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B && , (C . -1 . -* =+ &* ( . + . =+. ++5 * 2, & . 2 1+ & &2 * * +. 1+ & . *& . &*2&* . 1 D 1, , & 0 0:6! B E 0% -@4 ( , . + . 1 , ++52 * & &2 * +. . 1+ +. 2 & . & 0 0:6! 4 '+ 8 & '+ 8 < =+ !8"6 @ 00 1+ * , +& . & . 1+ 6WHYH'UDNH 6HQLRU:HOOV(QJLQHHU Steven G. Drake Digitally signed by Steven G. 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' - .7 89:2 : 9 71 ; .2 $119 3$92 932' - $$.)<33 < 8983=$<99<1&7 123 $>2$9< 898$:&' ???<$3(19 $8-1??? . @ABA'$%)&C 7 89< 898 3$-A @AB$8-9 ) C 3<991<1- '-' @ABD$8A8$-9 D- '8 )D&) 1-$E7)' $>3991-$A 8$<' @ABD$8)1'$8 9&)&C3$$-' $ -7C 33<1$' 9<99182)'9 $$8)' 3-$$ 1' 7 @AB-$$@9B$$ >9'9<9>9 8 $>3991$'>>8> 8$3$'D$1 $ $>399339$9$3A' : /#"!*5"!*! /"F, "!0 MEMORANDUM TO: Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission " I' _GATE: 10/18/2020 FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector KRU 21VI-18 CPAI , PTD 1910190; Sundry 320-248 10/14/2020: 1 traveled out to KRU 21VI-18 to witness the surface abandonment. Pat VanCamp was the CPAI representative on location. The cut-off looked fine and was approximately 4 feet below tundra grade. Cement was set-up and hard in all strings. I noticed a mistake in the Permit to Drill number on the marker plate and that was swiftly fixed by the welder. No other issues. Attachments: Photos (2) -- 2020-1014—Surface—Abandon —KRU-2M- I 8 ae.docx Page 1 of 2 co C� L C co N LU Y o I v cn C O E a O U �O =O �Qo Q >+ N W-0 O V N � � O " ) — O Cl) 0— T-- Y�1 Operations shutdownPlug Perforations Fracture Stimulate Repair WellAbandon1. Type of Request: Change Approved ProgramPerforate Other Stimulate Pull TubingSuspend Perforate New Pool Re-enter Susp Well Alter CasingPlug for Redrill Other: Cement Squeeze 5.Permit to Drill Number:4.Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. W ell Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool?N/A NoWill planned perforations require a spacing exception? Yes 10. Field/Pool(s):9. Property Designation (Lease Number): 11. Junk (MD):Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): 7,926'N/A CollapseCasing Conductor Surface Production Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratoryStratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14.Estimated Date for WDSPLWINJOILCommencing Operations:Suspended WAGGASDate:16. Verbal Approval:SPLUGGSTOR Commission Representative: GINJ AbandonedOp Shutdown Steve Drake Contact Name:Steve Drake Sr. Wells Engineer Contact Email: Contact Phone:(907) 263-4062 Date: Sundry Number:Conditions of approval: Notify Commission so that a representative may witness BOP Test Mechanical Integrity Test Location ClearancePlug Integrity Other: Post Initial Injection MIT Req'd? NoYes Spacing Exception Required? Subsequent Form Required:NoYes APPROVED BY Date:ONCOMMISSIONERApproved by:THE COMMISSI Sr Res EngSr Pet GeoSr Pet EngComm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.191-019 7405 P. O. Box 100360, Anchorage, Alaska 99510 50-103-20151-00-00 KRU 2M-18 ADL 25586 Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 6,251'2500psi61597815 BurstTVDMDSizeLength 2,793'3,070'9 5/83,031' 123'123'16''83' 6,239'7,910'7''7,871' 7,406' Packers and SSSV MD (ft) and TVD (ft): Tubing MD (ft):Tubing Grade:Tubing Size:Perforation Depth TVD (ft):Perforation Depth MD (ft): 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. PLUGGEDPLUGGED J-553.500'' PACKER - OTIS HVT RETRIEVABLE PACKER SAFETY VLV - CAMCO TRDP-4A-RO SAFETY VALVE MD= 7380 TVD= 5851 MD= 1824 TVD= 1799 Authorized Name: Authorized Title:Steve.G.Drake@cop.com Authorized Signature: COMMISSION USE ONLY Perforate Reppair Well ServiceDevelopmentExploratoryStratigraphic BOP Test Mechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 6/12/2020 By Samantha Carlisle at 10:11 am, Jun 10, 2020 320-248 Steven G. Drake Digitally signed by Steven G. Drake Date: 2020.06.10 10:01:25 -08'00' DSR-6/10/2020 Surface abd VTL 6/11/20 X SFD 6/11/2020 SFD 6/11/2020 10-407 X X AOGCC inspection is required after cutoff and before any remedial cementing. Communicate results of PT to AOGCC after milling to ~1700' MD, after setting CIBP and after cement plug to ~885'. State witnessed PT and tag required. VTL 7/24/20 Comm. 7/24/2020 dts 7/24/2020 RBDMS HEW 7/24/2020 General Well Work Request Form GWWRv4.0c 5/29/20 klm 2 Well: 2M-18 Date of Request:6/1/2020 Request SPOC:CPF2 PE David/Adam x7519, pgr 252 Well Type:Producer Req. Written by:Steve Drake, 263-4062 Job Scope: Shut-In Reason Code:702 Well Integrity Other Well Shut in Date (if SI): Prioritization Category: Budget Category: Network: 10405974 Network Description:Wells Group use Well Work is not justified via increased production Preventive Maintenance Program Request Current Well Data After Well Work Data Current Oil Rate (BOPD) 0 Post-Job Oil Rate (BOPD) 0 Risked NOB (BOPD) Enter Success Probability Last SBHP 3609 psi Last Tag Surface H2S (PPM):250 ppm on 2M-24 12/15/19 SBHP Date 8/22/2014 Tag Date 2/17/2019 Any Fluid Restriction on Well?No SBHP Datum (TVD/SS?)5975 SS Max Inclin.47°Max Dogleg 7° Min. I.D (at/above work)2.99''Max Incl. Depth 5,700'md Max Dogleg Depth 1,700'md Cement Sqz Kuparuk Base Expense Well Work Justification & Objectives (and date required if appropriate): 2M-18 is a LTSI injector that was SI in late 2014. A P&A was exectued in early 2018 although failed due to a pressure build up on the tubing. The well has been on an open bleed since June of 2018. This procedure will outline the steps to remove the cement down to 1700' MD in the tubing and perform cement squeeze/job. Risk/Job Concerns: Well has no tree. (See WH Photo tab in this procedure) ~18 gallons of Portland Type II cement in top 40' of tubing. ~13 barrels of 15.7 ppg AS1 cement from 1552' to 40' inside of tubing. 15.8 ppg Class G from 1552' down. Highest tubing string perforations are at 1550-1552' MD. Steps: 2" CTU (Mill cement in 3.5" tubing) 1. Contact wells support (Miles/Marty x 7060) to ensure the proper equipment (crossover, flow cross, double stacked swab) have been installed. 2. Contact ReedHycalog rep (Marty Robertson 907-317-5573) to ensure quantity (2) 2.69" x 2.98" undersized PDC bicenter bits are available for cement milling. (see Bit Recommendations Tab) 3. Contact 3rd party vendor for motor milling equipment/BHA. 4. MIRU CTU and associated support equipment. Ensure adequate riser is picked up to allow some pipe movement during surface milling. 5. MU aforementioned bit to the BHA and RIH. 6. Pumping with slick seawater, begin milling on cement, keeping nose of bit planted in cement to ensure a good pilot hole. Utilize gel sweeps liberally througout milling of cement. 7. Use caution while milling top 40' of Portland Cement as it will be harder/more brittle than the AS1 below. Use caution as well near transition zones between one type of cement to the next. 8. Mill through cement base which is expected near the perforations at 1550' MD. Should expect ROP's of 100-150'/hr. which could take from 17 to 11 hours to complete. 9. USE CAUTION when exiting cement base. Well may drink or have slight pressure. DO NOT PASS SSSV @ 1823' RKB with bi-centerbit. 10. Once TD is reached pump 5 bbl gel sweep to the bit & chase out of hole at max comfortable pump rate while pulling ~50ft/min. 11. RBIH to 1700' and place 60/40 meth freeze protect. DO NOT USE DIESEL. 12. Pop off well. RDMO. Lay down unit for the night. DHD - (PT tubing and perform DDT) 1. PT tubing to 2500 psi. 2. Perform DDT on tubing. Bleed tubing to zero and monitor for build up for a few hours. 3. Bleed tubing to zero and SI for BUR overnight. *********** PROCEDURE CONTINUED ON NEXT PAGE ******************** 2M-18 Cement Squeeze 06-01-2020 SGD Rev 1 Printed 7/24/2020 Page 2 Well: 2M-18 Date of Request:6/1/2020 Request SPOC:CPF2 PE David/Adam x7519, pgr 252 Steps Continued (list service type): Relay - (Set plug) 1. MIRU Relay and associated equipment. 2. Brush plug setting area from 1700-1800' RKB. Concentrate around 1770' RKB. Should not be able to pump into well, no FLUSH requested. 3. Perform dummy plug drift down to 1800' RKB. 4. Set composite plug @ approximately 1770' RKB in the middle of a full joint above SSSV. 5. Pressure test plug to 2500 psi and perform draw down test to 0 psi. Troubleshoot any failing positive pressure test. 6. SI Well with 0 psi for 24 hour monitor. 7. RDMO. Well ready for cement job. 2" CTU (Pump cement in 3.5" tubing) 1. Contact Halliburton cement (town: Karl Molvig/Julia Nichols 435-219-2014/303-710-3932 slope: Mark Dean 303-506-8462) to ensure cement product and crews are available and ready. Will utilize a blend of 15.8 ppg Class G with a gasblock/latex slurry. HAL equivalient of 1% S001 and 2 sacks per barrel latex additive. (Cement design pump schedule to follow) 2. MIRU Halliburton cementers along with other associated equipment. 3. MU cement nozzle and RIH pumping min rates with sea water to TD. 4. Clean up with one volume of sea water (approximately 15 barrels) 5. Clean up with one volume of surfactant wash. 6. Place 8 barrels of 15.8 ppg Class G cement with 1% S001 and 2 sacks per barrel of latex additive. (see cement design) 7. Keeping cement above the nozzle, lay cement in from plug to 885' RKB. 8. Pull nozzle up into the flow cross and monitor open top tanks for clean returns. 9. (Optional) Drop ball to side jet and clean up top 6-10 feet of tubing and up through tree and monitor for clean fluid (slic k seawater) at tanks. 10. Once clean fluids are seen at tanks trap 2500 psi on WH and monitor for 30 minutes. Add more if necessary. 11. Freeze protect with 60/40 meth water mixture. 12. Pop off well, maintaining 2500 psi WHP. 13. RDMO. Leave well SI for 72 hours. (UCA table says xx hours until calculated hardness) DHD - (PT tubing and perform DDT) 1. PT tubing to 2500 psi. 2. Perform DDT on tubing. Bleed tubing to zero and monitor for build up for a few hours. 3. Bleed tubing to zero and SI for BUR overnight. Relay - (CONTINGENCY PLUG if DHD testing fails) 1. If cement plug does not hold, set composite plug on top of cement plug. 2. MIRU Relay and associated equipment. 3. Brush plug setting area near TOC @ 620' RKB. 3. Perform dummy plug drift down to TOC @ 620' RKB. 4. Set composite plug @ approximately 600' RKB. 5. Pressure test plug to 2500 psi and perform draw down test to 0 psi. Troubleshoot any failing positive pressure test. 6. SI Well with 0 psi for 24 hour monitor. 7. RDMO. Well ready for cement job. 2M-18 Cement Squeeze 06-01-2020 SGD Rev 1 Printed 7/24/2020 Steps Continued (list service type): 2" CTU (Pump cement in 3.5" tubing) 1. Contact Halliburton cement (town: Karl Molvig/Julia Nichols 435-219-2014/303-710-3932 slope: Mark Dean 303-506-8462) to ensure cement product and crews are available and ready. Will utilize a blend of 15.8 ppg Class G with a gasblock/latex slurry. HAL equivalient of 1% S001 and 2 sacks per barrel latex additive. (Cement design pump schedule to follow) 2. MIRU Halliburton cementers along with other associated equipment. 3. MU cement nozzle and RIH pumping min rates with sea water to TD. 4. Clean up with one volume of sea water (approximately 15 barrels) 5. Clean up with one volume of surfactant wash. 6. Pump 15 barrels of 15.8 ppg Class G cement with 1% S001 and 2 sacks per barrel of latex additive. (see cement design) 7. Keeping cement above the nozzle, pull nozzle up into the flow cross and monitor open top tanks for clean/good cement returns. 8. Drop ball to side jet and clean up top 6-10 feet of tubing and up through tree and monitor for clean fluid (slick seawater) at tanks. 9. Once clean fluids are seen at tanks trap 2500 psi on WH and monitor for 30 minutes. Add more if necessary. 10. Freeze protect with 60/40 meth water mixture. 11. Pop off well, maintaining 2500 psi WHP. 12. RDMO. Leave well SI for 72 hours. (UCA table says xx hours until calculated hardness) Well Integrity (Remove wellhead) 1. WOC for 72 hr or until field blend UCA chart shows cement developed 2,000 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. 4. Notify AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 48 hrs in advance of witness). 5. Bleed off T/I/O to ensure all pressure is bled off the system. 6. Remove production tree in preparation for excavation and casing cut. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. REMOVE ANY RESIDUAL DIESEL IN ANNULUS BEFORE MAKING WELLHEAD CUT. 8. Cut off wellhead and all casing strings at 4 feet below original ground level. 9. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 10. Send the casing head with stub to materials shop. Photo document. 11. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips 2M-18 PTD #: 191-019 API #: 50-103-20151-00 12. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 13. Obtain site clearance approval from AOGCC. RDMO. 14. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed. 2M-18 Cement Squeeze 06-01-2020 SGD Rev 1 Printed 7/24/2020 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB to TOP of CMT 1,905.0 3/21/2018 2M-18 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Cement plug 6/21/2018 2M-18 rmclaug Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 123.0 Set Depth (TVD) (ftK 123.0 Wt/Len (lb/ft 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 39.0 Set Depth (ftKB) 3,070.2 Set Depth (TVD) (ftK 2,793.5 Wt/Len (lb/ft 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 39.0 Set Depth (ftKB) 7,909.5 Set Depth (TVD) (ftK 6,239.2 Wt/Len (lb/ft 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Max No 3 1/2 ID (in) 2.99 Top (ftKB) 38.6 Set Depth (ftKB) 7,405.6 Set Depth (TVD) (ftKB 5,869.7 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Item Des Com Nominal ID (in) 38.6 38.6 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,823.7 1,799.0 27.87 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 7,364.6 5,839.9 43.39 PBR OTIS PBR w/10' STROKE, 4" SEAL BORE 2.970 7,380.3 5,851.3 43.35 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 7,395.6 5,862.4 43.32 NIPPLE CAMCO D NIPPLE 2.750 7,405.0 5,869.3 43.30 WLEG OTIS RH BALL SEAT SUB/WL GUIDE (SHEARED), TTL ELMD @ 7393' SWS IPROF 1/5/1999 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) Top Incl (°)Des Com Run Date ID (in) SN 1,770.0 1,751.4 26.52 Composite Plug 2.75" Composite Plug 7/7/2020 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 1,550.0 1,552.0 1,545.6 1,547.6 4/11/2018 4.0 CMT SQZ 0° phasing, 2" Owen Good Hole charges. 1,580.0 1,582.0 1,574.7 1,576.6 4/11/2018 4.0 CMT SQZ 0° phasing, 2" RTG, Owen BH Charges 1,850.0 1,853.0 1,822.3 1,824.9 3/14/2018 4.0 CMT SQZ 0° phase, 2" RTG, Owen BH charges, 12 holes, magnetic decentralizer oriented 90° from low side 1,853.0 1,855.5 1,824.9 1,827.1 3/13/2018 6.0 CMT SQZ 0° phase, 1.69" OD, 2.5' Tbg punch, 15 holes, decentralized to low side 1,866.0 1,873.0 1,836.4 1,842.6 3/13/2018 6.0 CMT SQZ 0° phase, 1.69" OD, 2.5' x 2' (Blank) x 2.5' Tbg punch, 30 holes, decentralized to low side 1,880.0 1,883.0 1,848.8 1,851.4 3/14/2018 4.0 CMT SQZ 0° phase, 2" RTG, Owen BH charges, 12 holes, magnetic decentralizer oriented on top and bottom 1,880.0 1,882.0 1,848.8 1,850.6 3/20/2018 4.0 CMT SQZ 0° phase, 2" Owen Good Hole charges, 8 holes, magnetic decentralizer oriented 180° from low side 6,853.0 6,859.0 5,471.4 5,475.7 2/17/2018 4.0 CMT SQZ 0° phase, 1.56" x 4' Tbg punch, 0.43" EHD, decentralized to low side 6,900.0 6,904.0 5,505.3 5,508.1 2/17/2018 4.0 CMT SQZ 0° phase, 1.56" x 4' Tbg punch, 0.43" EHD, decentralized to low side 7,490.0 7,518.0 5,931.2 5,951.7 C-4, 2M-18 4/16/1995 4.0 APERF 0° phasing; 2 1/8" EnerJet III 7,529.0 7,537.0 5,959.7 5,965.5 A-5, 2M-18 4/16/1995 4.0 APERF 0° phasing; 2 1/8" EnerJet III 7,545.0 7,562.0 5,971.4 5,983.8 A-4, 2M-18 4/16/1995 4.0 APERF 0° phasing; 2 1/8" EnerJet III 7,573.0 7,593.0 5,991.8 6,006.5 A-3, 2M-18 2/27/1992 4.0 IPERF 180° phasing; Oriented 169 deg. CCW; 4 1/2" Csg Gun 7,593.0 7,612.0 6,006.5 6,020.3 A-3, 2M-18 2/27/1992 4.0 IPERF 180°. phasing; Oriented 169 deg. CCW; 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 7,405.0 7,758.0 5,869.3 6,127.2 Cement Plug 2/11/2018 18.5 bbls of 15.8 Class G cement, Bullhead to End of Tbg (EOT) and to 7" below EOT 6,970.0 7,405.0 5,555.6 5,869.3 Cement Plug 2/11/2018 1,905.0 6,853.0 1,870.9 5,471.4 Cement Plug 3/1/2018 168.6 bbls of 15.8 Class G cement, Bullhead down Tbg and into IA 1,905.0 6,853.0 1,870.9 5,471.4 Cement Plug 3/1/2018 40.0 773.0 40.0 773.0 Cement Plug 5/12/2018 23 BBL of 15.7# AS1 w/PressureNet down OA 1,550.0 1,870.9 1,545.6 1,840.8 Cement Plug 5/26/2018 Downsqueezed 20 bbl of 15.7# AS1 w/PressureNet down IA 38.6 1,550.0 38.6 1,545.6 Cement Plug 6/20/2018 74 bbls of 15.7# AS1 cement 38.6 1,770.0 38.6 1,751.4 Cement Plug 6/20/2018 Mandrel Inserts St ati on N Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,232.1 2,910.0 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1999 2 5,487.3 4,503.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/18/1995 3 6,602.5 5,290.9 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/18/1995 4 7,311.9 5,801.6 OTIS LBX 1 1/2 GAS LIFT DMY RM1 0.000 0.0 12/3/1999 2M-18, 7/7/2020 4:03:57 PM Vertical schematic (actual) PRODUCTION; 39.0-7,909.5 IPERF; 7,593.0-7,612.0 IPERF; 7,573.0-7,593.0 APERF; 7,545.0-7,562.0 APERF; 7,529.0-7,537.0 APERF; 7,490.0-7,518.0 WLEG; 7,405.0 Cement Plug; 7,405.0 ftKB NIPPLE; 7,395.6 PACKER; 7,380.3 PBR; 7,364.6 GAS LIFT; 7,311.9 Cement Plug; 6,970.0 ftKB CMT SQZ; 6,900.0-6,904.0 CMT SQZ; 6,853.0-6,859.0 GAS LIFT; 6,602.5 GAS LIFT; 5,487.3 GAS LIFT; 3,232.1 SURFACE; 39.0-3,070.2 Cement Plug; 1,905.0 ftKB Cement Plug; 1,905.0 ftKB CMT SQZ; 1,880.0-1,883.0 CMT SQZ; 1,880.0-1,882.0 CMT SQZ; 1,866.0-1,873.0 CMT SQZ; 1,853.0-1,855.5 CMT SQZ; 1,850.0-1,853.0 SAFETY VLV; 1,823.7 Composite Plug; 1,770.0 CMT SQZ; 1,580.0-1,582.0 CMT SQZ; 1,550.0-1,552.0 Cement Plug; 1,550.0 ftKB CONDUCTOR; 40.0-123.0 HANGER; 38.6 Cement Plug; 40.0 ftKB Cement Plug; 38.6 ftKB Cement Plug; 38.6 ftKB KUP INJ KB-Grd (ft) 44.00 Rig Release Date 11/5/1991 2M-18 ... TD Act Btm (ftKB) 7,926.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015100 Wellbore Status INJ Max Angle & MD Incl (°) 46.91 MD (ftKB) 5,700.00 WELLNAME WELLBORE2M-18 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Notes: General & Safety End Date Annotation 11/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 12/3/1999 NOTE: 7" casing loaded w/193 bbls diesel. 11/28/1999 NOTE: Largest tool to pass w/o problem 2.75" OD 2M-18, 7/7/2020 4:03:57 PM Vertical schematic (actual) PRODUCTION; 39.0-7,909.5 IPERF; 7,593.0-7,612.0 IPERF; 7,573.0-7,593.0 APERF; 7,545.0-7,562.0 APERF; 7,529.0-7,537.0 APERF; 7,490.0-7,518.0 WLEG; 7,405.0 Cement Plug; 7,405.0 ftKB NIPPLE; 7,395.6 PACKER; 7,380.3 PBR; 7,364.6 GAS LIFT; 7,311.9 Cement Plug; 6,970.0 ftKB CMT SQZ; 6,900.0-6,904.0 CMT SQZ; 6,853.0-6,859.0 GAS LIFT; 6,602.5 GAS LIFT; 5,487.3 GAS LIFT; 3,232.1 SURFACE; 39.0-3,070.2 Cement Plug; 1,905.0 ftKB Cement Plug; 1,905.0 ftKB CMT SQZ; 1,880.0-1,883.0 CMT SQZ; 1,880.0-1,882.0 CMT SQZ; 1,866.0-1,873.0 CMT SQZ; 1,853.0-1,855.5 CMT SQZ; 1,850.0-1,853.0 SAFETY VLV; 1,823.7 Composite Plug; 1,770.0 CMT SQZ; 1,580.0-1,582.0 CMT SQZ; 1,550.0-1,552.0 Cement Plug; 1,550.0 ftKB CONDUCTOR; 40.0-123.0 HANGER; 38.6 Cement Plug; 40.0 ftKB Cement Plug; 38.6 ftKB Cement Plug; 38.6 ftKB KUP INJ 2M-18 ... WELLNAME WELLBORE2M-18 General Well Work Request Form GWWRv4.0c 5/29/20 klm 2 Well: 2M-18 Date of Request:6/1/2020 Request SPOC:CPF2 PE David/Adam x7519, pgr 252 Well Type:Producer Req. Written by:Steve Drake, 263-4062 Job Scope: Shut-In Reason Code:702 Well Integrity Other Well Shut in Date (if SI): Prioritization Category: Budget Category: Network: 10405974 Network Description:Wells Group use Well Work is not justified via increased production Preventive Maintenance Program Request Current Well Data After Well Work Data Current Oil Rate (BOPD) 0 Post-Job Oil Rate (BOPD) 0 Risked NOB (BOPD) Enter Success Probability Last SBHP 3609 psi Last Tag Surface H2S (PPM):250 ppm on 2M-24 12/15/19 SBHP Date 8/22/2014 Tag Date 2/17/2019 Any Fluid Restriction on Well?No SBHP Datum (TVD/SS?)5975 SS Max Inclin.47°Max Dogleg 7° Min. I.D (at/above work)2.99''Max Incl. Depth 5,700'md Max Dogleg Depth 1,700'md Cement Sqz Kuparuk Base Expense Well Work Justification & Objectives (and date required if appropriate): 2M-18 is a LTSI injector that was SI in late 2014. A P&A was exectued in early 2018 although failed due to a pressure build up on the tubing. The well has been on an open bleed since June of 2018. This procedure will outline the steps to remove the cement down to 1700' MD in the tubing and perform cement squeeze/job. Risk/Job Concerns: Well has no tree. (See WH Photo tab in this procedure) ~18 gallons of Portland Type II cement in top 40' of tubing. ~13 barrels of 15.7 ppg AS1 cement from 1552' to 40' inside of tubing. 15.8 ppg Class G from 1552' down. Highest tubing string perforations are at 1550-1552' MD. Steps: 2" CTU (Mill cement in 3.5" tubing) - Day 1 1. Contact wells support (Miles/Marty x 7060) to ensure the proper equipment (crossover, flow cross, double stacked swab) have been installed. 2. Contact ReedHycalog rep (Marty Robertson 907-317-5573) to ensure quantity (2) 2.69" x 2.98" undersized PDC bicenter bits are available for cement milling. (see Bit Recommendations Tab) 3. Contact 3rd party vendor for motor milling equipment/BHA. 4. MIRU CTU and associated support equipment. Ensure adequate riser is picked up to allow some pipe movement during surface milling. 5. MU aforementioned bit to the BHA and RIH. 6. Pumping with slick seawater, begin milling on cement, keeping nose of bit planted in cement to ensure a good pilot hole. Ut ilize gel sweeps liberally througout milling of cement. 7. Use caution while milling top 40' of Portland Cement as it will be harder/more brittle than the AS1 below. Use caution as well near transition zones between one type of cement to the next. 8. Mill down to 1700' MD. Should expect ROP's of 100-150'/hr. which could take from 17 to 11 hours to complete. 9. Once TD is reached pump 5 bbl gel sweep to the bit & chase out of hole at max comfortable pump rate while pulling ~50ft/min . 10. RBIH to TD and place 60/40 meth freeze protect. DO NOT USE DIESEL. 11. Pop off well. RDMO. Lay down unit for the night. 2" CTU (Pump cement in 3.5" tubing) - Day 2 1. Contact Halliburton cement (town: Karl Molvig/Julia Nichols 435-219-2014/303-710-3932 slope: Mark Dean 303-506-8462) to ensure cement product and crews are available and ready. Will utilize a blend of 15.8 ppg Class G with a gasblock/latex slurry. HAL equivalient of 1% S001 and 2 sacks per barrel latex additive. (Cement design pump schedule to follow) 2. MIRU Halliburton cementers along with other associated equipment. *********** PROCEDURE CONTINUED ON NEXT PAGE ******************** 2M-18 Cement Squeeze 06-01-2020 SGD (003).xlsm Printed 6/9/2020 SUPERCEDED VTL 7/24/20 Page 2 Well: 2M-18 Date of Request:6/1/2020 Request SPOC:CPF2 PE David/Adam x7519, pgr 252 Steps Continued (list service type): 2" CTU (Pump cement in 3.5" tubing) - Day 2 continued 3. MU cement nozzle and RIH pumping min rates with sea water to TD. 4. Clean up with one volume of sea water (approximately 15 barrels) 5. Clean up with one volume of surfactant wash. 6. Place 25 barrels of 15.8 ppg Class G cement with 1% S001 and 2 sacks per barrel of latex additive. (see cement design) 7. Keeping cement above the nozzle, pull nozzle up into the flow cross and monitor open top tanks for clean/good cement returns. 8. Drop ball to side jet and clean up top 6-10 feet of tubing and up through tree and monitor for clean fluid (slick seawater) at tanks. 9. Once clean fluids are seen at tanks trap 2500 psi on WH and monitor for 30 minutes. Add more if necessary. 10. Freeze protect with 60/40 meth water mixture. 11. Pop off well, maintaining 2500 psi WHP. 12. RDMO. Leave well SI for 72 hours. (UCA table says xx hours until calculated hardness) Well Integrity (Remove wellhead) 1. WOC for 72 hr or until field blend UCA chart shows cement developed 2,000 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. 4. Notify AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 48 hrs in advance of witness). 5. Bleed off T/I/O to ensure all pressure is bled off the system. 6. Remove production tree in preparation for excavation and casing cut. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. REMOVE ANY RESIDUAL DIESEL IN ANNULUS BEFORE MAKING WELLHEAD CUT. 8. Cut off wellhead and all casing strings at 4 feet below original ground level. 9. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 10. Send the casing head with stub to materials shop. Photo document. 11. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips 2M-18 PTD #: 191-019 API #: 50-103-20151-00 12. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 13. Obtain site clearance approval from AOGCC. RDMO. 14. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed. 2M-18 Cement Squeeze 06-01-2020 SGD (003).xlsm Printed 6/9/2020 AOGCC inspection is required after cutoff andbefore any remedialcementing SUPERCEDED VTL 7/24/20 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB to TOP of CMT 1,905.0 3/21/2018 2M-18 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Cement plug 6/21/2018 2M-18 rmclaug Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 123.0 Set Depth (TVD) … 123.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 39.0 Set Depth (ftKB) 3,070.2 Set Depth (TVD) … 2,793.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 39.0 Set Depth (ftKB) 7,909.5 Set Depth (TVD) … 6,239.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 38.6 Set Depth (ft… 7,405.6 Set Depth (TVD) (… 5,869.7 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 38.6 38.6 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,823.7 1,799.0 27.87 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 7,364.6 5,839.9 43.39 PBR OTIS PBR w/10' STROKE, 4" SEAL BORE 2.970 7,380.3 5,851.3 43.35 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 7,395.6 5,862.4 43.32 NIPPLE CAMCO D NIPPLE 2.750 7,405.0 5,869.3 43.30 WLEG OTIS RH BALL SEAT SUB/WL GUIDE (SHEARED), TTL ELMD @ 7393' SWS IPROF 1/5/1999 3.015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 1,550.0 1,552.0 1,545.6 1,547.6 4/11/2018 4.0 CMT SQZ 0° phasing, 2" Owen Good Hole charges. 1,580.0 1,582.0 1,574.7 1,576.6 4/11/2018 4.0 CMT SQZ 0° phasing, 2" RTG, Owen BH Charges 1,850.0 1,853.0 1,822.3 1,824.9 3/14/2018 4.0 CMT SQZ 0° phase, 2" RTG, Owen BH charges, 12 holes, magnetic decentralizer oriented 90° from low side 1,853.0 1,855.5 1,824.9 1,827.1 3/13/2018 6.0 CMT SQZ 0° phase, 1.69" OD, 2.5' Tbg punch, 15 holes, decentralized to low side 1,866.0 1,873.0 1,836.4 1,842.6 3/13/2018 6.0 CMT SQZ 0° phase, 1.69" OD, 2.5' x 2' (Blank) x 2.5' Tbg punch, 30 holes, decentralized to low side 1,880.0 1,883.0 1,848.8 1,851.4 3/14/2018 4.0 CMT SQZ 0° phase, 2" RTG, Owen BH charges, 12 holes, magnetic decentralizer oriented on top and bottom 1,880.0 1,882.0 1,848.8 1,850.6 3/20/2018 4.0 CMT SQZ 0° phase, 2" Owen Good Hole charges, 8 holes, magnetic decentralizer oriented 180° from low side 6,853.0 6,859.0 5,471.4 5,475.7 2/17/2018 4.0 CMT SQZ 0° phase, 1.56" x 4' Tbg punch, 0.43" EHD, decentralized to low side 6,900.0 6,904.0 5,505.3 5,508.1 2/17/2018 4.0 CMT SQZ 0° phase, 1.56" x 4' Tbg punch, 0.43" EHD, decentralized to low side 7,490.0 7,518.0 5,931.2 5,951.7 C-4, 2M-18 4/16/1995 4.0 APERF 0° phasing; 2 1/8" EnerJet III 7,529.0 7,537.0 5,959.7 5,965.5 A-5, 2M-18 4/16/1995 4.0 APERF 0° phasing; 2 1/8" EnerJet III 7,545.0 7,562.0 5,971.4 5,983.8 A-4, 2M-18 4/16/1995 4.0 APERF 0° phasing; 2 1/8" EnerJet III 7,573.0 7,593.0 5,991.8 6,006.5 A-3, 2M-18 2/27/1992 4.0 IPERF 180° phasing; Oriented 169 deg. CCW; 4 1/2" Csg Gun 7,593.0 7,612.0 6,006.5 6,020.3 A-3, 2M-18 2/27/1992 4.0 IPERF 180°. phasing; Oriented 169 deg. CCW; 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 7,405.0 7,758.0 5,869.3 6,127.2 Cement Plug 2/11/2018 18.5 bbls of 15.8 Class G cement, Bullhead to End of Tbg (EOT) and to 7" below EOT 6,970.0 7,405.0 5,555.6 5,869.3 Cement Plug 2/11/2018 1,905.0 6,853.0 1,870.9 5,471.4 Cement Plug 3/1/2018 168.6 bbls of 15.8 Class G cement, Bullhead down Tbg and into IA 1,905.0 6,853.0 1,870.9 5,471.4 Cement Plug 3/1/2018 40.0 773.0 40.0 773.0 Cement Plug 5/12/2018 23 BBL of 15.7# AS1 w/PressureNet down OA 1,550.0 1,870.9 1,545.6 1,840.8 Cement Plug 5/26/2018 Downsqueezed 20 bbl of 15.7# AS1 w/PressureNet down IA 38.6 1,550.0 38.6 1,545.6 Cement Plug 6/20/2018 74 bbls of 15.7# AS1 cement 38.6 1,550.0 38.6 1,545.6 Cement Plug 6/20/2018 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,232.1 2,910.0 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1999 2 5,487.3 4,503.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/18/1995 3 6,602.5 5,290.9 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/18/1995 4 7,311.9 5,801.6 OTIS LBX 1 1/2 GAS LIFT DMY RM1 0.000 0.0 12/3/1999 2M-18, 6/9/2020 1:25:24 PM Vertical schematic (actual) PRODUCTION; 39.0-7,909.5 IPERF; 7,593.0-7,612.0 IPERF; 7,573.0-7,593.0 APERF; 7,545.0-7,562.0 APERF; 7,529.0-7,537.0 APERF; 7,490.0-7,518.0 WLEG; 7,405.0 Cement Plug; 7,405.0 ftKB NIPPLE; 7,395.6 PACKER; 7,380.3 PBR; 7,364.6 GAS LIFT; 7,311.9 Cement Plug; 6,970.0 ftKB CMT SQZ; 6,900.0-6,904.0 CMT SQZ; 6,853.0-6,859.0 GAS LIFT; 6,602.5 GAS LIFT; 5,487.3 GAS LIFT; 3,232.1 SURFACE; 39.0-3,070.2 Cement Plug; 1,905.0 ftKB Cement Plug; 1,905.0 ftKB CMT SQZ; 1,880.0-1,883.0 CMT SQZ; 1,880.0-1,882.0 CMT SQZ; 1,866.0-1,873.0 CMT SQZ; 1,853.0-1,855.5 CMT SQZ; 1,850.0-1,853.0 SAFETY VLV; 1,823.7 CMT SQZ; 1,580.0-1,582.0 CMT SQZ; 1,550.0-1,552.0 Cement Plug; 1,550.0 ftKB CONDUCTOR; 40.0-123.0 HANGER; 38.6 Cement Plug; 40.0 ftKB Cement Plug; 38.6 ftKB Cement Plug; 38.6 ftKB KUP INJ KB-Grd (ft) 44.00 Rig Release Date 11/5/1991 2M-18 ... TD Act Btm (ftKB) 7,926.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015100 Wellbore Status INJ Max Angle & MD Incl (°) 46.91 MD (ftKB) 5,700.00 WELLNAME WELLBORE2M-18 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP SUPERCEDEDVTL 7/24/20 Notes: General & Safety End Date Annotation 11/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 12/3/1999 NOTE: 7" casing loaded w/193 bbls diesel. 11/28/1999 NOTE: Largest tool to pass w/o problem 2.75" OD 2M-18, 6/9/2020 1:25:24 PM Vertical schematic (actual) PRODUCTION; 39.0-7,909.5 IPERF; 7,593.0-7,612.0 IPERF; 7,573.0-7,593.0 APERF; 7,545.0-7,562.0 APERF; 7,529.0-7,537.0 APERF; 7,490.0-7,518.0 WLEG; 7,405.0 Cement Plug; 7,405.0 ftKB NIPPLE; 7,395.6 PACKER; 7,380.3 PBR; 7,364.6 GAS LIFT; 7,311.9 Cement Plug; 6,970.0 ftKB CMT SQZ; 6,900.0-6,904.0 CMT SQZ; 6,853.0-6,859.0 GAS LIFT; 6,602.5 GAS LIFT; 5,487.3 GAS LIFT; 3,232.1 SURFACE; 39.0-3,070.2 Cement Plug; 1,905.0 ftKB Cement Plug; 1,905.0 ftKB CMT SQZ; 1,880.0-1,883.0 CMT SQZ; 1,880.0-1,882.0 CMT SQZ; 1,866.0-1,873.0 CMT SQZ; 1,853.0-1,855.5 CMT SQZ; 1,850.0-1,853.0 SAFETY VLV; 1,823.7 CMT SQZ; 1,580.0-1,582.0 CMT SQZ; 1,550.0-1,552.0 Cement Plug; 1,550.0 ftKB CONDUCTOR; 40.0-123.0 HANGER; 38.6 Cement Plug; 40.0 ftKB Cement Plug; 38.6 ftKB Cement Plug; 38.6 ftKB KUP INJ 2M-18 ... WELLNAME WELLBORE2M-18 From:Drake, Steve G To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL]KRU 2M-18(PTD 191-019, Sundry 320-248) Sundry for surface abandonment Date:Tuesday, July 7, 2020 4:08:01 PM Attachments:2M-18 Cement Squeeze 06-01-2020 SGD Rev 1.xlsm 2M-18 Post Cement Job Schematic 07-07-2020.pdf Victoria, The source of the pressure in the tubing is most likely from the perforations that went through the production casing and surface casing at 1850’ RKB. It’s either finding a micro annulus on the backside of the tubing and coming through the tubing holes at 1550’ and making its way to surface or coming all the way to the ID of the tubing and coming up a microannulus that way to surface. I’ve taken your requests into consideration so that we can get a good plan in place to show competent cement. Instead of just cleaning out the cement and redoing what has already failed in the past, my plan is to clean out the cement, set a plug, which should fail if the pressure is coming through the holes at 1550, then lay cement on the plug from 1770 to about 900’. We’ll be able to monitor the well after that and see how our cement job did. If we get a good test we’ll just lay cement on top of the other cement and call it good. If the cement job still does not hold, the contingency will be to set a plug just above the first cement plug, get a good test on it, then cement off the rest of the well to surface. I’ve attached the modified procedure as well as a schematic of what I hope the well to look like after all is said and done. Please let me know if you have any other questions. Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, June 11, 2020 9:36 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2M-18(PTD 191-019, Sundry 320-248) Sundry for surface abandonment Steve, Also, after the cement is milled out, should you see what the pressure builds up to in the tubing over a period of time or perform a pressure test on the tubing? Victoria From: Loepp, Victoria T (CED) Sent: Thursday, June 11, 2020 8:45 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: KRU 2M-18(PTD 191-019, Sundry 320-248) Sundry for surface abandonment Steve, Please provide a post job schematic. What do you think the source of the pressure is on the tubing? Victoria From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, June 10, 2020 11:52 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Simek, Jill <Jill.Simek@conocophillips.com> Cc: Roby, David S (CED) <dave.roby@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]KRU 2M-18(PTD 191-019, Sundry 320-248) Sundry for surface abandonment Hi Victoria, This well has since been handed off to me, hence my reply and not Jill’s. To answer your questions, I looked at the AOGCC Form Tracker and confirmed that yes, the initial Plug and Abandon sundry 317-596 was submitted on 12/20/17 and approved on 1/4/18. Work was completed and a 407 was submitted on 3/14/19 showing a status of complete. Although the well showed a passing MIT-T on the previous sundry it appears that further monitor of the well before the excavation and removal of the wellhead showed that there was a small tubing pressure build up post cement jobs. The draw down of the OA and IA to zero were successful. A 10-403 to address the building pressure on the IA was submitted on 3/14/19 with written approval granted on 3/28/19. No work was ever done on this 403 and it was decided to let the 403 expire. Since then the tubing has continued to remain on an open bleed as it is still showing pressure. The last 48 hour build up rate conducted on 5/8/20 to 5/10/20 showed an increase on the tubing of 16 psi. The 48 hour BUR test prior to that showed an increase of 18 psi. In order to properly abandon this well and ensure there is zero pressure on the tubing, we have submitted this most recent 403 to commence work as early as next week. Please let me know if you have any other questions. Thanks, Steve From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, June 10, 2020 11:18 AM To: Simek, Jill <Jill.Simek@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Roby, David S (CED) <dave.roby@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: [EXTERNAL]KRU 2M-18(PTD 191-019, Sundry 320-248) Sundry for surface abandonment Jill, This well was suspended under Sundry 317-596 with several plugs. I instructed you to close out the sundry with a 10-407 and submit a sundry for the surface abandonment when the work was planned. It appears the reservoir plug was tagged and passed an MIT-T(Sundry 317-596). Now this new sundry(320-248) for the surface abandonment has been submitted which indicates pressure on the tubing and an open bleed since 2018. Please provide more history and information on the source and magnitude of the tubing pressure. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov THE STATE 01ALASKA GOVERNOR MIKE DUNI.EAVY Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-18 Permit to Drill Number: 191-019 Sundry Number: 319-127 Dear Ms. Simek: AIaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc,alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. CSincerely, Daniel T. Seamount, Jr. Commissioner 7`6 DATED this- day of March, 2019. RBDMS�AR Y B IN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 11,41 F711 F, h I'iti✓.' S rP Saab MAR 14 204,9 1. Type of Request: Abandon El' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[] Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ 'F/y �C�h nge Approved Progmm❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Sv rta C� cc 6,4 Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli sAlaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑ 191-019 - 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20151-00-�U 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2M-18 Will planned perforations require a spacing exception? Yes ❑ No O 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25586 ' I Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,926' 6,251' 7815 6169 Opel 7390 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 83' 16" 123' 123' Surface 3,031' 95/8 3,070' 2,793' Production 7,871' 7" 7,910' 6,239' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7490-7518, 7529-7537, 7545- 5931-5952,5960-5965,5971- 3.500" J-55 7,406' 7562,7 6006-6020 Packets and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - OTIS HVT RETRIEVABLE PACKER MD= 7380 ND= 5851 SAFETY VLV - CAMCO TRDP-4A-RO SAFETY VALVE MD= 1824 TVD= 1799 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 14. Estimated Date for 4/1/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well IntegrityEngineer Contact Email: Jill.Simek@cop.com tContact Phone: (907) 263.4131 Authorized Signature: Date: COMMI SIGN USE ONLY Conditions of approval: Notify C m ission so that a representative may witness Sundry Number: n {✓'cl' j ' Plug Integrity g BOP Test ElMechanical Integrity Test ElLocation Clearance Other: BBDMSL✓ MAR 2 8 2019 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: /D .. 40 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 31 20 1 1 � 31� I ti VTC.. 3 2 5/11 y UNIUINAL orm 10r 3 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Du licate ConocoPhillips 2M-18 P&A Permit to Drill #: 191-019 The objective of the proposed 2M-18 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Procedure: Wellhead Excavation / Final P&A: 1. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Remove the well house, if still installed. 3. Bleed off T/I/O to ensure all pressure is bled off the system. 4. Remove the production tree, in preparation for the excavation and casing cut. 5. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 6. Cut off the wellhead and all casing strings at 4 feet below original ground level. 7. Verify that cement is at surface in all strings. AOGCC witness and photo ✓ document required. 8. Send the casing head w/ stub to materials shop. Photo document. 9. Weld ''/d' thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2M-18 PTD M 191-019 API M 50-103-20151-00 10. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 11. Obtain site clearance approval from AOGCC. RDMO. 12. Report the Final P&A has been completed to the AOGCC, and any other agencies ` required. Photo document final location condition after all work is completed. JS ConocoPhillips Alaska, Inc. KUP INJ WELLNAME 2M-18 5100 WELLBORE 2M-18 a4 -le. Wlumle rm aAM Leet Tag widol. lamb) Annotation Degn(IMB)End Dale WeIIGon Lost ski By ..........., cw�wnt 14 as 6l4m _- d.ms",Flu. Last Tag RKB IOTOP of CMT 1,9050 1212018 ZM-18 pproven saennd- Last Rev, Reason femwen..0. NAN(5E@ffi9 Anndelbn End Cow waling, Last Moo By Rev Henson: Cement plug &21I2p18 2M-18 zmchug Casing Strings Caalnq Cewn zoom CONDUCTOR 00unn III IT IX1{BI 16 15.06 40.0 BN OepIN (XKeI eel Depth lTvoF.. W4Len I1... Grede Top Tpryad 1230 1230 62.58 HAO WELDED CONDUCTOR: 40.0-190 Caalnq description SURFACE Color, ID lin) T PuldKB) 958 8.92 39.0 setlainh XNB) Into DepM IIVD)... W6Lm (I... Grade TCp thread 13,070,2 12,7935 3600 J-55 BTC ownemoul sSoonKn .1111 1.550,0-1.5520- Gena eescrlpolon PRODUCTION ..umI011nl ToplM(B) 7 628 39.0 aNpaplhgtKO) laws Depq IND)... When g...Gmde TOp Th"n 17,909.5 16,239.2 26.00 J-55 BTC Tutting Strings ..T9oz:l,W0CI%m- Tuanp description TUBING Btnng Ma.. m 1n) Tool., 3112 299 38.fi sa morn lm. Bx Degh INE) I... wtpm0 amde Top Connmxan 7,405.6 5,869, 930 J-55 ABM-EUE Completion Details 6AFEry VLV, 1821 Top(ND) Top (.8) (KKB) lm` Top NomWl l°) Item Das Co. 10 (in) 36.6 38.5 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,8237 1,799.0 27.87 SAFETYWV CAMCO TRDP4A-RO SAFETY VALVE 2.812 cMTaoL 1,850.61 m3.o� cIti 1,ie}61,9-6.5- 7364.6 5,8399 4.9 P9R OTIS PER W10' STROKE. 4- SEAL BORE 70 7,3W.3 5851.3 4 35 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 7,395.6 5862.4 4.32 NIPPLE CAMCO DNIPPLE 2750 cMr aoz: I..tal rz1ao- ),4050 5,869.3 4330 WLEG OITS R 1393' SWS ALL SEAT SUML GUIDE HARED), TTL ELMO@ 3015 IPROF 11511999 Perforations & Slots CMT SOZ; I,B-m.61,a92o CMT Sot; I,aa3.o.1.60i0� Cewwm Pp; l.am.mma cement PN} 1.maorolBom Top MB) an MKEd Top MD) (-) arm ITVDI ViLI.WZone Dare Won Nos (aholvn ) Noe 1,550.0 1,552.0 1,5456 1,54]6 4111/2018 4.0 MT SO2SOZ deg phasing, 2"Owen Good Hole charges. 1,580.0 1,5820 1,574.7 1,5)6.6 4/112018 4.0 CMT SOZeg phasing, Z' , Owen BH Charges sus'..:39.03.0mi 1,850.0 1,853.0 1,822.3 1,824.9 714-W84.0 CMT SOZ p ase, ' RT n BH charges, 4 SPF, 12 holes, magne0c We LIFT, 3,2321 aecen08lizer oriented 90° from low side 1,853.0 7,855.5 7,824.9 1,827.1 132018 60 CMTSOZ phase, 1. Ws uFr; s,4S1.3 Tbg punts, 6 SPF, 15 holes, decentralized W tow side GAS UFT; It"s 1,866.0 1,8730 1,836.4 1,8426 11 018 60 CMTSQZ Phase , 1. "O x 2' (Blank) x 2.5' Tbg punch, CMTBOZI daa3.paWo� 6 SPF, 30 holes, decentralised W low Side 1,8806 1,883.0 1,848.8 1,851.4 142018 40 CMTSOZ 7 phase R TO,Owen eLrt SO2: e.aoo.ce,ewo� BH charges, 4 SPF, 12 holes, magnetic dome", FI., amend decenvalizer oriented on top and bottom 1,8800 1, 820 LM&S 1,850.6 32012018 4.0 SQZ p ase,Z'Owen Good Wa UFT 2311 n Hole charges, 4 SPF, 8 JCMT holes, magnefic decentralizer oriented 180' from IOw side 6,8530 61859.0 5,4714 5,475.7 W1712018 4.0 CMTSOZ phase, 15 x r Tbg vas, 7,awll punch, 4 SPF, 043" EHO, decentralized W low side PAticlac ,3833 6,900.0 6,904.0 5,505.3 5,508.1 If72018 40 CMTS Z phase, 1.56"x 4 Ong punts, 4 SPF, 0 43" EHD, decentralized to low side NPFLE: Tons 7,4900 ],5180 5.931.2 5.951, C -0,2M-18 4/1 1995 40 APERF eg.phnsing; 2118" owwrIn..7.406.10a ' WLEG, TiCad EnerJetlll 7,529.0 7,537.0 59597 5965.5 A -52M-18 411&1995 40 APERF rig. pleasing', 2 L8" EnerJetlll 7,545.0 7,5620 5,9714 5,983.8 A-0, 2M-18 4/1611995 4.0 APERF eg. phasing;2118" EnerJel 111 7,573.0 7,5930 5,991.8 6006.5 A-3, 2M-18 2/2711992 40 /PERF deg.phasing; Oriented 169 deg. CCW; 4112' Csg PPEPF: 2.4�.6],5180� Gun 7,59].0 712.0 6,0065 5020.3 A -3,2M48 2/2711992 40 IPERF degphasing; dented 169deg.CCW;412'Csg Gun Cement Squeezes Top ITV)) BXoIND) APERF; 7.%az,7M70� Top IhKB) B1m IXKBt (XKB) ME) Des Find Dan Com 7,45.0 7,7580 5869.3 8,1273 Cement Plug 2/1112018 .5 role, lass G cement ullhe6dWEnd of Tbg (EOT) and to T' below EDT 6970.0 7,405.0 5.5556 5,86 3 Cement lug 2/112018 AvaRF: es4so-Tsa2.o� 1,905.0 6.853.0 1,870.9 5,471.4 Cement Plug 3112018 bblso ass cement, Bullhead down -1-17-09- Tbg and into IA IPEXFI 7,nom-76120�; IPERF', gsaro-Talzo� 1,905.0 Q853.6 54714 Cement Plug 3,112018 4077jp 40.0 430 Cement Plug &1&2010 BBL of 15J#A51w/PreasumNet down 1,5500 1,8709 1,545.6 1,810.8 Gement Plug 5262018 DovmsEllcezetl bbl .7#A lei ressumNet su it. IA 38. 1,550.0 86 M56 Cement Plug &202018 74 bbis of 15.7# AS1 cement 38.6 1,550.0 78.6 1,545.8Cement Plug 97 2018 vaooucnoN139.o-1,Wgs KUP INJ WELLNAME 2M-18 WELLBORE 2M-18 ConocoPhillips"" Alaska, fI1C. zAr+e.9+arzplenptw AM Mandrel Inserts VwBal alnaB9e l+edal St w H Too SHUR Top Top (Np) Mn W" Mosel 00 fin1 Sol Est" Type Latcn Type Pats- TRO Pun 9n) (0811 F.-.-F— un dab Can Cemvrt PYg:.33_BKKB Cwnern Plup: SS.9KKI """""" [emempids Anne" H OER: me 1 3.232.1 2,9100 OTIS WOO 1 1GAS LIFT DMY BK 0000 0.0112811999 2 5,48)3 8503.4 OTI WBD 1 GAS LIFT DMY BK 0000 0.0 81811995 3 6,602.5 5.290.9 OTfS WBO 1 GAS LIFT DMY BK 0.000 0.0 ]/1811995 4 ),3t 1.9 5.801.6 OTIS La% 112 GAS LIFT DMY HM1 0000 00 121Y1999 .�,. coxSUCTOR;aoaap Notes: General 88atety End one, I A.d..n cwvn PER. 1.5500um 1112811999 NOTE. Largest tool to pass w/o problem 275" OD CMT s08 tSw.ats¢o_ 11/28/1999 NO I E. 1041'SUA slightly collapsed TOG encountered 121311 NOTE: ]" casing loaded W1193 bbl5 diesel. [Mr 902; 15500y5ax.o—. 111152010 I NOTE: View Schematic wl Alaska 5chemaill SAFETY VLV, 1 East CAR 802; 1,B .Sell CMT 802; 1,6SB0.1,S5i CAR al 1,958.0.18l CMT SOj 1,081.0.,, 0 CMT IMUSG86,0�� Cemnl 1.905 Cen dds, 0IYHRd. wl Poq', 1gR. SURFACE; S903A702� G45 U'T. am I OAS LIFT: Aetna Gets LIFT; E.5 [MT 902:..853.0a0590- CMT SO2', BSSOMSM.0� CwmM Fed. 8.90 OKKB GAS LIFT: 7,3119 FACADE 1. 3 NIPPLE.].. Cemwl Flus ],YS.0M WIEG].4G5,0 APERF:].<800.1, 5180 APERF: 7S29 b7537 APERF', 7.w 0O7.5l PERF TS(a.b],69ci IPERF',].54'16T6130� PRODUCIttol: M 04 ass,5 SPREADSHEET Prod-Inject_Cumes_Well_V319_1910190_KRU_2M-18_20190320.xjsx 3/20/2019 CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV UNIT 2M-18 (191-019) KUPARUK RIVER, KUPARUK RIV OIL Monthly Production Rates 11000,000 -- s-- Produced Gas (MCFM) —w— Produced Oil (BOPM) --e— Produced Water (BOPM) 1,000,000 100,000- .., 100,000 10,000 000 10, yr LL 1,000 -- ---__ ----_ m 1,000 --. 100 __— - -- — s - -- 100 10 — • Cum. Prod Oil (hbls): 1,121,750 Cum. Prod Gas (mcf): 764,425 Cum. Prod Water (bbls): 388,878 _ Jan -1990 Jan -1995 Jan -2000 lan-2005 Jan -2010 Jan -2015 10 Jan -2020 1,000,000 i Monthly Injection Rates - -- --- - ` --- _ --A- Injected Gas (MCFM) � - Injected Water (BOPM) - - - - -- - -_ 1,000,000 300,000 ♦ — L _ -- _---- ----_ ----_ _ 100,000 N 10,000 _ - 0 10,000 CIL ty 1,0002,000 rD 100 _ 100 Q -- - Cum. Inj Gas (mcf): 3,121,780 Cum. Inj Liquid (bbls): 310931615 10 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan 2015 10 lan-2020 SPREADSHEET Prod-Inject_Cumes_Well_V319_1910190_KRU_2M-18_20190320.xjsx 3/20/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ia. Well Status: oil[] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑� ib. Well Class: 20AAC 25.x05 20AAC25.110 • Development El Exploratory [1] GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 2/1712019 .191-019/317-596 3. Address: 7. Date Spudded: 15, API Number: P.O. Box 100360 Anchorage, AK 99510-0360 10/2811991 50-103-20151-00.00 ' 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 114' FSL, 404' FWL, Sec 27, T71N, R8E, UM 11/211991 KRU 2M-18 Top of Productive Interval: 9. Ref Elevations: KB:148 17. Field / Pool(s): 1289' FSL, 1390' FWL, Sec 27, T7IN, R8E, UM GL: 106 BF: Kuparuk River Field/Kuparuk River Oil Pool - Total Depth: % Plug Back Depth MD/rVD: 18. Property Designation: 1002' FSL, 1465' FWL, Sec 27, T1 IN, R8E, UM at Surface ADL 25586 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 488244 y- 5948985 Zone- 4 • 7926/6251 • ALK 2672 TPI: x- 489230 y- 5950159 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 489305 y- 5949872 Zone- 4 1824/1799 1 1400/1398 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 NIA (ft MSL) I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 40 123 40 123 24 225 sx ASII 96/8 36 J-55 39 3070 39 2793 121/4 380 sx PF E, 510 sx Class G 100 sx PF C Top Job 7 26 J-55 39 7909 39 6239 81/2 300 sx Class G 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MDlf VD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD[TVD) Size and Number; Date Perld): 31/2 7406 7380 Perforations Plugged ......... 3/1/2018 StJS 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� -- Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2 OI 21F(ED Plug 1 Pumped 18.5 bbls Class G down tubing across Perfs Plug 2 Pumped 168.6 bbls down tubing, Up IA Plug 3 23 bbls ASI OA downs ueeze-774ft KB to surface Plug 4 20 bbis ASI IA downsgueeze Plug 5 7I bbls ASI tubing x IA surface plug 1555 ft to surface 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A PLUGGED Date of Test: Hours Tested: Production for Oil -Bbl: Gas-MCF:Water-Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casino Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): P 24 -Hour Rate VTL 3/20/19 Form 10-407 Revised 5/2017 0* 3,14 CONTINUED ON PAGE 2 RBDMS MAR 15 2019Ss�t ORIGINIAL only 28. CORE DATA Conventional Corals): Yes ❑ No 0 , Sidewall Cores: Yes ❑ No [Z If Yes, list formations and intervals cored (MD/rVD, From/ro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No I] If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1400 1398 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI - NIA NIA Kuparuk C Bottom 7521 5954 Kuparuk A Bottom 7702 6086 Formation at total depth: NIA NIA 31. List of Attachments: Daily Operations Summary, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological r 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. Alvord Contact Name: Jill Simek Authorized Title: Alaska Drilling Manager Contact Email: Jill.Simek a co Authorized Contact Phone: 263-4131 Signature: �- ♦ Date: %1AJ?0%9 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-ABernating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use some as reference for depth measurements given in other spaces on this forth and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only SUNDRY NOTICE 10-407 ConocoPhillips Well 2M-18 Plug and Abandonment March 13, 2019 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2M-18, commencing operations on January 29, 2018, and suspending operations on February 17, 2019 due to expired Sundry #317-596. Operations to date are listed below. Plug#1 • Pumped 18.5 bbls Class G down tubing, across perforations • State Witnessed tag at 6,970ft • MIT -T passed (1500psi), DDT -T passed Plug #2 • Pumped 168.6 bbls down tubing, up IA • Tagged at 1,904ft in tubing • MIT -T passed (1500psi), DDT -T pass, MIT -IA passed (1500psi) Plug #3 • 23 bbls AS 1 OA downsqueeze (774ft KB to surface) • OA TOC found at 7011 with stringline, top job performed Plug #4 • 20 bbls ASI IA downsqueeze (displaced to 155511 KB) Plug #5 • 74 bbls AS 1 tubing x IA surface plug (155211 to surface) • Tubing TOC at 3811, IA TOC found @ surface • Top job on tubing performed Currently the well is cemented to surface in tubing, IA, and OA. The well will remain in its current state until a new sundry approval is obtained for the remaining abandonment activities. Well schematic and well work summary are included in this notice. 2M-18 PBA WELL EVENTS SUMMARY Date Well Event 2/17/2019 TOP TUBING WITH 18 GALS OF PORTLAND TYPE II CEMENT 12/29/2018 SI FOR BUR, TOC@ 32.5' 2/1' OF FLUID. 6/27/2018 (P&A): IA DDT (IN PROGRESS), OA DDT (IN PROGRESS). 6/26/2018 (P & A): IA DDT (IN PROGRESS), OA DDT (IN PROGRESS), REMOVED FLOOR KIT CLAMP. (P&A) IN PROGRESS, IA/OA DDT. REMOVED WELLHEAD PLATFORM AND TREE. INSTALLED BLIND WITH NEEDLE VALVE ON THA. 6/25/2018 T TOC = 38', OA TOC= 8" BELOW OA VALVE. 6/24/2018 (P&A) IN PROGRESS. DDT OF T/I/O POST CEMENT FOR PLUG AND ABANDONMENT. 6/23/2018 (P&A) IN PROGRESS. DDT OF T/I/O POST CEMENT FOR PLUG AND ABANDONMENT. FULLBORE CEMENTJOB, PUMPED 74 BBLS OF 15.7# A51 CEMENT DOWN TUBING TAKING RETURNS UP IA, CONFIRMED GOOD 6/20/2018 CEMENT AT SURFACE WITH MUDSCALE, READY FOR DHD AFTER 48 HRS. ATTEMPTED TO PUMP DOWN TUBING THROUGH REVERSE-OUT SKID, SKID PLUGGED OFF. TROUBLESHOOT SKID (SEE LOG) PUMPED 15 BBLS OF DIESEL DOWN THE TUBING TO CONFIRM TUBING IS CLEAR PUMPED 3.5 BBLS OF DIESEL DOWN THE IA. IA PRESSURED UP TO 3000 PSI. 6/13/2018 PUMPED 41 BBLS OF 6/12/2018 ATTEMP TO CIRC DOWN TUBING PRESSURED UP, PUMP 5.5 BELS 15.6 CEMENT INTO OA PUMPED 1 BBLS DIESEL DOWN TBG WITH IA SHUT IN. PRESSURED UP TO 1900 PSI AND HELD. PUMPED 20 BELS DIESEL DOWN TBG TAKING RETURNS UP IA TO 210-33 FOR SUCESSFUL INIECTIVITY TEST. 5/28/2018 JOB COMPLETE DOWNSOUEEZED 20 BBLS 15.7# AS1 W/PRESSURENET CEMENT DOWN THE IA, DISPLACED WITH 5 BBLS FW AND 33 BBLS DIESEL, 5/26/2018 READY FOR E-LINE. INJECTIVITY TEST PUMPED 20 BELS DIESEL DOWN TUBING ESTABLISHED RATE OF 1.5 BPM 5/14/2018 JOB COMPLETE PUMPED 35 BBLS DSL DOWN TBG UP IA FOR INIECTIVITY TEST-S BBLS/MIN @300 PSI (JOBCOMPLETE) 5/13/2018 VERIFIED NO IA x OA COMMUNICATION (JOB COMPLETE) PUMPED TOTAL OF 23 BBLS OF 15.7 PPG AS1 CEMENT WITH PRESSURE NET DOWN O/A WHILE TAKING RETURNS FROM TUBING. PRESSURE LOCKED UP AT 1000 PSI WITH NO BLEED OFF, TUBING AND I/A PRESSURE UNAFFECTED, RETURN IN A.M. TO CIRC DIESEI 5/12/2018 THROUGH TUBING AND I/A. (AC EVAL): PUMPED 20 BBLS OF DIESEL DOWN TBG TAKING.. 13 BBLS OF RETURNS UP THE IA, PUMPED 20 BBLS OF DIESEL DOWN TBG TAKING^' 12 BBLS OF RETURNS UP THE OA, CMIT TX IA CA (FAILED ESTABLISHED A LLR OF 24 GPM@ 870 PSI), PUMPED 20 5/6/2018 BBLS OF DIESEL DOWN OA 5/5/2018 (AC EVAL) ANNCOMM EVALUATION IN PROGRESS DUE TO FROZEN HARDLINE. FULLBORE CEMENT JOB. PUMPED 10 BBL DIESEL DOWN TUBING TAKING RETURNS OFF IA AND OA FOLLOWED BY 10 BBL FRESHWATER SPACER TO ESTABLISH CIRCULATION, SWAP TO CEMENT AND PUMP 136 BBLS OF 15.8# ASI DOWN TUBING TAKING 4/23/2018 RETURNS OFF OA, NO CEMENT RETURNS OBSERVED A INJECTIVITY TEST PUMP 15 BBLS DIESEL DOWN OA TAKING RETURNS UP TUBING TO 2M-33 AT 1200 PSI AT 1 BPM PUMP 15 BBLS DIESEL DOWN IA UP TUBING AT 350 PSI AT 1 BPM PUMP 30 BBLS DIESEL DOWN TUBING TAKING RETURNS UP OA TO 2M-33 @ 1200 PSI AT 2 BPM 4/11/2018 JOB COMPLET Perforate tubing from 1580'-1582' with RTG-2125-402F charges oriented low side. Unable to establish communication with OA. Perforate tubing from 1550'-1552' with RTG-2125-302GH charges oriented high side. Establish good communication between 4/11/2018 tubing, IA PUMPED DOWN OA PRESSURED UPTO 1000 PSI START PUMPING DOWN IA UP TBG, RETURNS TO WELL 33. PUMP'D TOTAL 1750 BBL HOT PW,IBPM,200- FLUID BLEED OFF OA SEVERALTIMES. 1750 BBLS PUMPED AWAY, LRS TRIED TO PUMP DOWN OA AGAIN 3/30/2018 PRESSURED UP, NO COMMUNICATION. 3/20/2018 "'JOB CONTINUED FROM PREVIOUS E-LINE WSR'• 3/20/2018 PERFORATE TUBING FROM 1880'-1882' WITH 2" OWEN GOOD HOLE CHARGES. HELD 2000 PSI ON TUBING AND IA WITH 340 PSI 3/14/2018 Perforate tubing from 1850'-1853' and from 1880'-1883' and attempt to establish circulation between tubing and the OA. 3/13/2018 Run CBL to find top of cement and perforate to establish circulation form the tubing to the OA. Tag cement at 1905' RKB Shoot 3/6/2018 MITT TO 1500 PSI (PASS); PERFORMED DDT ON TBG TO ZERO PSI (PASS). JOB COMPLETE. 3/6/2018 TAG TOC W/ 5' X 2.25" BAILER @ 1904' RKB. JOB COMPLETE. LRS ON LOCATION PERFORMING MITT AND DDT. 3/1/2018 PUMPED 168.6 BBLS CLASS G CEMENT DOWN TUBING FOLLOWED BY 5" FOAM BALL, DISPLACED WITH 3 BBLS FRESHWATER AND 2/17/2018 With AOGCC as witness, RIH w/ weight bars, CCL, Jars and centralized swage and tagged top of cement twice at 6970'. Cement wa: 2/14/2018 DELAYED START DUE TO WIND. MIT TBG TO 1500 (PASS). DDT (PASS). JOB POSTPONED DUE TO GENERATOR FAILURE ON UNIT. IN 2/11/2018 PUMPED 18.5 BBLS CLASS G CEMENT DOWN TUBING FOLLOWED BY FOAM PLUG, DISPLACED WITH 40 BBLS F/W AND 22.6 DIESEL, 1/30/2018 I W ECTIVITY TEST W/ 30 BBLS DIESEL: 1/29/2018 PULLED 2.69" WRP @ 7390' RKB. READY FOR INJECTIVITY TEST. IN PROGRESS. Conoco`Phillips Alaska. inc KUP INJ WELLNAME 2M-18 WELLBORE 2M-18 ,eg Arne. NVlat99ma'.4e AM Last Tag women vlanOc Ki Annoomon asphalt End Gale well WreLast MOE By Cemem Plug.Mama.. Inst Tag' RKB W TOP W CMT 1,905031212V RI 2M -t8 pproven c.m.m"'°:Mama Last Rev Reason Gema F. mmol Procto ion EM Data wNlaws Last MW By HMBaa, Ma Rev Reason: Cement plug lWauld 2M-18 rmclaug Casing Strings eosins Description OD (in) (in) Top IRKe) Set Depth mKB) Set Depth �Ve)-1woes. P...Dmde Top Thrtaa CONDUCTOR ifi 110 15.06 40.0 123.0 1230 62.53 H40 WELDED eONWCTOR;W61D0 Deme. 0ascripiionDD SURFACE sins 90DW IDllnl Topords,1 892 39.0 .Ceprom(a) SH DapM jIVDt... WtlLan 11... Oratle Top iM1rcai 3,0)02 2,)93.5 36.00 J55 BTC casing Description OD [In)Io1M Top IRKB) BN CepM ptl(Bt SN Depth (NDt... WIMnp... Grade Top Tllmd cresempra"amoome PRODUCTION ) 628 39.0 7.9095 6.239.2 26.00 J-55 BTC Tubing Strings cert SOZ1.Ma155I Tubing Description semy ma... m 1n1 Top lnlLe) 6N De�L111R. 8ef Depth NVDI I. WL I'M Gq]e Top eonnectes curt agz: Tseoalsexu- TUBING 3112 2.99 38.6 ).405.6 5,869) 9.30 J-55 PBM-EUE Completion Details Too RVD) Topmcl Nominal Topimrel (ma) 19 Item Dee con, go (in) sPFErvvLv tan.7 38,6 3B 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,823] 1,799.0 27.87 SAFETY VLV CANDO TRDP4A-RO SAFETY VALVE 81 7,364.6 5,839.9 43.39 PER OTIS PER w11T STROKE, 4"SEAL BORE 2.970 GMTMal.MD.D1 M.D� 7,3803 5,851.3 .35 PACKER OTE HVT RETRIEVABLE PACKER 3250 cMT aDL taual.esss- 7,3956 5,882.4 43.32 NIPPLE CAMCODNIPPLE 2]50 7,405.0 5,869.3 43.30 WLEG OTIS RH BALL SEAT SUI GUIDE (SHEARED). TTL ELMD �lO 3015 cMT sox: t,emaLe79.0� 7393 SWS IPROF 101999 Perforations & SIOts .Tal lA910.1,L92a .T 90x;1..; m1.0~� To(We)D) Bt1 Snai Dens (eM6m Tep al Bim(M(6) (mus Unkazone Date Type Dom cement yersoma c.,mrnn F cesLN: 1,806 o cera 15500 1,552.0 1,5456 154].6 411112018 00 CMTSOZ Gegphasing, n Good Hole charges. 1,5800 1,582.0 1,5747 75766 411112018 40 CMTSOZ U deg phaMng, Owen BH Charges 17500 1,853.0 1.8223 1,8249 3114!2018 40 CMT SOZ phase,en SoRFACE:sonoodi BH charges, 4 SPF, 12 holes, magnets[ GP911FTI aaaa 1 decenbalizer oriented 90° from law side 1,853.0 1,8555 1,824.9 1,827,1 31132018 60 CMTSOZ phase, . D. 5' Tbg Wnch, 6 SPF, 15 GIS UFT: S.SI hall decentralized M low side Gas OFT, 8,026 1,866.0 1,873.0 1,8364 1,8426 31132018 6.0 CMTSOZ 01 phase, 161 OD. 25x 2' (Blank) x 2.5' Tbg punch, 6 SPF, 30 holes, CIR SDz:6,050"Ill decentralized W law side 1.880.0 1.883 0 1,848.8 1,8514 3!142018 40 CMT SOZ 0D phase, ';RTG,n exlrsoaapmadspi BH charges,PF, 12 holes, magndere realizeented an cwmnt Pug; Sam Dwe tap and bOtlO1,880.0 1,8820 1,848.8 1,850.11 32012018 4.0 CMT SOZ phase, en DDdHole OPS LIFT: ].911.8holes, chargeSPF, 8 magn im odenhtl 180° door 1. from low side 6,853.0 6,859.0 5,4714 5,475.7 27172018 4.0 CMT S02 Fphopl l 5" x 4' Tbg punch, 4 SPF, 0.43" EHD, PBR: ].%e.9 decenValiabd W low side 6.9000 6.904.0 5,505.3 5,508.1 27172018 4.0 CMTSOZ W phase, 1,56- x 4' Tag PACxFR'. 7.MJ.9 punch, 4 SPF, 0,43- EHD, decenaaloed to law side NI rm E ].aide 7,490.0 7,518.0 5,931.2 5,951.7 C4,210-18 4/1611995 40 APERF 0 deg. phasing; 11 " EnerJet 111 cement Fne, 7,4060 Dial 7,529.0 7.537.0 5,9597 5,965.5 A-5,21il 411611995 40 APERF 0deg. phasing; V " emEG 74mo EnerJet III 7,545.0 ),562.0 5,9714 5,983.8 A4, 2M-18 4`1611995 40 APERF 0deg. phasing; 11' EnerJet It 7,573.0 7.593.0 5.9918 60065 A -3,2M-18 227/1992 4.0 (PERF 181 -phawngOdWed 169 deg. CCW; 412' C9g Gun MIiaF; 7,4m.a7.6190� 7.5930 7.6120 6,006.5 6,0203 A-3, 2gr 22111992 4.0 (PERE180 deg. phasing; Oriented! I I 169 deg. CCW; 4112" Csg Gun Cement Squeezes TmpRo) .1. "Is Almov 7521007M7D- 1p,DKB) ermines, (tIHB) sh.) Des start Doh A- am7,INT 7 7,756 5869.3 6.1272 Ceneem Plug 2I1V2018 11 -bb-77lass G cement, Bullhead to Endo Tbg (EOT) and To 7" below EDT 6,97 , 5. .0 ) 5$55.6 5,8693 Cement Plug 2/1122018 APERF. 76aa.0.)Mz.O 1,8)0.9 54714 Cement Plug 3112018 168a able0 1935 G cement, BuIldheas dawn Tbg and ioto IA IPERF:7.5DROr.St 1,905.0 6,853.0 1,870.9 5,471.4 Cement Plug 3112018 40.0 7730 40.0 773.0 Cement Plug 51122018 23 BBL of 1570 AS1 w2PressumNet down OA IPERF:7.900- NZO 1,550.0 1,870.9 1,545.6 1,840.8 Cement Plug 52612018 Downsqueezed 20 Not of 15 74 AST wlPressureNet down IA 38.6 1,550.0 38.6 1,M5.6 Cement Plug &M271 8 74 bbl. of 15 J4 AS I cement 36.6 1,550.0 38.6 1,545.8 Cement Plug 612012018 PRDWCTION;MG-7.90 ConocoPhillips KUP INJ WELLNAME 2M-18 WELLBORE 2M-18 Naska.lnc. �'"'' 1-1 m.m.3ruame eazu AM Mandrel Inserts wlo-mm.amml.aMm s< al on N Tap ntl[2. Tcs,"D) MB) Make Meet Maw, Type Lake Typo ..e. TRo Run IMI (pai) Rua Mate Com ............... Cmy.0. pw: . 39 i5:8 KKB flKB Censll PFq.B- -- camml.Ga..s 3,232.1 BD 2,91. TIS WBD 1 GAS LIFT LIF DMV BK 00 00 112811999 XAHGER, 39.6 2 5,4823 4,503.4 OTIS WBD 1 GAS LIFT DMV BK 0.000 0.0 ]11811995 3 61602.5 5,290.9 OTIS WBD 1 GAS LIFT DMY BK 9.000 0.0 ]l1&1995 4 ],311.9 5,801.6 OTIG LBX ii/2 GAS LIFT DMY RM1 0.000 00 12/Lt999 caxoucrORl aD1v.p Notes: General B Safety E.a Dam I Annoblion Cxmnt PLMa s30Ova 1112611999 NOTE Largest fool to pass w/o problem 2.75 OD 1112611999 NOTE:]041'SLM- slightly collapsetl TBG encountered CMT so. rwa0l.82.0� 1M/1999 NOTE: ]'casing loaded wl193 bbls tliesel. CMTSoz:I,Mn1. 2o. 11/1512010 NOTE: View Schematic wl Alaska Schemap6.0 SFFETY Y V:1 M 7 CMr at Z I'M .,..0— CMT SOL 1,553 LL1,865.5— CMr S02; 196&01 Anew CM sCrZ 1,m@ lX2.0` CMT M 1,BB0D1,893.0� Camel Ppo; 1.S6..O flYB Cxmnf PLq; 1.B]S.ON(B SURFACE', 9B3,090.2� WS LIFT. 392.1 OAS LIFT', %482.9 G48 LIFT', SBV.S CMr 60Z,a63P4. 0— CMTaoa;....O— Cemnl PxM: 6.B20.OflK0 OAB LIFT: TA110 PBR; T,]V 6 PACKER: 7..3 NIWLE:7,958 CenxM :T,4050W WLEO; 7,b5.0 Maw 2,L90.o2,5 O9 MERF:lrsaaB7,53T0� MERF; ],5U,O-75B20� (PERF; ],5290.], 541.D� IPEFF; ],59D.DT,B120� PRODUCTION: MO. lr a)ea P7-0 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, March 12, 2019 2:11 PM To: Simek, Jill Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Yes, please submit a 10-407 to close out Sundry 317-596. A new sundry for the remainder of the P&A should be submitted and a subsequent 10-407 when the work is complete. Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, March 12, 2019 12:18 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Victoria, I will submit a new sundry for the P&A steps remaining (excavation and wellhead removal). Will a 10-407 need to be submitted for work already done on Sundry #317-596? Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp(&alaska.gov> Sent: Thursday, March 07, 2019 8:46 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Please submit a new sundry for the P&A. No need to cancel Sundry 317-596 as it has expired. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoora: alaska. cov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeipp@alaska.gov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, March 5, 2019 1:27 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Victoria, Nabors 7ES is just getting on 2M-21 and is tentatively scheduled for 20.5 days. With the rig's close proximity to 2M-18, our 2M-18 P&A activities will be affected. Originally 211 was scheduled for mid march, after the rig left. But with the rig arriving later than expected, our completion time of the P&A also may be delayed. Is it possible to extend the P&A deadline to May 1 to minimize sim-ops on the 2M pad? Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Friday, February 01, 2019 11:22 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Approval is granted to complete this P&A as outlined below. The work may be completed under the original Sundry(PTD 191-019, Sundry 317-596) with the modifications outlined below. The work must be completed by April 1, 2019. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(a)alaska qov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 oryictoria.LoeoQ@alaska qov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, January 16, 2019 3:02 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]RE: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Schematic attached. Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Pov> Sent: Wednesday, January 16, 2019 2:38 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Do you have an updated schematic with info on plugs? Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, January 16, 2019 2:33 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Victoria, Per our conversation, the 2M-18 Sundry (#317-596) expired on 4 January, 2019. Currently, the well is cemented to surface; next steps in the P&A procedure are the excavation, casing cut, and wellhead removal. However, after repeated/extended bleeds, we are unable to maintain Opsi on the tubing, the last build up having stabilized at 11psi. Summary of work to date is listed below. Attached, for your reference, are original Sundry Approval and subsequent approvals (dated 4/30/2018 and 5/23/2018) for amendments to the procedure. This email serves as a request from ConocoPhillips for an extension to the existing Sundry, with remaining work outlined below. Please review and contact me with any questions. Thank you, Jill Simek 907 263-4131 P&A PROPOSED NEXT STEPS: DHD: 1. Bleed T/I/O to Opsi. 2. Pull flange. DHD: 3. With 1" cement hose, place ''/< bbl plug (28ft) in tubing. 4. Shut-in well. WOC. 1. Perform drawdown test on tubing, IA, and OA, allowing for minimum 48hr buildup. 2. If pressures remain Opsi, continue to excavation. Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off T/I/O to ensure all pressure is bled off the system. 5. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld %" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2M-18 PTD #: 191-019 API#: 50-103-20151-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. P&A WORK TO DATE: Plug#1 Pumped 18.5 bbls Class G down tubing, across perfs State Witnessed tag @ 6970ft MIT -T passed (1500psi), DDT -T passed Plug #2 • Pumped 168.6 bbls down tubing, up IA • Tagged @ 1904ft in tubing • MIT -T passed (1500psi), DDT -T pass, MIT -IA passed (1500psi) Plug #3 • 23 bbls ASI OA downsqueeze (-774ft KB to surface) • OA TOC found at 70ft with stringline, top job performed Plug #4 • 20 bbls ASI IA downsqueeze (displaced to-1555ft KB) Plug #5 • 74 bbls ASI tubing x IA surface plug (-1552ft to —surface) • Tubing TOC @ 38ft, IA TOC found @ surface • Extended bleeds and monitor; T/I/O = 11/0/0 on 1/6/2019 Well Work Summarv: 1/29/2018 Pull 2.69" WRP @ 7390ft and perform injectivity test 2/11/2018 Pump 18.5 bbls Class G cement plug down tubing and across perfs; displace with diesel to — 7,200ft 2/14/2018 MIT -T passed to 1500psi, DDT -T passed 2/17/2018 AOGCC Witnessed tag @ 6,970ft Tubing punch at 6900-6904ft; no circulation achieved Tubing punch at 6859-6853ft; 2 bbl/min @ 400psi achieved 3/1/2018 Pump 168.6 bbls Class G down tubing, followed by 5" foam ball, displaced with 3 bbls freshwater and 14.4 bbls diesel; estimate TOC = 2000ft 3/6/2018 Tag TOC @ 1904ft; MIT -T passed to 1500psi, DDT -T passed 3/8/2018 MIT -IA passed to 1500psi 3/13/2018 Log CBL for IA TOC; tag TOC @ 1905ft Perftubing and PC at 1870-1873ft, 1866-1868.5, and 1853-1855.5ft; communication from tubing to IA achieved, no communication to OA 3/14/2018 Perftubing and PC at 1850-1853 and 1880-1883ft; no communication to OA 4/11/2018 Perftubing and PC at 1580-1582ft and 1550-1552ft; communication achieved 4/23/2018 Pump 136 bbls ASI down tubing, taking returns to OA. No returns at surface; flush tubing with 123 bbls seawater; freeze protect down OA and tubing with returns to IA 5/6/2018 CMIT-TxlAxOA failed 5/12/2018 Pumped 23 bbls (planned 55bbls) ArcticSet 1 down OA, taking returns to tubing. Pressure locked up; job suspended 5/13/2018 Pump 35 bbls diesel down tubing, up IA for injectivity test; verify no IAxOA communication Circulation test, tubing to IA; 1.5 bpm losses IA downsqueeze with 20 bbls ArcticSet 1; displaced to —1555ft M6/20/2018 Circulation test, tubing to IA; passed OA TOC @ 70ft OA top -job Pump 74 bbls ArcticSet 1 down tubing, returns up IA 6/25/2018 Bleed 1/1/0. Remove tree. Tubing TOC @ 38ft, OA TOC @ 8" 6/29/2018 IA cement @ surface Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-41311 Cell. 907-980-7503 A770 /9t-017 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, March 7, 2019 8:46 AM To: 'Simek, Jill' Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Follow Up Flag: Follow up Flag Status: Completed Please submit a new sundry for the P&A. No need to cancel Sundry 317-596 as it has expired. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeopeDalaskago CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria LoeM,riL laska_gov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, March 5, 2019 1:27 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Victoria, Nabors 7ES is just getting on 2M-21 and is tentatively scheduled for 20.5 days. With the rig's close proximity to 2M-18, our 2M-18 P&A activities will be affected. Originally 2M-18 was scheduled for mid march, after the rig left. But with the rig arriving later than expected, our completion time of the P&A also may be delayed. Is it possible to extend the P&A deadline to May 1 to minimize sim-ops on the 2M pad? Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Friday, February 01, 2019 11:22 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) -Sundry Extension and Procedure Change Approval is granted to complete this P&A as outlined below. The work may be completed under the original Sundry(PTD 191-019, Sundry 317-596) with the modifications outlined below. The work must be completed by April 1, 2019. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeop(cDalaska. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Victoria.Loeop@alaska.gov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, January 16, 2019 3:02 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]RE: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Schematic attached. Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, January 16, 2019 2:38 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Do you have an updated schematic with info on plugs? Thanx, Victoria 2M-18 PTD #: 191-019 API #: 50-103-20151-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. P&A WORK TO DATE: Plug#1 • Pumped 18.5 bbls Class G down tubing, across perfs • State Witnessed tag @ 6970ft • MIT -T passed (1500psi), DDT -T passed Plug #2 • Pumped 168.6 bbls down tubing, up IA • Tagged @ 1904ft in tubing • MIT -T passed (1500psi), DDT -T pass, MIT -IA passed (1500psi) Plug #3 • 23 bbls ASI OA downsqueeze (-774ft KB to surface) • OA TOC found at 70ft with stringline, top job performed Plug #4 • 20 bbls AS1 IA downsqueeze (displaced to —1555ft KB) Plug #5 • 74 bbls AS1 tubing x IA surface plug (-1552ft to —surface) • Tubing TOC @ 38ft, IA TOC found @ surface • Extended bleeds and monitor; T/I/O = 11/0/0 on 1/6/2019 Well Work 5ummarv: 1/29/2018 Pull 2.69" WRP @ 7390ft and perform injectivity test 2/11/2018 Pump 18.5 bbls Class G cement plug down tubing and across perfs; displace with diesel to — 7,200ft 2/14/2018 MIT -T passed to 1500psi, DDT -T passed 2/17/2018 AOGCC Witnessed tag @ 6,970ft Tubing punch at 6900-6904ft; no circulation achieved Tubing punch at 6859-6853ft; 2 bbl/min @ 400psi achieved 3/1/2018 Pump 168.6 bbls Class G down tubing, followed by S" foam ball, displaced with 3 bbls freshwater and 14.4 bbls diesel; estimate TOC = 2000ft 3/6/2018 Tag TOC @ 1904ft; MIT -T passed to 1500psi, DDT -T passed 3/8/2018 MIT -IA passed to 1500psi 3/13/2018 Log CBL for IA TOC; tag TOC @ 1905ft Perf tubing and PC at 1870-1873ft, 1866-1868.5, and 1853-1855.5ft; communication from tubing to IA achieved, no communication to OA 3/14/2018 Perftubing and PC at 1850-1853 and 1880-1883ft; no communication to OA 4/11/2018 Perftubing and PC at 1580-1582ft and 1550-1552ft; communication achieved 4 4/23/2018 Pump 136 bbis AS1 down tubing, taking returns to OA. No returns at surface; flush tubing with 123 bbls seawater; freeze protect down OA and tubing with returns to IA 5/6/2018 CMIT-TxlAXOAfailed 5/12/2018 Pumped 23 bbis (planned 55bbls) ArcticSet 1 down OA, taking returns to tubing. Pressure locked up; job suspended 5/13/2018 Pump 35 bbls diesel down tubing, up IA for injectivity test; verify no IAxOA communication 5/14/2018 Circulation test, tubing to IA; 1.5 bpm losses 5/26/2018 IA downsclueeze with 20 bbls ArcticSet 1; displaced to —1555ft 5/28/2018 Circulation test, tubing to IA; passed 6/3/2018 OA TOC @ 70ft 6/12/2018 OA top -job 6/20/2018 1 Pump 74 bbls ArcticSet 1 down tubing, returns up IA 6/25/2018 Bleed T/I/O. Remove tree. Tubing TOC @ 38ft, OA TOC @ 8" 6/29/2018 IA cement @ surface Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-41311 Cella 907-980-7503 PTO l9/—oi9 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, February 1, 2019 11:22 AM To: 'Simek, Jill' Subject: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Follow Up Flag: Follow up Flag Status: Flagged Approval is granted to complete this P&A as outlined below. The work may be completed under the original Sundry(PTD 191-019, Sundry 317-596) with the modifications outlined below. The work must be completed by April 1, 2019. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp0Aalaska.goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria. Loeppeaaloska. ov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, January 16, 2019 3:02 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Schematic attached. Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Sent: Wednesday, January 16, 2019 2:38 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL)RE: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Do you have an updated schematic with info on plugs? Thanx, Victoria From: Simek, Jill <Jill.Simek(@@ conocophillips.com> Sent: Wednesday, January 16, 2019 2:33 PM To: Loepp, Victoria T (DOA) <victona.loepp(@alaska.gov> Subject: KRU 2M-18 (PTD 191-019, Sundry 317-596) - Sundry Extension and Procedure Change Victoria, Per our conversation, the 2M-18 Sundry (#317-596) expired on 4 January, 2019. Currently, the well is cemented to surface; next steps in the P&A procedure are the excavation, casing cut, and wellhead removal. However, after repeated/extended bleeds, we are unable to maintain Opsi on the tubing, the last build up having stabilized at 11psi. Summary of work to date is listed below. Attached, for your reference, are original Sundry Approval and subsequent approvals (dated 4/30/2018 and 5/23/2018) for amendments to the procedure. This email serves as a request from ConocoPhillips for an extension to the existing Sundry, with remaining work outlined below. Please review and contact me with any questions. Thank you, Jill Simek 907 263-4131 P&A PROPOSED NEXT STEPS: DHD: DHD: 1. Bleed T/I/O to Opsi. 2. Pull flange. 3. With 1" cement hose, place ''/< bbl plug (28ft) in tubing. 4. Shut-in well. WOC. 1. Perform drawdown test on tubing, IA, and OA, allowing for minimum 48hr buildup. 2. If pressures remain Opsi, continue to excavation. Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off T/I/O to ensure all pressure is bled off the system. S. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld X" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. est. AOGCC Witness Required. ConocoPhillips 2M-18 PTD #: 191-019 API#: 50-103-20151-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is complete P&A WORK TO DATE: Plug#1 • Pumped 18.5 bbls Class G down tubing, across perfs • State Witnessed tag @ 6970ft • MIT -T passed (1500psi), DDT -T passed Plug #2 • Pumped 168.6 bbls down tubing, up IA • Tagged @ 1904ft in tubing • MIT -T passed (1500psi), DDT -T pass, MIT -IA passed (1500psi) Plug #3 • 23 bbls ASI OA downsqueeze ("774ft KB to —surface) • OA TOC found at 70ft with stringline, top job performed Plug #4 • 20 bbls ASI IA downsqueeze (displaced to -1555ft KB) Plug #5 • 74 bbls ASI tubing x IA surface plug (-1552ft to surface) • Tubing TOC @ 38ft, IA TOC found @ surface • Extended bleeds and monitor; T/I/O = 11/0/0 on 1/6/2019 Well Work Summary: 1/29/2018 Pull 2.69" WRP @ 7390ft and perform injectivity test 2/11/2018 Pump 18.5 bbls Class G cement plug down tubing and across perfs; displace with diesel to — 7,200ft 2/14/2018 MIT -T passed to 1500psi, DDT -T passed 2/17/2018 AOGCC Witnessed tag @ 6,970ft Tubing punch at 6900-6904ft; no circulation achieved Tubing punch at 6859-6853ft; 2 bbl/min @ 400psi achieved 3/1/2018 Pump 168.6 bbls Class G down tubing, followed by 5" foam ball, displaced with 3 bbls freshwater and 14.4 bbls diesel; estimate TOC = 2000ft 3/6/2018 Tag TOC @ 1904ft; MIT -T passed to 1500psi, DDT -T passed 3 3/8/2018 MIT -IA passed to 1500psi 3/13/2018 Log CBL for IA TOC; tag TOC @ 1905ft Perftubing and PC at 1870-1873ft, 1866-1868.5, and 1853-1855.5ft; communication from tubing to IA achieved, no communication to OA 3/14/2018 Perf tubing and PC at 1850-1853 and 1880-1883ft; no communication to OA 4/11/2018 Perf tubing and PC at 1580-1582ft and 1550-1552ft; communication achieved 4/23/2018 Pump 136 bbls AS1 down tubing, taking returns to OA. No returns at surface; flush tubing with 123 bbls seawater; freeze protect down OA and tubing with returns to IA 5/6/2018 CMIT-TxlAxOA failed 5/12/2018 Pumped 23 bbls (planned 55bbls) ArcticSet 1 down OA, taking returns to tubing. Pressure locked up; job suspended 5/13/2018 Pump 35 bbls diesel down tubing, up IA for injectivity test; verify no IAxOA communication 5/14/2018 Circulation test, tubing to IA; 1.5 bpm losses 5/26/2018 IA downsqueeze with 20 bbls ArcticSet 1; displaced to -1555ft 5/28/2018 Circulation test, tubing to IA; passed 6/3/2018 OA TOC @ 70ft 6/12/2018 OA top -job 6/20/2018 Pump 74 bbls ArcticSet 1 down tubing, returns up IA 6/25/2018 Bleed T/1/0. Remove tree. Tubing TOC @ 38ft, OA TOC @ 8" 6/29/2018 IA cement @ surface Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 • • 77—D 11Y - 01 `1 Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, May 23, 2018 9:22 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019, Sundry 317-596) Final P&A- Change Approval Follow Up Flag: Follow up Flag Status: Flagged Thank you! From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 23,2018 9:07 AM To:Simek,Jill<Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 2M-18(PTD 191-019,Sundry 317-596) Final P&A-Change Approval Jill, Approval is granted to proceed as outlined below. Please include this change with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer 11 tt1c� State of Alaska SCANNED ' fl I o JUN 1 Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp[cilalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeou@alaska.gov From:Simek,Jill<Jill.Simek@conocophillips.com> Sent:Wednesday, May 23, 2018 9:01 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:2M-18 Next Steps(Sundry#317-596) Victoria, Per our conversation,ConocoPhillips would like to amend the cementing procedure for the surface plug on the 2M-18 P&A. Last operations performed included pumping permafrost cement down the production casing x surface casing annulus (OA). After 23 bbls of cement was pumped,OA pressure increased to 1000psi and cementing operations were shut down. The 23 bbls corresponds tt4ft of cement in the OA,versus 1,850ft planned. There are perforations in the tubing, production casing,and (suspected)surface casing at 1,850ft,and due to total planned volume of cement not being pumped (55 bbls plus excess), it is assumed that these perforations are still open and not squeezed off,as intended,during the OA cement job. Before proceeding with the tubing x IA cement job,we intend to pump an additional cement squeeze,this time down the IA, in an attempt to shut off any communication to formation through the perforations. Recent circulation tests show 1.5 bpm losses when pumping diesel down tubing, and taking returns to the IA.A successful downsqueeze will be confirmed by the elimination of these losses. Proposed cementing procedures are outlined below. Please let me know if this meets with AOGCC approval. Thanks Jill Cementing —Plug #4 Objective: Downsqueeze IA with 28 bbls cement to plug off suspected IAxOAxFORM communication at—1850ft KB 1. Conduct safety meeting and identify hazards. Inspect wellhead and pad condition to identify any pre-existing conditions 2. Pressure test SLB lines 3. Line up down IA 4. Pump 5 bbl water as spacer at 5 bpm 5. Pump 28 bbls of ArcticSet 1 with PressureNet added 6. Pump 41 bbls diesel to displace cement to —1,555ft KB. Monitor T/I/O for pressure change. 7. RDMO E-Line/ Little Red Objective: Confirm/establish TxIA circulation 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU LRS and PT Surface Equipment as required. 3. Pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 4. If 2 bpm circ. rate is not achievable, proceed to step 5. Otherwise RDMO. 5. RU e-line and PT Equipment as required. 6. RIH with dummy puncher for Top of Cement (TOC) tag. 7. RIH with 2" x 4' tubing punch. Punch 30' above TOC, as close to mid joint as possible. 8. Pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 9. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 10. RDMO Cementing —Plug #5 Objective: Place a cement plug from 1,552' KB (shallowest tubing perfs) to surface. We will be circulating cement down the 3'/2" tubing and up the 31/2" x 7" annulus. 2 • • Cement Volume Calculations (TOC at surface): • Tubing: (0.00869627 bbl/ft) * (1,552' KB) = 13.5 bbl • 3-1/2" x 7"Annulus: (0.0263627 bbl/ft) * (1,552' KB) =40.9 bbl • Excess: 20 bbl • Total volume = 13.5 +40.9 + 20 = 74.4 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU SLB Cement Equipment, ensuring that hardline is rigged up to pump down the tubing and take returns to a tank from the 3'/z" x 7" annulus. 3. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 4. PT surface equipment as required. 5. Pump 10 bbls fresh water spacer. 6. Pump 74.4 bbls of 15.7 ppg ARCTICSET* 1 (AS1) Cement. a) This calculation assumes 20 bbl of excess cement to ensure good cement to surface. b) Calculation is based on 1,552' KB tubing punch depth. Recalculate cement volumes if required. 7. Monitor returns on surface, taking samples and checking pH/density. 8. Once good cement returns are verified on surface (use mud scale for cement density measurement), shut down and open up the surface bypass line to flush all lines with water. 9. Wash up SLB cement pumps. 10. RDMO Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 3 PTO 1 9/-- o • 9 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,April 03, 2018 9:13 AM To: 'Simek,Jill' Subject: KRU 2M-18 PB&A (PTD 191-019, Sundry#317-596) Plug Change Approval Jill, Approval is granted for the change outlined below. Please include this approval with the approved Sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission SCANNED 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to • you,contact Victoria Loepp at(907)793-1247 or Victoria.Loern@alaska.gov From:Simek,Jill<Jill.Simek@conocophillips.com> Sent: Monday,April 02,2018 1:49 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>;McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject:2M-18 P&A Next Steps(Sundry#317-596) Hi Victoria, We are currently working on 2M-18 P&A per Sundry#317-596 approved procedure. On 3/20/18,tubing and production casing were perforated at 1880-1882' KB to establish communication from tubing o IA and OA in preparation for the surface cement plug. After perforating,communication was confirmed from tubing to IA but we were unable to establish communication to the OA. Suspecting an OA ice plug,we attempted to thaw with hot produced water pumped down the IA,taking returns up the tubing(3/30/18). However,after pumping a total of 1750bbls,we have still not observed communication to the OA. Next step planned is to perforate 300ft higher at—1580' KB. If communication can be confirmed,we will continue wit the procedure to pump the third and final cement plug. Please let me know if this plan is acceptable to AOGCC. Thanks, 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regge 3r DATE: 3/4/2018 P. I. Supervisor t FROM: Matt Herrera SUBJECT: Plug Verification Petroleum Inspector KRU 2M-18 CPAI PTD 1910190; Sundry 317-596 2/17/2018: I travelled to KRU 2M-pad to witness the P&A cement plug tag with Pollard E-Line and met with CPAI representative John Condio. Casing depths are as follows: 16" 123ft 9 5/8" 3070 ft 7" 7910 ft The cement plug was sent prior to my arrival, consisting of 18.5 bbls of 15.8 ppg cement, displaced with 40 bbl of diesel. An E-line casing collar locator tool was used to correlate back for corrected RKB depth. They tagged the top of cement with E-line at 6070 ft. Positive and negative pressure tests of the tubing were also to be performed but I was not able to witness due to a schedule conflict. Mr. Condio forwarded the test results from 2/14/18 (attached). Attachments: CPAI Pressure Test Reports (2) 3/22/2018 Follow-up Discussion: The work procedure in approved Sundry 317-596 calls for pressure tests following the plug tag. I contacted Jill Simek (CPAI; Well Integrity Engineer; 263-4131) about the sequence of plug verifications. She said the tag and tests were originally scheduled for 2/14/18 but high winds prevented rigging up to do the tag; pressure tests were not affected so they proceeded with positive and negative pressure tests on plug in tubing. Plug tag was rescheduled to 2/17/18. 1,1 2018-0217_Plug_Verification KRU_2M-18_mh.docx Page 1 of 1 �� 0 0 Z.- 1,4 r- M M v 1 ! _ O - 0 ° J N CO .4 (0 -I O O.Qa LL LL �" a 0 0-(0 CC 0 ' LL to {- ig N CO 2 > > L > >Y O = = i2 o a o 0. 0 0. tlgya c fD a fD a tG 0_ " 0 ill cory QI 00 ° Z• ftanztniE E g a 1 mN g W a 0oN Ev in . K u y v O. 0. a 71 Q e--. III WN X IW W ` W (I) _._._._.._...— Ni a N U' u.�J' N N 999 O Lij �• W � 4 o zN � u) (/) N .• F to a Eo 20 a. ^ 5 (o a: Etna a. 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It w as z Zo Li gula � � m Eu1a gut ► q tj u o L h o 4 CO 11.1 u] N W m ' — — 6i a z -Jo. p I— o a) .Q� a o _0- (1. o ari cu g u < LLO ii- 152 o W g a — I ¢ I p C i ri i;, a v& iu 1- 41 o a P t_ ,1 � cpS8-, I m I,-, 2 win u W 0 a h j W I- w I w II- w I-01 aa! 3' v s .8 15 4 1 Wui Qi c G1' =z a 1 m - a. z a y •- ,r_ y :A o I] m ._1 ~ 1 m rq v W I u) I vJ ',i ' ' w E! .-° t� > > i N 07 mrd � , ;~ a , ]S @0 u t: !o -! Iu 4 N i / l-•a1 LLJ algp oo 4�.r Ll�L!AAp "' � pN .. o i yOF 7'4 110 s. THE STATE • Alaska Oil and Gas �►'z 11, of A T A c Conservation Commission 1 11J1 1!J = = 333 West Seventh Avenue �Tha GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o p. Main: 907.279.1433 ALAS.o Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer %AHMED JAN1 ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-18 Permit to Drill Number: 191-019 Sundry Number: 317-596 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this t day of January, 2018. ✓.r. ,• a U :;) 0 0 RECEIVED ORIGINAL STATE OF ALASKA DEC 0 z' ALASKA OIL AND GAS CONSERVATION COMMISSION a 4-- ( 7 APPLICATION FOR SUNDRY APPROVALS A G 20 AAC 25.280 1.Type of Request: Abandon 0 ' Plug Perforations 0 '. Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory ❑ Development ❑ 191-019 3.Address: Stratigraphic ❑ Service 0 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-103-20151-00 I 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' KRU 2M-18 • Will planned perforations require a spacing exception? Yes ❑ No 0 el 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25586 + Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,926' 6,251' 7815 6169 3027psi 7390 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 83' 16" 123' 123' Surface 3,031' 9 5/8 3,070' 2,793' Production 7,871' 7" 7,910' 6,239' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7490-7518,7529-7537,7545- 5931-5952,5960-5965,5971- 3.500" J-55 7,406' 7562,7573-7593,7593-7612 , 5984,5992-6006,6006-6020 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-OTIS HVT RETRIEVABLE PACKER MD=7380 TVD=5851 SAFETY VLV-CAMCO TRDP-4A-RO SAFETY VALVE ' MD=1824 TVD=1799 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 R 14.Estimated Date for 1/7/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ LI Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. v Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well IntegrityEngineer Contact Email: Jill.Simek@cop.com Authorized Signature: Date: 1,9mlC-7' COMMISSION USE ONLY Contact Phone: (907)263-4131 3n- -S--- Conditions of approval: N ti ommission so that a representative may witness Sundry Number: ( e Plug Integrity V BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance [ Other: O CZ C C VV! �h Z $f ° h C! 77 J-.o to el O C'c //i'1,1 t-v� 4 Ct, '✓L l\UY� i-q d . Post Initial Injection MIT Req'd? Yes ❑ No L,-- - Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / b ÷0 7- lie APPROVED BY Approved by: 11)C7--\., COMMISSIONER THE COMMISSION Date: I I li 1 6iS IA,/p.' 17- /,0��7 vri_ i/2ps Submit Form and 0 Form 10-403 Revised 4/2017 /Approved application is valid for 12 months from the date of approval. Attachments in Duplicate \� • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 14 December 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to Plug and Abandon Kuparuk Injector 2M-18 (PTD#: 191-019). 2M-18 was drilled and completed in November,1991 as an A Sand injector. In November 1999, slickline encountered a tubing obstruction at 7,050ft KB and the well was shut-in. Slickline secured the well in August 2014 with a 2.69" plug set at 7,390ft KB. Since then, repair has been deemed uneconomical and the well remains shut-in. In addition to the damage at 7,050ft KB, a 2015 gyro shows helically buckled tubing to approximately 1,100ft KB,with offset plots indicating possible production and surface casing damage. Recent drifts show multiple restrictions to 3,9 i ft KB. / No future utility exists for 2M-18 as offset producers have not shown significant declines since the well has hee p.A_ j. Furthermore, a grassroots well is planned at 2M, to utilize the 2M-18 location and reuse flowlines,wellhouse and other facilities. With subsidence risk,no future utility, and a need to recover the 2M-18 location,a P&A of the well is recommended. CO4Cr/r „toriZb i//7 The well has 9-5/8" surface casing to 3,070.2ft KB, 7" production casing to 7,909.5ft KB, and 3-1/2" tubing to 7,405.6ft KB, with a packer set at 7,380.3ft KB. A 2.69" Wireline Retrievable Plug is set at 7,390ft KB. Four sets of Kuparuk perforations are at 7,490.0ft -7,518.0ft KB, 7,529.0ft -7,537.0ft KB, 7,545.0ft-7,562.0ft KB,and 7,573.0ft-7,612.0ft KB. Per this procedure,P&A operations will be performed to pump cement across the Kuparuk perforations and into the 3-1/2"tubing to 7,200ft KB. Holes will then be punched in the tubing, above Plug#1 and cement pumped into the tubing and tubing x production casing annulus(IA)to 2,000ft KB. Tubing and production casing will be punched above Plug#2 and a third cement plug will be pumped to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level,wellhead and cellar removed,and site backfilled with gravel/fill to ground level. J If you have any questions or require any further information,please contact me at 263-4131. Sincerely, ,'i (I Jill.imek W: 1 Integrity Engineer 'AI Drilling and Wells IV • ConocoPhiTlips 2M-18 P&A Permit to Drill #: 191-019 P&A operations will be performed to pump cement across the Kuparuk perforations and into the 3-1/2" tubing to 7,200ft KB. Holes will then be punched in the tubing, above Plug #1 and cement pumped into the tubing and tubing x production casing annulus (IA) to 2,000ft KB. Tubing and production casing will be punched above Plug #2 and a third cement plug will be pumped to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. / Procedure: Slickline / Little Red: Objective: Pull plug, injectivity test 1. Inspect pad and work area for hazards. Complete pre-job Safety Meeting. 2. RU Slickline unit and support equipment. PT lubricator and surface lines as required. 3. RIH and pull plug at 7,390.0' KB. 4. Rig up LRS and pump 30 bbls of diesel to verify injectivity required for cementing operations (+/- 2 bpm at 2,000psi). DISCUSS RESULTS WITH WELL INTEGRITY ENGINEEP 5. RDMO. Cementing: Objective: Plug #1 - Place a cement plug across the open perforations and squeeze some cement into perforations. NOTE: Maximum pressure, volume and rate for squeeze to be discussed and agreed with client representative at site prior to starting cement job, based on injectivity test results. Cement Volume Calculations (TOC in tubing to be at approximately 7,200' KB): • 7" production casing volume from 100ft below perforations to tubing tail = (7,712' — 7,405') x 0.03826 = 11.7 bbl • 3-1/2 tubing volume from tubing tail to 7,200' KB = (7,405' — 7,200') x 0.008696 bbl/ft = 1.8 bbl • Total volume: 11.7 + 1.8 = 13.5 bbl + SQUEEZE VOLUME • Displacement volume (diesel): (2,000') * (0.008696 bbl/ft) = 17.4 bbl • Displacement volume (fresh water): (7,200' - 2,000') * (0.008696 bbl/ft) = 45.2 bbl Js • • 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/ Stephen Higgins 907 659-6121). The job is designed for 13.5 bbls of 15.8#Class "G" cement PLUS SQUEEZE VOLUME squeeze volume to be determined based on injectivity test results) 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. Ensure a 5" foam ball is loaded into the tree prior to the cement job. 5. RU cementers. Pressure test surface equipment as required. 6. Follow pump schedule below: i. Pump 10 bbls fresh water spacer ii. Pump 23.5 bbls of 15.8 ppg Class "G" Cement iii. Drop 5" foam ball. iv. Pump 45.2 bbls fresh water and 17.4 bbls diesel freeze protect to displace cement to 7,200' KB. 7. Wash up cement pumps and clean up surface lines. 8. RDMO Slickline / DHD Objective: State witnessed tag of TOC, MIT-T, DDT-T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,200' KB. Record Results. TAG MUST BE AOGCC WITNESSED 5. Perform MIT-T to 1,500 psi. Record Results. 6. Perform DDT-T. Record Results. 7. Report issues and results to Well Integrity Engineer. 8. ONLY PROCELD TO NEXT STEP IF MITs & DDT PASS. OTHERWISE DISCUSS CONTINGENCY CEMENT JOB WITH WELL INTEGRITY ENGINEER. 9. RDMO Eline / Little Red: Objective: Punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E-Line and PT Equipment as required. Js . • 3. RIH with 2" x 4' tubing punch, 4 spf; reference 8/23/2014 schematic and tubing details for depth correlation. 4. Punch approximately 30' above TOC or as close to mid joint as possible. 5. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO. Cementing: Objective: Plug #2 - Fill the wellbore with cement from tubing punch (-7,200' KB) to approximately 2,000' KB. We will be circulating cement down the 3 1/2" tubing and up the 3 '/2" x 7" annulus. Cement Volume Calculations (TOC approximately 2,000' in tubing and annulus): • Volume in 3 1/2" x 7" annulus: (7,200' -2,000') x 0.02636 bbl/ft = 137.1 bbl • Volume inside 3 1/2' tubing: (7,200' -2,000') x 0.008696 bbl/ft = 45.2 bbl • Total volume: 137.1 + 45.2 = 182.3 bbl • Displacement volume: (2,000' KB) * (0.008696 bbl/ft) -3 bbl spacer = 14.4 bbl 1. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/ Stephen Higgins 907 659-6121). The job is designed for 182.3 bbls of 15.8# Class "G" cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. Ensure a 5" foam ball is loaded into the tree prior to the cement job. 4. RU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. 5. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 '/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 6. PT surface equipment as required 7. Establish circulation with diesel. 8. Pump 2 bbls fresh water spacer 9. Pump 182.3 bbls of 15.8 ppg Class "G" cement. • Assumes tubing punch at 7,200' KB. Recalculate based on actual tubing punch depth. • Pump up to 2 bpm initially and slow pump rate to <1 bpm after first 40 bbl of cement, to avoid pumping through leak into formation. 10. Drop 5" Foam Ball 11. Pump 3 bbls fresh water spacer. 12. Displace with 14.4 bbls diesel to leave Top of Cement in tubing and IA at 2,000' KB. 'Jo not overdisplace. Js • • 13. Shut down pumps and close in Tubing and IA. 14. Wash up cement pumps and clean up surface lines. 15. RDMO Slickline / DHD Objective: Tag TOC 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 2,000' KB. Record results and report tag depth to Well Integrity Engineer. 5. Report issues & results to Well Integrity Engineer. 6. RDMO E-line / Little Red Objective: Log CBL, Punch 31/2" tubing and 7" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT Equipment as required. 3. Log CBL to determine TOC in IA. 4. DISCUSS CBL RESULTS WITH WELL INTEGRITY ENGINEER TO CONFIRM REQUIRED PUNCH DEPTH 5. RIH with dual-string perforating gun, referencing 8/23/2014 schematic and tubing details for depth correlation. 6. Punch at depth determined by TOC tag and CBL log, 0 BE CONFIRMED BY WELL INTEGRITY ENGINEER. 7. Pump diesel down tubing to confirm circulation to both IA and OA (+/- 2 bpm <_ 2,000psi). Ensure fresh diesel is circulated into OA to fully displace unknown annulus fluid. 8. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 9. RDMO Is • • Pumping Services: Objective: Plug #3 - Fill the wellbore with cement from punch depth (-2,000' MD) to surface. We will be circulating cement down the 3 '/2" tubing and up the 9 5/8" x 7" annulus as well as up the 7" x 3 1/2" annulus. Cement Volume Calculations: • Volume in 3 1/2" x 7" annulus: (2,000'-0') x 0.02636 bbl/ft = 52.7 bbl • Volume in 7" x 9 5/8" annulus: (2,000'-0') x 0.02971 bbl/ft = 59.4 bbl • Volume inside 3 1/2' tubing: (2,000'-0') x 0.008696 bbl/ft = 17.4 bbl • Excess: 20 bbl • Total volume: 52.7 + 59.4 + 17.4 + 20 = 149.5 bbl 1. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/ Stephen Higgins 907 659-6121). The job is designed for 149.5 bbls of ArcticSet 1 (AS1) cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU cement equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7" x 9 5/8" (OA) and 3 '/2" x 7" (IA) annuli independently. Also ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up AS1. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 149.5 bbl of Permafrost Cement (cement to surface in T/I/O, including 20 bbls excess) 9. After approximately 76.8 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good AS1 to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. This step must be performed efficiently as AS1 is thixotropic and will develop gel strength quickly when static. 11. After approximately 52.7 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good AS1 to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO Is . • DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off T/I/O to ensure all pressure is bled off the system. 5. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Verify that cement is at surface in all strings. AOGCC witness and photo document requires. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld '/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2M-18 PTD #: 191-019 API #: 50-103-20151-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. JS KUP INJ 4 f V,0/7 2M-18 ConocoPhillips ,r Well Attributes Max Angle&MD TD AIa''s Irl(`. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(HKB) Act Blot(ftKB) (b•••AO barn 501032015100 KUPARUK RIVER UNIT INJ 46.91 5,700.00 7,926.0 • ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2M-18,8/23/2014 4:08:05 PM SSSV:TRDP Last WO: 44.00 11/5/1991 Venial schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..................................................... Last Tag:SLM 7,758.0 6/30/2014 Rev Reason:TAG,SET PLUG hipshkf 8/23/2014 2 € ��I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I, CONDUCTOR 16 15.062 40.0 123.0 123.0 62.58 H-40 WELDED HANGER;38.8 , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...WVLen(I...Grade Top Thread SURFACE 9 5/8 8.921 39.0 3,070.2 2,793.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 39.0 7,909.5 6,239.2 26.00 J-55 BTC • Tubing Strings Tubing Description String Ma...ID(in) I Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 38.61 7,405.61 5.869.7 9.30 J-55 ABM-EUE Me CONDUCTOR;40.0-123.0• ' -A-+7'Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 38.6 38.6 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,823.7 1,799.0 27.87 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 SAFETY VLV;1,823.7 11.p 7,364.6 l 5,839.9 43.39 PBR OTIS PBR w/10'STROKE,4"SEAL BORE 2.970 7,380.3 5,851.3 43.35 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 • 7,395.6 5,862.4 43.32 NIPPLE CAMCO D NIPPLE 2.750 7,405.0 5.869.3 43.30 WLEG OTIS RH BALL SEAT SUBNJL GUIDE(SHEARED).TTL 3.015 ELMD @ 7393'SWS IPROF 1/5/1999 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) ('I Des Com Run Date ID(in) SURFACE;3503,070.2-A 7,390.0 5,858.4 43.33-PLUG 2.69"WRP 8/22/2014 - Perforations&Slots _ GAS LIFT;3,231.1 F I Shot Dens Top(TVD) sem(TVD) (ehots/f Top(ftKB) She(ftKB) (ftKB) (ftKB) Zone Date t( Type Com 7,490.0 7,518.0 5,931.2 5,951.7 C-4,2M-18 4/16/1995 4.0 APERF 0 deg.phasing;2 1/8" EnerJet III GAS LIFT;5,437.3 7,529.0 7,537.0 5,959.7 5,965.5 A-5,2M-18 4/16/1995 4.0 APERF 0 deg.phasing;21/8" EnerJet III 7,545.0 7,562.0 5,971.4 5,983.8 A-4,2M-18 4/16/1995 4.0 APERF 0 deg.phasing;2 1/8" EnerJet III GAS LIFT;8,802.5 7,573.0 7,593.0 5,991.8 6,006.5 A-3,2M-18 2/27/1992 4.0 IPERF 180 deg.phasing; Oriented 169 deg.CCW; 4 1/2"Csg Gun 7,593.0 7,612.0 6,006.5 6,020.3 A-3,2M-18 2/27/1992 4.0 IPERF 180 deg.phasing; Oriented 169 deg.CCW; GAS LIFT;7,311.9 41/2"Csg Gun Mandrel Inserts St ati C on Top(TVD) Valve Latch Port Size TRO Run No Top MKS) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 3,232.1 2,910.0 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1999 2 5,487.3 4,503.4 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/18/1995 PBS,73rd (1 3 6,602.5 5,290.9 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/18/1995 I4 7.311.9 5.801.6 OTIS LBX 1 1/2 GAS LIFT DMY RM1 0.000 0.0 12/3/1999 I Notes:General&Safety imi PACKER;7,380 3 End Date Annotation 11/28/1999 NOTE.Largest tool to pass w/o problem 2.75"OD 11/28/1999 NOTE:7041'SLM-slightly collapsed TBG encountered PLUG;7,390.0 12/3/1999 NOTE:7"casing loaded w/193 bbls diesel. 11/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;7,395.6 WLEG;7,405.0 APERF;7,490.0-7,518.0 APERF;7,529.0.7,537.0 APERF;7,545.0-7,5820 IPERF;7,573.0-7,503.O-.� IPERF;7,593.0-7,812.0 PRODUCTION;39.0-7,909.5 • • Schematic: t' '--, KUP it&J 2M-18 Com 5�ilii r wok aseibutws flax+rata s MO TO / 1.........1 r 4/...A... e'Yf ikt 7111 AYt 611.11 11,.7 4: 2 4^t.I.€i9rg,Ss1-11 1.4 x ... < ^Mt 1m111 At ...NW 114 MAA to - Qs* 4....,2,." .42 ^f'=.,y" .,a.7K.: 44l 72' ..........1411 ;a 1..1 tee am 4.11111 tee We er etlitt : tem, r 1 �:attM;i atirrat tnc1_ rent '1 TM..Al flat 1're truAl trete "mai ar:-tree.` itUrrttrate tut+ii tee +urc tate.. 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Ziova.., 19x114'"Amer ma. •u.ate ''.t! 222'*t*r*eMs.-1 w 4dm«a::cwr.".::a *11-;trx Yi4*1 r meatS,Mee r- i44.G.7 uss / <,+1,0."9'sr Xsst,res Is • 0 P&A Diagram: 2M-18 Plug & Abandonment PTD#: 191-019 Current Compietron Proposed P&A Ali iiih„ lir 52,50+440 corgiaztor 1 z3 Ks Ai Plug if1,4,.,&CA 0000 KB-3yearer / 1 =., ;-4,40,1,34;f:.e:,..f,;:r, IL Penne:0st Cement Z..75#;t6:;,'':t•-,T''''','''' , • SSSV 4g 1.8237 KB Second Plug IT&IAI 7„200 KB-2,000KB 15.8 ppg Class 10" 4,-, '''1:, 4 Sur"aoe Casing 2 3 070.2 KB " MikAll C.41 NVAA,r;;.,,,ktkA44 'NO 10,04,OW ;ell 64*OW V61k#00# k.412;WI:A 61744, GLAtt g*If,.$4,40:4! DittrY g 32321'KB ``.,. mu. BUY a BATTS'KB '''''''A -.'„:11',(4;1 • LIMY a d MCI KB Wel7ll k7.174 ,•-i:,' 414 Sg KB 1: ''-4 10°4 .B44;>14 „4,440-444,0,,r1t4r. .,i,7!„, Pmclunion Casrg 4.444-7 BSC KB 4,R1111°,-,,,i, - FIrst Plug(Perforacers,Castrig,&%two <111111111 7,717-7207 KS W. 152 ppg Class 77 1. M = Cite i-nti Retrevable Picker 4)7383'KB 'PIO me,11//t 25W ifIRP/0 7,3071.1 KB ill 6„A r.010:t.:4 im, 3-14,'0 34 J-55 Tung/§7,40Z B'KB ,,,114(104,015% Utee,t4,01,4,1.14,-16, ',,T,44ft440740,414fit; Perk , 7,400.0-7,5111.0.KB ',• .,E1 I L•.',':t--— 7.045.0-7,5521T KB ,„1.=A1'4,11,,111"1,lt0'1"1•.::- •-- ',.:.(„p:1),?,',Iivo.,.444!;* ' 7,573.13-7„1312Z1U3 ...,,,,=,...a...... IS,14504;V,P4 " .,..4> 7"204/J-E5 Producton Casing.7 000 5 KB :01:G.M.:1 .kralli6.. JS 12-14-2017 Js • . Bettis, Patricia K (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, December 21, 2017 10:00 AM To: Bettis, Patricia K (DOA) Cc: Haggerty-Sherrod, Ann (Northland Staffing Services) Subject: RE: [EXTERNAL]KRU 2M-18 (PTD 191-019): Sundry Application Attachments: 2M-18.pdf Patricia, Schematic attached. Let me know if you require anything else. Jill From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, December 21, 2017 9:22 AM To: Simek,Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 2M-18 (PTD 191-019): Sundry Application Good morning Jill, The wellbore schematic is of poor quality. Please resubmit a copy of the wellbore schematic that is clear and readable. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 f • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Thursday, December 21, 2017 9:22 AM To: 'JilLSimek@conocophillips.com' Subject: KRU 2M-18 (PTD 191-019): Sundry Application Good morning Jill, The wellbore schematic is of poor quality. Please resubmit a copy of the wellbore schematic that is clear and readable. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning projecL They are available in the original file and viewable by direct inspection. /~'/~/~ File Nu m be rof Well H is to ry File PAGES TO DELETE Complete RESCAN~ - - Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts ~ Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED [] Logs of vadous kinds n Other COMMENTS: Scanned by: TO RE-SCAN Notes: - Beverly D~n Lowell THE MATE~AL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 E E PI~ E W M A T E R IA L U N D ER TH IS M ARK ER, C:LORBMFILM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casin, g ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. C). Box 100360, Anchorage, AK 99510 4. Location of well at surface Stimulate RePair well 5. Type of Well: Development Exploratory .. Stratigraphic .... Service X Plugging Perforate Other X 6. Datum elevation (DF or KB) RKB 146 7. Unit or Property name Kuparuk River Unit 8. Well number feet 114' FSL, 404' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1289' FNL, 1390' FWL, SEC 27, T11N, R8E, UM At effective depth 1074' FNL, 1446' FWL, SEC 27, T11N, R8E, UM At total depth 1002' FNL, 1465' FWL, SEC 27, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7926 feet true vertical 6251 feet 2M-18 9. Permit number/approval number AIL API91n~1m9b/er95-1 04 I5o-103-20151 11: ~;dTP-; ;I Kuparuk River Field/Oil Pool Plugs (measured) Effective depth: measured 7815 feet true vertical 6169 feet Junk (measured) Casing Le n g t h Size Structural Conductor 8 0' 1 6" Surface 3027' 9 5/8" Intermediate Production 7862' 7" Liner Perforation depth: measured 7490'-7518', true vertical 5931 '-5951 ', Cemented 225 SX ASII 380 SX PF E,510 SX CLASS G 100 SX PFC TOP JOB 300 SX CLASS G 7529'-7537', 5959'-5965', 7545'-7562', 5971'-5984', Tubing (size, grade, and measured depth) 3 .5", 9.3# J55 AMB-EUE, @7406' Packers and SSSV (type and measured depth) PKR: OTIS HVT PKR @ 7365', SSSV: CAMCO TRDP-4A-RO @ 1824' Measured depth True verticaldepth 123' 123' 307O' 2793' 7905' 5781' 13. Stimulation or cement squeeze summary Converted well from oil producer to WAG injector. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-lVlcf Water-Bbl Casing Pressure 301 444 624 1207 0 0 3100 900 Tubing Pressure 267 2425 15. Attachments Wellbore Schematic Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 16. Status of well classification as: Oil Gas Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~ ~"'" ~ Title Wells Superintendent Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE WELL 2M-18 INJECTOR APl # 5010320151 SURFACE LOCATION: 114' FSL, 404' FWL, SEC. 27, T11N, R8E, UM TOP OF KUPARUK: 1289' FNL, 1390' FWL, SEC 27, T11N, R8E, UM TD LOCATION: 1002' FNL,1465' FWL, SEC 27, T11N, R8E, UM DEPTHS: REFERENCED TO 0' RKB ALL DEPTHS MD-RKB TUBING SPOOL RKB=38.58' 16": 62.5# H-40 @ 123' WELL TYPE: INJECTOR 9.625": 36# J-55 @ 3070' OTIS PBR: @ 7365' OTIS HVT PKR: CAMCO D NIPPLE: 2.75" ID @ 7380' @ 7396' OTIS SHROUT: @ 7405' C A5 A4 A3 7": 26# J-55 @ 7905' VOLUME: 0.0383 BBL/FT =BTD: 7815' PBTDSS: 6028' L SPUD: 10/27/91 COMPLETION: 2/27/92 SSSV: CAMCO TRDP-4A-RO @ 1824' GLMI: GLM2: GLM3: GLM4: 3232'/OTIS WB/1.0"/.25" JRN-DV 5487'/OTIS WB/1.0"/.25" JRN-DV 6603'/OTIS WB/1.0"/.25" JRN-DV 7312'/OTIS LB/1.5"/.25" VRN-DV 3.5" 9.3# J-55 ABM-EUE, @ 7406' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 42.5 DEGREES MAX. HOLE ANGLE = 47 DEGREES @ 5755' VOLUME TO TOP PERF = 71 BBLS 7490' - 7518' (28') 4 SPF 0° 2-1/8" EJ IIIDP 7529' - 7537' (8') 4 SPF 0° 2-1/8" EJ IIIDP 7545' - 7562' (17') 4 SPF 0° 2-1/8" EJ IIIDP 7573'-7593' (20'), 4 SPF, 180 ° @169 o CCW 7593'-7612' (19'), 4 SPF,180 o @169 o CCW LAST TAG DATE: 7/18/95 @ 7775' REVISION: RKS/HTE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing , Alter casing Stimulate __ Plugging , . Repair well ~ Perforate X Other 2. Name of Operator ARCO Alaska, Inc.. 3. Address iP. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ,X, Exploratory _ Stratigraphic _ Service i4. Location of well at surface 114' FSL, 404' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1289' FNL, 1390' FWL, SEC 27, T11N, R8E, UM At effective depth 1074' FNL, 1446' FWL, SEC 27, T11N, R8E, UM At total depth 1002' FNL, 1465' FWL, SEC 27, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7926' feet true vertical 6251' feet Effective depth: measured 7815' feet true vertical 6169' feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 148' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-18 9. Permit number/approval number 91-19 10. APl number 5o-103-20151 11. Field/Pool Kup..aruk River ,Oil Pool feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 3027' 9 5/8" Intermediate Production 7862' 7" Liner Perforation depth: measured 7490'-7518', true vertical 5931 '-5951 ', Cemented 225 SX ASII 380 SX PF E,510 SX CLASS G 100 SX PFC TOP JOB 300 SX CLASS G Measured depth True vertical depth 123' 123' 3070' 2793' 7905' 5781' 7529'-7537', 7545'-7562', 7573'-7612' 5959'-5965', 5971'-5984', 5992'-6020' Tubing (size, grade, and measured depth) 3 .5", 9.3# J55 AMB-EUE, @7406' Packers and SSSV (type and measured depth) PKR: OTIS HVT PKR @ 7365', SSSV: CAMCO TRDP-4A-RO @ 1824' RECEIVED 13. Stimulation or cement squeeze summary Perforate A4, A5, C4 Sands w/2-1/8" Enerjets @ 4 SPF 0° Phasing Intervals treated (measured) 7490'-751 8' 7529'-7537', 7545'-7562' ! Treatment description including volumes used and final pressure JUL 0 7 1995 ~lt & Gas Cons. Commission 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 318 1275 778 1250 252 Subsequent to operation 3 4 9 8 2 4 836 1220 240 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date ~~"~ SUBMIT IN DUPLICATE ARCO Alaska, inc. Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 2M-1 $ Perforate A4, AS, C4 Sands DATE' 4/16/95 DAY 2 TIME 1000 1145 1400 1630 1800 CONTRACTOR / KEY PERSON SWS-Gerard Johnson PBTD (RKB) ILAST TAG (RKB) - DATE 7815' I 7782' on 2/8/95 I LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT I xlcm cK TInS BLOCK IF SUMMARY IS CONTINUED ON BACK I I Weather Report Temp. I Chill Factor Initial Pressures: Tbg = 900#, 7" = 1200# (Gas Lift SI), 9-5/8" = 750~ Vel. jSi d I Visibility mile'sIwind mph, MIRU SWS and Hot Oil. SI well and block in gas lift at 1030 hrs. Held safety meeting. ,, !PT lubricator to 2500g. Displace tubing w/30 bbls warm diesel at 2 bpm and 1500#. RIH w/17' 2-1/8" Enerjet guns, 4 spf (EJIII, DP, 14 gms, EHD = 0.31", Penetration = 21.8"). 0° phase, MPD, 6' 2-1/8" wt bar, CCL (CCL to top shot = 5'). Tie into short joints with !CET dated 11/12/91. Perforate 7545'-7562' MD-RKB. WHP climbed to 1020# from 960g. lFired guns at 1300 hrs. POOH. ASF. :R/H w/8' gun as above. Tie in and perforate 7529'-7537' MD-RKB. WHP remained at 1000~. · !POOH. ASF. RIH w/28' gun as above. Tie in and perforate 7490'-7518' MD-RKB, POOH. ASF 'On Surface, RDMO SWS. Summary Perforated with 2 1/8" Enerjet 1TI 'DP' 4 SPF, 14 grams, EHD=0.31", Penetration= 21.8" Intervals Shot: 7490'-7518' (28') 7529'-7537' (8') 7545'-7562' (17') INCOMPLETE Randy Smith/Steve Bradley Ill [AFC/CC# - SCA# K84959/11223 IFIELD COST EST. IACCUMULATED COST I $20,821 ! $21,963 ISSSV m,e ICamco ,TRDP / In Service STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Operation Shutdown __ Pull tubing L Alter casing Stimulate m Plugging Repair well Perforate ~ Other 2, Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at sudace 114' FSL, 404' FWL, SEC 27, T11N, RSE, UM At top of productive interval 1289' FNL, 1390' FWL, SEC 27, T11N, R8E, UM At effective depth 1074' FNL, 1446' FWL, SEC 27, T11N, R8E, UM At total depth 1002' FNL, 1465' FWL, SEC 27, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7926' feet true vertical 6251' feet 6. Datum elevation (DF or KB) RKB 148' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-18 9. Permit number/approval number 91-19 10. APl number 5o-103-20151 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) feet Effective depth: measured 7815' feet true vertical 6169' feet Junk (measured) 13. 14. Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: Length Size 80' 16" 3027' 9 5/8" 7862' 7" measured 7490'-7518', true vertical 5931'-5951', Cemented 225 SX ASil 380 SX PF E,510 SX CLASS G 100 SX PFC TOP JOB 300 SX CLASS G 7529'-7537', 7545'-7562', 5959'-5965', 5971'-5984', Tubing (size, grade, and measured depth) 3 .5", 9.3# J55 AMB-EUE, @7406' Packers and SSSV (type and measured depth) PKR: OTIS HVT PKR ~..73.65', SSSV: CAMCO TRDP-4A-RO @ 1824' Stimulation or cement squeeze summary Perforate A4, A5, C4 Sands w/2-1/8" Enerjets @ 4 SPF 0° Phasing Intervals treated (measured) 7490'-751 8', 7529'-7537', 7545'-7562' Treatment description including volumes used and final pressure Measured depth True vertical depth 123' 123' 307O' 2793' 7905' 5781' 7573'-7612' 5992'-6020' RECEIVED JUL o 7 19 ,5 ~Jil & Gas Cons. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 318 1275 778 1250 252 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 3 4 9 8 2 4 836 16. status of well classification as: Water Injector __ Oil X Gas _ Suspended 122O Service 24O 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date SUBMIT IN DUPLICATE WELL 2M-18 DATE 4/16/95 DAY 2 ARCO Alaska, inc. O Subsidiary of Atlantic Richfield Company DESCRIPTION OF WORK Perforate A4, A5, C4 Sands CONTRACTOR / KEY PERSON SWS-Gerard Johnson PBTD (RKB') [LAST '~AG (kKB) - DATE 7815' I 7782' on 2/8/95 1 1000 LOG ENTRY FIELD COST EST. $20,821 sssv TYP / ST : S Camco TRDP / In Service !Irdtial Pressures: Tbg = 900#, 7" = 1200# (Gas Lift SI), 9-5/8" = 750g TIME KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# K84959/I I223 ACCUMULATED COST . $21,9,63 I XlCHECK THIS BLOCK IF ~UMMARY, IS CONTINU~ ON BACK Weather [Temp. IChill Factor Report 1800 1630 0° phase, MPD, 61. 2-1/8" wt bar, CCL (CCL to top s.hot = 5'). Tie in.to sh.ort joints with !CRT dated 11/12/91. Perforate 7545'-7562' MD-RKB. WHP climbed to 1020# from 960g. iFired guns at 1300 hrs. POOH. ASF. RIH w/8' gun as above. Tie in and perforate 7529'-7537' MD-RKB. WHP remained at 1000#. iPOOH. ASF. iRIH w/28' gun as above. Tie in and perforate 7490'-7518' MD-RKB, POOH. ASF 'On Surface, RDMO SWS. Summary , Perforated with 2 1/8" Enerjet III 'DP' 4 SPF, 14 grams, EHD~.31", Penetration= 21.8" Intervals Shot: 7490'-7518' (28') 7529'-7537' (8') 7545'-7562' (17') 1400 1145 'RIH w/17' 2-1/8" Enerjet guns, 4 spf (EJIII, DP, 14 gms, EHD = 0.31", Penetration = 21.8"). Vel. I Signed Visibility, milesl Wtnd mphl , INCOMPLETE Randy Smith/Steve Bradley ;MIRU sWS and Hot Oil. SI well and block in gas..!i.ft at 1030 hrs. Held safety meeting. !PT lubricator to 2500g. Displace tubing w/30 bbls warm diesel at 2 bpm and 1500#. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 _ Pull tubing _ Variance _ Perforate _ Other X (CONV) 6. Datum elevation (DF or KB) 2, Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 114' FSL, 404' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1289' FNL, 1390' FWL, SEC 27, T11N, R8E, UM At effective depth 1074' FNL, 1446' FWL, SEC 27, T11N, R8E, UM At total depth 1002' FNL, 1465' FWL, SEC 27, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7926' feet true vertical 6251' feet Plugs (measured) RKB 146 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2M-18 9. Permit number 91-!9 10. APl number 50-103-20151 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7815' true vertical 6169' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3027' 9 5/8" 7862' 7" measured 7490'-7518', true vertical 5931'-5951', Cemented Measured depth 225 SX AS II 380SX PF E,510 SX CLASS G 100 SX PFC TOP JOB 300 SX CLASS G 7529'-7537', 5960'-5966', Tubing (size, grade, and measured depth) 3 .5", 9.3# J55 AMB-EUE, @7406' Packers and SSSV (type and measured depth) PKR: OTIS HVT @ 7380', SSSV: CAMCO TRDP-4A-RO @ 1824' 123' 3070' 7905' 13. Attachments Description summary of proposal CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR. True vertical depth 123' 2793' 6236' 5971'-5984', 5992'-6020' dUN 0 7 1995 Alaska Oil & Gas Corls Detailed operation program ~ BOP-~'~'~{~'~ 14. Estimated date for commencing operation JULY 1, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended To be reclassified as: Service WAG INJECTOR 17. I hereby_ ce..rt..i,f,,y that the foreooincL.!S~.~true Signed and correct to the best of my knowledge. Title: Wells Superintendent Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test ~ Subsequent form require Approved by order of the Commission Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Alaska, inc~/-'~- Post Office . 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION Stimulate ~;',--~-~. 2M-18 Stimulate Stimulate :.;, ~_ !~.::~ 2M- 19 Stimulate Stimulate ~.. ,_~ ¢. 2M-20 Stimulate Stimulate ~; ~_~,-~ 2M-21 Stimulate Stimulate ~:?z._ ~q. 2M-22 Stimulate Stimulate c~.~.. 5¢ 2M-24 Stimulate Stimulate o1,_ ~_~ 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051696 (w/o atch) AR3B-6003-93 242-2603 j STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate X Plugging Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 404' FWL, SEC27, T11N, R8E, UM At top of productive interval 1289' FSL, 1390' FWL, SEC27, T11N, R8E, UM At effective depth At total depth 1002' FSL, 1465' FWL, SEC27, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7926' 6251 ' feet feet Perforate -- Other 6. Datum elevation (DF or KB) RKB 148' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-18 9. Permit number/approval number 10. APl number 5o-103-20151 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 78 1 5' true vertical 6169' feet feet Junk (measured) Casing Length Size Structural Conductor 1 2 3' 1 6" Surface 3070' 9 5/8" Intermediate Production 7905' 7" Liner Perforation depth: measured 7573' - 7612' true vertical 5992'- 6020' Tubing (size, grade, and measured depth) 3 .5", 9.3# J55 AMB-EUE, @7406' Cemented Measured depth True vertical depth 225 SX AS II 380SX PF E,510 SX CLASS G 100 SX PFC TOP JOB 300 SX CLASS G RECEIVED MAY 20 1994 Oii & Gas Cons. Commission Packers and SSSV (type and measured depth) CAMCO TRDP-4A-RO @ 1824', OTIS PBR @ 7365', OTIS HVT PKR @ 7380' Anchorage 113. Stimulation or cement squeeze summary Intervals treated (measured)7573' - 7612' Treatment description including volumes used and final pressure See Attached Summary 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation None 3047 2563 0 1000 I 16. Status of well classification as: Water Injector Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~;~-~F'~, ~/~-~~ Title Senior Engineer Form 10-404 Rev 06/15/88 Subsequent to operation 5/17/92 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 150 Service Date ~' -1 7'""~/..ir SUBMIT IN DUPLICATE 2M-18 04/21/92 GSW FRAC W/DS YF140D. PUMPED 250 BBL GW PREPAD @ 25 BPM, LAST WHTP=3864 PSI, ISIP=1332 PSI, FG=.66 PSI/FT, PERF/XS FRIC=1030 PSI. SD FOR 30 MINUTES. PUMP 393 BBL PAD @ 25 BPM, LAST WHTP=5008 PSI. PUMP 89.5 MLBS 12/18 CL IN 2 TO 12 PPA STAGES @ 25 BPM. FLUSH W/77 BBLS GW/SLK WTR/SLK DSL @ 25 BPM, LAST WHTP=5576 PSI, ISIP=1703 PSI, FG=.72 PSI/FT. TOTAL PROP: DESIGN=93.3 MLBS, IN FORM=86.6 MLBS W/12.4 PPA @ PERFS. TOTAL FLUIDS: WATER=836 BBLS, DSL(FLA)=80 BBLS, ADD'S=68 BBLS. ALL FLUIDS EXCELLENT. SMART COMPUTER @ 2V-15. (LENZ/BEAL) Gas Cons. Commission Anchorage AOGCC Individual Well Geological Materials Inventory Page: Date: 1 01/19/94 PERMIT 91-019 91-019 91-019 91-019 91-019 91-019 91-019 91-019 DATA CBT CET CYB / DIL/SF/'GR(PHAS) GR(PHAS) / LDL/CNL~R(PORO) USIT (C&C) DATA_PLUS 5800-7814 5800-7814 3070-7881 L 3070-7914 L 3070-7914 L 3070-7881 L 3070-7881 L 100-3065 SCALE 5 5 5 5 2 2&5 2&5 5 DATE_RECVD 11/27/91 11/27/91 11/19/91 11/19/91 11/19/91 11/19/91 11/19/91 11/19/91 91-019 407 R COMP DATE: 02/27/92 03/20/92 91-019 91-019 91-019 DAILY WELL OP SST 'O/'- ~_T P.E CT~ ~,,'AL 5133 Are dry ditch samples Was the well cored? 10/28/91-02/28/92 0-7926 T 102-7962, required? yes no no OH-Z~A~hrNL And received? yes no Analysis & description received? 03/20/92 03/20/92 12/09/91 yes no Are well tests required? yes no Received? yes no Well is in compliance Initial Comments ~1 .V~, ~&V~OI.~.~ ~-~ ORIGINAL ~STATE OI~ AI. A3KA ALA:SKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED r'-] SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-19 & 91-342(403 SA. NO.) ..... 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360~ ~.-,... __~..~_~___ 50-103-20151 4 Location of well at surface ~'!]~!i~i i~!:~;~'~' 9 Unit or Lease Name ~ ,~ ...... ~ LOCATION&: KUPARUK RIVER 1289 ESL, FWL, 27, 1N, R8E, ~(.~. ~i 2M-18 At Total Depth !~ :~ L~' ~~ ~ ~ ~ 11 Field and Pool 1002' FSL, 1465' FWL, SEC 27, T11N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 148', PAD 106' GL ADL 25586, ALK 2672 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 10/28/91. 11/02/91. 02/27/92.J NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7926' MD, 6251' TVD 7815' MD, 6169' TVD YES X~ NO U 1824' feet MD 1400' APPROX 22 Type Electric or Other Logs Run LDTCN L/DIL/SFL/G R/CAL/S P/AIT/CBT/CET/USIT/GCT 23 CASING, LINER AND CEMENTING RECORD I SEI-I-ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 123' 24" 225 SX ASII 9-5/8" 36# J-55 SURF 3070' 12-1/4" 380 SX PF E, 510 SX CLASS G 100 SX PFC TOP JOB 7" 26# J-55 SURF 7905' 8-1/2" 300 SX CLASS G ,. 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) !PACKER SET (MD) 3-1/2" 7406' 7380' 7573' -7612' W/4-1/2" CSG GUN @ 4 SPF MD 5991 '-6020' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,e FI°w Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE Brief description of lifhology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N ~ ~ ~ I V MAR 0 1992 Alaska 01~ & Bas Cons. ~omtms~lo~'-' Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KU PAFIUK C TOP 7488' 5930' NA KU PARUK C Bo'FrOM 7521' 5954' KU PARUK A TOP 7521' ]954' KUPARUK A Bo'FrOM 7702' 6086' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ..... ~~___'___~~ Title AREA DRILLING ENGINEER 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 ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-18 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20151 91-19 DAILY OPERATIONS ACCEPT: 10/27/91 SPUD: 10/28/91 RELEASE: 11/04/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK5717 PAGE: 1 10/28/91 (1) TD: 760' ( 760) SUPV:DS 10/29/91 (2) TD: 3125'(2365) SUPV:DS 10/30/91 (3) TD: 3125'( SUPV:DS o) 10/31/91 (4) TD: 4645' (1520) SUPV:DS 11/01/91 ( 5) TD: 6102' (1457) SUPV:DS 11/02/91 ( 6) TD: 7850' (1748) SUPV: KKL DRILLING SURF HOLE 9-5/8"@ 3070' MW: 9.0 VIS: 84 ACCEPT RIG @ 0900. NU DIVERTER AND FUNCTION TEST. MIX SPUD MUD. SERVICE TOP DRIVE. MU BHA #1. DRILL FROM 110' TO 760'. DAILY:S64,234 CUM:$64,234 ETD:S64,234 EFC:$1,250,000 POH W/5" DP 9-5/8"@ 3070' MW: 9.4 VIS: 45 CONTINUE DRILLING FROM 760' TO 3125' SHORT TRIP TO HWDP. RIH AND CBU. POH FOR 9-5/8" CASING. DAILY:S55,748 CUM:$119,982 ETD:S119,982 EFC:$1,250,000 PU DP IN PREP TO RIH 9-5/8"@ 3070' MW: 9.7 VIS: 38 POH, LD MWD. RU CSG CREW AND RUN 71 JTS OF 9-5/8" J-55 36# CASING. TAG BRIDGE @ 3055' AND WASH DOWN TO 3075'. CIRC AND RECIP PIPE. PUMPED PLUG #1, 100 BBL FRESH WATER SPACER, PLUG #2, 133 BBL PERMAFRAOST "E" LEAD CEMENT @ 12.3 PPG, 105 BBL CLASS G TAIL CEMENT @ 15.6, TOP PLUG. DIPLACED WITH 20 BBL WATER AND 213 BBL MUD. RECIP THRUOUT JOB, FULL RETURNS UNTIL CEMENT ROUNDED SHOE AND THEN 50% RETURNS IMPROVING TO NEARLY FULL RETURNS HALFWAY THRU DISPLACEMENT. BUMPED PLUG, NO CEMENT TO SURFACE, PUMPED 100 SX TOP JOB. SET 9-5/8" SLIPS, INSTALL BRADENHEAD ADAPTER, PREHEAT CSG WITH HOT-HEAD, WELD ADAPTER TO CASING. 2ND HOT-HED TO STRESS RELIEVE. WAIT ON CASING TO COOL AND WORK ON TOP DRIVE, CUT DRILL LINE, PU DP. DAILY:S153,559 CUM:$273,541 ETD:S273,541 EFC:$1,250,000 DRILLING AT 4645 9-5/8"@ 3070' MW: 9.0 VIS: 35 ND BRADENHEAD. NU AND TEST BOPE. RIH AND TEST CASING· DRILL FC, FS, AND 10' NEW HOLE. TEST FORMATION TO 12.5 PPG. DRILL FROM 3135' TO 4645' DAILY:S87,358 CUM:$360,~99 ETD:S360,899 EFC:$1,250,000 DRILLING AT 6102 9-5/8"@ 3070' MW: 9.4 VIS: 39 DRILL FROM 4645' TO 5477'. CBU, POOH TO SHOE TO WORK ON TOP DRIVE. RIH AND DRILL FROM 5477' TO 6102' · DAILY:S57,926 CUM:$418,825 ETD:S418,825 EFC:$1,250,000 9-5/8"@ 3070' MW:10.3 VIS: 38 DRILLING FROM 6102' TO 7710' LOST ALL RIG POWER AND HAD TO RESTART ENGINES AND BRING POWER BACK UP. DRILL FROM 7710' TO 7850'. DAILY:S57,926 CUM:$476,751 ETD:S476,751 EFC:$1,250,000 RECEIVED 0 1992 Alaska 0i{ ,& Gas Cons. Oom ' ss' o WELL: 2M-19 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 11/03/91 ( 7) TD: 7926' ( 76) SUPV: KKL LOGGING 9-5/8" CASING 9-5/8"@ 3070' MW:10.4 VIS: 39 DRILL FROM 7850' TO 7926' (TD). SHORT TRIP TO SHOE. CIRCULATE AND CLEAN HOLE FOR LOGS. POH. RU SWS AND RUN OPEN HOLE LOGS. DAILY:S51,965 CUM:$528,716 ETD:S528,716 EFC:$1,250,000 11/04/91 ( 8) TD: 7926' ( SUPV: KKL o) 9-5/8"@ 3070' MW:10.5 VIS: 0 FINISH RUNNING USIT LOG. MAKE WIPER TRIP. RUN 7" CASING. CIRCULATE AND CONDITION MUD FOR CEMENTING. ONLY RECIEVED PARTIAL RETURNS WHILE CIRCULATING. PUMPED LOSS CIRCULATION MATERIAL TO TRY TO REGAIN RETURNS. BEGAN MIXING PREFLUSH FOR CEMENT JOB. DAILY:S241,209 CUM:$769,925 ETD:S769,925 EFC:$1,250,000 11/05/91 ( 9) TD: 7926'( SUPV:KKL o) RIG RELEASED 7"@ 7905' MW:10.6 VIS: 0 CEMENT 7" CASING W/300 SX CLASS G.RECIP CASING UNTIL APPROX 200 STROKES BEFORE BUMPING PLUG. FULL RETURNS UNTIL THIS POINT ALSO. BUMP PLUG, TEST CASING TO 3500 PSI, FLOATS HELD. ND BOPE AND NU FMC WELLHEAD. INJECT 70 BBLS DOWN 7" X 9-5/8" ANNULUS FOR FREEZE PROTECTION. DAILY:S24,220 CUM:$794,145 ETD:S794,145 EFC:$1,250,000 SIGNATURE: DRILLING~PERINTEN~_~NT DATE: ARCQ ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: IELD: LEASE: API: PERMIT APPROVAL: 2M-18 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20151 91-19 ACCEPT: 02/26/92 SPUD: RELEASE: 02/27/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK5717 02/27/92 (10) TD: 7926 PB: 7815 SUPV:DB/SB 02/28/92 (11) TD: 7926 PB: 7815 SUPV:DB/SB RD WIRELINE 7"@ 7905' MW:10.6 NaC1/Br MOVE RIG F/2M-15 TO 2M-18,ACCEPT RIG AT 2030 HRS 2-26-92,ND TREE,NU BOPE, TEST BOPE TO 3K, OK, RU SWS,PERF F/7573-7612',4 SPF, 180 DEG PHS,ORIENTED,POH, RD SWS DAILY:S26,761 CUM:$820,906 ETD:SO EFC:$2,070,906 RIG RELEASED 7"@ 7905' MW:10.6 NaC1/Br CONT RD SWS,RU AND RIH W/3-1/2" SINGLE COMPLETION AS PER PROCEDURE,MU SSSV AND C-LINE, TEST C-LINE TO 5K, OK, CONT RIH W/COMP,MU HGR AND C-LINE,TEST C-LINE TO 5K, OK, LAND TBG, RILDS PRESS TBG F/500-3000 PSI IN 500 PSI INCREMENTS TO SET PKR BLEED OFF PRESS,BOLDS,PRESS TBG TO 1900 PSI,PU AND SHEAR PBR AT 90K#,RELAND TBG, RILDS,TEST SSSV W/500 PSI DIFF,OK, TEST ANN TO 2500 PSI FOR 15 MIN, OK, PRESS TBG TO 3600 PSI AND SHEAR SOS,CLOSE SSSV, SET BPV, ND BOPE,NU TREE,PULL BPV, SET TEST PLUG, TEST TREE TO 250/5000 PSI,OK, TEST PACKOFF TO 5000 PSI,OK, PULL TEST PLUG, OPEN SSSV, RU AND DISPLACE ANN W/12 BBLS DIESEL, BULLHEAD 4 BBLS DIESEL DN TBG, RD LINES,SECURE WELL, SITP=300,SICP=0,SIAP=700,RELEASE RIG AT 1900 HRS 2/27/92,MOVE TO 2M-19 DAILY:S155,314 CUM:$976,220 ETD:SO EFC:$2,226,220 SIGNATURE: DATE: 0 i~ I-G I.N A L SUB - S URFA CE DIRECTIONAL SURVEY r~-j UIDANCE ONTINUOUS r'~ OOL RECEIVED MAR ~ 0 1992, Alaska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 2M-18 (114' FSL,404' FWL, SEC 27,T11N,R8E) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 75324 Loclqed By: BARNARD Date 13-NOV-91 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 13-NOV-91 ENGINEER: K.BARNARD METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. Averaged deviation and azimuth PROJECTED ONTO A TARGET A~IMUTH OF NORTH 13 DEG 37 MIN EAST COMPUTATION DATE: 16-JAN-92 PAGE 1 ARCO ALASKA [NC. 2M - 18 KUPARUK RZVER NORTH SLOPE, ALASKA DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 14t.00 FT ENGINEER: K.BARNARD [NTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTZCAL VERTZCAL DEVIATION AZZMUTH DEPTH DEPTH DEPTH DEG MZN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DZST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG M[N 0.00 100.00 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0.00 -141.00 0 0 N 0 0 E 100.00 -41.00 0 7 $ 4 57 W 200.00 59.00 0 7 S 16 42 E 300.00 159.00 0 5 S 23 27 E 400.00 259.00 0 9 $ 35 48 E 500.00 359.00 0 9 S 38 4 E 600.00 459.00 0 13 S 39 45 E 700.00 559.00 0 12 $ 48 9 E 800.00 659.00 0 20 S 39 11 E 899,99 758,99 0 25 S 36 3 E O.O0 -0.06 -0.25 -0 42 -0 57 -0 74 -0 91 -1 12 -1 40 -1 77 0.00 0.00 N 0.00 E 0.22 0.06 S 0.00 W 0.38 0.27 S 0.05 E O. 15 0.47 $ 0.14 E 0.37 0.66 S 0.28 E 0.51 0.87 S 0.45 E 0.45 1.09 S 0.64 E 0.35 1.37 S 0.89 E 0.36 1,74 S 1.22 E 0.14 2.20 S 1.58 E 0.00 N 0 0 E O. 06 S 0 27 W 0 27 S 10 54 E 0 49 S 16 45 E 071 S 23 9 E 0 97 S 27 23 E ~ 27 S 30 18 E 1 63 S 33 3 E 2 12 S 35 7 E 2 71 S 35 41 E 1000.00 999.99 858.99 0 24 1100.00 1099.99 958.99 0 38 1200.00 1199.94 1058.94 2 55 1300.00 1299.58 1158.58 6 43 1400.00 1398.54 1257.54 9 42 1500.00 1496.84 1355.84 11 24 1600.00 1593.96 1452.96 16 15 1700.00 1668.07 1547.07 23 23 1800.00 1777.66 1636.66 27 52 1900.00 1866.13 1725.13 27 52 S 42 29 E N 79 22 E N 27 11 E N 17 5 E N 14 27 E N 14 55 E N 17 11E N 16 57 E N 15 16 E N 15 39 E -2 16 -2 16 0 30 8 49 22 80 41 15 64 78 98 31 142 62 189.22 0.28 2.70 S 1.98 E 3.35 S 36 18 E 1.29 2.86 S 2.64 E 3.89 S 42 41 E 3.15 0,76 S 4.43 E 4.50 S 80 16 E 3.4t 6.98 N 7.29 E 10.09 N 46 15 E 2.87 20,77 N 11.10 E 23.55 N 28 8 E 2.97 38.54 N 15.68 E 41.61 N 22 9 E 5.36 61.25 N 22.28 E 65.18 N 20 0 E 8.63 93,31 N 32.38 E 98.77 N 19 8 E 0.75 135,99 N 44.39 E 143.05 N 18 5 E 0,61 180.92 N 56.88 E 189.65 N 17 27 E 2000.00 1953.88 1812.88 29 46 2100.00 2039.50 1898.50 32 20 2200.00 2122.87 1981.87 34 29 2300,00 2204.95 2063.95 35 1 2400.00 2286.84 2145.84 35 15 2500.00 2367.49 2226.49 37 17 2600.00 2445.52 2304.52 40 8 2700,00 2520.89 2379.89 41 45 2800.00 2595.07 2454.07 42 9 N 9 59 E 2900.00 2669.16 2528.16 42 29 N 9 48 E N 14 25 E 237 15 N 12 0 E 288 78 N 9 47 E 343 91 N 9 58 E 40O 91 N 10 29 E 458 2O N 10 46 E 517 24 N 10 20 E 579 66 N 10 22 E 645.28 712.22 779.24 2.65 2.71 1 .21 0.35 1 .41 2.65 3.12 1 .23 0.53 0.82 227.18 N 69.47 E 237.56 N 17 0 E 277.46 N 81.23 E 289.11 N 16 19 E 331.69 N 91.51 E 344.08 N 15 25 E 387.99 N 101.20 E 400.98 N 14 37 E 444.46 N 111.40 E 458.21 N 14 4 E 502.55 N 122.39 E 517.24 N 13 41 E 564.03 N 133.75 E 579.67 N 13 20 E 628,66 N 145.63 E 645.31 N 13 3 E 694.68 N 157.43 E 712.30 N 12 46 E 760.84 N 168.98 E 779.38 N 12 31 E 3000.00 2742.31 2601.31 43 35 N 9 37 E 847.26 3100.00 2814.50 2673.50 43 52 N 9 40 E 916.30 3200.00 2886.37 2745.37 44 9 N 9 3 E 985.64 3300.00 2958.09 2817.09 44 18 N 8 36 E 1055.08 3400.00 3029.58 2888.58 44 19 N 8 24 E 1124.72 3500.00 3101.15 2960.15 44 20 N 8 21 E 1194.27 3600.00 3172.62 3031.62 44 28 N 8 28 E 1263.92 3700.00 3243.97 3102.97 44 30 N 8 26 E 1333.70 3800.00 3315.50 3174.50 44 7 N 9 47 E 1403.32 3900.00 3387.51 3246.51 43 58 N 16 42 E 1472.66 1 .23 O. 48 0.51 0.33 0.43 0.23 0.20 0.74 4.37 2.48 828.05 N 180.44 E 847.48 N 12 18 E 896.28 N 192.03 E 916.62 N 12 6 E 964.87 N 203.41 E 986.07 N 11 54 E 1033.75 N 214.01 E 1055.67 N 11 42 E 1102.90 N 224.36 E 1125 49 N 11 30 E 1172.00 N 234.51 E 1195 23 N 11 19 E 1241.19 N 244.73 E 1265 08 N 11 9 E 1310.49 N 255.04 E 1335 08 N 11 1 E 1379.56 N 265.59 E 1404 90 N 10 54 E 1446.92 N 282.03 E 1474 16 N 11 2 E COMPUTATION DATE: 16-JAN-92 PAGE 2 ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG 'RECTANGULAR COORDINATES HOR[Z. DEPARTURE MEASURED -VERTICAL VERTICAL DEVIATION AZIMUTH SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG MZN FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3459.39 3318.39 44 12 N 19 32 E 1541.92 4100.00 3530.90 3389.90 44 31 N 19 23 E 1611.46 4200.00 3602.06 3461.06 44 45 N 19 17 E 1681.36 4300.00 3672.94 3531.94 45 2 N 19 5 E 1751.57 4400.00 3743.49 3602.49 45 13 N 18 54 E 1822.13 4500,00 3813.81 3672.81 45 27 N 18 43 E 1892,94 4600.00 3883.93 3742.93 45 28 N 18 37 E 1963.95 4700.00 3953.98 3812.98 45 36 N 18 14 E 2035.06 4800.00 4023.94 3882.94 45 32 N 17 43 E 2106.3~ 4900.00 4093.97 3952.97 45 36 N 17 22 E 2177.52 0.45 1512.85 N 304.07 E 1543 10 N 11 22 E 0.30 1578.76 N 327 37 E 1612 34 N 11 43 E 0.14 1645.04 N 350 0.38 1711.67 N 373 0.28 1778.68 N 396 0.32 1845.99 N 419 0.15 1913.53 N 442 0.36 1981,22 N 465 0.49 2049.18 N 487 0.23 2117.26 N 508 63 E 1682 O0 N 12 2 E 81 E 1752 02 N 12 19 E 89 E 1822 42 N 12 35 E 81 E 1893 12 N 12 49 E 63 E 1964.05 N 13 1 E 22 E 2035.11 N 13 13 E 30 E 2106.33 N 13 23 E 76 E 2177.53 N 13 31 E 5000.00 4164.00 4023.00 45 32 N 17 10 E 2248.77 5100.00 4233.94 4092.94 45 46 N 16 50 E 2320.12 5200.00 4303.66 4162.66 45 51 N 16 41 E 2391.70 5300.00 4373.18 4232.18 46 2 N 16 41 E 2463.48 5400.00 4442.61 4301.6t 46 5 N 16 38 E 2535.34 5500.00 4511.76 4370.76 46 22 N 16 36 E 2607.48 5600°00 4580.78 4439.78 46 27 N 16 37 E 2679.75 5700.00 4649.35 4508.35 46 55 N 16 14 E 2752,44 5800.00 4717,59 4576.59 46 16 N 15 58 E 2825.48 5900.00 4788.35 4647.35 44 28 N 15 52 E 2896.06 0.48 2185.43 N 529 93 E 2248.77 N 13 38 E 0.49 2253.79 N 550 0.37 2322.44 N 571 0.26 2391.30 N 592 0.09 2460.26 N 612 0.09 2529.48 N 633 0.47 2598.82 N 654 0.41 2668.63 N 674 4.17 2738.87 N 694 81 E 2320,12 N 13 44 E 44 E 239'1.71 N 13 49 E 07 E 2463,51 N 13 54 E 68 E 2535,40 N 13 59 E 34 E 2607.56 N 14 3 E 04 E 2679.85 N 14 8 E 64 E 2752.58 N 14 11 E 88 E 2825.65 N 14 14 E 0.67 2806.76 N 714.42 E 2896,26 N 14 17 E 6000.00 4859.94 4718.94 44 0 N 15 15 E 2965.84 6100.00 4931.87 4790.87 44 9 N 14 59 E 3035.29 6200.00 5003.63 4862.63 44 6 N 14 33 E 3104.92 6300.00 5075.33 4934.33 44 15 N 14 14 E 3174.62 6400.00 5146.75 5005.75 44 33 N 14 1 E 3244.61 6500.00 5217.86 5076.86 44 48 N 13 52 E 3314.92 6600.00 5288.80 5147.80 44 55 N 13 30 E 3385.40 6700.00 5360.47 5219.47 43 29 N 14 24 E 3455.13 6800.00 5432.87 5291.87 43 46 N 14 22 E 3524.10 6900.00 5504.97 5363.97 43 58 N 14 5 E 3593.40 0 67 2874.06 N 733 02 E 2966.06 N 14 18 E 74 2941.09 N 751 55 3008.44 N 768 06 3075.98 N 786 35 3143.86 N 803 23 3212.09 N 820 71 3280.55 N 837 04 3348.29 N 853 53 3415.10 N 870 0.29 3482.27 N 887 27 E 3035.53 N 14 20 E 98 E 3105.17 N 14 20 E 25 E 3174,87 N 14 20 E 33 E 3244.87 N 14 20 E 29 E 3315.18 N 14 20 E 01 E 3385.65 N 14 19 E 59 E 3455.38 N 14 18 E 75 E 3524.36 N 14 18 E 79 E 3593.66 N 14 18 E 7000.00 5576.86 5435.86 44 6 N 13 57 E 3662.91 7100.00 5648.64 5507.64 44 14 N 13 58 E 3732.53 7200.00 5720.40 5579.40 43 56 N 13 52 E 3802 17 7300.00 5792.66 5651.66 43 32 N 13 33 E 3871 30 7400.00 5865.29 5724.29 43 18 N 13 57 E 3940 04 7500.00 5938.27 5797,27 43 7 N 15 22 E 4008 38 7600.00 6011.30 5870.30 43 1 N 14 52 E 4076 67 7700.00 6084.51 5943.51 43 0 N 14 36 E 4144 79 7800.00 6158.21 6017.21 42 21 N 14 27 E 4212 33 7900.00 6232.12 6091.12 42 21 N 14 27 E 4279 68 0.32 3549.72 N 904 60 E 3663 17 N 14 18 E 0.21 3617.29 N 921 0.72 3684.89 N 938 0.66 3752.06 N 954 0.99 3818.85 N 970 0.54 3884.99 N 988 0.93 3950.93 N 1005 1.35 4016.84 N 1023 0.00 4082.25 N 1039 0.00 4147.47 N 1056 39 E 3732 12 E 3802 47 E 3871 70 E 3940 O0 E 4008 83 E 4076 06 E 4145 97 E 4212 78 E 4279 79 N 14 17 E 44 N 14 17 E 56 N 14 16 E 29 N 14 16 E 65 N 14 16 E ,95 N 14 17 E 08 N 14 17 E 63 N 14 18 E ,99 N 14 18 E ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE= 16-JAN-92 PAGE 3 DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 7926.00 6251.34 6110.34 42 21 N 14 27 E 4297.19 0.00 4164.43 N 1061.16 E 4297.50 N 14 18 E COMPUTATION DATE: 16-JAN-92 PAGE 4 ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG M[N FEET DEG/IO0 FEET FEET FEET DEG 0 O0 1000 2000 3000 4OOO 5000 6000 7O00 7926 O0 999.99 858.99 0 24 S 42 29 E -2 O0 1953.88 1812 88 29 46 N 14 25 E 237 O0 2742.31 2601 31 43 35 N 9 37 E 847 O0 3459.39 3318 39 44 12 N 19 32 E 1541 O0 4164.00 4023 O0 45 32 N 17 10 E 2248 O0 4859.94 4718 94 44 0 N 15 15 E 2965 O0 5576.86 5435 86 44 6 N 13 57 E 3662 O0 6251.34 6110 34 42 21 N 14 27 E 4297 0.00 -141.00 0 0 N 0 0 E 0 O0 16 15 26 92 77 8~ 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.28 2.70 S 1.98 E 3.35 $ 36 18 E 2.65 227.18 N 69.47 E 237.56 N 17 0 E 1.23 828.05 N 180.4a E 847.48 N 12 18 E 0.45 1512.85 N 304.07 E 1543.10 N 11 22 E 0.48 2185.43 N 529.93 E 2248.77 N 13 38 E 0.67 2B74.06 N 733.02 E 2966.06 N 14 lB E 0.32 3549.72 N 904.60 E 3663.17 N t4 18 E 0.00 4164.43 N 1061.16 E 4297.50 N 14 18 E COMPUTATION DATE: 16-JAN-92 PAGE 5 ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 141.00 241.00 341.00 441.00 541.00 641.00 741.00 841.00 941.01 0.00 -141.00 141.00 0.00 241.00 100.00 341.00 200 O0 441.00 300 O0 541.00 400 O0 641,00 500 O0 741,00 600 O0 841,00 700 O0 941,00 800 O0 0 0 N 0 0 E 0 9 S 29 19 E 0 g S 25 26 E 0 9 S 41 51 E 0 9 S 39 13 E 0 10 S 39 31 E 0 11 S 41 45 E 0 19 S 39 19 E 0 18 S 40 7 E 0 20 S 40 20 E 0,00 0,00 0,00 N -0,17 0,35 0,18 S -0,34 0,10 0,37 S -0.48 O. 14 0.54 S -0.64 0.16 0.74 S -0.81 0.36 0.95 S -0.,99 0,24 1,20 S -1,22 0,53 1.50 S -1,54 0,48 1,92 S -1.93 0.25 2.41 S 0,00 E 0,03 E 0,09 E 0 19 E 0 35 E 0 52 E 0 74 E 1 01 E I 38 E I 75 E 0.00 N 0 0 E 0.18 S 8 33 E 0.38 S 14 27 E 0.57 S 19 42 E 0.82 S 25 19 E 1 .09 S 28 27 E !.41 S 31 ~,4 E i,81 S 33 52 E 2.36 S 35 39 E 2,97 S 35 58 E 1041,01 1041,00 900,00 0 20 1141,02 1141,00 1000,00 1 21 1241,14 1241,00 1100,00 4 18 1341,77 1341,00 1200 O0 8 0 1443,14 1441,00 1300 O0 10 32 1545,21 1541,00 1400 O0 13 21 1649.42 1641.00 1500 O0 19 31 1758.65 1741.00 1600 O0 27 7 1871.59 1841.00 1700 O0 27 44 1985.21 1941.00 1800 O0 29 24 S 73 18 E N 49 33 E N 21 21 E N 15 40 E N 14 18 E N 16 2 E N 17 45 E N 15 22 E N 15 38 E N 14 44 E -2 24 -1 70 2183 13 86 30 41 50 79 79 88 123 51 175 98 229 87 0.29 2.69 4.15 2.74 1.11 5.31 7.48 3.43 0.41 2.72 2,84 S 2,20 E 3,59 S 37 45 E 2,52 S 3,22 E 4,09 S 51 53 E 1,59 N 5,46 E 5,68 N 73 46 E 12,13 N 8,79 E 14,98 N 35 56 E 28. 15 N 12.99 E 31 . O0 N 24 46 E 47.84 N 18.26 E 51.21 N 20 54 E 75.69 N 26.84 E 80.31 N 19 32 E 117.55 N 39.35 E 123.96 N 18 30 E 168.16 N 53.31 E 176.41 N 17 35 E 220.14 N 67.62 E 230.29 N 17 5 E 2101.78 2041.00 1900 O0 32 23 2222.02 2141.00 2000 2344.00 2241.00 2100 2466.87 2341.00 2200 2594.12 2441.00 2300 2727.01 2541.00 2400 2861.92 2641.00 2500 2998,18 2741,00 2600 3136,80 2841,00 2700 3276.14 2941.00 2800 N 11 58 E O0 34 43 N 9 41 E 356 O0 34 57 N 10 13 E 426 O0 36 34 N 10 49 E 497 O0 39 58 N 10 20 E 575 O0 42 4 N 10 12 E 663 O0 42 10 N 9 53 E 753 O0 43 34 N 9 37 E 846 O0 44 2 N 9 33 E 941 O0 44 13 N 8 38 E 1038 289 74 38 O9 36 91 28 66 O0 77 49 2,72 0,81 0.52 1 .79 2.95 1 ,32 0,74 1 ,26 0.68 O. 44 278,40 N 81,43 E 290,06 N 16 18 E 344,01 N 93,62 E 356,52 N 15 13 E 412,83 N 105,62 E 426.13 N 14 21 E 483,00 N 118,66 E 497.36 N 13 48 E 560.33 N 133,07 E 575.91 N 13 22 E 646,40 N 148,85 E 663.32 N 12 58 E 735,58 N 164,59 E 753,77 N 12 37 E 826,81 N 180,23 E 846,23 N 12 18 E 921,45 N 196,30 E 942,13 N 12 2 E 1017,28 N 211,51 E 1039,04 N 11 45 E 3415.96 3041.00 2900 O0 44 17 3555.71 3141.00 3000 O0 44 22 3695.83 3241.00 3100 O0 44 31 3835.44 3341.00 3200.00 43 55 3974.38 3441.00 3300 O0 44 5 4114,17 3541,00 3400100 44 34 4254,88 3641,00 3500.00 44 52 4396.46 3741,00 3600,00 45 13 4538,78 3841,00 3700,00 45 29 4681,45 3941,00 3800,00 45 34 N 8 21E 1135.83 N 8 25 E 1233 04 N 8 26 E 1330 N 12 47 E 1427 N 19 24 E 1524 N 19 22 E 1621 N 19 10 E 1719 N 18 55 E 1819 N 18 41 E 1920 N 18 19 E 2021 79 91 17 35 84 63 48 86 O. 34 0.57 0.71 6.88 0.80 0.52 0.41 0.29 1113.93 N 225.98 E 1136.62 N 11 28 E 1210.51 N 240.18 E 1234.11 N 11 13 E 1307.60 N 254.61 E 1332.16 N 11 1 E 1403.69 N 270.42 E 1429.50 N 10 54 E 1496.02 N 298.12 E 1525.44 N 11 16 E 1588.13 N 330.67 E 1622.19 N 11 46 E 1681.56 N 363.37 E 1720.37 N 12 12 E 1776.30 N 396.07 E 1819.92 N 12 34 E 0,00' 1872,18 N 428,67 E 1920.63 N 12 54 E 0,39 1968,64 N 461.06 E 2021,91 N 13 11 E COMPUTATION DATE: 16-JAN-92 PAGE 6 ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 'TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4824 36 4041.00 3900 O0 45 31 4967 5110 5253 5397 5542 5687 5833 5973 6112 17 4141,00 4000 12 4241,00 4100 67 4341,00 4200 68 4441,00 4300 35 4541,00 4400 78 4641,00 4500 47 4741,00 4600 63 4841,00 4700 73 4941,00 4800 O0 45 30 O0 45 48 O0 45 58 O0 46 5 O0 46 19 O0 46 53 O0 45 2 0[: 44 11 OC 44 10 N 17 34 E 2123.65 N 17 12 E 2225.39 N 16 48 E 2327.35 N 16 41 E 2430.19 N 16 39 E 2533.67 N 16 37 E 2638.08 N 16 18 E 2743.53 N 16 8 E 2849.37 N 15 14 E 2947.50 N 14 53 E 3044.16 0.39 0,29 0,41 0.14 0,05 0.19 0,35 3,02 0.93 0,63 2065,75 N 492,57 E 2123 66 N 13 25 E 2163,06 N 523,01 E 2225 .2260,73 N 552,91 E 2327 2359,38 N 582,50 E 2430 2458,65 N 612.20 E 2533 2558,84 N 642,10 E 2638 2660,06 N 672,14 E 2743 2761.86 N 701,49 E 2849 2856,36'N 728,19 E 2947 2949,66 N 753,55 E 3044 39 N 13 36 E 36 N 13 45 E 22 N 13 52 E 73 N 13 59 E 17 N !4 5 E 67 N t4 11 E 55 N 14 15 E 72 N 14 18 E 40 N 14 20 E 6252.09 5041.00 4900.00 44 13 N 14 19 E 3141.20 6391.93 5141.00 5000.00 44 31 N 14 1 E 3238.96 6532.60 5241.00 5100.00 44 46 N 13 48 E 3337.88 6673.10 5341 O0 5200.00 43 45 N 14 1 E 3436.58 6811.26 5441 O0 5300.00 43 48 N 14 20 E 3531.90 6950.10 5541 O0 5400.00 44 2 N 13 58 E 3628.20 7089.35 5641 O0 5500.00 44 12 N 13 58 E 3725.10 7228.57 5741 O0 5600.00 43 47 N 13 45 E 3821.97 7366.59 5841 O0 5700.00 43 27 N 13 40 E 3917.09 7503.74 5941 O0 5800.00 43 7 N 15 22 E 4010.94 0.25 0.32 0.31 2 52 041 012 0 27 0 45 0 25 0 53 3043,59 N 778,02 E 3141 45 N 14 20 E 3138.37 N 801.96 E 3239 3234.39 N 825.78 E 3338 3330.30 N 849.04 E 3436 3422.65 N 872.68 E 3532 3516.04 N 896.23 E 3628 3610.08 N 919.60 E 3725 3704.12 N 942.85 E 3822 3796.57 N 965.22 E 3917 3887.45 N 988.68 E 4011 21 N 14 2O E 14 N 14 19 E 83 N 14 18 E 16 N 14 18 E 46 N 14 18 E 37 N 14 17 E 23 N 14 17 E 35 N 14 16 E 20 N 14 16 E 7640.57 6041.00 5900.00 42 53 N 14 36 E 4104.31 7776.72 6141.00 6000.00 42 21 N 14 27 E 4196.65 7912.01 6241.00 6100.00 42 21 N 14 27 E 4287.77 7926.00 6251.34 6110.34 42 21 N 14 27 E 4297.19 0,78 0.00 0.00 0,00 3977,67 N 1012.86 E 4104.60 N 14 17 E 4067,06 N 1036,06 E 4196.95 N 14 18 E 4155,30 N 1058,80 E 4288,08 N 14 18 E 4164.43 N 1061,16 E 4297,50 N 14 18 E COMPUTATION DATE: 16-JAN-92 PAGE 7 ARCO ALASKA [NC. 2M - 18 KUPARUK R]:VER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY: 13-NOV-91 KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114" FSL & 404'FWL, SEC27 TllN RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3070.00 2792.86 7488.00 5929.51 7521.00 5953.60 7521.00 5953.60 7702.00 6085.97 7750.09 6121.32 7815.00 6169.30 7905.00 6235.82 7926.00 625~.34 2651 5788 5812 5812 5944 5980 6028 6094 6110 86 51 60 60 97 32 30 82 3,4 875.79 N 188.54 E 3877.08 N 985.85 E 3898.83 N 991.80 E 3898.83 N 991.80 E 4018.16 N 1023.41 E 4049.73 N 1031.57 E 4092.03 N 1042.49 E 4150.73 N 1057.63 E 4164.43 N 1061.16 E COMPUTATION DATE: 16-JAN-92 PAGE 8 ARCO ALASKA INC. 2M - 18 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GC7 PBTD 7" CASING TD DATE OF SURVEY: 13-NOV-gl KELLY BUSHING ELEVATION: 141.00 FT ENGINEER: K.BARNARD SURFACE LOCATION = 114' FSL & 404'FWL, SEC27 T11N RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3070.00 2792.86 2651.86 7488.00 5929.51 5788.51 7521.00 5953.60 5812.60 7521.00 5953.60 5812.60 7702.00 6085.97 5944.97 7750,09 6121.32 5980,32 7815.00 6169,30 6028.30 7905,00 6235.82 6094.82 7926.00 6251,34 6110.34 875 79 N 3877 08 N 3898 83 N 3898 83 N 4018 16 N 4049 73 N 4092 03 N 4150 73 N 4164 43 N 188.54 E 985.85 E 991.80 E 991.80 E 1023.41E 1031.57 E 1042.49 E 1057.63 E 1061.16 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7926.00 6251.34 6110.34 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4297.50 N 14 18 E DIRECTIONAL SURVEY COMPANY AF~CO ALASKA INC. ;,EL~ KUPARUK RIVER WELt. 2M - 18 COUNTRY USA RUN ONE DAT~ LOCKED 13 - NOV - 91 DEPTH UNIT FEET REFERENCE 75324 WELL' 2M218 (114' FSL, 404' FWL, SEC 27, T11N, R8E) HORIZONTAL, PROJECTION WELL' 2M-18 (1i4' FSL, 404' FWL, SEC 27, TllN, R8E) VERTICAL PROJECTION -~:K~O -1000 0 0 1000 L~O00 3000 4000 (DO0 ~/F'r ~OGCC G£OLOGICAL tdAT£RIALS INVFNTOFIY LIST COMPLEIlON DATE .2_- i ~ i ~',,,~--~ CO. CONTACT & NO. Iorm received ~eceive'd date Commenls ,, 493 yes no sund~ application '404 yes no " report of sund~ appliCallan Open ---requ'ired 'r~e-~:~ive'd' ~'~,~se~-'~,q-ui;~d .... ;eceiv,~, i~rb'~i'~-~:iio, ;eq'uired- received hole log hole log log .. USeL enL. BHCiSL ...... cet 'sss ...... Pa~e. "' .~..~....... Data : .... FDC_ FDC " HWD ,equi,c~' ~e'cUiVCd SA~L~ iequi,Cd' ';cceive~ iLDTICNL ...... ML core CY~[h LOOK , , , ~nalysis , , , ~S ~ , , , ..... . ,,, , , NGr ~ ....... , . .... ,., .... , ARCO Alaska, Inc. Date: January 24, 1992 Transmittal #: 8344 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 M - 1 8 Sub-Surface Directional 1 I - 1 3 - 91 75324 Survey *REVISED* ~--------~~Date' D&M S~Ra Receipt Acknowledged: RECEIVED JAN 2 7 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 10, 1992 Transmittal #: 8326 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 13'1 '" I'~ 2M- 1 8 ,,," Sub-Surface Directional ! Survey ~ - Sub-Surface Directional . 6~/ /,7.~ 2M 21 rvey Sub-Surface Directional ~[~.il3 1R-21 -~'/ Su Survey Receipt Acknowledged: D&M 11-13-91 11-28-91 10-27-91 75324 75323 751 22 RECEIVED JAN 1 3 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 6, 1991 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy~of this transmittal. '~~~-.//..-[~--~_.~M~21c").~~ LISTapeand Listing 11-11-91 75161 - 1 9 I LIS Tape and Listing 1 I - 1 7 - 9 1 7 5 2 0 6 U I 8 I ~ ~ LIS Tape and Listing .x/J ' 11 - 2- 91 751 29 Receipt Ack n o w I e d g e d: ......--'~-z~-'~--,,,z'-~- ~-"~----- D a t e· - ......... DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: November 22, 1991 Transmittal #: 8294 RETURN TO: ARCO Alaska, Inco ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 ql ,"22 M- 18 M 18 Transmitted here with are the following Cased Hole items. return one Signed copy of this transmitta .'t'~ Cement Bond Log '-'"'"'/ 1 1 - 1 2 - 9 1 Cement Evaluation Log k------"~ 1 1 - 1 2 - 9 1 Receipt Acknowledge' -~~ Date' Please acknowledge receipt and 5800-7814 5800-7814 Drilling State of Alaska(+sepia) NSK RECEIVED NOV 2 7 1991 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' November 15, 1991 Transmittal #: 8286 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO- 1'119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. h,.f2 M- 1 8 ~"~'~ 222M 18 ~ 2M 18~-'~' - M 18~-'''~ Litho Density-CNL-GR 2" & 5" Porosity Litho Density-CNL-GR 2"& 5" Raw Data Cyberlook DI-SFL-GR DI-SFL-GR Receipt Acknowledged' DiSTRiBUTION: 2" Phasor 5" Phasor 1 1 -2-91 3070-7881 1 1-2-91 3070-7881 11-2-91 11-2-91 Date' 3070-7881 3070-7914 3070-7914 D&M Drilling Vendor Package(Johnston) NSK State o~~,~.Sepia) ARCO Alaska, Inc. Date' November 15, 1991 Transmittal #: 8285 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATe-1 1 1 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-18~ Ultrasonic Imager 11-3-91 100-3065 (Cement & Corrosion) Acknowledg Date' ~/ State 'o ...... ' Receipt Drilling NSK "-" APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~X Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 404' FWL, Sec. 27, T11N, R8E, UM At top of productive interval 1300' FNL, 1340' FWL, Sec. 27, T11N, R8E, UM (proposed) At effective depth At total depth 1032' FNL, 1405' FWL, Sec. 27, T11N, RSE, UM (proposed) 12. Present well condition summary Total Depth: RKB 141' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-18 9. Permit number 91-19 10. APl number $o-1 03-201 51 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool measured 3075' feet Plugs (measured) true vertical 2792' feet Effective depth: measured 2993' feet Junk (measured) true vertical 273 9' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3026' 9 5/8" measured true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 225 sx AS II 124' 124' 380 Sx Perm. E 3070' 2795' (proposed) w/505 sx Class G RECEIVED N OV - 8 !991 AJaska 0ii & Gas Cons. Commissiot~ Anchorage 13. Attachments Description summary of proposal ~ Detailed operation program Reduce 9-5/8" lead cement volume from 505 sx to 380 sx Permafrost Type E. BOP sketch 14. Estimated date for commencing operation October 30, 1 16. If proposal was verbally approved Name of approver David Johnston Date approved 1 0/29/91 15. Status of well classification as: Oil X (DrODOSed) Gas_ .. Service Suspended 17. I hereby,certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~/, '~~~~__3~' Title: Area Drilling Engineer ! FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require IAppro_.val NoN .. ~1- Approved by the order of the. Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY Commissioner Date LONNIE: C. SMITH SUBMIT IN TRIPLICATE KUPARUK WELL 2M-18 9-5/8" LEAD CEMENT VOLUME REDUCTION The lead cement volume for Well 2M-18 was permitted for 505 sacks of cement which is 100% over the calculated hole volume from 500' above the West Sak interval to the surface. In an attempt to minimize 0p_e_r. atiQ.Da~l.~ro_~bJ~e_~., of handling excess cement returns at the surface, ARCO Alaska, Inc. requests approval to decrease the lead cement volume on Well 2M-18 to 50% over the calculated hole volume (380 sacks). If cement does not reach the surface, ARCO will perform a top cement job to ensure a cement plug from the surface to a depth of 100'. RECEIVED Alaska Oil & ~as Co~s. Commission Anchorage TO: MEMORANDUM of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C S DATE: November 5, 1991 Comm is s ioner FILE NO: LG115 - 6. DOC THRU: Blair Wondzell S.P.E. TELEPHONE NO: SUBJECT: Rig/BOPE Inspection Arco 2M-18 Permit No. 91-19 Kuparuk River Field FROM: Louis R GrimaldiJ~ Petr Inspector ~_u_~da¥~_NovembeF 3, 1991 I made a rig/BOPE inspection on Pool Rig #7 Drilling Well 2M-18 in the Kuparuk River Field for Arco Alaska. I found one noncompliance, this being the firewall that shields the master accumulator controls from the cellar had not been raised. Gary Goerlich, the pool toolpusher, had this taken care of before I left location. The rest of the rig and its BOPE was in good shape as was the surrounding location. In summary, Pool Rig #7 is a well maintained rig and appears to be in good shape for drilling 2M-18. Attachment 02-00lA (Rev. 6/89) 20/11LYIEMOl.PM3 OPERATION: Drlg.~ Operator ~ f~ Location: Sec ~ Drlg contr '~O~/._~- Location (gen'l) IN COMPLIANCE; ~es ~ n/a 1.() () (-) 2.() () () 3.() (} () 4.() () () $.() () () 6.() () () 7.() () () () () 9.~? () () 10. ( ) ( ) 11. ~ ( ) ( ) 12. ( ) ( ) 13. () ( ) 14. (X~;~ ( ) ( ) ~$. (~ () () 16. (;,~) ( ) ( ) 17. (,~ ( ) ( ) 18. (~ ( ) ( ) 19. (~) ( ) ( ) 20. C~2 () () 21. (~ ( ) ( ) 22. ~ ( ) ( ) 23. (~o) ( ) ( ) 24. (.~)) ( ) ( ) 25. () () 26. (~ ( ) ( ) 27. 0~) ( ) ( ) 28. ("~ ( ) ( ) 29. ~<) ( ) ( ) 3o.(~ () () 31. ~) () () 32. y' () () REMARKS: ~ --33 Compl~ T ///~-] Wkvr U Permit # ~/ R ~"E' M Rig# Well sign STATE OF ALASKA ALASKA 0 i L AND GAS CONSERVAT ! ON COMM I SS I ON Rig/BOPE Inspection Report DATE: //' Representative Well name Representat i ve A. DlVERTER line sz & length line conn& anchored bifurcated & dwn wi nd 90° targeted turns vlvs: auto & simultaneous annul ar pack-off condition B. BOP STACK wellhead flg ~g press stack wkg press annul ar preventer pi pe rams bl i nd rams stack anchored chke/kill line sz 90° turns targeted (chke & kill ln) HCR vlvs (chke & kill) manual vlvs (chke & kill) connections (flgd, whd, Clmpd) drl spool fl ow ni ppl e fl ow moni tot control lines fire protected C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs regulator bypass 4-way vlvs (actuators) blind handle cover driller control panel remote control panel i N COMPL I ANCE :, ~/es no n/a () (X') () () 35. ~<L~ ( ) ( ) 36. (,~) ( ) ( ) 37. (~ ( ) ( ) 38..(X) ( ) ( ) 39. (/) ( ) ( ) 40~) ( ) ( ) ~'~. ~) () () 42. ~;"~) ( ) ( ) ,+3. ~) ( ) ( ) () () 45. (>dj ( ) ( ) 46.(20 ( ) ( ) 47. ()~) ( ) ( ) 48. ~) ( ) ( ) 49. ~ ( ) ( ) so. () 51. ¢/~ () () $2.() () () 53.,V~) () () 54. ( ) ( ) ( ) 55. ~;~) () () 56. Q-z) () () 57.() () (,~ s8. (y,,l ( ) ( ) firewall nitrogen power source (back-up condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In conn trip tank E. RIG FLOOR kelly cocks (upper,lower, IBOP) floor vlvs (dart vlv, ball vlvl kelly & floor vlv wrenches driller's console (flow monitor flow rate indicator, pit leve indicators, gauges) kill sheet up-to-date gas ~etection monitors '(H S & methane) hydr chke panel chke manifold F. MISC EQUIPMENT flare/vent line 90 ° turns targeted (dwn strm choke Ins) reserve pit tankage personnel protective equip avai all drl site suprvs trained for procedures H2S probes rig housekeeping RECORDS: Date of last BOP inspection: Date of last BOP test: Resulting non-compliance: ~ C) /f~] ~ Non-compl i ances not corrected & why: -------' Date corrections will be completed: ~ BOP test & results properly entered on daily record? ALAS KA OIL AND GAS CONSERVATION COMI~I S S I ON TO: Lonnie C. Smith Commis s loner FROM: Louis R.Grimaldi Petroleum Inspector DATE: ~ j ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 29, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Applications for Permit to Drill KRU Field Well 2M Pad Addendum to Previously Approved Permits to Drill The attached correspondence is the Alaska Oil and Gas Commission's ruling which approves isolation of Colville Sands at 2M pad by down squeezing cement into the annular space between surface and production casing. This will occur after the pdmary cement job on the production casing is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. There have been four drilling permits which have already been approved prior to the ruling mentioned above. ARCO Alaska, Inc. requests that these four previously approved drilling permits also be included in the ruling. The four wells are: Well Permit NO. AP! No. Approval Date 2M-15 91-33 50-103-20154 03/05/91 2M-16 91-32 50-103-20153 03/05/91 2M-17 91-18 50-103-20150 02/22/91 2M-18 91-19 50-103-20151 02/22/91 If there are any questions, please contact Tim Billingsley at 265-6575. Thank you for your assistance in this matter. Sincerely, A.W. Area Drilling Engineer RECEIVED MAR 29 1991 ,Alaska 0il & Gas Cons, Anchorar~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3~6003-C ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOFY: (907) 276-7542 March 21, 1991 A Wayne McBride Area Drlg Engineer ARCO Alaska, Inc P O Box 100360 Anchorage AK 99510-0360 Re: Alternative cementing procedure for some Kuparuk River Field wells on Drill Site 2M. Dear Mr McBride: This is in reply to the meeting with the Commission on March 8, and your letter of request dated March 11, 1991. The Commission has reviewed the conditions expected to exist on Drill Site 2M, and approves isolation of Colville Sands by down squeezing cement into the annular space between surface, and production casing. This will occur after the primary cement job is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. If you have any questions, please feel free to call me. sincerely,/-~ Lonnie C Smith Commis s loner Lcs/3o RF.C IVED 4iaska Oil & Gas Cons. C0m~s$[~ll Anchora§~ ...... ALASKA OIL AND GAS CONSERVATION COMMISSION~ February 22, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 2M-18 ARCO Alaska, Inc. Permit No. 91-19 Sur. Loc. ll4'FSL, 404'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc.1032'FNL, 1405'FWL, Sec. 27, TllN, RSE, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. ~Sinzc~rely, ~ '~/~'~ ~. ~ ~;~h, ~ ommi s s i o n e r Alaska Oil and Gas Conservation Commission 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 20 AAC 25.005 la. Type of Work Drill X; Redrill ~ lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 141'. pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 404' FWL, Sec. 27, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1300' FNL, 1340' FWL, Sec. 27, T11N, R8E, UM 2M-18 #U630610 At total depth 9. Approximate spud date Amount 1032' FNL, 1405' FWL, Sec 27, T11N, R8E, UM 01-MAR-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2M-17 (~ P~.oPO~"~) 7907' MD 1032' @ TD feet 25' at surface feet 2560 6261' TVD feet 16. To be completed for deviated wells 17. Anticipaled pressure (see 20 AAC 25.035(e)(2)) kickoff depth 11 00' feet Maximum hole an~lle 44° Maximum sudace 1650 psig At total depth (TVD) 3360psicJ @ 6261' 18. casing program setting Depth size Specification Top Bottom Quantity of cement Hole Casin~ Weight Grade Coupling Lenc~th IVD TVD IVD TVD linclude stac~e data) 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' ±200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 301 8' 35' 35' 3053 2776' 980 Cu. Ft. AS III & HF-ERW 580 Cu.Ft. Class G 8.5 7" 26.0# J-55 BTC 7872' 35' 35' 7907' 6261' 200 Cu. Ft. Class G Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vedical depth Structural Conductor Cu. Ft. Sa,ace Cu. Ft. RECEIVED Intermediate Production Liner FEB - 8 1991 Perforation depth: measured Alaska 0il & Gas Cons. C0_m lssl true vertical - All;h rafl_ 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 requirements 21 I hereby certify that the foregoing is true and correct to the best of my knowledge Si~n Title Area Drilling Encjineer Date 2-7-- e// Commission Use Only Permit Number I APl numb I Approval date See cover letter for ?/__,/c~' 50-/~C~,~ - ~- (~ / ,,S'- / 0~__/99/_ql other recluirements Conditions ~f approval Samples required ~ es~ N o Mud Io~ req'uired ~ Yes ~ N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ,,~Yes ~ N o Other:Required working pressure for BOPE ~ 2~/: ~_ 3~.M ,(..~'~ 5 M' ~ I 0 M' ~ I 5 M /'~ ' ',4'~"~'-,~ ~, Commissioner the commission Date ~ - 7_ z_-~'! Approved b~/ ; ~_/ C~3.~-~_~r~;' by order of Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO ALASKA, Inc. Structure ' Pad 2M Well ' 18 Field · Kuparuk River Unit Location · North Slope, Alaska o 400 o 40O 12oo (- - -I--- 1600- ~ 2000- 0 2400- 0 - -I..- 2800- _ 3200- _ 3600- 4ooo- 4400 - _ 4800- 5200- 5600- 6000- 6400- Created by : jones FOR.' T BILLINGSLEY Date plotted : 6-Feb-91 Plot Reference is 18 version ~2. Coordinates are in feet reference slot ~18, True Vertical Depths are reference wellhead. I-~IIEASTMAN IZ/ZllUC H RISTENS E N N 13 DEG 57 MINE ,3978' (TO TARGET) RKB ELEVATION: 141' TARGET LOCATION: 1300' FNL, 1540' FWL SEC. 27, T11N, R8E TARGET Tv'0=5976 TMD=7511 DEP=3978 NORTH 3866 EAST 936 KOP TVD=llO0 TMD=1100 DEP=O 3.00 9.00 B/ PERMAFROST TVD=1391 TMD=1392 DEP=22 T/ UGNU SANDS TV0=1451 TMD=1453 DEP=53 - 15.00 21.00 BUILD .3 DEG/IO0 FT 27.00 T/ W SAK SANDS TVD=2016 TMD=2055 DEP=234. 33.00 39.00 FOG 1VD=2430 TMD=2571 DEP=539 B/ W SAK SANDS 'TVD=2576 TMD=2775 DEP=681 9 5/8" CASING PT AVERAOE ANOLE 44 DEG 7 MIN TARGET ~976 TMD=7511 DEP=3978 ~ T/ ZONE A 'fVD=5997 TMD=7540 DEP--3998 %~ B/ KUP SANDS TVD=6117 TMD=7707 DEP=4114 ~ TD / LOGGING PT TVD=6261 TMD=7907 DEP=4254- i i i i i i i i I i t i i i i i i i i i i i i i i 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 Scale1 ' 200.00 Vertical Section on 13.61 azimufh wifh reference 0.00 N, 0.00 E from slof j~18 ...... East --> 0 250 500 750 1000 1250 I I II II II II I -4250 TO LOCATION: I 1032' FNL, 1405' F'WL SEC. 27, T11N, RSE 4000 5750 3500 3250 _ -3000 _ -2750 - -2500 - -2000 Z - -1750 ~'~ _ -1500 _ -1250 _ -1000 750 500 250 , . o'1 o o o JSURFACE LOCATION: 114' FSL, 404' FWLI SEC. 27,...z ,T!IN, RSEJ R ¢EIV D FEB - 8 t991 .Oil .& Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM (2M-18) Spud to 9-5/8" Drill out to surface casing weight UD Density 8.6-10.0 8.6-9.6 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4- 8 APl Filtrate 10-12 8-10 pH 9- 1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 10.3 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED FEB - 8 t99~ Alask~a Oil .& Gas Cons..Commission ~chorage Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1650 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2M-18 will be 2M-17 (proposed). As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2M PAD 10 11 12 13 14 15 16 17 18 19 Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. ,.dPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 HCR \ 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 , 6 5 4 I3 (21 13 5/8" 5000 F,-,I BOP STACK ACCUMUI,,.ATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MIN UTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'FI'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"-2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 ~$ $,$4e;91~. $3 41~, ~Rg. ~ ?0° I~'10.~?'?' ~ ~,9~0,$0~.$5 4~P, 7P~.58 PO~/~' /~.~?7" · ~,948,98~.9 ~ 4~7,804.5~ ~0~/~'/O.~r8" 4 ~,9~8,9~.9 I 4~P, 8~9.44 NO, Y X ~ ~,940~ 905.9~ ~O~, 0~4. 41 ?0~I~' 10.~9" I0 ~,940,905.~4 48r ,g Pg. 31 tl 5;940, Qa~. 95 400, 00~.~9 70°/E'IO,~MI " 1~ 5, 9~ 905.8~ 488, Ogg. 4S 13 ~,940,905.74 408, 119.27 14 5, 940, $0~.9R 480; 1d~.43 ?O°l~' /0.~3 /~ ~,948,~8~98 4~8,/69.02 1~ ~,948; 9~94 488, 194.04 ~0~1~' /~ ~,94~, g$&06 4~, ~/9./~ ~0~/~' /M.~gS" /~ ~,~4~,~~ 4~, 244.~/ ~0~/~'/~.~' .~0 5,948, S~$4 408, esq.03 ~1 S, gqO,$O~.O0 4~0, ,F/RIO ~ ~,94~ ~~ 40~, ~44.~0 ~0°t~' /~.~0~, ~ 5,9~0, $0575 400,394~$ PO°l~' /0.$0s'' ~ ~,94~, 9~ 488, 419.~$ F. ~. &. ~. £.L. 00. PaD ~? " I 1 d ' t I I ; 101.0' 104.9 ~6 ' / 14 ' ~G ' I01.0' 104.9 809" / /d ' 6/ ' I01.0' 104.9 /~OeO~'5~.08M " / / 4 ' 36' I01.0' /~0~ 0~' ~435~ " //4' //' ~01.0' ~05.0 630" //4' /4' 1~.9' I0~. /78" I/4 ' 64' 100.8' I0~.~ /5OeO~'~/.~O'' //~' ~' 10~8' 105.4 /~OeO~'EO. rSO" //~' //4 ' IOOJ' 105.~ /5~e0~'4~.~4'' //4 ' /~' 100.6' / ~Oe O~'~9.~4 " //4 ' /~4' I00.~' 105.5 0~'4~5~4 " //4 ' /~' 1~.5' I0~.~ t~8" //4' ~04 ' ~.~' ~05.6 /~000~'44.470" 114' ;~' 100.~' 105,~ X~Z " I1~ ' ~5~' I~.1' ~05. 1~000~'4~.E7~" ti4 ' 404' 99.9' 105.7 8~4" //4 ' 4~9' 9$.S' /50°09"40.0~" t/4' 4P$' 99.7' /05.5 1~0~0~'3~.6~0" i/4' ~' 99.6' i04.9 t~0°0~'~911 ' //4' 55~' 99.5' 104.9 l~ " /1 4 ' ~79' 99.4' I~.9 SURVEYOR~ CERTIFTCATE I HEREBY CERTIFY THAT I AM PROPERLY A ND THAT THIS PL4T REPRESENT$ A SURVEY ',". ;: ' ';' ~' ~ '"' "' ' ' ~ ' 'MADE BY ME OR UNDER MY DIRECT SURERWSlON~ ~/~;:~...',~"., .'~$3~. ,.,. ~..~ · ~'.~ ..,~, . · 'AND THAT ALL O~ENSION$ AND OTHffR ' ' ~,--/:,,,,;- ,.- "'~'~' ,'," i i i ii i ARCO ALASKA, INC. DWG ~ NSDK. Z MOO'CEA'D2MX. 6~ I $ O 7 i llll ii i i IIIli ii I Ill Ill I I I i ITEM APPROVE DATE YES NO ~/_.. Z./"~/~.~./ ~ 1. Is the permit fee attached - ......................................... Mi --- . (2) Loc --- (2' thru 8)' - (8) <3> Admi, 9. (9 thru L3)- 10. (10 and 13) 12. 13. (14 thru 22) (23 thru 28) ~S 2. Is well tff 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 undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ~ ...... 7. Is operator the only affected party ................................. ~ .., , 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order neede ...................................... . Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 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 and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... /~.. Is the drilling fluid program schematic and list of equipment adequate/~. Are necessary diagrams and descriptions of diverter and BOPE attached./~ . Does BOPE have sufficient pressure rating - Test to $~OO psig .. //~ · , Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ,.~ (6) OTHER /f~ .7// '(29 thru" Engineering: ..... rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNI'T ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not Particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. CO~PAN¥~NAN~ 1991 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-DECo1991 09:18 **** REE5 HEADER SERVICE NAME : EDIT DATE : 91/12/ 5 ORIGIN : FSIC REEL NAME : 75129 CONTINUATION # : PREVXOU$ REEL COMMENT m ARCO ALASKA, ZNC,,KUPARUK,2M - 1~,50-103-20{51-00 **** TAPE HEADER **** SERVICE NARE : EDIT DATE ~ 91/12/ 5 O~IGIN : FLIC TAP~ NAME : 75129 CPNTINUATION # : 1 PREVIOUS TAPE COMMENT ~ ARCO PAGE: **** F'ISE HEADER **** FIbE NAME : EDIT .001 $~RVICE : FLIC VERSION : 001A07 DATE : 91/12/ 5 ~X REC $IZ£ : 1024 FILE TYPE : LO ~AST FILE : ******************************************************************************* ** SCHLUMBERGER ** ************************************************************************************ cOMpANY NAME: ARCO ALASKA, INC,. FZEbD: . KUPARUK BOROUGH: NORTH S~OPE STATE! A~ASKA API NU~ER: 50'103-20151-00 ~OCATION~ 114" F$~ & 404' F~ SECTION: 27 TOWNSHIP~ lIN RANGE: 8E PERMANENT DATU~ ~EAN SEA ~E~EVATION~ 0 ~OG ~EASURED FRO~ RKB 150 ABOVE PER~ANENT' DATU~ Tape Yeri~icatton 6ist[n~ ~chlUmberqer laska Computinq Center 5-DEC-X991 09=18 PAGE: ELEVATIONS KB: 150 DF: DATE LOGGED= 02-NOV-1991 RUN NUMBER= TD DRILLER= 7926 TD LOGGERI 7925 CASING 1= BIT SIZE 1= 8,5 FTLTRATE RESIS?IVITY~ 2,~ ~ 60 MUD CAKE RESISTIVXTYI 1.e5 ~ 62 TY~E CIRCULATION ENDED: 16~00 2-NOV-91 MAXIMUM TEMP RECORDED: 140 LOGGING DIS?RXCT~ LOGGING £NGXNEER= WYTNESS~ TOOL NUMBERS= ECH-KC 2320 SGC'SA 60 DRS"C 49 ECH-~KA 781 GSR.d 692~ 106 9.625 6B ~ DRILLER DEPTH OF 3070 AND LOGGER DEPTH OF 3070 VxscOsIT FLUID LOSS[ 4,4 PRUDHOE BAY ~,:WARNER/fl, HA.~IOND . CHIVV.IS?K, 6ENZ CNC-HA398 NSR-F 2290 N¢$-E 775 PDM-b ]?b5 AXS-BA 6 AIC-BA 3 AiH-,AA 6 DIS-HB 379 DIO-EB 377 F!EbD RENARK$= THE TOob STRING (SOT'TOPIvI$'~~I"DITE'AI:T'LDT'CNL'GR'TCC'AM$' NEUTRON DENSITY ~ATRIX ,LE ON IPE. BUT NOT PRESENTABLE.~ NEUTRON' RATIO (TNRA) AVA!LAB REPEAT SECTION RUN ON HR . RBPROCES$I. NG TOS 6 INCH NOT POSSIBLE WITH CURRENT D~_TE oOB STARTED, 4-DEC"9! jOB REFERENCE NOI 75129 6DP/ANA= S, DEBS Schlumberger Alasl~a ComputLng Center 5-DEC-199! 09=18 FILE ' ED!T,O01 ARCO AbASKA, INC,. KUPARUK 0-103-20151-00 MAIN PASS bOG DATA 15 FROM FIELD FILE O~B CASING LOG DATA IS FROM FIELD FILE DATA SAMPLED EVERY -,5000 FEET DATA INCLUDED - TOOT., EXTENSION TOOL TYPE USED NAME DIT'E ,DTE bDT ,LDT CNT-A/D/H ,CNb GR ,CSG PHASOR DUAL INDUCTION LITHO DENSITY COMPENSATED NEUTRON GAMMA RAY TABLE TYPE.' CONS TUNI VALU DEFI ...... ,. CN ~R~O ALASKA, 'INC.' N KUPARUK WN SECT TOWN RANG COUN STAT NA?I bAT! ~ONG WITN SON PDAT APD EDF TDD TD~ FT FT FT FT FT FT M - 8 ~0,~0~i'20151-00 14" FSL & 404'~ FWL ALASKA USA B i VVI$/K. bENZ MEAN SEA LEVEL 999.25 7925, Com.~any.Name Field Name Wel::Name AP~ Serial..Number r~eld, bocation Section.. Township anqe oenty Sta:e~or Province Nation_ bat~tu~e Lono~tude w~t6ess Name Service Order Permanent data Elevation or: ~rmanent Datum bog Measured.:From Above':Perma~ent,Oat~m . . Elevat(on ot Kelly Elevat~on ot oerr~c~ ~Xc~ Elevation ot ground Level TOtal OePth~- Or~er ?ota~ DePt~:- Logger Tape Verlftcatlon blsC~nq 3chlum~erger Alaska Computing Center TUNI VALU DEr! FT 3070: BbI DFT biND DFD G/C3 10,4 DFPH 10,1 DrY CP 38 Orb r3 4,~oooo! RNS OHMM 2.51 MST DEGF 63 RMF$ OHMM 2'§5 MFST DEGF 60 RMCS OHMM Mcs? OEGF 16, 62'00 2-Nov-gl STEM DEGF 55 BHT. DEGF 14~,. Bottom Log Interval Top bog Interval~ Orilllno Fluid TYpe~. Drilling Fluid Density Drilling Fluid Pb. Drilling Fluid Viscosity ~rltling~F!uid Loss. ' Resistivity Resistivity o~-Mud. Filt~te Mud*.rL~trate SamPle. TemPe~atu Resistivity o~ MMd'C&Ke,Sa~pl Mud CeKe.-.SamPie Temperature Time Clrcul&tLo~ Stoppee ~urtace Temperature. ... uottom Hole Temperature.... DgPT ¢IDP C~MP ClbO ClLM iMor I'!RD I{XD ilX~ GR T~N$ MTEM M~E8 HTEN DPH! RHOB DRHO PEr bU ~e N Y N~UCTION DEEP PHA$OR CO DUCTIV~T INDUCTION DEEP PHASOR:.RESIiTIVITY INDUCTION MEDIUM pHASOR CONDUCTIVITY INDUCTION, MEDIUM PHASOR RESISTIVITY Conductlvl:¥ IL Deep $:andard, Processed Deep Induction 8~anOard Pro~essed Reslst~vity Cop4uctivity !~ ~edlum Staneard processed Medlum..Inductlon Standard Processed Resistivity Induction Deep Oualitv Factor Induction Medium Ouality Factor _ .. Deep Znduc~$on ~eai In~ermed$a~? ~onduc~$v$ty Deep induction uUad Incermedlm~e Medium Induction Real Intermediate ~on~uc~lvlty ~ed!um Induction Ouad Intermedlate Conductivity 8FL Resistivity Unaveraged ipontaneous~Potentlal Gamma Ray Tension MUd Temper t re estst v tv Head Tension DenSitY Poros~ 8ul~ Dens~¥ Delia RHO ~hotoElectr~c Factor Oua~ity control of long spaciDg for LDT Oua!ity control on short spacing for bDT Long Sbacing Computed count Rate (bb+bU/2) Long Upper 1 2' ~indow Count Rate (LUI+bUi) ?ape Verification Listing ChlUmberger las~a Computing Center 5,,,DEC-199! 09~t8 DEFI LL LSRN LURH GR ?ENS MTEM HT£N NPH! TNPH TNRA RCN? RCFT CNTC CFTC GR CALl TENS MRES MTEM HTEN TENS HTEM bong bower.Window Count Rate bttholog Window Count Rate Short Spacing ! Window Count Rate Short Spacing 2 Window Count Rate Lon~ Spacing High Voltage Short Spacing Hiqh Voltage Short SPacln~ ! Density bong Spacing Bulk De~slty Long.Upper BulR Density Caliper Gamma Ray Tension Nud Temperature HUD ReSistivitY Head Tension ~ Neutron Porosity Raw Thermal Neutron Ratio Thermal Neutron Porosity 'ed Thermal Neutron Ratio Cal~bratcatii Program Neutron Porosity from an Appl on RAW NEAR CNT COUNTS RAW FAR CNT COUNTS Corrected Near Thermal. Counts Corrected Far Thermal Counts' Gamma Ray Caliper Tension MUD Reslstiv~ty Mud Temp Eature Head. Ten~lon Gamm9 Ray Tenslon,~. HUD Resistiv~ty Hud Temperature Head Tension. DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB **' ,- TYPE REPR.CODE ~VALUE I 66 0 2 66 0 3 73 260 4 66 l 5 66 6 7~ 7 65 Tape Verl~Ication ~st$ Sc~lumberqer Alas~<a ¢omputinn~ Center 5-DgC-199! 09118 TYPE REPR CODE VAbUE 9 65 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 NAME SF, RV UNIT SERVICE API APl AP1 APl FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER ~,, bOG TYP~ CbASS MOD NUMB ~AMP ,EbEM CODE (HZX) ,. .z.~ r~ ~.~. oo ooo oo o ClOP DTE MMHO 548238 O0 000 O0 0 ! t ~ 4 68 IDF" DTE OHMM 548238 O0 000 O0 0 c~o ~s M..O S~S23S O0 000 O00 ~o ~ o... s~s2~ oo ooo ooo c~..~ ...o s~o2~o oo ooo ooo bM ~ 1 DO~ DTE OHMM 548238 O0 000 DTE 548238 O0 000 O0 0 ! 1 ! 4 68 IMQF DTE 548238 O0 000 O0 0 I ! 1 4 68 IIRD DTE MMHO 5482~8 O0 000 O0 0 ! 1 1 4 68 MMHO 548238 O0 000 O0 0 I 1 1 4 6 ilXD DTE 68 ~x. D~ ...o 5,.., oo ooooo o S~bODTE OHMM 5~ 8 O0 000O0 0 .ooooo ooo 68 ~ ~ ~ oo ooo oo o ~.~ ~ ~ ~,, ~ oo ooo oo o · MTEM DTE DZGF 54 8 O0 000 O0 0 I I ! 4 M~E8 DTE OHMM $ ~.38 O0 000 O0 0 1 ! I 4 68 HTEN OTB bB 5 138 O0 000 O0 0 [ 1 I 4 68 5 O0 000 O0 0 I ! ~ 4 8 DPH! bDT PU ,2~8 oo ooo oo o DRHO bDT G/C3 548238 O0 000 O0 0 .!! I! 1 46 68 p~r ~ ~~ oo ooo oo o o~ ~ ~2~. oo ooo oo o OSS bDT 548238 O0 000 O0 0 !1 I 4 68 LU LDT CPS 548238 O0 bb bDT CPS LITH bDT CPS 548238 O0 00' 0 ! ! 4 68 $$~ bDT CPS 548238 O0 000 O0 0 I I $8~ LOT CPS 548238 O0 000 O0 0 ! ! ! 4 68 LSHV LDT v 548238 O0 000 O0 0 ! 1 I 4 68 SSHV LD? ¥ 548238 O0 000 O0 0 ! ! I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000. 0000000000 0000000000 O00000OO00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O0 0000000 0000000 ooooooo 0000000000 0000000000 0000000000 00000000.00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tape Yerl~lcattaon btstin,q chlumoercjer Alas~ Comput:[nq Center 5-D£C-199! 09=18 NAME SERV UNIT SERVICE AP1 AP! APl API FILE NUMB NUMB SIZE REPR PROCESS ID- ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM -.CODE (HEX) SIR" bDT G/C3 548238 00 000 00 0 t ! ! 4 ~ 0000000000 ~SR. ~DT ~/C3 548238 00 000 00 0 ~ ~ ! 4 -~ 0000000000 bUR. bDT ¢/C3 548238 OD ooo OD o I ! 1 4 68 ooooooooo0 ~! bDT IN 5482~8 O0 000 O0 0 ~ ~ ! 4 68 0000000000 OR ~DT GAPI 540238 O0 000 O0 0 t ~ ! 4 68 0000000000 TEN8 bDT bS 548238 O0 000 O0 0 ! ! ~ 4 68 0~00000000 MTEM bDT DEGr 548238 O0 000 O0 0 1 1 1 4 68 0.00000000 MRES bDT OHMM $482~8 00 000 00 0 ~ 1 ! 4 ~ 0000000000 HTEN bDT ~B 5482~8 00 000 00 0 ! ~ ~ 4 -. 0000000000 NPHI CNb PU 548238 00 000 00 0 I ! [ 4 68 0000000000 RTNR CNb 548238 00 000 00 0 t [ ! 4 68 0000000000 TNPH CNb PU 548238 O0 000 O0 0 ! ~ ! 4 68 0000000090 ,.., ~.~ ~4.2~. OD ooo OD o , ~ ~ , ,. oooooooooo .~o~ ~.~, ~,.2~e ODooo OD o ~ , , , O0000OO000 ~ c~ ~ ..:~.OD oooOD o ~ ~ ~ ~ .. oooooooooo Rcr? cN~ cP~5~e~]e OD oooOD o 1 i ~ ~ ~e oooooooooo CN~ CPS548238 O0 000O0 0 [ I ! 4 68 0000000000 CN?C CFTC C.~ CPS S4e23S O0 000 O0 0 ~ ~ ~ 4 ~S O000000C~O0 ~ ~ ooooooo o ~ ~ ~.~ooooo ooo~ ~ ~ . oo 000000~ 0 b! CNb IN 548238 00 000 00 0 4 68 00 ~.E~C~h o.~ ~48~a8 O0 o00 O0 0 ~! ! .4 $8 0000000000 ~ C~ D~ 5482~8 O0 000 O0 0 HTE. CNb bB 545288 OD 000 oo 0 1 1 [ 4 68 0000000000 Ge cst GAP!548238 00 000 00 0 I 1 1 4 68 0000000000 T~NS CSG kB 54e23$ 00 000 00 0 i I ~ 4 68 9~90000000 ..~ c~ oH..~482~ OD ooo oD o ~ ~ ~ 4 6e ~ oooooooo H?EN C80 LB 548238 00 000.. 00 0. 1 ! I ..4 68 0000 OOOO90 DEPT, 796i .-b:.OT£ 3 SP.,DTE MRE$;DTE DRHO'LDT 0 bS.eLDT 322 SSI'LDT 224 $1RH'LDT OR.bDT HT:EN;LDT 'T~RA,CNL 3 C~TC,CNb 2~69 TENS*C~L 2660 GR,CSG -999 HTEN.CSG -999 ~o :33~ 86 000 ::105 077 266 555 142 440 428 637 ,000 250 250 C~LD DTE IDQF DTE IIRM,D?E GR,D!E HTEN PEr. bDT bU~bDT bSRH'LDT TENS, bDT NPH'I,CNL NPOR~CNb Cr?C,CNE T~N$~CSG .837 0.000 2~0'460 [2,0,142 I191.4~0 DPHI 4,05 ObS 3!2.003 Lb 2~2:.~., ~u.,, 0,000 MTEM. 0,828 RTNR:: 40"396 R~N? 64[,:7 OR: 'IbD.,DTE 3~,302 CILM,D~E 3.0,143 I.XXM,DTE 23.642:8F UTE. L~'D~L bDT ~5;,.538 RHOB/bDT 1:'~4 ,bDT ~66~265 LXTH,LDT :bDT 1t61~:302 $SHV,.LDT [2[4'757 9,' LOT 2.316 CAbl,bO~ 1.2~2105 bDT [40.~637 MRES,LDT CNL 3:,600 TNPH,CNL 40'396 CNL 2223,540 RCFT,:CNb 609.;607 CNL [20,142 CALX,CN~ '99;2!20 ~Zs TuaOe veri~icat~on L~st~nq Scl~ mberger la~ka Compu~InO Cente~ PAGEI DEPT. I~PH.DTE ILP,DTE IIXD,DTE SP'DT£ MRES,DTE DRHO.LDT b$.LDT $$1~LDT 81RH bDT HTE~ LO? TNRA GR CSG HTEN DEPT l~Pg DTE 1L~ DTE ZZXD SP~DTE NRESDTE GA'bDT HTEN,LDT T~RA.CNb CNT¢'.C~b TENS.CNb GR'CSG HTEN.CSG DEPT IbM,DTE IIXD,DTE MRE$,DTE DmHO.LDT $SI.,LDT $1RH.bDT GR bDT HTEN bDT TNRA CNb CNTC CNb TENS 7900 000 4 072 4 059 34 702 -17 500 1 ~05 0 077 322 266 224 555 12~ 3 212 .24 2 6;`428 O0 -999~250 7800~,,000 ~i 662 694 50:9!3 -20~125 1:140 0,,011 254.732 198 542 2~I3 101t706 21'29,437 '9 3*524 !43,704 ~325~000 ,999,250 999;250 lO00 770~,83~ -~000 !*148 0~039 300 21~;489 105.22 i 204'7,958 19 9 ~ 5065,000 .,999*250 ,,,999,2.50 CIDP DTE CIbD DTE IDOF DTE IlRM DTE GRDTE HTEN DTE PEF bDT bU bDT $82 bDT LSRH LDT TENSLDT NPHX,CNb NPOR.CNb CFTC,CNL MRES,CNL TENS.CSG CXDP'DTE CILD,DTE IDGF,DTE IlRM,DTE GR,DTE HTEN,DTE PEF,bDT bU*LDT S82,bDT bSRH.LDT TENS'bDT NPHI;CNb NPOR,CNb CFTC~CNL MRES, CNL TEN$,CSG CiDP DTE CXLD DTE IDQF .DTE IIR~ DTE GRDTE HTEN DTE PEF bDT LULDT SS2LDT bSRH bDT T~N$'LOT ~POR,CNb CFTC.CNb MRE$,CNb 254 ~08 256 46 0 ~00 230 2t29 4 3 ~00 i0396 641 ,237 99~ :105 .~50 379,690 382,970 0.000 345.093 101'7P6 53~5,0_0 549,019 1,140 -999,250 204'7 648 ,,9919 IDPH.DTE ILD DTE IMOF DTE IIXM DTE TEN$.DTE DPHI:bDT Ob8 bDT Lb. bDT bSHV bDT bURH bDT RTNR MTEM,CNL MRES,CSG ILD,DTE XMGF.'DTE IX.XM,DTE TENS*DTE DPHX,LDT LSHV*bDT RCNT,CNb GR*CNb MTEM, 'NL · IbD,.DTE 'IMQF,DTE :iIXM,.DTE TENS*.DTE DPHI:~bDT GbS~bDT LL:ibDT bSHVLDT LURHbDT MTEM bDT RTNR CNb RCNTGR ~NL MT£M CNb MRE$ 3.929 3,906 CXLN,DTE 0.000 XXRD.DTE 19.162 SFLU.DTE 5310.000 MTE#,DTE 15.538 RHOB*LDT -O,P47 OSS*LDT 166.265 LITH.LDT 1161.302 ~SHV.bDT 2.31~ CAb! bDT 140-637 NRE$ bDT °600 222~.540 RCFTTNPH CNLNb 120,142 CALX i40,637 HTEN C$~ -999,250 ~TE~ CH 634 3 }0 XLMDTE IRD DT SFLU:DT[ MTEM.DT'E RHOB.LDT O$S*bDT LXTH,LDT GSHV*LDT CALl,bDT MRES~LDT TNPHeCNL RCFT.CNL CA. LZeCNL HTEN;CNL MTEM;CSG 4,42! 4,45 0.00 5065,~00~ 15,17 -0,02 !5.5,96~ o I:I .,4o. III 999.250 CILM.DTE XZRD'DTE :$FLU,DTE M~EM.DTE RHOB*LDT O$$.LDT LZ~H-LDT SSHV,LDT CALl*LOT ~RE$*LDT TNPH.CNL RCFT,CNb CALI..CNL HTEN.CN~ ~MTEM.CSG 245'588 246,' 85 219.t47 14~, 609~607 2129~t50 :-999, 375*690 371,330. 31~'i69 ,471 5~ '018 .807 1215~199 9.,3. t5 42~843 508.,~t7 99~250 ~¢0; 0~o :"999,250 bls Tape Verification List[n~q 5Chlumuerger RlasRa ¢omputin~ Center 5-D£C-199! 09:1~ DEPT IMPHiDTE Ib~ DTE IIXD DT£ 8P DTE MRESDTE DRHOLDT LS. LDT $$~ LDT StRH LOT GR bDT HTEN bDT CNTC TEN8 D£PT,' ILN.DTE IIXD'DTE SP,DTE M~ES,DTE S$!,LDT G &LDT HTEN.LDT NRA~CNb ~TC~C~b T£NS.~CN'L GR,CSG HTENeCSG X~PH..DTE ILM DTE iIXD DT£ 8P DTE MRES DTE ~S bDT SSi hD? G~ bDT HTEM bDT TNRA CNb T~N$ tnb GR CSG HTE~ CSG 7600.000 13,636 1~,928 ,702 -38.975 1;150 0,011 ~0~12 204~156 2,317 86* 7 2085.~3~ 4875,000 9998~50 60~~ 07 5 ,~84 081 26,$70 4930,000 '999,250 '999,250 7400.000 1,526 506 01 22 666 t:181 0 .007 306 ~10 202 641 20~0,576 3.,866 742.935 670.000 999,250 999'250 CIDP'DTE CILD.DTE IDQF,DTE IIRM.DTE GR.DTE HTEN.DTE PEr,bDT LU.LDT SS2;bDT bSRH*bDT TENS,bDT NPHI.CNb NPOR,CNb Cr?C,CNb NRE$,CNL TENSeCSG CIDP.DTE CIbD,DTE IDGF'DT HTI~:DTEDTE PEr;bDT bU*bDT bSRH.LDT TENS, bDT NPHI,CNb NPOR,~CNb CrTC~CNb .MR£S~CNb ?ENS, CSG CIDP DTE CIbO DTE IDOr DTE IR~ DTE GR DTE HTEN DTE PEr.bDT bU~.bDT SS'!.bDT bSR~'bDT NPHI.CNb NPOR.CNb CrTC,,CNL HRES,,CNL TEN$CSG 70 74 0 7~ 208~ 2t 94 9~9 O74 O25 000 ~0 ~0 I DPH DTE ILO DTE IMQr DTE IlXM DTE TENS DTE DPHI bDT LSHV ,bDT MbURH .bDT TEM, I, DT RTNR, ',Nb RCNT ',Nb , b MTEM~ 0 000 8, 018 4875 000 1~ 737 6O 29 845 25 ~90 86;2?8 .250 CXMP,DTE CXbM,DTE IXRD,DTE SFLUeDTE MTEM, DTE RHOE :bDT QS,~ LOT LIT~ ,LOT SSHI ,bDT CAb] .bDT MRE~ DT RCF~ ,tNb HTEt MTEM, 77.354 64.605 10,638 141,425 2.'374 O*02t 92~862 1215,521 9.005 31'~50 0,. 90 893,970 9.005 2085;538 '999,250 5,046 IDPH,DTE 4.8i5 ,o.ooo . 7~604 I'IXM~DTE 48.972 DTE DPHI, bDT.,I;'0 R~NR~CNb GR,CNL 48 ~,~66 MTEN~CNb 999.250 HRE$,CSG '999~ 465 CIMP,DTE 16 609 298 CIbM,DTE 18:490 000 XIRD,DTE 23,631 :398 SFbU.DTE 153,230 -000 MTEM'DTE 1.41,358 ~ · 0 :~5 RNOB'bDT 2,5!4 i~264 b{Tg LOT 41,417 ~4~505 SSHV LOT 1216.456 683i 4670 48 46, 459 000 !M F*DTE 0,000 746 ZIXMaDTE 49.~99 670 TENS* DTE 46 T 0,000 eLS* bDT '0,016 Lb, bDT ! 60,855 I LURH*LDT ,649 R~NR~CNb 3,836 693 RCNT.CNL 1794,.133 ~ GR"* CNb 90'670 MTEMeCNL: .139,975 ,25u 999'250 ~RES. CSG CXLM DTE ! 'bDT bDT bDT *CNL CRbI;CNL HTEN*CNL 665,~40 517,~14 t59 ,)35 84~. }.04 12!6,~05 9.'350 2._9,350. ~.-999,250 bls Ta · Verification Listing Schlumberger Alaska computing Center 5-DEC-1991 09:18 10 DEPT. INPH.DTE IbM,DTE IIXD,DTE ~RSP,DIE .. ES,DIE D~HO ~S bDT SS! bDT S1RH LDT HTEN bDT ?NRA CNb CNTCCNb TEN8 CNL GR CSG HTEN CSG DEPT~ IMpH~DTE IbN, DTZ IIXD,DTE SP DTE MAES DTE DRHO bDT bS bDT ~bDT CNTC CN · GRCSG HTE, N CS, G I,.PH DTE IbM DTE ]IXD DTE 8P DTE MAES DTE DRHO bDT 25 bDT 85t bDT $1RHLDT GR bDT HTEN bDT TNR6 tnb CNT~ TENS CNL GR CSG HTEN CSG 7300 000 3 218 3 216 41 764 -29,938 1: e5 0 29 294,074 208 783 14~ ~92~7 204] 095 878 1936 ~75 4655000 -g99 250 -999 250 7200 000 I 985 2 O55 - 625 I 336 0,002 ,064 30~ .386 '726 2000,~65 t991*i:49 ~000 '999,250 7100,000 ,642 '~ 813 t 310 0 005 263.~394 196,285 2 420 171 334 2008 983 3, 505 2006 186 4465000 -999250 -999 250 CIDP.DTE CIbD.DTE IDQF.DTE IIRM,DTE GR,DTE HTEN,DTE PEF~bDT LU,LDT $S2,LDT LSRH,bDT TEN&,bDT NPHI'CNb NPOR,CNb CrTC,CNb MRE$,CNb TEN$,CSG CIDP,DTE CIbD,DTE IDGF'DTE IIRMtDTE GR,DTE HTEN,DTE PEF~bDT LU~bDT T£N&,bDT ~PHi'CNb NPOR~CNb MRE$*CNb TEN$"CSG ClDP~DTE CIbD,DTE iDQF'DTE IIRM;DTE GR~D?E HTEN~DTE PEF,ibDT LU,~bDT $.$2i,bPT LSRH~,~bDT TENS~,LDT NPHX,CNb NPOR~CNb MRE&-CNb TEN$,CSG 929 0,000 290,224 !49,2~7 2043,095 3,385 282,279 277,724 2,375 4655.000 48.759 44.0!6 5400487 . 1,185 999,250 514 277 532 58 44~ 028 309 726 265,2 6 8 4 45 389 45:169 596 87.4 60{ 0 000 2O ¢83 3 5O7 ~06 '766 4 0492 572,189 .99~ .310 '250 IDPH, DTE ILD, DTE IMQF DTE IlXM DTE TEN$DTE DPHX bDT OLSLDT Lb bDT LSHV,bDT bURH bDT MTEN.bDT RTNRCNb RCNT,CNb MTEM MRE8 CSG IDPH~DTE XLD, DTE lMor, o~g IIXM DTE TENS~DT£ DPHX~bDT OLSbDT Lb, bDT LSHVtbDT ~uRH.,bDT RTNR," RCNT, Nb GR~Nb MRESe IDPH, DTE ILDDTE IMQFDTE XIXM DTE TENS DTE DPHX bDT Ob$ bDT Lb LOT b&HV bDT bURHbDT M'TEM bDT RTNrR CNL MTEM CNL MRES 3 145 CIMP DTE 3oio0 CXbM DTE O. XIRD DTE 364 &FLU DTE 745 750 20 4655 000 MTEN DTE 14 906 RHOB bDT i04 ° ! 152 9 4 blTH bDT 4 9 SSHV 1216,447 138 523 MRES i"" - -999,2~ 1,94~ CINP.DTE 1.87 CIbM,DTE o.°oi .34,68 $ 4565'.00 15,54~ RHOB,LDT 0,03 QS$.LDT 153.,43~ bITH, bDT t162,00 SSHV~LDT 2'42! C.ALX~LDT 138r'00 MRES~LDT i RCFT'CNb 309'~2 CAbZ~CNL '138';00 NTEN~CN' -999'25 MTEM,C~ 503,676 486-609 73;950 1216;07! 9~222 ~,336 ~9,733 5 8o:125 ~000.065 ! 370' 1162; 3 29 -999 0oo - {~6 RHOB· [27 SSHV LDT t55 CAbX bDT )52 MRES bDT ~! TNPH ~NL ~ RCFT Nb CALI Nb MTEM CSG 239~ 0 5 bl~ Tape Verification bistlng Sc r pu Cent r lumberge Alaska Co~ ting · 5-DEC-1991 09118 PAGE! 11 DEPT. IMpH.DTE IbM,DTE IIXD,DTE SP.DTE MRESeDTE DRHO,bDT LS.bDT SS~:LDT SiRH bDT GR, bDT HTgN bDT TNRA CNb CNTC CNb ?EN$ CNb G~ CSG H~EN DEPT IbN DTE IIXD:DTE SP DTE MRESDTE DRHD bDT b$ bDT SS1 SIRHbDT GR bDT HTEN-DT TNRA CNTC CNL TEN8 GR,CSG HTEN'CSG DEPT, ~b~.DTE IIXD~DTE MRES DTZ DRHO bDT L$ bDT SS1 bDT SJR~ bDT HT~ bDT bDT TNRA CNL C~TC TENS CNb G~ HTEN CSG 7000 000 439 4 1~0 24 547 -39 000 .99/9 267 250 -999 250 -99 '9999 250 .250 -999 .250 -999.250 -999, 250 -999. 250 -999~ 250 -999~ 250 -999 250 6900.000 36~.57 -39~,000 ,305 -999;250 '999,250 '999'250 '999.250 '999'250 i9991250 ~999,~50 .999'250 6800,000 5',056 5,:033 .22':t76 45'563 . I:~459 999,250 -999,250 -999~250 -999~250 -999.250 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 CIDP.DTE CIbDDTE IDQF DTE IIRMDTE GRDTE HTEN,DTE PErbDT bU bDT 8S2~bDT LSRH bDT TENS,bDT NPHI CNb NPOR CNb CFTC CNb TENS, CIDPDTE CIbD.:DTE !DQF, DTE IIRM. DTE GR DTE HTEN~DTE PEr :bDT bU.,:bOT $$2,bDT bSRH~.bDT TENS~:bDT NPHI~CNb NPOR~CNb CrTC,CNb TENS~CSG CIDP'DTE CI. bD,DTE IDQF,DTE IiR~':DTE GR,DTE HTEN~DTE PEFi,bDT bU, bPT SS2, bDT bSRH:bD? 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LOT LOT LOT bDT 229,905 238,682 20),022 5 067 .135,497 999~250 'g ,:2 0 '999e250 '999~2~0 -999 250 .099e,2~P ~-999~2~0 -99~250 -999i. 250 -999.250 -9 -99 '999 :99, 250 999*290 '999,2~0 -999,2S0 :999,'2~0 :999~2~0 '999,2~0 bis Tape Verification Listing SChlUmberger Alaska ComputXnq Center 5-~EC-199! 09~18 PAGE~ 12 I~PH, IbN,DTE IIXD,DIE SP,DTE ~RES'DTE DRHO~bDT SSi,bDT S1RN,bDT -bDT TNRA;CNb CN?¢,¢Nb TEN$,CNb HTE DEPT lb~ DTE IIXD DIE SP DIE ~E'S DTE DRHO bDT kS bDT SIRH GR ~DI H~E~ ?NRA HTEN CS~ 6700 000 3 450 31'443 440 =45 438 o99~ 369 250 -999 250 -999 250 -999 25O ~999250 =999 250 -999~250 -999~250 ~$0 -999 -999 6600,000 ! 402 -999 250 ~999 250 -999 250 -999.50 -9'99 -999 250 '999 ~50 '999 t50 -999 250 -999 250 CIDP,DTE CIbD,,DTE IDQF, DTE ZIRM, DTE GR~DTE HTEN, DTE PEF, bDT S$2bDT bSRH. bDT TENS bDT NPHI CNb NPOR CNb TENS CSG CIDP'DTE CZbD,DTE XDQF,DTE IIR~,DIE GR,DTE HTEN,.DTE bU~bDT SSi,bDT TENS, bDT NPHI,CNb NPOR~CNb CFTC,CNb ~RES, CNb TENS*CSG 286.374 IDPH,DTE 3.492Cl~P.DTE 2~,813 288.5~6 IDD,DTE 3,466 CXb#.DTE 2 o. 27X,04 0 XMQF'DTE 0,000 XXRD.DTE TENS,DYE 4305..000 ~TE#,DTE ~986,~4 DPHI,bDT -999,250 RHOB,bDT .999,2 -999. 0 QbS,~DI -999'250 QSS,bDT 999d. 2~0 -999;250 ~b,bDT -999,250 blTH.bDI -999,250 -999,250 bSHV'bDT '999.250 $SHV'bDT 9250 -999,250 NTEa,bDT -999.250 ~RE$,bDT -999,250 -999.250 R?NR,CNb -999 250 TN~H.CN~ -9~9,250 ' 99,.0 '999,250 RCNT'CNb -999250 RCFT.CNb "999,250925 '999.250 GR.CNb -999 ~50 '999'250 HTEM,CNb '999 ~502 HTEN.CNb ~99~,2~0 -999,250 HRES,CSG -999250 ~TEN,CSG '-999,~50 IbD,DTE 4 !IX~,.DTE 6 DPHI.,bDT '99g '999~2~0 OhS,bDT -999 -999,250 bSHV~bDT -999,2~0 bURH,~DT -999 -999~250 ~TE~;,~DT -999 -9~9,.250 RTNR~CN~ -999 ..999,:250 RCNT*CNb '999 -99'9,~. 0 9 ~T'E~'CNb -99'9'250 ~RES,CSG -99 DEP?,: 6500,:000 ClOP'DIE 288.396 'IDPX~ 289, iNPH,DTE 3,426 CIbD,DTE 6~I lbDi · i:ooo ZXXD.DTE36.235 SP.DI£ '49,625 GR,DTE' 2~2''0 4' ~RES;DTE ,__1'391~ HTEN~DTE · DP:H~. DRHO'LDI ~99~50 PEr,bDT -999; 0 _kS,LOT -999,250 bU~bPI -999,250 Lb, SEt'bDT .999,250' SS2*~DT -999,250 GRoLDT 999,250 TENS'LDT -99e MTEM RTNR TNRA,CNL -999,250 NPOR~CNb -999,250 RCNT CNTC..CNL -999,250 CFTC,CNb -999'250 OR TENS,,CNb -999~250 MRES~CN~ -999,250 MTEM GR,,CSG '..999~250_ TENS;CSG '999,250 MRE$ H?EN,CSG 999,250 473 CIb#,DTE O00 ~50 SFDUeD~E 000 250 RHOB'bD~ 250 QSSbDT ~50 bITH bDT ~-999. -999: 999 DTE DIE , DIE ,DIE ,DTE ~.bDT ,,bDT ,bDT bDT CSG 0~0:00 ,9,250 RHOB,bDT ;9~9.250 OSS,bDT :999,250 ~9,~50 bi,H. DT ~999,250 '999"1'502 '9~ 150 .999.250 -999~250 MRES, ~T -999 ESO -999.250 TN~H.'N' '999 ~ 0 -999~ 50 '999150 .9,, !,o '999 250 ~I$ Ta~e verification ~lst~ng chlum erger Alaska Computing Center 5-DEC-199! 09~I~ DEPT, I~PH DTE ILM'DTE IIXD DTE SP DTE HRE8 DTE DRHOLDT L$ bDT SSi.bDT SiRH.bDT HTEN,bDT TNRA,CNb CNTC,CNb TENS,CNG GR,CSG HTEN,CSG DEPT XMP~ PTE IbM DTE XIXD DTE MRSP DTE ES DTE DRXO LDT LS LDT ss! LDT $1RH bDT GR LDT H~EN bDT TNRA CNG. 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DTE DPHX, LDT OhS. bDT LL~bDT LSHV, LDT bURH bDT MTEM bDT RTNR CNL RCNT CNG GRCNb MTEMCNL MRES CSO IDPX*DTE ILD,DTE XNGF.,DTE IXX~,DTE TENS,:DTE: DPHX.LDT Q~S bDT bSH~ bDT LOT LURH GDT M~EMbDT RTNR CN RCN?CN~ GR,CNL MRE$ IDPH~,DTE IL~DTE ING'DTE IiXM!~'DTE TENS~,,DTE DPXI:bDT Ob8 bD~ LbibOT $HV,.LDT URX~,LDT MTEM,.bDT R'TNR*CNL RCNT;CNL GR'CNL ~TE~'CNL ~RE$*CSG 3 3 0 -99 -999 -999 -999 -999 -999 -999 i24 CIMP.DTE 3S5,543 11 0~0 CXLH,DTE 315,899 IXRD'DTE 268,943 3 0 srLU.DT£ 33,097 0~0 NTE#,DTE .t 0,048 .250 RHOBUbDT ,999,250 .250 999,.250 '999.25O OSS,bDT ,250 .150 $6HV,bDT -999;250 ~,~50 CALI.LDT "999,250 , 50 ~RE$,LDT '999'250 ,250 T~PH.CNb :'999,250 ~999'25~ RCFT'CNL "999'250 999,25 CALt,C~b 5 .9 .2so o -999,250 MTE#;CSG ¸ 5O Cib~,D~E 29~,~47 0,00 IIRD,~[ 263,860 29.69 8FLU, , ),335 4465.00 MTEN, , ,:~ ,4 . $$HV.LDT -9.9,250 CALZ.LDi '-9!9,250 -999 2:5~ RCFT, -999 25 CALl. ::-9~ 9,250 MTEM, -9!9~250 3.00~ CXMP'DTE ~,,000 IIRD.DTE 25*465 SFLU.DTE ~175'000 ~TEM'DT~. 999.250 RHOB,LDT -999.25o LITH*LDT -999,250 C L'.bDT -999,250 MRE$*LDT -999,250 TNPH,:CNL 999*25. 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INPH.DTE IbM..DTE I~XD.DTE 8P.DTE MRE$eDTE DRHO*bDT bSebDT $$1.LDT $1RH.LDT GR.LDT HTEN.LDT TNRA CNL CNTC CNb TENS CNL HTEN CSG DEPT., IMpN,DTE IbM.,DTE IXXD,DTE SP,DTE HRES,DTE DRHO*LDT LS,LDT SSi*bDT SiRH~LDT GRebDT HTEN*bDT TNRR.CNb NTC;CNb ENS'CNL GR.CSG HTEN*CSG D~PT IL~.DTE IIXD~DTE SP DTE ~RES DTE D~HO~DT ~SLDT SSi ~DT Sim, ~DT G~,LDT HTEN,bDT T,RA.'CNL CNTCiCNL TENS* Nb ' GR,~SO HTEN,CSG 6100.000 2 774 2 795 51476 -58,438 .99~376 ,250 -999.250 -999 ~50 -999 50 -999,250 -999,250 -999, 50 -999,250 6000 000 4 62~ 4 57 44 616 -64 68 -999 -999 ~50 -999 -9 :50 -g ~250 -999,250 -999,250 590i,000 ,5JO ,498 999 '999 50 '99'~ 250 '99! 250 '999.250 '999 50 -999,~50 -999:~50 -999: 50 -999 250 -999 25O CIDP, DTE ClbO DTE IDQFDTE IIRM DTE GR DTE MTEN DTE PEF bDT bU bDT S82LDT bSRH,bDT TEN&bDT NPHX,CNb NPORCNL CFTC,CNb HRES,~CNb TENS,,CSG CXLD~DTE · ' DTE GR, D.E PEF. b T ,LU:L~T S$2, LDT LSRH!LDT TENS bDT NPHI;rCNL NPOR,CNL CFTC,CNL MRE$~CNb TEN$,CSG CIDP DTE ClbO DTE DOF DTE ~XRM DTE GRDTE HTEN DTE PEF.LDT LU bDT bS.' bDT TENS bDT NPHI CNL NPOR CNL CFTC CNb HR. 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Z~D,DTE 3 _0,000 l~ F,DTE 0 -999,250 bURH,bDT -999..2'~0 NTEM,bDT *999,250 RTNR,CNb -999,250 -999a~50 MRES~'CSG -99 - ;250 '".,, :.ti "99:,250 )00 ZMQF.~'DTE O0 999 !~O QLS*bDT *999,250 OS8*LDT ~,~' 0 -999 !~0 LL,,LDT -999'250 .999 150 bSHV bDT 50 $SH~,LDT ~999 -9~9~250 NTEM bDT 999~2 MRES:*bDT -999.250 RTNR, CNb -999:2~0 TNPH'CNL -999 -999,~0 RCNT CNL -999 ~50 -999,250 ~RES CSG -999 250 MT~H, ::-999 bis Tape Verification blst[nq 3chlum~erqerAlasKa ¢omputin~ Center 5-DEC-~99! 09118 PAG£~ I~PHiDTE IbMDTE IlXO DTE SP~DTE NRE$ DTE DRHO bS bDT SS1 bDT SIRH bDT bDT TNRA CNb CNTC CNb HTEN CSG D~PT~ I~XD,,~D?£ DRHO~bDT SS.,,LDT SlRH,,,,bDT TGR,bDT H'_EN;bDT TNRA,.CNb CNTC..¢NL TTNS'CNL GR'CSG HTEN,CSG DEPT .I~PH DTE !bMDTE IIXD SP OTB ~RES DTE DRHO bDT $8~ bDT S]RH bDT ,T~ bDT ~DT CNTC TENS GRCSG HTEN.CSG 5800 000 C[DP DTE ~40.248 [DP. DTE 2.93~ C[MP.DTE 344.9 2899 CIbD DTE 340.865 IbD DTE 2.93. '42 931 IOOF DTE 0.000 INQF DTE ~ :r~2 ~*'"~2 2~:000492 8rbU'DTENTE#.D,EZZRD'DTE 28~'647,000 ! 109'3§2 3845'000 ,250 999.250 -999 OSS bDT '999.250 -999 '999.2~0 -999 ~50 -999.250 -999., 50 -999.250 .9990 -999.250 °999 -999.250 -999 ! ~50 , 50 -999.250 :999,250 999,250 -9~t 250 IIRH DTE IIXN DTE GR DTE TENS OTE 122:933 -9919 HTEN DTE DPH! bDT -999,250 PEr bDT OL$,bDT ~ - -999,250 -999,250 bU bDT Lb,bDT LITH:bDT -999,250 882:bDT bSH¥,bDT SSH¥~LOT .-999~250 -999,~50 -999.~250 bSRH.bDT bURHebDT , CALI,bDT -999,250 . 999~250 TENS, bDT ~TE~,LDT ~ ~RES,ZDT .-999.250 -999,250 NPHI,CNb RTNR.CNb · TNPH,CNb -999,250 ~999i250 CFTC,CNb GR,CNb . · -999~250 TENS. CSG NRES,CSG , -999;250 $700,000 4.094 06 .999 2SO .999.~250 .999+.250 999.,250 '999~:,250 ~999~250 ~999~250 ~999~250 -999~2'50 5600'000 2'867 999,250 -999,250 -999~250 ~999 250 -999 250 -999 250 '999,;250 '999;250 '999~250 ~999~250 CIDP'DTE CIbD,DTE IDQF,DTE IIRN,,!DTE GR.DTE HTENJ. DTE PEF,LDT LU,LDT SS2'.LDT bSRH,bDT TENS,bDT NPHI,CNb NPOR*CNL CFTC'~:CNL TEN'$,,CSG, C'iDP~.DTE CILDi,DTE iDOFi~DTE IIRMi:.DTE HT'EN~;DTE PEF~bDT bU,bDT b8 ,bDT TENSaLDT NPHX,CNb NPOR,:CNb CFTC,CML MRES, CNL TEN$,CSG 00~ 20 '999 999 ,,999 ,,999 '999 ,,999 2,5~2 0,0~0 3 ',07 999,250 '999;250 '999,250 '999'r250 '999'2:50 ~999'250 ,,999'250 *'999,250 ,,999;250 l DPH DTZ ~DTE ,DTE TE~ ,DTE DPH! ,bDT L~LDT .bDT bSHV bUR:Il bDT td~El4 · DT IDPHOTE ILDDTE INQF DTg. I'!X~DTZ TENS DTE' DPHI bDT OhS bDT Lb, bDT bSH¥ bDT bURH bDT MTE~bDT RTNR~CNL RCNT~CNL~ 'GR~CNL MRES 4 i:ii 0 t 4., 000 4 01~ .~999 .:~ 0 999 ,~i 0 ~2! 0 I~094 0000 21369 ~870 000 .999250 999250 -999.250 -999~250 '999~250 '999,25. .999~250 -999.250 -999,250 -999,250 INP,DTE I~N'DTE NTEN~DTE RHOB,LDT 3SS,bDT C~L CALI,CN~ 'SrbU~ RHOB~bD~ QSS, L.DT bX~H~LDT SSH¥,LDT MRE$. TNPH, CNL CALI Cab HTEN CN!. '349~ -,,,999, .,,999: ..,999 Iil bis Tape Vertftcatton bisttnq Schlumberger Alaska Computtn~ Center 5-DGC-199! 09118 $6 DEPT, IMPHDTE ILM DTE IZXD DTE SP DTE MRES DTE DRHO bDT L$ LDT $1R~ bDT ~R LDT HTE~,~DT TNR~CNb TENS,CNb DEPT IMPH DTE ZLM DTE IZXD DTE SP DTE MRE$ DTE DRHO bDT L$ LDT S$2. bDT $1RH bDT bDT TNRA CNb CN?~ TENS GR CSG H?EN CSG 5500.000 ! 670 2 088 86 364 '48 688 '99~ 505 25O -999 250 -999 250 -999 250 -999 250 -999-250 -999 -999 )50 -999250 -999~250 -999250 CIDP,.DTE CILD~DTE IDOF~DTE IIRM~DTE GR, DTE HTEN~DTE PEFLDT bSRH bDT T~N$ NPH! CNL NPOR CNL CFTC CNL NRE$ CNL TENS CSG 540.987 549.288 0.000 442.232 109.233 i970,963 -999o250 -999.250 -999.250 "999.250 '999.250 '999.250 '999.2~0 999.25o 999;250 -999,250 IDPH.DTE IbD,DTE IMQF,DTE TEN$,DTE DPHI.bDT OLS,LDT LURH,~D? MTEM~LDT RTNR:CNL RCNTCNL GR:CNL MTEM CNb MRES CSG 1.646 CZMP'DTE 5{4,e57 1.62! CXLM,DTE 479,006 0.000 XXRD,DTE 433,734 45.979 SFLU.DTE 2,1i! -999.250 RHOB,LD? ' -999,.250 bXTH,LDT -999.~50 SSH¥,LD~ ' 99~ 0 -99 ,250 CALl,bDT -99 .250 MRES.LDT -999,250 -999,-~ TNPH,CNL -999,250 -999~5o RCFT.CNh ~999,250 -999.25P CALZ,CNL -999,250 -999.250 HTEN~CN~ '9999250 -999.250 MTEMoCSG -999,250 5400.000 CIDP'DTE 197,6~2 IDPH DTE 5,059 CZMP*DTE 5.060 CXLD,DTE 299,594 IUD DTE 5,010 CXLM,DTE 4~879 IDGF,DTE 90,000 ZMQF DTE 0.000 XXRD~DT~ 23.~?$ IIRM,DTE ! 2,664 ZIXM 'DTE 10,500 SFLU.DT~ -69,750 GR,DTE 1~9'3~? TENS DTE 3945,000 MTZ~,DTE 1,475 HTEN,DTE 1978..i71 DPH! bDT '999,250 LDT -.999,250~ PEF.~LDT -999.250 QLS LTD :999.25~ RHOB.Q$~.i~!LDT .999;250 LU*LDT -999,250 Lb LD? 999.25 'TH .-999,250 LSHV.iLDT -999,250 -999,250 L R *bDT -999,250 LURH*LDT .-999..25'0 CALl . ~' -999,.250 TENS'..LDT -999,250 MTE~,LDT -999,,5~ MRE$~D, -99 0 NPOR,CNL -99'9,250 RCNT,CNL -999'250 RC'FT -999.,250 CFTC'CNL -999,2~0 GR~CNL '.999.250 CALl -999,250 MRE$,C'NL -999,250 MTEM~.CNL~ -999,250 HTEN -999,250 TENS.CSG -999.250 MRES,CSG. '999,250 MTEM -999.250 CIDP DTE CXbD~DT IOOF DTI HTEN DTE PEF. LDT bU LDT SS DT TENS bDT NPHI NL CC CNb MRES CNG TENS CSG 7,8?9 'XLD.~"DTE 0,46! 'IIXM,DT~ 9.79 TEN$:iDTE ~9'2~ OLS:~LDT ~996.26 DPHX*LDT 999~25 '999,~25 LSHV,bDT -999,250 LURH,LDT -999, RTNR,CNb '9!"50 RCNT'C~L '9~ ~0 GR,CL -999,250 MRES*CSG i 867 CXMP.DTg 8 9 0~)0 CILM,.DTE IXRD,DTE' 46 21:0 SFLU,DTE 3865 000 NTE~eD?E -999 250 RHOB.LDT -99 ~.' 50 -99 ~ 50 QSS;bDT LXTH,LDT -9 SSHV,LDT -9~ .250 Clb:I,bOT -9~ ;250 ~RES'LDT ,250 TNP~,CNL ,250 CALI,CNL -9 .:250 HTEN,CNL ~999'250 HTE~,CSG DEPT..:: 5300.:000 iMPH.DTE 1,793 ILM,DTE _[{800 IIXD;DTE 88;.400 SP.'DTE -49~938 MRES,DTE . 1,489 DRHO,LDT 999,250 L$;LDT :999.,250 8$1*LDT ,999,250 SiRH.LDT .999,250 GR.;LDT .999'250 H?EN~bD? 999,250 TNRA.CNL :999~250 CNTC'CNL ,999,250 TEN$,CNL 999,250 GR,CSG -999~.250 HTEN,CSG -999~250 204, !3.,)i '":" :'99:) "991 250 '999*250 .~999,250 :-999,250 :-999'250 "'999'250 '999'250 "999'~250 :'999,250 bis Tape Veriticat~ton bist~nq $chlumeercjer Alasica Computing Center 5-DEC-1991 09=18 D~PT, ILM.DTE IIXD~DT£ MRE$.DTE DRHOebDT LS.bDT SSI,bDT SIRH,bDT GR,bD? HrEN bDT ?NRR CNb CNTC CNb TENS CNb GR NTEN OEP? I~PHiD?E Ib~ DTE IIXD,DT£ SP,DTE MRE$,DTE DRHO,bDT L$,bDT SSI,bDT S1RH,LDT bDt TNRA TENS Nb GR HTEN DEPT*i XMPH,DTE ILN,DTE IXXD,DTE RSP,DTE M E$'~DTE DRHO;LDT b$,bDT SSI,bDT S1RH.LDT O~LDT HTEN~LDT TNRA,CNL CNTC,CNL TENS*CNL Ce*cso HTEN.C$O 5200,000 CIDP~ 2,205 CILD, 2,186 IDQF 71,705 IlR~ -51,875 OR . ~,494 HTEN .999,250 PEF 999,250 LU ~999,250 882 .999,250 LSRH 999*250 TENS~ ~999'250 NPHX~ .999e250 NPOR~ 999,~$0 CFTC, :999,2S0 HRE$, .999'250 TENS, 999~250 510i:000 840 494 -999250 -999.250 -999.250 -999,250 -999 250 '999250 '999 250 '999 250 -999 250 DTE 467'583 ZDPH.DTE ~.139 CXNP,DTE 453,444 ,P?g 470,9;1 lbO,OrE 2,,123 C. ILN,DYE DTE 0.000 Z.OreO?E 0oO00 ZZRD.DtE 376.~ .DTE 422,943 IZX~,DTE 36,043 SFLUeDTE 2, ,DTE I17,670 TENS,DTE ~940,000 MTEMeDTE .bDT :999,250 QbS,bDT -999.250 O$S,bDT -999,250 .bDT 999.250 bb*bD? -999,250 blaH,bDT -999~250 ~bDT :999 250 bSHV,bD? -999..250 &&HV,bD? 250 .bDT .999 250 LURH,LDT -999.250 CAL~,bDT ..-99' ~250 .bDT 999 250 NTEN,LDT -999,250 MRESeLDT ,CNb -999 250 RTNRtCNb -999,250 TNPH,CNL ~99 RCFT.CNL :Nb -Egg 250 GROCNL 999.250 CAbX'CNb -999,250 CNb -999 250 H~EH,CN~ -9 CSG -999 250 RZ$.CSG HTgN.CNb ,250 HTEH,CSG. w999,250 C2DP::D?E CILDDTE XDGF~DTE IXRM~DTE GR, DTE HTEN, DTE PEr. bDT LUbDT SS2. LDT LSR:H~.bDT TENS. bDT NPHICNb NPOR~CNb CFTC,CNL MRE&,CNL TEN$~CSG 504,378 509. iO O; 503, '999a -999; !0 '999, 9.9, '999' '999~ '999' iO ~999,50 'IDPH'DTE 1 983 XbD,DTE ~ 964 XMGF,DTE 000 IXX~'OTE i~ 9~8 TEN$,'DTE 37 0 0 .o Lb,bDT -9~ 0 bURH*bDT '~!! 0 MTEMebDT i~O RTNR,CNb 099 R~NT,:CNb -99 CXNP.DTE CILM,DTE ,DT~ TE ,DTE RHOB bDT ,bDT RCFT .Nb HTEN MTEMi "999 ~-999 ·*999 66.1 . 50 · $0 0 5000,000 3,805. .35,~60 60'063 . !,532 .999~250 .999,250 999'250 -999~250 -999,250 -999'250 -999'250 -999*250 -999,250 -999,250 -999,250 CXbD,DTE IDQF,DTE IXRM,DTE GR,DTE HTEN,DTE PEr,bDT LU bDT bSR~ bDT bDT TENS LOT NPHICNL NPOR CNL CFTC CNL MRE$ CNb TENS CSG 59: 999 '999: -999; '999, '999, 'g99' '999, '999, -999' lbO,OrE 3 000 ZMOr~OTE ~o 646 IZX~,DTE 002 TENS~:DTE 36 996 DPHXabDT -999 250 QbS,bDT '999 250 Lb~LDT 50 LSHVebDT MTEM,bDT RTNR~.CNb -999 i GR,CNb -99.9 RCNT,CNb -999 ~TEM*CNb -999 50 MRES,CSG -999 85? , 50 IIRD'DTE 647 SFbU,DTE 000 ~TE~'DTE ~250 RHOB~LDT ~250 QSS,LDT ·250 :' 0 C~L:t*LDT · ~50 MRES,LDT ~250 TNPH.eCNb 50 RCFT,CNL 50 HTEN~CNb 250 MTEM'CSG ! 999 ,250 ,,,999,250 ~999 ~I$ Tape Verification b~st~ng ohlum~erger AiasKa ~omput~ng Center 5-DEC-199! 09=lB 18 DEPT IMPH DTE IbM DTE IIXD DTE SP DTE MRES.DTE DRHO,LDT S$1.bDT $1RH,LDT OR,bDT H?EN,LDT TNRA,CNb CNTC;CNb TENSCNb DEPT IIXD SP MRE$ DRHO SS1 $1RH DTE DTE DTE bDT bDT bDT bDT bDT bDT TNRA;CNb. CNTC,.CNb TENS,.CNb GReCSG HTEN. CSG X~PH,DTE. IbM DT RSP.DTE DRHO'bDT bS bDT SS~ bDT SlRH bDT GR 5DT HTEN ~DT TNRA CN5 CNT TENS GR O0 3~498 -59 ! 5t2 -999 250-999 250-999 250 °999 25O -999 250-999250 °999250 -999 250-999.250 '999.250 '999,250 4800~000 3,075 3,070 40.224 -55,438 . 1'554 999'250 -999;250 -999*, 50 '999'~50 .999, .999;250 -999:~250 '999~250 *999'250 -999~250 ,620 ,024 *,: 0 -9'9;9'~0 .99; .250 *250 -999~250 -999,250 -999,250 -999~.250 -999.250 -999'.250 -999,250 CIDP. DTE CILD, DTE IDOF, D?E IXR~,DTE GRD~E HTENDTE pzr, bDT bUiLD? SS bDT LSR~ bDT TENS bDT NPH! tnb NPOR CNL CfTC CNb MRES CNL TEN& CSG CXbD, DTE OOr :OTE IIRM,DTE GR,DTE HTE~DTE PEr,bDT bU,bDT $$2'bDT bSRH.~bDT TENS, bDT NPHX,.CNL NPOR*CNL CFTC,C'NL TENS,CSG. CIDP,,DT'E CXLD~)TE. XOQFDTE DT IIRMoR DTE HTENDTE PEF bDT LU bDT $82 bDT LS:RH bDT TEN& bDT NPHX CNL NPORCNb CFTC CNL MRE&CNL TEN$~CSG, 277,259 278,486 0,000 267 66 117 ~72 2059 ~55 -999:50 -999250 -999.25 -999 25~ -999 250 -99g 250 -999 25O *g99 .250 -g99 25O -999 250 96,706 0.000 303,773 82,4~i 2141,574 '999,250 '999,.250 :"999~'2~0 '999,250 -999,2~0 -9~9,250 '999.250 '999.250 ~999.250 14 0 ~00 · 2~38 91 *999 · 999 250 -999;2 0 '999,250 '999,250 *999,250 '999,250 '999'250 *999,250 IDPH~DTE XLD~,DTE IMOF,,DTE XXXN,DTE TENS,DTE DPHI~LDT eLS bDT Lb, bDT LSHV~LDT LURH~LD? MTEMeLDT RTNRtCNL RCNT,CNb GR,CNL MTEM,CNL MRE$~CSG XDPH DT TENS DTE DPHX bDT ~L$~DT L~,LDT bSHVbDT LURH, LDT R'TNR*C~L RCNT,CNL G.R,CNb MRES'. 3,607 CXMP.DT~ 3.591 CZLM.DTE 0.000 XXRD.DTE 40~. 260 SFbU.DTE .000 MTEM.DTE -9 9,250 RHOBeLDT -99 GSS.LDT .99~'250 -999 [i~ LXTH~LDT $8HV, LDT 0 000 ~XRD.DTE 22 412 SFLU.DTE 3845 .000 MTEM,DTE -999 250 RHOB.LDT 0999 250 Q$$ rDT *,999 250 bXTH;L -999 250 SSHV:~; ~ . -999i250 RCFT.~NL NL '-999,250 -999,250 HTEN -999.250 999 RHOBi -999 O" -999 50 ~RE8, RCFT, -999.2 CALl, "999,250 HTEN -999,250 ~! CXLM'DTE .000 XZRD.DTE 99 MTEMi.DTE ,,~50 ~LDT .~50 bDT ~.50 bDT ,. 50 LDT LD t 28 ,868 28 ,844 23 ,829 9 -99 ~250 -999,250 0999, '999~ '999 ,:250 '9~9 250 "999 "999 :'999 - '999 '999 -9~ 250 ,*99 250 -999,250 -999,250 -999,250 :-999,.250 .-999,250 -999 ,.250 ~Is ?a~e Yeri~cat~o~ $chlu~bercjer Alaska ¢o~put~ncj Center 5-DE~0199! 09~18 PAGE! I~P~,DTE 3,202 CIbD DT£ 302,?~4 I D,DTZ 3 303 CIb#,DTZ t}i . 58 0.000 I~r. DTE :~36 Ib~.DTE 3.173 0000 IIRD,DTE IIXD.DTE 41,693 IZR~ DTE 294.1~2 IIXH+DTE 21~?07 SrLU,D~g~205 !o8,1 4 TENS,DTE ~825 000 SP,DTE -60,938 GR D?E 205~,4190 -999~250 250 RHOB.LDT '999. DPHX,~D? NRES'DTE . !'583 HTEN DTE DRHO"LDT .999'250 PEF LDT °999.250 GLS.bDT -999250 GS$.~DT -999,250 L$~LDT 999,250 LU LDT -999,~50 LL,LD? -999~250 LITH,LDT -999,250 SSI LDT -999,250 SS2 LD~ -999.~50 LSHV~D? -999~ 250 'SSHV.LDT °999.250 $1RH LD? -999.250 LSRH,LDT -999, I~0 LURH~O~ -999:250 CALI.LD~ -999;250 GR LD? '9997250 TENS LD? -999, 150 ~TEH,~D? -999;250 HRES.LD7 :-999 250 ?NRA CNL -999.250 NPOR.CNL -999, 50 RCNTtCNb -999,250 CN?C CN~ -999.250 C;TC,CNL -999" ~0 GRtCNL -999~250 CAbX~CNL ~;~; 250 50 T;NS CNL -999d250 ~RZ$,~CNL -999. 50 ~T;N.CNL -999..250 HTEN.CNL -9992250 GR CSG -9990250 TENS~,CSG '999, 50 HRESoCSG -999.250 MTEM,CSG H?E~ CSG -999.250 DEPT.~ 4500.000 CZDPLDTE 306, 30 IDPH'DTE XNPHeDT£ 3,130 CZLDiDTE 306 60 ~bD,DTE 3:262 CIbN,DTE 322,126 'I~.DT£ 3,~04 IDGF'D?E ~_0~ ~0 IHGF,DTE. 0 000 IIRD,DTE 257'670 IIXD'DTE 40*.29g ZIR~,D?E 300~ 5 IIX~.DTE 2! 943 SFLU,DTE 2.869 SP,DTB -62.500 GRtDTE I:05 0 TENS,DTE 3725 000 MTEN-DTE .109,23~ MRE$,DT£ 1,560 HTENiDTE 203~: ! DPHItLDT -999 250 RHOB.LDT 999,250 DRHO~LDT -999i250 PZF.~DT O$S.LDT -999,250 $$~,LDT -999.25'0 L ~bDT Lb,bDT - 50 ~SHV~bDT ,999,250 ~SHV*LDT S1RH,bD? :999.~250 LS~H;LD~ 999. 0 bUR:H~bDT : $ ~RE$.LDT -999~250 G bDT 999,. 0 TEN$~bDT 0999 .0 HTEM,bDT CNT¢,CNb ~999~250 CFTC~C~L -999 0 'GR,C~L ;999 250 CAbI;C~L ~999,250 TEN$,CNL . -999,250 ~R£S, CNL -g99 0 ~TZM,CNL °999 250 HTEN.CNL : 999,250 GR,CSG ~999,250 TENS, CSG -999 0 MR. ES,CSG 999 250 MT£M.CSG -999,250 H?ENeCSG 999,250 DEPT. Ib~ DTE IIXD~T£ SP)TE ~RES DTE DRHO ~$ UDT $tRH bDT' GR LDT H?EN TNRA CNL C~T¢ C~, TENS 4400 .999 999 -999 -999. -999 -999. -999 -999 -999 -999 -999 000 831 :556 250 250 250 250 0 25O 25O .DTE ,DTE Z GR ~DTE HTEN~.D'TE bU:,~bDT bSRHabDT TEN$~bDT NPHI*CNL NPOR,CNb CFTC,.CNL MRE$iC~L TENS,CSG i. LD ,0,000. I~OF 330,412 -999;250 0~8 -999.250 -'999.,250 hS~' -999.250 hURH -999,250 MTEM '999.250 RTNR -999,250 RCNT -'999,250 GR -999.250 MT£H -999.250 MRZ$ :DTE DTE 0;000 I'iRD. DTE OTE 36i5,.:~.00 bDT ,999,250 LDT -999,250 .,bDT -999~250 LITH bDT -999,250 $$HV LD? -999,250 ~ D? -999~290 TNPH ~.NL -999~.250 MRE8 .CNL -999,250 RCFT CNL -999,250 CALX C'NL -999i250 CSG -999,250 MTEM DTE LDT . oI: ;999; '999, :-999. :-999. ~999 :;999 .'999 250 250 "!0 chlumberger AlasKa Comput er 5-DEC-1991 09{18 2O DEPT~ ZbM,DTE !IXDiDTE SPDTE MRE$ DTE DRHO bDT bS bDT SS! bDT $1RH bDT GR bDT HTEN bDT TNRA CNL CNTC CNb TENS CNL GR CSG HTEN CSG DEPT,, IMPH,DTE ~bM,DTE ~ZXD.DTE RSP~DTE M ES,OTE D~HO,LDT bS,bOT S~RH,bDT GR~LDT HTEN*bDT T~RA,CNL C'TC~¢Nb GR,CSG DEPT I~PH DTE IbM DTE IIXD DTE SP DTE MRE$ DTE DRHO LOT bS bDT SSIbDT S!RH bDT GR HTENbDT TNRA CNb CNTC tnb TENS Nb G~ HTEN,CSG 4300 000 2 689 2 700 45 397 -62.000 -999 250 50 -999 -999: 0999 250 0999 0 0999 250 '999 250 '999 o00 o~? -63 000 584 -99~ -99 ::50 -99 -999;2~0 -g ~250 -9 ,250 4 oo'ooo 3,524 3~5~0 .33,~28 $4~375 1,603 ~999~250 ~999 250 -999 ,250 -999 -999~50 -999 250 -999 e999 250 -999 -999!250 -999 CIDP DTE CZbD DTE GR DTE HTENDTE PEF bDT L~.LDT 882 bDT bSRH bDT TEN~ bDT NPOR, CFTC~CNb MRESiCNL TEN$CSG ClLD,DTE IDQF.eDTE GR;DTE HTEN,OTE LU~LDT &S2~LDT LSRH~LDT TENS, bDT NPHi~CNL NPOR,CNL TENS,CSG CIDP DT CX'LD IIRM,DTE GR,DTE HTEN~DTE PEF,bDT bU~bDT SS2~,bDT bSRH~bDT TEN$:~bDT NP~I CNb ~POR CFTC~CNb ~RES~,CNL TENS:,CSG 345 325 347 0 )00 -999 !50 -999 -gg9 t0 -999 ~50 ~50 -999; -999' -999, .0 "9gg, 50 IDPH,DTE ILD DTE IMQF DTE IIXM DTE TENS DTE DPHX bDT ObS bDT Lb bDT LUR~ bDT bDT NTENbDT RTNR.CNL RCNT.CN GRi.CN~ MTEM, Nb MRES,:~SG O, 309, 99, 20!~3 "9!t9 '9! 9 "'g! 9 -g! g 'g! 9 "g! 9: "9! g -g! g. *g~ g 250 IDPH*DTE .ILD,DTE IMQF,OTE TENStOTE DPHIebDT Ob$~bOT LLiGDT bSHV:bDT bURH, bOT ~TE~ .OT RTNRi!NL RCNT~ Nb GR,.NL MTEM,iN 6!,~ IDPH OTE ILO DTE TENS DTE -999,250 Lb bDT '999,250 LSHV bDT 0999'250 LURH~,LDT '999,250 MTEM,LDT ''999,250 RTNR*CNb '999,250 RCNT,CNL -999'250 GR'C'NL -999~250 -999,250 MRE$,CSG CIMP DTE 371.893 CILM DTE 370,402 000 XIRD DTE 287,561 725 SFLU DTE 2,4g0 000 NTEM DTE 0 ~,.~ 06 $0 -999.250 QSS bDT : 999,250 -999 250 b~H bDT -999~250 -999 .250 SSHV bDT -999,250 -999 250 CAbZ,bDT -999*250 -999 250 HRES*bDT ~999~250 -999 250 TNPH&CNb -999~250 -999 250 RCFT.CNb -999,250 -999 250 C~bZ,CNb -999,250 0999 250 HTEN.CNL -999,250 -999 250 HTEHoCSG ''999,250 o,ooo 23,492 SFLU.OTE 2t845 3550,000 MTEN,DTE 106,720 -999~ QSS:bDT :-999,250 :799,{ LXTH LDT :'-999,250 999,2~0 S$HV, hDT '-999~250 i :-999'250 :~gg~:~l~ ~RES '999'250 'ggg. 50 CA~ CN~ ~99g~250 -999, 50 HTEN CNL ::999,250 -999~ 50 H?EM*CSG ~ 999,250 3, 64 cz P'* 3,~36 C!bM, 0,000 IIRD~, . 7.~872 MTEM~ 34~0'000 SrbU. '999,~5~ RHOB, -999,250 088, -999 25'0 ~ITHi -999 ~ SSHV -999 50 CA~'{i -999 250 MRES -g ~ 50 CALl . HTEN - g5'O M?E~ DTE DTE DT£ DTE DTE bDT bDT LOT LOT LOT lo~°5 :-ggg "999~ -999~250 .~999 250 ::-999~250 ~999&250 ''999~250 '~999,250 e999,250 -999,250 Tape Verification List~L Schlumeerqer Alaska Computlnngg Center 5-DEC-199! 09~8 21 DEPT, INPH,DTE ILN,DTE IIXD,DTE 5P,DTE ~RES,DTE DRHO,GDT LS.LDT SSi.LOT StRH.LDT GR,GDT HTEN,LDT TNRA.CNL CNTC;CNL TENS.CNG GR,CSG H?EN.CSG DEPT.~ XMPH,DTE iGM.DTE IIXD,DT£ $P,DTE MRES~.DTE DRHO~.:LDT bS.:LDT SSI~LDT SiRH~LDT TG~ LOT CNTC T~NS CNL GR CS HTEN IbM DTE IIXD DTE MRSP DIE · ES DTE DRHOLDT GS bDT · SS! bDT $!RH bDT GR GDT HTEN LOT TNRA CNG CNTC CNG TENS CNG G~ HTE~ CSG 400].000 .592 .571 32 . 1-: 39 999 250 -999 -999 250 -999 250 -999 250 -999 250 -999 ~$0 '999 250 '999 250 "999 250 CIDPDTE CIGD.DTE IDOF.DTE IIRN,~DTE GR,~DTE HTEN.~DTE PEP, GDT GU. bDT SS2, GDT GSRH~GDT TENS;GDT NPHICNG NPOR'iNG CFTC;Nb MRES, Nb TEN$,CSG 6 t38 0 000 2O 076 -999 2~0 -999~ -999;250 -999,250 '999.250 '999, ''''')~ '999. IDPH.DTE IGD.DTE IMQF+DTE IIXM.DTE TENS,OTE DPHX.GDT QGS,LDT Lb,GDT LSHV, GOT LURH~LDT MTEM~GOT RTNR, CNG RCNT, CNG MTEM: MRES, CSG 3 825 3 797 0 000 I? 668 ooo - 9,250 -999,250 -999'250 -9 -9'9,250 -99 ,250 CXNP.DTE CILM.DTE IXRD.DTE SFGU.DTE MTEM,OTE RHOB,LDT OSS.LDT LXTH,,GDT SSHV,,LDT CALX,,GDT MRES,:GDT TNPN,,CNL RCFT,,CNG CAGX,,CNL HTEN,~CNG MTEM,,CSG 278 tio -999 -999 ~999 m999 -999~250 ~999~250 ~999,250 3900.000 CZDP,DTE 247.~ ZDPH ~OTE 4'033 C~MPeDTE ZbD,,DTE 4.002 3,961 IDOF.DTE -~0~ IMOF.,DT~ 0.000 IXRD.D,E -66,688 GR,DTE 94. TENS;rOTE 3!25,000 MTEM.DTE . 1~647 HTEN,DTE 2017,9~6 DPHI~GDT '999.250 RHOB.,GDT 999.250 PEF~LDT -999.2~0 OLS:,GDT -999'.250 Q$$~LDT -9996250 LUe. GDT -999.250 GG~GDT -999'250 LZTH,,LDT -999,250 S$2'bDT -999,,250 bSHV.bOT -99 2 -9 ~,~.5 NPHI.,.CNG -999,.250 RT.NR.CNG -999, 5 NPOR,CNb -999,2~0 RCNT.CNG 999~250 RCFT:::,CNL -999,250 CFTC.CNG -999..2-~0 GR,CNG '999,250 -999~250 MRES,CNG -999,250 MTEM,CNL -999,250 HTEN~,CNb -999..,250 TEN$,CSG -999,250 MRES'CSG: -999,250 MTEM,iCSG -.999,250 3800'O00 3,382 3.341 34,897 -67'43~ 1.65. -999~..250 -999~2:50 -999 .:50 '999 :~50 '999 ~50 '999~50 '999 250 '999 50 '999 ~50 -999 250 -999 250 CIDP.~DTE CILDaDTE IDOF*DTE II.RM.DTE GR~DTE HTENvDTE PEF~LDT :LUeG. DT LSat,bDT TENS. GDT NPHI;CNL NPDR,CNG CFTC'CNG HRESiCNL TENSeCSG 27~;~.1277'5~2 IDPH..DTE.I~D.DTE 3,5943'603, ~{:~MP :279:6~ Z.r. OTE 0.000 87;~499 TENS,DTE 3265,:000 MTEM ~065,t8~ DPHI,GDT 0999.,250 RHOB. 999,250 QLS*LDT -999'250 QSS '999,2~0 GG,LDT -999,250 LXTH. 0999,250 GSHV~GDT -999~250 SSHV -999,250 GURH,GDT -999,250 CALl '999.250 MTEM,GDT '999.250 MRES -999.250 RTNR,CNG '999-25~ TNPH~RcF? '999.250 RCNT,CNL -999~25~ '999.250 OR,CNG -999,250 CALX: '999,250 MTEM,CNG -999.250 HTEN. -'999.250 ~RES'CSG -999.25~ MTEM. ,918 ;114 '458 . o ,,557 .2~0 ~999~20 999,250 D~E 295~664 :236.403 03-200 LOT '999,250 LOT LDT -999,250 LOT -999,250 LOT -999,250 LOT -999~250 CNG -999~250 -999,250 '999'250 LIs Tape Verl~ication Ltst~n~ Scblumberaer Alaska Computing 5-DEC-1991 09~ 18 PAGE~ D~PT XMPH DTE ILN DTE IIXD DTE SP ~RE$ DTE DRHO,LDT b$,LDT $~R ,bDT GR,LDT HTEN,LDT NRA~CNb NTC~NL TEN$,CNL GR,CSG DEFT,, IMPHeDTE Ib~.DTE IXXD'DTE S~'DTE M~E$.DTE DRHO;bDT SSI,bDT StRH'..bDT TG~:bDT ,bDT TNRA,CNb CNTC,CNb' D~PT ,Xb~ DTE IXXD DTE SP DTE MRES DT:E DRHD bDT b$ bDT '$$1 bDT $~H ~DT .TLR*bDT H. EN,LDT TNRA,CNL TENS,.N' HTEN,CS~ 370~, 000 . ! 98 ~7 $ -68 5 -999 250 -999 250 -999 250 -999; 250 -,999~50 .,999~250 ~999~250 -999,250 -999~250 ]600'0~0 ,545 '5~8 4 ~816 '999 '99' '99~ ~50' '99~ '99' ~0 -9' ;0 "9' ~0 '99' ;0 0 '9' 50 -9~ -999. 250 ~9~' 250 ~99' 250 '999 250 '999 0 ~999 250 '999 250 DPiDTE bD. DTE XD~F~DTE GR. DTE HTENDTE PEF~LDT bU. bDT $62. bDT LSRH bDT TENS bDT NPHI tnb NPOR CFTC;CNL MRES, CNb TENS,CSG I. DP,DTE 1LD?DTE !DQFiDTE II'RM*DTE GR,DTE HTEN.*DTE .PEF&LDT LU~bDT $$2 bDT LSRH bDT T~N$ ~bDT N'L NPHX~Nb NPOR CFTC MR~S* N TENS'i..'8~ 225.473 IDPH.DTE 4.435 CIMP,DTE 238,23~ 227.39' IbD,DTE 4.398 CXLM,DTE 0.000 IMQF.DTE 0.000 XIRD.DTZ 90,297 TENSeDTE 3~80.000 MTE#.DTE ~993,810 DPHI,bDT -999,250 RHOB,bDT ~999.250 QLS,bDT -999,250 O$S,LDT "999,250 .999.250 Lb,bDT -999.250 blTH,LDT '999,250 0999°250 bSHV*bDT -999;250 $SHV.LDT '999;250 999,250~ MTEM,LDT -999'250 MRE$,LDT -999;2-0 LURH,LDT -999,250 CALl,bDT -999,250 -,,,. -999, CALl, 99,250 -999' MRES.CSG -999,~0 MTEMeCSG o9! ¸65 000 .99~ '250 ,250 -999'250 '9' '999 ~0 .999 ~0 -999 CIDP, DTE 1,7 CIbD.*DTE 171 XDQF,DTE 0 IXRM,DTE 179 GR*DTE HTEN,DTE 206 LU:~bDT '999 S$~*bDT -999 bSR.,LD'T "99~ TENSeLDT NPOReCNL cF?c,c MRE$,CNL '999 T£NS~CSG "99'9 IDPH ID ~IIXM TENS D~! $HV URH RTNR RCNT, GR MRES DTE DTE DTE DTE OTE bDT bDT bDT bDT bDT bDT CNL CNb CNb ooo -999, -999: :0 -9991 -999: -999 ~0 -999~ '999~!~0 '999 elL#, XZRD, 8FLU. MTEM, RHOB, SSHV CALl TNP. RCFT CALl HTEN MTEM DTE ~DT ~DT 39, 294~ .' 999! ':~999i -999, '999~ 999~ -999~ -999 . 0 iO ,825 ~'0 ILD,DTE XMQF,DTE XXXM.,'DTE TENT.tOTE DPHI,LDT ~LS,GDT Lb bDT bSHV bDT bURH bDT MTEM bDT RTNR CN MTE~ CNG MRES CSG O0 X/RD:,D~~ ~40!!.0~~ SFLU~MTEM~DTE ' 999~250 RHOB LOT -999'250 Q$8 LDT -999~250 LiTH bDT -9~ 250 $$HVLDT 0999~ CALI.CNL -9 ,250 tnb HTr.. 250 MTEM,CSG 155, 100' -999, ':-999.~ -999. "999; -999, 999, ~999, ~50 ~.50 ~50 0 IIo 0 ~$0 ~fiO his Tape verl~lcstlon bist"ng Schlumberger laska Computing Center S-DEC-199! 09:18 ,23 DEPT. INPH.DTE IbM,DTE IIXD,DTE MRES.DTE DRMO,LDT b$.LDT $$1;bDT $1RH.LDT GR bDT HTEN bDT TNRA ,Nb CNTC ~Nb TZN8 Nb D£PT IMPHDTE IbM D?E IIXD D?E 8P DR bDT b$ .bDT SS 1 bDT S1RH.bDT GR.bDT H~EN,,bDT TNRA~CNb CNTC.CN5 TEN$,CN5 .~GR.CSG HTEN.CSD DEPT IMP~ IbM I!XO MRSP ES DTE D~ObDT h$ ~DT ~S~bDT 8~RH bDT HTEN.bDT TNRR'CNb CNTC'CNb TENS,CNL HTEN.CSG 3400.000 4.728 5,219 .20,6'/0 69,813 1~970 -999,250 -999.2~0 "999,250 '999*250 '999,250 '999*250 '999;i50 '999 ~. -999, 0 "999, ~0 ~999,: 0 oo'ooo ~999 ~999 ~0 '999 ~999 "999 -999 ~50 ~999 ' 999 2 ~ 0 -999 .694 - 8 3 1 -999 ~999 ~50 -999~ ,250 :999~250 1999'250 999 ~ 250 -999,250 -999' 250 125,603 1957'447 CIDP DTE CIbD DTE IDQF DTE IIRM DTE OR DTE HTEN DTE PEFbDT bU bDT SS2 bDT bSRH bDT TENSbDT NPHI,CNb NPOR*CN~ C~TC~CNb NRE$.CN~ TEN$.CSG CIDP~DTE CZbD,DTE IDOF,DTE IiRM,DTE GR~DTE HTEN,DTZ PEF~bDT bU~bOT SS2~bDT ' TEN$~bDT NPHI,CNb NPOR,CNb Cr?C,CNb MRES,; Nb TENS,~$G CIDP~DTE CIbD*DTE IDQF,DTE GR.DTE HTENL!DTE PEF bDT LU bDT S$2 bDT bSRH bDT TENS bDT ~PHI CNb NPOR CN5 C~TC ~RE$ TEN$,CSG 159.783 ZDPH DTE 61258 ~66.624 ~bD DT~ 6,002 CZb.,OTE 0,000 IMOF DTE 0,000 IIRD, DTE O~ 180,286 IIXM DTE ~2,806 $rbU, DTE 84.495 TENS DTE 3105.000 MTEM, DTE '~99. 2160.012 DPH! bDT -999.250 RHOB, LDT -999.250 Lb bDT -999,250 -999o2~0 bSHV bDT -999,250 -999.250 bURH bDT -999.250 -999.250 MTEM bDT -999*2S0 MRES, bDT -999,2S0 -999.250 RTNRCNb -9996250 TNPH, CNb -999,250 -999,250 RCNT CNL -999,~50 RCFT, CNL -999,250 -99962~0 GR CNb 0999,~ CAb~CNb -999~250 -999.250 MRE$ CSG -999.250 MTEM. CSG -9 o.ooo .,or;.oT, ,066 2091'324 DPH!,bDT -999 25'0 RHOB'bDT ' 999,2~0 :999~250 QbSobDT -999 250 OSS:,bDT -999,~0 999.2~0 l~b:.bOT -099 ~50 -999~.250 bUii~H:bD~ .-999 250 CAbI'bOT -999,2~0 MTi~M~ ,DT -999 250 MRES.'bDT -999,250 RZI~R~ :Nb -999 250 TNPH,CNb :. ,.~0 -999.250 :,,R, .Nb -999 250 CabI,'CNb -999,2~i0 -999,250 'MTI~M: :Nb: :999 250 HTEN~CNb -999,2;.0 '999.250 MR]~S :SG 999 250 NTEM~CSG .--999.2.i0 133 136 -999 -999 -999 -999 -9 9 -999 -999 2910 325 IDPH~ 028 000 I~D 954 52~ DPH! 2~0 2 0 bb 25O 250 bURH 25O 0RTNR RCNT 250 GR 25O 000 , 0.351 DTE ~960,000 bDT 999'250 RHOB,bDT '-9'. bDT -999'250 QSS'LDT bDT -999,250 L:ITH'LDT -9 ~DT .999,,250 bDT -999;25~ MRES*LDT CNL -999,~5 TNPH,CNb :-9 CNb -999,~50 RCFT.CNb CNb '0999,~5 CAbI,CNL CNb -999,~59 H. TEN,CN. CSG 1.'989 MTEMoCS~ ' . bls Tape Verification t, lstJ. nq 5-DE:¢-1991 09:18 PAGE! SChlum~erqer Alaska Computinq Center 24 DEPT I~PH DTE I~ DTE IIXD DTE SP DTE MRE8 DTE DRHO bDT bDT $1RH bDT GR ~DT HTEN ?NRA CNb GR,CSG HTEN'CSG DEPT,': I~PH,DTE IbN,DTE IIXD~DTE DRHO~LDT .LS~LDT SS1 bDT SiRH bDT GR bDT HTEN bDT T~R~ CNL C TC CNL TENS CNL G.~ HTE. CSG D~PT I~PH DTE IL~ DT XXXDDT~ SPDTE ~RESDTE DRHO bDT bS bDT .bDT TNRR;CNb CNTC,CNL T£NS,CNL GR,CSG HTEN,CSG 3100 000 CXDPeOT£ 227, 56 XDPH!,DTE 4o40~ CIMPoDTE 251 570 3,975 CXLD°DTE 227,~60 ILD~,DTE 4°38 CXb#°DTE 255 704 239, .6 24 363 ZZRN~DTE 20,35~ SFbUeDTE 3 4 2040, :; I 950 HT£N DTE ~ TEN$~,DTE 2980,000 MTEM,DTE 95 693 -999 250 -999,250 DPHIi,L~T -999.250 QSS,LDT :999 250 PEr, LOT ~ Ob$,b T -999.250 .999 250 ~U~bDT -999, 5 -999,250 .999 250 $$2~DT -999, ~ ~b~;.bD? 1999.250 999 250 bSRH,.LDT ~ ~SHV..bD? -999.250 SSH¥,~DT .999.250 -999, -999 250 TENS bDT -999, ~ L~RH~bDT -999,250 CAh]*~DT .999 250 =999 250 NPH~CNb ~ HTE~;;,bDT -999~250 #RE$.hD~ 999 250 T~PH,CNL ?99,250 RTNR'CNb -999 250 HPOR~CNb -999~ ~90 999~5 .999,250 -999. :50 GR.¢Nb -999~250 CAbZ,¢Nb .999~,250 -999 250 CFTC,CNb ~ RCNT,CNb RCF?,CNb *999 250 MRES,CNb -999° 150 MTEM,CNb -999~250 HT~N,~NL 999,~250 95.167 TENS. CSG 2845.000 MRES,CSG 1'793 NTEM.CSG 97..157 1995 466 3000,000 CIDP~DTE 52.135 *IDPH,D?E 19.181 CINP*DTZ -48o,324 1950,000 ¢IbD~D?~ 54,369 'I~D.D?E 18.393 CI~M.DTE -484,844 1950,000 IDOF,DTE 0.000 IMGF,DTE 0,000 IIRD,DTE 50,561 -458,496 IIRM*DT£ -478,504 iIXM,DTE 1475,298 SFLU,DT~ 9700*000 NTE#.,DTE ~*1,250 GR,DTE 57,i03 T£NS*OTE ~900,000 , 97~530 1,853 HTEN.*D. TE 2030,9~2 DPHX,LDT 999,250 RHOB,LDT .'..999~ 5 ~999,:.250 PEF~LDT -999,250 GLS,LDT -999.250 OSS,LDT :999,~50 LU:,LDT "999,~0 Lb~*LDT -999,~50 LXTHeLDT .999,250 SS iLDT "999~250 LSHV,'LDT '999,250 $SHV,LDT 0999,250 NPHX,CNL -999,.250 RTNR~CNL 999,250 TNPH~CNL '~999,250 -999,250 RCFT,CNL -999,250 -999.250 NPOR~CNL .999,250 RCNT,CNL -999,;}g CAL~.CNL ~999,250 CFTC,~CNL, -999,2~0 GR,CNL .:999,250 ' 999,.250 MRES*CNb *999,250 MTEM,CNL -999,Z~ NTEN,CNb : 999.,~50 I9500000. CZLD,DTE ILD~DTE 13~270 ~bM.DTE 1950,000 I~QF*DTE 0,000 :IHGFeDTE 0,000 'XXRD,DTE .. -467'1~4 IIRM~DT'Z XIXM,DTE 1386:6~08 SFLUeDTE 5.,438 GR,DTE 42,4.84. T£N$;.DTE 2905*000 MTEN*DTE . .1,874 HTEN*DTE ~04~'273 DPHI,bDT -999.,250 RHOB~LDT 999,250 PEri, bDT' 999,250 QLS*bDT -999:,.250 GSS;*LDT -999,~50 ~999..250 LU.iLDT 0999,250 Lb,bDT -999,250 LXTH*LDT -999~250 -999,250 LSHV,bDT 99'9 2.50 SS~*LDT -999,250 SSH¥*LDT -999 250 bSR ,bDT 0999,250 LURH,LDT -999,250 CALI,LDT '-999.~250 -999 250 TENS, bDT -999~0 MTE:~,LDT -999,250 MRE$.*bDT -999~250 -999 250 NPHi.*CNL °999.250 RTNR,CNL -999,250 TNP~.*CNL .0999,250 -999 250 NPOR,CNL -999,.250 RCNT,CNL -999.250 RCF ,CNb .:~999,250 -999,250 CAbZ,CNL .~999,250 *999 250 CFTC,CNb -999.,:2~0 GR,CNb -999a~5~ -999 250 MRES~CNL -999,:250 MTEM,.CNL HTEN,CN~ .19~ 004 TEN$,CSG 2865,000 MRE$.CSG 1..7 MTEN,CSG 230 LZS Tape veriftcacton Listing SchlumbergerAlaslca Computlnq Center 5-DEC-lggl 09:18 PAGE: 25 DEPT. XMpH.DTE XIXD'DTE SP.DTE MRES.DTE DRHO.bD? LS.bDT S$1.bDT S1RH.LDT GR~bDT H?EN.bDT TNRA~CNL TEN$.CNb GR.CSG HTEN.CSG IMPH DTE IbM DTE IIXD DTE MRSP DIE SS~ bDT SIRH bDT GR bDT N~EN bDT TN~A CNT¢ TENS CNb GR C G HTE~ DEPT IbM DTE IIXD.OTE SP,DTE DRHO~LDT 'SS1~LDT $1RH.LDT GR~LDT HTEN.LDT TNR.A~CNL CNTC'CNL T~N$,CNb GR.CSG HTEN.CSG 2800.000 '999~250 '999,250 '999.150 '999.~50 -999 50 '999 250 -999 250 -999 ')50 -999 50 -999 250 -999250 -999 250 -999 250 '999~'~50 43.~12 1960,260 2700%000 -999,250 -999,250 -999,250 '999'250 -999~250 -999; 5o :999,2'50 ::999, 50 ~999~250 :999'250 999,250 -999~250 -999;.250 56,~92 2009,.025 2600,000 '999,250 ~999,250 .999.;250 .999,250 .999,,250 :99 ,25o 999~250 -999,250 -999~250 ~999~250 -999~250 ~999,,250 -999;.250 20~ '260 .475 CIbD,DTE ~D~F~DTE GR;DTE HTEN,DTE PEF*bDT LU~LDT SS2~LDT LSRH,LDT TENS, bDT NPHX,CNL NPOR~CNL CFTC,.CNL MRE$,CNL TEN$,CSG CI~D~.DTE XDGF~DTE IXRN,DTE H GR,DTE TEN*DTE PBF~hDT LU,~DT TENS~LDT NPHI,CNL N~OR,.CNL CFTC:~CNb MRES~CNL TENS.CSG -999,250 IDPH DTE -999.250 CIMP.DTE -,999.250 -999~ 5 ILD DTE 99.250 CXLM.DTE -999'250 IMOF DIE -999.250 IXRD.,DTE '999'250 '999, IIXM DTE '999,_250 SFLU.DTE '999.250 '999,: ~0 .'999. 250 50 TENS. DTE -999.250 MTEM-. DTE -999,1)50 RHOB~LDT '999,2~0 DPHX bDT .999.250 -999. Ol~$ bDT -999__50 QSS,LDT · 999.250 -999.2.0 ~. bDT -999.250 bXTH,LDT .-999. 250 -999 : 50 LSHV bDT -999.250 SSHV.LDT · 999, 250 LURHi, LDT -999.250 CALI.t. DT -999, 250 -.50 MTEM,LDT -9~i9.250 MRES,LDT -9992250 -999~ 250 -999,250 TNPH,CNL -999. 250 -999 RCNT.CNL -999,250 RCFT. .999~' 250 -999 ~$0 :GR,CNb -999,250 CAbZ. "'999, 250 MTEM, CNL -999,250 HTEN. 0999~ 250 ~?~ 000 MRES.CSG 1,e84 MTE#.~$~ 95, 491 :999,250 IDPH DTE '999'250 CiMP,DTE '999,250 XLD DTE -999,250 _ _C~M,D'E -999., 250 IlXN DTE -999;250 DTE -999,250 TENS DTE -999,250 r DTE '999'250 DPHX bDT '999*250 -999,2~0 LLiLDT -999,250bi. T~ bDT :999~250 LUR'.H,LDT :999;250 CALl LOT · 999,250 ~E~'~DT 999,250 HREt ~DT -999,250 R~NR,CNL: TNPk -999,250 RONT,,CNL 999,~5 RCF~ N~ C~] T999,250' HTEM~CNL -999,250 HTE~ 999,25o 999,250 '"999, 0 "999~250 "999,250 9,, 50 -999,250 99', 0 CXOP'DTE CXhD~.DTE I~GFiDTE IIRM,DTE GR,DTE HTEN,DTE PEF,~DT LU ~DT S$2 bDT LSRH bDT TENS bDT NPHI.;CNL NPOR.CNL CFTC.CNL TEN$.CSG '999,250 ',DTE '999,250 I~X.M,DTE -999 -999'250 T~N$,,.DTE -999 -999,250 DPH~.~DT -999 -999'250 '999,2:5~ LSHV,LDT -99~ :999'250 LURH*LDT -99 :999,250 -9 :999,250 GR.CNL 999;250 MTEM'CNL -99~ 2775,000 ~RE$'C6G 50 ~. 50 50 '.50 ~ $0 $0 : 2~0 ~$0 ~02 CXMP'DTE CXLM:*DTE XZRD~DTE SFU~DT MT~M;DT~ RHOB~LDT OSS.LDT LXTH.LDT SSHV.LDT CALZ.LDT ~RES.LDT TNPH.CNL RCFT.CNL CALI;CNL HTEN,CNb MTEM.CSG -999 2$o -9!)( ' -9!)~ :i~ , 0 '99!,250 ~999~250 -999~250 .999~ LIS Tape Verification blstlng Schlumberger Alaska Computing Center 5-DEC-199! 09=18 26 DEPT, I~PH,DTE IbM.DTE IIXD.DTE SP,DTE MRE$.DTE DRHO,LDT $$1.hDT $1RH bDT- GR bD? HT£N bDT TNRA CNL TEN8 CNb GR,CSG HTENoCSG Ib~ DTE XIXD DTE SP DTE MRE8 DTE DRHO bDT L$ LOT $$1. bDT $1RH bDT GR LOT 'HTEN LDT TNRA CNL CNTC~CNL TENS,CNb GR,CSG HTEN.CSG DEPT X'b" DTE XXXDDTE SP DTE MRE$ DTE DRHO bDT bDT $1RH bDT G~ bDT HTEN.LDT TNRA;CNb CNTC,CNb TEN$.CNL HTEN,CSG ooo ~250 -999 250 -999 250 ''999 25O -999 250 -999 250 -999 250 -999 250 ''999 -999 i50 50 -999 I 2400 000 -999 250 -999 250 ''999 250 ''999 250 -999 250 :999~250 ~999.250 999,~50 -999~250 -999,250 46,524 2045~240 ~300 oo 99 "9~9 50 '''999 ~999 ~50 -999 ~0 -999 *999 50 *999 50 -999,~50 -999 250 -999250 -999 25O -999 250 -999 250 5~ 706 20~ 367 CIDP DTE CILD DTE IDQF DTE IIRM DTE GR DTE HT~N DTE PEF bDT LU bDT 882 bDT LSRH bDT TENSbDT NPHX.CNL NPOR~CNL CFTC,CNL MRES. CNb TENS.CSG CXDP,DT~ CXbD,DTE IDOF~DT£ IIRM,DTE GR.DTE HTEN,DTE PEF,bDT LU,hDT S$.,bDT LSR~LDT TENSabDT NPHI.CNL NPOR~¢Nb CFTC,CNb TEN$.CSG CiDP'DTE CILD,DTE IDOF,DTE ~IR~,DTE GR.DTE HTEN~DTE PEF,LDT LU,bDT $S2,bDT LSRH,LDT TEN$~bDT NPHI,CNb NPOR,CNb CFTC,CNb -999250 -999250 ''999250 -999250 *999 250 -99925O -999250 -999250 ,,999 ~0 2 0 -9991150 -999 -999,2~0 *,999.2 0 .999.250 -999,250 2775. 000 '999,250 '999,~50 '999, ~ '999, "999..~50 "999, 50 '99' *99', gO ''999, 50 '999'i ~999~ 2 ,i :goo -99'~ 250 -99) 250 -99'),2 0 '999:2~0: -999.~50. "999'i50 ~999~ 50 "999 50 "999 '999 50 2675, O00 IDPH.DTE ILD.DTE IMOF,DTE IIXM,DTE TENS.DTE DPHI,bDT OLS.bDT Lb bDT LSHV bDT bURH bDT MTEM bDT RCNT GR CNL MTEM CNL MAES CSG IDPH DTE iLD DTE 'IIXM DTE TENSDTE DPHI bDT OLSbDT bb bDT .bSHV,bD~ bURN b T MTE~.b~T RCNT GR .~NL MTEM Nb MRE$ XDPH,DTE .ILD,DTE XMQF,DTE ~IIXM,DTE TENS,DTE DPHX-bDT Lb,.LDT LSHV,bDT LURH.bDT MTEM,bDT RTNR*CNL RCNT,CNL GR,CNL MTEM~CNb MRE$,CSG -999°250 -999.250 -999. '999~250 -999,250 -999.250 -999.250 :999;25o 999~ - 9:50 -999250 ,,,,999 ~ 50 I ~16 CXMP.DTE '''99' 250 CXLM,DTE '99' 250 IXRD,DTE '9' I~0 SFbUeDTE "~ 0 MTEM,DTE -99! 250 RHOB.bDT -99' 250 OSS,LD ~iTH.LOt --99"99'250250 $SHV.bDT -99 250 CAbI;LDT -99~ 250 MRE$.LDT -99' TNPH,CNL RCFT,CNL "999,2S0 CAbZeCNL '999,2S0 HTEN,CNL *999.250 MTEM.CSG 93,456 ,,,999' 250 CIMP~DTE :-999.250 -999250 CIbM,DTE .-999.250 -999250 RD,, DTE '*999.250 -999 !50 MTEM, TE -999,250. -999250 RHOB;LDT '999 S. 2 0 -999250 OSS,LD, -999.250 -999 ~50 8SHV,bDT -999 CAbl.bDT . 0 -999 ~0 MRES,bDT -999 TNPH'CNL '9 CALX*CNL -.9 ,2 0 :999 i 250 RH OB · bDT 9w,~~ ~ 0 ,250 LXTH*LOT -,, .,. · ~50 CALI*LDT 999.250 RCFT'CNL .: · 999 CALX;CNL '250 .HTEN,CNL '999, .99~.250 · 964 MTEM*CSG 9Z, Tape Vertttcat/on L/sting chlumberger AiasRa Computtng Center 5-DEC-X991 09=18 PAGEI 27 DEPT. IMPH DTE IbM DTE IIXD DTE SP DTE MRE$ DTE DRHO bDT 861 bDT S1RH LDT GR LDT HTEN bDT TNRA CNb CNTC CNb TENSCNb HTEN.CSG DEPT, X~PH'DTE 'bNeDTE XXXD.DTE SP,DTE MRES,DTE DRHO,bDT ,LDT SL~i'~LDT .bDT TN{ HTEN,.CSG DEPT.~ I~PN,DTE lbM,DTE IXXD'DTE SP'OT~ MRES,DTE DEHO.bDT L$.LDT S~RH.LDT TNRA CNb CNTC TEN$~CNL GE CSG HTE~ CSG 2200,000 -ggg 250 -99g 250 -g99,250 -999~250 -999,250 -999~250 -999 250 -999250 -999250 -999~250 -999250 -999 250 -999 250 -999 250 2100 000 -999 250 -999 250 -999250 -999 ~50 -999 ~50 -999 '999 -999 250 -999 250 '999 2055~994 o°0,oo0 999,250 ~999,250 -g99~250 :999, 5o .999'250 999~250 -999 !50 -999 }50 -999 ~50 -999250 -999,250 -999 25'0 -999 250 2072 102 CIDP.DTE CXLD,DTE IDQF,DTE IXRM,DTE GR,DTE HTEN,DTE PEF,LDT bU.bDT SS2, LDT bSRH~bDT TENS. bDT NPHX~ CNb NPOR~CNb CFTC~CNL MRES. CNL TENS CSG CXDP, DTE CILD. DTE IDQF DTE IlRM DTE GRDTE HTEN DTE PEFbDT LU bDT $8 LSR~ ~LDT bDT TENS*!DT N'PHX, Nb NPOR, Nb: CFTC. MRES;CNL TENS'CSG CIDP, DTE Ci.LD DTE IDOF D?E HTEN DTE PEFLDT LU:LDT 882 bDT LSRHbDT TENS bDT NPHi CNL NPOR CFTC CNb MEESCNb TEN$.C8G -999o250 XDPH.DTE -999.250 CIMPoDTE '999'250 -999.2~0 ILD,DTE -999,250 CXLN'DTE -999,250 -999.250 IMOF,DTE -999,250 XXRD,DTE -999, 0 '999,250 XIXM, DTE -999°250 SFbU.DTE -999.250 QLS.bDT -999-~u OSS,bDT -999,2~0 LSHV.LDT - .999.250 8SHV.LDT -999,250 -999.2i0 LURH,LDT 999.250 CALX,bDT '999,2i0 RTNR.dCNb -999~)~ TNPH,CNb '999,250 '999°2~0 RCNT,CNL -999 RCFT,CNb '999,250 '999,2[0 GR.CNb -999 CAbX,CNL '999.250 -999,2i0 MTEM,CNb -99~~0,250 HTEN ~9%2~0 -999, '999~ '999 '999 '999 '999 '999* '999' '999, 2590, 0 0 0 0 ZDPHeDTE XbD,DTE IM~F,DTE I'IX~,DTE TEN$,DTE DPHX':.bDT OhS bDT Lb bDT LSH¥ bDT LURH bDT MT,EM bDT ReNT CNb GE CNL MTE~:,CN~ MRES.iCS~. 'g99 250 -g99 -999 -999 -9 -9 -9 1 CIMP DTE 250 CXLM DTE 250 ZXRD DTE 25O SrLU.OTE -50 .D~E 50 MTEM RHOB~LD~ ~ 50 50OS$'LDT LXTH,LDT ~!50 :$SHV,LDT ~ 50 :C~L.X*LDT . 50 MRE$~LDT ~ 0 tlo CAL:I'CNL MTEM*CSG -999*250 .-999'250 'ggg,250 -999,250 -999'250 -ggg '999 -g99 '999 '999 -gg9 '99g ~999 '999 '999 '999 '999 ~999 ~0 0 :50 :50 000 IDPH,DTE IbD,D?E IMOF,:DTE IIXM,,DTE TEN$,DTE DPHX,LDT Ob$~bDT Lb, bDT LSHV:bDT bURHbDT MTEMbDT RTNRCNb~ RCNT, CNb GRCNb ~TEMCNb MR£$ CSG ... -gg~ -gg9 -999 -g99 -999 -999 ~9'99 -g99 -999 ,DTE SFLU~DTE 250 ~LDT , 5o ,bDT ,,:~SO TNPH;CNb ~50 RCFTiCNL ,~50 CAbX.:CNb ,~50 HTEN N~ :~97 MTEM ~S.,,' '"ggg,250 -999 -999 .,9 -gg~ ~gg9 8g ,693 Tape VerlAflcatlon bist~nq Schlumberger laska Computtnq Center 5-DGC-1991 09~18 PAGE: 28 DEPT. I~XD.DTE _SP.DTE DRHOeLDT bS.LDT SS!.bDT SIRN,LDT H?EN BDT TNRA CNb CNTC CNb GR CSG HTEN CSG DEPT Ib~ DTE IIXD DTE 8P DTE MRE8 DTE DRHO BDT $~RH BDT BDT BDT GR HTEN BDT TNRA CNb: CNTC CNb. TENS CNb GR CSG HTEN DEPT.~ IbM,DTE IIXP,DTE 8P.DTE · bDT GR,bDT H?EN.LDT TNRA CNb C~TCCNb T GR,,CSG HTEN,CSG 1900 000 -999 250 '999 ~50 '999 50 '999 250 "999 ~250 '999 .250 '999 250 -999 ,250 -999 -999 .250 -999 250 -999 250 999,250 _ 34,275 2078.854 1800'000 '999'250 -999,~50 '999, 50 '999' 50 999.' '999'~5 "999" -99 0 -99' 0 -999;250 -999,. ~0 2083,. !700,000 "999*250 ~'999,250 -999~250 -999,~50 -999,250 -999.250 -999,~50 '999 ,'250 "'999,250 ','999;250 -99! , 250 '99 , 250 -999,250 ' 9 9 9 · r2 5 0 43,755 2063.509 CIDP.DTE ClbD DTE IDOFDTE IIRM DTE OR DTE HTEN DTE PEr BDT bU bDT SS2 BDT bSRHbDT TENS bDT NPHICNb NPOR CNb CFT¢~CNb TENS, C IbD, DTE !DOF,DTE IIRM.DTE GR,DTE HTEN. DTE PEF, ,BDT SS2, bDT TN aPOR: Nb crTC CIDP:DTE CIbD..DTE IDOFDTE IIRMDTE GR, DTE HTENDTE PEF:bPT bU. bP? SS2,bOT LSRH.bDT TENS;BDT NPHI.,CNb NPOR,CNb CFT¢~CNL MRES~CNb TEN$,CSG -999,250 IDPH.DTE -999,250 CI~P.DTE -999,250 -999.250 IbD,DTE -999.250 CIbM.DTE -999.250 "999.250 IMQF,DTE -999.250 IIRD.DTE "999.250 -999,250 IIXM,DTE -999,250 SFLU,DTE -999, -999.250 TENS.DTE -999'~ :99~.25~ #T=NeDTE -999.250 DPHIebDT 99 ,25 RHOB.bDT -999;2 .999 250 QLS,~DT -999,250 G S -999.~5 -999 bb bDT -999,2,0 bi{" bDT ~$HV ~DT -999~2~0 ~D~ '999, SSHV bDT '999,250 ~URH SD? -999~250 CALl LDT -999~250 250 ~RES 250 250 250 250 250 250 000 :999 999 :'II -999 ~999 545 ~TEN RTNR RCNT GR MTEM NRES bDT CNL CNL CNL CNb -999~ -999~ -999: -999~ -999, 2 250 TNPH 250 RCF'T ~50 CALl 250 HTEN 023 NTEN BDT -999~250 CNL --999,250 CNL :-999 i50 -999;,50 -99 -99 -99 -99 -99 -99 -999 '999 '999 2440 25O 250 $0 XDPHDTE lbo DTE IMOFDTE IIX~ DTE TENS DTE DPHI bDT OhS bDT bb bDT LSHV LOT' LURH bDT ~?EM bDT RTNR CNb RCNT,CNb GR.CNb MTEM,,CNL MRES,CSG -999 250 CZMP,DTE -999;,.50 -999:250 CIL~.DTE -999~50 -999,250 $ b , '"999, -999.250 MTEM.DTE '999.i5i0~ -999~250 RHOB,bDT '0999, 50 -999 250 TH, DT -999, 0 CALl, :'999' TNPH, .999,2~0 -999,250 RCFT.CNL :999,250 " HTEN. MTEM.~ 999, 50 88,!60 -999,!;0 -999, ;0 '.999~ ;0 "999,; ;0 '999~i;0 -999~ ;0 "999~ ;0 '999. ~999~ '999~ 50 '999. 50 "999.250 '999.250 '999e250 2350,000 IDPH:DTE 'Ib.D,,;DTE ZMOF.D:TE '~IXM.DTE TENS,DTE DPHI*LDT OLS,bDT LL,LDT bSHV,LDT bURH*LDT MTEM.LDT RTNR*CNb RCNT,CNL GR,CNb MTEM,CNL MRE$,CSG -999, C:ILM..DTE -999, SFLU,DT~ -999~ 25¢ MTgM,,D~E -999.25~ '999, 999~;~5C OSS,LDT bXTH,LDT -999'25C SSHV';LDT ~999~2S0 .999,250 TN'PH;:CNL .999,250 .999,250 999,250 H~E~, CN~ 2'006 "999 250 '~50 -999 -999 m999.250 ~999 250 '-999 150 :-999 ~50 ':-999 ~0 "999 }50 :'999'210. · ~. '~99, "999,2 0 88,606 Tape Verlflcatton Listing lumDerger Alaska Computln~ Center 5-DEC-199! 09:18 PAGE: 29 D~PT Z~PH~DT£ lb~ DTE IlXD DTE SP DT~ MRE$ DTE DRHO ~$LDT $~! bDT $~RH bDT GR~bDT HTEN:LDT TNRRCNb C~TC~CNL ,CNb GR,,CSG HTEN,CSG D~PT, XMPH:DTE · ILN:,DTE IIXD:DT~ RSP DIE DRHO~bD? .L$;LDT GRiLDT .HTEN. LDT TNRA.CNL CNTC,CNb TENSeCNL GR.CSG X..~XD*DTE D~HOeLDT L$,LDT SSI.bDT $1RH.LDT Ge,LOT HTEN.;LDT TNRA*CNL CNTC*CNL T£NS,CNb GR*CSG HTEN'C&G 1600,000 '999.250 -999°~50 '999 250 -999 250 -999~50 -999 ~50 -999 250 -999 -999 250 -999 25O -999*250 29 20441116 150 ,000 -99~,~50 -999~50 -999,250 "999'250 ~999'250 '999; 50 '999~ -999i ~999, 250 2.0 -99!9:~250 *999,250 -999:,:0 '999.1~.0 57~944 206T~863 1400'000 -999.250 -999,2 -999,250 -999.250 -99 .gg~ '250 ,250 -999.250 -999'250 26~375 2058.849 CIDP~DTE CILD~DT£ IDOF, DTE IIRN~DTE GR~,DTE HTEN~,,DT£ bU~bDT TENS, bDT NPHX CNb NPOR CNb CFTC MRE& Nb TEN& SG IDP,DT · ILD,DT~ I'DOF;DTE ZRN.DTE GR..DTE HTEN.DTE $$2~,bDT LSRH.LDT TEN$~bDT NPOR.CNL CFTC,CNL MRES. C'NL TENSeCSG CIDP~,DTE CILD~DTE iDOF;DTE iIR~DTE GRiDTE HTEN~DTE PEFbDT bU bDT 882 bDT L&RHLDT TEN$bDT NPHX Nb NPOR CFTC CNL MRE$CNL TENS CSG -999~ -999. -999i -999 -999 -999 -999 -999 -999 0999 -999 '9~9 '999 "999 2305 250 5O 50 50 50 50 50 50 50 50 50 5O 5O 50 000 IDPH.DTE ILD.DTE IIXM,DTE TENS,DTE DPHIebDT OhS.bDT bbi,bOT bSHV,,bDT LURH~,bOT MTEM, LDT R~:NR, CNb tnb' ~RES CSO °999.250 CINP DTE -999.250 -999,250 IXRD.DTE -999,250 SFbU,DTE -999..250 MTKM,DTE -999.250 -999,250 OSS bDT -999,250 ~IIH~LDT -999.250 Y, LDT -999,250 CAbZ;bDT -999,250 HRES*LDT -999,2~0 TNPH,CN~ -999,250 RCFT,¢Nb -999,250 -999,250 2,033 -999 "999 '999 ;'999 '999 -999 °999 w999 · B9d 87 250 2 0 250 ,25O ;250 ~250 ,250 ,.250 ,720 '99,2~0 I'bD, DTE: 9i2~0 TENS. DTE: :2 ~ 8FbU:DIE 9.2,0 : ..o. -9 CibI bDT .-iD '9'9~50 ~N bDT ~ ~RES -999 TNPH.¢NL -9.9,2~0 RT~R CNL !0 -9 9,250 RCNT CNL -- -9 9.250 GR CNL -999,2~0 .CALI. CNL 227 5,000 MRES,CSG 20011 MTEN CSG .86,440 :999'250 ZDPHOTE '999'2,0' ClSP DTE -999,,250 TENS.OTB -999,:91:0 MTEMDTE *.9~9'250 DPHI.~DT :999,2[0 RHOBbDT ,999~250 -999,250 ObS,.bDT 999~:~i0 GSS;LDT .999,250 *'999'2~0 bb,bDT -9991~ iO blaH.bDT 999~50 -999,2~0 LSHV,.bDT -999,~0 $SHV bDT -999,250 ~999,250 ~URH.~DT -999,:2~0 CA~'bDT -999~250 -999~250 ~TE~.LDT' -999,;~0 MR~$~DT ~999,250 -999,250 RTNR,CNL -999.~0 TNPH~CNL ~999~250 -999'250 RCN?;CN~ ' ~999.250 RCF?,CN~ ~999~250 -999,250 GR,CNb ' .999'250 CALI..CNL "999,250 -999.250 H?EH.CN~ 999.'250 H?EN*.CN~ ~999,.250 2190,000 MRE$'.CSG 2.101 NTE~:eCSG bis Tape Yerlflcatton bistinq Schlumberger Alaska Computing Center 5-DEC-1991 09118 PAGEI 30 DEPT. IMPH.DTE ILM.DTE IIXD.DTE SP.DTE NRES.DT£ DRHO.bDT bS,bDT SSt,bDT S1RH.bDT GR,bDT HTEN.bDT NRA Nb NTC TENS CNL GR CSG HTE~ CSG I~PH MREI DTE DRH~ bDT bS bDT . DT TNRA.CNL CNTC;¢~b TENS.¢~b GR.CSG HTEN.CSG D~PT IMPH DTE IbM DTE IIXD SP~DTE MRES DTE DRHO bDT SSi bDT SIRH bDT GR bDT HTEN bDT TNRA CNb CNTC CNb GR HTEN CSG 1300 000 -999 150 ;50 -999 -999 250 -999 250 -999 ~50 -999 250 -50 -999 ~50 -999 ~$0 -999 -999 -999,250 -999*250 :999~250 999.250 34,755 2052,563 ~200,000 .999.250 999~250 -999,250 -999~250 -999.250 '999'250 '999,250 -999,'50 -999~50 '999. '999, 2049, CIDP DTE CIbD DTE IDOF DTE IIRM DTE GR DTE HTEN DTE PEF bDT $S2bDT GSRH bDT TENS.bDT NPHI*CNb NPOR,CNb CFTC,CNL ~RE$,CNL TENS,CSG ClDP.DTE CILD,DTE IDOFeDTE IIRN,DTE GR,,,,DTE HTEN,DTE PEF*hDT bU..bDT SS2'bDT bSRH,. DT TEN$,~DT NPOR, CFTC,CNb MRES, CNb TEN$;CSG -999, -999 -999 999 -999 -999 -999 -999 -999 -99g -999 -g99 -999 2100 250 IDPH.DTE 250 ILD,DTE 250 INOF,DTE 250 IlXN,DTE 250 TENS,DTE 250 DPHX'LDT 250 OhS.bDT 250 Lb,bDT 250 LSHV,b~T 250 bURH,b T 250 M?EN,bDT 250 RTNR,CNL 250 RCNT,CNb .50 ~SO GReCNL MTEM.CNb 000 MRES,CSG -999.250 '999.2500 -999.'25 -999.2-50 -999.250 -999, :50 :999. ~50 999 -999 -999 150 -999 5O °999 ~50 250 CIMP,DTE CIbM.DTE IIRD.DTE SFLU'DTE NTE#.DTE RHOB.bDT O$S,bDT LITHebDT SSHV.LDT CALl,LOT TNPH Nb RCr~ Nb CALl CN HTEN CS~ MTEH "999, '999, :-9991 '999~250 -'999,250 "999, 84. 250 IBD,DTE -999.250 CIbM*DTE .-999, I50 -999 250 IIXM,DTE .99~.250 SFbU~DTE :-999~150 -999 250 TENS:6DTE -999~IS0 .250 MTEM.DTE -999,2~0 DPHI,LDT -999,250 RHO~,LDT -999,250 QLS'bDT ~999,250 QSS*LDT ~-250 $SHV -999,250 '9!99,2:~0 RTNR~CNb -999',:~50 TN~H,CNL RCNT,CNb -999 RCFT,CNL -g99 MTEM,CNb : ,250 HTEN 2o o.ooo ,250 CiLD*DTE .,999~ 0 -999. 250 IOOF ;DTE -'9~9 ,: 5 -999~250 GR,DTE -999, -999,250 HTEN,~DTE -999~50 -999;250 PE;,~DT -999, -999 ~250 ~U,~D~ -999,2~0 -999:~ bSRH'LDT 999'250 =999 TENS* bDT '999,250 "999i250 NPHi*CNb '999,25,0 '999'250 NPO'R~,CNb "999.250 ~999,250 C~C*CN~ ~999'250 -999~.250 ~R E.S., CNG ~999,250 37,~84 TENS,C'SG 2060,000 IDPH~TE lbO, 'I. MQF~,DTEi iIXM. · PHI bDT bb~bDT LSHVbDT bURH*bDT MTEM,bDT RTNR,CNb RCNT,CNL GR,CNb MRES,CSG -99g -999 :999~250 999~.50 .999 ~,!50 -999~ 5O -999 ~$0 -99~,250 -999~250 -999 50 -999 66 IbM,DTE 'IZRD.DTE SFLU,DTE NTEM*DTE RHOB, DT OSS~DT ~I. TH~ 'SSHV,,bDT ,bDT MRES.bDT ?NPH~CNL Reft tnb CAbI CNL H~N -999;250 .~150 ~ggg~ *gg9 '"'iii -ggg 8.2 Tape verification Listinq chlumber.qer Alasl<a Computtnq Center 3! IMPH IbM IIXD SP MRES DRHO S1RH GR HTEN TNRA CNTC TENS DEPT~ XIXD MRE~ DRHO TNRA CNTC TENS HTEN DEPT IIXO SP MRES DRHO SSl, SIRH~ TNRA CNTC T~NS DTE DTE DTE DTE DTE LOT ,LOT bDT ,bDT ,LOT bDT CNL .CNL .CSG ,CSG DTE DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT DTE DTE DTE DTE DTE [,DT bDT bDT bDT bDT bDT CNL CNL 1000 000 -999 250 -999 250 -999 50 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 150 '999 :50 -999 50 '999,250 -999'250 -999,250 .900.000 .9996250 999.250 '999'250 '999*250 :999.250 999,250 -999~.250 -999 150 -999 50 -999 -999 ~50 -999 ~50 999, 50 999 2O 800 000 -999 250 · ,999 .'250 2 0 .999 -99 -9 ~ 250 -99 250 -999 2'50 ,,999 250 .,999 250 -999 250 -999 250 -999 2'50 -999 250 249 CIDP, DTE CXLD, DTE IDQF~DTE IIRM DTE GR. DTE HTEN DTE PEFbDT LU:LOT SS~LDT bSR bDT TENSebDT NPHX.CNb NPOR.CNb CFTC.CNL MRES.CNb TENS.CSG CXDP DTE CXLD DTE XDQF DTE IXRM DTE GR DTE HTEN DTE PEF bDT bU bDT NPHI NPOR Nb CFTC, Nb NRES~ Nb TENS CSG CIDPDTE CILD,DTE IPQF DTE IIRM DTE GR DTE HTEN DTE PEr bDT bU bDT 8S2 bDT LSRH bDT TENS bDT NPH! CNb NPOR CNL CFTC CNb MRES CNb TENS CSG -999.250 XDPH,DTE '999'250 ¢XNP'DTE -999.250 ILD.DTE -999,250 CXLN.DTE -999,250 -999,2 0 -999.250 IIRD.DTE -999,250 -999,2~0 IMQF,DTE IIXM.DT~ -999.250 SFbU,DTE -999,250 -999.250 TENS.DTE -999.250 MTEM.DTE -999,250 · 50 '999.250 RHOB,LDT 0999,250 '999.)50 DPHX,bDT -999,250 bb,bDT -999.250 b~TH.bDT -9!99;250 -999.250 SSHV.LDT -999 250 '999.2~0 LSHV.bDT '999,2-0 LURH.LDT -999..250 CALX.bDT :999,25o -,,,. RTNR 999.250 TNPH CNL -99g~$0 -999, MTEM CNb -999~250 HTEN~ -999 -999 -999 -999 .999 '999 '999 "999 '999 "999 '999 '999 "999 '999 -999 ~990 250 250 25O 25~0 ~$0 IDPH,DTB -999'~50 CXNP.DTE -999.250 I~D,DTE -999~250 CILM,OT£ 50 IM~F.DTE -999,250 TXRD.DTE -999,~0 IIXM,OTE -999,250 SrbU.OT' -999, _0 TENS.DTE -999,250 MTEM.DTE '-999, bS,~.bDT -99. 250 "?gM'CNb · 99 250 i -99 RCNT, Nb NTIS, Nb :~ CALt.CNL '999, MRES.CSG MTEM.CSG -999. '999, -999 -999., -999~ -999. -999 "999 999 -999 -999 -999 1990 5O 5O 000 ID~H DTE IM~ DTE IIX~ OTE TENS DTE Qb$.LDT bb.bDT bSH'V,bDT bURH.LDT MTEM.LDT RTNR.CNL RCNT,CNL GR.CNb MTEM.CNb MRES,CSG '999'~50 CX,P.DTE .:-999.=150 -999i250 CILM.:DTE ;'999,250 '999.250 IIRD,.DTE "999,250 -999,~$0 SFLU.DTE -999,250 -999.~50 MTEM,DTE -999'250 -999,,250 -99~,.~50 blaH.bDT ~-999 '999, 0 -999~250 SSH~*LDT '-999i!I! -999.2~0 C~LZ;LDT -999,:~50 RCFT,¢NL :999,250 HTEN,CN~ .999~250 99~'250 CALi,¢NL ;999,250 ;.215 MTEM;CSG 80.949 IS Ta~e verlfXcatlon t, Xstin.c chlumberqer Alaska ¢o~Put~ng Center 5-DE~-199! DEPT. IMPH.DTE IZXD DTB SP DIE MRE$ DTB DRHO bDT b8 bDT SS! LOT S1RHbDT GR,LD? H?BN.LDT T~RR,CNB C TC,CNb TEN&,CNb GR,CSG H?BN.CSG 700 000 -999 250 -999 250 -999 250 -999.250 -999:250 -999.250 -999 250 .999 250 -999 250 ~50 -999 -999 -999 250 -999 250 -999 2 0 36 2038 4e7 CIDP'DTE '999. 50 CILD.DTE '999.~50 IDPH.DTEx5D.DTE IDOF,DTE '999.i50 IHQF.DTE IIRM.DTE '999. 50 XIXM,DTE OR,DIE -999,~50 TENS,DIE HTEN.DTE -999, 50 DPHI.LDT PEF,LDT -999, 50 GbS,bDT bU.bDT '999.~0~ L6HV:.'bDTbb:'bDT SS2.bOT '999.~ TENS~bDT -999, 0 MTEM,LDT NPHI.¢NL -999.250 RTNR,¢NL NPOR'CNL -999;250 RCNT,CNL CFTC,CNL -999'250 GR.CNb MRE$, 1925,2 0 MTEM,CNb TENS.~ '999'0~0 NRES,CSG -999 250 CIMP.DTE -999 250 CXLM,DTE -999 250 XXRD.DTE -999 150 SFLUoDTE -999 MTBM.DTE -999 RHOB.LDT -999 ;0 GSS~L T -999 bXTH,L~T SSHV -999 .LOT -999 CALX~,LDT -999 MRES. -999 50 '99! iO w99! '99! '99! :'999 iNb "999~1 Nb '999, DEPT., .600,000 CZDP' DTE :999,250 'XDPH OTB -999.,250 I~_pH.DTB .999',250 CZbD DTB 999,250 I~D OTB -999,.~5P CILM,DT~ :-999, ~'50 ILM,DTE .999:,250 IDGF DTE -999.,250 XN F. 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T"RA.CNL *'999,250 NPOR~ CNL -9992~ ~:~ 0 RCNT,C*L CNTC,CNb -999~250 CFTC;.CNb GR,CNb :999,250 CAL~:,CNL :-999~ T~NS,CNL -999,,250 MRES~.CNL -999,2~0 MTEM*CNL 999~250 HTZN,CN~ -999~ GR,CSG 48'856 TENS.~CSG 18600000 MRES',.CSG: 26~158 MTEM,CSG 8t.~ · HTEN.CSG 2047,601 DEPT ,~ .500'.000 CXD.P.~.DTE -999,250 ,DPH~DTB '999'250 CXMP~'DTE IMPH ,DTE .999'250 CILD~.DTB '999.250 ILD~,DTE ~999~ 2r50 CILM,DTE IbM DTE ;999.,250 IDQF~DTE '999,250 XMQ:F, DTE ~999.250 iXRD,DTE ~'9 , 50 XiXD DTE 999'250 IIRM~.DTE -999.250 X.XXM,DTE 999*250 SFLU.DTE -999.,250 RSP DTE .999,250 GR~,~DTE 0999'250 TENS,DTE -999,~50 MTE~.DTE ~ ES DTE ~999.250 HTEN~DTE -9990250 DPHI,~DT 0999.250 RHOB.,LDT 0999,250 DRHO bDT ,999 250 PEF~LDT -999...250 QLS*bDT -999.250 GSS"LDT -999~250 L8 bDT .999 250 LU,.LDT ~999~250 LL,~DT ~999,250 LXTH*LDT -999,250 SSi .bDT -999 250 8S2~.LDT -999.250 LSHV~DT -999.250 SSHV,LDT: -.992509 ,.- GR., bDT -999 250 TBNS,bDT '-9~9,250 MTE~,LDT :999,250 MR. 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