 2649.06 i 65.53 i 277.13 [ 92.93 2010.20 i 1332.34 315.19 T .1303.38 0,79 i -0.44 0.72 , 2'~APR-98 i MWD l- ...... ~ ..... ~ ~ I 9 7~ ~ ' 2741.98 ! 64.76t 277.00 92.92 2049,26 i 1416.66 325.56 -1387.05 0.84 -0.83 -0.14 I MWD 2834.57 J 63.86 I 276.04 92.59 2089.39 , 150~)'~) 335.04 -1469.95 1,35 ,0. -1.04 I I I 93.09 2213.22 1740.79 350.30 -1710.61 2.72 -0.92 -2.89 2~A;~98 MWD 3105.69 161.791 ' 0.84 28-APR-98 | MWD 3206.62 i 62.64 ; 272.01 i 100.93 2260.27 1829.73 353.46 I -1799.85 0.84 J I -0.03 ...........t ,J- I T I ...l "' 30-APR-98 j MWD 13299.60 ] 62.98 j 273.52 , 92.98 2302.76 1912.20 357,45 -1882.45 1.49j 03~, 1.62 j63/4"MlXLSET@1.2 ........... i i 63.05 ' 0 -0.04/ 30-APR-98 MWDi 3388.61 i i 273.48 i 89.01 2343.14 . 1991.36 362.29 -1961.62 0.09 , ' 30-APR-98 MWD 3478.45II 63.45 273.67 89.84 2383.58 2071.43 367.29 , -2041.69 0.48 0.45 t 0.21 I 30-APR-98 MWD ' , -,, 2238.98 377.63 1,j 3574.56 64.11 I 273.45 96.11 2426.04 j 2157.49 372.65 -2127.75 0.72 0.69 -0.23 30-APR-98 MWD 3665.31 J 64,15 273.55 90.75 2465.64 J -2209.25 0.11 0.04 0.11 '30-APR-98 MWD 3756.37 J 63.6i 273.80 91.06 2505.73 ' 2320.60 382.87 -2290.84 0.64 -0.59 J 0.27 31'SLIDE 130R TF 30-APR-98 MWD 3851.29 64.00 274.22 94.92 2547.63 2405.64 388.83 -2375.80 0.57 0.41 0.44 01 -MA¥-98 MWD 3946.15 63.76 276.13 94.86 2589.40 2490.76 396.51 -2460.62 1.83 -0.25 2.01 ., 01-MAY-98 MWD 4036.45 63.46 277.01 90.30 2629.53 2571.65 405.76 -2540.98 0,93 -0.33 0,97 31' SLIDE 140R TF ., I 01 -MAY-98 MWD 4130.83 63.29 276.16 94.38 2671.83 2656.02 415.44 -2624.79 0.83 -0,18 -0.90 ,, , 01-MAY-98 MWD 4224.66 62.42 276,84 93.83 2714.64 2739.50 424.89 -2707.75 1.13 -0.93 0.72 31' SLIDE 180 TF ,,. 01 -MAY-98 MWD 4314.93 62.63 276.36 90.27 2756.29 2819.59 434.09 -2787.31 0.53 0.23 -0.53 1 " 01 -MAY-98 MWD 4407.68 63.04 277.36 j 92.75 2798.63 2902.11 443.95 -2869.24 1.06 0.44 1.08 i ii ii iJ i i i iiiiii i ii i i,K R' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-97414 Sidetrack No, __ Page 3 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. DOYEN - 141 Field TARN DEVELOPEMENT FIELD Well Name & No, TARN DRILLSITE 2N/329 Survey Section Name _ P-1 BHI Rep. KIRT CHRISTENSEN ~N~~ WELL DATA I Target TVD (FT) Target Coord. N/S Slot Coord. N/S -88.10 Grid Correction 0.000 Depths Measured From: RKB .~ MSL[--] SS~ Target Description Target Coord. E/W Slot Coord. E/W -879.77 Magn. Declination 27.100 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ 10m~ Vert. Sec. Azim. 277.10 Magn. to Map Corr. 27.100 Map North to: OTHER SURVEY DATA Survey Survey i Incl. Hole ! Course Vertical Total Coordinate Build Rate I Walk Rate Date Tool Depth AngleDirection { Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) I Comment ..... Type i (FT) (DD) (DD) .~-_--~ (FT) (F'l') (FT) (FT) (Per ~oo F'r) Drop (-) Left (-) 01-MAY-98 MWD 4503.08 63.23 ' 276.58 I 95.40 2841.74 2987.21 454.28 -2953.71 0.76 ~ 0.20 -0.82 ' 0.98 ' 01-MAY-98i MWD i 4593.88 i 63.32 275.59 90.80 2882.58 3068,30 462,87 -3034.35 0.10 -1.09 01-MAY-98 I MWDI 4682.24 i 63.46 i 275.08 88.36 2922.16 3147.26 470.22 -3113.01 0.54 0.16 -0.58 01-MAY-98 i, MWD ,I 4780.49 i 64.06 , 275.84 I 98.25 2965.60 i 3235.35 478.61 -3200.73 0.92 I 0.61 0.77 01-MAY-98 I MwD~ 4869.79 ' ' i [ 63.85 ! 277.16 89.30 3004.81 3315.57 487.69 -3280,45 1.35 -0.24 , 1.48 131' SLIDE 180TF 01-MAY-98 MWD 4961.26 i 62.43[ 277,04 91.47 3046,13 3397.17 497.77 -3361.42 1.56 -1.55 -0.13 01-MAY-98t MWD 5053.90 I 62,03 276,62 92.64 -t 3089.30 3479,14 507.52 -3442.81 0.59 -0.43 -0.45 01 -MAY-98 i MWD 5147.60 61.75 , 276.69 93.70 3133.44 3561.78 517,10 -3524.90 0.31 -0.30 0.07 01-MAY-98 ! MWD I 5238.87 61.40 276,61 i 91.27 3176,89 3642,05 526.40 -3604.63 0.39 -0.38 -0.09 01-MAY-98 ~ 01-MAY-98 ; MWD 5422.23 ! 61.83I 275.81 , 85.89 3264.01 3803.34 542.77 -3765.13 0.45 0.20 0,45 15'SLIDEOTF 01-MAY-98I MWD, 5525.22 ~ 61.25I 274.43 102.99 3313.10 3893.83 550.86 -3855.31 1.31 -0,56 , -1.34 ,, 01-MAY-98 MWD 5616.87 i 61.56 I 274.08 91.65 3356.96 3974.20 556.83 -3935.55 0.48 0.34 -0.38 120' SLIDE OTF 01-MAY-98 MWD , 5795.77 62.43 274.35 92.55 3441.21 4131.79 567.81 -4092.99 0.88 0.68 0.64 01-MAY-98 MWD 5891.44 64,10 274,63 95.67 3484.25 4217.14 574.50 -4178.17 1,77 1.75 0.29 ! 31' SLIDE 20R TF 01-MAY-98 MWD 5981.33 163.67 275,21 89.89 3523.82 4297.79 581.42 -4258.58 0.75 -0.48 0.65 __ 01-MAY-98 MWD 6079.53 t63,49 276,23 98,20 3567.51 4385.71 590.19 -4346.09 0.95 ~).18 1.04 01 - MAY-98 MWD 6171.23 63.04 274.05 91.70 3608.77 4467.55 597.53 -4427.65 2.18 -0.49 -2.38 02-MAY-98 MWD 6266.63 62.67 273.07 95.40 3652.29 4552.28 602,80 -4512,37 0.99 -0,39 -1.03 02-MAY-98 MWD 6357.62 63.41 271.20 90.99 3693.55 4633.07 605.81 -4593.41 2.00 0.81 -2.06 02-MAY-98 MWD 6452.26 64.60 271.35 94.64 3735.03 4717.69 607.71 .4678.46 1.27 1.26 0.16 31' SLIDE 20R TF 02-MAY-98 MWD 6544.45 65.01 271.34 92.19 3774.27 4800.69 609.67 -4761.85 0.44 0.44 -0.01 02-MAY-98 MWD 6637.45 65.47 272.95 93.00 3813.22 4884.82 , 612.83 i .4846.24 1.65 I 0.49 1.73 31' SLIDE 90R TF -- ,. i ! .... i ii I I .... : [l_r~: I Company ARCO ALASKA, INC. . ....... Rig Contractor & No. DOYON - 141 Field TARN DEVELOPEMENT FIELD BI Well Name & No. TARN DRILLSITE 2N/329 Survey Section Name P-1 BHI Rep. KIRT CHRISTENSEN me~ · a~a~' WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -88.10 Grid Correction __0,000 Depths Measured From: RKB ~ MSL~] SS~' Target Description Target Coord. E/W Slot Coord. E/W -879.77 Magn. Declination 27.100 Calculation Method MINIMUM CURVATURE ., !Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ 10m~ Vert. Sec. Azim. 277.10 Magn. to Map Corr. 27,100 Map North to: O_.T, HER SURVEY DATA Survey { I I Total Coordinate Build Rate Walk Rate Date Tool I Survey ! Incl. Hole Course Vertical Depth ' Angle Direction Length 'I'VD Section N(+) / S(-) E(+)/W(-) DL Build (+) Right (+)I Comment Type (ET) (DD) (DD) (F'D (FT) (FT) (FT) (Per 100 ~ Drop (-) Left (-) . ,,i 02-MAY-98 MWD 6730.24 I 66.18 276.22 92,79 3851,23 4969,38 619,60 -4930.60 3.30 0.77 3.52 I , 02-MAY-98 ...... ........ ~l MWD ~ 6914'38 i 66'96; i 276-~)~-~ 90.38 3924.49 5138.31 639.33[_~. -5098.30 1.11 J 0.45 -1.1 ..... J J , 93.65 3961.09 5224,51 649.19 ' -5184.02 0,73j 0,07 0.79 02-MAY-98 [ MWD I 7008.03 67.03 ! 276.94 1 02-MAY-981 MWD i 7101'19 I Ii| ~- , i 65.58 278.28 93.16 3998.53 5309,81 660.48 -5268.57 2,04 i -1.56 1.44 31' SLIDE 160R TF 02-MAY-98 [ MWD 7287.02163.80 279.75 92.78 4077.97 5477.63 688,40' -5434.21 1,03 -0,96 -0,41 ! 02-MAY-98! MWD 7380.14 I 62.66 279.71 I 93.12 4119.92 5560.68 702.4~5--[ -5516.15 1.22 -1.22 -0.04 31'SUDE140LTF 02-MAY-98 ', MWD 7465.82 62.49 277.90 85.68 4159.38 5636.69 -5591.30 -0.20 -2.11 02-MAY-90 I MWD 7558,26 }62.35! 278.79 ~ 92.44 4202.18 5718.61 725.99 -5672,37 0.87 -0.15 0,96 02-MAY-98 i MWD I 7651.14 i 62,35 i 278,44 92.88 4245,28 5800,85 738.31 -5753.71 0.331 0,00 -0.38 02-MAY-98 [ MWD 7754123 ] 62.24 278.66I 103.09 4293.21 [ 5892.09 751l~'1~ '5843,97 0.22! '0,11 ' 0.21 02-MAY-90 MWD 7845.48 t 62'44t 277.82 91.25 4335.57 5972.90 763,46 -5923.96 0.84i 0.22 -0.9 02-MAY-98 [ MWD 7930.18 62,35 277.88 I 84.70 4374.82 6047.95 773,71 t .5998.31 0,12i -0,11 0.07 02-MAY-90 I MWD 8023.17 I 62.34 276,62 92,99 4417.98 6130,31 784.11 -6080,02 1.20 I -0.01 -1.35 31'SLIDE 70LTF 02-MAY-98 ! MWD 8115.56 62.23 275,79 92.39 4460,95 6212,09 792,95 -6161.33 0.80 -0.12 -0.90 I 02-MAY-98t MWD 8208.92 i 62.05 275,72I 93.36 4504.58 6294.61 801.23 -6243.45 0,20 -0,19 -0.08 03-MAY-98 MWD 8308,20 61.35 275.95 I 99.28 4551.65 6382,00 810.11 -6330,41 0.73 -0.71 0.23 45' SLIDE 160L TF i 03-MAY-98 MWD 8397.27 58.87 271,88 t 89.07 4596.04 6459.07 815,42 -6407.42 4.84 -2,78 -4.57 03-MAY-98 MWD 8493.93 56.86 272.95 96.66 4647.46 6540.64 818.86 -6489.19 2.28 -2,08 1.11 31' SLIDE 160L TF 03-MAY-98 MWD 6586.15 55.41 273.20 92.22 4698.85 6617.03 822.96 -6565,66 1.59 -1,57 0.27 31' SLIDE 160R TF 03-MAY-08 MWD 8679.71 53.56 272.58 93.56 4753,19 6692.97 826.81 I -6641.71 2.05 -1.98 -0.66 31' SLIDE 160R TF - i' 03-MAY-08 MWD 8768.32 51.07 272.91 88.61 4807,36 6762.89 830.16 -6711.75 2.83 -2.81 0.37 45' SLIDE 160R IF 03-MAY-98 MWD 8865.91 i 48.39 275.57 I 97.59 4870.44 6837.24 835.63 -6785.99 3,44 .-2.75 2.73 45' SLIDE 150R TF i ii i I i I I ii It iiiii I I i i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-97414 Sidetrack No. Page 5 of _5___- Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/329 Survey Section Name P-1 BHI Rep. KIRT CHRISTENSEN ~ll~r~ WELL DATA / ~a--r~get TVD (~T) Taiget Coord. N/S Slot Coord. N/S -88.10 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. EJW · -879.77 Magn. Declination 27.100 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m[~ 10m0 Vert. Sec. Azim. 277.10 Magn, to Map Corr. 27.100 Map North to: OTHER SURVEY DATA 'Survey I Total Coordinate Build Rate Walk Rate Survey Incl. Hole Course Vertical Date Tool Depth Angle ; Direction Length TVD Section N(+)/S(-) I E(+)/W(-) DL Build (+) Right (+) Comment Type (F-r) I (DD) (DD) (F-r) (FT) (FT), (FT) (Per 100 FT) Drop (-) Left (-) ..__ 03-MAY-98 MWD 8955,04 45.84 274.75 89.13 4931.09 6902.50 841.51 -6851.02 2.94 -2.86 -0.92 45' SLIDE 150R TF , 03-MAY-98 MWD t 9044.61 I 44.74 275.60 i 89.57 4994.11 I 6966.12 847.25 -6914.42 1.40 -1.23 0.95 31' SLIDE 180TF 03-MAY-98 MWDt 9136.90 i 44,98 276.61 92.29 5059.52 7031,21 854.18 -6979.15 0.81 0.26 1.09 1.37I t 03-MAY-98 MWD 9415,34 45.04 279.16 92.84 5256.62 7227,85 881.12 -7173.96 0.99I O. 10 1.40 I , 1.11 I I 03-MAY-98 I MWD 9594.42 44.41 277.70 85.57 5383.67 7354,04 898.88 -7298.90 0.55 -0.55 -0.01 03-MAY-98 I MWD 9690.00 i 44.41 277.70 95.58 5451.95 7420,92 907.84 -7365,19 0,00 0.00 0.00 NO SURVEY EXTRAPOLATED TO TD, 1 _ L . i i i i i i i 7/24/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-i'N: Sherrie NO. 11366 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk ,, KRU 2N-323 ~ '-' ©'-/ I STATIC PRESS/I'EMP SURVEY 980620 I 1 KRU 2N-329 ~ ~. ~.~(~'~I STATIC PRESS/TEMP LOG 980626 I I DATE: SIGNED' ,~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 15, 1998 2N-329, AK-MM-80209 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' ,Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-329: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20257-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20257-00 · '"~ I I 5tt ~ . x MD Neutron & Density Logs: 50-103-20257-00 2" x 5" TVD Neutron & Density Logs: 50-103-20257-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 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 Division of Dresser Industries, Inc. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Tavlor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 8, 1998 2N-329, ,M(-MM-80209 1 LDWG formatted Disc with verification listing. APl#: 50-103-20257-00 PLEASE ACKNOWLEDGE RECEllYF BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVEF~NOF~ ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 14, 1998 Mr. Mike Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 ~'~- ~(or7 Tarn wells 2N-323t~N-329) 2N:343 annular Re: disposal requests Dear Mr. Zanghi: Pursuant to reviewing the additional geologic information, leak-off'test data and cementing information presented today, the Commission is satisfied that sufficient data has been submitted to determine that the waste will be contained in a suitable receiving zone and the disposal will not contaminate freshwater, cause drilling waste to surface, impair the mechanical integrity of the well used for disposal, damage a producing or potentially producing formation or impair the recovery of oil or gas from a pool. Therefore, your request for annular injection into wells 2N-323, 2N-329 and 2N-343 is approved. Dav'~ W. John~ Chairman ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 12, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-329 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for Kuparuk Well 2N-329. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. If there are any questions, please call 265-1492. Sincerely, F. C. Johnson Drilling Engineer Kuparuk Drill Site Development CONFIDENT/AL FCJ/skad cc: Blair Wondzell ARCO Alaska, Inc. Casing Detail 9.625" Surface Casing WELL: TARN 2N-329 DATE: 4/28/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to Pad = 29.5' TOPS Above RKB -7.06 9 5/8" Landing Joint 35.00 -7.06 FMC GEN V- Prudhoe 9 5/8" Csg Hgr 1.56 27.94 jts. 50-85 9 5/8", 40#, L-80 BTC 1368.79 29.50 jr. 49 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 37.60 1398.29 Gemeco 9 5/8" Stage Collar (BAKERLOIO 2.82 1435.89 jt. 48 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 38.79 1438.71 jts. 3-47 9 5/8", 40#, L-80 BTC (shutoff baffle on top of jt #3, BAKERLOK) 1724.38 1477.50 Gemeco Float Collar 1.47 3201.88 jts 1-2 9 5/8", 40#, L-80 BTC 78.00 3203.35 Gemeco Float Shoe 1.69 3281.35 3283.04 ? 40 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, 48, 49 over stop collars and over casing collars on Jts. 3-14 and over collars of jts. 17,20,23,26,29,32,35,38,41,44,47,50,53,56,59,62,65,68,71,74,77,80, 83 and 84 Joints 86-87 (2 joints) will remain in the pipe shed. ·. ~..~ ~!,.~_,! !'...!i: ?_,: Remarks: String Weights with Blocks: 105K# Up, 8OK# Dn, 2Ok# Blocks. Ran 85 ioints of casing. Drifted casing with 8.679 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor:Robert L. Morrison Jr. ARCO Alaska, Inc. Cementing Details Well Name: 2N-329 Report Date: 04~29~98 Report Number: 3 Rig Name: DOYON 141 AFC No.: AK9389 Field: KRU Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: I % washout: 9.625 12.25 NIAI 3283 3'164.21 I Centralizers State type used, intervals covered and spacing Comments: Ran 40 Gemeco Bow Spring centralizers. See Casing Detail for placement. Mud Weight: PV(pdor cond): PV(after cond): YP(pdor cond): YP(after cond): Comments: 10.4 26 21 24 18 Stage 1/Stage 2 Gels before: Gels after: Total Volume Circulated: 9/15 6/14 1070 bbls/634 bbls Wash Stage 1/Stage 2 Type: Volume: Weight: Comments: ARCO B-45 SPACER I0/0 8.3 Spacer Stage 11Stage2 Type: Volume: Weight: Comments: ARCO 30~30 10.5 Lead Cement Stage 1/Stage Type: Mix wtr temp: No. of Sacks: Weight: Yield: 2 Comments: ASIII 70 110/251 10.5/10.5 4.42/4.42 Used AS3 Lite Additives: Comments: 70 350/60 15.8/15.7 1.17/'1.17 Stage I = G Cmt./Stage 2 = AS I Cmt. Additives: Stage 1 = G+0.3% D65, 1.0% SO1. IIIII Stage 2 = AS1 standard blend. Displacement Rate(before fail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 10 10 105 Stage 1 / Stage 2 Reciprocation length: Reciprocation speed: Str. Wt. Down: 10 10 FPM 80 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 240.38~ 109.38 243.71/110.49 85 Calculated top of cement: CP: Bumped plug: Floats held: Surface through stage collar at 1436'. Stage 1 @0058 4/29/98,, yes/yes yes/yes Stage 2 @0324, 4/29/98 Remarks:Stage 1, mixed and pumped 86.5 bbls. AS3 lite at 10.5 ppg. Followed by 62.9 bbls. G + adds at 15.8 ppg. Preceeded cement with 5 bbls water, 10 bbls. preflush at 8.3 and 30 bbls. spacer at 10.5 ppg. Displaced with 10 bbls. G cmt. + 20 bbls. Wash water + 213.71 bbls. 10.4 ppg mud. Reciprocated casing until 181.5 bbls. of displacement had been pumped. Had full returns while circulating and cementing. Stage 2, mixed and pumped 198 bbls. AS3 Lite at 10.5 ppg. Followed by 9.9 bbls. AS 1 at 15.7 ppg. Preceeded cement with 5 bbls. water and 30 bbls. Arco Spacer at 10.5 ppg. Displaced with 20 bbls. wash water and 90.49 bbls. 10.4 ppg. mud. Had full returns while circulating and cementing. Cement Company: I Rig Contractor: Approved By: DS IDOYON Robert L. Morrison Jr. CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-329 Date: 4~30~98 Supervisor: Robert L. Morrison Jr. Casing Size and Description: 9 5~8", 40 ppf, L-80, BTC Casing Setting Depth: 3,283' TMD 2,295' TVD Mud Weight: Hole Depth: 9.O ppg 2,295' TVD EMW = Leak-off Press. + MW 0.052 x TVD 930 psi + 9.0 ppg LOT = (0.052 x 2,295') = 16.8 ppg Fluid Pumped = 4.6 bbl Pump output = 0.1010 bps 25OO 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 ,--e--, LEAK-OFF TEST '--e--CASING TEST , SHUT DOWN PUMP SHUT IN I~RESSURE 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 STROKES TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 24. 1998 Michael Zanghi. Drill Site Dcvcl Supv ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 ac~ Kuparuk River Unit 2N-329 ARCO Alaska. Inc.~]~ Permit No. 98-'~1~ Sur. Loc.' 89'FNL. 880'FEL. Sec. 3. T9N. R7E. UM Btmholc Loc 805'FSL. ' .._497 FWL. Sec. no. T10N. RTE. UM Dear Mr. Zanr, hi: Enclosed is thc approved application for permit to drill thc above rcfcrcnced well. Thc permit to drill docs not cxcmpt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Based on previous evidence from drilling in the Kuparuk River Unit. your request for a waiver to the requirements for H:S is approved and the request for a waiver to 20 AAC 25.033(e)(2)(D) shale density is also approved. Annular disposal of drilling waste ,,',;ill not be approved until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling wastes will be contingent on obtaining a ,,,,'ell cemented surface casing confirmed bra valid Formation Integrity Tcst (FIT) - cementing records. FIT data. and any CQLs must be submitted for approval by the Commission on a Form 10-403 prior to thc start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient noticc (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the tcst. Notice may bc given by~ng the Commission petrolcum ficld inspector on the North · . Chairman '" ~,~ / '~ BY ORDER OF THE IISSION dlt'/¢nch,sures CC: Department offish & Game. Ilabitat Section w o encl. I)epartment et' Environmental Conscr~'ation w o encl. STATE OF ALASKA -~" ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill I~llb. TypeofWell Exploratory Dm` StratigraphicTest ~' Development Oil X Re-Entry E Deepen r'~I Service [~ Development Gas r-: Single Zone X Multiple Zone ~.. 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Unit 3. Address 6. Property Designation ,.~.~O~,pr"~// Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4293 ADLer( 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 89' FNL 880' FEL Sec 3 TDN R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 785' FSL 2,611' FEL Sec 33 T10N R7E, UM 2N-329 #U-630610 At total depth 9. Approximate spud date Amount 805' FSL 2,497' FWL Sec 33 T10N R7E, UM 4/10/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ARCO Tarn #3 MD 9,830' 785' @ target feet 1.1 Miles ' feet 2,560 TVD 5,382' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 450' feet Maximum hole angle 73° Maximum su,~a~e 1,835 psig At total depth (TVD) 2,425 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 20" 16" Welded 80' 28' 28' 108' 108' 230 sx_+ Permafrost Cement 12~,~'' 9-5/8" 40 ppf L-80 BTC 3,681' 28' 28' 3,681' 2,500' ~ sx G, 360 sx AS3L 81/2" 7" 26 ppf L-80 BTC-Mod 8,830' 28' 28' 8,830' 4,490' 540 sx G 8W' 4F2" 12.6 ppf L-80 NSCT 1,000' 8,830' 4,490' 9,830' 5,382' (included above) 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vedical feet Casing Length Size Cemented Measu re~l~E~CE l Structural Conductor Surface Intermediate .-:'.' 1-~. (~ '~ Ix;,J0 Production Liner Perforation depth: measured A~aska 0il & Gas Cof~:. ~;or~trmss~0n true vertical Anchorage 20. Attachments Filing fee X Property plat r- BOP Sketch X DiverterSketch X Drilling program X Drilling fluid program X Time vs de~h plot [~ Refraction analysis [-- Seabed report E~ 20 AAC 25.050 requirements X 21. I hereby certify that the f~~ is true and~ct to the best of my knowledge~(/ Signed . . . Title Drill Site Development Supv. Date ,,~',"'.~ Commission Use Only Permit Number ,/~4,,~ .APl I Approval date .~..,~/_ ¢~ I See cover letter for ~'-~]1"~'_ I 50- ,,~'~.,,~ --' ~..~ .~_~".~' other requirements Conditions of approval ' S~'~ples required [~ Yes ~ No Mud Icg required [~ Yes [~ No Hydrogen sulfide measures []Yes ,~ No Directional survey required .J~ Yes r- No Required working pressure for BOPE r- 2M [~ 3M ~, 5M ~' 10M [-' 15M Other: navid w .,nhno+,-n byorderof ~ "'C~'~ .... ' .... ' ~ ~ Commissioner the commission Date Approved by - -:-_ ...... Form 10-401 Rev. 7-24-89 Submit in triplicate ~ · ARCO Alaska, Inc. '--' GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD -INJECTOR KRU 2N 329 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 121A'' hole to 9-5/8" surface casing point (3,641'_+ MD 2,500' TVD) according to the directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' MD below the base of the permafrost. Use light weight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. AOG¢C Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (2,500' TVD) * (0.25 psi/ft) = 625 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (5, 750 psi) = 4,025 psi 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 81/2'' hole to TD (9,830' MD 5,382' TVD) according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 7" L-80 BTC Csg X 4½" L-80 NSCT tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (5,382' TVD) * (0.25 psi/R) = 1,350 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (7,240 psi) = 5, 070 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (8,440 psi) = 5,910 psi 10. Run 4Y2" L-80 NSCT completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Shut in and secure well. 2N 329 MLP,03/31/98, v. 1 '~ ARCO Alaska, Inc. ~---" 13. Clean location and RDMO in preparation for perforating. AOGCC Casing Testing Regulation 20 AAC 25.030. (g) Pressure Testing of Casing and Casing Surveys. (1) with the exception of structural and conductor casing, before drilling out the casing or liner after cementing, all casing, liners, and liner laps must be tested to a surface pressure of 1500 psig, or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater; however, surface pressure must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent in 30 minutes, or if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken. (2) when, in the commission's discretion, casing is subjected to prolonged actual drilling operations the casing must be pressure tested, calipered or otherwise evaluated by a method approved by the commission. (3) for injection wells, a cement bond log must be obtained following the primary cementing of all casing that is 9-5/8 inches or less in diameter, and sufficient notice of pressure tests required by (1) of this subsection must be given, so that a representative of the commission may witness the test. RECEIVED A~aska 0il & Gas cern:, Anchorage 2N 329 MLP,03/31/98, v.1 2N 329 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB perm afrost'~'~.i:i:i:!: 1,250' TVD Stage :.:.:.:.: 1,450' MD :i:!:i:i: :.:.:.:.: Top of West Sak 1,2OO'TYD West Sak 1,800' 9-5/8" Surface Casing at 3,681' MD / RKB Top of Cement at 8,300' MD / RKB :-:. Production :::::::::::: Casing at .:.:.:.:.:.: 8,830' MD / RKB i:i:i:i:i:i: 4-1/2" Production Casing at 9,830' MD / RKB 12~" Hole 8I/~'' Hole .... ¥:::: :.:.:.. .... ;.:.:.. .... ./.::::::- · .-..,-.,.. .......,%. ,.,,%.,.. .......,%.. ........,.% Conductor Casing Size / Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: 100% RKB 16" in 20" hole Volume Calculations: (135 If) (0.7854 cf/If) (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 228 sx Slurry Volume: 212 cf or ARCTICSET I 230 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Surface Casing Size/Hole Size 9-5/8" in 12-1/4" hole Depth: 3,681' Top of Cement 0' Stage Collar: 1,450' Excess Calculated: 45% Stage 1 400% Stage 2 BHT (Static): 700- F BHT (Circ): 70°- F Stage 1: Volume (2,231 If) (0.3132 cf/If) (1.45) = 1,013 cf shoe joint vol 30 sx + (1,013cf) /(1.15cf/sx) = 911sx System: (Class G cement + 1% SI(CaCI2) + 0.3% D65 (dispersent) + 0.2% D46 (defol Slurry Volume: 1,047 cf or 920 sx Slurry Weight 15.8 ppg rounded Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing Stage 2: Volume (1,050 If) (0.3132 cf/if) (4.00) = 1,315 cf Lead (1,315 cf) /(4.42 cf/sx) = 300 sx (400 If) (0.3132 cf/If) (1.45) = 56 cf Tail (56 cf) /(0.93 cf/sx) = 60 sx System: Lead (Artic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1% S1 (CaCI2) + 1.5% D79 (extender) + 0.4% D46 (defoarr Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,315 cf or 300 sx Slurry Weight 10.5 ppg rounded Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 56 cf or 60 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size / Hole Size Depth: 9,830' Top of 4-1/2" casing 8,830' Top of Cement 8,300' Excess Calculated: 75% BHT (Static): 160° F BHT ( Circ): 130° F Volume around 7 " (530 if) (0.1268 cf/If) Volume around 4-1/2" (1,000 If) (0.2836 cf/If) shoe joint vol 6 sx + (614 cf) /(1.20 cf/sx) System: (Class G cement + 2 gps D600 (latex) + + 0.1 D47 (defoamer) + 3% D53 (Gyp) + 0.7% Slurry Volume: 614 cf Slurry Weight 15.8 ppg Slurry Yield 1.20 cf/sx Thickenincj Time 7" and 4-1/2" in 8-1/2" hole (1.75) = 118 cf (1.75) = 496 cf 614 cf 517 sx 0.1 gps D135 (stabilizer) D65 (disp) + 0.15% D800 (retarder) or 520 sx rounded 3.5 - 4.5 hours 3/31/98 .... ARCO Alaska, Inc. ' .... DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 329 Drillinq Fluid Properties' Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.5-1 O.2 ppg 15-35 25-50 130-150* 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 9.8 - 10.2 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: ITriple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 130-150 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the 8-1/2" production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/E) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,750 psi. Therefore ARCO will test the BOP equipment to 3,000 psi after setting surface casing. MASP = (2,500 ft)(0.70 - 0.11) = 2,551 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4,969'. 2N 329 MLP, 03/31/98, v. 1 ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 329 is the plugged and abandoned ARCO Tarn #3 about one mile to the north. This is the first well to be drilled on this new drillsite. Drillinq Area Risks: The primary risk in the 2N 329 drilling area is lost circulation in the Tarn formation. Careful analysis of pressure data from offset wells shows that a mud weight of 10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumpin_cl Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 329 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation with significant hydrocarbons. We request that 2N 329 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi Max Pressure = 3,060 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: 2N 329 MLP, 03/31/98, v. 1 ARCO Alaska, Inc. Wt Connection 85% of 85% of OD (ppf) 'Grade Range Type Collapse Collapse Burst Burst 9.-5/8" 40 L-80 3 BTC 3,090 psi 2,627 psi 5,750 psi 4,888 psi 7" 26 L-80 3 BTC-M 5,410 psi 4,,599 psi 7,240 psi 6,154 psi 4F2" 12.6 L-80 3 NSCT 7,500 psi 6,37'5 psi 8,440 psi 7,174 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). RECE!VFD APP. Of 1998 Anchorage 2N 329 MLP, 03/31/98, v. 1 ARCO Tarn 2N-343 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT MANUAL GATE KILL LINE ~_~ 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP '"~L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom / --J CHOKE LINE ~1~~o psi WP OCT ~__J~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL L-~ ~ w/two 3" 5,000 psi WP outlets J SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe Diverter Schematic Doyon 141 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I I I 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) 350 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4.200 455O 4900 5250 5600 550 ARCO Alaska, Inc. ' Field : Tarn Development Field Location : North Slope, Alaska -~ r KOP 1¥D=450 TMD::450 DEP=O ~'(~(~ <- West (feet) 91.20700 DLS: 5.00 deg pc, ,00 ,, 7200 6750 6300 5850 5400 4950 4500 4050 3600 3150 2700 2250 1800 1350 900 450 0 450 1~.00 BEGIN TURN TO TARGET ............ ,;~,~0(~ ...................... /135o 19 47 ~D=1008 TMD=1017 OEP=83 e~~ ~ 22.44 ~ ~ ~ 25.42 ~ .~ .o~ I 88' FNL. 880' FELI ~ 900 A 28.40 ~ G~2 I Sec. 5, T9N, R7E ~ I ~ 49.33 ~ ~ 55.32 450 ~ 277.09 Azimuth 7065' (TO TARSET) ~ ***PLANE OF PROPOSAL*** MAXIMUM ANGLE _ BEGIN ANGLE DROP ~D=3481 TMD=~7 DEP~302 71.44 ~ I Plot Reference i, 329 Vet*ion ~3. I c, S~ ~. 29.44 ~ '~ TARGET TVD=SOi2 TMD=9422 DEP=7065 25.44 = TARGEI ANGM, 0 350 700 1050 1400 1 750 2100 2450 2800 3150 .3500 3SbU 4200 4550 4900 5250 5600 5950 61500 6650 7000 7350 Vertical Section (feet) -> Azimuth 277.09 with reference 0.00 N, 0.00 E from slot //329 Crcotcd by ion¢~ For: M PresLridge Dote plotted : 27-Mor-~8 Plot Rei'erence is 529 Version ~5. Coordinat ..... in feet re, .......... ~52g. ARCO A][aska nc. Structure : Tarn Drill Site 2N Well: 329 Field : Tarn Development Field Location : North Slope, Alaska lOOO 80O 600 <- West (feet) 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 i i i i i i i i i i i i I i i i i i i i i i .L..~. I I } I I I I I I I I I I I I I I I I L 3100 ...... 3000 .................. 2900 2800 ....................... 2700 2600 ............................. ~ 2400 '-'T'zz .................. 2300 200 ............. 2200 2100 .......... 1900 17-0 .................... u 15oo .............. 1200 ..... ~3oo J~--~- ~ eoo 1000 1200 4200 4000 3800 5600 5400 5200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 <- West (feet) 400 "~ 200 0 400 1000 800 600 400 200 0 0 20o '~' 400 I V 600 800 1000 1200 1400 ARCO Alaska, Inc. Tarn Drill Site 2N 329 slot #329 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION b-NCERTAINTIES Baker Hughes INTEQ Your ref : 329 Version #3 Our ref : prop2853 License : Date printed : 27-Mar-98 Date created : 27-Feb-98 Last revised : 27-Mar-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.090,w150 18 58.260 Slot Grid coordinates are N 5911919.899, E 460713.162 Slot local coordinates are 87.90 S 879.80 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N, 329 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 329 Version #3 Last revised : 27-Mar-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 285.00 100.00 0.00 N 0.00 E 200.00 0.00 285.00 200.00 0.00 N 0.00 E 300.00 0.00 285.00 300.00 0.00 N 0.00 E 400.00 0.00 285.00 400.00 0.00 N 0.00 ~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 450.00 0.00 285.00 450.00 0.00 N 0.00 E 550.00 3.00 285.00 549.95 0.68 N 2.53 W 650.00 6.00 285.00 649.63 2.71 N 10.11 W 750.00 9.00 285.00 748.77 6.09 N 22.71 W 850.00 12.00 285.00 847.08 10.80 N 40.31 W 0.00 0.00 KOP 3.00 2.59 3.00 10.36 3.00 23.29 3.00 41.34 950.00 15.00 285.00 944.31 16.84 N 62.86 W 1016.67 17.00 285.00 1008.39 21.60 N 80.61 W 1100.00 19.47 283.75 1087.53 28.05 N 105.87 W 1200.00 22.44 282.60 1180.91 36.18 N 140.69 W 1300.00 25.42 281.70 1272.30 44.69 N 180.34 W 3.00 64.46 3.00 82.66 Begin Turn to Target 3.00 108.52 3.00 144.08 3.00 184.48 1400.00 28.40 280.98 1361.46 53.58 N 224.72 W 1500.00 31.39 280.39 1448.15 62.81 N 273.69 W 1600.00 34.37 279.89 1532.12 72.36 N 327.12 W 1700.00 37.36 279.47 1613.15 82.20 N 384.88 W 1800.00 40.36 279.09 1691.01 92.31 N 446.79 W 3.00 229.61 3.00 '279.35 3.00 333.56 3.00 392.08 3.00 454.77 1900.00 43.35 278.76 1765.49 102.66 N 512.70 W 2000.00 46.34 278.47 1836.38 113.22 N 582.41 W 2100.00 49.33 278.20 1903.50 123.96 N 655.74 W 2200.00 52.33 277.96 1966.65 134.85 N 732.49 W 2300.00 55.32 277.73 2025.67 145.86 N 812.45 W 3.00 521.45 3.00 591.94 3.00 666.03 3.00 743.54 3.00 824.25 2400.00 58.32 277.52 2080.39 156.96 N 895.40 W 2500.00 61.31 277.33 2130.67 168.13 N 981.10 W 2600.00 64.31 277.14 2176.36 179.33 N 1069.33 W 2700.00 67.30 276.96 2217.34 190.53 N 1159.85 W 2800.00 70.30 276.80 2253.49 201.69 N 1252.40 W 3.00 907.93 3.00 994.36 3.00 1083.29 3.00 1174.50 3.00 1267.72 2893.61 73.10 276.64 2282.88 212.09 N 1340.66 W 3000.00 73.10 276.64 2313.80 223.87 N 1441.77 W 3500.00 73.10 276.64 2459.13 279.22 N 1916.97 W 3640.63 73.10 276.64 2500.00 294.79 N 2050.63 W 4000.00 73.10 276.64 2604.45 334.57 N 2392.18 W 3.00 1356.59 EOC 0.00 1458.38 0.00 1936.78 0.00 2071.34 9 5/8" Casing Pt 0.00 2415.18 4500.00 73.10 276.64 2749.77 389.92 N 2867.38 W 5000.00 73.10 276.64 2895.09 445.27 N 3342.58 W 5500.00 73.10 276.64 3040.41 500.62 N 3817.79 W 6000.00 73.10 276.64 3185.73 555.97 N 4292.99 W 6500.00 73.10 276.64 3331.06 611.32 N 4768.19 W 0.00 2893.58 0.00 3371.99 0.00 3850.39 0.00 4328.79 0.00 4807.19 7000.00 73.10 276.64 3476.38 666.68 N 5243.40 W 7016.91 73.10 276.64 3481.29 668.55 N 5259.47 W 7100.00 71.44 276.64 3506.59 677.70 N 5338.08 W 7200.00 69.44 276.64 3540.07 688.61 N 5431.67 W 7300.00 67.44 276.64 3576.81 699.37 N 5524.04 W 0.00 5285.59 0.00 5301.77 Begin Angle Drop 2.00 5380.91 2.00 5475.13 2.00 5568.13 7400.00 65.44 276.64 3616.77 709.97 N 5615.09 W 2.00 5659.79 7500.00 63.44 276.64 3659.92 720.41 N 5704.69 W 2.00 5749.99 7600.00 61.44 276.64 3706.18 730.66 N 5792.75 W 2.00 5838.64 7700.00 59.44 276.64 3755.51 740.73 N 5879.15 W 2.00 5925.62 7800.00 57.44 276.64 3807.84 750.59 N 5963.78 W 2.00 6010.82 All data is in feet unless otherwise stated. Coordinates from slot #329 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Total Dogleg for wellpath is 121.41 degrees. Vertical section is from wellhead on azimuth 277.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 329 Version #3 Last revised : 27-Mar-98 Dogleg Vert Deg/100ft Sect 7900.00 55.44 276.64 3863.12 760.23 N 6046.55 W 2.00 6094.15 8000.00 53.44 276.64 3921.27 769.64 N 6127.35 W 2.00 6175.49 8100.00 51.44 276.64 3982.22 778.81 N 6206.09 W 2.00 6254.76 8200.00 49.44 276.64 4045.90 787.73 N 6282.66 W 2.00 6331.85 8300.00 47.44 276.64 4112.24 796.39 N 6356.98 W 2.00 6406.67 8400.00 45.44 276.64 4181.14 804.77 N 6428.96 W 2.00 6479.13 8500.00 43.44 276.64 4252.54 812.87 N 6498.51 W 2.00 6549.15 8600.00 41.44 276.64 4326.33 820.68 N 6565.53 W 2.00 6616.63 8700.00 39.44 276.64 4402.43 828.19 N 6629.96 W 2.00 6681.49 8800.00 37.44 276.64 4480.75 835.38 N 6691.71 W 2.00 6743.66 8900.00 35.44 276.64 4561.19 842.25 N 6750.71 W 2.00 6803.05 9000.00 33.44 276.64 4643.66 848.80 N 6806.89 W 2.00 6859.60 9100.00 31.44 276.64 4728.05 855.00 N 6860.17 W 2.00 6913.24 9200.00 29.44 276.64 4814.26 860.87 N 6910.49 W 2.00 6963.90 9300.00 27.44 276.64 4902.18 866.38 N 6957.79 W 2.00 7011.53 9400.00 25.44 276.64 4991.72 871.53 N 7002.02 W 2.00 7056.05 9422.08 25.00 276.64 5011.69 872.62 N 7011.37 W 2.00 7'065.46 TARGET 9422.09 25.00 276.64 5011.70 872.62 N 7011.37 W 2.00 7065.46 331 Rvsd 20-Mar-98 9500.00 25.00 276.64 5082.31 876.43 N 7044.08 W 0.00 7098.39 9630.32 25.00 276.64 5200.42 882.80 N 7098.78 W 0.00 7153.46 9830.32 25.00 276.64 5381.68 892.58 N 7182.74 W 0.00 7237.99 TD / 7" Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #329 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Total Dogleg for wellpath is 121.41 degrees. Vertical section is from wellhead on azimuth 277.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 329 Version #3 Last revised : 27-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 450 1016 2893 3640 7016 9422 9422 9830 00 450.00 0 67 1008.39 21 61 2282.88 212 63 2500.00 294 91 3481.29 668 08 5011.69 872 09 5011.70 872 32 5381.68 892 00 N 60 N 09 N 79 N 55 N 62 N 62 N 58 N 0.00 E KOP 80.61 W Begin Turn to Target 1340.66 W EOC 2050.63 W 9 5/8" Casing Pt 5259.47 W Begin Angle Drop 7011.37 W TARGET 7011.37 W 331 Rvsd 20-Mar-98 7182.74 W TD / 7" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3640.63 2500.00 294.79N 2050.63W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9830.32 5381.68 892.58N 7182.74W 7" Casing Targets associated with this wellpath Target ha=ne Geographic Location T.V.D. Rectangular Coordinates Revised 331 Rvsd 20-Mar-98 453707.000,5912828.000,0.0000 5011.70 872.62N 7011.37W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 329 Version #3 Last revised : 27-Mar-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 87.90 S 879.80 W 0.00 0.00 100.00 0.00 285.00 100.00 87.90 S 879.80 W 0.00 0.00 200.00 0.00 285.00 200.00 87.90 S 879.80 W 0.00 0.00 300.00 0.00 285.00 300.00 87.90 S 879.80 W 0.00 0.00 400.00 0.00 285.00 400.00 87.90 S 879.80 W 0.00 0.00 450.00 0.00 285.00 450.00 87.90 S 879.80 W 0.00 0.00 KOP 550.00 3.00 285.00 549.95 87.22 S 882.33 W 3.00 2.59 650.00 6.00 285.00 649.63 85.19 S 889.91 W 3.00 10.36 750.00 9.00 285.00 748.77 81.81 S 902.52 W 3.00 23.29 850.00 12.00 285.00 847.08 77.10 S 920.12 W 3.00 41.34 950.00 15.00 285.00 944.31 71.06 S 942.66 W 3.00 1016.67 17.00 285.00 1008.39 66.30 S 960.41 W 3.00 1100.00 19.47 283.75 1087.53 59.85 S 985.67 W 3.00 1200.00 22.44 282.60 1180.91 51.72 S 1020.50 W 3.00 1300.00 25.42 281.70 1272.30 43.21 S 1060.15 W 3.00 64.46 82.66 Begin Turn to Target 108.52 144.08 184.48 1400.00 28.40 280.98 1361.46 34.32 S 1104.52 W 3.00 1500.00 31.39 280.39 1448.15 25.09 S 1153.49 W 3.00 1600.00 34.37 279.89 1532.12 15.54 S 1206.93 W 3.00 1700.00 37.36 279.47 1613.15 5.70 S 1264.68 W 3.00 1800.00 40.36 279.09 1691.01 4.41 N 1326.60 W 3.00 229.61 '279.35 333.56 392.08 454.77 1900.00 43.35 278.76 1765.49 14.76 N 1392.50 W 3.00 2000.00 46.34 278.47 1836.38 25.32 N 1462.22 W 3.00 2100.00 49.33 278.20 1903.50 36.06 N 1535.55 W 3.00 2200.00 52.33 277.96 1966.65 46.95 N 1612.30 W 3.00 2300.00 55.32 277.73 2025.67 57.96 N 1692.26 W 3.00 521.45 591.94 666.03 743.54 824.25 2400.00 58.32 277.52 2080.39 69.07 N 1775.20 W 3.00 2500.00 61.31 277.33 2130.67 80.23 N 1860.91 W 3.00 2600.00 64.31 277.14 2176.36 91.43 N 1949.14 W 3.00 2700.00 67.30 276.96 2217.34 102.63 N 2039.65 W 3.00 2800.00 70.30 276.80 2253.49 113.79 N 2132.21 W 3.00 907.93 994.36 1083.29 1174.50 1267.72 2893.61 73.10 276.64 2282.88 124.19 N 2220.46 W 3.00 3000.00 73.10 276.64 2313.80 135.97 N 2321.58 W 0.00 3500.00 73.10 276.64 2459.13 191.32 N 2796.78 W 0.00 3640.63 73.10 276.64 2500.00 206.89 N 2930.44 W 0.00 4000.00 73.10 276.64 2604.45 246.67 N 3271.98 W 0.00 1356.59 EOC 1458.38 1936.78 2071.34 9 5/8" Casing Pt 2415.18 4500.00 73.10 276.64 2749.77 302.02 N 3747.19 W 0.00 5000.00 73.10 276.64 2895.09 357.37 N 4222.39 W 0.00 5500.00 73.10 276.64 3040.41 412.72 N 4697.59 W 0.00 6000.00 73.10 276.64 3185.73 468.07 N 5172.79 W 0.00 6500.00 73.10 276.64 3331.06 523.43 N 5648.00 W 0.00 2893.58 3371.99 3850.39 4328.79 4807.19 7000.00 73.10 276.64 3476.38 578.78 N 6123.20 W 0.00 7016.91 73.10 276.64 3481.29 580.65 N 6139.27 W 0.00 7100.00 71.44 276.64 3506.59 589.81 N 6217.88 W 2.00 7200.00 69.44 276.64 3540.07 600.71 N 6311.47 W 2.00 7300.00 67.44 276.64 3576.81 611.47 N 6403.85 W 2.00 5285.59 5301.77 Begin Angle Drop 5380.91 5475.13 5568.13 7400.00 65.44 276.64 3616.77 622.07 N 6494.89 W 2.00 5659.79 7500.00 63.44 276.64 3659.92 632.51 N 6584.50 W 2.00 5749.99 7600.00 61.44 276.64 3706.18 642.77 N 6672.55 W 2.00 5838.64 7700.00 59.44 276.64 3755.51 652.83 N 6758.95 W 2.00 5925.62 7800.00 57.44 276.64 3807.84 662.69 N 6843.58 W 2.00 6010.82 Ail data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, R7E and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Total Dogleg for wellpath is 121.41 degrees. Vertical section is from wellhead on azimuth 277.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site '2N, 329 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A Depth Degrees Degrees Depth C O O R D I N A T E 7900.00 55.44 276.64 3863.12 672.33 N 8000.00 53.44 276.64 3921.27 681.74 N 8100.00 51.44 276.64 3982.22 690.91 N 8200.00 49.44 276.64 4045.90 699.83 N 8300.00 47.44 276.64 4112.24 708.49 N PROPOSAL LISTING Page 2 Your ref : 329 Version #3 Last revised : 27-Mar-98 8400.00 45.44 276.64 4181.14 716.87 N 8500.00 43.44 276.64 4252.54 724.98 N 8600.00 41.44 276.64 4326.33 732.78 N 8700.00 39.44 276.64 4402.43 740.29 N 8800.00 37.44 276.64 4480.75 747.48 N R Dogleg Vert S Deg/100ft Sect 8900.00 35.44 276.64 4561.19 754.35 N 9000.00 33.44 276.64 4643.66 760.90 N 9100.00 31.44 276.64 4728.05 767.11 N 9200.00 29.44 276.64 4814.26 772.97 N 9300.00 27.44 276.64 4902.18 778.48 N 6926.35 W 7007.15 W 7085.89 W 7162.47 W 7236.79 W 9400.00 25.44 276.64 4991.72 783.63 N 9422.08 25.00 276.64 5011.69 784.72 N 9422.09 25.00 276.64 5011.70 784.72 N 9500.00 25.00 276.64 5082.31 788.53 N 9630.32 25.00 276.64 5200.42 794.90 N 77 W 31 W 34 W 77 W 52 W 52 W 69 W 97 W 3O W 6O W 7308. 7378. 7445. 7509. 7571. 7630. 7686. 7739. 7790. 7837. 7881.83 W 7891.17 W 7891.18 W 7923.88 W 7978.59 W 9830.32 25.00 276.64 5381.68 804.68 N 8062.54 W 2.00 6094.15 2.00 6175.49 2.00 6254.76 2.00 6331.85 2.00 6406.67 2.00 6479.13 2.00 6549.15 2.00 6616.63 2.00 6681.49 2.00 6743.66 2.00 6803.05 2.00 6859.60 2.00 6913.24 2.00 6963.90 2.00 7011.53 2.00 7056.05 2.00 7'065.46 TARGET 2.00 7065.46 331 Rvsd 20-Mar-98 0.00 7098.39 0.00 7153.46 0.00 7237.99 TD / 7" Casing Pt RECEIVED Alaska Oil & ~ias Cons. Commission Anchorage All data is in feet unless otherwise stated. Coordinates from SE Corner of'Sec. 34, T10N, RTE and TVD from RF~B (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Total Dogleg for wellpath is 121.41 degrees. Vertical section is from wellhead on azimuth 277.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 329 Version #3 Last revised : 27-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 450 00 1016 67 2893 61 3640 63 7016 91 9422 08 9422.09 9830.32 450.00 87.90 S 879 1008.39 66.30 S 960 2282.88 124.19 N 2220 2500.00 206.89 N 2930 3481.29 580.65 N 6139 5011.69 784.72 N 7891 5011.70 784.72 N 7891 5381.68 804.68 N 8062 80 W KOP 41 W Begin Turn to Target 46 W EOC 44 W 9 5/8" Casing Pt 27 W Begin Angle Drop 17 W TARGET 18 W 331 Rvsd 20-Mar-98 54 W TD / 7" Casing Pt Casing positions in string 'A' ======================= ======= Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 87.90S 879.80W 3640.63 2500.00 206.89N 2930.44W 9 5/8" Casing 0.00 0.00 87.90S 879.80W 9830.32 5381.68 804.68N 8062.5%W 7" Casing Targets associated with this wellDath ===================================== Target na~e Geographic Location T.V.D. Rectangular Coordinates Revised 331 Rvsd 20-Mar-98 453707.000,5912828.000,0.0000 5011.70 784.72N 7891.18W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 329 Version Last revised : 27-Mar-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S Vert Ellipse Semi Axes Minor · Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 285.00 100.00 0.00 N 0.00 E 200.00 0.00 285.00 200.00 0.00 N 0.00 E 300.00 0.00 285.00 300.00 0.00 N 0.00 E 400.00 0.00 285.00 400.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 0.00 0.26 0.26 0.15 N/A 0.00 0.52 0.52 0.30 N/A 0.00 0.78 0.78 0.45 N/A 0.00 1.04 1.04 0.60 N/A 450.00 0.00 285.00 450.00 0.00 N 0.00 E 550.00 3.00 285.00 549.95 0.68 N 2.53 W 650.00 6.00 285.00 649.63 2.71 N 10.11 W 750.00 9.00 285.00 748.77 6.09 N 22.71 W 850.00 12.00 285.00 847.08 10.80 N 40.31 W 0.00 1.17 1.17 0.68 N/A 2.59 1.45 1.44 0.83 285.00 10.36 1.79 1.70 0.98 285.00 23.29 2.27 1.98 1.13 285.00 41.34 2.95 2.28 1.29 285.00 950.00 15.00 285.00 944.31 16.84 N 62.86 W 1016.67 17.00 285.00 1008.39 21.60 N 80.61 W 1100.00 19.47 283.75 1087.53 28.05 N 105.87 W 1200.00 22.44 282.60 1180.91 36.18 N 140.69 W 1300.00 25.42 281.70 1272.30 44.69 N 180.34 W 64.46 3.89 2.60 1.45 285.00 82.66 4.65 2.83 1.56 285.00 108.52 5.80 3.13 1.71 284.69 144.08 7.51 3.52 1.91 284.13 184.48 9.58 3.94 2.13 283.54 1400.00 28.40 280.98 1361.46 53.58 N 224.72 W 1500.00 31.39 280.39 1448.15 62.81 N 273.69 W 1600.00 34.37 279.89 1532.12 72.36 N 327.12 W 1700.00 37.36 279.47 1613.15 82.20 N 384.88 W 1800.00 40.36 279.09 1691.01 92.31 N 446.79 W 229.61 12.03 4.39 2.38 282.97 279.35 14.88 4.87 2.67 282.43 333.56 18.15 5.36 2.99 281.94 392.08 21.86 5.88 3.37 281.49 454.77 26.02 6.41 3.79 281.09 1900.00 43.35 278.76 1765.49 102.66 N 512.70 W 2000.00 46.34 278.47 1836.38 113.22 N 582.41 W 2100.00 49.33 278.20 1903.50 123.96 N 655.74 W 2200.00 52.33 277.96 1966.65 134.85 N 732.49 W 2300.00 55.32 277.73 2025.67 145.86 N 812.45 W 521.45 30.63 6.95 4.28 280.72 591.94 35.71 7.49 4.81 280.38 666.03 41.24 8.02 5.40 280.08 743.54 47.22 8.56 6.05 279.80 824.25 53.63 9.07 6.76 279.54 2400.00 58.32 277.52 2080.39 156.96 2500.00 61.31 277.33 2130.67 168.13 2600.00 64.31 277.14 2176.36 179.33 2700.00 67.30 276.96 2217.34 190.53 2800.00 70.30 276.80 2253.49 201.69 895.40 W 907.93 60.47 9.58 7.52 279.30 981.10 W 994.36 67.71 10.06 8.33 279.08 1069.33 W 1083.29 75.33 10.51 9.18 278.88 1159.85 W 1174.50 83.29 10.93 10.09 278.69 1252.40 W 1267.72 91.56 11.32 11.03 278.52 2893.61 73.10 276.64 2282.88 212.09 3000.00 73.10 276.64 2313.80 223.87 3500.00 73.10 276.64 2459.13 279.22 3640.63 73.10 276.64 2500.00 294.79 4000.00 73.10 276.64 2604.45 334.57 1340.66 W 1356.59 99.55 11.65 11.94 278.36 1441.77 W 1458.38 108.65 12.03 12.99 278.21 1916.97 W 1936.78 151.50 13.77 17.91 277.76 2050.63 W 2071.34 163.58 14.26 19.30 277.69 2392.18 W 2415.18 194.45 15.50 22.85 277.51 4500.00 73.10 276.64 2749.77 389.92 5000.00 73.10 276.64 2895.09 445.27 5500.00 73.10 276.64 3040.41 500.62 6000.00 73.10 276.64 3185.73 555.97 6500.00 73.10 276.64 3331.06 611.32 2867.38 W 2893.58 237.44 17.21 27.79 277.35 3342.58 W 3371.99 280.45 18.92 32.74 277.24 3817.79 W 3850.39 323.48 20.61 37.69 277.16 4292.99 W 4328.79 366.52 22.31 42.64 277.10 4768.19 W 4807.19 409.57 24.00 47.60 277.05 7000.00 73.10 276.64 3476.38 666.68 N 7016.91 73.10 276.64 3481.29 668.55 N 7100.00 71.44 276.64 3506.59 677.70 N 7200.00 69.44 276.64 3540.07 688.61 N 7300.00 67.44 276.64 3576.81 699.37 N 5243.40 W 5285.59 452.61 25.69 52.55 277.01 5259.47 W 5301.77 454.07 25.74 52.72 277.01 5338.08 W 5380.91 461.10 26.04 53.53 277.01 5431.67 W 5475.13 469.38 26.42 54.48 277.00 5524.04 W 5568.13 477.45 26.83 55.41 276.99 7400.00 65.44 276.64 3616.77 709.97 N 5615.09 W 5659.79 485.29 27.25 56.31 276.99 7500.00 63.44 276.64 3659.92 720.41 N 5704.69 W 5749.99 492.90 27.70 57.18 276.98 7600.00 61.44 276.64 3706.18 730.66 N 5792.75 W 5838.64 500.26 28.17 58.02 276.98 7700.00 59.44 276.64 3755.51 740.73 N 5879.15 W 5925.62 507.36 28.65 58.83 276.97 7800.00 57.44 276.64 3807.84 750.59 N 5963.78 W 6010.82 514.19 29.15 59.61 276.97 All data is in feet unless otherwSse stated. Coordinates from slot #329 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Vertical section is from wellhead on azimuth 277.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Vert Sect PROPOSAL LISTING Page 2 Your ref : 329 Version #3 Last revised : 27-Mar-98 Ellipse Semi Axes Minor Major Minor Vert. Azi. 7900.00 55.44 276.64 3863.12 760.23 N 6046.55 W 6094.15 520.73 29.67 60.36 276.97 8000.00 53.44 276.64 3921.27 769.64 N 6127.35 W 6175.49 526.99 30.19 61.08 276.96 8100.00 51.44 276.64 3982.22 778.81 N 6206.09 W 6254.76 532.95 30.73 61.76 276.96 8200.00 49.44 276.64 4045.90 787.73 N 6282.66 W 6331.85 538.61 31.28 62.40 276.95 8300.00 47.44 276.64 4112.24 796.39 N 6356.98 W 6406.67 543.96 31.83 63.01 276.95 8400.00 45.44 276.64 4181.14 804.77 N 6428.96 W 6479.13 549.00 32.38 63.58 276.95 8500.00 43.44 276.64 4252.54 812.87 N 6498.51 W 6549.15 553.73 32.94 64.12 276.95 8600.00 41.44 276.64 4326.33 820.68 N 6565.53 W 6616.63 558.15 33.50 64.63 276.94 8700.00 39.44 276.64 4402.43 828.19 N 6629.96 W 6681.49 562.26 34.05 65.09 276.94 8800.00 37.44 276.64 4480.75 835.38 N 6691.71 W 6743.66 566.07 34.60 65.53 276.94 8900.00 35.44 276.64 4561.19 842.25 N 6750.71 W 6803.05 569.57 35.14 65.93 276.94 9000.00 33.44 276.64 4643.66 848.80 N 6806.89 W 6859.60 572.77 35.68 66.30 276.94 9100.00 31.44 276.64 4728.05 855.00 N 6860.17 W 6913.24 575.69 36.20 66.63 276.94 9200.00 29.44 276.64 4814.26 860.87 N 6910.49 W 6963.90 578.32 36.71 66.94 276.93 9300.00 27.44 276.64 4902.18 866.38 N 6957.79 W 7011.53 580.67 37.21 67.21 276.93 9400.00 25.44 276.64 4991.72 871.53 N 7002.02 W 7056.05 582.77 37.69 67.46 276.93 9422.08 25.00 276.64 5011.69 872.62 N 7011.37 W 7065.46 5'83.22 37.79 67.51 276.93 9422.09 25.00 276.64 5011.70 872.62 N 7011.37 W 7065.46 583.22 37.79 67.51 276.93 9500.00 25.00 276.64 5082.31 876.43 N 7044.08.W 7098.39 584.80 38.16 67.70 276.93 9630.32 25.00 276.64 5200.42 882.80 N 7098.78 W 7153.46 587.46 38.79 68.01 276.93 9830.32 25.00 276.64 5381.68 892.58 N 7182.74 W 7237.99 591.54 39.74 68.50 276.93 POSITION UNCERTAINTY SUM/6ARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 9830 ARCO (H.A. Mag) User specified 591.54 39.74 68.50 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #329 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Vertical section is from wellhead on azimuth 277.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 329 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 329 Version #3 Last revised : 27-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 450 1016 2893 3640 7016 9422 9422 9830 00 67 61 63 91 08 09 32 450 00 1008 39 2282 88 2500 00 3481 29 5011 69 5011 70 5381.68 0 21 212 294 668 872 872 892 00 N 6O N 09 N 79 N 55 N 62 N 62 N 58 N 0.00 E KOP 80.61 W Begin Turn to Target 1340.66 W EOC 2050.63 W 9 5/8" Casing Pt 5259.47 W Begin Angle Drop 7011.37 W TARGET 7011.37 W 331 Rvsd 20-Mar-98 7182.74 W TD / 7" Casing Pt Casing positions in string 'A' ___ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3640.63 2500.00 294.79N 2050.63W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9830.32 5381.68 892.58N 7182.74W 7" Casing Targets associated with this wellpath ...... Target name Geographic Location T.V.D. Rectangular Coordinates Revised 331 Rvsd 20-Mar-98 453707.000,5912828.000,0.0000 5011.70 872.62N 7011.37W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 329 Version #3 Last revised : 27-Mar-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 100.00 0.00 285.00 100.00 0.00N 200.00 0.00 285.00 200.00 0.00N 300.00 0.00 285.00 300.00 0.00N 400.00 0.00 285.00 400.00 0.00N 0.00E 0.00 0.00 460713.16 5911919.90 0.00E 0.00 0.00 460713.16 5911919.90 0.00E 0.00 0.00 460713.16 5911919.90 0.00E 0.00 0.00 460713.16 5911919.90 0.00E 0.00 0.00 460713.16 5911919.90 450.00 0.00 285.00 450.00 550.00 3.00 285.00 549.95 650.00 6.00 285.00 649.63 750.00 9.00 285.00 748.77 850.00 12.00 285.00 847.08 0.00N 0.68N 2.71N 6.09N 10.80N 0.00E 0.00 0.00 460713.16 5911919.90 2.53W 3.00 2.59 460710.64 5911920.59 10.11W 3.00 10.36 460703.07 5911922.66 22.71W 3.00 23.29 460690.48 5911926.10 40.31W 3.00 41.34 460672.91 5911930.90 950.00 15,00 285.00 944.31 1016.67 17.00 285.00 1008.39 1100.00 19.47 283.75 1087.53 1200.00 22.44 282.60 1180.91 1300.00 25.42 281.70 1272.30 16.84N 21.60N 28.05N 36.18N 44.69N 62.86W 3.00 64.46 460650.40 5911937.06 80.61W 3.00 82.66 460632.67 5911941.90 105.87W 3.00 108.52 460607.45 5911948.49 140.69W 3.00 144.08 460572.67 5911956.79 180.34W 3.00 184.48 460533.07 5911965.50 1400.00 28.40 280.98 1361.46 1500.00 31.39 280.39 1448.15 1600.00 34.37 279.89 1532.12 1700.00 37.36 279.47 1613.15 1800.00 40.36 279.09 1691.01 53.58N 62.81N 72.36N 82.20N 92.31N 224.72W 3.00 229.61 460488.74 5911974.61 273.69W 3.00 27'9.35 460439.82 5911984.09 327.12W 3.00 333.56 460386.44 5911993.91 384.88W 3.00 392.08 460328.74 5912004.04 446.79W 3.00 454.77 460266.89 5912014.47 1900.00 43.35 278.76 1765.49 2000.00 46.34 278.47 1836.38 2100.00 49.33 278.20 1903.50 2200.00 52.33 277.96 1966.65 2300.00 55.32 277.73 2025.67 102.66N 113.22N 123.96N 134.85N 145.86N 512.70W 3.00 521.45 460201.04 5912025.15 582.41W 3.00 591.94 460131.39 5912036.06 655.74W 3.00 666.03 460058.12 5912047.17 732.49W 3.00 743.54 459981.43 5912058.45 812.45W 3.00 824.25 459901.54 5912069.87 2400.00 58.32 277.52 2080.39 2500.00 61.31 277.33 2130.67 2600.00 64.31 277.14 2176.36 2700.00 67.30 276.96 2217.34 2800.00 70.30 276.80 2253.49 156.96N 895.40W 3.00 907.93 459818.66 5912081.39 168.13N 981.10W 3.00 994.36 459733.02 5912092.99 179.33N 1069.33W 3.00 1083.29 459644.86 5912104.63 190.53N 1159.85W 3.00 1174.50 459554.41 5912116.29 201.69N 1252.40W 3.00 1267.72 459461.92 5912127.92 2893.61 73.10 276.64 2282.88 3000.00 73.10 276.64 2313.80 3500.00 73.10 276.64 2459.13 3640.63 73.10 276.64 2500.00 4000.00 73.10 276.64 2604.45 212.09N 1340.66W 3.00 1356.59 459373.73 5912138.77 223.87N 1441.77W 0.00 1458.38 459272.69 5912151.06 279.22N 1916.97W 0.00 1936.78 458797.82 5912208.81 294.79N 2050.63W 0.00 2071.34 458664.25 5912225.06 334.57N 2392.18W 0.00 2415.18 458322.95 5912266.57 4500.00 73.10 276.64 2749.77 5000.00 73.10 276.64 2895.09 5500.00 73.10 276.64 3040.41 6000.00 73.10 276.64 3185.73 6500.00 73.10 276.64 3331.06 389.92N 2867.38W 0.00 2893.58 457848.08 5912324.33 445.27N 3342.58W 0.00 3371.99 457373.21 5912382.08 500.62N 3817.79W 0.00 3850.39 456898.34 5912439.84 555.97N 4292.99W 0.00 4328.79 456423.47 5912497.60 611.32N 4768.19W 0.00 4807.19 455948.60 5912555.35 7000.00 73.10 276.64 3476.38 7016.91 73.10 276.64 3481.29 7100.00 71.44 276.64 3506.59 7200.00 69.44 276.64 3540.07 7300.00 67.44 276.64 3576.81 7400.00 65.44 276.64 3616.77 7500.00 63.44 276.64 3659.92 7600.00 61.44 276.64 3706.18 7700.00 59.44 276.64 3755.51 7800.00 57.44 276.64 3807.84 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #329 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Total Dogleg for wellpath is 121.41 degrees. Vertical section is from wellhead on azimuth 277.09 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 666.68N 5243.40W 0.00 5285.59 455473.73 5912613.11 668.55N 5259.47W 0.00 5301.77 455457.67 5912615.06 677.70N 5338.08W 2.00 5380.91 455379.12 5912624.62 688.61N 5431.67W 2.00 5475.13 455285.59 5912635.99 .oo 705.97N 5615.05~ 2.00 5659.79 455102.30 5912658.28 720.41N 5704.69W 2.00 5749.99 455012.76 5912669.18 730.66N 5752.75W 2.00 5838.64 454924.77 5512679.88{..;~'~ !~r~i-\ \:.,; £ '] ~9 740.73N 5879.15W 2.00 5925.62 454838.43 5512650.38 750.59N 5963.78W 2.00 6010.82 454753.86 5512700.67 Anchorage ARCO Alaska, Inc. Tarn Drill Site 2N,329 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 329 Version #3 Last revised : 27-Mar-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 7900.00 55.44 276.64 3863.12 760.23N 6046.55W 2.00 6094.15 454671.14 5912710.73 8000.00 53.44 276.64 3921.27 769.64N 6127.35W 2.00 6175.49 454590.40 5912720.55 8100.00 51.44 276.64 3982.22 778.81N 6206.09W 2.00 6254.76 454511.72 5912730.12 8200.00 49.44 276.64 4045.90 787.73N 6282.66W 2.00 6331.85 454435.20 5912739.42 8300.00 47.44 276.64 4112.24 796.39N 6356.98W 2.00 6406.67 454360.93 5912748.46 8400.00 45.44 276.64 4181.14 804.77N 6428.96W 2.00 6479.13 454289.00 5912757.21 8500.00 43.44 276.64 4252.54 812.87N 6498.51W 2.00 6549.15 454219.50 5912765.66 8600.00 41.44 276.64 4326.33 820.68N 6565.53W 2.00 6616.63 454152.52 5912773.81 8700.00 39.44 276.64 4402.43 828.19N 6629.96W 2.00 6681.49 454088.14 5912781.64 8800.00 37.44 276.64 4480.75 835.38N 6691.71W 2.00 6743.66 454026.43 5912789.14 8900.00 35.44 276.64 4561.19 842.25N 6750.71W 2.00 6803.05 453967.48 5912796.32 9000.00 33.44 276.64 4643.66 848.80N 6806.89W 2.00 6859.60 453911.34 5912803]14 9100.00 31.44 276.64 4728.05 855.00N 6860.17W 2.00 6913.24 453858.10 5912809.62 9200.00 29.44 276.64 4814.26 860.87N 6910.49W 2.00 6963.90 453807.81 5912815.74 9300.00 27.44 276.64 4902.18 866.38N 6957.79W 2.00 7011.53 453760.54 5912821.49 9400.00 25.44 276.64 4991.72 871.53N 7002.02W 2.00 7056.05 453716.34 5912826.86 9422.08 25.00 276.64 5011.69 872.62N 7011.37W 2.00 7065.46 453707.00 5912828.00 9422.09 25.00 276.64 5011.70 872.62N 7011.37W 2.00 7065.46 453707.00 5912828.00 9500.00 25.00 276.64 5082.31 876.43N 7044.08W 0.00 7098.39 453674.32 5912831.98 9630.32 25.00 276.'64 5200.42 882.80N 7098.78W 0.00 7153.46 453619.65 5912838.63 9830.32 25.00 276.64 5381.68 892.58N 7182.74W 0.00 7237.99 453535.75 5912848.83 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #329 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7237.99 on azimuth 277.08 degrees from wellhead. Total Dogleg for wellpath is 121.41 degrees. Vertical section is from wellhead on azimuth 277.09 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 329 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 329 Version #3 Last revised : 27-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 450.00 450.00 0.00N 0.00E KOP 1016.67 1008.39 21.60N 80.61W Begin Turn to Target 2893.61 2282.88 212.09N 1340.66W EOC 3640.63 2500.00 294.79N 2050.63W 9 5/8" Casing Pt 7016.91 3481.29 668.55N 5259.47W Begin Angle Drop 9422.08 5011.69 872.62N 7011.37W TARGET 9422.09 5011.70 872.62N 7011.37W 331 Rvsd 20-Mar-98 9830.32 5381.68 892.58N 7182.74W TD / 7" Casing Pt Casing positions in string 'A' .... ===================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3640.63 2500.00 294.79N 2050.63W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9830.32 5381.68 892.58N 7182.74W 7" Casing Targets associated with this wellpath ======m Target ns.me Geographic Location T.V.D. Rectangular Coordinates Revised 331 Rvsd 20-Mar-98 453707.000,5912828.000,0.0000 5011.70 872.62N 7011.37W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N 329 slot #329 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 329 Version #3 Our ref ~ prop2853 License : Date printed : 27-Mar-98 Date created : 27-Feb-98 Last revised : 2?-Mar-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n?0 10 13.090,w150 18 58.260 Slot Grid coordinates are N 5911919.899, E 460713.162 Slot local coordinates are 87.90 S 879.80 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 301 Version #1 ,301 302 Version #1,.302 303 Version #2, 303 304 Version #1,304 305 Version #2,305 306 Version #1,306 307 Version #1, 307 308 Version #1, 308 309 Version #1 ,309 310 Version #1, 310 311 Version #1 ,311 313 Version #1, 314 Version #1 315 Version #1, 317 Version #1 319 Version #1, 320 Version #1 .Tarn Drill .Tarn Drill Tarn Drill .Tarn Drill .Tarn Drill .Tarn Drill Tarn Drill Tarn Drill Tarn Drill Tarn Drill Tarn Drill 313,Tarn Drill ,314,Tarn Drill 315,Tarn Drill ,317,Tarn Drill 319,Tarn Drill ,320,Tarn Drill Closest approach with 3-D Last revised Distance M.D. Diverging from M.D. Site 2N 8-Mar-98 420.0 300.0 300.0 Site 2N 8-Mar-98 405.0 400.0 400.0 Site 2N 8-Mar-98 390.0 400.0 400.0 Site 2N 8-Mar-98 375.0 450.0 450.0 Site 2N 8-Mar-98 360.0 450.0 450.0 Site 2N 8-Mar-98 345.0 450.0 450.0 Site 2N 8-Mar-98 330.0 450.0 450.0 Site 2N 8-Mar-98 315.0 450.0 450.0 Site 2N 8-Mar-98 300.0 300.0 300.0 Site 2N 8-Mar-98 284.9 450.0 450.0 Site 2N 8-Mar-98 269.3 475.0 475.0 Site 2N 8-Mar-98 238.8 500.0 500.0 Site 2N 8-Mar-98 223.2 525.0 525.0 Site 2N 8-Mar-98 210.0 450.0 450.0 Site 2N 8-Mar-98 180.0 450.0 450.0 Site 2N 8-Mar-98 150.0 450.0 450.0 Site 2N 8-Mar-98 130.3 625.0 625.0 2N 20-Mar-98 115.5 625.0 625.0 24-Mar-98 30.5 200.0 200.0 8-Mar-98 60.3 300.0 300.0 8-Mar-98 75.2 300.0 300.0 8-Mar-98 90.2 300.0 300.0 20-Mar-98 120.2 300.0 300.0 22-Mar-98 150.1 300.0 300.0 24-Mar-98 180.1 300.0 300.0 321 Version #2, 321,Tarn Drill Site 331 Temp,,331,Tarn Drill Site 2N 333 Version #1,,333,Tarn Drill Site 2N 334 Version #l,,334,Tarn Drill Site 2N 335 Version #1,,335,Tarn Drill Site 2N 337 Version #2,,337,Tarn Drill Site 2N 339 Version #2,,339,Tarn Drill Site 2N 341 Version #2,,341,Tarn Drill Site 2N Minimum Distance method 345 Version #2,,345,Tarn Drl Site 2N 347 Uersio~ #l,,347,Tarn Dri~ Site 2N 350 Vets. #l,,350,Taz-n Drill Site 2~ 343 Versio~ #2,,343,Tarn Drill Sitm 2N 330 TemD,,330,Tarn Drill Site 2N 327 Version #2,,327,Tarn Drill Site 2N 326 Version #2,,326,Tarn Drill Site 2N 325 Versio~ #2,,325,Tarn Drill Site 2N 323 Versio~ #2,,323,Tarn Drill Site 2N 24~Mar-98 240.1 300.0 1425.0 8~Mar-98 270.1 300.0 ..... 2025.0 8~Mar-98 236.6 1950.0 1950.0 2~~Mar-98 210.1 200.0 1250.0 27-Mar-98 15.9 300.0 300.0 27~Mar-98 30.4 475.0 475.0 27-Mar~98 38.9 650.0 650.0 27~Mar~g8 55.3 625.0 625.0 27-Mar~98 90.1 400.0 400.0 Alaska Oil & Gas Ochres. ~;ommlssion Anchorage ARCO Alaska, Inc Post Office'u-~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 31, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill KRU 2N-329 Dear Commissioner Johnston, ~ /.~ ARCO Alaska, Inc. hereby files this Applicatio~rmit to Drill its first onshore development well in the Tam area, KRU 2,~343,~cated approximately seven miles southwest of the Kuparuk River Unit's-21V[ Drillsite. This well will be accessed via a new gravel road originating at 2M Pad. It will be drilled and evaluated using Doyon Rig 141. If the well is commercial, it will completed with Doyon 141 also. This is the first of approximately 20 wells to be drilled to Tam objectives during 1998. Attached find the information required by 20 AAC 25.005(c) and 20 AAC 25.061. All waste drilling mud and cuttings generated during the drilling of this well will be hauled to either the Kupamk River Field or Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation which is similar in depth to the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. ARCO also requests an exception to the shale density requirement in 20 AAC 25.033(e, 2, D). The shale density technique does not work well in Alaska due to the variable composition of the shales and the chemical used in the shale density column is listed as an exceptional health hazard. RECEIVED Anch0rag0 ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6O03-C The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 3) Geologic Data and Logs (20 AAC 25.071) Doug Hastings, Geologist 265-6967 If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Mike~pg~it -- Drilling/.gd'perintendent Kuparuk Drillsite Development Attachments CC: KRU 2N-343 Well File Ryan Stramp ATO-1246 Lamont Frazer ATO- 1244 R 'CEIVED Alaska 0il & Gas Cor~s C0ml~lS,qt0rJ Anchorage WELL PERMIT CHECKLIST COMPANY · ADM I N I ST R A .T..!._O..N_ APPR [)Al I'~,rrllit lee attached 2 I ease ~unlber appropriate. 3 Unique well name and numbe~.. 4 Well located in a defined pool ......... 5 Well located proper dislance from drilling unil boundary. 6 Well located proper distance from other wells . . 7 Sufficient acreage available in drilling unit 8 If deviated, is wellbore plat included 90peralor only aflecled pady. 10 Operalor t~as approprlale bond ir/force. 11 Pem~il can be issued wilhoul conservalion order' 12 ['ermil can be issued wilhoul administrative apploval I:~, (:;~lm, lnHl be approved before 15-daywait ENGINEERING GEOLOGY WELL NAME,,'~ "~.~--,~2-'¢~' PROGRAM: exp [] dev~,redrll Fl serv [] wellbore segl ann disposal para rrq GEOL AREA ~"z:h ~2 UNIT# ,///_f~., ____ ON/OFF SHORE .... ~,~.. · 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 conduclol st~mg provided .... ' ~.~N ...................................................................................................................................... Surface casing prolects all known USDWs .... (.~ N CklT vol adequale to circulate on conductor & surf csg. . ... ~N ...................... CMl vol adequate to tie-in long string lo sud csg ..... ~ CM'I will cover' all known produclive horizons ..... Cas/hq designs adequaie for C, ~. B & permafrost . N Adeqt~ale tankage or rese~e pit ............. Il a re.dlill, has a 10-403 for abandonrnenl been approved. ~ N ~ ' N Adeqtiale wellbore sepmalion proposed ..... ~ N ..~~ If diverler required, does it meet regulations I N I)~ilhr~ct fh~i(t p~oqrarn ~;chemalic & e/t~ip h.,l adeq~ale ~N~ BO[.)E pless rating appropriate', led lo ~~ ....... psig ~N . Choke manifold complies w/APl RP-53 (May 84) ..... (~ N Work will occur withoLlt operation shutdown ..... ~ /,~ ~ Is p~ese~ce of tI,S gas probable.. . 30 F'ern,t can be issued w/o hydrogen sulfide measures 31 Data p~esenled on polenlial overplessule zones 32 Se~srmc analysis of shallow gas zones. 33 Seabed condition survey (if off..shore) ..... :14 (':ord;']cl ~]~]r]le/phc)f]e for weekly progress reports [exploratory only] RFC 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 Tue Jun 30 08:58:19 1998 Reel Header Service name ............. LISTPE Date ..................... 98/06/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Tape Header Service name ............. LISTPE Date ..................... 98/06/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical 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 TARN POOL MWD RUN 1 AK-MM-80209 R. KRELL R. SPRINGER FROM MSL 0) 2N-329 501032025700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 30-JUN-98 MWD RUN 2 AK-MM-80209 M. GABEL B. MORRISON 3 9N 7E 89 88O KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 148.80 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625~ 3283.0 8.500 9690.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH SHIFTING OF THE MWD DATA IS WAIVED AS PER THE CONVERSATION BETWEEN DOUG HASTINGS AND A. TURKER ON 05/07/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. NEUTRON DATA IS NOT PROVIDED FOR RUN 1 DUE TO LARGE STAND OFF. 6. GAMMA RAY LOGGED THROUGH CASING FROM 3257'MD, 2283'TVD TO 3283'MD, 2295'TVD. 7. RESISTIVITY LOGGED BEHIND CASING FROM 3228'MD, 2270'TVD TO 3283'MD, 2295'TVD. 8. MWD RUNS 1 AND 2 REPRESENT WELL 2N-329 WITH AN API# 50-103-20257-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9690'MD, 5452'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. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE-SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTOR' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY (BEST BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). COMPENSATED NEUTRON POROSITY PROCESSING PARAMETERS: FIXED HOLE SIZE: 8.5" MUD WEIGHT: 9:00 TO 9.80 PPG. MUD SALINITY: 700 CL PPM. FORMATION WATER SALINITY: 19,149 CL PPM. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX DRHO RHOB GR FET ROP PEF FCNT NCNT NPHI $ START DEPTH 70.0 70.O 70 0 70 0 70 5 70 5 73 5 102 5 104.5 130.0 3203.0 3203.0 3203.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ STOP DEPTH 9622.5 9622.5 9622.5 9622.5 9639.0 9639.0 9650.0 9622.5 9690.5 9639.0 9630.0 9630.0 9630.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 108.0 3290.0 2 3290.0 9690.0 REMARKS: MERGED ~IN 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 API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHM~ 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 SNP2 MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 70 9690.5 GR 9.8218 248.874 RPX 1.0669 2000 RPS 0.776 2000 RPM 0.3121 2000 RPD 0.2451 2000 ROP 8.6786 3711.13 FET 0.3751 62.1264 NCNT 2176 3784 FCNT 402 1025 RHOB 0.7317 3.7572 DRHO -1.439 1.1815 SNP2 1.1711 18.0039 NPHI 14.8986 99.8056 Mean Nsam 4880.25 19242 104.988 19154 13.3021 19106 14.3703 19106 26.778 19106 37.1585 19106 215.442 19173 1.23213 19041 2700.57 12855 588.222 12855 2.24498 19053 0.0553503 19053 3.43028 19019 37.9228 12855 First Reading 70 73.5 70 7O 70 70 104.5 102.5 3203 3203 70.5 70.5 130 3203 Last Reading 9690.5 9650 9622.5 9622.5 9622.5 9622.5 9690.5 9622.5 9630 9630 9639 9639 9639 9630 First Reading For Entire File .......... 70 Last Reading For Entire File ........... 9690.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ...... '.98/06/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 70.0 3227.5 RPM 70.0 3227.5 RPS 70.0 3227.5 RPX 70.0 3227.5 PEF 70.5 3244.5 RHOB 70.5 3244.5 GR 73.5 3256.5 FET 102.5 3227.5 ROP 104.5 3289.0 DRHO 130.0 3244.5 $ LOG HEADER DATA DATE LOGGED: 28-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 3290.0 TOP LOG INTERVAL (FT) : 108.0 BOTTOM LOG INTERVAL (FT): 3290.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM 7kNGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS) 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 65.9 TOOL NUMBER P1005CRNLG8 P1005CRNLG8 P1005CRNLG8 P1005CRNLG8 12.250 12.3 SPUD 10.30 65.0 9.0 800 4.8 4.500 4.085 4.600 5.000 28.4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 RHOB MWD 1 G/CC 4 1 68 DRHO MWD 1 G/CC 4 1 68 SNP2 MWD 1 BARN 4 1 68 20 24 28 32 36 4O 6 7 8 9 10 11 Name Min Max Mean DEPT 70 3289 1679.5 GR 9.8218 142.786 73.5992 RPX 1.4222 2000 30.2615 RPS 0.776 2000 32.8062 RPM 0.3121 2000 68.5281 RPD 0.3756 2000 75.4625 ROP 8.6786 3711.13 137.833 FET 0.4406 3.6161 0.910071 RHOB 0.7317 3.7572 2.08361 DRHO -1.439 1.1815 0.076372 SNP2 1.1711 18.0039 5.40461 Nsam 6439 6367 6316 6316 6316 6316· 6370 6251 6349 6349 6230 First Reading 70 73.5 7O 70 70 70 104.5 102.5 70.5 70.5 130 Last Reading 3289 3256.5 3227.5 3227.5 3227.5 3227.5 3289 3227.5 3244.5 3244.5 3244.5 First Reading For Entire File .......... 70 Last Reading For Entire File ........... 3289 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS FET RPX FCNT NCNT NPHI GR PEF ROP DRHO RHOB $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3193.0 3193.0 3193.0 3194 0 3194 0 3203 0 3203 0 3203 0 3222 0 3237 0 3262.0 3287.5 3287.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9622.5 9622.5 9622.5 9622.5 9622.5 9630.0 9630.0 9630.0 9650.0 9639.0 9690.5 9639.0 9639.0 · TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MIJD 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: 03-MAY-98 5.07 5.46 MEMORY 9690.0 3290.0 9690.0 44.4 6703.0 TOOL NUMBER P0983CRNLG6 P0983CRNLG6 P0983CRNLG6 P0983CRNLG6 8.500 8.5 lsnd 9.20 42.0 9.0 700 6.8 2.800 1.927 2.500 53.3 MUD CAKE AT MT: 3.100 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 NPHI MWD 2 P.U. 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMS4 4 1 68 24 7 ROP MWD 2 FT/H 4 1 68 28 8 FET MWD 2 HOUR 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 SNP2 MWD 2 BARN 4 1 68 52 14 Name DEPT NPHI GR RPX RPS RPM RPD ROP FET FCNT NCNT Min 3193 14.8986 44 6306 1 0669 0 9347 1 1074 0 2451 11 7967 0 3751 402 2176 First Max Mean Nsam Reading 9690.5 6441.75 12996 3193 99.8056 37.9228 12855 3203 248.874 120.276 12857 3222 58.7583 4.91368 12858 3194 65.2756 5.25691 12860 3193 2000 6.15644 12860 3193 2000 23.9375 12860 3193 2114.65 253.721 12858 3262 62.1264 1.70335 12858 3194 1025 588.222 12855 3203 3784 2700.57 12855 3203 Last Reading 9690.5 9630 9650 9622.5 9622.5 9622.5 9622.5 9690.5 9622.5 9630 9630 RHOB 1.9177 2.6874 2.32563 12704 DRHO -0.108 0.3079 0.0448444 12704 SNP2 1.3386 15.2756 2.47749 12805 3287.5 9639 3287.5 9639 3237 9639 First Reading For Entire File .......... 3193 Last Reading For Entire File ........... 9690.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/06/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/06/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File