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Home My WebLink About193-201Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 9/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 8/18/2024 YELLOWJACKET PERF BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 9/9/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 8/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 9/14/2024 AK E-LINE CBL END 1-61 50029225200000 194142 9/11/2024 READ CaliperSurvey KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF MPU B-24 50029226420000 196009 9/9/2024 READ CaliperSurvey MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey MPU R-103 50029237990000 224114 9/16/2024 AK E-LINE TubingCut MPU R-103 50029237990000 224114 9/19/2024 AK E-LINE TubingCut MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug NCIU A-19 50883201940000 224026 9/20/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/13/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/15/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/18/2024 AK E-LINE CBL NCIU A-20 50883201960000 224065 9/11/2024 AK E-LINE PPROF NCIU A-20 50883201960000 224065 8/26/2024 READ MemoryRadialCementBondLog PBU 09-27A 50029212910100 215206 9/13/2024 AK E-LINE CBL/TubingPunch PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL PBU 13-24B 50029207390200 224087 8/21/2024 YELLOWJACKET CBL-PERF PBU 13-24B 50029207390200 224087 8/23/2024 YELLOWJACKET CBL PBU 13-26 50029207460000 182074 8/13/2024 YELLOWJACKET CCL PBU NK-26A 50029224400100 218009 7/20/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T39593 T39594 T39595 T39596 T39597 T39598 T39599 T39600 T39601 T39602 T39603 T39603 T39604 T39605 T39605 T39605 T39605 T39606 T39606 T39607 T39608 T39609 T39609 T39610 T39611 PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.27 14:47:28 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-34A Squeeze Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-201 50-029-21329-01-00 12630 Conductor Surface Intermediate Production Liner 8979 80 2484 9172 2009 1856 10955 20" 13-3/8" 9-5/8" 7-5/8" 5-1/2" 8778 30 - 110 28 - 2512 26 - 9198 8947 - 10956 10769 - 12625 30 - 110 28 - 2510 26 - 7227 7070 - 8779 8645 - 8979 unknown (2) 470 2670 1760 4790 6280 none 1490 5380 6870 6890 7740 11065 - 12565 4-1/2" 12.6# 13Cr80 25 - 10774 8849 - 8972 Structural 4-1/2" Baker SABL-3 , 10716 , 8604 No SSSV 10716 8604 Bo York Operations Manager Dave Wages David.Wages@hilcorp.com (907) 564-4545 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028324 25 - 8648 10799 - 10870 Squeeze Perforations with ~30 bbls of 15.8 ppg class G cement to 2000 psi 57 76 6865 21382 10172 40150 1819 1398 385 285 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:47 pm, Sep 05, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.05 13:07:34 - 08'00' Bo York (1248) DSR-9/11/24 RBDMS JSB 091124 WCB 10-3-2024 ACTIVITYDATE SUMMARY 12/25/2023 LRS 72 Assist Slickline (PROFILE MODIFICATION). Freeze protect the F/L with 5 bbls of 60/40 MeOH and 64 bbls of crude. Close the IGV and pressure up to 1500 psi. 12/25/2023 ***ARRIVE ON LOCATION- WELL FLOWING *** DRIFT TO DEVIATION W/ 10' X 3.66"(145") DUMMY GUNS, 1 3/4" SAMPLE BAILER, SAT DOWN @11093' SLM, NO SAMPLE RIH W/ 2' X 1 7/8" STEM, 3.80" CENT, TAGGED X-NIPPLE @ 9157' SLM (9188' MD') CORRECTION +31' RIH W/ 8' X 2 1/2" DRIVE DOWN BAILER (msfb), SET DOWN AT 11,132' SLM WORKED BAILER IN AREA, TAPPED DOWN @ 11,183' SLM (11,214' MD) NO FURTHER DEPTH GAIN ***DEPART LOCATION WELL SHUT IN*** HAND AND FINGER SAFETY DRILL W/ WELLSITE LEADER (GALLOWAY) 12/31/2023 *** WELL FLOWING ON ARRIVAL *** INITIAL T/I/O = 450/1700/0 LOG PPROF PER PROGRAM, NO ISSUES GETTING IN HOLE. SEE PPROF TAB FOR SPLITS. FINAL T/I/O = 450/1700/0 *** WELL FLOWING ON DEPARTURE, DSO NOTIFIED *** 1/1/2024 T/I/O= 800/1550/0. LRS 70 Freeze Protection (PROFILE MODIFICATION). Pumped 38 bbls of crude into the TBG. Pumped 5 bbls of 60/40 MeOH and 60 bbls of crude into the F/L. Final T/I/O= 327/1500/0. 2/29/2024 T/I/O= 2500/1550/0 TFS Unit 4 Pumped 3 BBLS of 60/40 and 197 BBLS of Crude to Load the TBG to the Perfs. E-Line will move in and take control of well upon departure. FWHP = 390/1550/0 3/21/2024 ***WELL S/I ON ARRIVAL*** (SET 3'' OD BAKER IBP IN 5.5'' 17# LINER) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RIH W/CH/1.69'' CCL/BAKER IBP SETTING TOOL AND 3'' IBP TO SET PLUG ME AT 11000' MD (TOP OF PLUG 10991') CCL TO MID ELEMENT 26.26' ,CCL STOP DEPTH 10973.74' MD OAL LIH = 13.4' CCL CORRELATE TO SLB PERFORATION RECORD DATED 31-OCTOBER-2016 TAKE 78 MINUTES TO SET BAKER IBP ***WELL S/I ON DEPARTURE*** 3/21/2024 T/I/O 2502/1466/0 Temp Si Load tubing (Profile modification) SSV frozen Thaw backside of valve and function test SSV. Load tubing with 5 bbls of 60/40 and 275 bbls of crude for E-line. Final WHPS = 160/1504/0 3/28/2024 *** WELL SHUT IN ON ARRIVAL ***(dump bail 20' sand/sluggits) RAN 3.78" GAUGE RING TO XN-NIP @ 10.726' SLM / 10,760 MD (-34' correction) MAKE 4 RUNS W/ 10' x 3.0" DUMP BAILER, 1.75" K-JAR, 2.95" CENT/3.25"CENT, DUMP BAIL FROM 10,992' MD TO 10,982' MD (gently s/d on ibp @ 10,992' md) ***CONT WSR ON 3/29/24*** Daily Report of Well Operations PBU 09-34A RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RIH W/CH/1.69'' CCL/BAKER IBP SETTING TOOL AND 3'' IBP TO SET PLUG ME AT 11000' MD (TOP OF PLUG 10991') CCL TO MID ELEMENT 26.26' ,CCL STOP ( DEPTH 10973.74' MD Daily Report of Well Operations PBU 09-34A 3/29/2024 ***CONT WSR FROM 3/28/24***(dump bail 20' sand/sluggits) MAKE 4 RUNS W/ 10' x 3.0" DUMP BAILER, 1.75"K-JAR, 2.95"/3.25"CENT, DUMP BAIL RIVER SAND FROM 10,948 SLM TO 10,931'SLM - (10,982-10,965 MD) MAKE 2 RUNS W/ 10' x 3.0" DUMP BAILER, 1.75"K-JAR, 2.95"/3.25"CENT, DUMP BAIL SLUGGETS 10,931 -10,925' SLM - (10,965-10,959' MD) RAN 3.65" BLIND BOX, TAG TOP OF SLUGGETS @ 10,925' SLM /10,959' MD ***WELL SHUT IN ON DEPARTURE *** ***DRILL - DISCUSSION ABOUT LOST TOOLS WHILE POOH, STUFFING BOX LEAKING / PACK-OFF STUFFING BOX / STILL LEAKING SHUT WLVS STILL LEAKING CLOSE SWAB VALVE TO GAIN WELL CONTROL*** 4/21/2024 T/I/O = SSV/1670/0. Temp = SI. Bleed IAP to CLP (pre coil tubing). AL SI @ CV = 1950 psi. IA FL @ 7791' (Sta# 2 SO, 417 bbls). Bled IAP to production (09-49) to 420 psi in 4 hrs. IA FL unchanged. Monitor for 30 min, IAP unchanged , IA FL unchanged. FWHP's = SSV/420/0 SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:00. 4/23/2024 T/I/O=1600/450/0 Temp=S/I (Injectivity test) Load TBG max PSI 2500, Pumped 3 bbls 60/40 spear followed by 170 bbls diesel down the TBG. For test reduce rate to 1 BPM for 10 bbls, Increase rate to 2 BPM for 15 bbls, for a total of 195 bbls of DSL pumped down the TBG. Injectivity test 1BPM @ 250 PSI, 2BPM @ 300 PSI. PO notified of well status upon departure. FWHPS=100/450/0 4/26/2024 LRS #2 2" 0.156WT Objective: Sqz perfs, fish IBP. Waiting on snow removal. SLB cementers delayed on another job. Complete weekly BOPE testing to 250 psi low / 4250 psi high. Decision from town to postpone job and head to E-101. Lay mast down and travel to LRS yard. ***Continued on Weather Standby WSR*** 7/26/2024 LRS CTU #1 1.75" .156 Blue Coil Job Scope: Cement/Pull IBP Travel to DS9. Stand by for Well support to finish rigging up **Continued to WSR on 7/27/24** 7/26/2024 T/I/O=1722/575/0 TFS Unit 1 Assist Coil (IA LOAD) Pumped 3 BBLS of 50/50 and 450 BBLS of Crude to Load the IA for Coil Tubing. After pumping 311 BBLS Crude Reduced Rate to 1.5 BPM to pump through the SO. Coil Tubing on location upon departure. FWHP= 1850/600/0 7/27/2024 LRS CTU #1 1.75" .156 Blue Coil Job Scope: Cement/Pull IBP Well support finishing R/U. MIRU CTU. PT Lub and wing valve 300/4200. RIH w/ 2" CTC, (2) 4' stingers, and 2" Ball drop nozzle OAL 8.75'. Tag @ 10976' CTM. RU SLB Cementers. Start to bullhead well w/ diesel. Noted IA tracking Tbg. Discuss w/ OE. Will postpone sqz until DGLVs installed. POH and RD. **Job Postponed** Daily Report of Well Operations PBU 09-34A 7/28/2024 ***WELL S/I ON ARRIVAL*** SET 4-1/2" X-CATCHER @ 9,188' MD PULLED RK-OGLV FROM ST #2 @ 7,791' MD PULLED RK-LGLV'S FROM ST #3 @ 6,213' MD & ST #4 @ 3,460' MD SET RK-DGLV'S IN ST #4 @ 3,460' MD, ST #3 @ 6,213' MD & ST #2 @ 7,791' MD PRESSURED IA UP TO 2,750 PSI, VALVES ARE IN THEIR POCKETS PULLED 4-1/2" X-CATCHER FROM 9,188' MD ***WELL LEFT S/I ON DEPARTURE*** 7/28/2024 LRS CTU #1 1.75" .156 Blue Coil Job Scope: Cement/Pull IBP Travel to DS9. MIRU **Continued to WSR on 7/29/24** 7/29/2024 LRS CTU #1 1.75" .156 Blue Coil Job Scope: Cement/Pull IBP Continue R/U CTU. M/U cementing BHA w/2.5" BDJSN. RIH. Tag sand at 10973. Flag pipe. Call out SLB cementers. PUH to EOT and displace to 1.2X well bore volumes w/ diesel. 4 bpm @ 850 psi. SD pump. SITP 315 psi. CT Lead hand became ill. Stby for relief Lead Hand. POH and perform BOP (done) and slip test. M/U cementing BHA w/2.5" JSN. RIH. Tag sand at 10973. Paint flag. pick up 10'. **Continued to WSR on 7/30/24** 7/30/2024 LRS CTU #1 1.75" .156 Blue Coil Job Scope: Cement/Pull IBP Batch up cement. Lay in cement from 10956 to 9737'. Pump 8 bbls 15.8 ppg class G cement into perforations and start hesitations. Started building squeeze pressure at 14 bbls pushed away but unable to get full squeeze with remaining cement. Achieved 1450 psi Squeeze then broke back with no cement left. Push cement away into preforations. RIH contaminating @ 2:1 and pushing into formation. WHP in creased to 1850 @ 1.5 bpm. Take returns @ 1:1. Drop WHP to 400 psi and make 2 jetting passes across perfs @ 2.5 bpm. Hard tag @ 10960' (5' above flag) unable to jet past. POH @ 50% in liner and 70 in tbg. Jet 2 passes across all GLMs. Order out 15 bbls pumpable for round 2. Injectivity >530 psi @ .5 bpm with full column 1% KCL. **Continued to WSR on 7/31/24** 7/31/2024 LRS CTU #1 1.75" .156 Blue Coil Job Scope: Cement/Pull IBP Wait on lab tests for cement. RIH, tag sand top at 10975' CTMD. Lay in 16 bbls 15.8ppg class G cement. Down squeeze 9.6bbls. Hold 2000psi for 20 min with 60 psi total loss. (40psi in 10min and 20psi next 10). RIH contam remaining cement down to tag at 10966' CTMD, chase out of hole jetting all GLM's on the way out. Jet BOP stack and wait on cement to build compressive strength. ...Continued on WSR 8-1-24... Batch up cement. Lay in cement from 10956 to 9737'. Pump 8 bbls 15.8 ppg class Gyg cement into perforations and start hesitations. Started building squeeze pressure atg 14 bbls pushed away but unable to get full squeeze with remaining cement. Achieved yg g 1450 psi Squeeze then broke back with no cement left. Push cement away into preforations R/U CTU. M/U cementing BHA Daily Report of Well Operations PBU 09-34A 8/1/2024 LRS CTU #1 - 1.75" Coil ***Continued from WSR 7-31-24*** Job Objective: Cement Squeeze, Pull IBP Wait on cement to reach compressive strength. Make up milling BHA with 3.68" junk mill, RIH. Tag top of sand/cement cap at 10967' CTMD and mill 4-5' crust before cleaning out to a tag at 10991' CTMD. Pump gel sweep and chase OOH. Make up slim DJN BHA and RIH. Tag at 10995' CTMD. Jet down but make no further depth. POOH. Trim 100' of coil. Make up IBP retrieval BHA with 3.50" hydraulic JDC overshot. RIH. Latch IBP at 10994' CTMD (10991 MD) and release. Able to RIH though without equalizing IBP there is marginal fluid bypass. Let element relax. ...Continued on WSR 8-2-24.... 8/2/2024 LRS CTU #1 - 1.75" Coil ***Continued from WSR 8-1-24*** Job Objective:Cement Squeeze, Pull IBP Drift downhole with IBP to 11132' CTMD. Begin POOH with multiple overpulls and swabbing fluid in the tubing. FP well with 38 bbls of diesel. IBP retrieved, though all 3 elements left in hole. Rig down CTU. ...Job in Progress... 8/3/2024 ***WELL SHUT IN ON ARRIVAL*** (ADPERF) RIG UP AKEL PCE FUNCTION TEST WLV'S PT 250L 3000H RIH WITH 20' DUMMY GUN 3.16'' AND DRIFT FREELY TO 11150' PERFORATE (11081-11093) 3 1/8" 6 SPF 60 DEGREE PHASE GEO RAZOR CHARGES CCL STOP DEPTH=11063.7' (CCL-TS=17.3') CORRELATED TO SLB CBL DATED 06-OCT-16 JOB COMPLETE TURN OVER TO OPS. RDMO AKEL ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE TURN OVER TO OPS. 8/7/2024 ***WELL S/I UPON ARRIVAL*** (gaslift) ATTEMPT TO SET 4 1/2" X-CATCHER, SD HIGH IN TUBING @ 7,416' SLM (sticky, possible element from ibp) ***CONT WSR ON 8/8/24*** 8/8/2024 ***CONT WSR FROM 8/7/24*** (gaslift) RAN 4 1/2" BRUSH, 3.50" WIRE GRAB TO 9,270' SLM (recovered 1 element from ibp) SET 4 1/2" X-CATCHER IN X-NIPPLE @ 9,172' SLM / 9,188' MD PULLED RK-DGLV'S FROM STA #3 @ 6,213' MD & ST#4 @ 3,460' MD. SET RK-LGLV IN ST#4 @ 3,460' MD. SET RK-OGLV IN ST#3 @ 6,213' MD. PULLED 4-1/2" X-CATCHER FROM X-NIPPLE @ 9,188' MD.(empty) RAN 4-1/2" BRUSH & 3.50" WIRE GRAB TO 10,900' SLM.(no issues, no recovery) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** j Drift downhole with IBP to 11132' CTMD.Begin POOH with multiple overpulls andg swabbing fluid in the tubing. FP well with 38 bbls of diesel. IBP retrieved, though all 3gg elements left in hole. Rig down CTU PERFORATE (11081-11093) IBP was set, squeeze was performed, IBP was retrieved, and the adperfs were shot. Squeezed perfs and the adperfs are correctly shown on the WBS, below. -WCB Make upggg slim DJN BHA and RIH. Tag at 10995' CTMD. Jet down but make no further depth. g POOH. Trim 100' of coil. Make up IBP retrieval BHA with 3.50" hydraulic JDCy overshot. RIH. Latch IBP at 10994' CTMD (10991 MD) and release. Able to RIH() though without equalizing IBP there is marginal fluid bypass. 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ϭ͘ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘WĂƚĐŚŝĂŐƌĂŵ ϰ͘tŝƌĞůŝŶĞsĂůǀĞƐ^ĐŚĞŵĂƚŝĐ ϱ͘DŝŶŝ>ŽŐ >ŝŶĞƌWĂƚĐŚĨŽƌ'ĂƐ^ŚƵƚŽĨĨ ϬϵͲϯϰ Wd͗ϭϵϯϮϬϭ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ >ŝŶĞƌWĂƚĐŚĨŽƌ'ĂƐ^ŚƵƚŽĨĨ ϬϵͲϯϰ Wd͗ϭϵϯϮϬϭ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ >ŝŶĞƌWĂƚĐŚĨŽƌ'ĂƐ^ŚƵƚŽĨĨ ϬϵͲϯϰ Wd͗ϭϵϯϮϬϭ WĂƚĐŚŝĂŐƌĂŵ >ŝŶĞƌWĂƚĐŚĨŽƌ'ĂƐ^ŚƵƚŽĨĨ ϬϵͲϯϰ Wd͗ϭϵϯϮϬϭ >ŝŶĞƌWĂƚĐŚĨŽƌ'ĂƐ^ŚƵƚŽĨĨ ϬϵͲϯϰ Wd͗ϭϵϯϮϬϭ tŝƌĞůŝŶĞsĂůǀĞƐƵƌŝŶŐĂŶĚĨƚĞƌWĂƚĐŚĞƉůŽǇŵĞŶƚͲĞƉůŽǇŝŶŐƚŚĞƉĂƚĐŚŽƉĞŶͲŚŽůĞƐŚŽƵůĚƚĂŬĞŶŽŵŽƌĞƚŚĂŶ ϭϬŵŝŶƵƚĞƐ͘/ĨĂƚĂŶǇƉŽŝŶƚƚŚĞƉĂƚĐŚƐŝƚƐĚŽǁŶĚƵƌŝŶŐĚĞƉůŽǇŵĞŶƚĂŶĚĐĂŶŶŽƚďĞĚĞƉůŽǇĞĚǁŝƚŚĞĂƐĞ͕WKK, ǁŝƚŚƚŚĞĐƌĂŶĞĂŶĚ^/ƚŚĞǁĞůů͘EŽƚŝĨǇKƉƌŝŽƌƚŽŵŽǀŝŶŐĨŽƌǁĂƌĚ͘ >ŝŶĞƌWĂƚĐŚĨŽƌ'ĂƐ^ŚƵƚŽĨĨ ϬϵͲϯϰ Wd͗ϭϵϯϮϬϭ ϬϵͲϯϰDŝŶŝ>ŽŐ • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,June 17, 2018 6:01 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS2 Drillsites; Nottingham, Derek; Ohms, Danielle H; Richards, Meredyth; Stechauner, Bernhard; Summers, Matthew Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: UNDER EVALUATION: Producer 09-34A(PTD#1932010) sustained IA pressure above NOL Attachments: 09-34A.pdf All, Producer 09-34A(PTD#1932010)was reported to have inner annulus casing pressure above NOL on 06/14/18.The pressure was 2,002 psi. Efforts to deliver a tank and bleed the IA to perform a TIFL have been hindered by the road repair to DS 9.The well is now classified as Under Evaluation and is on the 28 day clock for diagnostics. Plan forward: 1. DHD:TIFL 2. Slickline (pending):GLV change out 3. DHD(pending):TIFL Please respond with any questions. Andrew Ogg Well Integrity Engineer SCANNED JUN 2 0 [u ii BP Global Wells Organization-Alaska Office:907-659-8110 1 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 193-201 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21329-01-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number: PBU 09-34A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: ril Total Depth: measured 12630 feet Plugs measured feet true vertical 8979 feet Junk measured feet 0 1 2016 Effective Depth: measured 12588 feet Packer measured See Attachment feet DECL.t A true vertical 8975 feet Packer true vertical See Attachment feet AOGOC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED ,1 A- 3 237 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 171 3408 5876 1862 273 Subsequent to operation: - 207 3352 6449 1830 281 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .11:SC(.12 .---...----- . Phone +1 907 564 4424 Date 12/1/16 Form 10-404 Revised 5/2015 27/ RBDMS 1,Y DEC - 6 2016 Submit Original Only Z7167;1 • • Packers and SSV's Attachment PBU 09-34A SW Name Type MD TVD Depscription 09-34A PACKER 2146.45 2146.28 9-5/8" BOT External CSG PKR 09-34A PACKER 8947.45 7069.78 7" Baker Packer 09-34A TBG PACKER 9213.66 7237.13 4-1/2" Baker Premier Packer 09-34A TBG PACKER 10711.16 8600.04 4-1/2" Baker SABL-3 Packer 09-34A PACKER 10776.74 8650.35 7" Baker Type H Liner Top Packer • ! 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OQ 0 * * Hq. .= N 3 * U) a0 IL * * � * CD CO CD CO 0 0 0 0 N N N N r r M M r• r 0 0 r r r r r . • 0 0 = E / § E \ \ k ƒ / E ] § lif C y f ® % _ En s e C t 5 % > \ . / R E \ = c ' n = o 222 / io \ $ \ ƒ 0 0 \ 7 / / _ ce ± /_c $ / % 5 / I \ = - — i0 - / &�\ � # Ifs $ e ' / 6 /ƒ .2 / H / / t _$ D) y _j _ CD 2 = o C o &\ a � = E .g E » o 0fa % / / a \ ° E CU § # R / \ / \ ¢ o E a) o .$? ©/ co o k • . �� / % O Q \ k / UJ ,ca \ k / � Vt t = 4 E 2 2 a= ° & — 5 R/ e I_ \ % 2 \ 3 o ° - Z / - - 2 / 0_ \ I.F. nye- \ f - tea / / * U o o t o__ e t .c CC o_ t CO 5 c & & - w _, m O f k ® 0 ©ix g o F $ - 0 •• = N A 4 m g r » COw 0 c cc / , —J0 \ e / / a \ H � $ .� & < ct g 7 e 2 Et < = m / ± Z $ < e ▪CO $ % 3 } / 2 ,- & 0 R \ o g e �� @ x _ / £ / 77 ± wfCD_ 2g7 ƒ 22 ƒ / 3 / f 'a - . $ / a = ± - 4 = / 2 - 2 u) / $ 6 2 6 0 / — \ z 0 m \ E a 0 R G ,_ o o R a i ° - / % G 0 i § % a 0 w § e 0 0 / / / A/ / Et / 2tt / / � / \ ff / ¥ / 2 _ } OO t & E E ± ; / t 5 2 5 4 ,- CO e co CO \ d d \ / mA7 $ / g f f + CO ® # A TREE_ _ CNH I W LLHEAt = MCEVOY 09-34A S NOTES: WELL ANGLE>70° 11212'. " ACTUATOR= BAKERC CH QAAE TBG&LNR*** KB.ELEV= 55' 20"COND, H 113' --I vI. :. BF.B_Ey= ? 91.5#,H-40, ..4 ' ' 4 2011' -4-1/2"FES X NP,D=3.813" KOP= 3093' D=19.124" �4 '14'..._2• Max Angle= 94°@ 12184` 9-5/8"CSG,47#, -{ 2095' /�;�, 2127' -1_9_-5/8"FES ES CEMENTER I Datum MD= 11064' L-80 HYD-563 ►�/ Datum WO= 8800'SS g- 2150' --9-5/8"BKR EC-P1 XO TO L-80 BTC 9-5/8"CSG,47#,L-80 HYD 563,D=8.681" H 2183' r 9-5/8"BOWEN CSG PATCH H 2183'-2187' , _ GAS LFT MANDREt.S 13-3/8"CSG,68#/72#,K-55/L-80 BTC, - 2512' ST MD TVD DEV TYPE VLV LATCH PORT (DATE D=12347" L d 4 3460 3444 18 MMG DOME RK 16 03/07/09 3 6213 5390 51 MNG DOME RK 16 03/07/09 9-5/8"X 7-5/8"BKR PKR -I 8952' 2 7791 6377 54 MMG SO RK 28 12/30/15 w/PBR EXT,D= JO 1 9119 17177 52 KBMG DMY BK 0 12/30/15 Minimum ID =3.726" @ 10760' ' ' F-4.188. --14-1/2"HES x NP,D=3.813"i 4-1/2" OTIS XN NIPPLE MLLOUT WINDOW(09-34A) 9198'- " 1.9 5/8"CSG 47#,L-80 BTC,D=8.681 -9198 X 9209' H 7-5/8" X 4-1/2"BKR PKR PREM PKR,D=3.875" ' ' 9245' H4-112"HES X NP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP. --I 10653' .0152 bpf,D=3.958" l 10655' H7"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(02/15/09) H10649' I� I� 10694' 44-1/2"OTIS X NP, D=3.813" I Z _ 10715' -7-5/8"X 4-1/2"BKR SA BL-3 PKR 4-112"TBG-PC, 12.6#,13CR,NSCT,D=3.958' - 10772' W/KBH-22 ANCHOR,ID=3.875" TOP OF 5-1/2"LNR -I 10774' ' 10739' -{4-112"OTIS X NP D=3.813" , [7-5/8"LNR,29.7#,L-80 STL.0459 bpf,0=6.875" H 10961' i 10760' -14-1/2"OTIS XN NP?D=3.725" PERFORATION SUMMARY / REF LOG:BI-CS ON 03/06/94&SPERRY MUNE GR 3/30/94 10772' -4-1/2'WLEG,D=3.958"j ANGLE AT TOP F .43'@ 10799' I 107749_5/8"x 7-5/8"BKR C-2 TEE BK SLV,D=5.750" Note:Refer to Roduction OB for historical pert data ■ - SIZE SPF INTERVAL Opn/Sqz SHOT SOZ ■ 10781' -I9 5/8"x 7-5/8"BKR H WR w ISLH HGR D=5.750" 3-1/2" 6 10799- 10820 0 10/31/16 ■ 2-7/8" 6 10836- 10851 0 05/13/15 ■ 3-1/2" 6 10837-10850 0 10/31/16 I► 2-7/8" 6 10855-10870 0 05/13/15 3-1/2" 6 11065-11075 0 10/31/16 2-7/8" 6 11138-11146 0 04/15/02 ■ 2-7/8" 6 11206-11217 0 02/24/14 ■ 2-7/8" 6 11245- 11260 0 05/12/15 0 2-7/8" 6 11340- 11355 0 05/12/15 ■ 2-7/8" 6 11415-11445 0 05/08/15 0 2-7/8" 6 11505-11535 0 02/24/14 0 2-7/8" 6 11535-11565 0 02/24/14 ■ ■ 3-3/8" 6 11750- 11910 0 04/02/94 ■ 3-3/8" 6 11950- 12200 0 04/02/94 ■ 33/8" 6 12230-12420 0 04/02/94 12588' I_ PBTD 3-3/8" 12 12440-12565 0 04/04/94 .4+..+.t. � 4 Fyr y. 5-1/2"LNR 17#,13CR NSCC .0232 bpf,D=4 892"... 1-4___ 12630' J DATE REV BY COMANTS _ DATE REV BY COMMENTS PRUDHOE BAY UNTT 06/10/85 TOWAN3:ORIGINAL COMPLETION 11/07/16 MRD/JMD ACPERFS(10/31/16) WELL: 09-34A 04/04/94 N2ES SIDETRACKED(09-34A) PERMIT No:'1932010 _02!27/09 N4ES RWO - API No: 50-029-21329-01 03/23/14 SET/PJC ADPERFS(02/24/14) SEC 2,T1ON,R15E, 1763'FSL&1036'Fa 05/14/15 MSS/PJC ADFERFS(02/08-02/13/15) _ 01/05/16 GTW/JMC GLV C/O(12/30/15) BP Exploration(Alaska) 0 • I- o o > E 0 O L _c 3 v _Clap 4' , ° +o h Es O HU Y E > pNw ° az o + O +� N O Q C C a +, a Cr m 0 Q <IDU co c0 Up Up O of c0 v u N OU L J V. r r E 4.., C -O 0 N O c y y 0 0 aa) 0_ aa) 0 0 L C v� rnOOt-' . 4 . O c co us gr VCf F cy — N J N N — f0 O LO C 2 a 0 j E \0 v O 1 H +�., u +' C i ca 0 I- 0 v -0 v, U O 0 0 0 0 0 0 0 0 0 C 0) J J J J J J J J J J � 0- 0d W W W W W W W W W W v, a1 C .-. H LL LL LL. LL LL LL LL LL LL Lc. +'' v O N -0 o a J J J J J J J J J J 0_ _0 > + w to ; 1 f- a a a a a a a a a a a) N C 4 •� Z CO o ZZZZZZZZZZ v t v N .��.. LL LL LL U. LL LL LL LL LL. LL K -0 C > W sy1.: , ) > C N • ,+4 N (a O _, Li E O U N O Z7) 1* Z n a a) u > OA U ).. () 0 E E E v U c �i O . , F- d d i �, r.: a H �" ,� v`. X X X C r"a Q c O e�ki:! ,yZ V N a, J 0 Q v a v, c a IN 'V On! O O O J O U b M 1 a tY tY LY Z a Z cc Z m G F .� cc -o -0 v C/3J 5 GI j Li; v e-.4 QW LL a 0_ 2 ca M 0 - 0 O 03 403 -, U 1 01 a 0 c. °) z \ CD V d J J J J 0 J J J J 011 .ii c cc Fi 3 3 3 3 E 3 3 3 3 d W 0 W a a a a a a a a a a ` g m CO CO CO m m CO CO CO CO N% GC 0 0 0 0 0 0 0 0 0 0 O 2 2 2 2 2 22 2 2 2 J 0 0 0 0 0 0 0 0 0 0 N u+ M ® IT IYtY tY tY tC CYCLtY t‘ CC Y a Cl. a a Cl. a a a a aro O a ^tx0 L co cj 0 p;, v o 1.-- 0 N o (03) CO X n 0 o C.,-.1 t,` may..,AN N O 0 O 0 0 0 0 O c6 Q1 ° 0 0 0 0 0 0 0 0 0 O CD s �.,� 0 0 0 0 0 0 0 0 0 0 .■ /$�:., V J LL I a 01 0) (� LL LL ch a) 4 1"J U �. a N d 2 2 N f9 (II to 0 O 4 Y 2 2 E Z Z v E O a Z Z Y ® W D O O O O O O 0 0 0 ,_ O b m O z M O U 0 0 0 0 . . . . +' O O O o 0 0 0 0 0 o Q co 00 CO N N M M rii .4.4 > 0 O N N M E m Na N N N N N N N N N N en C N a 0) 0) o) o) 0) (4) 0) 0) o) 0) c o N N N N N N N N N N f6 00 O O O O O O O O O L C O 0 0 0 0 0 0 0 0 0a-. Y U t: In In In I() It) In IL) In N It) Q - CO C. Z Q1 ) •_ 0 DO) ILI le 0 CCW ILI CJ CU 4.44 N U Z a O M a +r O C N Z GO �ytj Z Q 3 7 ,- co N• 1" N M +' cc co 0 U C aQ aN J 00mm m c c Z a = UO W 3 3 c - .c c P ^ k; O O O i •� a) c a 0 y ti Lo a H a s m RED STATE OF ALASKA 3KA OIL AND GAS CONSERVATION COMh,,.,SION I UN 0 5 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ Operations shutdown ❑ Performed Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casinm Change Approved Program ❑ Plug for Redrill n'erforate New Pool ❑ Repair Well n Re-enter Susp Well n Other ❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑✓ Exploratory ❑ 193-201-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-21329-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028324 PBU 09-34A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12630 feet Plugs measured None feet true vertical 8979 37 feet Junk measured None feet Effective Depth measured 12588 feet Packer measured See Attachment feet true vertical 8974 62 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 26-106 26-105 99 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 9173 9-5/8"47#L-80 25-9198 25-7226 93 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED W ) 9 LV.. True Vertical depth See Attachmentfeet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured)' Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 196 6354 5271 0 249 Subsequent to operation 389 6913 6471 0 265 14 Attachments(required per 20 AAC 25 070 25 071,8 25 283) 15 Well Class after work Daily Report of Well Operations ❑ Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil E Gas LJ WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhaysbp.com Printed Name Nita mmerhays / Title Data Manager Sign ��.7j / ./4,11,11!)-P"'. _ .��, Phone 564-4035 Date 6/5/2015 VTL 6 lig/is RBDMS ) JUN 1 1 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028324 ACTid,1TYDATE I SUMMARY CTU#9 1.75"Scope:AdPerfs MIRU. MU tools. PT MHA. Stab on for surface PT. Low PT. Good. Leak in P-subs. Grease crew on location. High PT. Good. FP the flowline with 60 bbls of 50/50. Kill the well with 180 bbls of Safelube and FP cap. RIH BOT MHA w/2.2" PDS logging carrier w/GR/CCL&3.40"JSN to 11500'. PU for a jewlery log at 40 fpm. Paint Flag @ 11150 E/11191 M. Log up to 9000'. POOH. 5/7/2015 ""Job continued on 5/8/2015"" CTU#9 1.75"Coil. Scope:AdPerfs **Job continued from 5/7/2015** POOH with PDS logging carrier and 3.40"JSN. Tie-in to MWD-GR 30-MARCH-1994, +7' correction. MU SLB 2.88" x 30' perf gun(6 spf and 2906PJ, HMX charges)and RIH. Perforate interval 11,415' -11445'. POOH. MU SLB 2.88"x 15' perf gun and RIH. Found thin spot in pipe at 5918'ctm with a wall thicknes below allowable minimums.. Decision made to POOH and take unit to yard and swap to CTU 3. Freeze protect well with 50/50 meoh to 2200'. Blow down the reel with N2. PT the Tree Cap. 5/8/2015 **"Job continued on 5/9/2015*** CTU#9 1.75"Coil Scope: Rig Down Continue rigging down. MO to yard to swap units. 5/9/2015 ***Job Incomplete*** CTU#3 1.75"Coil Scope:AdPerf Travel from slb yard to 09-34. MIRU 5/10/2015 **Continued on 5/11/2015** CTU#3 1.75"Coil Scope: adperfs Continued from 5/10/2015 Continue rigging up on 09-34. Drift Coil with 1.25"Ball. Small Leak of high pressure grease fittings into reel sump. Complete BOPE Test. RIH w/BOT MHA w/PDS 2.20"GR/CCL logging carrier& 3.50"JSN. Load well w/200 bbls of safelube capped w/10 bbls of 50/50 meoh. RIH and stop at 11,501'. Log up from 11,501'to 10,500'at 40 fpm. Paint yellow flag at 11,150'. POOH. LD logging tools. Download data. Good data. Tie into MWD-GR 30-MARCH-1994. +4'correction. MU gun run #2: SLB 2.88"x 15' perf gun (6 spf and 2906PJ, HMX charges)and RIH. 5/11/2015 **Continued on 05/12/15** CTU#3 1.75"Coil Scope: adperfs Continued from 5/11/2015 Continue RIH with Gun#2 to flag. Correct to top shot depth. Perforate interval 11,340'- 11355'. POOH. MU gun#3:2.88"x 15'and RIH. Perforate interval 11,245'- 11,260'. POOH. MU& RIH w/ BOT MHA w/2.2"PDS logging carrier w/GR/CCL&3.50"JSN. Log from 11200-10500' at 40fpm. Paint flag at 10750E/10745M. POOH. Tie into SLB Perf Record 15-APR-2002. -2'Correction. MU perf Gun#4: 2.88"x 15'6 SPF of(2906PJO, HMX Charges)and RIH. 5/12/2015 ***Job continued on 5/13/2015*** CTU#3 1.75"Coil Scope: adperf Continued from 5/12/2015 RIH to Flag. Correct to top shot depth. Perf interval: 10855-10870'. POOH. MU 5th 2.88"x 15' perf gun and RIH. Perforate interval 10836'-10851'. POOH. Freeze protect well to 2000'with 50/50 meoh. RDMOL. 5/13/2015 **Job complete** FLUIDS PUMPED BBLS METH DIESEL 323 50/50 METH 732 1% KCL W/SAFELUBE 1055 TOTAL Perforation Attachment ADL0028324 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 09-34A 5/13/2015 APF 10836 10851 8693.94 8704.92 09-34A 5/13/2015 APF T 10855 10870 8707.84 8718.71 09-34A 4/15/2002 APF 11138 11146 8885.98 8889.47 09-34A 2/24/2014 APF 11206 11217 8912.63 8916.28 09-34A 5/12/2015 APF 11245 11260 8924.97 8929.19 09-34A 5/12/2015 APF 11340 11355 8944.34 8946.13 09-34A 5/8/2015 APF 11415 11445 8951.82 8953.86 09-34A 2/23/2014 APF 11505 11535 8956.28 8956.85 09-34A 2/22/2014 APF 11535 11565 8956.85 8957.32 09-34A 4/2/1994 PER 11750 11910 8960.73 8968.41 09-34A 4/2/1994 PER 11950 12200 8967.47 8953.14 09-34A 4/2/1994 PER 12230 12420 8952.17 8959.09 09-34A 4/4/1994 PER 12440 12565 8960.48 8972.14 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF o• 0 0 0 0 0 0 0 ca6) co co in Co C) C) - N- N N- 6) N to LU - V' CO cr r N fh- N- U N o 0 0 0 0 0 C) 0 I- 6) 6) V N- LU N (Y) CO • Ct CO N- CO V O V Ca CO h CO CO Ln CO CO 61 CO N- CO h V to O CO CO 6) N- 6) OD • CN f� CO N- N LU O CO r 6) N Ln Ln Cfl r CO CO r N CO CO CI 11111111 H C7 M 6) O N CD in co N- 6) N N N CO N Cp CO CO = O co Lo VCD O 6C) O O LU O Cfl N ✓ O N N O O r r r r • 2 I < MN CO co C) N (V CO N N N co = O _ .5 O J O ~ 0 CDC) LU CO UCCO `n0° UU M J Y J CO 00 CY)• cl) coo coo *k *k N Ln 6) V CO (s) Co Co ,(Q N 6) CV - 00 00 co U - - • M M N N N r 6) M M t co co O O LO co M C CO O OO r CO G) N r 6) N J c Z C7)p w w C j � QQC� C� • a CC CC O IL Lt. Z Z Q Z_ Z_ � D D J D UJJ1 (/) U) F- H Packers and SSV's Attachment ADL0028324 SW Name Type MD TVDDepscription 09-34A PACKER 9217 7239.33 4-1/2" Baker Premier Packer 09-34A PACKER 10716 8603.87 _4-1/2" Baker SABL-3 Packer 09-34A PACKER 10781 8653.49 5-1/2" Baker H Packer D= ^ °Y 0 9-34A CHRO NOTES: ANGLE>70" 11212'. ••, ACTUATOR= BAKERC KB.ELEV= 55' 1 BF.ELEi/= ? "CONDCTR, 113' 9 KOP= 3093' 20 2011' H 4-1/2"HES X NP,D=3.813' Max Angle= 14°@ 12184' 91.5#,F1-40, 1 D=19.124" Datum MD= 11064' Datum TVD= 8800'SS 2127' _--19-58'HES ES CEMENTER 9-5/8"CSG,47#,L-80 HYD-563 2095' 2150' H9-5/8'BKR ECP XO TOL-8OBTC • e 95/8'CSG,47#,L-80 HY D 563,D=8.681" —{ 2183' / 11GAS LFT MANDRELS 9-5/8"BOWEN CSG PATCH 2183'-2187. ST IAD TVD DEV TYFE VLV LATCH PORT DATE 4 3460 3444 18 MMG DOLE RK 16 03/07/09 13-38'CSG,68#/72#,K-55/L-80 BTC, — 2512' 3 6213 5390 51 14NG DOLE RK 16 03/07/09 D=12.347" 2 7791 6377 54 MAG DOLE RK 16 03/07/09 9-5/8"X 7-58'BKR PKR H 8952' I. 1 9119 7177 52 KBMG SO BK 28 08/18/10 w/PBREXT,D= " '=; Minimum ID =3.726" @ 10760' ' 9188' H4-1/2"E C.. r1 X P,ID=3.813" 4-1/2" OTIS XN NIPPLE i MLLO rWH)Ow(09-34A) 9198' ' 9-5/8'CSG,47#,L-80 BTC,D=8.681" —I —9198 9209' H7-5/8" X 4-112"BKR PKR PREM R(R,D=3.875' ir9245' H4-1/2"HES X NP,D=3.813" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 10653' /1.....,,,,.„.. 1� —14-112'OTISE DST .0152 bpf,D=3.958" lam' X NP, 4-1/2'TBG STUB(02/15/09) —I 10649' 4-1/2"TBG-PC, 12.6#,13CR,NSCT,D=3.958" H 10772' C 10715' I—7-5/8"X 4-112'BKR SABL-3 PKR TOP OF 5-1/2"LAR H 10774' ' W/KBF+22 ANCHOR, =3.875" 10739' H4-1/2"OTIS X NP,D=3.813" 7-5/8"LNR,29.7#,L-80 SR.0459 bpf,D=6.875' H 10961' , PERFORATION SUPAVARY 1 1 10760' H4-1/2"OTIS XN NP,D=3.725" RFT LOG:BI-CS ON 03/06/94&SPERRY IME-GR 3/30/94 C10772' —4-1/2"VVLEG,D=3.958" ANGLE AT TOP PERF:_'@ 10836' ( 10774' H9-5/8"x 7-5/8"BKR C-2 TEEBK SLV,D=5.750" Note:Refer to Production DB for historical perf data ■ SIZE SPF INTERVAL Opn/Sgz SHOT SQZ ■ 2-7/8' 6 10836-10851 O 05/13/15 11, 2-7/8" 6 10855- 10870 O 05/13/15 10781' —I9 5/8'x 7-5J8'BKR H PKR w/SLH HGR D=5.750' 2-7/8" 6 11138-11146 0 04/15/02 2-7/8" 6 11206- 11217 0 02/24/14 2-7/8" 6 11245-11260 0 05/12/15 ■ ■ 2-7/8" 6 11340- 11355 0 05/12/15 111 2-7/8" 6 11415-11445 0 05/08115 ■ 2-7/8" 6 11505- 11535 0 02/24/14 ■ 2-7/8" 6 11535-11565 0 02/24/14 ■ 3-3/8" 6 11750-11910 0 04/02/94 ■ 3-3/8" 6 11950-12200 0 04/02/94 ■ ■ 3-3/8' 6 12230- 12420 0 04/02/94 ■ 3-3/8" 12 12440-12565 0 04/04/94 12588' H PBTD 5-12'LNR, 17#, 13CR NSCC,.0232 bpf,D=4.892" }- 12630' DA IL REV BY C00,443sITS DATE REV BY CO.$ENTS PRUDHOE BAY UNIT 06/1O/8540WAN3!ORIGINAL COMPLETION 08/25/10 GJF/AC GLV C/O(08/18/10) 1/11ELL: 09-34A 04/04/94 FRES SIDETRACKED(09-34A) 03/23/14 SET/PJC ADPERFS(02/24/14) PST No: 1932010 02/27/09 N4E5 RINO 05/14/15*t5S/PJCADFERFS(02/08-02/13/15) API No: 50-029-21329-01 03/23/09. /SV GLV C/O(03/19/09) SEC 2,T1ON,R15E, 1763'FSL 8 1036'FEL 06/01/09 SWC/TLH PXN PLUG FUZED(04/07/09) 04/15/10 DB/J14.83 DRLG DRAFT CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA RECEIVED • AL. .,,KA OIL AND GAS CONSERVATION COMMI„JON APR 0 1 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U AOGC"" Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill' 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 193-201-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: • Anchorage,AK 99519-6612 50-029-21329-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028324 PBU 09-34A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): •10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured . 12630 feet Plugs measured None feet true vertical 8979.37 feet Junk measured None feet Effective Depth measured • 12588 feet Packer measured See Attachment feet true vertical 8974.62 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 26-106 26-105.99 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 9173 9-5/8"47#L-80 25-9198 25-7226.93 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11138-11146 feet 11206-11217 feet 11505-11535 feet 11535-11565 feet 11750-11910 feet 11950-12200 feet 12230-12420 feet 12440-12565 feet True Vertical depth 8885.98-8889.47 feet 8912.63-8916.28 feet 8956.28-8956.85 feet 8956.85-8957.32 feet 8960.73-8968.41 feet 8967.47-8953.14 feet 8952.17-8959.09 feet 8960.48-8972.14 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RgDM MAY 14 2014 Treatment descriptions including volumes used and final pressure: SCANNED JUN 1 9 20111 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 60 6228 4249 1906 275 Subsequent to operation: 431 7506 5495 1885 299 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 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: N/A Contact Nita Summerhays Email No.Summerhayst bp.com Printed Name Nita Summerhays Title Data Coordinator •• .0 �`.� 2 1 Phone 564-4035 Date 4/1/2014 y VI-i 5/ 0// L fii,ell Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028324 ACTIVITYDATE I SUMMARY , T/I/0=1500/1500/0 Assist E-Line load and kill. Pumped 5 bbls neat methanol, followed by 262 bbls of 120* 1%kcl down tbg to load. Freeze protect tbg with 2 bbls neat, followed by 40 bbls of crude. Dso notified of well status and tree valve positions as follows: 2/17/2014 SV,WV,SSV= closed. MV=open. IA and OA open to gauges. FWHP=0/1489/0 ***WELL SI ON ARRIVAL*** (ELINE: TRACTOR/ PERF) INITIAL T/I/O = 500/1300/0 RIG UP 2/17/2014 ***JOB IN PROGRESS CONTINUED ON 18-FEB-2014 *** ***JOB CONTINUED FROM 17-FEB-2014***(ELINE: TRACTOR/ PERI-) RIG UP STANDBY FOR COLD TEMPS 2/18/2014 ***JOB POSTPONED*** ***WELL SI UPON ARRIVAL*** (ELINE: DRIFT/PERF) INITIAL T/I/O: 500/1300/0 RUN 1: DRIFT W/HEAD/ECRD/XTRA-B/PBMS/30' OF 2-7/8" DUMMY GUNS. OAL= 61', OAW= 1000#, MAX OD = 3.125" 2/21/2014 ***JOB IN PROGRESS CONTINUED ON 22-FEB-2014*** 2/22/2014 Road to loc,job cancelled ***JOB CONTINUED FROM 21-FEB-2014 ***(ELINE: TRACTOR/PERF) FINISH DRIFT TO 11810'. RUN 2: RIH WITH HEAD/ECRD/XTRA-B TRACTOR/WPP/30' OF 2-7/8" PJO 2906, HMX. OAL= 71', MAX OD = 3.125", OAW= 1250 LBS. PERFORATED INTERVAL 11535-11565'. TOP SHOT= 11535' CCL TO TOPSHOT= 12.3' CCL STOP DEPTH = 11522.7'. PEN = 36.0 IN EH = 0.34 IN MAX SWELL= 3.32 IN TIE-IN/REF LOG: SPERRY MWD-GR ON 03/30/1994 TOOLSTRING STUCK-9280'AND PTO BROKE ON LOGGER. WAIT ON MECHANIC TO FIX. PTO IS FIXED. TRACTOR IN REVERSE TO FREE UP TOOLSTRING. PARTIAL RIG DOWN TO RELIEVE DAYLIGHT CREW ON DS-07. 2/22/2014 ***JOB IN PROGRESS CONTINUED ON 23-FEB-14*** ***JOB CONTINUED FROM 22-FEB-2014*** (ELINE: TRACTOR/PERF) STANDBY FOR WIND RUN 3: RIH WITH HEAD/ECR)/XTRA-B/WPP/30' OF 2-7/8" PJO 2906, HMX. OAL= 72", OAW= 1000#, MAX OD = 3.125". PERF INTERVAL= 11505'-11535'. POOH. CCL TO TOP SHOT= 12.3'. CCL STOP DEPTH = 11492.7'. PEN = 36.0 IN EH = 0.34 IN MAX SWELL= 3.32 IN TIE-IN/REF LOG: SPERRY MWD-GR ON 03/30/1994 RUN 4: RIH WITH HEAD (ECRD)/XTRA-B/WPP/ 11' OF 2-7/8" PJO 2906, HMX. OAL = 61', OAW= 860#, MAX OD = 3.125" 2/23/2014 ***JOB IN PROGRESS CONTINUED ON 24-FEB-2014*** Daily Report of Well Operations ADL0028324 ***JOB CONTINUED1-ROM 23-FEB-2014 *** PERF INTERVAL= 11206'-11217' CCL TO TOP SHOT= 20.3' CCL STOP DEPTH = 11185.7' PEN = 36.0 IN EH = 0.34 IN MAX SWELL= 3.32 IN TIE-IN/REF LOG: SPERRY MWD-GR ON 03/30/1994 FINAL T/I/O = 500/1350/0 ***JOB COMPLETE-WELL SHUT IN UPON DEPARTURE - DSO NOTIFIED 2/24/2014 STATUS*** FLUIDS PUMPED BBLS 3 DIESEL 7 METH 262 1% KCL 40 CRUDE 312 TOTAL 0-0• 0000000 Mrrn� N w (f� O NDLOc000 C TtCO ,TN r- V LO0vN- ) NCOY) C) O r- M gOc') O) r- 0) O ▪ O ti N O O CO N' 0 N- CAN O O CO OD OD N- N CO CO coiiiiii M CoNppOCOCA � N NrN N CO N CO owM co co co 0 0 O N O N O N O O N < Co) NCO CSD CON c Oi CV CD ND _ .Q o J H04.9 00 cY) J Y -.11 M M d *kN � WW * * Cn Ntf) CA * � W0 (00 C) N •0) N � ropfX) ZOCNi � O N O M ch (V NI- , , 77' ' i t M r- M 4 OO MW C CC) O CO Nrd. C O J N ,- 0) N • Z O WW H• O 0UULC9C9 f 0 0LLLLLZZ ZO Z Z W D D D D Packers and SSV's Attachment ADL0028324 SW Name Type MD ND Depscription 09-34A PACKER 9217 _ 7191.07 4-1/2" Baker Premier Packer 09-34A PACKER 10716 8555.61 4-1/2" Baker SABL-3 Packer 09-34A PACKER 10781 8605.23 5-1/2" Baker H Packer TREE= CNV SAI TOTES: WELL ANGLE>70'IS 11212'. WELLHEAD= MCEVOY 09-34A •**4-12"CHROME TBG&5-1/2"CHROME LNR"* ACTUATOR= BAKER KB.ELEV= 55' BF.ELEV= 2 I KOP 3093' 1 /1 Max • Angle= 34'Q 12184' 20"CONDCTR 113' 4 4. Datum MD= 11064' 91.5#,1+40, 4 ' w2011' 4-1/2"HES X NP,D=3.813' Datum TVD= 8800'SS D=19.124' '�1 9-5/8"CSG,47#,L-80 HYD-563 H 2095' i /•$1 I •1 212T H9-5/8"FES ES CBu1BJTOt XO TO L-80 BTC ; • ► • 9-5/8'CSG,47#,L-80 BTC,D=8.681' ---12183' 2150' -19-5/8"BKR ECF J GAS UFT MANDRELS 9-5/8"BOW EN CSG PATCH -l 2187' T ND TVD DEV TYPE VLV LATCH FORT DATE • 3460 3444 18 MMG DOME RK 16 03/07/09 13-3/8'CSG,68#172#,K-55/L-80 BTC, 2512' r 3 6213 5390 51 MMG DOME RK 16 03/07/09 D=12.347' 2 7791 6377 54 MMG DONE RK 16 03/07/09 Minimum ID = 3.725" @ 10760' 1 9119 7177 52 KBN1G SO BK 28 08/18/10 4-1/2" OTIS XN NIPPLE 8940' H7'BKR FKR w/PBR EXT&LNR HGR ASSY,ID=6.875' ITOP OF 7-5/8'LNR 1---{ 8968' 1 W /C4 j 9188' -4-1/2"HES X NP,D=3.813" I 1 9209' H7-5/8" X 4-1/2"BKR PKR PREM PKR,D=3.875" 9-5/8*CSG,47#,L$0,ID=8.681' � -9198' � _ 11_ • 144,"- b4� 9245' -14-1/2"HES X NP,D=3.813" 144, I 44 1�44 ,\ 10655' H7"x 4-1/2"UNIQUE OVERSHOT t% 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -I 10653' ...A4, 10694 1-14-1/2-OTIS X NIP,D=3.813' 1 WOO .0152 bpf,D=3.958" 14444 10715' -7-5/8"X 4-1/7 BKR SABL-3 PKR 1Al,,,,OA 4-112"TBG STUB(02/15/09) J 10662' 1. 1 4�4�4�* /e. W/KBH 22 ANCHOR,D=3.875' 4444444, v 44444 44 ' 10739' -4-1/2"OTIS XNP,ID=3.813 J ♦••1•••11♦ 10760' 4-112"OTIS XNNIP,D=3.725" VAVAVIVA 1111, BAKER K-1 BRIDGE PLUG kweemeeeeeeBRIDGE 10772' --14-1/2'VVLEG,D=3.958" 4. 4-1/7 TBG-PC, 12.6#,13CR.NSCT,D=3.958' I- 10772' TOP OF 5-1/2'LNR --1 10774' f 7-5/8' LNR,29.7#,L-80,STL,D=6.875' 1--I 10961' PERFORATION StM fARY ` REF LOG: BHCS ON 03/06/94&SPERRY MWE GR 3/30/94 ` ANGLE AT TOP PERF:64`@ 11138' NLLOUT 1M DOW(09-34A) 9180'-8231' Note:Refer to Roduction DB for historical perf data ` SIZE SPF NTBRVAL Opn/Sqz SHOT SQZ 2-7/8" 6 11138-11146 0 04/15/02 ` 2-7/8" 6 11206-11217 0 0224/14 2-7/8' 6 11505-11535 0 02/24/14 v 2-7/8" 6 11535-11565 0 02/24/14 3-3/8" 6 11750-11910 0 04/02/94 3-3/8" 6 11950-12200 0 04/02/94 PBTD 12588' ,\,%-, 3-3/8" 6 12230-12420 0 04/02/94 `%,\ �, 3-3/8" 12 12440-12565 0 04/04/94 5-1/2'LNR 17#,13CR,NSCC,.0232 bpf,D=4.892" 12630' DATE REV BY COMMENTS DATE REV BY COMVB'ITS R JDHOE BAY MT 06/10/85 FaOWAN35 ORIGINAL COMPLETION 04/15/10 DB/JMD DRLG DRAFT CORRECTIONS WELL: 09-34A 04/04/94 N2ES S10ETRACKB)(09-34A) 08/25/10 GE/AGR GLV CIO(08/18/10) PIT No:'1932010 02/27/09 N4ES RWO 03/23/14 SET!PJC ADPERZFS(02/24/14) API Na: 50-029-21329-01 03/02/09 PJC DRLG CORRECTIONS RFC 2,T1 ON,R15E,1763'FSL&1036'FEL 03/23/09 /SV GLV C/O(03/19/09) 06/01/09 SVVC/TLH PXN RUG PULLED(04/07/09)- BP Exploration(Alaska) STATE OF ALASKA . ALASK.. AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon IS Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver 0 - Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Re- energize secondary seals 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 193 - 201 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 • 50 - 029 - 21329 - 01 - 00 7. Property Designation: 8. Well Name and Number: ADL028324 . e PBU 09 -34A 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 12630' feet Plugs (measured) 10760' feet true vertical 8979' feet Junk (measured) None feet Effective depth: measured 12588' feet Packer: (measured) 9209' & 10716' feet true vertical 8975' feet Packer: (true vertical) 7234' & 8604' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1490 470 Surface 2512' 13 -3/8" 2512' 2512' 3450 / 4930 1950 / 2670 Intermediate Production 9198' 9 -5/8" 9198' 7227' 6870 4760 Liner 2021' 7 -5/8" 8940' - 10961' 7065' - 8783' 6890 4790 Liner 1856' 5 -1/2" 10774' - 12630' 8648' - 8979' 7740 6280 Perforation Depth: Measured Depth: 11138' - 12565' }' " / :': Ill True Vertical Depth: 8886' - 8972' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# 13Cr80 10772' 8647' Packers and SSSV (type, measured and true vertical depth): 7 -5/8" x 4 -1/2" Baker Premier packer; 9209' 7234' 7 - 5/8" x 4 - 1/2" Baker 'SABL - 3' Packer 10716' 8604' 11. Stimulation or cement squeeze summary: RECEIVED/ Intervals treated (measured): °3 EP 2 2 2O1 Treatment description including volumes used and final pressure: Alaska Gil & Gas Cons. Commission A.,C►or4Ci 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 131 4,939 4,641 20 1,860 Subsequent to operation: 128 5,837 4,760 20 1,800 13. Attachments: ❑Copies of Logs and Surveys run 14. Well Class after work: ■.: Daily Report of Well Operations ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic IN Well Schematic Diagram 15. Well Status after work: ❑ GINJ • ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. 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 Charles Reynolds, 564 -5480 311 - 238 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number. Signature Phone 564 -4628 Date l (�� Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 RBDMS SEP 26 2611171 [. e ez4 -I( `ie */ Submit Original Only • • • 09 -34A, Well History (Wellhead Repair) Date Summary 08/03/11 T /I /0= 690/1240/6. Temp= SI. Bleed IA & OA to 0 (Assist with PPPOT) AL is SI at casing valve an lateral valve with 2000 psi. Rig down Crystal gauge. Initial IA FL= 8625' (above oglv, 461 bbls). Bled IAP to UR tank to 4 psi in 6.5 hrs.(gas). IA FL is unchanged. Pressures are unchanged during 30 min monitor. WHP's 650/5/4. * ** Job incomplete * * *. NOTE: AL casing valve and lateral valve were serviced. 08/04/11 T /I /0= 650/0/0, Temp =Sl. PPPOT-IC (PASS), re- energize secondary seal IC. DHD holding open bleed on IA & OA. PPPOT -IC: Stung into test port (0+ psi), bled to 0 psi. RU packing gun to IC PKG port. Pressure test void, unable to achieve test pressure of 3500 psi. Re- energize secondary seal with plastic. Pumped approx 1/2 stick J stick plastic. Pressured test void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 08/04/11 T /I /O = 650/4/5. Temp = SI. Assist Cameron /bleed IAP & OAP to 0 psi (Pre- PPPOT -IC). AL is SI @ casing & lateral valves, ALP @ 1920 psi. IA FL @ 8625' (494' above sta # 1 so, 462 bbls). Bled IAP from 4 psi to 0 psi (gas, to UR) in 2 hours & held open bleed for an additional 2 hours. Bled OAP from 5 psi to 0 psi in 10 seconds. Assist Cameron w/ PPPOT -IC. FWHP's = 650/0/0. Job Complete. 08/05/11 T /I /O = 650/0/0. Temp = SI. Assist Ops w/ POP (Eval IAxOA comm). AL is SI @ casing & lateral valve, ALP @ 1920 psi. Rigged up crystal gauge to IA & OA. DSO POP'ed well @ 13:00. Monitor OA BUR through shift (OAP increased to 5 psi in 4 hours). Crystal gauge left on OA. Temp = 86 °. FWHP's = 250/1830/5. Job Complete. 08/10/11 T /I /O = 250/1830/4. Temp =58 °. WHPs (Post PPPOT -IC). AL is on line @ 1830 psi. OAP decreased 1 psi since 8/5/11. Replaced batteries on Crystal gauge. Page 1 of 1 TREE = CNV VVELLHEAp = MCEVOY SAFETY NO.: WELL ANGLE> 70 @ 11212'. ACTUATOR = BAKER C • * * *4 -1/2" ME TBG & 5 -112" CHROME LNR"' KB! ELEV= 55' 9 -34A BF. ELEV = 7 KOP = 3093' "0 • I Max Angle = 94° @ 12184' 20" CONDCTR, — 113' 1 �, �t • Datum MD = 11064' 91.5#, 14-40, 0 I , - 4 • 1 2011' H4-1/2" HES X NP, ID = 3.813" 1 Datum TVD = 8800' SS • 4 ID = 19.124" 14 • 1. 9-5/8" CSG, 47 #, L -80 HYD-563 2095' 1' • 2127' H9 -5/8" HES ES CEMENTER 1 • XO TO L -80 BTC 1; • 2150' H9 5/8" BKR ECP CSG, 471,1-80 BTC, ID = 8.681" 83 21' C 19 -5/8" BOWEN CSG PATCH H 218T GAS LIFT MANDRELS ST MD ND1DEV TYPE VLV LATCH PORT DATE 1 13 3/8" CSG, 681/72 1, K- 551L -80 BTC, 2512' [jj 4 3460 3444 18 MC DOME RK 16 03/07/09 = 12.347" 3 6213 5390 51 MMG DONE RK 16 03/07/09 2 7791 6377 54 MMG DOME RK 16 03/07/09 Minimum ID = 3.725" @ 10760' 1 9119 7177 52 KBMG SO BK 28 08/18/10 4 -1/2" OTIS XN NIPPLE 8940' H7" BKR PKR w /PBR EXT & LNR HGR A SSY, 0 = 6.875" I ITOP OF 7-5/8" LNR H 8968' I u e; 9188' 4-1/T HES X NP, ID = 3.813" I ' 9209' 7 -5/8" X 41 /2" BKR PKR PREM PKR, O = 3.875" 9-5/8" CSG, 47 1, LSO, ID = 8.681" H 9198' V. VA H I 1#1 �� /•/ 9245' H 41/2" HES X NIP, O = 3.813" 1 1 I 4./ 14 10655' H7" X 41/2" UNIQUE OVERSHOT 1 •, 41/2" TBG, 12.61, 13CR 80 VA TOP, — 10653' ( 1 .0152 bpf, ID = 3.958" '�' 4 10694' H41/2" OTIS X NIP, ID = 3.813" 1 1•••• •• 1071 S (— 7 -518 X 41 /2" BKR SABL -3 PKR 4 •.•..� 1 ■ Ilk ANCHOR, 0 = 3.875" 141/2" TBG STUB (02/15/09) ►• j� j� j� j * j * j� v 1��•••••■ ' 10739' 1 J41/Z' OTIS X NIP, ID= 3.813" 1 1 • ••••••••••Ir •1. 111" 10760' H4-1/2" OTIS XN NP, ID = 3.725" 1 I BAKER K -1 BRIDGE PLUG 50' ►•• ∎iii ∎••i ∎••i •i ∎i7i I � 10772' 41/2" WLEG, 0 = 3.958" I HELMD TT NOT LOGGED I 1 4-1/2" TBG -PC, 12.6#, 13CR, NSCT, ID = 3.958" H 10772' (TOP OF 5-1/T LNR H 10774' 1 7-5/8" LNR, 29.71, L-80, STL, ID = 6.875" H 10961' ` PERFORATION SUMMARY ` REF LOG: BHCS ON 03/06/94 ANGLE AT TOP PERF: 64° @ 11138' ` Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sqz DATE MELOUT WINDOW (09-34A) 9180' - 8231' ` 2 -7/8" 6 11138 - 11146 0 04/15/02 3 -3/8" 6 11750 - 11910 0 04/02/94 3-3/8" 6 11950 - 12200 0 04/02/94 3 -3/8" 6 12230 - 12420 0 04/02/94 3-3/8" 12 12440 - 12565 O 04/04!94 PBTD 12588' \ N ii N`■\► 5-1/2" LNR, 171, 13CR, NSCC, .0232 bpf, ID = 4.892" H 12630' DATE REV BY CONNIENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/10/85 ROWAN35 ORIGINAL COMPLETION 04/15/10 DB/JMD DRLG DRAFT CORRECTIONS WELL: 09-34A 04/04/94 N2ES SIDETRACKED (09 -34A) 08/25/10 GJF /AGR GLV C/O (08/18/10) PERMT No: '1932010 02/27/09 N4ES RWO API No: 50 -029- 21329 -01 03/02/09 PJC DRLG CORRECTIONS SEC 2, T1 ON, R15E 1763' FSL & 1036' FEL 03/23/09 /SV GLV CIO (03/19/09) 06/01/09 SWC/TLH PXN PLUG PULLED (04/07/09) BP Exploration (Alaska) OPERABLE: Producer 09 -34A (PTD 32010) IAxOA Communication Mitilid Page 1 Q 3- J` Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, August 30, 2011 2:54 PM (( • 13t(1( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Longden, Kaity Subject: OPERABLE: Producer 09 -34A (PTD #1932010) IAxOA Communication Mitigated Attachments: Producer 09 -34A (PTD #1932010) TIO Plot.doc All, Producer 09 -34A (PTD #1932010) has shown no signs of IAxOA communication after the secondary seals were re- enerqized on 08/04/2011. A PPPOT -IC performed on 08/04/2011 confirmed the success of the treatment. A previous PPPOT -IC on 07/09/2011 indicated a secondary seal failure. The well has been online for 10 days, and has shown no indication of OA repressurization after shutting in the well. The well is reclassified as Operable. A current TIO plot is included for reference. «Producer 09 -34A (PTD #1932010) TIO Plot.doc» A 10 -404 form will be submitted to the AOGCC to confirm completion of the repair proposed in Sundry Number 311 -238 dated 7/29/2011. Please call if you have any questions. Thank you, � L u h Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 02, 2011 4:13 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; Cismoski, Doug A; AK, D: ' Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; , OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Longden, Kai. Subject: UNDER EVALUATION: Producer 09 -34A (PTD #1932010) Resume Product- to Diagnose IAxOA Communication All, Producer 09 -34A (PTD #1932010) was shut -in for sc -duled turnaround work on 06/18/2011. After the well was shut -in, the OA and IA pressures equalizz. at 1860 psi. The surface casing for the well has 2 joints of 13 -3/8" 68 ppf K -55 from surface to 77' hich has a burst rating of 3450 psi. The 1860 psi seen on 06/18/2011 was 53.9% of internal yield pr- sure. Conservation order 492 requires a submission of a 10-403 sundry with corrective actions for A •GCC approval when surface casing pressure exceeds 45% of yield. Discussion with the AOGCC h-s given us permission to continue diagnostics before submitting 8/31/2011 PBU 09 -34A PTD #1932010 8/30/2011 TIO Pressures Plot Well: 09 -34 4,000 • 3,000 - +R Tbg — IA 2,000 - OA 00A 00CIA 0n 1,000 - 06/04111 06/11/11 06/18/11 06/25/11 07/02/11 07/09/11 07/16/11 07123/11 07130/11 08106/11 08113/11 08/20/11 08127111 • • • ETIAIrE SEAN PARNELL, GOVERNOR ij ALASKA OIL .AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Kara Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09 -34A Sundry Number: 311 -238 Dear Mr. Kara: De ,�: 4 ' JA L292 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 . eekend. Sin - ! 4 , e ,g Da r. eamount, _ . Cha DATED this ?/ day of July, 2011. Encl. STATE OF ALASKA a* ,1 \,, E ALAS AND GAS CONSERVATION COMMIS. 1/ ; ii ; i4 2111 APPLITION FOR SUNDRY APPROVAL 20 AAC 25.280 _ s i. '.' a >, > • PP. OK. (v 1 'Gil Rii$$i011 1. Type of Request: 4 -,..r ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing 0 Other Re- energize secondary seals 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Development ❑ Exploratory 193 -201 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 21329 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09 -34A Spacing Exception Required? ❑ Yes 0 No 9. Property Designation: 10. Field / Pool(s): ADL 028320 & 028324 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12630 8979 12588 8975 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1490 470 Surface 2512' 13 -3/8" 2512' 2512' 3450/4930 1950 / 2270 Intermediate Production 9198' 9-5/8" 9198' 7227' 6870 4760 Liner 2021' 7 -5/8" 8940' - 10961' 7065' - 8783' 6890 4790 Liner 1856' 5-1/2" 10774' - 12630' 8648' - 8979' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11138' - 12565' 8886' - 8972' 4 -1/2 ", 12.6# 13CR80 10772' Packers and SSSV Type: 7 -5/8" x 4 -1/2" Baker Premier packer Packers and SSSV 9209' MD / 7234' TVD 7 -5/8" x 4 -1/2" Baker 'SABL -3' packer MD (ft) and TVD (ft): 10716' MD/ 8604' TVD 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 30, 2011 0 Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Charles Reynolds, 564 -5480 Printed Name Dan Kara Title Engineering Team Leader Signature de , ____7�� p,Dv Ti 3 O�q P hone 564 - 5667 Date Elizab B -5674 Commission Use Only Date Conditions of approval: Notify Commission so that a representative may witness ! 1 ,� Sundry Number 1 ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance • Other: Subsequent Form Required: /b — / , 7 / / APPROVED BY 7-2. 9_// Approved By: 0 MISSIONER THE COMMISSION Date Form 10-403 Revise.. „1D1 S JUL 2 9 r r f ! Submit In Duplicate \. No. •"'- _ 0 . INAL 7 4._ 7, J'-i/ : , . . by Date: July 28, 2011 To: Jerry Murphy /Mehreen Vazir Liddelow, AK, D &C Well Integrity Coordinator From: Charles Reynolds, Well Integrity Engineer 564 -5480 Subject: 09 -34A Wellhead Repair Est. Cost: $10m AFE: APBD09WL34 IOR: req comp Step Type Procedure 1 D Bleed IA and OA to 0 psi 2 W Re- energize secondary seals on IC hanger with plastic packing 3 W PPPOT -IC to 3500 psi Objective: This procedure is to repair the wellhead leakpath between the IA and OA which allowed the OA and IA to equalize at 1860 psi exceeding 45% of the surface casing yield. Well Stats: Well Status: Under Eval (PAL) — Invesigating IAxOA comm Last Productivity test: 120 BOPD, 97% WC, 40,623 GOR Deviation: N/A Min ID: N/A Last BHP: 2531 psi @ 8800' TVD, (6/10/2001) Last H2S: 130 PPM (03/06/11) Well Events Summary: 09 -34 is an artificially lifted producer originally drilled in 1986 and sidetracked in 1994. The well suffered slow IAxOA communication and was waivered to remain on production. When the waiver was cancelled in July of 2005 the well was shut in and secured until the RWO in 2009 in which the production casing was replaced and the OA was cemented back to surface to repair the IAxOA communication. When the well was shut -in for scheduled turnaround work on 06/18/2011 the OA and IA pressures equalized at 1860 psi. The surface casing for the well has 2 joints of 13 -3/8" 68 ppf K- 55, which has a burst rating of 3450 psi therefore the 1860 psi seen on 06/18/2011 was 53.9% of internal yield pressure. Subsequent diagnostic testing has shown that the primary seals on the inner casing packoff were leaking when cold, however are holding when hot and the secondary seals continue to leak when hot. Please call Charles Reynolds at 907 - 564 -5480 with any questions or concerns regarding this program. Cc: Well File AK, D &C Well Integrity Engineer 1 GIW _HEAD= M C E V O Y SAFETY N : W ELL ANGLE > 70' @ 11212'. JATOR _ BAKER C 09-34A 4 "d -112" CHROME TRG & 5 -112" CHROME INR"* 1 aEV = 55' ELEV = '7 '= 3093 12 A ! ►� R Angle = 94' 12184' 20" CONDCTR, 1` 4 tum MD = 11064' 91.5#. H-4 1 4 1 2011' H4 -1 /2" HES X NP, D = 3.813" 1 tum TV1l a �� 8900 SS ' D - 19.124" !; 0, 9-518 CSG, 47 #, L A01 110 551 2096' I XO 10 L -80 B 1C is �! 2127' , _j9 -518" HES ES CEMENTER 1 • 1 2150' - {9 -51A" SKR CCP 1 9-5 CSG, 470 1.80 BTC, D = 8.681" I 2183' i 1 19 -518" BOWEN CSG PATCH H 2187' GAS LIFT MANDRFI S egpipoinailamizal LATCt4 PORT DATE 13318 CSG. 58#/72#, K 5S+1. 80 BTC 2512' In 4 3460 3444 18 WAG DOVE RK 16 03/0709 ID = 12.34r 3 6213 5390 51 I*M3 DOME RK 15 031074139 2 7791 6377 54 MG DOME RK 16 03!07,10 Minimum ID = 3.726" @ 10760' 1 9119 7177 52 KHMG SO BK 28 08/18/10 4-1/2" OTIS XN NIPPLE 8940' H7' BIM PKRw /PAR F I$ I. NRfORASSY,ID=6875" 1TOP OF 7-5/8" LNR I 8968' c1 ► 9188' 1 -14- 1 /2"tiESXNP.D= 3.813" 1 9 -5.8 C SG 4711, L-80 ID = 8.681" 9209' 7 -518" X 41!2 BKR PKR PRElA PKR, E) - J R75" 1 � ' 919a r 1 iiii i • c∎ 0 �'. I 'R� �, �•� 9245' 4vrltFSxNP.a= 3.s13" r 4 i•i i ►4 `" 10655' Hr x4-1/7 UNIQUE OVERSHOT 1 4 1/2" TBG, 12.6#, 13CR -#0 VAM TOP, —I 10653' v A.% 10654' —14147 OTIS X I+AP, ID '3 813" 1 .9152 bpf, ID = 3.958" t� •�• diik 10711 7 bra' Y.4 i n" uVA SMIL 2 DKR 44444 41/7 TRG;STUPI u7 /1S/O9 10662' ► ►4 1/4,,4.4.. f 1 ) 1 ; r i N V.:"., W/KBH- 22 ANCHOR, 1) = 3.875" i 444444444 ► �►+ I * 10739' 1- 141!2" OT1S X NIP, ID = 3 813" 1 44444444► 14/4444444 �► 444444440.VF * 10760' 1- 14- t12' OTIS XN NP, D =3.725 44444444444 0440444444 . BAKER K. -1 BRIDGE PLUG 1a►tw" f.♦1 9 430 " 4 t: —1 • 11 1111111P"' 10772' -14-1/2" 1NL EG, ID =3.958" 1 0 1 1ELMD TT NOT LOGGED 1 , 1 411? TBG -PC, 12.80, 13CR. NSCT. ID - 3.96$" 1-1 10772' ;; TOP OF 5-112" UV 10774' 75/8• LNR, 29.71►, L-80, S11, ID = 6.875" I 10961' PERFORATION SUMMARY REF LOG: BRCS ON 03 ANGLE AT TOP PFRF 64' © 11138' Note: Refer to Production LE for trstortai pert data SCE SPF INTERVAL Opf1/SU DATE ML LOUT WINDOW (O1-34A) 9180' - 0231 2 -718" 6 11138 - 11148 0 - 04/15/02 3 -318` 6 11750 - 11910 0 04/C2 3 -318" 6 11950 - 12210 0 04/02/94 :R' A 1721.f1 - 17a:(1 0 04/02/94 3-318" 12 12440 - 12565 0 04/1;4+94 4 • PRTn 1 12588' 41a. ' 5.112" LNR. 170, 13CR, NSCC, 023? hot ID = 4 84?" 12630' DATE REV BY C0KNENTS DA IF RF.V HY COMM-HIS 3.ROUF('EBAY UNIT 06/10/86 ROWAN3: ORlG'1AL COMPLETION 0411 NS WELL: 09-34A 111 04/O4/ 4 N2f8 SIDETRACKS) (OS -34A) 08/25/10 GJF /A GR GLV C/0 (08118/10) PERMIT No: 9932010 02/27839 N4ES MOO . API Nu: 50- 029-21329 -01 03/02/09 PJC DRLG CORRECTIONS SEC 2, T1 ON, R15E 1763' FSL & 1036' FEL 03/23109 /SV GLV C/0 (03/19109) 06101109 SWC ILH PXN P_UG PULLED (04/0749) 8P Exploration (Alaska) 2 UNDER EVALUATION: Producer 094A (PTD #1932010) Resume Producti to Diagnose I... Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Ref 71121 Sent: Saturday, July 02, 2011 4:13 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Longden, Kaity Subject: UNDER EVALUATION: Producer 09 -34A (PTD #1932010) Resume Production to Diagnose IAxOA Communication All, Producer 09 -34A (PTD #1932010) was shut -in for scheduled turnaround work on 06/18/2011. After the well was shut -in, the OA and IA pressures equalized at 1860 psi. The surface casing for the well has 2 joints of 13 -3/8" 68 ppf K -55 from surface to 77', which has a burst rating of 3450 psi. The 1860 psi seen on 06/18/2011 was 53.9% of internal yield pressure. Conservation order 492 requires a submission of a 10 -403 sundry with corrective actions for AOGCC approval when surface casing pressure exceeds 45% of yield. Discussion with the AOGCC has given us permission to continue diagnostics before submitting the 10-403 for corrective actions. The well has been reclassified as Under Evaluation on a 28 day clock for further IAxOA communication diagnostics. Please notify the Well Integrity Engineer (x5525) prior to placing the well on production as DHD will need to be on location to monitor the OA. The well passed a PPPOT -T and PPPOT -IC after retorquing the lock down screws on 06/19/2011 after the well was shut -in. Plan forward: 1. Operations: Put well on production with DHD monitoring 2. DHD: Outer annulus repressurization test (OART for 5 days) 3. Wellhead: Positive Pressure Packoff test- inner casing (PPPOT -IC) with well flowing 4. DHD: Shut -in well and monitor for OA repressurization 5. WIE: Evaluate for Seal -Tite treatment 6. Anchorage Pad Engineer: Submit 10 -403 prior to any required repairs based on diagnostic findings. Please call if you have any questions or concerns. Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator JUL 1 4 2011 Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, June 20, 2011 10:09 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Longden, Kaity Subject: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA All, 7/12/2011 UNDER EVALUATION: Producer 094A (PTD #1932010) Resume Productiito Diagnose I... Page 2 of 2 Producer 09 -34A (PTD #1932010) was found to have sustained casing pressure on the"IZA. The tubing /IA/OA = SSV/1860/1860 on 6/18/2011. The well is currently shut in for turnaround activity and has been reclassified as Not Operable. The plan forward for diagnostics will be: 1. DHD: OA repressurization test 2. Wellhead: PPPOT -IC and Re- energize wellhead seals 3. DHD: Re -OA repressurization test 3. WIE: Evaluate for Seal -Tite treatment A TIO Plot and wellbore schematic are attached for reference: Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com II I 7/12/2011 NOT OPERABLE: Producer 09 -34A oD #1932010) Sustained Casing Pressuuon OA Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) (j In i( Sent: Thursday, June 23, 2011 12:43 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA Thank you for the call ealier explaining this and the follow -up email. I agree that the sundry application should be sent after completing diagnostics. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 �►'t Anchorage, AK 99501 i. �iLM 2 4 2 0 . 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, June 23, 2011 9:42 AM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA Jim, The 13 -3/8" surface casing has the following configuration: 77' of 13 -3/8" 68 ppf K -55 (77') 2435' of 13 -3/8" 72 ppf L -80 (2354') The pressure on the OA was exhibited when the well was shut in. The pressure on the IA and OA were immediately bled down at that time and the well has since remained shut in. We are planning to conduct diagnostics to determine location of the leak point (wellhead or downhole) and then develop a plan forward for repair. Once diagnostics are completed and a plan developed, we will submit a 10 -403 for corrective action as required by CO 492. Attached is an updated TIO plot for reference. Please let me know if you have any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, June 22, 2011 1:31 PM 6/23/2011 NOT OPERABLE: Producer 09 -34A oD #1932010) Sustained Casing Press on OA Page 2 of 2 To: AK, D &C Well Integrity Coordinator Cc: Schwartz, Guy L (DOA) Subject: RE: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA well schematic shows 13 -3/8" surface casing as a mixed string of K55 and L80 pipe. Unclear which is where in the string, but burst rating for K55 (assumed to be the 68ppf weight) is only 3450psi. The reported OA pressure (1860psi) represents 53.9% of MIYP. It is good that the well is shut in for turnaround, but according to CO 492, when SCP exceeds 45% you must also submit a 10-403 with corrective actions for Commission approval unless the well conditions require taking emergency action (does not appear to be the case here). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @bp.com] Sent: Monday, June 20, 2011 10:09 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Longden, Kaity Subject: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA All, Producer 09 -34A (PTD #1932010) was found to have sustained casing pressure on the OA. The tubing /IA/OA = SSV/1860/1860 on 6/18/2011. The well is currently shut in for turnaround activity and has been reclassified as Not Operable. The plan forward for diagnostics will be: 1. DHD: OA repressurization test 2. Wellhead: PPPOT -IC and Re- energize wellhead seals 3. DHD: Re -OA repressurization test 3. WIE: Evaluate for Seal -Tite treatment A TIO Plot and wellbore schematic are attached for reference: «09- 34A.pdf» «09 -34 TIO Plot.doc» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 6/23/2011 PBU 09 -34A PTD #1932010 6/23/2011 TIO Pressures Plot Welt 09-34 4,000 • 3,000 - —� — Tbg —u —IA 2.000 - — OA OOA On 1,000 f jIj(( 03/26111 04/02/11 04/00/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21/11 05/28/11 06/04/11 06/11/11 06/18 /11 NOT OPERABLE: Producer 09 -34A (D #1932010) Sustained Casing Pressuon OA Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) It Sent: Wednesday, June 22, 2011 1:31 PM l To: 'AK, D &C Well Integrity Coordinator' Cc: Schwartz, Guy L (DOA) Subject: RE: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA well schematic shows 13 -3/8" surface casing as a mixed string of K55 and L80 pipe. Unclear which is where in the string, but burst rating for K55 (assumed to be the 68ppf weight) is only 3450psi. The reported OA pressure (1860psi) represents 53.9% of MIYP. It is good that the well is shut in for turnaround, but according to CO 492, when SCP exceeds 45% you must also submit a 10 -403 with corrective actions for Commission approval unless the well conditions require taking emergency action (does not appear to be the case here). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 �� (� Anchorage, AK 99501 !° , `r } laths" , j u \ 2' l 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIllntegrityCoordinator ©bp.com] Sent: Monday, June 20, 2011 10:09 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Longden, Kaity Subject: NOT OPERABLE: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on OA All, Producer 09 -34A (PTD #1932010) was found to have sustained casing pressure on the OA. The tubing /IA/OA = SSV/1860/1860 on 6/18/2011. The well is currently shut in for turnaround activity and has been reclassified as Not Operable. The plan forward for diagnostics will be: 1. DHD: OA repressurization test 2. Wellhead: PPPOT -IC and Re- energize wellhead seals OA 5CP 13 3. DHD: Re -OA repressurization test 3. WIE: Evaluate for Seal -Tite treatment 1C SS (� ? F Zp A TIO Plot and wellbore schematic are attached for reference: «09- 34A.pdf» «09 -34 TIO Plot.doc» 5CP Thank you, t M- (P= S3.`j �� s Mehreen Vazir 4.6t (c : -&j (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 6/22/2011 PBU 09-34A PTD # 1932010 6/20/2011 TIO Pressures Plot Well: 09-34 I 4500 3500 Tbg —u—IA 2 000 --a— OA 00A — 4-- 0004 On • 1,000 . - - - •••••• ''' 03/26/11 04/02/11 04/08/11 04/16/11 04123/11 04/30/11 05/07/11 05/14/11 05/21/11 05/28/11 06/04/11 06/11/11 06/18/11 • TREE = CAN VVELLHEAD = MCEVOY- • A" ° v --: " gl 1N c › • • ,7, . A etuA =7"---13Akai6 0 9 -3 4 A '4 - - a ME TBG & 5 CHROME LNR KB. ELEV = 55'" BF. ELEV = 7 1 I KOP -- --- 3093 11 1 0. Max Angle = 94° @ -1184 20" CONDCTR, MEM if 14 Datum MD = 11064' 9 F.L.40, 4 • 2011' H4-1/2" HES X NIP, ID = 3.813" 1 t Datum TVD = 8800' SS v F A ID = 19.124" N # 9-5/8" CSG, 47#, L-80 HYD-563 2095' f , '4 I' 1 212T I HES ES CEMENTER 1 0 0,1 XO TO L-80 BTC x -,,,,v, 4,ssiw p", 7 4 2150' H9-5/8" BKR ECP . 1 19-5/8" CSG, 47#, L-80 BTC, ID = 8.681" I — I 2183' C 19 BOWEN CSG PATCH H 218T GAS LIFT MANDRELS Eff MO TVD DEV TYPE VLV LATCH PORT DATE 13-3/8" CSG, 68#172#, K-55/L-80 BTC, — 2512' IP 4 3460 3444 18 WAG DOME RK 16 03/07109 ID = 12.347" 3 6213 5390 51 IVIAG DOME RK 16 03/07/09 Minimum ID = 3.725" @ 10760' " 2 7791 6377 54 WAG DOME RK 16 03/07/09 1 9119 7177 52 KBMG SO BK 28 08/18/10 (e 755) - - 4-1/2" OTIS XN NIPPLE • L 8940' HT BKR PKR w /PBR ECT & LNR HGR ASSY, ID = 6.875" 1 olf7 t , 74„-or 1 ! TOP OF 7-5/8" LNR H 8968' I w I 9188' —14-1/2" FIF_S X NIP, ID 3.813" „ I 6 5 7 Cr'; 11111 9-5/8” CSG, 47#, L-80, ID = 8.681" 9198' 9209' J X 41/2" BKR PKR PREM PKR, ID = 3.875" 1--I 4 V'. &ICI ■T:1 A ■ 9245' —14-1/2" HES X NIP, D = 3.813" 1 4 imi. ■4 It, e . s 10655' 1--17 X 4-1/T UNIQUE OVERSHOT I *S 44 -- 1 41/2" TBG, 12.6#, 13CR VAM TOP, --I 10653' #., iA 10694' 14 OTIS X NIP, ID = 3.813" '• Vf .0152 bpf, ID= 3.958" /#00 l 10715' 117-518" X 41(2" BKR SABL-3 PKR 1 Yl.c W/KBH-22 ANCHOR, ID --; 3.875" 14-1/T TBG STUB (02)15/09) I 10662' 1141'4 \ 444 4* s Siar4A 4 • 4444 10739' 1-1411T 0115 X NIP, ID = 3.813" 1 ,,,,& ........ vp- ......... 10760' H4-1/2" OBS XN NIP, ID = 3,725" 1 t A.40404tt, I ■ AvAvA •••■■■■■WAvi 'BAKER K-1 BRIDGE PLUG 1-1 9450' «« - W, ID = 3.958" 1 .../1111111111..- • 'W ...„, I 1-1ELMD TT NOT LOGGED 1 4-1/2" 1BG-PC, 12.6#, 13CR, NSCT, ID = 3.958" H 10772' '#) 'TOP OF 5-1/2" LNR H 10774' 1 7-5/8" LNR, 29.7#, L-80, STL, ID = 6.875" H 10961' \ PERFORATION SUMMARY REF LOG: BHCS ON 03/06/94 ANGLE AT TOP PERF: 64° @ 11138' 1 \ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Scp DATE MILLOUT WIsIDOW (09-34A) 9180' - 8231' 1 \ 2-7/8" 6 11138 - 11146 0 04/15/02 3-3/8" 6 11750 - 11910 0 04/02/94 3-3/8" 6 11950 - 12200 0 04/02/94 3-3/8" 6 12230 - 12420 0 04/02/94 3-3/8" 12 12440 - 12565 0 04/04/94 I PBTD I 12588' . At Iti, N% [5-1/2" LNR, 17#, 13CR NSCC, .0232 bpf, ID = 4.892" H 12630' DATE 'REV BY COMMENTS DATE REV BY COMMENTS PRUDI-IOE BAY UNfT 06/10/85 ROWAN35 ORIGINAL COMPLETION 04115/10 DB/JMD DRLG DRAFT CORRECTIONS WELL: 09-34A - 1 04/04/94 N2ES SIDETRACKED (09-34A) 08/25/10 GJF/AGR GLV C/O (08/18/10) PERMfT No: 9 932010 02/27/09 Al4ES RWO AR No: 50-029-21329-01 03/02/09 PJC DRLG CORRECTIONS SEC 2, T1ON, R15E 1763' FSL & 1036' FEL 03/23/09 /SV GLV C/O (03/19/09) - 06/01/09 SWC/TLH PXN PLUG PULLED (04/07/09) _ BP Exploration (Alaska) OPERABLE: Producer 09 -34A (PTD #42010) IAxOA comm manageable Page 1 Regg, James B (DOA) • From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, January 27, 2011 9:04 PM + To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr Cc: Walker, Greg (D &C); Longden, Kaity Subject: OPERABLE: Producer 09 -34A (PTD #1932010) IAxOA comm manageable Attachments: 09 -34A TIO Plot 01- 27- 11.doc All, Well 09 -34A (PTD #1932010) passed a pack -off test on the inner casing on 01/20/11 after the OA was reported to have sustained casing pressure. The well was then placed on production and an OA repressurization test performed to evaluate the IAxOA communication. The OART showed a 0 psi build- up -rate over an 8 day monitor. The well has been reclassified as Operable and may continue on production. A TIO plot has been included for reference. «09 -34A TIO Plot 01- 27- 11.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) MiNED FEB 1 201r Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, January 18, 2011 11:18 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wirelin- operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, e FS2 OSS; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; Longden, Kaity; Holt, Ryan P (ASRC); AK, D& ell Integrity Coordinator Subject: UNDER EVALUATION: Producer 09 -34A (PTD #19 .10) Sustained Casing Pressure on the OA - POP to eval IAxOA comm All, Artificially lifted producer 09 -34A (PTD 1932010) was classified as Not Operable during the shut down due to sustained casing pressure o• he OA. The wellhead pressures were tubing /IA/OA equal to SSV/1940/1740 psi on 01/13/21 . The well has been reclassified as Under Evaluation so that it may be placed on production to pert• m diagnostics. Please notify Well Integrity prior to placing the well on production as DHD will - -d to be on location to monitor the OA repressurization during start up. 1/28/2011 PBU 09 -34A PTD 1932010 1/27/2011 TIO Pressures Plot Well: 09 -34 4,000 • 3,000 - I —F Tbg —F IA 2,000 - —4— OA 00A ••■Dn t000 - • • • 11/27/10 12/04/10 12/11/10 12)18/10 12,125/10 01/01/11 01/08/11 01/15/11 01/22/11 UNDER EVALUATION: Producer 09-41y. (PTD #1932010) Sustained Casing *sure on the ... Page 1 pet Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Tuesday, January 18, 2011 11:18 AM 'gdet.1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; Longden, Kaity; Holt, Ryan P (ASRC); AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer 09 -34A (PTD #1932010) Sustained Casing Pressure on the OA - POP to eval IAxOA comm Attachments: 09 -34A TIO Plot 01- 18- 11.doc; 09- 34A.pdf All, Artificially lifted producer 09 -34A (PTD # 1932010) was classified as Not Operable during the shut down due to sustained casing pressure on the OA. The wellhead pressures were tubing /IA/OA equal to SSV/1940/1740 psi on 01/13/2011. The well has been reclassified as Under Evaluation so that it may be placed on production to perform diagnostics. Please notify Well Integrity prior to placing the well on production as DHD will need to be on location to monitor the OA repressurization during start up. The plan forward is as follows: 1. W: PPPOT -IC S L) FEB072O1 2. DHD: OART A TIO plot and wellbore schematic have been included for reference. «09 -34A TIO Plot 01- 18- 11.doc» «09- 34A.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, January 14, 2011 10:34 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, • (DOA)'; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; A i &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS F. OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OP C3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OP C2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OP. ell Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; A • ES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Ki s, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christo► er; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustain G casing pressure on IA and OA due to proration All, 1/25/2011 PBU 09 -34A PTD 1932010 1/18/2011 TIO Pressures Plot Well: 09 -34 4.000 3,000 • — Tbg —•— IA 2.000 -A-- OA 004 T 000A On 1 ..000 - #1i A _ 1 10/23/10 11108/10 11/20/10 12/04/10 12/18/10 01/01/11 01/15/11 • TREE = CM/ • WELLHEAD = MCEVOY , SAFETY N WELL ANGLE> 700 a:, 11212'. ACTUATOR = BAKER C .4-1/2" C ME TBG & 5-1/2" CHROME LNR*** I ' KB. ELEV = 5 09-34A BF, ELEV = KOP = 3093' �� 11 Max Angle = 94° @ 12184' 20" coNDCTR, � • Datum MD = 11064' 91 H-40, • i 1 201V1 FES X NIP, ID = 3.813" 1 Datum TVD = 8800' SS' N A 1 ID =19.124" P. ',I ti 4 9 -5 /8" CSG, 47 #, L -80 HYD-563 2095' r • 2127' I -19 -5/8" HES ES CEMENTER , XO TO L -80 BTC If . iA 2150' 9 -5/8" BKR ECP 19-5/8" CSG, 47 #, L -80 BTC, ID = 8.681" H 2183' I I9 -5/8" BOWEN CSG PATCH H 218T GAS LIFT MANDRELS M ST MD TVDIDEV TYPE , VLV LATCH PORT DATE 13-3/8" CSG, 68#/72#, K- 55 /L -80 BTC, 2512' In 4 3460 3444 18 MMG DOME RK 16 03/07/09 ID = 12.347" 3 6213 5390 51 MMG DOME RK 16 03/07/09 2 7791 6377 54 MMG DOME RK 16 03/07/09 Minimum ID = 3.725" @ 10760' 1 9119 7177 52 KBMG I SO BK 28 08/18/10 4 -1/2" OTIS XN NIPPLE I 8940' 1-17" BKR PKR w /PBR EXT & LNR HGR ASSY, ID = 6.875" I [TOP OF 7-5/8" LNR I 8968' 1.1 0 9188' 1-141 /2" HES X NIP, ID = 3.813" I '- 9-5/8" CSG, 47 #, L-80, ID = 8.681" H 9198' Q vi 9209' 7-5/8" X 4-1/2" BKR PKR PREM PKR, ID = 3.875 1� �� o A 9245' —{ 4-1 /2" HES X NIP, ID = 3.813" 1 `0 11 10655' I X 41/2" UNIQUE OVERSHOT I • 41/2" TBG, 12.641, 13CR -80 VAM TOP, 10653' ,4,4 10694' — OTIS X NIP, ID = 3.813" I 'cot 0152 bpf, D = 3.958" 111• 1 10715 1— 7 -5/8" X 4-1/2" BKR SABL -3 PKR dii 111 <'11�1 1 h `— `, W/KBH -22 ANCHOR, ID = 3.875" 1 ' 1 ' �11 14-1l2" TBG STUB (02/15109) H 10662' ♦11 v� 114144 ♦ 10739 - 1 4112 OTIS X NIP, ID = 3 813" 11141111 ,i■ 111 11 1 444 1 �� ' 10760' 41/2" OTIS XN NIP, ID = 3.725" 11141 BAKER K -1 BRIDGE PLUG 9450' + 1 �,a 1 A 1 4 � 1 � H - 10772' { 4-1 /2" WLEG, ID = 3.958" I ■ I I- IELMD TT NOT LOGGED I 41/7' TBG -PC, 12.6#, 13CR, NSCT, ID = 3.958" H 10772' ' [TOP OF 5 -1 LNR H 10774' 1 7-5/8" LNR, 29.7 #, L-80, STL, ID = 6.875" 1-1 10961' PERFORATION SUMMARY REF LOG: BHCS ON 03/06/94 ANGLE AT TOP PERF: 64° Q 11138' \ Note: Refer to Production DB for historical perf data {{ SIZE SPF INTERVAL Opn /Sqz 1 DATE ti/LOUT WINDOW (09 -34A) 9180' - 6231' 2 -7/8" 6 11138 - 11146 0 04/15/02 3 -3/8" 6 11750 11910 0 04/02/94 3 -3/8" 6 11950 - 12200 0 04/02/94 3-3/8" 6 12230 - 12420 0 04/02/94 3-3/8" 12 12440 - 12565 0 04/04/94 I PBTD I 12588' 4 \ ; ' 1.11,• 1 5-1/2" LNR, 171f, 13CR, NSCC, 0232 bpf, ID = 4,892" 12630' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfl 06/10/85 ROWAN35 ORIGINAL COMPLETION 04/15/10 " DB /JMD DRLG DRAFT CORRECTIONS WELL 09-34A 04/04/94 N2ES (09 -34A) 08/25/10 GJF /AGR GLV C/O (08 /18/10) PERMIT No 'i932010 02/27/09 N4ES RWO API No 50-029-21329-01 03/02/09 PJC DRLG CORRECTIONS SEC 2, T10N, RISE 1763' FSL & 1036' FEL 03/23/09 /SV GLV C/O (03/19/09) 06/01/09 SWCITLH PXN PLUG PULLED (04/07 /09) BP Exploration (Alaska) • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Friday, January 14, 2011 10:34 PM 11 1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570) C -15A (PTD #2090520) E -17A (PTD #2042040) E -27A (PTD #1990590) F -04B (PTD #2100870) W -01A (PTD #2031760) W -16A (PTD #2031000) W -21A (PTD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. /69 -34A (PTD #1932010 Y -2 • D #1• • 1 N -22B (PTD #2061610) All the wells listed above will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start-up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 STATE OF ALASKA A~ OIL AND GAS CONSERVATION COf~SION REPORT OF SUNDRY WELL OPERATIONS ~` ~ ~~6~I EC)~a~-o9 ~,~:~~? ~ ~ 2.~D9 ~a'eSfA ~i has Cons. COmmissi0n 1. Operations Performed: QgChOtagB ^ Abandon ®Repair Well , ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ®Alter Casing ®Pull Tubing _ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 193-201 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21329-01-00- 7. KB Elevation (tt): -".~ 48 26' - 9. Well Name and Number: PBU 09-34A - 8. Property Designation: 10. Field /Pool(s): ADL028324 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 12630'- feet true vertical 8979' - feet Plugs (measured) 10760' Effective depth: measured 12588' feet Junk (measured) None true vertical 8975' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1490 470 Surface 2512' 13-3/8" 2512' 2512' 3450 / 4930 1950 / 2670 Intermediate Production 9198' 9-5/8" 9198' 7227' 6870 4760 Liner 2021' 7-5/8" 8940' - 10961' 7065' - 8783' 6890 4790 Liner 1856' 5-1/2" ' 7740 6280 8648' - 897 10774' - 1 2 6 30' 9 hh pp~~ ~~yy ~ yi ~ ~} Perforation Depth MD (ft): 11138' - 12565' Perforation Depth TVD (ft): 8886' - 8972' 4-1/2", 12.6# 13Cr80 10772' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x4-1/2" Baker Premier packer; 9209'; 7-5/8" x 4-1/2" Baker'SABL-3' Packer 10716' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~`` S ~ ~' ` ~~ Treatment description including volumes used and final pressure: Set PXN Plug at 10760'. Cut, pull and mill 4-1/2".tubing to 10662'. Cut, pull and dress 9-5/8" casing to -2183'. Run 9-5/8" (47#, L -80 tieback to 2187'. Cement with 150 Bbls GasBlok 1.17 field . Run new Chrome tubin to 10655'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil- ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 308-455 Printed Name Terris Hubble Title Drilling Technologist Prepared By Name/Num~r. L~ Signature Phone 564-4628 Date Terris Hubble 564-4628 Form 10-404 Revised 04/2006 {~A,(1~ ~> r ~"'") f ~ Submit Original Only !/5" 1. "~ "`/~ s 09-34A, Well History (Pre Rig Workover) Date Summary 01/05/09 T/I/0= 1910/1970/450. Temp= SI. T & IA FL (pre-slickline). TBG FL @ 8020' (above sta # 3). IA FL @ 10438' (above sta # 7, s/o). SV, W V = C. SSV, MV = O. IA, OA = OTG. NOVP. 01/06/09 WELL S/I ON ARRIVAL. BRUSHED XN NIPPLE @ 10760' MD. SET 4 1/2" PXN PLUG BODY @ 10760' MD. 01/07/09 RUN 4 1/2" CHECK SET TO CONFIRM PXN-PLUG BODY SET @ 10,760' MD'. (GOOD SET) SET P-PRONG @ 10,760' MD. PERFORM DRAW DOWN TEST ON PXN-PLUG @ 10760' MD. (PASS) ATTEMPT TO SET 4 1/2"JUNK CATCHER ON PXN-PLUG @ 10760' MD. 01/07/09 T/I/0=200/1050/480 Temp=S/I. Assist S-Line F-Protect F-Line Load TBG( RWO) Spear in to F-Line w/5 bblsof meth followed by 53 bbls of 120° crude. Shut IGV psi up to 1500 psi w/2 bbls of meth. Pumped 5 bbls of meth down TBG followed by 108 bbls of 120° crude. Final Whp's =vac / 1000 / 480. Wing shut, swab shut, SSV open, casing valves open to gauges. 01/08/09 SET 4 1/2" JUNK CATCHER @ 10718' SLM. WELL LEFT S/I, DSO NOTIFIED. 01/08/09 T/I/0= 0+/1550/450. Temp= SI. T & IA FL (post-slickline). AL connected w/ 1550 psi. T FL @ 132' (3 bbls). IA FL @ 10366' (sta # 6, 555 bbls). SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 01/16/09 T/I/0= 0/1550/500 Temp= SI CMIT-TxIA to 3500psi (Pre RWO). CMIT- TxIA to 3500nsi FAI D.. Pumped 3 bbl Neat meth spear followed by a total of 900 bbls down IA and up Tbg to fluid pack. LLR of 3 BPM @ 1600 psi. Pumped 3 bbl Neat meth spear folowed by 52 bbls 120° crude capped with 4 bbls Neat meth down Flowline to freeze protect. FWHP's = 1000/250/580. Annulus casing valves tagged and left open to gauges. Swab shut, Wing shut, SSV open, Master open. 01/19/09 T/I/0=950/200/500 Assist S/L w/ Petradat LDL (RWO). Pumped 150 bbls crude down the TBG while slickline made logging passes. Pump 3 bbls crude down TBG to presure up for SL to set flowsleeve. Bled TP back down. Valve positions upon departure: WV =Closed, Pit valve =open; SV, MV, SSV = SL control; IA, OA = OTG. SL on well upon LRS departure, operator notified. FWHP's = 150/200/500. 01/19/09 WELL S/I ON ARRIVAL. RAN 3.57" CENT & TAGGED 4-1/2" JUNK CATCHER @ 10741' SLM W/ NO RESTRICTIONS. RAN 2.13" CENT., PDS STP LDL TOOL FROM 10741' SLM TO SURFACE PER PROGRAM. RECEIVED DATA PER PDS REP. LRS PUMPED 160 BBLS CRUDE FOR LDL. LOCKED OUT TRDP -4A SSSV @ 2072' SLM. (RAN 3.84" NO-GO, 5' x 1 1/4" STEM & FLAPPER CHECKER TO VERIFY TRDP LOCKED OUT). CURRENTLY IN HOLE WITH 4 1/2" GS. 01/20/09 PULLED JUNK CATCHER FROM 10738' SLM. PULLED P-PRONG FROM 10746' SLM. PULLED PXN PLUG BODY FROM 10752' SLM. RAN 4-1/2" BLB, 3.625" GAUGE RING BRUSHED XN NIPPLE. SET & PULLED 4-1/2" CAT STANDING VALVE TO 10750' SLM. TESTED TO 2000psi. (good test). SET 4- 1/2" PXN PLUG BODY @ 10753' SLM SET P-PRONG @ 10748' SLM. CURRENTLY RUNNING 4 1/2" GS, 4 1/2" JUNK CATCHER. 01/20/09 T/I/0=300/200/500 Assist SLB w/ CMIT Tx IA to 3500 psi. (Pre RWO) Pumped 11.7 bbls crude down TBG to pressure up to 2000 psi. Pumped 13.7 bbls down IA to pressure up T X IA to 3000 psi to confirm prong set for SL. 01/21/09 CMIT TxIA PASSED to 3500 psi (Pre RWO) _Pumped 15.1 bbls crude down IA to reach test pressure. T/IA lost 10/20 in the 1st 15 mins and 10/0 psi in the 2nd 15 mins for a total pressure loss of 20/20 psi in 30 mins. Bled back (-15 bbls). FWHP's = 200/200/500. Valve positions upon departure: SV, WV = Closed. SSV, MV =Open. IA, OA = OTG. slickline on well upon LRS departure. 01/21/09 SET 4 1/2" JUNK CATCHER @ 10737' SLM. PERFORMED CMIT-TxIA (PASS). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 01/22/09 CONTINUE RIGGING UP E-LINE. RIH WITH OD = 3.65" POWER CUTTER. TOOL LENGTH = 16'. CUT TUBING AT 10664' CORRELATED TO TUBING TALLY DATED 4/3/94. DSO NOTIFIED OF VALVE POSITIONS ON DEPARTURE. FINAL T/I/O = 800/800/500. WELL LSHUT-IN ON DEPARTURE. Page 1 of 2 09-34A, Well History (Pre Rig Workover) Date Summary 01/23/09 T/I/0=800/850/500 Temp=S/I (flowline=250 psi) CMIT TxIA PASSED to 3500 psi,~Circ Well (RWO prep) Pumped 1 bbl meth, 11 bbls crude down Tbg to pressure up for CMIT TxIA. T/IA lost 50/20 psi in the 1st 15 mins and 30/30 psi in the 2nd 15 mins for a total pressure loss of 80/50 psi in 30 mins. Bumped TxIA to test pressure with 0.2 bbls crude. T/IA lost 20/20 psi in the 1st 15 mins and 0/0 psi in the 2nd 15 mins for a total pressure loss of 20/20 psi in 30 min test. Bled TxIA to -500 psi. Pumped 10 bbls neat meth, 1057 bbls 3% KCI, 0.5 bbls neat meth, 150 bbls 110°F diesel, 0.5 bbls neat meth down Tbg to circ well taking returns up IA & down flowline. U-tube TxIA for - 1 hour. Freeze protect hardline with 2 bbls diesel. Freeze protect flowline with 5 bbls neat, 43 bbls crude, 10 bbls diesel. MIT OA: Bled OAP down from 540 psi to 10 psi in 105 min (all gas). Pumped 22.7 bbls crude down OA to reach test pressure. OA lost 100 psi in the 1st 15 mins and 60 psi in the 2nd 15 mins. MITOA continued. 01/24/09 MIT-OA FAILED to 2000 psi (RWO prep) MIT-OA 3rd test, OA lost 40 psi in the 1st 15 mins, 40 psi in the 2nd 15 mins, 40 psi in the 3rd 15 mins and 30 psi in the 4th 15 mins for a total pressure loss of 150 psi in 60 min test. Bled OA (--2.2 bbls). Bled TP and IAP (-0.6 bbls). DSO notified of valve postions upon departure: SV, WV, CV =closed. MV, SSV =open. IA, OA = OTG. FWHP'S = 0/0/0 01/26/09 T/I/O=SSV/200/100, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: External check installed. Stung into test port (0 psi). Functioned LDS, 2 were tight but moving, the rest moved freely (2"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: External check installed. Stung into test port (200 psi), unable to bleed to 0 psi (diesel). Functioned LDS, all moved freely (2.5"), still unable to bleed void. RU to PKG port, pumped 2.5 J sticks (plastic) to re-energize secondary Y seal. Bled void to 0 psi. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 01/27/09 T/I/O 250/200/0 Set 4 1/16"' H CIW RPV 1-?' axt used tagged Q 104, no problems. Final T/I/O 0/0/0. Page 2 of 2 BP EXPLORATION Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To ~, Hours ~ Task Code NPT 2/4/2009 06:00 - 10:00 4.00 RIGD P 10:00 - 11:30 1.50 MOB N WAIT 11:30 - 12:00 0.50 MOB P 12:00 - 00:00 12.00 MOB P 2/5/2009 00:00 - 07:00 7.00 MOB P 07:00 - 13:00 6.00 MOB P 13:00 - 16:30 3.50 KILL P 16:30 - 17:30 1.00 WHSUR P 17:30 - 18:00 I 0.501 WHSUR I P 18:00 - 18:30 I 0.501 WHSUR I P 18:30 - 20:30 I 2.001 WHSUR I P 20:30 - 21:30 I 1.001 WHSUR I P 21:30 - 23:00 I 1.501 WHSUR I P 23:00 - 23:30 0.50 WHSUR P 23:30 - 00:00 0.50 WHSUR P 2/6/2009 100:00 - 01:30 I 1.501 WHSUR I P 01:30 - 04:00 2.501 WHSUR P 04:00 - 04:30 0.50 BOPSUF~ P 04:30 - 09:30 5.00 BOPSU P 09:30 - 11:00 1.50 BOPSU P 11:00 - 16:30 5.50 BOPSU P 17:00 - 17:30 I 0.501 WHSUR I P 17:30 - 18:00 0.50 WHSUR N 18:00 - 19:00 1.00 WHSUR P 19:00 - 20:00 I 1.001 PULL I P WAIT Start: 1 /30/2009 Rig Release: 2/27/2009 Rig Number: Phase PRE PRE PRE PRE PRE PRE Page 1 of 14 Spud Date: 5/15/1985 End: 2/27/2009 Description of Operations Scope down and lay over derrick. Wait on trucks to move rig. PJSM -Rig move safety reviewed with all rig crew and trucking company personnel. Move rig and components from R pad to DS 09-34A. Move rig and components from R pad to DS 09-34A. MIRU on 09-34A. Spot sub, pits and pipe shed. Spot satellite camp and establish communications. Raise and scope derrick. DECOMP Rig up lines and hookup to tree and IA. DECOMP PJSM -Review pulling BPV procedure with all crew and Valve Shop personnel. PUMU lubricator to swab valve. P/T DECOMP P/T lines to 3500-psi.Thaw out tiger Tank line prior to pressure testing. DECOMP Hold Pre-Spud meeting w/all hands. Review kill procedure & assign specfic tasks to personnel. DECOMP O en well. SITP = 0 si SIAP = 0 si. Circulate well & displace out diesel freeze protect fluid. Pump 4 1/2" BPM @ 550 psi. CP = 210 psi. S/D after 400 bbls to pull fluid from Tiger tank. DECOMP Thaw out Tiger Tank Riser to Vac Truck. Suck out 275 bbls from tiger Tank. DECOMP Con't to circulate well. Pump 5 BPM C«3 600 psi. CP 210 psi. S/D after 680 bbls. TP = 0 psi, CP = 0 psi. Pumped total of 680 bbls. Recovered 110 bbls of diesel in Tiger Tank. Sucked out remaining 290 bbls of seawater. DECOMP Monitor well for 30 min. Well dead. DECOMP Install TWC. Pressure test from below to 1000 psi, OK. DECOMP Con't to test TWC from top to 3500 Bad swab & wing valves. Charted t~ DECOMP Bleed off hanger void. & drain tree. N/D tree. 2 Barriers - PXN plug C~ 10760' &TWC in wellhead. Remove & snub tree out of cellar. Check threads in hanger. Had 7 1/2 rounds in 4 1/2" TDS hanger threads. Threads good. DECOMP Re-level rig. Prep well head & Check LDS. DECOMP N/U BOPE & Incorporate new "Dutch Lubricator Lockdown System". DECOMP Service choke manifold and makeup/rigup test equipment. DECOMP Pressure test BOPS er BP/AOGCC requirement to 250-psi Lo/3500-psi Hi. Tested choke manifold, HCR kill and HCR choke valves, blind/shear rams, 3-1/2" x 6" VBR's, test spool valve, TIW floor valve, upper and lower kelly valves, IBOP, annular preventer and Koomey. Tested VBR's with 3-1/2" and 4-1/2" test joints and tested annular with 3-1/2" test joint. DECOMP P/U Dutch lubricator lockdown mandrel w/extension land in lockdown flange. Run in lockdown pins and close annular preventer. DECOMP Wailt on DSM to arrive to pull TWC. DECOMP P/U & R/U lubricator. Pressure test to 500 psi, OK, Pull TWC. DECOMP ~ R/U floor & handling tools for 4 1/2" completion. R/U Spooling Printed: 3/6/2009 1:42:58 PM BP EXPLORATION Page 2 of 14 Operations Summary Report .Legal Well Name: 09-34 '.Common Well Name: 09-34 Spud Date: 5/15/1985 'Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 'Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: Date I'~ From - To ' NPT Phase Description of Operations Hours Task Code 2/6/2009 19:00 - 20:00 1.00 PULL P DECOMP unit. 20:00 - 21:00 1.00 PULL P DECOMP P/U & M/U landing jt. Tighten X-overs & TIW valve. BOLDS. Pull han er to floor. Pulled free w/ 160K. Wt dro ed off to 120K while pulling to floor. 21:00 - 22:00 1.00 PULL P DECOMP UD landing jt. Break out hanger & control line. R/U circulating pin. 22:00 - 23:00 1.00 PULL P DECOMP Reverse circulate 2 bottoms up. Pumped 5 1/2 BPM C~3 440 psi. Pumped total of 340 bbls. No GTS, No losses. Finish R/U floor & connect control line to spooler. 23:00 - 00:00 1.00 PULL P DECOMP POOH & UD 4 1/2" 12.6#, 13Cr-80 NSCT completion. Spool up SS control line. OOH w/ 20 jts. 2/7/2009 00:00 - 01:30 1.50 PULL P DECOMP Con't to POOH & UD 4 1/2" 12.6#, 13Cr-80, NSCT tubing. Recovered 52 jts, + 1 SSSV & 56 SS bands. 01:30 - 02:00 0.50 PULL P DECOMP Norm SS control lines, OK. R/U control line spooling unit & remove from rig floor. 02:00 - 09:00 7.00 PULL P DECOMP Con't to POOH & UD 4 1/2" 12.6# 13Cr-80, NSCT completion. recovered 268 jts. 4-1/2" 12.6#, 13Cr80 NSCT tubing, 7 ea. 4-1/2" x 1-1/2" GLM's. 1 ea. Cameo TRDP-4A SSSV, 26 ea. S/S bands and cut jt. Cut jt. length = 19' and flare O.D. _ 4-5/8". 4-1/2" tubing stub left looking up = 20.48'. No fluid losses in excess of i e dis lacement Burin TOH. 09:00 - 11:00 2.00 PULL P DECOMP PJSM -Review rigging down 4-1/2" tubing handling equipment and tools. Clear and clean rig floor. Rigged down 4-1/2" tubing handling tools and equipment. 11:00 - 13:00 2.00 EVAL N WAIT DECOMP Wait on SWS E-Line crew and equipment to arrive. 13:00 - 13:30 0.50 EVAL P DECOMP PJSM -review rigging up E-Line tools and equipment procedure. Identified hazards and assigned tasks to personnel. 13:30 - 15:00 1.50 EVAL P DECOMP Spot E-Line unit. Rigged up E-Line tools and equipment with air line wiper to run USIT log. Downhole barrier in place - "PXN" plug in "XN" nipple at 10,760'. 15:00 - 19:00 4.00 EVAL P DECOMP Ran USIT Log from 3000' to surface in cement/corrosion mode. Identified TOC C~ 2236'. Targeted 9-5/8" casing cut to be at .2182' -middle of second full joint above TOC. Located collars ~ 2162', 2202' & 2243'. E-mailed copy of log to town engineer. Plan to set RBP ~ +/-2300'. (collar ~ 2282') 19:00 - 20:00 1.00 WHSUR P DECOMP R/D SWS equip. Install Wear Bushing. Ran in 2 lock down screws. 20:00 - 23:30 3.50 CASE P TIE61 P/U & M/U RBP - P/U 9 - 4 3/4" DCs. RIH on 3 1/2" DP (1 x1 ). RIH w/ 64 jts. 23:30 - 00:00 0.50 CASE P TIEB1 P/U 24' DP pup. Space out & set RBP. COE ~ 2307' Too of RBP ~ 2302'. P/U wt = 52K, S/O Wt = 52K Set plug w/ 20K down wt. re-tagged plug to verify set. 2/8/2009 00:00 - 00:30 0.50 CASE P TIEB1 R/U & ressure test RBP to 1000 si for 10 min. C same. Good test. 00:30 - 03:30 3.00 CASE P TIEB1 Pull & UD DP pup, +2 singles. R/U & dump 2200# of 20-40 sand down DP. Pull 1 stand. Dispiace sand w/ 16 bbls of seawater. Allow sand to fall & settle for 1 hr. P/U DP, RIH & tag _ sand ~ 2250' 52' of sand on to of RBP . 03:30 - 04:30 1.00 CASE P TIEB1 Take on 9.8 ppg Brine & displace hole w/ 155 bbls of 9.8 ppg Printed: 3/6/2009 1:42:58 PM BP EXPLORATION Page 3 of 14 ' Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABORS 4ES Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 2/8/2009 03:30 - 04:30 1.00 CASE P TIEB1 Brine. Pump 5.5 BPM A 550 psi. 04:30 - 06:00 1.50 CASE P TIEB1 R/D circulating equip & excess singles. POOH & stand back 30 06:00 - 06:30 0.50 ~ CASE ~ P ~ ~ TIEB1 06:30 - 07:00 0.50 FISH P TIEB1 07:00 - 08:00 1.00 FISH P TIEB1 08:00 - 08:30 0.50 FISH P TIEB1 08:30 - 09:00 0.50 FISH P TIEB1 09:00 - 12:00 3.00 FISH N WAIT TIEB1 12:00 - 13:00 1.00 FISH P TIEB1 13:00 - 15:30 ~ 2.50 (FISH ~ P 15:30 - 16:30 1.00 FISH P 16:30 - 17:30 1.00 FISH P 17:30 - 18:30 1.00 FISH P 18:30 - 19:00 0.50 FISH P 19:00 - 21:00 I 2.001 FISH I P 21:00 - 23:00 ~ 2.00 ~ FISH ~ P 23:00 - 00:00 I 1.001 FISH I P TIEB1 TIE61 TIEB1 TIE61 TIEBi TIEB1 stands of 3 1/2" DP. Break out & UD RBP setting tool. PTSM w/day crew. PTSM. Service rig -check PVT's, grease drawworks, blocks and crown, environmental walkaround. PJSM -review making up BHA procedure. Bring BHA parts to floor. MU casing cutter BHA as follows: 8-1/4" Multi-String Cutter, XO, 7-1/4" Stabilizer, XO & 9 x 4-3/4" drill collars = 288.15'. RIH w/BHA #1 on 3-1/2" 15.5#, Grade "E" IF drillpipe from derrick. PU 24' 3-1/2" drillpipe pup and make up cement line hose with TIW valve. Establish circulation and mechanically locate casing collar at 2203'. POH UD 24' pup and 1 jt. drillpipe. Kelly up and circulate w/120F 9.8-ppg brine while waiting for LRS to arrive. Wait on LRS to arrive. Circulate 9-.8-ppg 120E brine to warm hole. Spot casing cutter. Establish cutting parameters - PUW = 50K, SOW = 50K, Rotating Wt. = 52K, RPM = 60, Torque = 60 Amps.,, Cut casing at 2182'. Cutter stalled out during cutting ops indicating cutter knives through pipe. Shut down and pulled cutter free. Resumed pumping to open cutter knives and located previous cut and rotated until cutter stalled again. Released torque and worked cutter up through cut with 35K overpull. MIRU LRS. PJSM -Review hot oil pumping operations. LRS P/T lines to 3000-psi. Spot 15-bbls. heated diesel to cutter. Closed annular preventer. Static O/A pressure before pumping = 200-psi. Bled O/A off to open top tank. Pressured up O/A to 2000-psi. Bled off slowly to 1000-psi with trickle of diesel/crude returns to open top tank. Repeated pressuring up O/A to 2000-psi with bleed off to 1000-psi 5 times with no increase in returns. Shut down LRS and suck back lines. Reverse 15-bbls. diesel from drillpipe to open top tank. Rig down/blow down circulating lines. POH w/casing cutter BHA #1 standing DP and DC's in derrick. Break out & UD BHA #1, cutting assy. BOLDS & pull Wear Bushing. Spear casing. Close in annular & P/U on hanger -1'. Well startedU-tubing. Have returns out IA. Heat diesel & pump 115 bbls of 150 degree diesel down casing. Pumped 1 BPM & increased to 2 BPM @ 575 psi. Getting crude & gas returns to open top tank Took 444~b1s tQ TIE61 Pumped 40 bbl Hi-Vis pill w/ Safe-Surf-O & displaced diesel out into IA w/ 120 bbls of 9.8 ppg Brine. Allow diesel to soak & heat IA for 1 hr. Pumped 3 BPM @ 250 psi. Returns had some gas cutting & then stopped. Saw no Arctic Pac in returns. TIEB1 Circulate out diesel & pill to open top tank. Fluid came clean w/ no gas cutting. S/D. CP =0 psi & IAP = 0 psi. Open annular. Printed: 3/6/2009 1:42:58 PM • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ' Name: 0 ell Name: e: Name: , From - To 9-34 09-34 WORKO NABOB NABOB ,Hours VER S ALASK S 4ES Task DRI Code LING NPT Start 1 Rig Rig Phase Spud Date: 5/15/1985 : 1/30/2009 End: 2/27/2009 Release: 2/27/2009 Number: Description of Operations 2/9/2009 00:00 - 01:00 1.00 FISH P TIEB1 Monitor well. Hold Weekly Safety meeting w/ all hands. Reviewed Stop Cards, recent Safety Bulletins & rig safety culture. Re-affirmed rig safety goals. 01:00 - 03:00 2.00 FISH P TIEB1 R/U floor to UD casing. Pull hanger to floor. UD spear & hanger. Prep to UD casing. 03:00 - 06:00 3.00 FISH P TIEB1 POOH & UD 9 5/8" 47# L-80 BTC casin ;OOH w/ 12 jts. Re-leveled rig. 06:00 - 11:00 5.00 FISH P TIEB1 POOH & UD 9 5/8" 47#, L-80, BTC casing. Recovered 55 jts. 9-5/8" casing and cut jt. Cut jt. length = 20.11'. 11:00 - 14:00 3.00 FISH P TIEB1 Clear and clean rig floor. Rig down 9-5/8" casing handling tools and equipment. Rig up to handle BHA and 3-1/2" DP. 14:00 - 15:00 1.00 FISH P TIEB1 PJSM -review picking up/making up BHA procedure. PUMU 9-5/8" casing dress off BHA #2 as follows: 12-1/8" dress off shoe, 11-3/4" washpipe ext., 10" dress off mill, 11-3/4" washover boot basket, double pin sub, 9-5/8" Roto-Vert" casing scraper, bit sub, float sub, XO, 4-3/4" LBS and 9 x 4-3/4" drill collars = 310.56'. 15:00 - 16:00 1.00 FISH P TIEB1 RIH w/BHA #2 on 3-1/2" 15.5#, Grade "E" IF drillpipe from derrick. 16:00 - 17:30 1.50 FISH P TIEB1 Tag up 9-5/8" casing stub at 2182'. Kelly up and establish milling parameters: P/U wt. = 55K, S/O wt. = 53K, Rot wt. _ 52K, RPM = 60, Torque = 60 amps. Mill over and dress off casing stub to 2183'. 17:30 - 18:00 0.50 FISH P TIEB1 Circulate, Mix & pump 40 bbl Hi-Vis Safe-Surf-O pill around & clean hole. Pump 4 BPM C~ 1700 psi. Pumped total of 395 bbls. Had some Arctic Pac returns. 17:30 - 18:00 0.50 FISH P TIEB1 Blow down lines. Set back Kelly. start to POOH & stand back 3 1/2" DP. 18:00 - 18:30 0.50 FISH P TIEB1 Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 FISH P TIEB1 POOH & stand back 20 stands of 3 1/2" DP. 19:00 - 21:00 2.00 FISH P TIEB1 Stand back 3 stands of 4 3/4" DCs. Break out & UD BHA #2 (Millin Ass .Clear & clean rig floor. 21:00 - 22:30 1.50 CASE P TIEB1 R/D DP tools. R/U floor & equip to run 9 5/8" Tie-Back string. R/U torque Turn equip. 22:30 - 23:00 0.50 CASE P TIEB1 Hold PJSM & review Tie-Back running procedure. Assign tasks to specific personnel. 23:00 - 00:00 I 1.001 CASE I P I I TIEB1 2/10/2009 ~ 00:00 - 04:30 ~ 4.50 CASE ~ P 04:30 - 07:30 I 3.001 CASE I P 07:30 - 09:00 ~ 1.50 ~ CASE ~ P cementer & X-over jt. Baker Lok connections below Baker ECP. RIH w/ same. TIEB1 RIH w/ 9 5/8" Tie-Back 47# L-80 H d 563 casing. Torque turn connections to 15800 ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. Install 1 free floating centralizer on every jt, except last jt run. Ran total of 56 jts. TIEB1 En a e Bowen Casin Patch onto 9 "casin stub 2183' P/U Wt = 100K. S/O Wt = 100K. P/U 30K over & insure good bite. P/U & pull test casing to 250K. S/O to 100K. M/U X-over & Halliburton Cementing Head on X-O. Check space out to collar on Jt#55. TIEB1 PR Bowen casina patch to 1000-psi for 10-charted minutes. 2000-psi and held for 10-charted minutes to test casing. Bled pressure to 0-psi. Increased pressure to 2900-psi and sheared Printed: 3/6/2009 1:42:58 PM BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task j Code 1 NPT Phase Description of Operations _ 2/10/2009 07:30 - 09:00 1.50 CASE P TIE61 open ES Cementer with oood indication of shear. 09:00 - 12:00 3.00 CASE P TIE61 Circulate well for 80F returns. 12:00 - 14:00 2.00 CASE N WAIT TIE61 Wait on ambient temperature to climb above -40F. 14:00 - 15:00 1.00 CASE P TIEB1 Safety meeting with day crew to review recent spate of hand 15:00 - 18:00 I 3.001 CASE I P I I TIEB1 18:00 - 18:30 0.50 CASE P TIEB1 18:30 - 00:00 5.50 CASE N WAIT TIEB1 2/11/2009 100:00 - 14:30 I 14.501 CASE I N I WAIT I TIEB1 14:30 - 15:00 I 0.501 CASE I P 15:00 - 18:00 I 3.001 CEMT I P 18:00 - 18:30 0.50 CASE P 18:30 - 20:30 2.00 CASE P 20:30 - 22:30 I 2.001 CASE I P 22:30 - 00:00 I 1.501 CASE I P 2/12/2009 100:00 - 04:00 I 4.001 CASE I P 04:00 - 06:00 I 2.001 CASE I P 06:00 - 07:30 I 1.501 CASE I P TIE61 TIEB1 TIE61 TIE61 TIEB1 injuries and to discuss hand safety. MIRU Schlumberger cementers. Prepare BOP stack, tools and cellar to remove BOP stack. Prepare rig floor to remove cementing head and vac out 9-5/8" casing in preparation to cut casing. Crew change, service rig, set and test PVT's. Wait on ambient temperture to climb above -40F. Perform general rig service and cleaning. Temperture between -43F and -47F Wait on ambient temperture to climb above -40F to perform cement job on 9-5/8" tie-back. Perform general rig service and cleaning. Temperature between -43F and -47F. Temperature C~ 07:15-hrs. _ -44F, windchill = -69F. Temperature ~ 08:15-hrs. _ -40F, windchill = -70F. Temperature Q 09:15-hrs. _ -40F, windchill = -63F. Temperature ~ 10:15-hrs. _ -39F, windchill = -65F. 14:15-hrs. Temperature = -30F, windchill = -55F. PJSM -Review pumping cement procedure and identify hazards. Assign perseonnel to specific tasks and ensure each are aware of their duties. Pump 5-bbls. fresh water to warm lines. P/T lines - to pressure stall at 800-psi, hi pressure stall at 4500-psi. Bleed off pressure. Batch mix tub of cement. Pumped 150-Bbls. 15.8-ppq cement with q_a_s-blok at 4-6.5-bom. Shut down and dropped wiper plug. Displaced cement and bumped plug with 158-Bbls. 9.8-ppg brine at 4-6.0 bpm. ES cementer closed at 2000-psi. Increased pressure to 2500-psi and held for 2 minutes. Bled off pressure and recovered 1.125-Bbls. to tub. Recovered 18-Bbls. neat cement to open top tank. Cement in place at 17:00-hrs. UCA indicates 11.0-hrs. to reach 500-psi. Closed annular preventer. Blew down lines and circulated through kill line to wash out O/A valve to open top tank. RDMO Schlumberger cementers. R/D cement head and lines. Flush BOP stack. N/D BOP stack and lift up to set Cameron slips with 100K. R/U Wach's cutter and cut 9-5/8" casing. Cut jt. length = 30.3'. Stand BOP stack back and remove tubing spool. Remove from cellar. TIEB1 N/U new McEvo SSH 13-5/8" 5000 T t -5/8" ack-off to 3 800 si for 30 minutes. TIE61 N/U BOP stack choke line and kill line. Test break to 250 psi low and 3,500 psi high. Hold each test for 5 minutes on the chart. Good test. TIEB1 BHA = 8-1/2" bit, bit sub, (9) 4-3/4" DC's, pump out sub. Total BHA length = 282.92' TIE61 HSE meeting with Steve Robinson, Paul Forman, Carl Mountford, Jim Willingham, Jeff Kilfoyle & Don Teller. Discussed 2008 performance and expectations for 2009 HSE and operational performance. Printed: 3/6/2009 1:42:58 PM • BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: ~ i Phase it Description of Operations bate From - To ' Hours Task Code NPT I _ _ -- 2/12/2009 07:30 - 08:30 1.00 CEMT P TIE61 RIH w/BHA #3. Tag cement at 2095'. 08:30 - 13:30 5.00 CEMT P TIEB1 Kelly up and establish drilling parameters: P/U wt. = 51 K, S/O wt. = 48K, Rot. Wt. = 50K, RPM = 83, Tork = 60-amps, 4.0-bpm @ 270-psi. Wash soft cement to ton of ES Cementer/wi er lu ~ 2127'. Drill out wi er lu and ES Cementer insert. Cleanout to to of sand at 2250'. Hard cement below cementer from 2128' to 2138' and stringer from 2138' to top of sand at 2250'. Dry drill and pulverize cementer insert from 2250' to 2253'. 13:30 - 15:00 1.50 CEMT P TIE61 Pump 30-Bbl. Flo-Vis sweep surface to surface at 6.0-bpm at 300-psi. Recovered cement, aluminum filings and rubber in returns. 15:00 - 15:30 0.50 CEMT P TIEB1 Set kelly back and blow down lines. Prepare to POH. 15:30 - 16:30 1.00 CEMT P TIE61 POH standin back 3-1/2" DP in derrick. UD BHA #3. 8-1/2" bit condition =Good. 16:30 - 17:30 1.00 CEMT P TIE61 M/U BHA #4 and stand back in derrick. BHA = 7-7/8" RCJB, (2) Boot Baskets, 9-5/8" Casing Scraper, XO, Oil Jar, (9) 4-3/4" DC's. Total BHA Length = 309.51' 17:30 - 19:00 1.50 CEMT P TIEB1 Test 9-5/8" casing to 3,500 psi for 30 minutes on the chart. Good test. 19:00 - 20:30 1.50 CEMT P TIEB1 RIH with BHA #4 on 3-1/2" drill pipe from derrick. Tag Top of Sand at 2,255' 20:30 - 22:00 1.50 CEMT P TIE61 P/U Kelly and establish parameters, P/U weight 53K, S/O weight 55K, 3-1/2 bpm 310 psi. Drop ball, 3-1/2 bpm at 620 psi, 6 bpm at 2,560 psi. Work RCJB to 2,270'. Pump 40 bbl high vis sweep 22:00 - 00:00 2.00 CEMT P TIEB1 Displace well from 9.8 ppg brine to 8.5 ppg seawater. 4 bpm at 700 psi 2/13/2009 00:00 - 01:30 1.50 CEMT P TIEB1 POOH from 2,277' standing back 3-1/2" drill pipe in derrick. 01:30 - 03:30 2.00 CEMT P TIEB1 Stand back 4-3/4" DC's, empty RCJB and boot baskets, Recovered 2 gallons of sand and pot metal pieces from float e ui ment. 03:30 - 05:00 1.50 CEMT P TIEB1 M/U HES RBP retrievin tool and RIH. Tag sand at 2,279' 05:00 - 07:30 2.50 CEMT P TIEB1 Reverse circulate sand off top of HES RBP from 2,279' to 2,302'. 4bpm at 400 psi. 07:30 - 08:30 1.00 CEMT P TIEB1 POH L/D 9-5/8" Halco RBP and retrievin tool. 08:30 - 17:00 8.50 BOPSU P TIEB1 Perform weekly BOPE pressure test per BP/AOGCC requirement to 250-psi Lo/3500-psi Hi. Charted all testing. Tested choke manifold, HCR kill and HCR choke valves, blind/shear rams, 3-1/2" x 6" VBR's, test spool valve, TIW floor valve, upper and lower kelly valves, IBOP, annular preventer and Koomey. Tested VBR's with 3-1/2" and 4-1/2" test joints and tested annular with 3-1/2" test joint. Bell surveyors also shot elevations and took measurements to begin well tie-in process. Jeff Jones - AOGCC waived states right to witness BOPE testing. 17:00 - 18:00 1.00 BOPSU P TIE81 Pull BOP test plug and install wear bushing. 18:00 - 19:00 1.00 CLEAN P CLEAN Crew change, discuss recent hand injuries with crew. service rig, inspect derrick, set and test PVT's. 19:00 - 20:00 1.00 CLEAN P CLEAN M 1= Dress Off Shoe, Dress Off Mill, (4) WP Extensions, WO Boot Basket, XO, 7-5/8" Csg Scraper, XO, Bumper Sub, (9) DC's, Circ Sub. Total BHA Length 318.37' Printed: 3/6/2009 1:42:58 PM • BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To Hours ~ Task Code NPT Start: 1 /30/2009 Rig Release: 2/27/2009 Rig Number: Spud Date: 5/15/1985 End: 2/27/2009 Phase Description of Operations 2/13/2009 20:00 - 20:30 0.50 CLEAN P CLEAN RIH with BHA #5 on 3-1/2" drill pipe from derrick to 2,465'. 20:30 - 00:00 3.50 CLEAN P CLEAN RIH with BHA #5 on 3-1/2" drill pipe singles from pipe shed from 2,465' to 6,539'. 2/14/2009 00:00 - 01:30 1.50 CLEAN P CLEAN Slip and cut drilling line. Inspect drawwork brakes. 01:30 - 04:30 3.00 CLEAN P CLEAN RIH with BHA #5, Dress Off assembly picking up 3-1/2" drill pipe singles from pipe shed from 6,539'. Tag tubing stub at 10 661'. Work scraper across packer setting area from 10,530 to 10,628'. 04:30 - 06:30 2.00 CLEAN P CLEAN P/U Kelly and establish parameters. P/U weight 163K, S/O weight 121 K, Rot weight 140K, 45 rpm with 4,100 fVlbs of torque, 3 bpm at 500 psi. Dress 4-1/2" tubing stub from 10,661 to 10 662' DPM. Weight on mill 2-3K, 45 rpm with 4,300 ft/Ibs of torque. Work milling assy. off and on stub several times while rotating. Worked milling assy. on and off stub 4 times without rotating. Achieved 16' of swallow with dress-off BHA. Pumped 40-Bbl. viscosified M-I Steel Lube EP pill surface to surface to determine effectiveness of product versushistorical Baroid EP Mud Lube effectiveness. P/U wt., S/O wt., free torque and milling torque were unaffected by M-I Steel Lube EP pill. 06:30 - 10:00 3.50 CLEAN P CLEAN Reverse circulated bottoms up ~ 5.5-bpm at 1250-psi with 4-1/2" tubing stub swallowed with milling BHA. Recovered small amount of carbolite, river sand and asphaltines across shaker screens. 10:00 - 14:30 4.50 CLEAN P CLEAN POH VD 2 single and 24' pup. POH standing 3-1/2" DP in derrick. 14:30 - 15:30 1.00 CLEAN BO/LD BHA #5. 15:30 - 17:00 1.50 CLEAN P CLEAN Clear and clean floor and prepare to pick up BHA #6. PJSM - review picking up BHA procedure. 17:00 - 18:00 1.00 CLEAN P CLEAN PUMU BHA #6 as follows: 2-3/8" Itco s ear double pin sub, cut lip guide, 2 x extensions, Shear Pin Guide, 4 jts. 2-7/8" PAC DP, XO, LBS, oil jar, 9 x 4-3/4" drill collars and pumpout sub = 431.40'. 18:00 - 19:00 1.00 CLEAN P CLEAN Crew Change, service rig, inspect derrick, set and test PVT's 19:00 - 21:30 2.50 CLEAN P CLEAN RIH with BHA #6 on 3-1/2" drill pipe from derrick to 9,061'. Taking 10K weight. 21:30 - 23:00 1.50 CLEAN P CLEAN Unable to get past 9,061', attempt to rotate, pipe rotates freely with 3,100 ft/Ibs of torque. Tried to work past 9,061' while pumping, had 2 bpm with 1,400 psi. Still unable to work past. It 23:00 - 00:00 1.00 CLEAN P CLEAN POOH with BHA #6, standing back 3-1/2" drill pipe in derrick. 2/15/2009 00:00 - 03:00 3.00 FISH P DECOMP POOH with BHA #6 standing back 3-1/2" drill pipe in derrick. 03:00 - 05:00 2.00 FISH P DECOMP Stand back 4-3/4" DC's and UD Skirted assembly. Skirted uide was sheared. 05:00 - 06:00 1.00 FISH P DECOMP Clear skirted assembly off floor. Clear and clean rig floor. 06:00 - 06:30 0.50 FISH P DECOMP Service rig, check PVT's, daily derrick inspection. 06:30 - 07:30 1.00 FISH P DECOMP MU BHA #7 as follows: 2-3/8" Itco Spear w/3.305" grapple, XO, 4 x 2-7/8" PAC DP, XO, 4-3/4" LBS, 4-3/4" Oil Jar, 9 x 4-3/4" Drill Collars, 3-1/2" IF Pump-Out Sub = 429.14'. 07:30 - 0.00 FISH P DECOMP RIH w/BHA #7 on 3-1/2" 15.5#, Grade "E" Drill Pipe from derrick. 07:30 - 16:30 9.00 FISH P DECOMP Tagged 7-5/8" 29.7# liner top ~ 8,940' w/spear. Worked pipe Printed: 3/6/2009 1:42:58 PM • BP EXPLORATION Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date ~~ From - To Hours II, Task Code NPT 2/15/2009 107:30 - 16:30 I 9.001 FISH I P 16:30 - 00:00 7.50 FISH P 2/16/2009 00:00 - 02:00 2.00 FISH P 02:00 - 03:30 1.50 FISH P 03:30 - 04:00 0.50 WHSUR P 04:00 - 05:00 1.00 WHSUR P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 06:30 I 0.501 WHSUR I P 06:30 - 12:00 I 5.50 12:00 - 18:00 I 6.00 18:00 - 19:00 I 1.001 RUN 19:00 - 00:00 I 5.001 BUNCO 2/17/2009 100:00 - 00:30 I 0.501 BUNCO 00:30 - 03:00 I 2.50 03:00 - 09:00 I 6.00 Page 8 of 14 Spud Date: 5/15/1985 Start: 1 /30/2009 End: 2/27/2009 I Rig Release: 2/27/2009 Rig Number: Phase Description of Operations DECOMP and spear through liner top. Continued RIH and tagged 4-1/2" 12.6#, 13Cr80 tubing stub at 10,662'. Worked pipe and spear into tubing stub and an additional 22' to 10,684 and tagged onbstruction. Kelly'd up and washed down to 10.694'. Could not et dee er while pum in .Shut down pump and worked spear to 10,700'. Stopped going. Set back and blowed down kelly. Resumed circulating with headpin at various rates and pressures while working pipe. Worked spear down to 10,739' DPM and could get no deeper. Discussed results and plan forward with RWO engineer. POH working pipe while pumping to top of tubing stub C~ 10,662'. Pipe dragging with 20K-30K overpull. DECOMP POH LDDP 1 x 1 through pipe shed. DECOMP POH LDDP 1 x 1 through pipe shed. DECOMP L/D BHA #7, Spear assembly. Did not recover junk catcher with spear assembly. RUNCMP M/U running tool and pull wear bushing. RUNCMP Hold weekly safety meeting with crew, discussed recent incidents on slope and hand safety. RUNCMP Clear and clean rig floor and pipe shed. Prepare pipe shed to run completion. RUNCMP Service rig -grease drawworks and crown, check PVT's and enviro walkaround. RUNCMP Rig up floor with torque turn equipment and single joint compensator. Found X nipples mismarked to indicate I.D. of 2.813". Called out Schlumberger to verify correct drift at 3.813". Verified correct drift and stamped correct I.D. on X nipple body. RUNCMP PUMU 4-1/2" completion jewelry as follows: 7-5/8" x 4-1/2" Unqiue Overshot, 4-1/2" HES X nipple assy., 7-5/8" x 4-1/2" Baker S-3 packer, 4-1/2" X Nipple Assy. Baker-lok'd all connections below packer. Torque-turned all connections to 4,440 ft-Ibs. optimum torque and used "Seal Guard" thread compound. 50-jts. RIH at 17:00-hrs. RUNCMP Crew change, service rig, inspect equipment, set and test PVT's RUNCMP RIH with 4-1/2". 12.6#. 13Cr80. Vam Too tubing. Torque turned all connections to 4,440 fUlbs optimum torque. Used Jet Lube Seal Guard pipe dope on connections. 150 jts RIH at 00:00 hours. RUNCMP RIH with 4-1/2", 12.6#, 13Cr80, Vam Top tubing. Torque turned all connections to 4,440 ft/Ibs optimum torque. Used Jet Lube Seal Guard pipe dope on connections. 159 jts RIH at 00:30 hours 6,937'. Wind has risen to 25 -35 mph and blowing blocks around, blocks hitting derrick beams and stabbing board. Suspend operations. RUNCMP Wait on weather, wind blowing 25- 35 mph with gusts of 40 mph. RUNCMP Wind speed dropped to 10 - 20 mph. Resumed operations. RIH with 4-1/2", 12.6#, 13Cr80, Vam Top tubing. Torque turned all connections to 4,440 ft/Ibs optimum torque. Used Jet Lube Seal Guard pipe dope on connections. Tagged up on 7-5/8" WAIT Printed: 3/6/2009 1:42:58 PM • BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: 0 9-34 .Common W ell Name: 0 9-34 Spud Date: 5/15/1985 (Event Nam e: WORKO VER Start : 1/30/2009 End: 2/27/2009 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/27/2009 Rig Name: NABOB S 4ES Rig Number: ~ Date From - To Hours Task Code NPT Phase Description of Operations x,2/17/2009 03:00 - 09:00 6.00 BUNCO RUNCMP pipe and turned pipe to all possible orientations to get past liner top. Layed top joint down, hooked up headpin and cement hose, picked joint back up and broke circulation long way at 5.0-BPM C~? 320-psi. resumed working pipe and rotating pipe to various oreintations. Made 1 foot into liner top. Set 20K downweight on overshot with no indication of further penetration. Conferred with RWO engineer and made decision to POH and la down com letion and RIH with olish mill to olish liner to . 09:00 - 09:30 0.50 PULL P DECOMP POH and lay down top joint with headpin and prepare floor to POH laying completion tubing down. 09:30 - 10:30 1.00 PULL P DECOMP After Action Review -Reviewed photos taken of picking up completion jewelry to heighten awareness of pinch points, body positioning, while also looking for possible improvements in procedure. 10:30 - 00:00 13.50 PULL N DPRB DECOMP POH laying down 4-1/2" 12.6#, 13Cr80 tubing 1 x 1 through. pipe shed. Used single joint compensator and single joint elevators for laying down pipe. Nabors Casing tech. cleaning and inspecting pins and boxes while POH. 2/18/2009 00:00 - 04:00 4.00 PULL N DPRB DECOMP POH laying down 4-1/2" 12.6#, 13Cr80 tubing 1 x 1 through pipe shed. Used single joint compensator and single joint elevators for laying down pipe. Nabors Casing tech. cleaning and inspecting pins and boxes while POH. Break out and UD Packer and jewelry assemblies. 04:00 - 06:00 2.00 PULL N DPRB DECOMP R/D 4-1/2" handling equipment, clear and clean rig floor. 06:00 - 07:00 1.00 FISH N DPRB DECOMP Service Rig. Inspect Derrick. Check PVT alarms. 07:00 - 10:15 3.25 FISH N DPRB DECOMP Start to load and tally 3 1/2" drill Pipe in Pipe shed. Install Wear Bushing. Load BHA #9 in Pipe Shed (Polish Mill Assembly). 10:15 - 10:30 0.25 FISH N DPRB DECOMP PJSM. Discuss picking up and making up BHA. 10:30 - 11:30 1.00 FISH N DPRB DECOMP Make up BHA #8 as follows: Bull Nose, String Mill, XO, Drill Pipe Pup Joint, Spacer subs, Polish Mill, XO, XO, 7" Boot Basket, 7" Boot Basket, XO, 9 ea Drill Collars. 11:30 - 21:30 10.00 FISH N DPRB DECOMP RIH with BHA #8. Single in with 3 1/2" Drill Pipe from Pipe Shed. Continue to load and tally Drill Pipe in Pipe Shed. RIH t/ 21:30 - 22:00 0.50 FISH N DPRB DECOMP P/U Kelly and establish parameters, P/U weight 130K, S/O weight 108K, Rotating weight 117K, 30 rpm with 2400 ft/Ibs of torque, 3 bpm with 410 psi. Polish 7-5/8" liner to from 8.940' to 8 957' - 5K weight on polishing mill, 30 rpm with 2,400 to 2,800 ft/Ibs of torque. Work through until string could slide through freely. 22:00 - 00:00 2.00 FISH N DPRB DECOMP Circulate 30 bbl high vis sweep around, 6 bpm with 1,100 psi. 2/19/2009 00:00 - 00:30 0.50 FISH N DPRB DECOMP Circulate 30 bbl high vis sweep around, 6 bpm with 1,100 psi. No noticeable increase in cuttings from sweep. 00:30 - 02:00 1.50 FISH N DPRB DECOMP Slip and Cut Drilling Line. 02:00 - 03:00 1.00 FISH N HMAN DECOMP Thaw frozen mud line. 03:00 - 08:00 5.00 FISH N DPRB DECOMP POOH with Polish Mill Assembly standing back 3-1/2" drill pipe in derrick. 08:00 - 09:00 1.00 FISH N DPRB DECOMP Lay down BHA #8. Saw a normal expected wear pattern on the brass section of the Polish Mill. Clear and clean Floor. 09:00 - 10:00 1.00 FISH N DPRB DECOMP Crew change (long change day). Service Rig. Inspect Derrick. Check PVT alarms. Printed: 3/6/2009 1:42:58 PM BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours I Task Code NPT Phase: Description of Operations 2/19/2009 10:00 - 11:00 1.00 FISH N DPRB DECOMP Make u BHA #9 to retrieve 'unk Fatcher as follows: Itco 2 3/8" 1:00 - 12:00 12:00 - 15:30 15:30 - 16:00 16:00 - 18:30 18:30 - 00:00 .00 3.50 0.50 2.50 5.50 ISH FISH FISH FISH FISH N N N N N PRB DPRB DPRB DPRB DPRB ECOMP DECOMP DECOMP DECOMP DECOMP Spear. Spear Ext, XO, XO, 4 Joints of 2 7/8" PAC Drill Pipe, XO, Bumper Sub, Oil Jar, 9 ea 4 3/4" Drill Collars, Pump-Out-Sub. Safety Stand-down with RWO Supervisor, RLG, WSL, Tool Pusher, and Rig Crew. Trip in with BHA #9 and 3 1/2" Drill Pipe from Derrick. Prep floor to pick up 3 1/2" Drill Pipe. Enter top of 9 5/8" x 7 5/8" Liner with no problems. Continue to top of 4-1/2" tubing stub, picking up 3 1/2" Drill Pipe from Pipe Shed. Tagged up at 10,657', 6' above top of 4-1/2"tubing stub. Establish parameters, P/U weight 154K, S/O weight 120K, 3 bpm at 1,100 psi. Wash down to Top of tubing stub at 10,662' then switch over and reverse circulate at 4 bpm with 2000 psi. Cleaned out 4-1/2" tubing to 10,736'. Brought Frac Sand, Scale and Schmoo to surface on bottoms u while reversin .Unable to clean out any further reversing circulating or circulating conventionality. Vary pump rate from 1/2 bpm to 4 bpm. Work pipe, setting bull nose on obstruction repeatedly. Unable to make any futher progress. 2/20/2009 00:00 - 01:00 1.00 FISH N DPRB DECOMP Crew change, service rig, inspect derrick, set and test PVT's 01:00 - 06:00 5.00 FISH N DPRB DECOMP POOH with S ear assembl ,standing back 3-1/2" drill pipe in derrick. 06:00 - 07:30 1.50 FISH N DPRB DECOMP Lay dow BHA and recovered Fish (Junk Catcher Sub). 07:30 - 08:00 0.50 FISH N DPRB DECOMP Pull Wear Ring. Install Test Plug. 08:00 - 14:00 6.00 FISH N DPRB DECOMP Rig up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. Test Pipe Rams with 3 1/2" and 4 1/2" test joints. Test Annular with the 3 1/2" test joint. Perform Koomey test. The State's right to witness the test was waived by L. Grimaldi. All tests recorded on chart. Good test. 14:00 - 14:30 0.50 FISH N DPRB DECOMP Pull Test Plug. Install Wear Ring. 14:30 - 15:00 0.50 FISH N DPRB DECOMP Pressure test Casina at 3 500 psi x 10 minutes. Record ~ chart. Good test. Riq down test equipment. 15:00 - 16:00 1.00 FISH N DPRB DECOMP Make-u BHA # 10 as follows: Dress Off Shoe, (4) Washpipe Extensions, WO Boot Basket, XO, 7-5/8" Casing Scraper, XO, Bumper Sub, (9) 4-3/4" DC's, Circ Sub. Total BHA length = 316.3. Stand back BHA. 16:00 - 00:00 8.00 FISH N RREP DECOMP When blowing down lines the choke line from the choke manifold on the rig floor to the gas buster was found to be frozen. R/U lines and start thawing choke line. 2/21/2009 00:00 - 06:00 6.00 FISH N RREP DECOMP Break both ends on choke line and thaw on inside of line. R/U air heater on outside of of choke line. 06:00 - 07:00 1.00 FISH N DPRB DECOMP Service rig. Inspect Derrick. Check PVT alarms. Completed line thaw. 07:00 - 08:00 1.00 FISH N DPRB DECOMP Test repaired choke line valve #1 at 250/3500 psi. 08:00 - 13:00 5.00 FISH N DPRB DECOMP Trip in with BHA #10 and 3 1/2" Drill Pipe from Derrick. Saw a few bobbles geting through the 9 5/8" x 7 5/8" Liner Top. Continue down to top of the 4 1/2" Tubing Stump at 10,657'dpm. 13:00 - 14:00 1.00 FISH N DPRB DECOMP Parameters as follows: PUW = 157K, SOW = 125K, RTW = 141 K, Pump Rate = 3.0 bpm/500 psi, 50 RPMs, 175 Amps = 4,500 fUlbs torque. Washed over 4 1/2" Tubing Stump with no problems. Dress assembly slips on and off with no problems, Printed: 3/6/2009 1:42:58 PM • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: Date ,From - To ', Hours Task ' Code I NPT Phase Description of Operations 2/21/2009 13:00 - 14:00 1.00 FISH -- N DPRB DECOMP both with rotation and no rotation. Set back Kelly. 14:00 - 14:30 0.50 FISH N DPRB DECOMP Pick up Joint of Drill Pipe and slip back over Stump. Rig up Lil' 14:30 - 14:45 0.25 FISH N 14:45 - 15:30 0.75 FISH N 15:30 - 16:15 I 0.751 FISH I N 16:15 - 20:30 I 4.251 FISH I N 20:30 - 00:00 3.50 FISH N 2/22/2009 00:00 - 04:00 4.00 FISH N 04:00 - 06:00 2.00 FISH N 06:00 - 07:00 1.00 BUNCO 07:00 - 08:00 1.00 BUNCO 08:00 - 10:45 2.75 10:45 - 11:00 0.25 11:00 - 12:00 1.00 12:00 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 00:00 2/23/2009 00:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 07:30 Red Hot Oil Unit. DPRB DECOMP PJSM with Lil' Red, Crew, WSL, TP, and Nabors Safety Rep. DPRB DECOMP Pressure test line at 1500 psi. Lil' Red pumped 45+ bbls of 175 de F. Diesel down Drill Pi-eat 1. .End Lil' Red. DPRB DECOMP Bring Rig pump on line and displace Diesel from Drill Pipe with hot Sea Water. Allow Diesel to soak behind pipe for 15 minutes. DPRB DECOMP Reverse in with a 50 bbls Hi-Vis Sweep at 4 bpm with 1,000 psi pump pressure. DPRB DECOMP POOH laving down 3-1/2" drill pipe through the pipe shed. DPRB DECOMP POOH laying down 3-1/2" drill pipe through the pipe shed. DPRB DECOMP Break out and UD BHA #10, dress off assembly. DPRB RUNCMP Service Rig. Inspect Derrick. Check PVT Alarms. DPRB RUNCMP Hold Sunday Safety Meeting with Rig Crew, Tool Pusher, and WSL. The main topic was Hand and Eye Safety. DPRB RUNCMP Clear and clean Floor. Rig up 4 1/2" handling equipment. Rig up Torque Turn equipment. Perform final jewerly inspection. DPRB RUNCMP PJSM with Rig Crew, Casing Crew, Baker Packers, Tool Pusher, and WSL. Topic Running Chrome Completion. DPRB RUNCMP Pick up Completion Jewelry as designed. Inspect Jewelry one more time as it is made up. Use Baker Lok on all connections below Packer. 6.00 BUNCO DPRB RUNCMP Run 4-1/2" 12.6# 13Cr80 Vam Tog tubing as per well plan. Use Jet Lube Seal Guard pipe dope on connections, Torque Turn all connections, make up torque of 4,440 fUlbs on connections. 1.00 BUNCO DPRB RUNCMP Crew change, service rig, inspect derrick and handling equipment, set and test PVT's. 1.00 BUNCO DPRB RUNCMP Hold Sunday Safety Meeting with Rig Crew, Tool Pusher, and WSL. The main topic was Hand and Eye Safety and personal responsibility. 4.00 BUNCO DPRB RUNCMP Run 4-1/2", 12.6#, 13Cr80, Vam Top tubing as per well plan. Use Jet Lube Seal Guard pipe dope on connections, Torque Turn all connections, make up torque of 4,440 fUlbs on connections. 5.00 BUNCO DPRB RUNCMP Run 4-1/2", 12.6#, 13Cr80, Vam Top tubing as per well plan. Use Jet Lube Seal Guard pipe dope on connections, Torque Turn all connections, make up torque of 4,440 ft/Ibs on connections. Hung up at top of 7-5/8" liner at 8,940'. P/U and work 1/2 turn into completion string, slid into liner top, packer 1.00 BUNCO P RUNCMP Run 4-1/2", 12.6#, 13Cr80, Vam Top tubing as per well plan. Use Jet Lube Seal Guard pipe dope on connections, Torque Turn all connections, make up torque of 4,440 fVibs on connections. 1.00 BUNCO P RUNCMP Service Rig. Inspect Derrick. Check PVT Alarms. 0.50 BUNCO P RUNCMP Continue running 4 1/2" Completion. At joint #215 (-9,333') Driller noticed that the string was taking weight (-4 - 6K), Normal SOW = 86K. Normal PUW = 104K. Attemp to pick u to normal weight. However now have over pull. PUW = 125K Printed: 3/6/2009 1:42:58 PM • • BP EXPLORATION Page 12 of 14 Operations. Summary Report ,Legal Well Name: 09-34 'Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 2/23/2009 07:00 - 07:30 0.50 BUNCO P RUNCMP Slack off to normal PUW of 104K. Rig up to reverse circulate. Discuss initial plan forward. Reverse circulate at 3.0 bpm/180 07:30 - 10:15 2.75 BUNCO DPRB RUNCMP 10:15 - 10:30 0.25 BUNCO DPRB RUNCMP 10:30 - 13:00 2.50 BUNCO DPRB RUNCMP 13:00 - 14:00 1.00 BUNCO DPRB RUNCMP 14:00 - 15:00 1.00 BUNCO DPRB RUNCMP Continue to reverse circulate at 3.0 bpm/180 psi. Full returns. Sea Water temp 80 degs in 80 degs out. Discuss next move with Anch Eng. Continue to reverse circulate. Work Completion to free with max parameters of a PUW of 125K and a SOW of 75K. Cycle 4 time while reverse circulating and 3 times with pump off line and bag open. No-Joy Resume reverse circulating at 3.0 bpm/180 psi. Leave Completion string with 125K pulled. Order out EP Mud Lube. Steam heat Sea Water in Pill Pit to 130 degs and mix a 45 bbl EP Mud Lube pill. Pump the 45 bbl pill down the 4 1/2" Completion String and chase with hot Sea Water at 3.0 bpm/175 psi. Work tubing free at 136 K (32K over pull). Discuss further attemo to continue to ao throuoh tight spot. Made several attempts with No-Joy. 15:00 - 00:00 9.00 BUNCO DPRB RUNCMP Prep to pull Completion. Lay down 4 1/2" Vam Top Tubing down in Pipe Shed. 2/24/2009 00:00 - 06:00 6.00 BUNCO DPRB RUNCMP _Pull Chrome Com_ pletion._ Laying down 4 1/2" Vam Top Tubinc 06:00 - 07:30 1.50 BUNCO DPRB RUNCMP La down Packer. Saw scratches and a few minor din s. Lay down X-Nipple w/RHC-M Assembly, one full Joint of 4 1/2" tubing, and the 7 5/8" x 4 1/2" Unique Overshot. Also saw long scratches and found a small pinch area on the lio of the 07:30 - 08:00 08:00 - 08:30 08:30 - 14:00 0.50 0.50 5.50 BUNCO BUNCO BUNCO DPRB DPRB DPRB RUNCMP RUNCMP RUNCMP Service Rig. Inspect Derrick. Check PVT Alarms. Clear and clean floor. Wait on new re-desi ned Jewerl Assemblies to be bucked u , ins ected, tested, and delivered to location. 14:00 - 14:30 0.50 BUNCO DPRB RUNCMP Load Jewelry in Pipe Shed. Tally and perform initial inspection of same. 14:30 - 14:45 0.25 BUNCO DPRB RUNCMP PJSM. Topic: running Chrome Tubing. 14:45 - 18:00 3.25 BUNCO DPRB RUNCMP Rig up Torque turn Equipment. Pick-up and perform final inspection of the re-designed Jewelry as follows: 7" x 4 1/2" Unique Overshot Assembly (1 set of shear pins), 2 Joints of 4 1/2" 12.6 Ib/ft 13Cr-80 Vam top tubing, X-Nipple (3.813") w/RHC-M Assembly, 7 5/8" x 4 1/2" Baker Premier Production Packer. All connections below the Packer have been Beaker Lok'd Ran in hole w/ 32 jts of 4 1/2" completion. 18:00 - 18:30 0.50 BUNCO DPRB RUNCMP Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 23:00 4.50 BUNCO DPRB RUNCMP Con't to RIH w/ 4 1/2" 12.6#, 13Cr-80, Vam Top Completion. Used Jet Lube Seal Guard thread compound on all connections, Torque Turn all connections to 4440 ft-Ibs. Ran in hole w/ 120 jts. 23:00 - 23:30 0.50 BUNCO DPRB RUNCMP Held H2S drill w/ all hands. Discuss Drill & Tuesday morning meeting highlights. 23:30 - 00:00 0.50 BUNCO RUNCMP Con't to RIH w/ 4 1/2" 12.6#, 13Cr080, Vam Top Completion.. Used Jet Lube Seal Guard thread compound on all connections. Torque Turn all connections to 4440 Ft-Ibs. Ran in hole w/130 jts. Printed: 3/6/2009 1:42:58 PM BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours I Task ,Code, NPT Phase Description of Operations __ _-- 2/25/2009 00:00 - 04:30 4.50 BUNCO DPRB RUNCMP Con't to RIH w/ 4 1/2" 12.6#, 13Cr-80, Vam Top Completion. Used Jet Lube Seal Guard thread compound on all connections. Torque Turn all connections to 4440 psi. Ran in 04:30 - 05:00 0.50 BUNCO DPRB RUNCMP 05:00 - 06:00 1.00 BUNCO DPRB RUNCMP 06:00 - 07:00 1.00 BUNCO DPRB RUNCMP 07:00 - 18:00 11.00 BUNCO DPRB RUNCMP 18:00 - 18:30 0.50 BUNCO DPRB RUNCMP 18:30 - 19:00 0.50 BUNCO DPRB RUNCMP 19:00 - 21:00 2.00 BUNCO DPRB RUNCMP 21:00 - 22:30 1.50 BUNCO DPRB RUNCMP 22:30 - 23:00 0.50 BUNCO DPRB RUNCMP 23:00 - 00:00 1.00 BUNCO DPRB RUNCMP 2/26/2009 00:00 - 01:30 1.50 BUNCO DPRB RUNCMP 01:30 - 06:00 4.50 BUNCO DPRB RUNCMP 06:00 - 07:00 1.00 BUNCO DPRB RUNCMP 07:00 - 13:45 6.75 BUNCO DPRB RUNCMP 13:45 - 15:45 2.00 BUNCO P RUNCMP 15:45 - 18:00 2.25 BUNCO P RUNCMP 18:00 - 18:30 0.50 BUNCO P RUNCMP 18:30 - 20:30 2.00 BUNCO P RUNCMP 20:30 - 22:30 2.00 BUNCO P RUNCMP 17K over & string came free.j Go back down & re-tag C~ same depth. Overshot depth C~ 9378' & packer ~ 9244'. P/U & pulled free 3-4k over. P/U wt = 104K, S/O wt = 85k. Notified town engineer & discussed problem. Plan to POOH & L/D completion. Hold PJSM. & R/U to POOH & L/D completion. Using compensator to avoid thread damage. Clear and clean floor. Service rig. Inspect Derrick. Check PVT Alarms. Lay down 4 1/2" Chrome tubing in Pipe Shed., Crew change. Service rig. check PVT alarms. Inspect derrick. R/U to break Baker Lok'd connections. POOH & heat Baker Lok'd connections below Packer. Inspect pins & boxes. UD same. Clear & clean rig floor. R/U handling equip to run tbg. R/U torque Turn equip. Hold PJSM. Review new running procedure & assign tasks to specific personnel. P/U &RIH w/ 4 1/2" 12.6#, 13Cr-80. Vam Too tubing. Used Jet tube seal guard on all connections. Torque turn all connections to 4440 ft-Ibs. RIH w/ 12 jts. Con't to P/U &RIH w/ revised completion. RIH w/ 34 jts, X Nipple assy, 10' pup, Premier Packer assy, X Nipple assy. Torque turned tubing to 4440 ft-Ibs. Used Jet tube Seal guard on tbg connections. Baker lok'd O/S assy, X nipple assy, Pup & connection below packer. Con't to P/U 4 1/2" 12.6#, 13Cr-80, Vam Top completion. Torque turn all connections to 4440 ft-Ibs. Used Jet Lubeseal Guard pipe compound on all connections. Ran in hole w/ 130 jts. Service Rig. Inspect Derrick. Check PVT Alarms. Continue rinning in with re-designed 4 1/2" Chrome Completion from Pipe Shed. Had no trouble getting into the 9 5/8" x 7 5/R° Liner. Pick up Joint #247. Install Head Pin. Bring pump on line at 1 bpm/30 psi. Ease in hole. Saw a bobble when Unique Overshot tagged the top of the 4 1/2" Tubing Stump. Continue to swallow stump to shear pins (5-ft). Set down on pins and sheared with 6K. Pressure increased to 40 psi. Continue down 3 more feet and bottom out on top of stump (stack 15K). Pull off Stump. Shut down Pump. Repeat tag a same spot. Lay down Joints 247 and 246. Add a 3.83' Pup Joint and pick up Joint 246. Make-up Tubing Hanger and landing Joint. Land Tubing Hanger. RILDS. Rig down Torque Turn Equipment. Clear and clean Floor. Prep for S-line operations. Crew change. Service rig. Check PVT alarms. Inspect derrick. Hold PJSM. Spot in & R/U Slick Line equip. RIH w/ 3.60" drift to 10,708' (SLM). No problem going thru O/S Printed: 3/6/2009 1:42:58 PM BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: 09-34 Common Well Name: 09-34 Spud Date: 5/15/1985 Event Name: WORKOVER Start: 1/30/2009 End: 2/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2009 Rig Name: NABOBS 4ES Rig Number: , i Date From - To Hours ', Task 'I Code NPT Phase Description of Operations 2/26/2009 20:30 - 22:30 2.00 BUNCO P RUNCMP - Tbg Stub connection. POOH & UD drift.,~PXN plug set C~3 10760' from well schmatic 22:30 - 00:00 1.50 BUNCO P RUNCMP M/U RHC-M sleeve & RIH. Set @ 9264' (SLM). 2/27/2009 00:00 - 01:00 1.00 BUNCO P RUNCMP Finish setting RHC-M sleeve ~ 9264' (SLM), 19' deep from completion running order. POOH & UD tools. 01:00 - 02:00 1.00 BUNCO P RUNCMP Bold PJSM. R/D Slick Line equip. 02:00 - 03:30 1.50 BUNCO P RUNCMP R/U lines. Test lines. Reverse down IA w/ 160 bbls of 120 degree Seawater. 3 BPM ~ 300 psi. 03:30 - 06:00 2.50 BUNCO RUNCMP Swap over to Inhibited seawater. Pump 580 bbls of 120 degree Inhibited seawater. Pump 3 BPM C~? 300 psi. 06:00 - 07:30 1.50 BUNCO RUNCMP Continue to reverse circulating hot Sea Water with Corrosion Inhibitor in at 3.0 bpm/300 psi. 07:30 - 09:30 2.00 BUNCO P RUNCMP Drop Packer settin Ball/Rod and wait to go on seat. Pressure u on Tubin to 3,500 si. Set Packer and test tubin at 3 500 psi x 30 minutes. Record on chart. Bleed off pressure from tubin to 1,500 si and block in. Pressure u on Inner-annulus to 3 500 si to test Packer and Casin at 3 500 six 30 minutes. Record on chart. Bleed of ressure from tubin . Saw the DCR shear Valve shear at 1,000 psi. Pump through Shear Valve both directions at 3.0 bpm/240 psi. 09:30 - 10:30 1.00 BOPSU P RUNCMP Camerson Re set TWCV. Test TWCV from top at 3,500 psi and from below at 1,000 psi. Both tests 10 minutes. Record on chart. 10:30 - 12:00 1.50 BOPSU P RUNCMP Nipple BOP stack and set back on stump. 12:00 - 15:00 3.00 WHSUR P RUNCMP Nipple up Cameron Adaptor Flange. Test void at 5,000 psi x 30 minutes. Good test. Nipple up Production Tree. Test Tree at 5,000 psi x 10 minutes record on chart. 15:00 - 16:30 1.50 WHSUR P RUNCMP P/U lubricator & test to 500 psi. Pull TWC. UD TWC & lubricator. 16:30 - 18:00 1.50 WHSUR P RUNCMP R/U lines to tree. Spot in Hot Oil. R/U Hot Oil lines. 18:00 - 18:30 0.50 WHSUR P RUNCMP Crew change, Service rig. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 WHSUR P RUNCMP R/U lines to U-tube well. 19:00 - 21:00 2.00 WHSUR P RUNCMP Hold PJSM. Pressure test lines to 2000 psi. Pump 150 bbls of 60 degree diesel to freeze protect well. Pumped 2 BPM ~ 500-700 psi. 21:00 - 22:00 1.00 WHSUR P RUNCMP O en valves & allow well to U-tube & e ulize diesel into tubin . 22:00 - 23:00 1.00 WHSUR P RUNCMP Install BPV. Test from below to 1000 psi for 10 min. Charted test. R/D Hot Oil equip. 23:00 - 00:00 1.00 WHSUR P RUNCMP Clean cellar. N/D 2nd annulus valve & install blank flange on tree. Secure well. RELEASE RIG ~ 2400 hrs. Printed: 3/6/2009 1:42:58 PM TREE = Mc EV OY WELLHEAD = MCEVOY ACTUATOR = CNV KB ELEV - 55' BF. ELEV - KOP = 3093' Max Angle = 94` Datum MD = 11 dd4' Datum TV D = 8800' SS TES: WELL ANGLE > 7tt° @ 912'3 Z`. 0 9 -3 4A %~~4.9 / CRE ~BG 5-9 /~&' CO34r3E LR**~ ~"" T 9-5 ( '~, L-Fld }iYD-563 XO TC7 L-8d BTC 2{395' 9-5%8" CSG. 7#, L-8d BTC, iD = 8.681" 2183' 9-518" BOVdEN OSG PATCH 2187' 13-3.~8° CSG, 72, i_-8d, ID = 12,347" 2512° Minimum ID = 3.725" @ 10760' 4-1 /2" HES XN NIPPLE TOP OF 7-5/8" LNR I-i 8940' 9-5/8" CSG, 47#, L-80, ID = 8.881" ~ 9198' MILLOUT WINDOW (09-34A) 9180' - 8231' 4-1?2" T>3G; 12.6#, 13CR-8~i VAM TOP ~ 10$53` .4152 11pf, il~ = 3.958" BAKER K-1 BRIDGE PLUG I-I 9450' 4-1/2" TBG-PC, 12.6#, 13CR-80 NSCT, ID = 3.958" ~~ 10772' {~ TOP OFS-1/2" LNR 10774 7-5/8" LNR, 29.7#, L-80, ID = 6.875" 10961' PERFORATION SUMMARY REF LOG: BHCS ON 03/06/94 ANGLE AT TOP PERF: 64° @ 11138' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11138 - 11146 C 04/15/02 3-3/8" 6 11750 - 11910 C 04/02/94 3-3/8" 6 11950 - 12200 C 04/02/94 3-3/8" 6 12230 - 12420 C 04/02/94 3-3/8" 12 12440 - 12565 C 04/04/94 076U~ ~-j4-1/2" OTIS XN NIP, ID = 3.725" 10760 4-1/2" PXN PLUG (01/20/09) 10772 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED PBTD -j 12588 5-1/2" LNR, 17#, 13-CR-80, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/06/85 OWAN 3 ORIGINAL COMPLETION 04/04/94 N2ES SIDETRACKED (09-34A) 02/27/09 N4ES RWO 03/02/09 PJC DRLG CORRECTIONS PRUDHOE BAY UNff WELL: 09-34A PERMIT No: 1932010 API No: 50-029-21329-01 SEC 2, T1 ON, R15E, 1764' FSL & 1036' FEL BP Exploration (Alaska) 201~~4-1i2" HES X N1P, 1D = 3.$92" 2127° 9-5; $" HES cc1~1=NTER 2150` ~-5s" B~~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ~ 34613 3444 18 DCK RKP (} 02126;49 3 6213 5394 51 i 9G DMY RK d 02t26id~J 2 1791 6377 54 ~ 9 DMY K d 02i26idd 1 9119 7177 51 BMG Dlv'h' BK d 02126,`49 9$' -~4-1;'2" DIES x NiP, 1C} = 3.812" 9209 7-5i8"x 4-1/2" BF t P}CR, ID = 3.875'• ;,' I~ 4-112'" HES X NIP; lD = 3.813" 10 ~ ~ 7" X 4-112° LNiUE OVERSHOT 10694' 4-1/2" OTIS X NIP, ID = 3.813" 10715 7-5/8" X 4-1/2" BAKER S-3 PKR W/KBH-22 ANCHOR, ID = 3.875" 10739 4-1/2" OTIS X NIP, ID = 3.813" 03/18/09 _.~~ ~,~~'~ i~~''~ ~~-~ ~p an ~~~ a~ ~~ ~~ ~- ~fri1~~~~~~~51` N0.5i33 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 p~ ~ _ `'r` ~~ Attn: Christine Mahnken ATTN: Beth «~.~ ~~~ iY+t'~` ~; ~~L;4~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wr±ll .Inh fk 1 .... n....~.:..a:~_ J-27A AY3J-00010 CBL - -_ ----•j -•_ 02/21/09 v 1V~ 1 S-107 09-34A AWJB-26 AZ4D-00005 MEM L L V ( 'a- USIT (REVISED) - 02/25/09 02/07/09 1 1 1 1 V-210 AWJB-00025 INJECTION PROFILE ` 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE _ (p ~ 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) j} . ~ ( - 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / - G/ 03/02/09 1 i B-25 AVYS-00023 USIT - /'~" /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG O`!3- a1~5 I' ~ 03/11/09 1 1 F-18 AVYS-00022 USIT ( ,- ~~%^ '~3` 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL / - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL - ~ 03/16/09 1 1 V-214 AY3J-00013 (PROF/RST WFL - C 03/15/09 1 1 K-066 AWJt-00017 MCNL ~ 01/28/09 1 1 L5-15 12113027 RST . /D ~ ~ • ~ 12/09/08 1 1 07-18 12071915 RST 9 12/01/08 1 1 15-15C AWJI-00015 MCNL ~ ~ 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT l 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT .- s' ( 01!04/09 2 1 H-18 11999064 RST / - 1 U `~ 12/03/08 1 1 - ~~ nl ~wc-~ wnvu~•~n ~ . --• •-- • •~.-..~..-~~....- .......... • rr. v.~wn.n~w r~~~v nom, vnn~naa vl\G NVr I GNlin 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~ c ~~ r2Gf~ed 3~a1 ~ C~3 3 l~l- ; ~ za` Co ~~ ~j Alaska Data & Consulting Services 2525 Gambell ~tce~t, ~uite,4p0 - - Anchorage, AK ~9F~~v3;~-2t~'38 .~ ATTN: Beth Received by: _ - *~A~~~ ~;t ~ °~(~^,~ ~~: r ~J 02/24!09 i --~'-- ~~i~~~J~~~h~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well _Inh ft n"t ~,~ Cwµ ~ n., NO.5109 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPS-43 AZCM-00001 -- ---- FMI .- YPw 12/29/08 DL I.VIVf 1 liU 1 P2-41 AWL9-00009 SCMT 01/01/09 1 1 MPS-43 AZCM-00001 SONIC SCANNER ~/ 12/29/09 1 1 S-26 AYTU-00014 PRODUCTION PROFILE ~ ~ -_~ `~~_ ` 02/16/09 1 1 F-45A AYLF-00018 LDL ~03-~~ ~/,~.~~ 02/24/09 1 1 4-04/T-26 12083416 MEM LDL - CP 02/21!09 1 1 09-34A AZ4D-00005 USIT - ~- 02/07/09 1 1 W-218 11968975 USIT (REVISED) .- ~-!.,( 12/11/08 1 1 L2-18A 11999063 RST ( 11/29/08 1 1 L2-33 11999065 RST 12/07/08 1 1 4-10A/L-28 12017518 RST ~ - 09/26/08 1 1 W-218 11968975 CH EDIT PDC GR (USIT) 12/11/08 1 PLEASE ACKNOWLEDGE RE CEIPT av clnw nlr. enln aGTUUnu~~r_ n~ir ~.,o.. r,,..., r.,. °°--`--° BP Exploration (Alaska) Inc. - Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street(`S i 400 "' Anchorage, AK 995 ATTN: Beth , Received by: l • • ~LL ~~~ ~ ~I~A/~~~If1°T"~4L ~. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below Ls being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Bh-d. Anchorage, Alaska 99508 and ~ ~ ~ ~~/ ProActive Diagnostic Services, Inc. ~ ~ ~~9 ~ Attn: Robert A. Richey 130 West Mternatianal Airport Road Suite C Anchorage, AK 99518 Pax: (907j 245-8952 1) Leak Detection - STP 19-Jan-09 09-34A 2) /rl J Signed : ~ . 111 i" ~~.~---~-_----~ Print Name: 1 Carr Log / EDE 50.029.21329-01 ~~u~ Date ~. _ ail `~ ' ~'~ ~F . PROACTIVE DIAGNOSTIC SERVICES, OIC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 98518 PHONE: (907)246-8951 FAx: (907)245-88952 E-M~uL : pdsanchorageCce~memorvlog.com WEBSITE : wvvw.memorv9og.com C:\Docn[nenia end Settings\OwneiU)esktop\Transmit_BP.docx • .. i '~ d F }$4I r~~ '~~ ~ k 1~~ ~ ~ S i ( 1` ++qgyy i "t ` +i ' 7 t p"~ l~ ~ tr 9 i ~, I~{ ~ l ~~* k - I t ' 6 _ ~ r i' .„.4 ; 4 i i ~ d ~ e j t ~ j ~,~ y ~ ~ { i t . i t 1 l~ f ~ ~ ! y ~ ~ ~ , ~ ~ ~ ~ .. s x ~ fl d F ~ ~ ~; a i l ~. ~_._ / ! t ~ ~S f f COI~SERQATIO CODIIAiIISSIpH David Reem Engineering Team header BP Exploration Alaska Inc. t~ ~; k~(- ~, PO Box 196612 ~~~"'~~~~~~ ~ t ~ ~ ~ ~~~~ Anchorage, AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-34A Sundry Number: 308-455 Dear Mr. Reem: o~ ~~3- ~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of December, 2008 Encl. STATE OF ALASKA / ~/ D~ ,~ ~b ALA OIL AND GAS CONSEf2VATION COM ION ~l o$ I ~ 1 APPLICATION FOR SUNDRY APP~VAI1 ~ ~~I_`.'~q' 1 ~1 ti 20 AAC 25.280 l ~~ ~ \ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing . ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit 7o Drill Number BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 193-201- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21329-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 08-34A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): - ADL028324 ~ 48.26 - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12630. 8979 12588 8975 None None t iz TVD r 11a ru r I r ~ ~ ~ 1 urf 251 13-3! " 1 ' 2 1 ' / 4 19 / 2 7 rm di 7 'n r 21' 7-5 ' _ 1 7 ' - 7 47 Lin r 1 56' -1 /2" 1 74' - 12 0' 6 ' - 774 2 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11138' -12565' 8886' - 8972' 4-1/2", 12.6# 13Cr-80 10772' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker SABL-3 Packer Packers and SSSV MD (ft): 10715' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 05, 2009 ®Oil - ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564-5683 Printed Nam David Reem Title Engineering Team Leader Prepared ey Name/Number. Signature C,~ Phone ~ Date !Z Is p Sondra Stewman, 564-4750 Commission Use OM Sundry Number: ~' ~j Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: -~~ ~ pS ~ rc.>.+`~~ ~~~5~ r ~~ ~ QS ~ t-~i +~'~ t"v +r-` ~~hJ~r~~~~ Subsequent Form Required: APPROVED BY +~ ~ Z A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 Submit In uupucate ,_ ' ~~ ! _ €~~=~` > ~ 200 • by 09-34 Expense Rig Workover • Scope of Work: Repair IA x OA communication to gas. Pull 4-~h" 13Cr-80 completion, cut and pull 9- 5/8" casing, run and cement to 9-5/8" surface casing, test 9-5/8" casing, run 4-1/2" 13Cr80 "stacker- packer" completion. MASP: 2514psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: February 05, 2009 Patti Phillips David Bjork Pre-Ria Work Reauest: S 1 Drift tubing for 4-1/2" Power Jet cut. Set PX plug and junk catcher in 3.725" XN profile at 10,760' MD Reference tubin tall dated 04-03-94 . F 3 Fluid- ack wellbore and CMIT TxIA to 3500 si, record LLR as necessar . E 5 Power Jet cut 4-~h" 13Cr-80 tubing at 10,664' MD, in the middle of the first full joint above the aaker Reference tubin tall dated 04-03-94 . F 6 Circulate well with 8.6 seawater and freeze rotect to 2000'. W 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 8 Set a BPV in the tubin han er. O 9 Verify that the well has a competent cellar. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-~/z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-~h" tubing string to the cut. 3. Run USIT log to determine top of cement in 9 5/e" x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" as the well has two tested barriers (PX plug and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" casing to surface. 7. Retrieve bridge plug. 8. Pull junk catcher. 9. Run 4-~/2" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 10574' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and to to 3500 psi. Freeze protect to 2000' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = Mc EV OY WELLHEAD = MCEVOY ,ACTUATOR = CNV KB. ELEV = 48' BF. ELEV = ? KOP = 3093' Max Angle = 94 @ 12184' Datum MD = 11064' Datum TV D = 8800' SS O ~ -34A /2TES: 70° @ 11212' S 90° @ 11588' - 4- ***CHROME TBGAND 5-1/2" CHROME LNR*** 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2512' Minimum ID = 3.725" @ 10760' 4-1/2" Otis XN No-Go Nipple TOP OF 7-5/8" LNR --8940' 9-5/8" CSG, 47#, L-80, ID = 8.681 " L- lJ 12" CA M TRDP-4A SSSV NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3077 3073 10 CA MMG DOME TG 16 03/12/01 2 6047 5287 51 Ga MMG DOME TG 16 03/12/01 3 8350 6708 51 CA MMG DMY TG 0 03/12/01 4 9305 7301 50 CA KBMG DMY BK 0 03/12/01 5 9836 7771 53 CA KBMG DOME BK-2 16 03/12/01 6 10366 8294 53 CA KBMG DMY BK-2 0 03/12/01 7 10628 8532 53 CA KBMG SO BK 24 11/17/02 I 10694' I 4-1/2" OTIS X NIP, ID = 3.813" { 7-5/8" X 4-1/2" BAKER SABL-3 PKR W/KBH-22 ANCHOR 4-1/2" OTIS X NIP, ID = 3.813" ' ~ 4-1/2" OTIS XN NO-GO NIP, ID = 3.725" 10739' I BAKER K-1 BRIDGE PLUG 4-1/2" TBG-PC, 12.6#, 13-CR-80, ID = 3.958" ~-1 TOP OF5-1/2" LNR 7-5/8" LNR, 29.7#, L-80, ID = 6.875" PERFORATION SUMMARY REF LOG: BHCS ON 03/06!94 ANGLE AT TOP PERF: 64 @ 11138' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11138 - 11146 O 04/15/02 3-3/8" 6 11750 - 11910 O 04/02/94 3-3/8" 6 11950 - 12200 O 04/02/94 3-3/8" 6 12230 - 12420 O 04/02/94 3-3/8" 12 12440 - 12565 O 04/04/94 10772' 1 PBTD 5-1/2" LNR 17#, 13-CR-80, ID = 4.892" { 10772' {-{4-1/2" TUBING TAIL WLEG u ELMD TT NOT LOGGED I 12630' 1 DATE RE1/ BY COMMENTS DATE REV BY COMMENTS 1988 ORIGINALCOMPLETION 09/26/05 MOR/PJC CORRC-CTGLVDATES 04/03/94 SIDETRACK®(09-34A) 05/30/06 DTM WELLHEAD CORRECTIONS 02/06/02 RNITP CORRECTIONS 10/11/06 KSB/TLH TTPPULLED 11/17/02 MWKAK GLV GO 07/13/05 KSB/PJC SET PXN PLUG @10742 07/25/05 RPH/PJC WANERCANCELLED PRUDHOE BAY UNff WELL: 09-34A PERMff No: 1932010 API No: 50-029-21329-01 SEC 2, T10N, R15E, 3554.76' FEL & 3911.79' FNL BP 6cploration (Alaska) TREE= McEVOY WELLHEAD = MCEVOY ACTUATOR = CMJ KB. ELEV = 48' BF. ELEV = ? KOP = 3093' Max Angle = 94 @ 12184' Datum MD = 11064' Datum TVD = 8800' SS 9-5/8" x 13-3/8" CSG, ECP 2380' 9-518" Casing Patch - 2400' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2512' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3003 3000 7 MMG DCK 5 5263 4800 51 MMG DMY 4 6947 5850 51 MMG DMY 3 8336 6700 53 MMG DMY 2 9549 7500 27 ti^~^~ ~^ ~~' 1 X0570 &i81 10555' a-1/2" HES X NIP, ID = 3.812" 19-5/8"x 4-1/2" BAKER S-3 PKR TOP OF 7-5/8" LNR 8940' 10620' 4-1/2" HES X NIP, ID = 3.812" 10660' 9-5/8" x a-1/2" UNIQUE OVERSHOT 9-5/8" CSG, 47#, L-80, ID = 8.681" 9198' 10694' 4-1/2" OTIS X NIP, ID = 3.813" 10715' 7-5/8" X 4-1/2" BAKER SABL-3 PKR W/KBH-22 ANCHOR Minimum ID = 3.725" @ ~ ~76U~ 10739' 4-1/2" OTIS X NIP, ID = 3.813" 4-1 /2" Otis XN NO-GO Nipple 10760' 4-1/2" OTIS XN NO-GO NIP, ID = 3.725" BAKER K-1 BRIDGE PLUG ~ 9450' \ 10772' 4-1/2" TUBING TAIL WLEG ELMD TT NOT LOGGED 4-1/2" TBG-PC, 12.6#, 13-CR-80, ID = 3.958" 10772' TOP OFS-1/2" LNR ~ 7-5/8" LNR, 29.7#, L-80, ID = 6.875" ~ PERFORATION SUMMARY REF LOG: BHCS ON 03/06/94 ANGLE AT TOP PERF: 64 @ 11138' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11138 - 11146 O 04/15/02 3-3/8" 6 11750 - 11910 O 04/02/94 3-3/8" 6 11950 - 12200 O 04/02/94 3-3/8" 6 12230 - 12420 O 04/02/94 3-3/8" 12 12440 - 12565 O 04/04/94 PBTD 17#, 13-CR-80, ID = 4.892" H 12630' DATE REV BY COMMENTS DATE REV BY COMMEMS 1986 ORIGINAL COMPLETION 09/26/05 MOR/PJC CORRECT GLV DATES 04/03/94 SIDEfRACKm (09-34A) 05/30/06 DTM WELLHEAD CORRECTIONS 02/06/02 RWTP CORRECTIONS 10/11/06 KSB/TLH TTP PULLED 11/17/02 MH/KAK GLV GO 01/10/06 AMS 2007 RWO 07/13/05 KSB/PJC SET PXN PLUG @10742 07!25/05 RPH/PJC WANERCANCELLED PRUDHOE BAY UNfr WELL: 09-34A PERMfr No: 1932010 API No: 50-029-21329-01 SEC 2, T10N, R15E, 3554.76' FEL ~ 3911.79' FNL BP Exploration (Alaska) ~ 9 -3 4 A STES: 70° @ 11212' 8 90° @ 11588' Proposed ***4-1/ HROMETBGAND5-1 /2" CHROME LNR*** Surface OA Cemented to Surface 2000' a-12° ~~FS ;< 09-34A (PTD # 1932010) Internal Waiver Cancellation ) ) Subject: 09-34A (PTD #1932010) Internal Waiver Cancellation From: "Dube, Anna T" <Anna.Dube@BP .com> Date: Sun, 24 Ju12005 16:18:13 -0800 To: "AOGCC - Winton Aubert (E-maìl)" <winton_aubert@admin.state.ak.us>, jim _regg@admin.state.ak.us CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellfutegrityEngineer@BP.com>, "Holt, Ryan P·(VECO)" <Ryan.Holt@BP.com> Wi nton and Jim, The internal BP waiver for TxlAxOA communication on well 09-34A (PTD #1932010) has been cancelled. The well no longer meets waiver criteria. The well has been secured and is classified as a trouble well. Options for repair or waiver are being evaluated. ~/ ,:56(L 'llZt7 (oç Please let me know if you have any questions. Thank you, }lnna q)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659..5102 Pager: (907) 659..5100 x1154 SCANNED AUG 0 9 2005 1 of 1 7/27/2005 9:23 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3515' FNL, 1034' FEL, Sec. 2, T10N, R15E, UM At top of productive interval 4106' FNL, 40' FEL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3912' FNL, 3555' FEL, Sec. 36, T11N, R15E, UM 5. Type of Well: Development __X Explorato~ Stratigraphic_ Service__ (asp's 717334, 5943202) (asp's 718190, 5947917) (asp's 719947, 5948162) 6. Datum elevation (DF or KB feet) RKB 48 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 09-34A 9. Permit number / approval number 193-201 10. APl number 50-029-21329-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12630 feet 8979 feet Effective depth: measured 12565 feet true vertical 8971 feet Plugs (measured) Casing Length Conductor 113' Surface 2464' Production 9150' Liner 2021' Liner 1856' Junk (measured) Size Cemented 20" 1800 Sx Poleset 13-3/8" 2500 Sx CS III & 400 Sx CS I1 9-5/8" 500 Sx Class G & 300 Sx CS I 7-5/8" 315 Sx Class G 5-1/2" 298 Sx Class G Cement Tagged PBTD @ 12565' CTM on 4/30/2001. Measured Depth True Vertical Depth 113' 113' 2512' 2512' 9198' 7227' 10961' 8781' 12630' 8979' Perforation depth: measured 11750'-11910'; 11950'-12200'; 12230'-12420'; 12440'-12565'. true vertical 8960' - 8968'; 8968' - 8969'; 8952' - 8952'; 8960' - 8958'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 PCT @ 10772' MD. Packers & SSSV (type & measured depth) 7-5/8" X 4-1/2" BAKER SABL-3 PACKER W/KBH-22 ANCHOR @ 10715' MD. 4-1/2" CAMCO TRDP-4A SSSV @ 2092' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production orlniection Data Oil-Bbl Gas-Mcr Water-Bbl 237 1250 77 97 1267 266 Casing Pressure Tubing Pressure - 254 252 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedjennifer Wats c~'~'~~A'''~ ~ ~ Title: DS 9 Surveillance Engineer Date 5/31/2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · DUPLICATE SUBMIT IN ~ 09-34A DESCRIPTION OF WORK COMPLETED CT ACID STIMULATION WITH WAX BEADS DIVERTER Date Event Summary 3/11/2001: 4/30/2001: 5/1/2001: RIH & drifted to 11180' SLM (HAVV). A CT FCO / Acid Stimulation Treatment w/diveder were performed as follows: MIRU CTU. PT'd equip. RIH w/CT & tagged PBTD @ 12565' CTM. POOH w/CT. Displaced IA gas to system. Fluid packed IA. Killed well w/2% KCI Water & Crude. Pumped the following fluid schedule across the open perforations located f/: 11750' - 11910' MD (Zone 1 B) Reference Log: BHCS 3/06/1994. 11950'- 12200' MD (Zone 1 B) 12230'- 12420' MD (Zone 1 B) 12440'- 12565' MD (Zone 1 B) Pumped: (a) 75 bbls 12% HCI - 10% Xylene w/additives @ 2.4 bpm, followed by (b) 5 bbls saturated NH4CI w/.5 BAF diverter @ 2.5 bpm, followed by (c) 75 bbls 12% HCI - 10% Xylene w/additives @ 2.2 bpm, followed by (d) 5 bbls saturated NH4CI w/.5 BAF diverter @ 2.2 bpm, followed by (e) 75 bbls 12% HCI - 10% Xylene w/additives @ 1.75 bpm, followed by (f) 6.3 bbls saturated NH4CI w/.5 BAF diverter @ 1.8 bpm, followed by (g) 75 bbls 12% HCI - 10% Xylene w/additives @ 1.8 bpm, followed by (h) 5.6 bbls saturated NH4CI w/.5 BAF diverter @ 1.8 bpm, followed by (i) 75 bbls 12% HCI - 10% Xylene w/additives @ 2.2 bpm, followed by (j) 11 bbls saturated NH4CI w/.5 BAF diverter @ 2.1 bpm, followed by (k) 158 bbls 12% HCI - 10% Xylene w/additives @ 1.3 bpm, followed by (I) 49 bbls 50/50 Diesel/Xylene @ 1.8 bpm, followed by (m) shutdown. POOH w/CT. RD CTU. Placed well BOL & obtained a welltest. Future wellwork options are currently being evalutated. Page 1 I I I I I I I I I I I I I If q )- ~o ( SPERRY-SUN DRll..LING SERVICES LOGGING SYSTEMS Anchorage, Alaska FINAL ~ END OF WELL LOGS and DATA i'\ [)\ ARCO ALASKA, INC I Y' 9-34A SLIMHOLE SECTION G\ÎJ Prudhoe Bay Unit, Alaska April 1994 CONFIDENTIAL PREPARED FOR: ARCO Alaska, Inc. PREPARED BY: W.A. Shepherd Sperry-Sun Drilling Services Logging Systems Anchorage, Alaska I I I I I RT:(:E\'lE[; 'I;P¡ Ä."f 2 t, -: {.; ',' , ! "1 ~ r,'. ~ ~~ F .~ l r',,,;~ IT~ )'1' hJVIIj i \. i\ ~' ¡ . w '. ~ --. Date If ~I() I , . r." ~ r" ',;, ~ ".., '. : I.' ;;, ~~t1,11'....r;,. 01'1 & (..,:",r~ ._,0.,.'.. ,,': ,.". - .." -' I- òtir\t~ .} -' -. . - .. Ancr;U¡;;Ç'r:' I I I I I I I I I I I I I The fol1owing information was derived from in house evaluations of weB cuttings caught at the Nabors 2ES rig site during the drilling of well 9-34A. The lithological evaluation was perfonned during the Horizontal I Slimhole section. The Engineer and Sample Catcher on location performed their duties on a twelve hour tour basis. The method of lag calculation used for depth tagging is considered crude, but fairly effective with limited operational means. Sample evaluations were performed by W.A. Shepherd, Sperry-Sun Drilling Services' Geologist/Logging Engineer, in house at our Anchorage lab. W.A. was able to give an interpretive analysis of lithology by utilizing FE/MWD data recorded from the weUsite. I 1 I I I I I 01, OR BEF ORE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIu,:,, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Pedorate _ Pull tubing_ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 48' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1763' NSL, 1036' WEL, Sec 2, T10N, R15E, UM. 9-34A At top of productive interval: 9. Permit number/approval number: 1173' NSL, 40' WEL, Sec 35, T11N, R15E, UM. 93-201 At effective depth: 10. APl number: 50-029-21329-01 At total depth: 11. Field/Pool: 1369' NSL, 1719' EWL, Sec 36, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12630 feet Plugs (measured) true vertical 9132 feet Effective Depth: measured 12588 feet Junk (measured) true vertical 8975 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 113' 20" 1800 Sx Poleset 113' 113' Surface 2457' 13-3/8" 2500 Sx CS III & 2512' 2512' 400 Sx CS II Production 11315' 9-5/8" 500 Sx Class G 11370' 8660' & 300 Sx CS I Liner 2009' 7-5/8" 315 Sx Class G 8952' 10961' Perforation Depth measured 11750- 11910'; 11950 - 12200'; 12230 - 12420'; 12440- 12565' true vedical 8960 - 8968'; 8968 - 8969'; 8952 - 8952'; 8960 - 8958' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 OR-80, Tbg @ 10772' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 10715' MD; 4-1/2" Camco TRDP-4A SSSV @ 2092' MD. 13. Stimulation or cement squeeze summary '~'~ Intervals treated (measured) see attached ORIGINAL Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 180 1374 7 255 Subsequent to operation 926 1159 129 254 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~'~~ /~ · ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-34A FRACTURE TREATMENT OF ZONE 1 DESCRIPTION OF WORK COMPLETED 7/1/97: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant through the perforation intervals located at: 11750- 11910' MD (Zl) 11950- 12200' MD (Zl) 12230- 12420' MD (Zl) 12440- 12565' MD (Zl) Ref. Log: BHCS 3/6/94. Pumped Breakdown: a) 250 bbls 20# Pre-Pad Gel @ 30 bpm, followed by b) Shutdown. ISIP @ 1506. Resumed pumping Datafrac #1: c) 45 bbls 30# Crosslinked Gel @ 30 bpm, followed by d) 182 bbls 20# Flush @ 5 - 30 bpm, followed by e) Shutdown. ISIP @ 2028. Resumed pumping Datafrac #2: f) 45 bbls 40# Crosslinked Gel @ 30 bpm, followed by g) 182 bbls 20# Flush @ 5 - 30 bpm, followed by h) Shutdown. ISlP @ 2255. Resumed pumping Fracture Treatment: i) 13 bbls 40# Crosslinked Pad @ 15 bpm, followed by j) 108 bbls Crosslinked Slurry in 2 to 12 ppg proppant stages, followed by k) 182 bbls Flush @ 30 bpm, followed by I) Shutdown. Placed a total of 21,856 lbs of proppant behind pipe. Rigged down. 7/2/97: RIH w/CT & jetted a proppant fill cleanout to 12550' MD. Returned the well to production w/gas lift & obtained a valid welltest. PERMIT 93-201 93-20!. 93~-201 93-201 9 ~ .~.~-~0! 93-201. a~3-201_~ 93-21}1 ¢: ~ 93-201 ~3 20i 93-20i DATA ..... ~' AOGCC individttai Well solog~cal Materials invent:tp.. ? T DATA_PLUS ~FA~LY WELL OP. ~A/GR ~R./EWR/FXE ~R/EMR/FXE 6M~LL/GR/SP ~LiHHOLE ~...kM.I:PIf~SLiHHOLE T 9120-11658, OH-DLL/AC. R COMP DATE'04/03/9% ~2/23-04/0S/94 R APRIL 1994 L 10450-11659 L 10450-11596 L I0~65 ~ ~' ~_630, MWD MD L 878~'-$~79 MWD TVD L c'-120-~ ~ ~ L 11650-12631 L 9120-11659 D 11650-12631 Page.' 1 Date- 10/1°/95. ._, RUN DATE_RECVD 1-7 1-7 i 05/27/94 0 ~ ~,/03/94 05/03/94 05/24/94 04/27/94 04/27/94 05/24/94 05/24/94 04/27/94 05/24/94 04/27/94 0~/24/~4~ ~ _ Are dry ditch samples required? yes Anaiysis & description received? Was the well cored? yes -recei,'rgr2?---~. yes__, no - ye s Are wel~ tests requir=d? ;~es ~e4~ no Well is in compliance In,rial ARCO Alaska, Inc. Date: Subject- From/Location: Telephone: To/Location: P.O. Box 100360, /. 4orage, AK May 24, 1994 Transmittal #: ARCO open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94O41 99510~ ~, Well Number i 01-09A 03-17-94 05-01-94 Iql i 03-32A I4-5A ~ 34APH · ~ 11-04A i 11-35 ! 11-36 ' 12-13A 15-09A Log Date i Tape Type (M-D-Y)! i ..pLL/CN/GR/AC/ ." Gl{ 05-03-94 J AC/GR & DLL/CN/ I¢" GR i AC/GR & DLL/CN/ ! ""~ 4CAL/GR 03-06-94 !B,.~.L/AC/CN/GR 03-01-94 IcQLL/ZDL/CN/GR 5-19-94 i'./ ZDL/CN 05-08-94 03-31-94 ?DIFL/ZDL/CN/GR i Dv~-L/AO/ON/GR Run, Footage 11786- 12637 9200-9654 8250- 10292 9120- 11658 Contractor Atlas Atlas Atlas Atlas · 8410-9341 Atlas 8670-9471 Atlas 9300-9969 Atlas Atlas 8607- 10380 03'30'93i .¢' MWD/GR 1,9971- 1. ~ 8767 15-34_ 05-16-94 i,/DE~ZD~CN/GR 10560-11282 18-23A · .1, 9635- 7999 03-06-93 i ''/ MWD/GR Sch Sch Sch Number of Records: 11 E, DeGrey Distribution: Bob Ocanas Phillips BPX Exxon :St~tb-~oflAla~k~" : _~_~, _: ~.-' _ , . _.~' Please acknow~dge receipt by signing and returning a copy of transmittal. By:. ....,~, ,f'~f'2--.¢.~'¢C~ Date' O Alaska Oil & Gas Cons. Commission Anchorage ARCO AlasKa, Inc. i$ a $~bsidlary of A~antJcRIchfleldCompa~y ARCO Alaska, Inc. Date' Apr 22, 1994 P.O. Box 100360, horage, AK 99510,~~k' Transmittal #: 94035 Subject: From/Location: ARCO Open Hole Finals John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Date i Tool Type i Run, Scale Contractor Number (M-D-Y)i ~ 01-09A i 1. 2"&5" Atlas 01-09A 01-09A 01-09A 04-45 04-45 9-34A 9-34A 03-17-94 i -' ~ , Dual Laterolog 03-17-94 ~" SSTVD 03-17-94 / BHCA/GR 03-17-94 /' CNL/GR 03-18-94 'fvlWD/-IWD:DGR, EWR-P4 03-18-94 /MWD/MD:DGR, EWR-P4 03-30-94 vfvlWD/MD:GRC, ~ EWR,FXE 03-30-94! ~/IWD/TVD:G RC, .= ¢ EWR.FXE ii 9-34A i 04-19-94 i,/ Slimhole 1 2-1 3A i 03-31-94 i¢' MWD: SSTVD 12-13A [ 03-31-94 !~/ BHCA/GR 12-13A ~ 03-31-94 ! ,,/ CNL/GR 12-13A 13-31 13-31 13-35 13-35 15-07A 03-31-94 04-14-94 04-14-94 03-31-94 03-31-94 .L/Dual Larerolo,~ ,/MWD/MD:GRC, EWR,FXE ,4VlWD/TVD:GRC, EWR,FXE ~ ,¢lrvlWD/MD:GRC, EWR,FXE WMWD/TVD:G RC, EWR,FXE ',/ Slimhole i 1. 2"&5" 1. 2"&5" 1. 2"&5" 1. 2"&5" 1-7, 2"&5" 1-7, 2"&5" 1,2" 1. 1"&2" 1. 2"&5" 1. 2"&5" 1. 2"&5" 1, 2"&5" 1, 2"&5" Atlas Atlas Atlas Sperry Sperry Spe. rry Sperry Sperry Atlas Atlas Atlas Atlas Sperry Sperry 1, 2"&5" Sperry 1, 2"&5" Sperry 03-15-94 1,2" 15-33 03-29-94 .~AWD/MD: DGR, 1-9, 2"&5" "CNP,SLD ' 15-33 03-29-94 :vMWD~D: DGR, 1-9, 2"&5" CNP,SLD 15-33 03-29-94 1-20 2"&5" 15-33 1-20 2"&5" 03-29-94 ~IWD/TVD: DGR, I EWR,FXE I/MWD/MD: DGR, ./ ! EWR,FXE ¢lncludes spiral 'notebook a'nd disk DS#15 logs are Pilot Hole Number of Records: 22 Sperry Sperry Sperry Sperry Sperry ~ 1994 oil,, & ~as Co,s. Anc'~rage Commission ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfletdCompany BP EXPLORATION ARCO Alaska, Inc. To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Date: May 4, 1994 Attention: Robert Crandall Subject: 9-34A Change of approved program Enclosed is an sundry application to change the approved program for well 9-34A. Due to hole problems encountered during the drilling of the first planned branch of 9-34A the decision was made to curtail drilling of Branch #2 as outlined in the drilling permit. This change will affect the APl # assigned to the well, referencing your letter of March 4, 1994, as a multiple hole section it had been assigned APl # 50-029-21329-61. As a single hole completion the APl # should be 50-029-21329-01 Yours Sincerely, RECEIVED Terry Jordan Drilling Engineer Supervisor MAY --9 1994 Al~sk~ Oil & Gas Cons. Commission Anchorage MS STATE OF ALASKA ALAbr,,A OIL AND GAS CONSERVATION COMMISSIC,,~, APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown ~ Re-enter suspended well __ Alter casing __ Repair well__ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing __ Variance__ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska,/nc. Development x KBE = 48.26 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Ser~ce ~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 9-34A 1763'NSL, 1036' WEL, SEC. 2, TION, R15E At top of productive interval 1173'NSL, 40' WEL, SEC. 35, T11N, R15E At effective depth At total depth 1369'NSL, 1719'EWL, SEC. 36, T11N, R15E 12. Present well condition summary Total depth: measured true vertical 9. Permit number 93-201 10. APl number 50- 029-21329-01 11. Field/Pool Prudhoe Bay Field/Oil Pool 12630 feet Plugs (measured) 8975 feet Effective depth: measured 12588 feet Junk (measured) true vertical 8975 feet Casing Length Size Cemented Measured depth Structural Conductor 113' 20" 1800 # Poleset 113' Surface 2457' 13-3/8" 2500 sx CS III & 2512' Intermediate 400 sx CS II Production 11315' 9-5/8" 5oo sx "G"/3oO sx CS / 11370' Liner 2009' 7-5/8" 315 sx Class "G" 8952' Perforation depth: measured 11750'-11910', 11950'-12200', 12230'-12240', 12440'-12565' True vertical depth 113' 2512' 8660' 10961' RECEIVED true vertical 8960'-8968', 8968'-8969', 8952'-8952; 8960'-8958' MAY - 9 1994 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR80 tubing to 10772' MD Alaska 0it & Gas Cons. Cornmissi Anchorage Packers and SSSV (type and measured depth) Baker SABL-3 packer @ 10715' MD; 4-1/2" Camco TRDP-4A SSSV @ 2092' MD 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 3/3O/94 16. If proposal was verbally approved Oil x Gas ~ Name of approv,.~r Date approved Service 7. I hereby certify/~hat, the foregoing is/true and correct to the best of my knowledge. Sig ned Title Drilling Engineer Supervisor 15. Status of well classification as: Suspended __ Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test~ Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required Original Signed 0avid W, doh ton I Approval No. Commissioner · ~,oproved Copy Returned · .- ~,(... . Date ~""/,/'~/~ ¥ SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] ~ [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number 3A. RACdfeAs~aska,/nc. 0 R 18 t ?J P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21329-01 4. Location of well at surface 9. Unit or Lease Name 1763' NSL, 1036' WEL, SEC. 2, TION, R15E .... ~ ~'"~ ~- "~'' i ~0~~ Prudhoe Bay Unit At Top Producing Interval i ~~/.~; l~ ¥~ i10. well Number 1173'NSL, 40'WEL, SEC. 35, T11N, R15E ! ~ ~i:.i:..~ ~ ! ~ ~,,~~'~_ 9-34A At Total Depth ! ~~-~3 i j~...~~ ~. Field and Pool ................ · . Prudhoo Bay F[old/Prodhoo Bag Pool 1369'NSL, 1719'£WL, $~C. 36, T11N, R15~ $. Elevation in ~eet (indicate KB, DF, etc.) ~. Lea,so Designation and 8~rial No. KBE = 48.26' I ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offshore J16. No. of Completions 2/27/94 3/30/94 4/3/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12630' MD/8975' TVD 12588' MD/8975' TVD YES [] NO []I 2092' feet MD I 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SE'FrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoI-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 113' 30" 1800 # Poleset 13-3/8" 68#/72# K-55/L-80 Surface 2512' 17-1/2" 2500 sx CS 111/400 sx CS II 9-5/8" 4 7# L-80 Surface 9198' 12-1/4" 5oo sx C/ass 7-5/8" 29. 7# L-80 8952' 10961' 8-1/2" 315 sx Class "G" 5-1/2" 17# 13CR80 10 774' 12630' 6-3/4" 298 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 13CR80 10772' 10716' MD TVD 11750'-11910' 8960'-8968' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11950'-12200' 8968'-8969' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12230'-12240' 8952'-8952' 12440'-12565' 8960'-8958' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 4/11/94 J Gas Lift Date of Test Hours Tested ~PRODUCTIONFOR OlL-BBL GAS-MCF ~/ATER-BBL CHOKE SITF: IGAS-OIL RATIO I FTEST PERIOD Flow Tubing Casing Pressure CALCULATED DIL-BBL GAS-MCF /VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lilhology, porosity, fractures, apparent dips, and presence ol oil, gas or water. Submit core chips. _ R£££IVED ~V~AY - $199q /~i~$ka Oil & Gas Cons. Cornrnission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -'4. 30. GEOLOC__..-~ 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. Subsea Sag River 10723' 8652' Top Sadlerochit 10748' 10748' Base Sadlerochit 11169' 11169' REC'EIV 'D ;':" .~h::,. '"...'i~, ~ ~'~,RS ~'orl$. 'qn~,;'omgo~ ,,, Coramissios 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Drilling Engineer Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-34A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/24/94 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 02/23/94 ( 1) TD:lll91 PB:l1215 02/24/94 ( 2) TD:lll91 PB: 9450 02/25/94 (3) TD: 9248 PB: 0 02/26/94 ( 4) TD: 9198 PB: 0 LAY DOWN TBG MW: 9.7 NaC1/Br MOVE RIG FROM DS 9-29 TO DS 9-34. RIG ACCEPTED @ 0900 HRS ON 02/22/94. WORK ON LINES. TAKE ON SEAWATER. RIG UP LUBRICATOR, PULL BPVV, RIG DOWN LUBRICATOR. OBSERVE WELL. ND TREE, INSPECT HGR THREADS, FUNCTION LDS. NU BOPE. TEST KELLY & FLOOR VALVES. TEST BLIND RAMS & CHOKE MANIFOLD. API RING LEAKING, ND BOPE, CHANGE OUT API RING, NU BOPE. PULL 2-WAY CHECK W/ LUBRICATOR. MU 5 1/2 TANDEM SPEAR. LAY DOWN HGR, 3 PUP JTS, 3 JTS TBG. MU TEST PLUG TO TBG. TEST RAMS. LAY DOWN TBG. MILLING SECTION MW: 9.7 NaC1/Br CONTINUED LD TUBING. INSTALLED WEAR BUSHING. MU BAKER MODEL K-1 BRIDGE PLUG. PU DP & RIH W/ BRIDGE PLUG. RELEASED F/ BP, TESTED CASING. DISPLACED WELL TO 9.9 PPG MILLING FLUID. POIH. LD RUNNING TOOL. MU BHA #1. RIH. POSITION MILL @ 9180' & BEGAN CUTOUT. RIH W/ MULESHOE MW: 9.7 NaC1/Br REPOSITIONED KNIVES @ 9198' MILLED F/ 9198-9231'. LOST #2 PUMP. REPAIRED DISCHARGE LINE ON #2 PUMP. CIRCULATED W/ #1 PUMP. MILLED F/ 9231-9248' CIRCULATED HOLE CLEAN. PUMPED PILL, POH. LD BHA #1. KNIVES 20% WORN. RIH. BROKE CIRCULATION @ 2500, 5000, 7500', THEN EVERY ROW. WASHING THRU SECTION & RU CEMENTERS. WASHING DOWN LOOKING F/ TOC PG MW: 9.7 NaC1/Br WASHED TRHU SECTION TO 9349' CIRCULATED & CONDITIONED MUD; BATCH MIXED CEMENT. PUMPED 5 BBLS WATER. POH 10 STANDS. SQUEEZES CEMENT. SLIPPED DRLG LINE. PUMPED DRY JOB & POH. CLEANED METAL CUTTINGS F/ BOP STACK. PWR. TESTED BOPE. INSTALL WEAR RING. MU BHA #2. RIH TO 7991' MU STORM PACKER & HANG OFF DRILLSTRING @28' PWR, DRAINED STACK & FLUSHED OUT AROUND PACK-OFF. PULLED PACK-OFF, REPLACED & TESTED SAME. INSTALLED WEAR RING. RETRIEVED STORM PACKER. RIH. WASHING DOWN LOKKING F/ CEMENT. RECEIVED Iris',,'( - ~ 'i~"'~'z, ,-';~ ~ . WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 2 02/27/94 ( 5) TD: 9198 PB: 7229 02/28/94 (6) TD: 9663'( 0) 03/01/94 ( 7) TD:10179' ( 516) 03/02/94 ( 8) TD:10321' ( 142) 03/03/94 (9) TD:10790' ( 469) 03/04/94 (10) TD:l1065' ( 275) WASHING DOWN TO TOC MW: 9.7 NaC1/Br WASHING DOWN LOOKING F/ CEMENT. TAGGED TOC @ 9218' DRESSED OFF PLUG TO 9228', CEMENT HARDNESS MEDIUM. MIXED & PUMPED DRY JOB. POH. SLM. NO CORRECTION. STOOD BACK BHA. MU MULESHOE. CIRCULATED & BATCH MIXED CEMENT. PUMPED 5 BBLS WATER. PULLED 10 STANDS, PUMPED DRY JOB & POH. LD MULESHOE, PU BHA & RIH TO 5831' SURFACE CHECKED MWD/MOTOR. SLIPPED & CUT DRILLING LINE. RIH TO 7991' WOC. WASHED DOWN LOOKING F/ TOC. DRILLING MW: 9.8 VIS: 55 WASHED DOWN TO TOC @ 9015' DRILLED HARDS CEMENT F/ 9015-9203'. BEGAN KICKOFF. DRILLED F/ 9203-9255'_ PAST STUMP & DRILLING NEW FORMATION. DRILLED F/ 9255-9288' DISPLACED WELL TO DRILLING FLUID. GOOD DISPLACEMENT. DRILLED F/ 9288-9663'. ROTATING ROP 80-85 FPH, SLIDING ROP 50-55 FPH. RIH W/ NEW BIT MW: 9.8 VIS: 50 DRILLED F/ 9633-10069'. CIRCULATED. SHORT TRIPPED 10 STANDS TO 9 5/8" CASING. DRILLED F/ 10069-10179'. ROP DECREASED AFTER DRILLING ACROSS K-5 CAP. CBU. POH F/ NEW BIT. HOLE IN GOOD SHAPE. CHANGED OUT BIT, RIH W/ BHA, TESTED MWD. RIH. POH MW: 9.9 VIS: 56 FINISHED RIH. REAMED 60' TO BOTTOM. DRILLED F/ 10179-10193'. ATTEMPTED TO ESTABLISH MWD SIGNAL, NO SUCCESS. DROPPED SURVEY, MIXED AND PUMPED DRY JOB. POH F/ MWD FAILURE. NO EXCESS DRAG IN OH. MU BHA #5. CHANGED OUT MAE) COLLARS. RIH TO 9125'. SLIPPED DRILLING LINE. RIH, WASHED 10' TO BOTTOM. DRILLED F/ 10193-10321' SLIDING AT LOW ROP, APPEARS TO HAVE HARD STREAK, BIT PROBABLY WORN OUT. PUMPED DRY JOB AND POH. DRILLING MW: 9.8 VIS: 58 POH. NO EXCESS DRAG IN OH. MU BHA #6. RIH & TESTED MWD. RIH. REAMED 58' TO BOTTOM (PRECAUTIONARY). NO FILL. HOLE IN GOOD SHAPE. DRILLED F/ 10321-10790'. DRILLING MW: 9.8 VIS: 60 DRILLED F/ 10790-10850'- CBU. PUMPED DRY JOB. POH F/ BIT & BHA CHANGE. LD BHA #6, MU BHA #7. PU 21 JTS 'E' DP, RIH, FLOW CHECKED MWD. RIH TO 9 5/8" SHOE. SLIPPED AND CUT DRILLING LINE, ADJUSTED ROTARY BRAKE. RIH. REAMED 70' TO BOTTOM (PRECAUTIONARY). NO FILL. DRILLED F/ 10850-11065'. WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 3 03/05/94 (11) TD:ll167' ( 102) 03/06/94 (12) TD:l1680' ( 513) 03/07/94 (13) TD:l1680' ( 0) 03/08/94 (14) TD:l1680' ( 0) 03/09/94 (15) TD:10913' ( 0) 03/10/94 (16) TD:11202' ( 289) PREPARING TO DRILL AHEAD MW: 9.8 VIS: 65 DRILLED F/ 11065-11167' DRILLED SHALE/CLAY SECTION F/ 11130-190' CBU. POH TO CASING. PUMPED DRY JOB & BLEW · DOWN KELLY' POH. STOOD BACK BHA & CLEARED FLOOR. PWR, TESTED BOPE. INSTALLED WEAR RING. MU BHA #8. RIH & FLOW TESTED MWD. RIH TO 9066'. FILLED PIPE. CUT & SLIPPED DRILLING LINE. RIH. WASHED/REAMED 120' TO BOTTOM. CONDITIONING HOLE F/ LOGS MW: 9.8 VIS: 60 DRILLED F/ 11167-11172'. HAD TROUBLE SLIDING, BEGAN WALL STICKING & HAVING TROUBLE COMING OFF BOTTOM. BEGAN ROTATING AHEAD F/ PILOT HOLE. AIR LINE TO ROTARY TABLE BROKE. POH TO SHOE, REPAIREDD AIR LINE, RIH. CONDITIONED MUD F/ HTHP W. L. TO 10CC ON TRIP. DRILLED F/ 11172-11680' KAVIK @ 11580'. ROP SAND 80 FPH, SHALE 20-25 FPH. ~BU 2X. SHORT TRIPPED 15 STANDS. PUMPED OUT 3 SINGLES, THEN OK. CBU. PUMPING LO-VIS SWEEP. LOGGING PILOT HOLE MW: 9.8 VIS: 64 CBU. PUMPED 2 LO-VIS SWEEPS, RECOVERED LARGE AMOUNT OF CLAY OVER SHAKERS. POH. OH IN EXCELLENT CONDITION, NO EXCESS DRAG. P/U KELLY AND PUMPED DRY JOB. CONT'D TO POH. R/U ATLAS DP CONVEYED LOGGING EQUIPMENT. CONT'D TO R/U LOGGING TOOLS. RIH TO 9120' MD. R/U SHEEVES, LATCHUP TOOLS AND SIDE DOOR SUB. CONT'D TO RIH WHILE PUMPING DOWN TOOL WITH 87 STROKES. LOGGING. TAGGED BOTTOM AT 11680' MD. P/U KICK-OFF ASSEMBLY /WOC MW: 9.9 VIS: 66 CONT'D TO LOG. POH TO SHOE @ 9198' MD AND L/D SIDE DOOR SUB & SHEEVES. PUMPED DRY JOB. POH. L/D 20 JOINTS OF 4 1/2" E GRADE DRILL PIPE. DOWN LOADED SOURCE TOOL AND L/D ALL ATLAS EQUIPMENT. RIH P/U 39 JOINTS OF 3 1/2" DRILL PIPE. SLIPPED 40' OF DRILLING LINE. CONT'D TO RIH. CIRCULATED TO CONDITION MUD IN PREPARATION FOR CEMENT JOB. POH. L/D 21 JTS OF 4 1/2" S-135 AND 39 JOINTS 3 1/2" DP. COND. MUD FOR KO MW:10.0 VIS: 95 M/U BHA #9. RIH TO 3000'. CIRCULATED. TESTED MWD. CONT'D TO RIH WITH BHA #9 TO 8595'. CUT DRILLING LINE. RIH TO 9100 AND CIRCULATED WHILE WOC. RIH TO 10651 & ?U KELLY. WASHED DOWN TO 10750' RIH TO 10750'. NO PROBLEMS WITH EXTRA DRAG OR FILL. FOUND HARD CEMENT @ 10852'MD. DRILLED HARD CEMENT FROM 10852-10913' MD. PUMPED 30 BBLS LOW-VIS SWEEP AND CONDITIONED MUD DUE TO CEMENT CONTAMINATION PRIOR TO KO. POH MW: 9.0 VIS: 63 CONDITION MUD DUE TO CEMENT CONTAMINATION. ORIENT TOOL. DRILL F/ 10914-11202'. CIRCULATE LO-VIS SWEEP. PULL 2 STANDS, PULLED TIGHT. KELLY UP. CIRC OUT 8 SINGLES. POH. WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 4 03/11/94 (17) TD:l1202' ( 0) 03/12/94 (18) TD:l1202' ( 0) 03/13/94 (19) TD:l1280' ( 78) 03/14/94 (20) TD:l1306' ( 26) 03/15/94 (21) TD:l1306' ( 0) 03/16/94 (22) TD:l1306' ( 0) POH MW:10.0 VIS: 70 POH, PULL 75K OVER NORMAL UP WT. UNABLE TO WORK PAST 10718'. KELLY UP, WASH & BACK REAM, PUMPING OUT SGLS TO 9318'. WASH & REAM F/ 9318-10720'. SET BACK KELLY. POH TO 9 5/8" SHOE. PUMP PILL. POH. CHANGE OUT MOTOR & BIT. VLEAR FLOOR. MU BHA #10, RIH. TEST MWD. RIH. FILL PIPE @ SHOE. SLIP LINE. RIH, TIGHT @ 10384'. KELLY UP, WASH THROUGH TIGHT SPOTS. CIRCULATE. POH TO 9 5/8" SHOE. PUMP DRY JOB. POH. POH/BACK REAMING MW:10.2 VIS: 69 LD BHA # 10, MU BHA #11. RIH, BREAK CIRCULATION @9128'. RIH TO 9285' KELLY UP WASH & REAM F/ 9285-9440'. RIH TO 10465'. ~ELLY UP. ~ASH AND REAM F/ 10465-10820'. CIRCULATE. POH, TIGHT @10968' KELLY UP WORK THROUGH TIGHT SPOT. STAND BACK KELLY. POH, WORKING TIGHT SPOT @9600'. BUILD ANGLE & DIRECTION MW:10.2 VIS: 71 WORK PAST TIGHT SPOT @9600'. BACK REAM TO 9479' PUMP DRY JOB @ SHOE. POH TO 4015' CUT AND SLIP DRLG LINE. POH TO BHA. LAY DOWN BHA. CLEAR FLOOR, PULL WB, SET TEST PLUG. TEST BOPE, FLOOR VALVES & KELLY. PULL TEST PLUG, INSTALL WEAR BUSHING. MU BHA #12, RIH, TEST MOTOR, RIH, TIGHT @10855'. ORIENT AND SLIDE F/ 11202-11227' TRIP IN HOLE MW:10.2 VIS: 72 SLIDING. LAY DOWN SGL, WORK PIPE. CIRCULATE LIQUID CSG SWEEP. POH W/ KELLY PUMPED & BACK REAMED F/ 11256-10777. SET KELLY BACK, POH @ 9450-9400'. PUMP DRY JOB. POH. LAY DN MOTOR AND MWD. MU BHA #13, RIH, TEST MWD, FAILED. POH, REPAIR MWD, RIH, SHALLOW TEST, OK. RIH, BREAK CIRC @4500 & 9187'. SLIP LINE. TRIP IN HOLE. POH MW: 10.2 VIS: 72 WASH AND REAM F/ 10742-10815' LAY DOWN 3 JTS. PUMP KCL SWEEP. WORK PIPE FULL KELLY + JT OF PIPE. HOLE CLEANED UP GOOD. REAM F/ 10752-10800'. PACKING OFF @10800' PUMP SWEEP #3. POH. TIGHT @9560'. UP REAM 9560-9545'. CHANGE BHA. REAMING @ 10803' MW:10.2 VIS: 75 MAKE UP BHA #14. RIH, BREAK CIRC @ 4550 & 9130' RIH TO 9319' BIT DEPTH. KELLY UP, REAM F/ 9319-9667'. LAY DOWN 11 JTS DP. RIH OUT OF DERRICK. TIGHT @ 10020 KELLY UP. REAM F/ 10000-10080'. RIH TO 10614' KELLY UP. REAM AND CLEAN OUT F/ 10600-10793' REAM F/ i0793-10799' WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 5 03/17/94 (23) TD:l1306' ( 0) 03/18/94 (24) TD:l1306' ( 0) 03/19/94 (25) TD:l1306' ( 0) 03/20/94 (26) TD:ll010' ( 0) TRIP IN HOLE MW:10.2 VIS: 68 REAM F/ 10803-10960' PUMP LO-VIS SWEEP, 75 BBL MUD, HI-VIS SWEEP, CIRCULATE TILL HOLE CLEAN. SET BACK KELLY. 8 STAND SHORT TRIP. SPOT BORE PLATE PILL ACROSS OPEN HOLE. POH TO 9 5/8" SHOE @10850' & 9847' KELLY UP, PUMP DRY JOB. POH. LAY DOWN BHA #14. MU BHA #15, RIH TO 1595', SHALLOW HOLE TEST MWD. RIH W/ BHA #15. CIRCULATE SWEEP MW:10.3 VIS: 71 RIH W/ BHA #15, BREAK CIRC. CUT AND SLIP DRLG LINE. RIH, TIGHT @ 10800'. KELLY UP. WASH AND REAM F/ 10800-11012' TORQUE AND DRAG. PUMP OUT SINGLES TO 10738' CIRCULATE LO-VIS SWEEP WHILE PUMPING OUT. ROTATE & WORK PIPE 10738-10780' PUMP HI-VIS SWEEP. WASH AND REAM F/ 10738-11010'. RECIPROCATE AND ROTATE WHILE PUMPING SWEEPS. HI-VIS SWEEP TO SURFACE. RUN 7 5/8" LINER MW:10.4 VIS: 78 PUMP HI-VIS SWEEP. ROTATE, RECIPROCATE. PULL 20 STANDS TO SHOE. INTERMITTANT DRAG. RIH DN DRAG. WASH AND REAM F/ 10847-11010'. 9577-10847' TIGHT. PUMP HI-VIS SWEEP, ROTATE & RECIPROCATE. SPOT 130 BBL BORE PLATE ON PILL ON BOTTOM. POH TO SHOE, INTERMITANT DRAG. PUMP DRY JOB, POH. SHAND BACH BHA. RIG UP NSS, RUN 7 5/8, 25.7#, L-80, STL, TOTAL 51 JTS. LINER HGR, LINER TOP PKR, TIE BACK ASSY. CIRCULATE LINER VOLUMNE. RIG DOWN CASG TOOLS. RIH W/ LINER ON DP. FILL EVERY 10 STANDS. CIRC PIPE VOLUME @ SHOE. RUN LINER IN OPEN HOLE. TIGHT @10847. CIRC AND WORK LINER TO LINER TO 10892' TRIP IN HOLE MW:10.4 VIS: 78 ATTEMPT TO WASH DOWN LINER @ 10961' SHOE DEPTH. CIRCULATE, BATCH MIX 315 SACKS. PUMP 5 BBL H20, TEST LINES, 5 BBL H20, 25 BBL PRE FLUSH, 66 BBL CMT. RELEASE PLUG. SET HGR, SET PKR. RELEASE RUNNING TOOL. REVERSE CIRCULATE, NO CMT. LAY DOWN CMT MANIFOLD. POH. STAND BACK 85 STANDS, LAY DOWN 66 JTS "E" LAY DOWN RUNNING TOOL. CLEAR FLOOR. RIH W/ BHA #15. SLIP DRLG LINE. LAY DOWN BHA #15. CLEAR FLOOR. PULL WB. INSTALL WB, TEST BOPE, SURFACE EQUIPMENT. MU BHA #16. CHANGE OUT SWIVEL. RIH W/ BHA #16. WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 6 03/21/94 (27) TD:ll014' ( 4) 03/22/94 (28) TD:10966' ( 0) 03/23/94 (29) TD: 11152' ( 186) 03/24/94 (30) TD:11328' ( 176) 03/25/94 (31) TD:l1630' ( 302) 03/26/94 (32) TD:11842' ( 212) POH MW: 9.7 VIS: 51 TAG CMT @10849'. CLEAN OUT TO 10882' (LANDING COLLAR). TEST LINER LAP. DRLG LDG COLLAR @10882', FLOAT COLLAR @10924'. CIRCULATE AND CONDITION MUD. DRILL SHOE @10961' CLEAN OUT TO TD @11010'. DRILL 4" HOLE. CIRCULATE HI-VIS SWEEP, FAIR AMOUNT OF CUTTINGS RETURNED. PUMP DRY JOB. POH. SET BACK BHA #16. CLEAR FLOOR. RIG UP 2 7/8" EQUIPMENT. PICK UP 9 JTS 2 7/8", RD TOOLS. RIH TO SET CEMENT PLUG IN OPEN HOLE. WASH F/ 10955-11014' CIRCULATE, BATCH MIX CEMENT. PUMP 5 BBL H20, TEST LINES. PULL 8 STANDS TO 10270' CIRCULATE DP VOLUME. PUMP PILL, POH. PULL OUT OF HOLE MW: 9.3 VIS: 52 PUMP PILL POOH. LD 9 JOINTS OF 2-7/8" CLEAR FLOOR. WOC. PU BHA # 17. RIH T/8953. BREAK CIRC @ 4500. CUT 80' SLIP 40' DL. CIRC, COND. MUD @ 8953 WHILE WOC. 11.5 BPM/2900PSI. LOWER WT T/9.3. RIH T/10724 & PU KELLY. WASH F/10742 T/TOP OF SOFT CMT @ 10753. CLEAN OUT SOFT CMT T/10773. DRILL HARD CMT T/10966. CBU. PUMP PILL. POOH. SLIDING MW: 9.3 VIS: 69 ORIENT MOTOR. RIH W/ BHA #19, FILL @2836', TEST MWD, FILL @ LINER LAP, TAG BTM @10966'. KELLY UP, 225 UP, 135 DN, 165 ROT. ORIENT HIGH SIDE. SLIDE F/ 10966-11058' CHANGE OVER TO NEW PRO FLOW MUD. WAS NOT ABLE TO DRILL UNTIL SWEEP AROUND BIT DUE TO PRESSURE FLUCTUATION AFFECTING MWD. DRILL F/ 11508-11152' DRILLING MW: 9.3 VIS: 54 DRILLED F/ 11152-11192' LOW PR, TROUBLE SLIDING. POH, NO EXCESS DRAG. CHANGED OUT BIT, CLEARED FLOOR FOLLOWING WET TRIP. RIH, FLOW CHECKED MWD. SLIPPED DRILLING LINE. RIH. REAMED 70' TO BOTTOM (PRECAUTIONARY). DRILLED F/ 11192-11328'. NET ROP LOW DUE TO SLIDING THROUGH SHALES. TARGET WINDOW 8961-8980' POH MW: 9.3 VIS: 54 DRILLED F/ 11328-11630'. MARKERS CAME IN 4' TVD DEEPER THAN PILOT HOLE. RE-LOGGED F/ 11593-11630' CBU. SHAKERS CLEAN. POH F/ BHA. NO EXCESS DRAG IN OH. PUMPED DRY JOB @ SHOE. POH MW: 9.2 VIS: 56 POH. STOOD BACK 3 1/2" DP, LD MOTOR, PU MWD/RLL, MU BHA #21 AND RIH. TESTED MWD. RIH W/ BHA #21. REAMED AND LOGGED F/ 11488-11630'. HOLE IN GOOD CONDITION. DRILLED F/ 11630-11842'. DRILLED THRU SHALE, BIT IN SAND. CIRCULATED HOLE CLEAN. POH F/ BHA. OH IN GOOD SHAPE. WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 7 03/27/94 (33) TD:11955' ( 113) 03/28/94 (34) TD:12211'( 256) 03/29/94 (35) TD:12435' ( 224) 03/30/94 (36) TD:12630' ( 195) 03/31/94 (37) TD:12630' ( 0) POH F/ BHA MW: 9.2 VIS: 58 POH TO 3 1/2" DP. SLIPPED AND CUT DRILLING LINE. POH. STOOD BACK BHA, DOWNLOADED MIND. PWR, TESTED BOPE, IWR. MU BHA #22. RIH AND TESTED MWD. RIH. PU KELLY AND REAMED F/ 11188-11262', 11724-11842' TIGHT HOLE DUE TO STIFF BHA. DRILLED F/ 11842-11955'. CIRCULATED HOLE CLEAN. POH. OH IN GOOD SHAPE. CBU MW: 9.3 VIS: 57 POH. MU BHA #23. RIH AND TESTED MWD. RIH W/ BHA #23. NO PROBLEMS IN OH. RE-LOG 11927-11955' DRILLED F/ 11955-12211'. DRILLING MW: 9.3 VIS: 57 CIRCULATED HOLE CLEAN. POH. HOLE DRAG NORMAL. SLIPPED DRILLING LINE. POH. MU BHA #24, DOWNLOADED MWD. RIH. FLOWCHECKED MWD ON TRIP IN. DRILLED F/ 12211-12225'. LEAK IN SWIVEL PACKING. POH TO SHOE, CHANGED OUT PACKING, RIH. DRILLED F/ 12225-12435'. PREPARING TO SHORT TRIP MW: 9.3 VIS: 65 DRILLED F/ 12435-12442'. SWIVEL PACKING LEAKING. POH, REPLACE PACKING, RIH. DRILLED F/ 12442-12489' CIRCULATE HOLE CLEAN. POH TO SHOE. WORKED THRU LEDGE @~1690'. SLIPPED AND CUT DRILLING LINE. POH. MU BHA #25. RIH. NO PROBLEMS IN OH, PRECAUTIONARY REAMED F/ 12409-12489'. DRILLED F/ 12489-12630'. CIRCULATE HOLE CLEAN. PREPARING TO CMT LINER MW: 9.3 VIS: 63 SHORT TRIPPED TO 7 5/8" SHOE. HOLE IN GOOD SHAPE. CBU. POH F/ 5 1/2" LINER. LD BHA #25, 39 JTS 3 1/2" DP, 25 JTS HWDP. CLEARED FLOOR. RU NCS. RAN 47 JTS 5 1/2" 17# 13CR NSCC LINER, BAKER SLH HANGER, TYPE H PACKER. CIRCULATED LINER VOLUME. RIH WITH LINER. CIRCULATED AT SHOE. CIRCULATED AND CONDITIONED MUD. WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 8 04/01/94 (38) TD:12630 PB:12588 04/02/94 (39) TD:12630 PB:12588 04/03/94 (40) TD:12630 PB:12588 CIRCULATING TO CLEAN SEAH20 MW: 9.7 NaC1/Br CIRCULATED AND CONDITIONED MUD WHILE BATCH MIXING CEMENT. LINER BECAME INCREASIINGLY MORE DIFFICULT TO RECIPROCATE AS CIRCULATION RATE INCREASED. UNABLE TO MOVE PIPE AFTER 4 BPM. STILL ABLE TO RECIPROCATE @ 2 BPM. SET SHOE ON BOTTOM. PT LINES TO 4500 PSI, PUMPED 70 BBLS 2% KCL PREFLUSH, 20 BBLS SCAVENGER SLURRY MIXED F/ 11.5012.5 PPG. KICKED OUT DART W/ 5 BBLS WATER. DISPLACED W/ RIG PUMPS @ 8 BPM THROUGHOUT DISPLACEMENT, FULL RETURNS THROUGHOUT JOB. BUMPED PLUG ON CALCULATED STROKES. SET HANGER, PACKER. RELEASED F/ RUNNING TOOL. REVERSED OUT 15 BBLS CEMENT, 70 BBLS PREFLUSH. PUMPED PILL & POH. SLIPPED DRILLING LINE. POH AND LD RUNNING TOOL. MU BHA #26. RIH. PU KELLY AND WASHED SOWN LOOKING F/ CEMENT. TAGGED CEMENT @12512'. DISPLACED FLOPRO OUT OF WELL TO AVOID CMENT CONTAMINATION. DRILLED FIRM CEMENT F/ 12512-12588' LC @12588' CBU. TESTED CASING. SOLID TEST, NO LOSS. CIRCULATED WELL TO CLEAN SEAWATER. KILLING WELL FOLLOWING PERFORG MW: 9.7 NaC1/Br FINISHED DISPLACING TO CLEAN SEAWATER. POH. SLIPPED AND CUT DRILLING LINE. POH. LD BHA. RU ATLAS AND RUN 815' PERFORATION ASSEMBLY, 32 JTS 2 7/8" EUA TUBING, UNDERBALANCE VALVE, CHAMP PACKER, SAFETY JOINT, JARS, FILL UP VALVE, AND RA SUB. RIH, TAGGED LC @12588', ENSURED FILL UP VALVE CLOSED @ 6000' BY PRESSURING ANNULUS TO 400 PSI. CONFIRMED W/ FLUID LEVEL. RU PRESSURE CONTROL HEAD, HARD LINE AND CHOKE MANIFOLD. SPACED OUT GUNS AND SET PACKER. PRESSURE TESTED LINES TO 3000 PSI. PRESSURED UP ON ANNULUS TO 2000 PSI. PRESSURE FLUCTUATION AND IMMEDIATE FLOW INDICATED GUNS FIRED. PERF INTERVALS 11750-11910, 11950-12200, 12230-12240, 12440-12565' DPM. FLOWED WELL. OPENED KILL PORTS ON PACKER AND BEGAN REVERSE CIRCULATING SEAWATER TO KILL WELL. RUNNING COMPLETION MW: 9.7 NaC1/Br ATTEMPTED TO REVERSE CIRCULATE TO KILL WELL. COULD NOT EDSTABLISH CIRCULATION. WELL TAKIN 180 BPM. BULLHEADED FILTERED SEAWATER DOWN TO DP TO TOP PERFORATION. RELEASED CHAMP PACKER. HAD TO WORK RH TORQUE TO MAKE PACKER RELEASE. CLEARED FLOOR. POH. LD DP, TUBING AND PERF ASSEMBLY. PAKER ELEMENTS DAMAGED, ALL GUNS FIRED. PWR. RU NCS AND RUN 4 1/2" 13CR COMPLETION. CONTINUED RUNNING COMPLETION. HAVE RUN 78 JTS, TP, PKR, 5 GLM'S AT REPORT TIME. WELL : DS 9-34A OPERATION: RIG : NABORS 2ES PAGE: 9 04/04/94 (41) TD:12630 PB:12588 04/05/94 (42) TD:12630 PB:12588 ND BOPE MW: 9.7 NaC1/Br CONTINUED RUNNING COMPLETION. FINISHED RUNNING COMPLETION. SPACED OUT WLEG INTO 5 1/2; TIE-BACK SLEEVE. MU HANGER, TESTED CONTROL LINE TO 5000 PSI. MU LANDING JOINT. REVERSED IN INHIBITED SEAWATER. DROPPED PACKER SETTING BALL. LANDED TUBING HANGER, RILDS. SET PACKER W/ 4000 PSI AND TESTED TUBING TO SAME. NO LOSS. BLED TUBING TO 1500 PSI AND TESTED ANNULUS TO 2000 PSI. NO LOSS. LD LANDING JOINT AND SET TWC. ND BOPE. RELEASE RIG MW: 9.7 NaC1/Br ND BOPE. NU TREE. TESTED TREE. RU LUBRICATOR AND PULLED TWC. PRESSURED TUBING, TESTED ANNULUS. NO LOSS. RELEASED TUBING PRESSURE, COULD NOT SHEAR DCR VALVE. RU LUBRICATOR, SET TWC. SECURED WELL. RELEASED RIG 04/04/94 @1330 HRS. SIGNATURE: (drilling superintendent) DATE: 10031 .~77 -" '~Z"": t-.- © .0:'~ ;e ~,.,:,.-,,' 21,75 ~55':, ...... ' ...... '" ~., , ~,'~: *. 7 C ./ ~." ~ ~ '7 '~ -~ ~,, 1458,78 ".-7', 78 ::-'2,99 461,5:25' 7,:,i,2i 1463,30 6:!I ---,~-,r,?-,,.,~.: ~ ',.', ~' ; ~-,r ,-.. ,- · 7zr., ~.,: -~oa,O.t 5,67 Z4,,f,,.-', "'"'" "?' '~i'OL7 .~ ?7 . :.._ ~.t...-~ ~$.z~.,,6-(J 4,59 ";-'" b,*.. ~'"':' "--~ 7A7 '"" z-o,. _ z~o -.' ~, _'-~. ... , -',..' C'- .... t,.- -,.. 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'=- ...... 31::,18 5,27 1,13 70,:=.-'I 3,:c' 10315,4 824-'..~-~7 1,~: -:,,.-,,::: .: .... . *:,', *.-': . :,:_-.=:,, =. :,::-: :_. .... '..",4:: -34,68 5,'¢3 !:z:'`;..,, 72,?Y _.~': l/._ 10377,2 ..! 394, } !: ': =*_:-c -:":..., **: v:¢ ?: '/-. - .: ....., :,v" 7 .:-, 6'.;' --"::: ';' 5 :u*?.:.~-r,, u c,:._-:.c,, 5( i, .-=,:-'" -31,~:,"" -7 ,::-- {7: ;v.-.. 7'--., ~ ,57 a i'- ;'-. '='~" * ~ 154F.:',6 ,"_"$61', £i 1,,_, ---- ,--:, ~.*, 61!5 i,76 75,34 i-'-347010 ~.E?i,34 2-.-!8 - :7, E'0 ,-'.', its -0,34 75,00 ._ / '"! ~ J.; -£ ~-.- - ;Z--' ~ 0-:: 19534,,:: ,=.-,~. :' .: ::.*,:.. _;' ,A~-'.._ -..-.::~ ..... :~. =_,,.o.. '-'¢ -0114 74,*.:" 8.6:'."6.:07 i :':' -:':: =':' !...!7 7e,',<:,: 4; ?'*~.,~- · 5631,3-6 2..-28 -~.c:,¢o 7 ~'-', .,-.~ ,',, -, -,~, r,..n? -~.65~67 ' '" -7:.60 6,61 -C~,--':g -: r,: - .- 6.::=,::'?--:::67 -..:_.,:7 -?-~:: .... 0, ?'.:-. ...... .,. v,::,, ::,4:':' ;::.6'5'7,2:., C,r?... -7 ,,_,,,°:: :" ,.::':'" 0;67 7,:,52: 2:,_~ ~' :--,, --'.:.,..?-, i~-:.;4 - ,:- ,. ,"' ~'. 3.,?~, -0 ""'" _'..-" ,z:'. -'~. '~":,' z..:.-':"- ~...':- i :.T: ~.':-'"" 3 "": i-~C' ~..- ~; .... 'L' ~ 7-' 10.-:'04:2 k74'.-'.:';':-.' i "-'"" -'=' "": ":":' ,,,,.,:, ..., .~,:..~.3.a.':', ,, 0:,_.... ...-'7,54 i ,,24 4==:'.. ....... ';'.::i4 ,..~.:""- 3,5':. (:,,70 i07'3._:.:3 '-:'-';~ ,",: I r.,: "' '"' ":'---'::'.-':' '-' '"'"" '" ":-'" ........ ,...,.,:. ..... ,:- _,-.._-. -,:o, ..... ---..,:zu 77.,43 ,..,,._-..,'-." .~ .: .:. , :. ~ 3,,''~' ~.,,'.~. 0,'.74 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 PRUDHOE BAY DRILLING PBU/9-34A 500292132961 NORTH SLOPE COMPUTATION DATE: 4/ 7/94 DATE OF SURVEY: 033194 MWD SURVEY JOB NUMBER: AK-MW-40026 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE INCLN DIRECTI DG MN DEGREES DLS TOTAL ON RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10936 8764.90 8716.90 10985 8798.72 8750.72 11016 8818.80 8770.80 11047 8837.98 8789.98 11079 8856.15 8808.15 46 0 N 82.20 47 47 N 82.90 49 49 N 83.70 53 42 N 84.00 57 6 N 84.60 E .00 4708.50N 1123.20E E 3.76 4713.18N 1159.03E E 6.97 4715.86N 1181.82E E 12.54 4718.46N 1206.03E E 10.74 4721.08N 1232.24E 1830.31 1866.44 1889.37 1913.69 1939.99 11110 8872.26 8824.26 11142 8887.17 8839.17 11188 8905.69 8857.69 11212 8914.08 8866.08 11245 8924.41 8876.41 60 16 N 84.00 64 8 N 83.80 68 22 N 84.00 70 42 N 84.90 72 47 N 85.40 E 10.33 4723.71N 1258.59E E 12.11 4726.72N 1286.73E E 9.23 4731.19N 1328.59E E 10.32 4733.36N 1350.97E E 6.46 4736.01N 1382.19E 1966.43 1994.71 2036.76 2059.20 2090.46 11276 8932.63 8884.63 11307 8938.92 8890.92 11338 8943.52 8895.52 11370 8947.19 8899.19 11402 8950.20 8902.20 76 25 N 84.40 80 9 N 83.60 82 46 N 83.90 84 4 N 83.10 85 9 N 83.90 E 12.15 4738.67N 1411.95E E 12.29 4741.84N 1442.14E E 8.47 4745.18N 1472.61E E 4.76 4748.78N 1504.19E E 4.19 4752.38N 1535.84E 2120.28 2150.60 2181.22 2212.98' 2244.81 11432 8952.47 8904.47 11464 8954.32 8906.32 11496 8955.49 8907.49 11526 8956.11 8908.11 11542 8956.41 8908.41 86 10 N' 81.00 87 10 N 82.10 88 38 N 80.70 88 59 N 82.00 88 54 N 82.90 E 10.22 4756.32N 1565.49E E 4.64 4761.01N 1597.09E E 6.34 4765.79N 1628.70E E 4.49 4770.30N 1658.35E E 5.65 4772.40N 1674.21E 2274.71 2306.66 2338.63 2368.62 2384.61 11588 8956.89 8908.89 11619 8957.03 8909.03 11649 8957.42 8909.42 11672 8957.88 8909.88 11704 8958.67 8910.67 89 54 N 83.20 89 33 N 83.90 88 56 N 83.90 88 46 N 83.70 88 25 N 85.10 E 2.29 4777.97N 1719.87E E 2.52 4781.45N 1750.67E E 2.07 4784.64N 1780.50E E 1.14 4787.12N 1803.36E E 4.51 4790.24N 1835.20E 2430.59 2461.56 2491.52 2514.49 2546.43 11736 8959.65 8911.65 11767 8960.91 8912.91 11802 8962.83 8914.83 11839 8965.39 8917.39 11870 8967.19 8919.19 88 4 N 85.10 87 16 N 85.40 86 24 N 85.30 85 41 N 84.70 87 37 N 84.90 E 1.09 4792.98N 1867.06E E 2.73 4795.54N 1897.93E E 2.53 4798.37N 1932.76E E 2.51 4801.59N 1969.53E E 6.29 4804.39N 2000.35E 2578.34 2609.24 2644.09 2680.92 2711.81 11901 8967.86 8919.86 11934 8967.43 8919.43 11966 8966.18 8918.18 11998 8964.51 8916.51 12029 8962.78 89 54 N 84.70 91 34 N 83.70 92 54 N 83.50 93 4 N 83.70 E 7.35 4807.20N 2031.21E E 5.92 4810.54N 2064.03E E 4.17 4814.10N 2095.80E E .84 4817.66N 2127.56E .84 4821.06N 2158.33E 2742.73 2775.68 2807.62 2839.55 2870.47 SPErRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/9-34A 500292132961 NORTH SLOPE COMPUTATION DATE: 4/ 7/94 DATE OF SURVEY: 033194 MWD SURVEY JOB NUMBER: AK-MW-40026 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12060 8960.95 8912.95 93 25 N 83.70 E .29 4824.46N 2189.09E 12091 8959.09 8911.09 93 25 N 83.50 E .64 4827.90N 2219.84E 12122 8957.25 8909.25 93 24 N 83.50 E .09 4831.41N 2250.58E 12154 8955.32 8907.32 93 31 N 82.80 E 2.22 4835.22N 2282.30E 12184 8953.45 8905.45 93 35 N 83.00 E .72 4838.92N 2312.01E 2901.39 2932.31 2963.23 2995.15 3025.08 12220 8951.83 8903.83 91 34 N 83.70 E 5.94 4843.08N 2347.72E 12251 8951.54 8903.54 89 28 .N 84.20 E 6.99 4846.35N 2378.54E 12282 8952.04 8904.04 88 40 N 84.20 E 2.55 4849.48N 2409.38E 12313 8952.94 8904.94 87 58 N 83.90 E 2.46 4852.69N 2440.20E 12345 8954.29 8906.29 87 11 N 84.40 E 2.92 4855.95N 2472.00E 3061.01 3091.97 3122.92 3153.87 3185.80 12377 8955.96 8907.96 86 50 N 84.20 E 1.26 4859.13N 2503.80E 12409 8957.82 8909.82 86 28 N 84.70 E 1.92 4862.21N 2535.60E 12440 8959.92 8911.92 85 46 N 84.00 E 3.19 4865.26N 2566.38E 12471 8962.38 8914.38 85 4 N 84.90 E 3.67 4868.25N 2597.13E 12501 8965.14 8917.14 84 22 N 84.40 E 2.86 4871.03N 2626.87E 3217.71 3249.60 3280.48 3311.33 3341.15 12533 8968.30 8920.30 84 17 N 84.60 E .68 12563 8971.35 8923.35 84 1 N 84.70 E .96 12595 8974.83 8926.83 83 30 N 84.90 E 1.74 THE CALCULATION PROCEDURES ARE BASED THREE-DIMENSION MINIMUM CURVATURE 4874.09N 2658.57E 4876.87N~5~688.28E 4879 75N ~719 96E ON THE USE OF2~s3 METHOD. 3372.94 3402.73 3434.48 HORIZONTAL DISPLACEMENT = 5586.61 FEET AT NORTH 29 DEG. 8 MIN. EAST AT MD = 12595 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 81.20 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/9-34A 500292132961 NORTH SLOPE COMPUTATION DATE: 4/ 7/94 DATE OF SURVEY: 033194 JOB NUMBER: AK-MW-40026 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 10936 11936 12595 8764.90 8716.90 8967.38 8919.38 8974.83 8926.83 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4708.50 N 1123.20 E 2171.10 4810.76 N 2066.02 E 2968.62 797.52 4879.75 N 2719.96 E 3620.17 651.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 PRUDHOE BAY DRILLING PBU/9-34A 500292132961 NORTH SLOPE COMPUTATION DATE: 4/ 7/94 DATE OF SURVEY: 033194 JOB NUMBER: AK-MW-40026 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 10936 8764.90 8716.90 11064 8848.00 8800.00 11378 8948.00 8900.00 11416 8951.32 8903.32 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4708.50 N 1123.20 E 2171.10 4719.90 N 1220.22 E 2216.44 45.34 4749.72 N 1512.12 E 2430.03 213.59 4754.03 N 1549.70 E 2464.68 34.~65 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. P.O. Box 100360, ,..:horage, AK Date: Subject: From/Location: Telephone: To/Location: Mar 18, 1994 Transmittal #: · Distribution 94033 99510,~ ~, Well I Log Date Tool Type Run, Scale Contractor Numberi (M-D-Y) ~// 9- i 03-06-94 ~ CNL/GR 1,2"&5" Atlas I 34APH , /~* 9- I 03-06-94 J SSTVD 1, Atlas i 34APH , 1"&2"&5" I 9- 03-06-94 ./' BHCA/GR 1, 2"&5" " Atlas 34APH *'~ 34APH9' i 03-06-94 ./DLL/GR/SP i 1,2"&5", Atlas .//.~,,t 11-04A ! 03-01-94 ,,' Borehole Prof I 1, 5" Atlas 11-04A 03-01-94 v- SSTVD 1, 2"&5" Atlas ~ ! 11-04AI 03-01-94 iv' CNL/GR 1, 2"&5" Atlas "X, I 11-04AI 03-01-94 ,/ DLL/GR/SP 1, 2"&5" Atlas '~i 11'04AI 03-01-94 ~' Z- I 1,2"&5" Atlas i Densii°~CNL/GR I * Well 9-34APH is the correct well name. Number of Records: 9 '~-nE DoGre; Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska Mobil D & M PB Well Files P 1 Files ARCO Alaska, Inc. Is & Subsldlm'y of Atlan~cRIchfleidCompany Please acknowledge receipt by signing and returning a copy of transmittal. By: w~ _~_~-~ Date: /~., ~'.~ ,.,~. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 4, 1994 Terry Jordan ARCO Alaska Inc P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Jordan: As we discussed today, the permit to drill Prudhoe Bay Unit well 9-34A incorrectly states the APl number for the well. The correct information is listed below. WELL NAME PERMIT NUMBER API NUMBER PBU 9-34A 93-201 50-029-21329-61 We do not consider assignment of separate API numbers for each downhole segment practical with a 12-digit AP1 number format nor is it consistent with current API guidelines.. The number 6 in the eleventh digit signifies a well with multiple downhole sections. The twelfth digit is incremented for each drilling permit issued for the surface location which is uniquely identified by the first ten digits. Several, downhole sections can be permitted at a single time so the twelfth digit is not necessarily an indicator or the number of downhole sections present in a well. I regret any inconvenience this change may cause. If any of your staff can suggest an alternate method for tracking wells with multiple downhole sections, please have them give me a call at 27%1433 Thanks. Robert Crandall Senior Petroleum Geologist ALASKA OIL AND GAS CONSERVATION COMMISSION · ..WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 29, 1993 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 9-34A ARCO alaska, Inc. Permit No. 93-201 Sur. Loc. 1763'NSL, 1036'WEL, Sec. 2, T10N, R15E, UM Btmnhole Loc. 1005'NSL, 3609'WEL, Sec. 36, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillEIIlb. Type of well. Exploratoryl-I Stratigraphic Test[-I Development OilE] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska,/nc. KBE = 48' feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Pooi P. O. Box 196612. Anchoraae. AlaSka 99519-6612 ADL 28324 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 2o ^AC 25.025) 1763' NSL, 1036' WEL, SEC. 2, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1293' NSL, 4562' WEL, SEC. 36, T11N, R15E 9-34A U-630610 At total depth 9. Approximate spud date Amount IO05' NSL, 3609' WEL, SEC. 36, T11N, R15E 2/2/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dTVD) property line ADL 28327-1545' feet No close approach feet 2560 12594' MD/8933'TVD feet 16. To be completed for deviated wells 117. Anticipated pressure (see 2o AAC 25.035 (,,)(2)) Kickoff depth 9~oo feet Maximum hole angle 9o o IMaxirnurn surface 3330 psig At total depth (TVD) 880¢/4390 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29tt ~'~ NSCC 1000' 10573' 8465' 11573' 8933' (Branch # 1) 8-1/2" 7" 29tt NTeOS NSCC 1523' 9050' 7135' 10573' 8465' (Branch #1) 300 sx Class "G" 6" 4-1/2" 12.6# VT8O/13CR NSCT 892' 11623' 8933' 12515' 8933' (Branch #1) 6" 4-1/2" 12.61/ ~cR NSOT 1070' 11495' 8933' 12565' 8933' (~aCcjc¢l~ ! ~1 r.. r~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary DECo 2 'i ' 995 Total depth: measured 12059 feet Plugs (measured) true vertical 8977 feet Al~,S¥.a 0il & Gas Cons. Commission Anchorage Effective' depth: measured 11815 feet Junk (measured) Fill@ 11815'MD (3/15/92) true vertical 8865 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 113' 20" 1800 # Poleset 113' 113' Surface 2457' 13-3/8" 2500 sx CS Iil & 2512' 2512' Intermediate 400 sx CS II P rod uctio n 11315' 9-5/8" 5o0 ~x'G'/300 ~x CS / 11370' 8660' Li.n e r 930' 7" 300 sx Class "G" 11124'- 12054' 89 74' Perforation depth' measured AII pedorations squeezed but leaking true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereg,b55, certify th, at the foregoing is true and correct to the best of my knowledge Sig~L2,~'-') Y~/~' ~ ~--~¢~ Commission' Title' Dri//in'En'ineerSuperviS°ruse Only Permit Number APl number --., 4, ]App.rov~a, d,at~ Ieee cover letter ~-, 50- O:"~- -~ /'.~'k l-CZ'"I/o4-c~7- ~'Z.,~ [for other requirements Conditi'Ons of approval Samples required [] Yes J~] No Mud Icg required []Yes .E] No Hydrogen sulfide measures [] Yes [~I No Directional survey requ,rea ']~ Yes [] No Required working pressure for DOPE [] 2M; 1-13M; ]~[5M; []10M' r-115M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner me commission Date/ · . Form 10-401 Rev. 12-1-85 Submit in Directional'. I KOP: i 9200' MDbkb, 7228' TVDbkb [, Maximum Hole Angle: ] 90° Close Approach Well: NONE The above listed wells will be secured during the close approach. Casing/Tubin Pro ram: Wt/Ft Hole Siz~ Csg/ Wt/Ft' G~'ade Conn Length Top Btm _ .,Tbg O.D. MD/TVD MD/TVD 8-1/2" 7" 29# NT80 13Cr NScc 1000' 10,573/8465 11,573/8933 8-1/2" 7" 29# NT80S NScc 1523 9050/7135 10,573/8465 6" 4.5" 12.6~ NT80 13Cr NSct 892' 11,623/8933 12,515/8933 6" 4.5" 12.6g NT80 13Cr NSct 1070' 11,495/8933 12,565/8933 Tubing 3.5" 9.2# NTB0 13Cr NSct 11,495' 0/0 11,495/8930 Cement Calculations: [Liner Size: ]7" ] Bas. is:] 50~'.'~)pefi"hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above linei' with DP. Total Cement Volume: 300 sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 500 pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Alaska Oil & i~as Cons. Oo~mission Redrill Plan Summary Page 2 I Well Name: ]DS 9-34A Redrill Plan Summary I Type of Redrill (producer or injector): I Producer I ISurface Location: Target Location: Bottom Hole Location ("Y" #1): Bottom Hole Location ("Y" g2): 1763 FSL 1036 FEL S02 T10N R15E UM i 1293 FSL 4562 FEL S36 TI 1N R15E UM 1545 FSL 3603 FEL S36 T11N R15E UM 1005 FSL 3609 FEL S36 T11N R15E UM I AFE Number: I 4J0243 Estimated S'tart Date: 1 2/2/94 MD: [12.565' I (B ranch #1) MD: 12.594' (Branch g2) Well Design (conventional, slimhole, etc.): I Rig: I Nabors 2ES I Operating days to complete: 129 TVD: 8933' KBE: 48.0' I Horizontal, Multi-lateral (Y-configuration) Objective: This redrill is recommended due to severe crossflow from the Victor to Tango perforations and washed out perforations in the Tango. An uncemented sidetrack from the original well also exists 100' from the current wellbore. The redrill is proposed with a horizontal "Y" branched configuration (multilateral). This will allow a test of multiple horizontal wellbores in the basal Lower Romeo. Mud Program: A 9.8 - 10.5 ppg Biozan polymer/KC1 water based mud will be used in the 8-1/2" hole section. I Special design [ 6" horizontal holes in Sadlerochit Zone 1 will use a 9.0 - 9.2 ppg ZanvisI considerations polymer system after running and cementing the 7" liner at the target. D'~pth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) ! 7228' 9.8 10 15 5 10 6 0 5 . tO tO tO tO tO tO tO tO tO 8933' 10.5 18 30 " 15 30 8 0 8 8933' 9.0 10 40 5 10 6 0 5 .. to to to to to to to to to , ! 8933' 9.2 18 50 25 30 8 0 8 .,. Redrill Plan Summary RECEIVED DEC 2 1 1~ Alaska 0il & Gas Cons. Commission Anchorar:je Page 1 SUMMARY PROCEDURE: , 19. 1. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut .5-1/2" tubing at 9500' MD. Freeze protect. 2. MIRU workover rig. Test intermediate packoff to 5000 psi. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set BPV. ND tree. 5. NU BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. Pull and lay down 5-1/2" tubing. Replace intermediate packoff if necessary. RIH w/9-5/8" permanent bridge plug. Set at 9450' MD. Test casing to 3500 psi. Change well over to milling fluid and spot an 18 ppg from PBTD to the base of the proposed section. 7. RIH with a 9-5/8" section mill and cut a 50' section in the 9-5/8" casing starting at +/- 9200' MD. 8. RIH with open-ended DP. Mix and pump a minimum of.145 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. 9. RIH with ,8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to target at 8933' TVD with a 90° hole angle. 10. RU Atlas wireline and drill-pipe log with the DLL / GR / Desity / Neutron. 11. Run 7" 29# 13CR NSCC x 7" 29# L80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. Crossover from 13CR to L-80 at +/- 10.57(;;)' MD. 12. Cement liner with a minimum of 300 sacks. (Ensure that cement covers up to 500' above all oil bearing sands) 13. Make up 1.25° bend, 6" steerable drilling assembly with Anadrill Slim-One GR / directional. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. 14. Drillout float equipment and 5' of open hole. Change well over to FIo-Pro mud system. 15. Drill 1000' of 6" hole #1, left-hand turn at 3°/100' as per the directional plan. CBU. 16. Lay down directional tools. Run 6" hole opener assembly to TD. CBU, POOH. 17. Pick up and run 4-1/2" 13-Cr slotted liner assembly with 2-1/16" circulation string and TIW CG-6 tieback sleeve with C-spline. Slotted liner should be 100' less than the open hole length.' See attached "Horizontal Multi-Lateral Program Addendum" for details. 18. Position slotted liner such that 50' of open hole remains between the top of the tieback sleeve and the 7" shoe. The C-splines will allow ro~ation of the slotted liner if necessary. Drop neutral bouyancy ball, pump down to setting tool, and pressure up to release from the liner. Circulate liner to seawater and spot lithium hypochlorite. Pull circulation string from the liner and into the 7" shoe. CBU, POOH, lay down circulation string and running tool. RECEIVED Rcdrill Plan Summary Alaska Oil & (lag ~o~. Anchorage Page 3 20. 21. 22. 23. 24. 25. 26. 27. 28. Make up 1.5° bend, 6" steerable drilling assembly with Anadrill Slim-One GR / directional. Orient bit at 5' into the 50' open-hole section. Directional drill as per program with 6°/100 turn rate to the right. CBU. Lay down directional tools. Run 6" hole opener assembly to TD. CBU, POOH. Pick up and run 4-1/2" 13-Cr slotted liner assembly with 2-1/16" circulation string and TIW "SS" 7"x 4-1/2" horizontal packer. Drop neutral bouyancy ball, pump down to setting tool, and pressure up to release from the liner. Circulate liner to seawater and spot lithium hypochlorite. Pull circulation string from the liner and into the 7" shoe. POOH, lay down circulation string and running tool. RU Nabors casing crew. RIH with 3-1/2" 9.2#/ft 13-Cr completion string. Change over to clean inhibited seawater. Space out, land completion into 7" TIW SS Packer, and set packer. Program may change to run a 7" packer with the tailpipe positioned above the slotted liner after review of the open-hole logs. Test tubing x casing annulus to 2000 psi for 5 minutes to ensure packer seal assembly is engaged (the reason for not testing to 3500 psi is to avoid the possibility of shearing out the Iockdown screws that hold the tubing hanger in place). Set BPV. ND BOP's. NU the adapter flange and 6-1/8" 5M tree. Install tree test plug and test to 5000 psi with diesel. Pull.tree test plug and BPV. Test tubing x casing annulus to 3000 psi for 30 minutes. Shear RP valve and freeze protect. Set BPV. Release rig. RECEIVED DEC 2 1 199~ A!sska Oil & Gas Cons. Commission Anchorage Redrill Plan Summary Page 4 PRUDHOE BAY DRILLING GROUP $£h]umberge£ , ,, ,. ,, , .. i I DS 09-34A (P2) VERTICAL SECT;ION VIEW Section at: TVD Scale.' Dep Scale" Drawn ' .20 inch = 400 feet inch = 400 fee[ ~1/30/93 c] E~ F~ : Iii Jl Marker Identi¢icafion MD BKB SECTN INCLN A] TIE-IN/KOP 6/100 9200 7228 i375 50.60 END OF 6/]00 CURVE¢I t003§ 7957 ]473 2.31 SIARI 6/100 CURVET2 10062 7984 ]474 2,31 BUILD 3/100 ]0813 8648 lTBt 47.36 BUILD 6/100 ]0911 8713 t855 50.32 · £ND OF 6/100 BUILD !1573 8933 2465 90.00 TARGET / 7" SLIDE i1573 8933 2465 90.00 START 3/100 LEFT fan 11623 8933 2515 90.00 ENO OF 3/100 ~URN liB61 8933 2752 90.00 TO 12585 8933 3451 90.00 800 lO00 1200 1400 ]600 1~0 2000 2200 2400 2600 Sect lan Departure 28O0 3000 3200 3,100 3600 3800 4000 4200 4400 {~n-~drill fzJy3 (1934AI)2 01.~ 4:3~ PK 1] /nadri ? ] SchYumberiTer PRUDHOE BAY DRILLING GROUP DS 09-30A' "Yi" PLAN VIEW -_ _. CLOSURE .... ' 5741 feet at AzimUth DECLINATION - 30.000 E SCALE ' ~ inch : 300 feet DRAIfN ' :~ :1/30/93 I ; M..a. rkcr Ident i f ~cat ion ,' N/S E/W i' E-I~//~OP 6/100 ~ 4312 72,1 6, ..~O ~ 6/I00 C~VE~I . / 4658 769 CI STAR[ 6/~00 C~VEt2 4659 770 ~] BUILD 3/~00 4706 J074 [] BUILD 6/t00 47~7 F) [~0 Or 6/100 BUILa 48~0 ]750 G) rAfiGEl / 7' SttOE 4610 lit STAll 3/100 LEFI [~l,i 4618 1799 il END ~ 3/100 lUSH 4~9 JJ TD 5062 2709 HD 9200 10062 lo~ / ii§?3 ii861 1256§~' ; l ! .! BDO0 -5850 -5700 -5550 -5400 -5250 5100 4950 4800 I I-- 0 300 45O 500 750 EAS! -> | : ' '---- 4350 , , I ; 900 ~050 1200 1350 1500 ~650 1800 IgF~ 2100 2250 2400 2550 2700 2050 3000 ' - -' STATE OF ALASKA A .,KA OIL AND GAS CONSERVATION COMMIt APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation Shutdown__ Re-enter suspended well__ Alter casing . Repair well __ Plugging X Time extension Stimulate__ Change approved program Pull tubing __ -- Variance .__ Perforate__ Other X __ Plugback for redrlll 2. Name of Operator ARCO Alaska,/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory .__ Stratigraphic__ Service 4. Location of well at surface 1763' NSL, 1036' WEL, SEC. 2, TION, R15E At top of productive interval 2384' NSL, 50' WEL, SEC. 35, T11N, R15E At effective depth 2380' SNL, 151' EWL, SEC. 36, T11N, R15E At total depth 2335' SNL, 169' EWL, SEC. 36, T11N, R15E R EW'E ib ~ DEC' 2 1 199,5 Alaska 0ii & Gas Cons. Commission Anch0r~e 12. Present well condition summary Total depth: measured true vertical 12O59 8977 feet Plugs (measured) feet 6. Datum elevation (DF or KB) KBE = 55' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 9-34 9. Permit number 85-69 10. APl number 50- 029-21329 11. Field/Pool Prudhoe Bay Field/Oil Pool Effective depth' measured 11815 feet true vertical 8865 feet Junk (measured) F/Il@ 11815'MD (3/15/92) Casing Length Size Structural Conductor 113' 20" Surface 2457' 13-3/8" Intermediate Production 11315' 9-5/8" Liner 930' 7" Perforation depth: measured All perforations squeezed but leaking Cemented Measured depth True vertical depth 1800 # Poleset 113' ,_ /! 400 CS II 500 sx "G'/300 sx CS ! t~ ~ ~.~)13Y0' 300 sx Class "G"""~1/1 124'-12054' 113' 2512' 8660' 8974' true vertical All perforations squeezed but leaking Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, pcT @ 11099'MD; 4-1/2", 12.6//, L-80, PCT @ 11191'MD Packers and SSSV (type and measured depth) Baker SB-3 packer @ 11078'MD; 5-1/2" Camco BAL-O SSSV @ 2174, MD 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 1/15/94 16. If proposal was verbally approved Name of al)prover Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. I her.,~ertify that the foregoing is true and correct to the best of my knowledge. Signed X~f~ /,,,~~ Title Drilling Enginoer Supervisor / ' ( / FOR COMMISSION USE ONLY Conditions of approval: Notify Cumfnission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission ~.~/~ Form 10-403 Rev 06/15/88 Commissioner Date /r.~/~ r_~/~ SUBMIT IN TRIPLICATE DS9-34A Plugback Schematic Top of 7" liner @ 9050' MD Window in 9-5/8" @ 9200 ' MD Bridge plug @ 9450' Tubing cut @ 9500' TOC @ 11,2OO' Top Perforation' 11,409' 7" Liner shoe: 12,059' Target Displacement: 1708' RECEIVED DEC 2 1 199~ Alaska Oil & Gas Cons. Commission Anchorage 4.~.5"._SlottedLnr J ~ Wellbore B TD Displacement: 2040' Wellbore A; 2703' Wellbore B ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE . 1) Fee ~/2,--. ,..~.:_,. ,.~ C 2 ) Loc .,,~<_ ,,'~ ,--:. :,,'~, -~ [2 thru 8] (3) Admin (4) Casg (5) BOPE [10 & 13 [14 thru 22] [23 thru Company /~,/r ~.:, _ (_--~ Lease & Well YES NO '/RE~RKS 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... '~ 5. Is sufficient undo. dicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... ~.. ,-, 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ '~ 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... ,~ Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... ~' Does well have a unique name & nLrnber ................................ /~ Is conductor string provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~- Is enough cement used to circulate on conductor & surface ............ ~ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. .(j/~- Is well to be kicked off from an existing wellbore ................... (~ Is old wellbore abandonment procedure included on 10-403 ............. ~ Is adequate wellbore separation proposed ............................. kjLl~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~-~ .psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other ~-' '~ / '~/~" 29 ~ ,/~.~ ~.,,',~ ?..~ · [29 thru 31] 30. 31. , . (7) Contact /~'~ i~,~..,/G~'~ 32 ~ F" ~ - .... ":~ ~,~'? , ~ ° [32] (8) Addl 33. geo 1 ogy' eng i nee r ing: DWJ~ RADI?--' 2,"I-' TAB=~: ev 6/93 o/6.011 FOR EXPLORATORY @ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requirements ............................................. i INITIAL GEOL UNIT ON/OFF POOL . CLASS STATUS AREA ~ SHORE / ~~:'zL. ~'.,'i / ~ "--'~" l " , Additional MERIDIAN: , remarks' UM ~( WELL TYPE' Exp/~., ," Inj Red rill ~ Rev SM O -rZ ~O IT1 I--.-I Z 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. o -Iv t~ t:~ O ALASKA INC D.S. 9 -34A PH PRUDHOE BAY Run 1' 06 - March - 1994 DLLIACICNIGR 9120 11658 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6167.00 R. ECK SEE REMARKS D.S. 9-34A PH 500292132970 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 21-MAR-94 RUN 2 RUN 3 2 10N 15E 1763 1036 52.40 51.40 26.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 REMARKS: 9.625 9198.0 11680.0 DLL/AC/CN/GR. LOGS WITNESSED BY: SEITZ, OWENS, LEVINSON. CIRCULATION STOPPED AT 09: 00, 06-MAR-94. PIPE CONVEYED LOGGING OPERATION. LOG DEPTH WAs SHIFTED UP 18' TO MATCH DRILLERS DEPTH. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, 8.5" BOREHOLE CORRECTION, CHISM FILTERING ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GR BCS DLL 2435 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9198.0 11594.0 10492.0 11658.0 9198.0 11628.0 10450.0 11595.5 BASELINE DEPTH LL3 9198.0 9198.0 9241.0 9241.0 9286.0 9285.5 9300.0 9299.5 9331.0 9331.0 9339.5 9339.5 9393.0 9393.5 9401.0 9401.0 9423.5 9423.5 9450.5 9450.5 9457.0 9456.5 9526.5 9526.5 9557.5 9558.0 9621.5 9621.0 9626.0 9626.0 9703.5 9703.0 9732.0 9732.5 9744.0 9744.0 9799.0 9799.0 9862.0 9862.0 9894.0 9894.5 9906.0 9906.0 9957.5 9957.5 9980.5 9980.5 9996.0 9996.5 10017.0 10017.0 10035.0 10035.0 10068.5 10068.0 10092.0 10092.0 10136.0 10135.5 10156.5 10156.0 10169.0 10169.0 10172.0 10172.0 10227.5 10228.0 10237.0 10237.0 10249.5 10250.0 10254.0 10254.5 10256.5 10256.5 10259.0 10258.5 10283.0 10283.0 all runs merged; no EQUIVALENT UNSHIFTED DEPTH DT NPHI 9198.0 9198.0 10286.5 10288.5 10292.5 10294.0 10300.5 10373.5 10402.0 10409.0 10415.5 10422.0 10427.5 10431.5 10434.0 10440.0 10442.5 10449.5 10461.0 10463.5 10480.0 10484.0 10499.5 10501.0 10508.5 10510.0 10512.5 10513.0 10522.0 10522.5 10525.5 10546.0 10551.5 10554.0 10554.5 10562.5 10563.0 10563.5 10574.0 10574.5 10580.0 10588.5 10596.5 10597.0 10601.5 10602.0 10604.5 10605.0 10623.5 10624.0 10632.0 10632.5 10652.0 10655.5 10656.0 10658.0 10672.0 10672.5 10689.0 10692.0 10693.5 10694.0 10287.0 10288.5 10293.0 10295.0 10300.5 10373.0 10401.5 10409.0 10415.5 10422.0 10428.0 10431.5 10435.0 10440.5 10442.5 10449.5 10461.0 10464.0 10480.5 10501.0 10510.0 10513.0 10522.5 10525.5 10551.5 10554.5 10563.5 10597.0 10606.0 10623.5 10632.0 10652.5 10656.5 10673.0 10691.5 10694.5 10512.5 10522.0 10555.0 10562.5 10574.0 10596.5 10602.0 10605.0 10632.0 10655.5 10672.0 10693.5 10484.0 10499.5 10508.5 10512.5 10522.0 10546.0 10563.5 10574.5 10580.0 10588.0 10596.0 10601.5 10605.0 10623.0 10632.5 10658.0 10689.0 10693.5 10698.0 10708.5 10719.5 10736.0 10743.0 10744.5 10745.5 10746.0 10751.0 10754.5 10758.0 10758.5 10792.5 10795.5 10818.5 10837.0 10837.5 10846.5 10847.0 10859.5 10880.0 10880.5 10885.0 10890.0 10893.0 10907.5 10921.0 10953.0 10959.5 10978.5 10991.5 10992.0 11005.5 11006.0 11014.0 11018.5 11031.0 11034.5 11041.5 11042.0 11042.5 11047.5 11081.0 11082.0 11093.5 11094.0 11096.0 11107.0 11123.0 11128.0 11132.0 11132.5 11134.5 11156.5 11164.5 11172.0 11190.0 11190.5 11197.5 11207.0 10698.0 10720.5 10735.5 10742.0 10745.5 10758.5 10796.0 10993.5 11006.5 11034.5 11042.5 11098.5 11124.0 11133.0 11190.5 10720.0 10736.5 10746.0 10759.0 10792.0 10819.5 10837.5 10846.5 10879.5 10907.5 10991.0 11005.5 11041.5 11047.5 11082.5 11094.0 11107.0 11127.5 11132.0 11135.0 11189.5 11198.0 11206.5 10709.0 10719.5 10745.0 10752.0 10754.5 10758.5 10792.5 10837.5 10846.5 10859.5 10880.0 10884.5 10890.0 10893.5 10921.5 10953.0 10959.0 10978.5 10992.0 11014.5 11019.0 11031.0 11042.5 11081.0 11093.5 11107.0 11127.5 11156.5 11164.0 11172.0 11211.5 11212.0 11222.5 11223.0 11227.5 11271.0 11274.5 11279.5 11280.0 11283.5 11302.0 11305.0 11308.5 11309.0 11314.5 11315.0 11327.5 11328.0 11330.5 11349.0 11360.0 11371.5 11381.0 11383.5 11389.0 11389.5 11402.0 11408.5 11458.0 11458.5 11463.5 11469.5 11473.0 11475.0 11475.5 11478.0 11492.0 11506.5 11507.0 11515.0 11519.0 11528.5 11666.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DLL 2435 $ REMARKS: 11211.5 11213.0 11211.5 11223.0 11223.0 11228.5 11227.5 11228.0 11270.0 11274.5 11279.5 11279.5 11283.0 11301.5 11301.5 11301.0 11304.0 11304.5 11308.5 11307.5 11314.0 11314.0 11315.5 11327.5 11327.5 11330.5 11349.0 11360.5 11360.0 11371.5 11381.5 11384.0 11388.5 11389.5 11402.0 11408.5 11457.5 11458.5 11463.0 11469.5 11475.0 11457.0 11473.0 11475.5 11475.5 11477.5 11507.0 11491.0 11506.5 11519.5 11515.5 11528.5 11666.0 11666.0 11666.0 RUN NO. PASS NO. MERGE TOP 1 7 9198.0 1 7 10492.0 1 7 9198.0 1 7 10450.0 MERGE BASE 11594.0 11658.0 11628.0 11595.5 OPEN HOLE portion of MAIN PASS. LLD, SP, MTEM, TEND, & TENS WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. / ? ?MATCH1. OUT / ? ?MATCH2. OUT CN WN FN COUN STAT / ? ?MATCH3. OUT $ : ARCO ALASKA INC. : D.S. 9-34A PH : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL3 DLL 68 1 OHMM 4 6 LLD DLL 68 1 OHMM 4 7 SP DLL 68 1 MV 4 8 MTEM DLL 68 1 DEGF 4 9 NPHI 2435 68 1 PU-S 4 10 FUCT 2435 68 1 CPS 4 11 NUCT 2435 68 1 CPS 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 236 Tape File Start Depth = 11666.000000 Tape File End Depth = 9198.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59245 datums Tape Subfile: 2 533 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 7 DEPTH INCREMENT: FILE S~Y PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: 0.5000 START DEPTH 9119.0 STOP DEPTH 9198.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 9-34A PH : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 2 TEND GR 68 1 LB 4 3 TENS GR 68 1 LB 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 4 Tape File Start Depth = 9198.000000 Tape File End Depth = 9090.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 869 datums 31 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 7 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9119.0 11594.0 AC 11491.0 11658.5 DLL 9190.0 11628.0 2435 10450.0 11600.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 06-MAR-94 FSYS REV. J001 VER. 1.1 900 06-MAR-94 438 07-MAR-94 11680.0 0.0 9120.0 11658.0 1200.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV BRID BRID CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC $ SWIVEL SUB BRIDLE ISOLATOR BRIDLE ISOLATOR CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG TOOL NUMBER 3944NA 3997XA 3997XA 3974XA 2806XA 1309XA 2435XA 3506XA 3923NA 3923NA 3967XA 1229EA/1229MA 3967XA 1609EB/1603MA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9198.0 9198.0 BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 9-34A PH : PRUDHOE BAY : NORTH SLOPE : ALASKA 9.80 65.0 9.0 5.6 176.0 0.102 0.041 0.097 0.000 0.130 0.000 THERMAL SANDSTONE 0.00 8.500 0.0 70.0 176.0 71.0 0.0 60.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR AC 68 1 GAPI AC AC 68 1 US/F ACQ AC 68 1 CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM IS DLL 68 1 A ID DLL 68 1 A ES DLL 68 1 MV ED DLL 68 1 MV SP DLL 68 1 MV TEMP DLL 68 1 DEGF CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 19 SSN 2435 68 1 CPS 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 859 966 BYTES * 76 Tape File Start Depth = 11666.000000 Tape File End Depth = 9090.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 265346 datums Tape Subfile: 4 944 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 6 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11367.0 11585.0 AC 11431.0 11650.0 DLL 11401.0 11619.0 2435 11373.0 11591.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV BRID BRID CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC $ SWIVEL SUB BRIDLE ISOLATOR BRIDLE ISOLATOR CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 06-MAR-94 FSYS REV. J001 VER. 1.1 900 06-MAR-94 400 07-MAR-94 11680.0 0.0 9120.0 11658.0 1200.0 TOOL NUMBER 3944NA 3997XA 3997XA 3974XA 2806XA 1309XA 2435XA 3506XA 3923NA 3923NA 3967XA 1229EA/1229MA 3967XA 1609EB/1603MA 8.500 9198.0 9198.0 FLOPRO 9.80 65.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 9-34A PH : PRUDHOE BAY : NORTH SLOPE : ALASKA 9.0 5.6 176.0 0.102 0.041 0.097 0.000 0.130 0.000 THERMAL SANDSTONE 0.00 8.500 0.0 70.0 176.0 71.0 0.0 60.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 GR AC 68 1 GAPI AC AC 68 1 US/F ACQ AC 68 1 CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM IS DLL 68 1 A ID DLL 68 1 A ES DLL 68 1 MV ED DLL 68 1 MV SP DLL 68 1 MV TEMP DLL 68 1 DEGF CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 107 966 BYTES * 76 Tape File Start Depth = 11657.000000 Tape File End Depth = 11337.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26490 datums Tape Subfile: 5 190 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS 94/ 3/19 01 **** REEL TRAILER **** 94/ 3/20 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 20 MAR 94 8:48a Elapsed execution time = 22.30 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-40026 T. SLIMS G. BECK D.S. 9-34A 500292132901 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 02-AUG-96 MWD RUN 2 AK-RB-940308 T. SAIMS G. BECK MWD RUN K. TOWNS G. BECK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 K. TOWNS G. BECK MWD RUN 5 M. GABEL G. BECK MWD RUN 6 HENNINGSEN G. BECK MWD RUN 7 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) iKELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD HENNINGSEN G. BECK 2 I0N 15E 1763 1036 48.00 46.00 19.70 AUG 1 2 199G Alast(~ Oil & Gas Cram, Commi~ion ,~chorage OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.625 10961.0 PRODUCTION STRING 6.750 12631.0 REMARKS: MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. RUNS 1-2 ARE DIRECTIONAL AND GAMMA RAY (SGRD), UTILIZING SCINTILLATON DETECTOR (NGP). RUNS 3-7 ARE DIRECTIONAL AND DUAL GAMMA RAY (DGR/SGRC), UTILIZING GEIGERMUELLER TUBE DETECTORS. SCINTILLATOR GAMMA AND GEIGER MUELLER GAMMA ARE MERGED AT 11423' MD. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10936.0 RP 11426.0 $ BASELINE CURVE FOR SHIFTS: UNKNOWN CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 10992.0 10974.0 11005.5 10989.5 11031.0 11004.0 11035.0 11008.5 11042.5 11022.5 11045.5 11026.5 11047.5 11030.0 11049.5 11033.5 11113.5 11114.5 11128.5 11130.5 11157.0 11156.0 11161.0 11160.5 11212.0 11201.5 11217.0 11207.5 11223.0 11228.0 11227.5 11236.5 11268.5 11280.5 11277.5 11285.5 11463.5 11465.0 11470.0 11471.0 11473.0 11475.0 11475.0 11476.0 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD $ REMARKS: DATA SOURCE TOOL CODE all bit runs merged. STOP DEPTH 12559.0 12566.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 10695.0 11192.0 2 11192.0 11630.0 3 11630.0 11843.0 4 11843.0 11955.0 5 11955.0 12211.0 6 12211.0 12489.0 7 12489.0 12630.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. /??SHIFT.OUT $ CN : ARCO ALASKA, INC. WN : D.S. 9-34A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 113 Tape File Start Depth = 12645.000000 Tape File End Depth = 10900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27929 datums Tape Subfile: 2 232 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10919.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE soFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11145.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 23-MAR-94 MWD 1.98 1.07 MEMORY 11192.0 10965.0 11192.0 0 .0 .0 TOOL NUMBER NGP 307 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 10961.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.30 56.0 10.0 40000 4.5 .000 .000 .000 .000 .0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 9-34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR 4 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 11195.000000 Tape File End Depth = 10915.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER-**** LIS representation code decoding summary: Rep Code: 68 1684 datums Tape Subfile: 3 70 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: 'LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11147.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG iNTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11613.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 25-MAR-94 MWD 1.98 1.07 MEMORY 11630.0 11192.0 11630.0 0 .0 .0 TOOL NUMBER NGP 307 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 10961.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.30 54.0 10.0 41000 4.8 .000 .000 .000 .000 .0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT GR DATA FROM RUN 2 IS ONLY USED FROM 11147'-11423' MD. $ : ARCO ALASKA, INC. : D.S. 9-34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 12 Tape File Start Depth = 11615.000000 Tape File End Depth = 11145.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30753 datums Tape Subfile: 4 76 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11423.0 EWR4 11429.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11774.0 11781.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 26-MAR-94 MWD 1.98 1.07 MEMORY 11843.0 11630.0 11843.0 0 .0 .0 TOOL NUMBER HN0001GR4 HN0001GR4 6.750 10961.0 FLO-PRO 9.20 56.0 9.7 40500 6.0 .110 .050 .080 .150 77.0 168.0 77.0 77.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3. $ : ARCO ALASKA, INC. : D.S. 9-34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 28 Tape File Start Depth = 11850.000000 Tape File End Depth = 11420.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8573 datums Tape Subfile: 5 93 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11739.0 EWR4 11745.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIM UMANGLE: STOP DEPTH 11867.0 11874.0 27-MAR-94 MWD 1.98 1.07 MEMORY 11955.0 11843.0 11955.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER HN0001GR4 HN0001GR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 10961.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.20 58.0 9.8 40000 6.0 .100 .060 ..080 .130 90.0 159.0 90.0 90.0 NEUTRON TOOL MATR I X: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 4 .- $ : ARCO ALASKA, INC. : D.S. 9-34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 FET MWD 68 1 HR 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 180 01 1 4 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 15 998 BYTES * Tape File Start Depth = 11960.000000 Tape File End Depth = 11735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34362 datums Tape Subfile: 6 80 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11868.0 EWR4 11875.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12151.0 12158.0 28-MAR-94 MWD 1.98 1.07 MEMORY 12211.0 11955.0 12211.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER HN0001GR4 HN0001GR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 10961.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.30 57.0 10.0 40000 5.9 .090 .050 .070 .140 87.0 164.0 87.0 87.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 5 $ : ARCO ALASKA, INC~ : D.S. 9-34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 FET MWD 68 1 HR 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 180 01 1 4 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 20 Tape File Start Depth = 12165.000000 Tape File End Depth = 11865.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13382 datums Tape Subfile: 7 85 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12144.0 EWR4 12151.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12418.0 12425.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS . 4 $ 29-MAR-94 MWD 1.98 1.07 MEMORY 12489.0 12211.0 12489.0 0 .0 .0 TOOL NUMBER HN0001GR4 HN0001GR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 10961.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.30 57.0 9.8 40000 5.9 .O5O .040 .040 .080 116.0 162.0 116.0 116.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .0 0 sa~Xq 866 :gSBuaI paoDaa ~nm~x~ sasXq E9 :g~BuaI paoDaa ~n~u~ · ''sp~ooa~ 88 8 :aI~qns ad~ smn$~p ~000~ 89 :apoo da~ :Xa~m-~ns 6u~poD~p ~poD uo~u~s~ad~a SI~ 00000g'0 = Bu!o~ds IaAa~ aI!~ ad~ 000000'0~IEI = qgdaG puH aI~ ad~A · SH~X~ 866 :spaooaH ~$uG I~$O,T, I0 018 06 ~ 9 I0 08I 06 ~ 9 9~ 0EI 06 ~ 9 99 0EI 06 9 ~ 9~ 0EI 06 9 ~ 9~ 0~I 06 ~ ~ I0 0I£ 06 ~ ~ pON SlO dAA dAA qSBuaq az~s A~D A~D 6Oq S$~UD saIdm~s apoD IOOA amgN :saA~nD £ & :aI g~dap ad~ HknfH~ HH~ HA~HG HNO (99 #~cIXJ.,) G~ODHH ,T.~IHO.~ ~ ~HS~I~ : H~O~S H~HON : X~ HOHf~IH~ : ~9E-6 'S'G : · DNI '¥HSk~I~ OOH%f : · 9 N/1H GM&4 NnOD N& NM : S HHkSTHH Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12419.0 EWR4 12426.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12559.0 12566.0 30-MAR-94 MWD 1.98 1.07 MEMORY 12630.0 12489.0 12630.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER HN0001GR4 HN0001GR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 10961.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.30 65.0 9.6 38000 5.8 .070 .050 .050 .110 114.0 170.0 114.0 114.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 7 .' $ : ARCO ALASKA, INC. : D.S. 9-34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 15 Tape File Start Depth = 12645.000000 Tape File End Depth = 12415.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17071 datums Tape Subfile: 9 80 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 10 is type'' LIS 96/ 8/ 5 01 **** REEL TRAILER **** 96/ 8/ 6 01 Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 6 AUG 96 2:01p Elapsed execution time = 6.92 seconds. SYSTEM RETURN CODE = 0