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178-040
Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11AͲ08 50Ͳ029Ͳ20313Ͳ00 909572342 Kuparuk River Leak Detect Log with ACXField & Processed 13ͲSepͲ24 0 121BͲ20 50Ͳ029Ͳ23164Ͳ00 909462416 Kuparuk River Multi Finger CaliperField & Processed 15ͲAugͲ24 0 131CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 25ͲAugͲ24 0 141CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 25ͲAugͲ24 0 151CͲ24 50Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002 Kuparuk River Packer Setting Record FieldͲFinal 15ͲSepͲ24 0 161DͲ32 50Ͳ029Ͳ22982Ͳ00 909582494 Kuparuk River Multi Finger CaliperField & Processed 6ͲSepͲ24 0 171EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Leak Detect Log FieldͲFinal 8ͲSepͲ24 0 181EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Packer Setting Record FieldͲFinal 7ͲSepͲ24 0 191HͲ01 50Ͳ029Ͳ22330Ͳ00 909524903 Kuparuk River Multi Finger CaliperField & Processed 29ͲAugͲ24 0 110 1HͲ01 50Ͳ029Ͳ22330Ͳ00 909593144 Kuparuk River Plug Setting Record FieldͲFinal 23ͲSepͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39678T39679T39680T39680T39680T39681T39682T39682T39683T39683178-040203-115201-248200-173182-154193-00610/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:33:37 -08'00'178-040203 1151AͲ0850Ͳ029Ͳ20313Ͳ00 909572342KuparukRiverLeakDetectLogwithACXField&Processed13ͲSepͲ2401T39678 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-09-01_23051_KRU_1A-08_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23051 KRU 1A-08 50-029-20313-00 LeakPoint Survey 01-Sep24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 178-040 T39542 9/10/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 15:55:21 -08'00' STATE OF ALASKA ALOA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS AUG 3 4 2013 1. Operations Performed: Abandon Repair well plug Perforations Perforate Other Alter Casing W Pull Tubing Stimulate - Frac Waiver F Time Extension Change Approved Program rOperat. Shutdown Stimulate - Other Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ryExploratory r Stratigraphic Service 178-040 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20313-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25647 ` 1A-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6382 feet Plugs (measured) 5960 true vertical 6374 feet Junk (measured) 5861', 5973' Effective Depth measured 6315 feet Packer (measured) 5846, 5927, 6145 true vertical 6307 feet (true vertical) 5838, 5919, 6137 Casing Length Size MD TVD Burst Collapse CONDUCTOR 138 16 162 162 SURFACE 2220 10.75 2244 2243 7" TIEBACK 1937 7 1962 1962 PRODUCTION 4406 7 6364 6356 Perforation depth: Measured depth: 6001-6037, 6041-6046, 6050-6055, 6073-6084, 6134-6136, 6217-6227, 6233-6259 True Vertical Depth: 5993-6029, 6033-6038, 6042-6047, 6065-6076, 6126-6128, 6209-6219, 6225-6251 Tubing (size, grade, MD, and TVD) 3.5, J-55, 5892 MD, 5884 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 5846 MD and 5838 TVD PACKER - BAKER FHL PACKER @ 5927 MD and 5919 TVD PACKER - BAKER FB -1 PACKER @ 6145 MD and 6137 TVD NIPPLE - CAMCO DS LANDING NIPPLE @ 480 MD and 480 TVD 12. Stimulation or cement squeeze summary: SCANNED ��P 2 2013 Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory Development • Service Stratigraphic 16. Well Status after work: Oil , Gas VVDSPIL Daily Report of Well Operations XXX GSTOR r ` VVINJ r WAG j'"` GINJ T7 SUSP r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313-294 Contact Erik Nelson (aD. 263-4693 Email Erik. Nelson(d-)conocophillips.com Printed Name Erik N on Title Sr. Wells Engineer Signature Phone: 263-4693 Date Form 10-404 Revised 10/2012 VLF '''�9'�3 9/Ic/ i3 RBDMS SEP - 9 2 Submit Original Only LOCATOR, 5,819 -- TUBING SPACE OUT, 5,819 PBR, 5,822 PACKER, 5,846 FISH, 5,861 NIPPLE, 5,867 OVERSHOT, SASS NIPPLE, 5,903 LOCATOR, 5,905 SEAL ASSY, 5,905\ PBR, 5,905 PACKER, 5,927 CATCHER, 5,950 PLUG, 5,960 PRODUCTION, 5,965 FISH, 5,973 IPERF, 6,073-6,064 Acid Wash, 6,001 NIPPLE, 6, 130 SLEEVE, 6,130 CMT SOZ, 6,1346,136 Cement ue sqeze, 6,134 LOCATOR. 6.143 PACKER, 6,145 Post Tie -Back, 1,958-6.364 TD, 6,382 Tubing De "ph"' strmg 0... stnng lu ... lop tnnoi ser oeprn •••._ ,••,•••e ... --••••e ._,. ...._ TUBING WO 1986 4 1/2 2.867 5,904.9 6,167.5 6,159.2 9.30 L-80 BTC 3.5x2.875" Com let' Details Top Depth ._.._, iavwi Top Incl ID lin) x Other In Hole Wireline retrievable lu s, valves pumps fish, etc.) Top Depth (ND) Top Incl \ 5,973.0 5,964.8 2.70 FISH WRP IN HOLE 34" 1 L x ZJU UU x .aO/ IU ar O/ZV o 6,129.9 6,121.6 2.50 SLEEVE AVA TPI SET IN AVA NIPPLE 4/2/2003 Perforations & Slots Shot Top (ND) Btm (TVD) Dens T,...,avo. on.,,e fRKB1 (II I zone Date (sh- Type Comment jTVI RO N... Tnn lRKRI (RKB) I I(°I Make Model fN I Sery Type Type 11n) T (Pat) Run Date I Com... KUP PROD • 1A-08 Conoic( I't IIIIIps Well Attributes Max Angle & MD TD Inc.Wellbore Alas. -.... APVUWI 500292031300 Field Name KUPARUK RIVER UNIT Wellbore Status PROD In 5.66 MD MD(RKB) 2,689.99 Act Btm(ftKB) 6,382.0 ...- ••• SSSV nt NIPPLE HZS m (PP ) 95 D End D 9/52011 Last WO: 8/52013 KB 33.00 Rig a 8/30/1978 WeIICon-1A-088920138:48:16AM Schematic -Actual Annotation Depth (RKB) End Date Annotation Last Tag: 6,255.0 11222002 Rev Reason: WORKOVER Last Mod 8y osbod End Date 8/92013 ' HANGER 23 Casing Strings Casing Description CONDUCTOR String C... 16 String ID ... 15.062 Top (ftKB) 24.0 at Depth If 162.0 Set Depth (ND) ... 162.0 String Wt... 65.00 String ... H40 String Top Third ---- Casing Description SURFACE String 0... 103/4 String ID ... 9.950 Top (ftKB) 24.0 Set Depth If 2,244.0 Set Depth (TVD)... 2,242.6 String wL.. 45.50 String .- K-55 String Top Third CONDUCTOR, s; 24-162TIEBACK Casing Description PRODUCTION 7' String 0... 7 String ID ... 6.276 Top (ftKB) 25.3 Set Depth If 1,962.3 Set Depth (ND) ... 1,961.6 Strtng WL.. 26.00 String ... L-80 String Top Third TCII Casing Description String 0... String ID ... Top(ftKB) Set Depth (f... Set Depth (ND) ... String WL.. String ... String Top Third NIPPLE, 480 _. r, ... ; PRODUCTION 7 6.276 1,958.0 6,364.0 6,355.5 26.00 K-55 Post Tie -Back Tubing Strin s Tubing Description TUBING WO 2013 String 0... String III ... 31/2 2.992 Top (ftKB) Set Depth if Set Depth IT ... 22.8 5,892.1 5,884.0 String Wt... String ... 9.30 L-80 String Top Third EUE-m Com letion Details PRODUCTION r TIEBACK, 257,962 SURFACE, 24-2,244 Top Depth (TVD) Top(ftKB) (ftKB) Top Incl (°) Item Description Comment Nom!... ID (in) 22.8 22.8 -1.95 HANGER FMC GEN IV TUBING HANGER 2.992 GAS LIFT.480.0 2,531 480.0 0.44 NIPPLE CAMCO DS LANDING NIPPLE 2.875 5,818.8 5,810.8 3.03 LOCATOR BAKER LOCATOR 2980 5,822.1 5,814.1 3.01 PBR BAKER 80-40 PBR, 4" OD SEALS 2.990 GAS LIFT, 5,846.0 5,838.0 2.93 PACKER BAKER PREMIER PACKER 2.875 3,789 5,867.0 5,859.0 2.85 NIPPLE CAMCO DS 2.812 NIPPLE wIRHC PLUG SERiI-T0612329 2.812 5,884.7 5,876.6 2.79 OVERSHOT BAKER POORBOY OVERSHOT 5.98" OD x 3.62" ID —above Swallowed 3.620 6.9' of tbg stub. GAS LIFT, 4,713 Tubing Description TUBINGW02003 String 0... String ID ... 31/2 2.992 Top(ftKB) Set Depth (f... Set Depth (ND) ... 5,885.2 5,917.3 5,909.2 String Wt... String ... 9.30 L-80 String Top Third ABMEUE Com letion Details � •• Top Depth (ND) Too fRKBI (RKB) Top Incl V) Item Description Comment- Nomi... OAS LIFT, 5,381 1 - _ LOCATOR, 5,819 -- TUBING SPACE OUT, 5,819 PBR, 5,822 PACKER, 5,846 FISH, 5,861 NIPPLE, 5,867 OVERSHOT, SASS NIPPLE, 5,903 LOCATOR, 5,905 SEAL ASSY, 5,905\ PBR, 5,905 PACKER, 5,927 CATCHER, 5,950 PLUG, 5,960 PRODUCTION, 5,965 FISH, 5,973 IPERF, 6,073-6,064 Acid Wash, 6,001 NIPPLE, 6, 130 SLEEVE, 6,130 CMT SOZ, 6,1346,136 Cement ue sqeze, 6,134 LOCATOR. 6.143 PACKER, 6,145 Post Tie -Back, 1,958-6.364 TD, 6,382 Tubing De "ph"' strmg 0... stnng lu ... lop tnnoi ser oeprn •••._ ,••,•••e ... --••••e ._,. ...._ TUBING WO 1986 4 1/2 2.867 5,904.9 6,167.5 6,159.2 9.30 L-80 BTC 3.5x2.875" Com let' Details Top Depth ._.._, iavwi Top Incl ID lin) x Other In Hole Wireline retrievable lu s, valves pumps fish, etc.) Top Depth (ND) Top Incl \ 5,973.0 5,964.8 2.70 FISH WRP IN HOLE 34" 1 L x ZJU UU x .aO/ IU ar O/ZV o 6,129.9 6,121.6 2.50 SLEEVE AVA TPI SET IN AVA NIPPLE 4/2/2003 Perforations & Slots Shot Top (ND) Btm (TVD) Dens T,...,avo. on.,,e fRKB1 (II I zone Date (sh- Type Comment jTVI RO N... Tnn lRKRI (RKB) I I(°I Make Model fN I Sery Type Type 11n) T (Pat) Run Date I Com... ConocoPhiNKUP PROD ips ;; Alaska, Inc. CONDUCTOR,_ 24-162 NIPPLE. 480 GAS LIFT, 2.531 GAS LIFT, 3,789 GAS LIFT, 4.713 GAS LIFT, 5.361 GAS LIFT. 5.763 LOCATOR, 5,819-- TUBING SPACE OUT, 5,819 PBR, 5,822 PACKER, 5,846 FISH, 5.861 NIPPLE, 5,867 OVERSHOT, 5,88.5 NIPPLE, 5,903 LOCATOR, 5,905 SEALASSV, 5,905 PBR, 5,905 PACKER, 5,927 CATCHER, 5,950 PLUG, 5.960 PRODUCTION, 5,965 FISH, 5,973 - ,001PERF, 6-6,037 RPERF. 6, 041-6.046 RPERF, 6,0508,055 IPERF, 6,0738,084 Acid Wash, 6,001 NIPPLE, 6,130 SLEEVE, 6,130 CMT SQZ, 6,1345136 Cement squeeze, 6.134 LOCATOR, 6,143 PACKER, 6,145 SBE, 6,149 ;A 1 1A-08 33.00 vtau¢Iaatuna:Qc: �rvw NOTE: Fish tagged on 722/98 & pulled from 60&5' on ITZ9196 7/302003 Shot 10/132004 Top (ND) Btm (TVD) NOTE: WAIVERED WELL -"'WARNING"' GLVs ARE NOT ALLOWED Dens ni—we—=n WPII - IA v OA x FORMATION communication Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment 6,073.0 6,084.0 6,064.7 6 1, 1A-08 ,075.7 5 8/18/1978 4.0 (PERF Slimkone 6,134.0 6,136.0 6,125.7 6,127.7 UNIT B. 1A-08 1/4/1986 4.0 CMT Squeezed SQZ 6,217.0 6,227.06 ,208.6 6,218.6 A-5, 1A-08 8/12/1978 4.0 IPE RF Slimkone 6,233.0 6,259.0 6,224.6 6,250.5 A-4, 1A-08 8/12/1978 4.0 IPERF Slimkone Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 6,001.0 6,259.0 5,992.8 6,250.5 Acid Wash 529/1982 6,217.0 6,259.0 6,208.6 6,250.5 FRAC 1122/1981 Pumped gelled water in - sand Frac with 12/18 Carbolite ueezes Cement7Btm — Top Depth Btm Depth (ND) (ND) Top (ftKB) (ftKB) (ftKB) (ftKB) Description Start Date Comment 6,134.0 6,136.0 6,125.7 6,127.7 Cement Squeeze 1/5/1986 Notes: General & Safety 729/1998 NOTE: Fish tagged on 722/98 & pulled from 60&5' on ITZ9196 7/302003 NOTE: WORKOVER 10/132004 NOTE: SUSPECT FAILED TUBING IN JOINT BELOW UPPER PACKER @5927' 2/42008 NOTE: WAIVERED WELL -"'WARNING"' GLVs ARE NOT ALLOWED —.1— ni—we—=n WPII - IA v OA x FORMATION communication Pre -Rig Well Work 1A-08 Pre and Post Rig Well Worl* DATE SUMMARY 4/10/2013 UNABLE TO DRIFT PAST 184' SLM W/ 2.78" DMY WRP; DRIFT W/ 2.69 DMY WRP ( BOBBLE'S THROUGH @ 184') AND TAG FISH @ 5973' RKB; DRIFT TO 5973' RKB W/ SIMULATED GYRO AND 2.79" G -RING DRIFTS W/ NO PROBLEMS. COMPLETE. 4/23/2013 (PRE RWO): RIG WORK, T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), OC POT (PASSED), OC PPPOT (PASSED) FUNCTION TEST LDS ((IC LDS @ 3, 5, & 9 o'clock & OC LDS @ 3 o'clock positions are seized to the gland nut, soaked with Kroil and still would not move). 4/26/2013 (PRE RWO): MITIA- PASSED. 6/16/2013 FIRST RIH FOR BOTTOM HOLE PRESSURE. 30 MIN STATION @ 5960', PRESS: 2560 PSI, TEMP: 151 DEG F. 15 MIN STATION @ 5860', PRESS: 2558 PSI, TEMP: 147 DEG F. SECOND RIH W/ WRP. CCL TO MID -ELEMENT: 11', CCL STOP DEPTH @ 5939', PLUG SET @ 5950', SMALL TENSION BOBBLE AROUND 184' COMING IN AND COMING OUT OF WELL W/ WRP. WELL HANDED OVER TO LITTLE RED FOR PRESSURE TEST ON WRP. 6/17/2013 BLEED GAS OFF WELL PUMP; LOAD W/33 BBLS AND ATTEMPT MIT (FAILED). ENERGIZED FLUID AT SURFACE, RDMO TO LET GAS/FLUIDS SETTLE. IN PROGRESS 6/19/2013 MIT TBG 1500 PSI, PASSED. SET 2.70" x 88" CATCHER SUB @ 5930' SLM. ATTEMPTED PULL DV @ 5858' RKB. IN PROGRESS. 6/20/2013 PULLED DV @ 5857' RKB. ATTEMPTED BLEED TBG / IA TO ZERO: FILLED TWO BLEED TANKS, GAS CUT FLUID. PUMPED 28 BBL DSL, MIT TBG / IA 1500 PSI, PASSED. BLED TBG TO 250 PSI. DISCUSSED WITH ANC ENGR. COMPLETE. 6/26/2013 (RWO) BLEED IA GAS CAP. Post Rig Well Work 8/17/2013 ATTEMPT TO PULL 3" FMC STYLE BPV, ASSIST BPV CREW WITH PULLING H STYLE BPV, PULLED BALL & ROD IN RHC PLUG BODY @ 5867' RKB, PULLED SOV @ 5763' RKB, SET DV @ SAME, PULLED DV @ 5360' RKB. IN PROGRESS. 8/18/2013 SET OV @ 5360' RKB, PULLED DV's @ 4713', 3789'& 2530' RKB, SET GLV's @ SAME. GOOD TBG TEST. PULLED 2.81 RHC PLUG BODY @ 5867' RKB. ATTEMPT TO PULL CATCHER ON WRP @ 5950' RKB, RAN BAILER RECOVERED 1 qt OF METAL SHAVINGS & BRASS. — 13' OF TRASH ON TOP OF CATCHER. IN PROGRESS. 8/19/2013 BAILED 10' OF SCALE, METAL SHAVINGS & GRAVEL FROM TOP OF CATCHER, PULLED CATCHER ON WRP @ 5950' RKB, EQUALIZED & ATTEMPTED TO PULL WRP @ 5950' RKB WRP PULLING TOOL STILL IN HOLE). IN PROGRESS 8/20/2013 PULLED 2.69 WRP @ 5950' RKB (MISSING 2 1/2 ELEMENTS). MADE 3 RUNS AND RECOVERED 1 ELEMENT IN PIECES. COMPLETE. Conoc Phillips Time Log &Summary We/Niew Web Reporting Report Well Name: 1A-08 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 6/29/2013 3:00:00 PM Rig Release: 8/3/2013 12:00:00 PM 6/28/2013 hr summary �24 Lay derrick over. Prepare rig & modules for rig move. Wait on Peak trucks, as they were moving Doyon 141. Load Pits, Shop and Satellite camp on trucks, and mobilize to 1A pad. 00:00 20:00 20.00 pits, and mechanic shop to 1A pad. MIRU MOVE MOB P Lay down derrick and pull off well. Install berming, spot same. 01:30 05:30 4.00 Perform rig maintenance while wating MIRU MOVE MOB P Mobilize sub base from 1Q pad to 1A on trucks to move. 20:00 21:00 1.00 pad with escort. DEMOB MOVE RURD P Rig released 6-27-13 23:59 HRS. MIRU MOVE MOB P Set matting boards, and spot rig over Held PJSM - lay derrick over. Prep well 1A-08. 07:30 09:30 2.00 rig for rig move. MIRU 21:00 01:00 4.00 Set herculikte and matting boards, MIRU MOVE MOB P Move Camp Downey, shop and pit spot & set Pit module. Release module to 1A pad and set up. 01:00 13:00 12.00 trucks. DEMOB MOVE MOB P Continue prep rig and location for rig MIRU MOVE MOB P Rig up, installing all interconnect move. Wait on Trucks from Peak, as lines, berming herculite, and set they were moving Doyon 141. Trucks cuttings tank. Begin setting and on location 1300 HRS. 13:00 17:00 4.00 berming bleed tanks. DEMOB MOVE MOB P Spot trucks , and load rig pits, MIRU MOVE MOB P Continue rig up and installing berms, Mechanics shop and Satellite camp. and cuttings tank. Rig accepted at Move rig off of well to allow the rig 1500 HRS. readv to take on Brine. pits to get by the sub base. 17:00 20:00 3.00 MIRU MOVE MOB P Wait on Change out. Security asked that we wait to get modules on the road, to allow for change out of CPF3 crews. Continue clean location and haul truckable loads to 1A pad. 20:00 00:00 4.00 MIRU MOVE MOB P Move 3 impassable loads form 1Q pad to 1A pad with escort. 6/29/2013 Continue mobilize rig modules from 1Q - 1A pad. Spot Satellite camp, shop and pit module. Move Sub base form 1Q -1A pad, and spot over well. Rig up on 1A -08. Rig accepted at 1500 HRS, ready to take on Brine. RU FMC to pull BPV. 00:00 01:30 1.50 MIRU MOVE MOB P Continue mobilize Satellite camp, pits, and mechanic shop to 1A pad. Install berming, spot same. 01:30 05:30 4.00 MIRU MOVE MOB P Mobilize sub base from 1Q pad to 1A pad with escort. 05:30 07:30 2.00 MIRU MOVE MOB P Set matting boards, and spot rig over well 1A-08. 07:30 09:30 2.00 MIRU MOVE MOB P Set herculikte and matting boards, spot & set Pit module. Release trucks. 09:30 12:00 2.50 MIRU MOVE MOB P Rig up, installing all interconnect lines, berming herculite, and set cuttings tank. Begin setting and berming bleed tanks. 12:00 15:00 3.00 MIRU MOVE MOB P Continue rig up and installing berms, and cuttings tank. Rig accepted at 1500 HRS. readv to take on Brine. r_1 Time L��JS T n ='3 Pi IN" ,, aM��1X ��11=�^.r Date « From I. To» .. Dur S. De th E. De "fh base Code y" Subcode T onimenfi 15:00 19:30 4.50 MIRU MOVE RURD P RU tuggers, manrider; bridals lines, assembly cattle chute, RU blocks after raising the derrick. 19:30 20:30 1.00 MIRU MOVE PRTS P Pressure test lines and surface equipment to 3500 psi. RU hoses and equipment in the cellar. 20:30 21:30 1.00 MIRU MOVE RURD P Secure and check all lines to the wellhead for bleed -off operations. Tighten fittings to cure leaks. 21:30 22:30 1.00 MIRU WHDBO RURD P RU lubricator and pressure test to 1000 psi -good. 22:30 23:30 1.00 MIRU WHDBO MPSP P Attempt to pull BPV with lubricator and the lubricator could not overcome the pressure under the BPV - 800 psi. 23:30 00:00 0.50 MIRU WHDBO MPSP P Lubricator failed to pull BPV, got bigger pump and put on lubricator. 6/30/2013 Pull BPV and shut in for Initial pressures; Tbg = 950 psi, IA = 420 psi. Bled off gas and fluids to static well, circulated 9.6 ppg brine around; well static. Perform tree valves work and ND tree and remove. NU BOPE. 00:00 00:30 0.50 SURPRI WHDBO RURD P Pull BPV and RD lubricator. 00:30 02:30 2.00 SURPRI WHDBO RURD P Rig up lines to bleed off pressures on well; IA = 420 psi, Tbg = 950 psi initial pressures after pulling BPV. Vent off gas and fluids to the Tiger Tank; final pressures; IA = 20 psi, Tbg = 0 psi with returns of 56.5 BBLs in the TT. 02:30 05:30 3.00 SURPRI WHDBO CIRC P Reverse circulate in 9.6 ppg to remove diesel from tubing at 2 BPM with 140 psi. Continue to circulate until 9.6 brine on returns. Pump 250 BBL with 250.9 BBLs returned to tiger tank. 05:30 06:00 0.50 SURPRI WHDBO CIRC P Blow down lines to tiger tank and RU to tubing taking returns to the rig pits. 06:00 07:30 1.50 SURPRI WHDBO CIRC P Pump taking returns to pits and down the tubing; 210 GPm with 610 psi. Pump surface to surface and check for flow; flow observed. 07:30 10:00 2.50 SURPRI WHDBO CIRC P Pump taking returns to pits and down the tubing; 210 GPm with 610 psi. Pump surface to surface and check for flow; no flow - Static. 10:00 11:00 1.00 SURPRI WHDBO PRTS P Pressure test tree, install BPV and test 1000 psi for 10 minutes - good. 11:00 12:00 1.00 SURPRI WHDBO RURD P ND tree, blow down all lines, clean and clear cellar. 12:00 13:30 1.50 SURPRI WHDBO RURD P ND tree. 13:30 16:00 2.50 SURPRI WHDBO RURD P ND/RD flanges IA and OA valves; install 3 1/8: 5K valve on each. 16:00 16:30 0.50 SURPRI WHDBO RURD P Lay down tree and adapter. Page 2 -of -4411 Ah • 'time Date" "From! '7d"" _ Oar' ko4 5. Det �. De th Phase Code Subcode T Oommer�t '' m Z;. 16:30 17:00 0.50 SURPRI WHDBO RUNL P install flanges on IA and OA valves; Valve shop crew attempts to pull VR plugs. Unable to connect lubricator to valve. 17:00 18:00 1.00 SURPRI WHDBO RURD P FMC rep install 3 1/2" blanking plug 12 1/2 RH turns on ACME top threads = 10 LH turns, set DSA. 18:00 19:00 1.00 SURPRIJ WHDBO RURD P Work on removing VR on IA, remove OA VR plug. 19:00 22:30 3.50 SURPRI WHDBO RURD P NU stack while attempting to pull IA VR plug. Success at 20:00 hours. Install AUX IA and OA valves and 1502 flanges. 22:30 00:00 1.50 SURPRI WHDBO RURD P Change lower rams to 7" rams. D7/01/2013 Testing BOPE; 250/3000 with 3 1/2" and 7" test joints. Performed Koomey draw -down tests - pass. All tests passed with the exception of CH 14 that was greased and exercised and passed. After discussion of hanger size; 13 5/8" and stack size 11" a larger stack was ordered out and the 11" stack was ND. Well Static. 9.6 PPG brine in hole. BPV set. The 13 5/8" stack was assembled and put on the well. Continued to nipple up stack as stack arrived on location. Rig put on hi hline power at 15:00. 00:00 01:00 1.00 SURPRI WHDBO BOPE P Continue changing rams to 7" solid body in lower set. 01:00 02:30 1.50 SURPRI WHDBO BOPE P PU test joint 3 1/2", TIW and Dart to ported blank sub. MU top drive to test joint and fill stack with water. 02:30 08:00 5.50 SURPRI WHDBO BOPE P Test BOPE; UVBR, valves, air IBOP, upper kelly hose valve, FOSV and inside IBOP. Super and manual chokes, HCR, kill line stand pipe. Perform accumulator tests - pass. LD FOSV to topdrive assembly. test annular, chokes and botom rams 7" - pass. 08:00 08:30 0.50 SURPRI WHDBO RURD P LD test joint, rig down crossovers and RU on choke. 08:30 10:00 1.50 SURPRI WHDBO BOPE P Test blinds, inner and outter valves - pass. LD test tool and blow down lines, clear floor. 10:00 10:15 0.25 SURPRI WHDBO SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to ND and remove 11" x 5M BOP stack. 10:15 18:00 7.75 SURPRI WHDBO RURD P ND 11" x 5M BOP's. Drain stack, remove riser. Note: Rig moved to Highline power @ 1500 HRS 18:00 18:15 0.25 SURPRI WHDBO SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to NU and install 13 5/8" x 5M BOP stack assembly. 18:15 00:00 5.75 SURPRI WHDBO RURD P NU 13 5/8" stack. 7/02/2013 NU 13 5/8", valves, control lines, kill lines, mud cross, install test spool, install riser and install rams; 3 1/2"x6" Top, 7" Bottom. Torque all bolts on stack and flanges. Function test all rams and annular. Perform body test on stack: Good. BOP test waived at 20:45 by AOGCC Rep. Jeff Turkin ton. Page3 of 44 Adk a Time Logs t} 0. Date From x4Tr °Dut 5. DeP th E De th Phase Code Subcode T„!u�Oomment ” 00:00 05:30 5.50 SURPRI WHDBO RURD P Continue to build BOP stack; NU BOP, install annular, install testing spool, install secondary valves. 05:30 06:00 0.50 SURPRI WHDBO SFTY P Safety meetings before picks on stack and setting spool. 06:00 11:30 5.50 SURPRI WHDBO RURD P Tighten all connections on stack flanges and connections, rig up Koomey lines. 11:30 12:00 0.50 SURPRI RIGMNT OTHR P Rig maintenance; service crown and skate. 12:00 16:00 4.00 SURPRI WHDBO RURD P Torque bolts on choke line, check torque on all stack bolts, MU kill line and install riser. 16:00 18:00 2.00 SURPRI WHDBO RURD Function test HCR's, annular, rams and MU crossovers to test joints 3 /12" and 7". 18:00 18:30 0.50 SURPRI WHDBO SFTY P Safety meeting for installing rams, blinds. Top VBR 3 1/2x6" and bottom 7". 18:30 22:00 3.50 SURPRI WHDBO RURD P Install rams; 3 1/2"x6" VBR in upper cavity, blind rams and 7" in the lower cavity. Grease manual kill, choke valves and HCR valves 22:00 23:00 1.00 SURPRI WHDBO RURD P PU test tools and RU to test BOPE; BOP test waived at 20:45 by AOGCC Rep. Jeff Turkington. 23:00 00:00 1.00 SURPRI WHDBO BOPE P PT Annular with 3 1/2" test joint, all flange breaks from stack change, CH #14 and kill to standpipe manifold. 7/03/2013 Continue BOP test; Pass. Pull BPV and rig up to pull tubing. Attempt to pull seal assembly f/ PBR- unsucessful. RU a line to cut mid jt of first full jt above seals, RI w/ string shot (160 gpf) to 5887', POOH w/ string shot -fired OK. 00:00 03:00 3.00 SURPRI WHDBO BOPE P Test BOPE: 250/3000 psi, Test with 3 1/2" UVBR, full shell test on choke manifold for 5 minutes each = Pass. With 7" test joint tested LPR and Annular 250/3000 psi for 5 minutes each = Pass. Drawdown test; mainfold=1640psi, ANN=1300psi, Start=3000psi, After closing= 1750psi, Initial 200psi=15 sec, FULL recovery 87 sec, closing times: UPR=6sec, Blinds-SIM=6sec, LPR-SIM=6sec, ANN=15sec, HCR CH=1sec, ELEC recovery=53sec, AIR recovery=260sec, 5 BTL @2000 psi. Test Blinds; 250/3000 psi for 5 minutes each. 03:00 03:30 0.50 SURPRI WHDBO RURD P Lay down test joint and Blow down lines and RD from testing. 03:30 04:00 0.50 COMPZ RPCOM RURD P Mu 10' pups for pulling hanger, Drain stack and Pull 3" ISA BPV as per FMC rep. Well static. 04:00 04:30 0.50 COMPZ RIGMN7 SVRG P I Service rig. Page 4 of 44 04:30 06:30 2.00 COMPZ RPCOM RURD P Rig up to Pull FMC 13-1/2" OD hanger. Install long bales, install crossovers & floor safety valve to (3) 3-1/2" pup joints made up as landing joint. Screw into FMC hanger. Upper LDS @ 23.32' RKB. 06:30 07:45 1.25 COMPZ RPCOM OTHR P Back out FMC lockdown screws on the tubing hanger (Upper LDS @ 23.32' RKB.). Back out lockdowns to 3-3/4" from flange= 1/4" inside of bowl. 07:45 09:15 1.50 COMPZ RPCOM PULL T Pick up on string, unseat hanger from load shoulder w/ 105k on weight indicator. With 115k, pipe moved 1' 3" at surface. Gradually increase pull to 130k w/ 2'6" movement at surface. SO weight appears to be 72k. Note: After making a line cut @ 5887', PU wt was actuallly 87k. Had 53k overpull trying to pull seals. 09:15 10:45 1.50 COMPZ RPCOM PULL T Pumping 10 bpm w/ 1260 psi trying to work seals free, pulling to 130k on wight indicator to 2' 10" above the floor. Pulling 140k on weight indicator, pumping 537 gpm w/ 2270 psi, 52% flow% to get hydaulic assist to pull seals free from PBR. 10:45 12:00 1.25 COMPZ RPCOM PULL T Drain stack, observed hanger hanging up in lower BOP ram cavity. Using tugger and EZ torque, center hanger in BOP stack. Continue pumping/pulling, gaining a little. Had a total of 4'9" movement above rig floor w/ 140k on weight indicator, while pumping 537 gpm w/ 2270 psi. 12:00 17:30 5.50 COMPZ RPCOM PULL T Continue working pipe to free seals f/ PBR. While pulling up to 140k on weight indicator. Pumping as much as 586 gpm w/ 3000 psi. Had as much as 6'9" movement @ the rig floor. Worked pipe up and down, having to stop pumping, drain stack, center hanger in BOPs, then pull and pump again. Hanging up in next ram cavity (Blind Rams). Called f/ E-line crew to cut pipe. Continued to work string to free seals while crew mobilized to location. Unable to pull seals free w/ 140k on weight indicator. Set pipe in slips w/ 95k on weight indicator. Break off top pup joint. 17:30 19:00 1.50 COMPZ RPCOM RURD P Set tubing on slips with 20K pull. Rig down long bales on top drive to short bales. Spot Halliburton E-line unit. r1 - Time Logs77 F. Date From To •,„..` Dur S..De th }`. De th Phase Gode Subcocle Aft ��i iVJE4'' - 9h"°"J' Tr. Commeit 19:00 19:15 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on rigging up E -line. Discussed overhead loads and rigging. Personnel assignments and duties. 19:15 21:00 1.75 COMPZ RPCOM RURD P Rig up Halliburton E -line equipment. 21:00 22:30 1.50 COMPZ RPCOM ELNE P RIH w/ string shot and Collar locator, RIH and fire shot at 22:10 hrs at a depth of 5887' WLD. Pull out of hole. 22:30 00:00 1.50 COMPZ RPCOM ELNE P I Lay down String shot and MU RCT with anchor assembly. 7/04/2013 Complete E -line run to cut tubing; successful. Pull tubing free; PU = 87K, SO = 63K, circulate and RD E -line equipment. Pull and lay down tubing to cut joint. Monitor well = Static. Total LD = 184 joint 3-1/2", 2 Pup joints and 5 GLM with pups top ;and bottom, 1 nipple and 14.51' cut joint. MU Baker BHA #1; scraper with min. OD 5.826". RIH and stack out at 145'. Decision made to LD drill collars and PU HWDP for flexibility. 00:00 01:30 1.50 5,887 5,887 COMPZ RPCOM ELNE P MU RCT and run in the hole, correlate to depth and fire cutter at 5887' WLD. WL tension showed decrease of 450 lbs at shot. Correlation of connections on the trip out showed 4' higher than trip in for shot with a good indication of tension release heard on the rigfloor. Pulled out to lay down RCT. 01:30 03:30 2.00 5,887 5,854 COMPZ RPCOM ELNE P LD RCT and RD E -line to standby. Latch on tubing landing joint and pulled free with tubing; PU = 87K, SO = 63K. Pull hanger to the floor and break out. MU to topdrive for control and complete RD of E -line. 03:30 04:00 0.50 5,854 5,854 COMPZ RPCOM FISH P Attempt to fish hanger seals out of stack and recovered 1/2 of the ring. Fill stack and circulate BU. 04:00 04:15 0.25 5,854 5,854 COMPZ RPCOM SFTY P PJSM for laying down tubing. Discussed pinch points and line of fire. Good communications and overhead loads, escape routes and wo ing together. While Circulating. 04:15 05:00 0.75 5,854 5,854 COMPZ RPCOM CIRC P Circulation; stage up to 414 GPM with 1200 psi at 171 strokes getting 44% flow returns and no gas at bottoms up. SPR #1; 2 BPM = 60 psi, 3 BPM = 120 psi. SPR #2-12 BPM = 60, 3 BPM = 1200 psi. Complete E -line RD. 05:00 07:30 2.50 5,854 4,616 COMPZ RPCOM PULL P Lay down 3 1.2" 9.3# tubing from 5887' to 4616'. PU = 85K, SO 63K. 07:30 08:30 1.00 4,616 4,616 COMPZ RPCOM FISH P Drain stack and fish out hanger seal ring. 08:30 12:00 3.50 4,616 2,012 COMPZ RPCOM PULL P LD tubing from 4616' to 2012'; PU = 57K, SO = 35K. 12:00 13:00 1.00 2,012 1,980 COMPZ RPCOM PULL P Pull tubing from 2012' to 1980' having I troulbe with GBR tongs. Page 6 of 44 Ah - Time dogs w NA" o.. Date From' To Dur. De th E.De th Phase Code SubcodeT Commant ''' 13:00 16:00 3.00 1,980 1,980 COMPZ RPCOM PULL T Casing tongs power head failure; wait on tong die retainer bolts from Deadhorse. Perform KWTD, service top drive. 16:00 17:00 1.00 1,980 1,097 COMPZ RPCOM PULL P Pull tubing from 1980' to 1097' increase in drag of 5K 17:00 18:00 1.00 1,097 1,097 COMPZ RPCOM PULL P Drain stack and check stack for obstruction; confirm stack is clear of obstructions that could cause increase in drag. 18:00 19:30 1.50 1,097 0 COMPZ RPCOM PULL P Pull and lay down tubing to cut joint from 1097' to surface. Monitor well= Static. LD 14.51' cut joint. Total LD = 184 joint 3-1/2", 2 Pup joints and 5 GLM with pups top ;and bottom, 1 nipple and cut joint. 19:30 21:00 1.50 0 0 COMPZ RPCOM RURD P Break down landing joints, RD safety valve X/O, change elevators, RD GBR tbg equipment. 21:00 22:00 1.00 0 0 COMPZ RPCOM RURD P I Bring Baker tools to the floor and stage for BHA. 22:00 00:00 2.00 0 145 COMPZ RPCOM PULD P MU BHA #1 per Baker rep. and RIH to 145' and stack out on weight. Decision made to LD DC and PU HWDP. 7/05/2013 Continue to ream in the hole with 7" casing reamer to 5884' and tag cut tubing stump. Pull up to 5882' and reverse circulate hole clean with 9.6 ppg brine with lube pill. Pull out of the hole and found the 7" scaper, bit sub and muleshoe were left in the hole. The same BHA components were run in the hole to engage the 3-1/2" REG connection. The string was run in the hole to 144' and was rotated in an attempt to engage fish at the highest point in the casing where extra drag was encountered. Three attempts were made at shallow depths to engage the fish without success. The string was then run in the hole. 00:00 00:30 0.50 145 0 COMPZ RPCOM RURD P LD drill collars and PU HWDP to make drill string more flexible. 00:30 01:30 1.00 0 195 COMPZ RPCOM TRIP P RIH with BHA and stack out at 143'. Screw in topdrive and ROT 10 RPM, 1-2 Torque, ROT and RIH to stack out at 175'. ROT from 175' to 195' and attempt to continue. Would not go in without rotation. Discuss with town and decide to continue the same. 01:30 06:00 4.50 195 1,252 COMPZ RPCOM REAM P Push to 285' and stack out with no progress. Start Rotating in the hole at 20 RPM with 2K torque; PU = 70K, ROT = 40K. 06:00 08:30 2.50 1,252 2,071 COMPZ RPCOM REAM P Run in ;the hole rotating 25 RPM with 4K Torque from 1252' to 20711', PU = 110K, SO = 28K. All DP drifted 2-3/8" going in the hole. 08:30 12:00 3.50 2,071 5,573 COMPZ RPCOM TRIP P Trip in the hole on elevators from 2071' to 5573% PU = 200K, SO = 62K. Running in with string vibration due to friction and drag. 12:00 12:30 0.50 5,573 5,884 COMPZ RPCOM TRIP P Trip in picking up singles to 5884' DP depth and tag on cut tubing stump. PU = 195K, SO = 74K. Tagged up on stump with 5K down weight. Page 7 of 44 r7 Tame Logs ,i T -0 men Dater From' To Dur' S. De th E. De th°Phase Code •..`Suboode 12:30 13:00 0.50 5,884 5,882 COMPZ RPCOM RURD P Pick up to 5882' to perform 1 circulation. RU to reverse circulate. 13:00 15:00 2.00 5,882 5,882 COMPZ RPCOM CIRC P Reverse circulate Lube pill; 106 strokes, 257 GPM with 1720 psi. 327 BBL on circulation. RD and blow down lines. Monitor well - Static. 15:00 20:00 5.00 5,882 0 COMPZ RPCOM TRIP P Trip to surface standing back DP. At the surface the BHA was found to be missing the 7" Scraper, double pin crossover and the bullnose muleshoe; 6.49'. These tools were left downhole. Inspection of the threads and connector showed that the 3-1/2" REG connection had backed -off leaving the threads in good shape, no damage seen. 20:00 21:00 1.00 0 0 COMPZ RPCOM TRIP P Monitor well - Static. Lay down the remainder of the BHA to make a plan forward assessment. 21:00 00:00 3.00 0 0 COMPZ RPCOM FISH T Decision made to run in the hole with the same BHA components replacing the first stand of HW with a stand of drill collars to assess if the stiffer assembly would make it through the tortuous casing. Tripped in to 145' with indications of weight an attempt was made to engage the fish without success. Tripped in to 144' and began rotation; 20 RPM with 1-2K torque rotating down to 159' with a torque increase 2-31K. POOH without recovery. Trip in the hole to 144' and rotated to 208' with a torque increase 34K. POOH without recovery. 7/06/2013 Trip in the hole rotating to 1900' then tripped on elevators to bottom to engage fish. Tagged up at 5878' plus 6.5' fish is the located tubing cut joint at 5884'. Rotated string to engage connection with 5K down weight on fish. Pullout of the hole rotating 10 RPM with 6K Torque to assure any purchace on the fish is not lost. At the surface the scaper was recovered but the bullnose and DP crossover were not; still in the hole. RU HES E -line and run in the hole with the Caliper logging #1 assembly; successful. The RCBL logging #2 assembly was run in the hole to bottom to log cement boundaries. 00:00 04:00 4.00 0 5,787 COMPZ RPCOM FISH T Trip in the hole with bit sub on bottom, using it for the fishing screw-in sub. Rotate from 150' to 1622'; unable to trip on elevators; ROT 20 RPM. Continue on elevators to 5787', PU =185K, SO = 70K, Rot = 115K with 15 RPM and 8K torque. 04:00 04:30 0.50 5,787 5,877 COMPZ RPCOM FISH T Trip in slowly and tag tubing cut joint at 5877' DP depth. Applied 5K down weight and rotated maintaining weight. Pickup while rotating 15' off tubin cut; Rot PU = 185K. 04:30 10:00 5.50 5,877 22 COMPZ RPCOM FISH T Trip out of the hole, rotating; BROOH with 15 RPM, 6-7K torque, PU = 150K while pulling. Pull to jars. Page 8 q# 44 Ah rl bate From' To ' Dur i ' S. De th E. De th Phase Code Subcode` -04 .�T !Commenter. 10:00 10:30 0.50 22 0 COMPZ RPCOM FISH T Lay down recovered scraper without Double Pin XO and Bullnose (TOF @ 5880.84' DPM); still in hole. 2.16' of fish remain in the hole on the cut joint. 10:30 12:00 1.50 0 0 COMPZ RPCOM ELOG P RU E -line; run 3 1/2" test donut in the hole and set. Spot E -line unit and RU. 12:00 14:00 2.00 0 0 COMPZ RPCOM ELOG P Continue RU of E -line unit and equipment. 14:00 17:00 3.00 0 0 COMPZ RPCOM ELOG P Run #1 E -line; 40 Arm Caliper and CCL. Toolstring: 1-7/16" cable head w/ 1.375" fishing neck, swival, telemetry cartridge, adapter, knuckle jt, collar locator, knuckle jt, roller centralizer, 2-3/4" OD multifinger imaging tool, roller centralizer, bullnose = 25.37'. Run to bottom (5862' WLM) and log out to surface. 17:00 20:30 3.50 0 0 COMPZ RPCOM ELOG P Lay down #1 E -line; 40 Arm Caliper and CCL. 20:30 00:00 3.50 0 0 COMPZ RPCOM ELOG P Run #2 E -line; RCBL for cement bond log. Toolstring= 1-7/16" x 1-3/8" cable head w/ 1.375" fishing neck, swival, roller centralizer, 2-3/4" 400 deg RIB W/O Temp, roller centralizer, 2-3/4" TEK CCL earth mag, 2-3/4" 400 deg, logging Gamma Ray, 40 arm caliper centralizer= 29.54'.Run to bottom (586LM)and logged to surface. 7/07/2013 Run in the hole with E -line and fire 240 GR string shot 03:22 at 1948' WLM. Pull out and MU 33/8" IBP #1. RIH with IBP #1 to 5730' WLM and set. Pressure test IBP #1 to 2500 psi for 5 minutes. Monitor well for 30 minutes and chart tests; Well Static. MU Baker 3 3/8" IBP #2 and RIH to 2490' WLM and set. Pressure test 2500 psi for 5 minutes and well static for 30 minutes on chart. RD E -line equipment. Trip in the hole with muleshoe to place sand on IBP #2 The string had to be rotated from 190' to 1511' . Placed 22-60# bags of sand on IBP #2, waited for 80 minutes and tagged at 2439' with 7K down weight. Stood back 2 stands of DP and MU Baker RBP. 00:00 00:30 0.50 COMPZ RPCOM ELOG P LD RCBL logging tools. 00:30 04:00 3.50 COMPZ RPCOM ELOG P Review logs and determine placement for string shot. MU 240 GR string shot. RIH with string shot and fire at 1948' WLM. 04:00 05:00 1.00 COMPZ RPCOM ELOG P POOH and LD string shot. MU Baker 3 3/8" IBP. 05:00 09:30 4.50 COMPZ RPCOM ELOG P RIH with IBP #1 and set at 5730' WLM. 09:30 10:30 1.00 COMPZ RPCOM PRTS P Pressure test IBP #1 to 2500 psi for 5 minutes and monitor well for 30 minutes - Static. 10:30 13:00 2.50 COMPZ RPCOM ELOG P Mu and RIH with IBP #2 to 2490' WLM and set. POOH with E -line. 13:00 14:30 1.50 COMPZ RPCOM RURD P RD E -line lubricator and pressure test IBP #2 to 2500 psi and monitor well for 30 minutes - Static. RD E -line and blow doen lines. Page 9 of 44 Alk a Time Logs di, ur To Dur 'EDetDate h Phase Code $ Subcode T ,,;Comment 14:30 17:30 3.00 0 1,511 COMPZ RPCOM TRIP P MU muleshoe, XO and 3 stand of HWDP, XO to DP and RIH to 190' to stack out. Start rotation 20 RPMwith 1-2K torque. Continue rotation at 15 RPM to 1511 with 3K torque. 17:30 18:30 1.00 1,511 2,423 COMPZ RPCOM TRIP P At 1511 tripping began on elevators Ito 2423'. PU = 105K, SO= 35K. 18:30 21:00 2.50 2,423 2,423 COMPZ RPCOM CIRC P Load 22-60# sacks of sand into drillpipe. Circulate drillpipe volume at 1 BPM with 40 psi. 21:00 23:00 2.00 2,423 2,273 COMPZ RPCOM COND P Pull back 2 stands and allow sand to settle. 23:00 00:00 1.00 2,439 2,268 COMPZ RPCOM TRIP P Trip in and tag sand with 3K down weight at 2439' showing 51 feet of sand on IBP #2. Trip out of the hole from 2439' to 2268'; PU = 90K, SO = 40K 7/08/2013 Tripped in the hole and attempted to set storm packer without success. During the second trip in to set packer the PU weight was lost and the packer and drill pipe fell to the IBP#2 plus the 51' of sand. The 3 1/2" EUE threads had backed -off placing the TOF at 160'. Called for overshot tool from Baker shop in Prudhoe. While waiting, attempts were made to engage fish with the 3 1/2 EUE connection without success. When overshot arrived it was tripped in the hole and engaged fish and pulled the packer to the surface. A new storm packer was made up, this one having ACME threads and set screws to prevent back -off. This packer was set at 79.87' COE and tested with 500 psi. BOPE was ND and the stack set back. RU HydraTite to wellhead with shooting flange and controlled 10 1/4" of growth. Applied PU of 180K and stretched 19 1/2", set slips and made cut. 00:00 01:30 1.50 2,268 0 COMPZ RPCOM TRIP P MU 7" Baker EA Retrievamatic, storm packer and RIH to set. Work packer to set at 70', over area of 50' to 90' and could not get the packer to set. Repeated attempts without success, the assembly was pulled to the surface to check the condition of the elements. At the surface the tool looked good and was tripped in the hole to attempt setting. 01:30 02:30 1.00 0 2,268 COMPZ RPCOM TRIP P While making more attempts to set the packer the PU weight was lost. The string was pulled to the surface and the Packer was left in the hole. A 3-1/2 EUE thread connection had backed off. The string fell to put the top of the fish at 160'. 02:30 03:00 0.50 0 0 COMPZ RPCOM TRIP T Service rig crown sheaves. While waiting on Baker tools from Prudhoe. 03:00 05:30 2.50 0 COMPZ FISH FISH T Waiting on tools from Baker Prudhoe. While waiting attempted to engage fish; no success. 05:30 07:00 1.50 COMPZ FISH FISH T MU overshot grapple fishing assembly and trip in hole engage fish at 160' and POOH with fish and lay down. 07:00 07:30 0.50 COMPZ RPCOM EQRP T Wait on 7" storm packer from Baker Prudhoe shop. Page 10 of 44 07:30 10:00 2.50 COMPZ RPCOM TRIP P Trip in hole with storm packer, set at 79.87' COE and POOH. Pressure test packer to 500 psi - good. Monitor well - Staic. Blow down and drain stack. PU wt 100k, SO wt 40k. Blocks and top drive 30k. 10:00 12:00 2.00 COMPZ RPCOM RURD I P Nippled down 13-5/8" BOPE and set 12:00 14:30 2.50 COMPZ RPCOM RURD P Remove tubing spool and set out. Tight pull w/ bridge crane. Reinstall BOP and attempt to pull w/ bridge crane- still tight. Rigged up (2) porta powers to jack on studs while ulling. With pull of bridge crane and jacking from below the tubing head started to come up. Worked up to 2". Set back stack and pulled FMC tubing head w/ bridge crane. Packoff is a single piece being held in place with the lockdown screws. 14:30 16:00 1.50 COMPZ RPCOM RURD P Change out a bad 7" casing head LDS and MU 13 5/8" shooting flange (MM part # 13322869) and rig up Hydratite equiment. 16:00 18:30 2.50 COMPZ RPCOM RURD P Initial start w/ flange to flange seperation of 6-3/8" was 10000 psi (216k force). Applied 11600 psi (250k force) pressure w/ Hydratite system. BOLDS and control casing growth, released 10-1/4" with Hydratite tool. RD Hydratite tool. After first cycle with hydratite pressure was 600 psi (129.6k force), after using system f/ 1 hr; 75.6k force w/ 3/4" growth, after 2 hrs: 26k force w/ total of 6-3/4" growth. From that point used wrenches to continue to grow casing to a total of 10 -1/4" - free. 18:30 19:30 1.00 COMPZ RPCOM RURD P MU Baker casing spear and engage casing as per Baker rep. Pull 180K indicated PU weight (36k -66k overpull) with 19 1/2" of stretch, totaling 29-3/4" of casing movement. Note: Storm packer in the hole w/ 2100' string hanging below COE 79.97'. 19:30 21:30 2.00 COMPZ RPCOM EQRP P FMC reps re -set slips and Baker spear released. FMC reps cut off 24", picked up and cleaned area. 21:30 00:00 1 2.50 COMPZ RPCOM RURD P NU 13-5/8" BOPE. Ah - Date From' To Dur S. De th.!De th F?#�ase bode°ti 5ubcode T 'Comment x, 7/09/2013 24 hr Summary NU BOP's and function tested. MU Baker overshot and tagged storm packer but could not engage. POOH and overshot cut lip was bent. Replaced and engaged storm packer and pulled to surface. POOH & stand back Hwt and UD mule shoe, M/U MSC BHA & RIH locate & make cut @ 1938' MD, Monitor well, POOH & UD multi string cutter, C/O to long bails, M/U Baker spear and try to engage 7" casing, No Go, N/D stack and found one side of 7" bent in to the center, FUU and cut 3/4" off the top of 7" casing and bevel & redress, N/U stack and riser, Held PJSM with all parties on circ out arctic pack. 00:00 00:30 0.50 COMPZ WELLPF OTHR P Function test BOPs and Hydrotest- I No leaks. 00:30 01:30 1.00 COMPZ RPCOM PULD P M/U Cut Lip running tool and TIH to top of Storm Packer, started rotating 20' above packer with 20 RPM TQ= 600, Slack off slowly onto top of packer and set down 2-3K, Tq= 900, unable to engage packer, POOH and found cutlip damage. 01:30 02:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig and iron roughneck, drawworks. 02:00 04:00 2.00 0 2,268 COMPZ RPCOM PULD P M/U new cut lip retrieving tool and TIH and engage packer, open and check for pressure- none, release from packer and POOH with packer and lay down same. PUW= 72K. 04:00 05:00 1.00 2,268 0 COMPZ RPCOM TRIP P POOH F/ 2268' MD, PUW= 70K, Rack back HWT and UD mule shoe. 05:00 05:30 0.50 0 0 COMPZ RPCOM PULD P M/U 4-1/2" MSC BHA 05:30 06:30 1.00 0 1,899 COMPZ RPCOM TRIP P TIH T/ 1899' MD, PUW= 62K, SOW= 52K, Rot= 59K, 70 RPM, Tq on= 1.8K, 06:30 09:00 2.50 1,899 1,938 COMPZ RPCOM OTHR P Locate 7" collars as per -Baker Rep. Locate collar @ 1953' MD DPM, Locate lower FO @ 1930' MD DPM, Confirm depths to make cut @ 1938" MD. Note: Top FO cementer @ 1846.5' DPM, Collar of jt @ 1969.5' DPM, Collar @ 1911' DPM, FO cementer @ 1930.5' DPM, String shot collar @ 1953' DPM. 09:00 10:00 1.00 1,938 1,938 COMPZ RPCOM CIRC P Circ and displace well to 9.6 ppg 170° Brine, open OA to tiger tank and monitor with no returns seen. 30 spm with 175 psi. 10:00 12:00 2.00 1,938 1,938 COMPZ RPCOM OTHR P Cut 7" casing with Baker's MSC @ 1938' MD, with 70 RPM, Tq= 2.5K, 45 spm with 330 psi. for one hour with no indication of successful cut, Torque climbed to 3.9K, shut down and picked up and slacked off to locate groove unable to locate. Relocate collar @ 1953' MD and P/U to 1938' and start cut again with 80 RPM, Tq= 3.8K, 54 spm with 500 psi. Page 12 of 44 12:00 13:30 1.50 1,938 1,938 COMPZ RPCOM OTHR P Continue cutting 7" casing @ 1938' MD with 102 spm with 920 psi, 80 RPM, Tq= 3.1 K, PUW= 64K, Rot= 57K. 13:30 15:30 2.00 1,938 0 COMPZ RPCOM TRIP P Monitor well, (static) POOH F 1938' T/ surface, make break on Baker tools and lay down same. Indication on knife blades show casing is cut. 15:30 16:30 1.00 0 0 COMPZ RPCOM OTHR P Change out to long bails on Top Drive. 16:30 18:30 2.00 0 0 COMPZ RPCOM FISH P M/U Baker spear assembly onto 7" casing stub, Packoff guide hanging up on top of 7" casing stub, unable to get packoff guide past top of 7" casing. 18:30 19:00 0.50 0 0 COMPZ RPCOM NUND P N/D BOP stack and raise. Found one side of 7" folded over causing restriction. 19:00 21:00 2.00 0 0 COMPZ RPCOM OTHR P R/U and recut 3/4" off the top of the 7" casing with air powered saw and bevel and redress top. Made successful run with Baker spear and pack-off. 21:00 22:00 1.00 0 0 COMPZ RPCOM NUND P N/U 13-5/8" BOP stack, turn buckles, riser and flowline. 22:00 00:00 2.00 0 0 COMPZ RPCOM FISH P Re-engage 7" casing with spear (Good) PUW= 98K, R/U lines to circ, helded PJSM with all parties. 7/10/2013 Displace arctic pack as per program, N/D BOP stack, weld slips to casing, Remove same, N/U BOP stack, Pull casing to rig floor and remove top joint, L/D spear & top cut joint, R/U and pull 7" casing to 86' MD, N/D stack & raise to be able to catch any junk being pulled up, finish L/D 7" casing, R/D GBR, N/U stack and clear rig floor. 00:00 00:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with all parties for arctic displacement. Pressure test Little Reds lines to 2500 psi. 00:30 01:00 0.50 0 0 COMPZ RPCOM CIRC P Pumped 52 bbls of heated 9.6 ppg brine, displace to tiger tank 3 bpm with 385 psi. 01:00 04:30 3.50 0 0 COMPZ RPCOM CIRC P R/U diesel truck to Little Red and heat and pump 190 bbls of 110 degree diesel at 2 bpm with 600 psi with returns going to open top tank, Shut down and suck down tank, continue pumping a total of 250 bbls of heated diesel. 04:30 06:30 2.00 0 0 COMPZ RPCOM CIRC P Line up truck with 134° sea water to Little Red and heat to 170° and pump down @ 2 bpm with 450 psi for a total of 150 bbls, 06:30 07:00 0.50 0 0 COMPZ RPCOM OTHR P Shut down pumping to remove 80 bbls from open top tank 7/11/2013 Flush out stack, R/U and test BOPE, P/U 10-3/4" scraper and DC's to 208' MD took wt. try to work through no go, L/D DC's and run in on hwt, no go, Run scraper in on 3.5" dp no go, L/D scraper BHA, P/U tandem Mill BHA, TIH & slide through past spots @ 208'250'323', 369', P/U to 350' and ream from 350' to 417' TIH F/ 417'T/ 1936' MD, Attempt to slide into 7" casing stub no go, PJSM, R/U and circ 180° sea water to clean 10-3/4" with 2 bpm and 200 psi. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P I M/U swizzle stick and flush out BOP cavities 01:00 02:00 1.00 0 0 COMPZ RPCOM BOPE P P/U test joint and test plug, set 01:00 -6�T - same and flood lines and stack with 07:00 08:30 1.50 0 0 COMPZ RPCOM CIRC P Move truck to tie into rig pumps to to be able to pump at faster rate to flush with, Pumped another 128 bbls @ 6 bpm with 430 psi untill clean returns were back to surface. Total seatwater pumped 278 bbls. Monitor well - static, R/D and blow down lines. 08:30 09:00 0.50 0 0 COMPZ RPCOM NUND P Nipple down stack to remove slips. 09:00 09:30 0.50 0 0 COMPZ RPCOM OTHR P Picked up string to 118K slips are dragging and not moving with pipe. 09:30 11:00 1.50 0 0 COMPZ RPCOM OTHR P Tack weld slips to casing and pick up to remove slips, PUW= 120K, SOW= 70K, N/U BOP stack. 11:00 12:00 1.00 0 0 COMPZ RPCOM PULL P I Pull 7" casing to rig floor with 135K, UD single and R/U casing tongs. 12:00 13:00 1.00 1,938 1,922 COMPZ RPCOM PULL P UD 7" casing spear, 15.63' Top cut joint (length includes the 2' cut off of jt when reset slips on 7/9/2013), M/U x -over and safety valve. 13:00 18:30 5.50 1,922 86 COMPZ RPCOM PULL P UD 7" 26 ppf J-55 BTC casing F/ 1922'T/ 86' M D 18:30 19:30 1.00 86 86 COMPZ RPCOM NUND P N/D and lift stack to try and retrieve any pieces that may have been pulled up with FO valves. 19:30 21:30 2.00 86 0 COMPZ RPCOM PULL P Finish laying down 7" casing (Total= 15.63' top cut joint, 47 full joints, Pup joint- FO- Pup joint, Pup joint - FO, 4.91' cut lower joint) Strap Out = 1940.94' (9 centrailzers w/ 2 clamps, 2 blades & 2 pieces of blades missing). Some pictures of the 7" csg on the "S" drive, in well folder. 21:30 22:00 0.50 0 0 COMPZ RPCOM PULL P R/D GBR Tools and clear floor. 22:00 23:30 1.50 0 0 COMPZ RPCOM NUND P PJSM, N/U BOP stack, Turn buckles. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P Install elevators and clean rig floor. 7/11/2013 Flush out stack, R/U and test BOPE, P/U 10-3/4" scraper and DC's to 208' MD took wt. try to work through no go, L/D DC's and run in on hwt, no go, Run scraper in on 3.5" dp no go, L/D scraper BHA, P/U tandem Mill BHA, TIH & slide through past spots @ 208'250'323', 369', P/U to 350' and ream from 350' to 417' TIH F/ 417'T/ 1936' MD, Attempt to slide into 7" casing stub no go, PJSM, R/U and circ 180° sea water to clean 10-3/4" with 2 bpm and 200 psi. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P I M/U swizzle stick and flush out BOP cavities 01:00 02:00 1.00 0 0 COMPZ RPCOM BOPE P P/U test joint and test plug, set 01:00 -6�T - same and flood lines and stack with 02:00 08:30 6.50 0 0 COMPZ RPCOM BOPE P Test BOPE, 250 low 3000 high, charted. Test Gas Alarms. Witness of test by AOGCC inspector Lou Grimaldi. Perform Koomey draw down test, Start= 3000 psi, Closing= 1750 psi, 200 psi= 15 sec, Final= 92 sec, 5 bottles avg 2050 psi, Pump Efficiency, Electric= 21 sec, Air= 117 sec. 08:30 09:30 1.00 0 0 COMPZ RPCOM BOPE P L/D test plug and joint, blow down I lines, re -align choke manifold. 09:30 11:00 1.50 0 208 COMPZ RPCOM PULD P M/U Baker 10-3/4" casing scraper and RIH on DCs and tagged @ 208' MD, PUW= 38K, SOW= 38K, attempt to work through several times with 8K and unable to get through. Note: Scraper blocks OD 9.375'. At bullnose depth of 208', blocks @ 200'. 11:00 12:00 1.00 208 205 COMPZ RPCOM PULD P POOH and lay down 2 DC's and stand back one stand, pulled scraper to rig floor and inspect, found 4 chunks of metal in scraper, TIH with scraper on HWT and tagged up @ 205' MD. Note: Scraper blocks OD 9.375'. At bullnose depth of 205', blocks @ 197'. 12:00 12:30 0.50 205 205 COMPZ RPCOM OTHR P Attempt to rotate through @ 205' MD with 54 spm, 131 gpm, 61 psi, 2k Tq, stalled with 7K Tq, PUW= 35K, SOW= 35K, Rot= 37K. Note: Scraper blocks OD 9.375'. At bullnose depth of 205', blocks @ 197'. 12:30 13:30 1.00 205 205 COMPZ RPCOM PULD P POOH F/ 205' and stand back HWT, RIH with 10-3/4" scraper on 3.5" dp to 205' MD attempt to slide past 205' unable to get past 205' MD (197' scraper blocks). 13:30 14:30 1.00 205 0 COMPZ RPCOM PULD P POOH and lay down BHA, jars, bumper sub, x-o's, and bit sub, L/D scraper dbl pin sub and jetted bull nose. 14:30 17:00 2.50 0 323 COMPZ RPCOM PULD P Break out bull nose from 7" casing spear and M/U tandem mill BHA to 323' MD, Had down drag at 250' bull nose depth but able to slide through. Note: @ 250' bullnose depth, 8-5/16 mill @ 153', 8-1/2" mill @ 138'. At 323' bullnose depth the 8-5/16" mill was at 226', the 8-1/2" OD mill @ 211'. Time Lo.'s.°` --To ,.>..� r (Phase �;�n a "• Date .,N From Dur = ` S. De th E. De th Code Subcode T Comment J 17:00 20:00 3.00 323 417 COMPZ RPCOM REAM P RIH to 369' had down drag at 369'- 372' Bull nose depth, P/U to 350' MD and ream F/350' T/ 417' MD, 5K WOM, 3.5K Tq, 65 RPM, 256 gpm, 220 psi, work mills up to 350 and then down to 417' MD. Note: @ 369' bullnose depth, 8-5/16 mill @ 272', 8-1/2" mill @ 257'. At 372' bullnose depth the 8-5/16" mill was at 275', the 8-1/2" OD mill @ 260'. Note: @ 417' bullnose depth, 8-5/16 mill @ 320', 8-1/2" mill @ 305'. 20:00 20:30 0.50 417 1,936 COMPZ RPCOM TRIP P RIH F/ 417' T/ 1936' MD top of 7" casing stub. 20:30 21:00 0.50 1,936 1,928 COMPZ RPCOM OTHR P Attempt to slide into 7" casing stub with bull nose at 1936' PUW= 45K, SOW= 37K, Slide down with 5K, P/U and slide down with 7 RPM, 2K Tq, 5K DWT, No Go, try slide down with 10K, with out rotation, No Go, P/U to 1928' MD. Note: When 7" casing was layed down: 2 bottom clamps/rings of the bow spring centralizers, 2 blades/bows & 2 pieces of blades/bows were missing --left in the hole. 21:00 22:00 1.00 1,928 1,928 COMPZ RPCOM SFTY P PJSM with Little Red and truck drivers, on pumping 170° sea water to flush 10-3/4" casing, Rig up lines to Little Red and open top tank. 22:00 00:00 2.00 1,928 1,928 COMPZ RPCOM CIRC P Line up and pump 35 bbl hi -vis pill, PT Little Red lines to 2500 psi, Little Red heat and pumped 180° sea water at 2 bpm with 200 psi. 7/12/2013 Displace well with 180° sea water with Little Red, POOH, Stand back 3 DC's and L/D 2 DC's, P/U Hwt to BHA and Ream out upper tight spots, POOH and L/D BHA, Found backed off DC, UD same, R/U and flush out stack, R/U a -line & gyrodata. RIH to 295' MD, POOH and add weighted bar, RIH to 1626' MD and log back to surface, R/D gyro tools and M/U caliper tools, RIH to 1642' MD and log to surface, R/D E -line, M/U taper string mill & RIH to 2188' MD, Pull up to 1900'& circ 13 BPM, Slip & cut drlg line, W/O load of 140° heated sea water, R/U to circ hot sea water. 00:00 01:30 1.50 1,928 1,928 COMPZ RPCOM CIRC P Conitue heating and pumping 180° sea water with Little Red at 2 bpm with 200 psi, flushing 10-3/4" casing out to open top tank with 290 bbls total pumped. 01:30 02:00 0.50 1,928 1,928 COMPZ RPCOM OTHR P R/D Little Red and blow down lines while monitoring well (Static). 02:00 03:00 1.00 1,928 73 COMPZ RPCOM TRIP P POOH F/ 1928'T/ Surface, Page 16 of 44 jime Logs Date From',. To Durbe the E, De th=Phase Code Sub ode T Comment 03:00 04:30 1.50 73 256 COMPZ RPCOM PULD P Stand back stand of DC's and UD two DC's and M/U stand of HWT to BHA and ream tight spots @ 144' with 8.5" mill, 200' with 8.5" mill, and 256' with the 8-5/16" mill. Pumping 109 spm, 254 gpm with 175 psi. 69 RPM, 2.2K Tq. 04:30 06:00 1.50 256 0 COMPZ RPCOM PULD P Stand back HWT and L/D BHA, Found 4-3/4" DC with 3.5"IF connection back off, only 1.5 turns to free connection, C/O DC, Upper mill showed wear and lower mill no wear. 06:00 07:00 1.00 0 0 COMPZ RPCOM OTHR P Make up swizzle stick and flush out BOP cavities. Pumped 10 bpm with 100 psi. 07:00 08:00 1.00 0 0 COMPZ RPCOM ELOG P PJSM rig up a -line and gyrodata tools. 08:00 09:00 1.00 0 0 COMPZ RPCOM ELOG P TIH with Gyro logging tool, unable to get past 295' Gyro depth 285' POOH add 10' weight bar 09:00 11:00 2.00 0 0 COMPZ RPCOM ELOG P RIH with Gyro logging tools to 1626' MD and log to surface from 1626' MD. 11:00 12:00 1.00 0 0 COMPZ RPCOM ELOG P UD Gyrodtat logging tools and M/U Caliper Logging tools. 12:00 12:30 0.50 0 0 COMPZ RPCOM ELOG P Finish M/U caliper logging tools. 12:30 14:00 1.50 0 0 COMPZ RPCOM ELOG P RIH to 1642' MD with caliper logging tools and POOH 14:00 14:30 0.50 0 0 COMPZ RPCOM ELOG P L/D caliper tools and R/D E -line. 14:30 15:00 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive, Travelling blocks and rig floor handling equipment. 15:00 17:00 2.00 0 485 COMPZ RPCOM PULD P Bring up and M/U Baker taper string mill BHA to 485' MD. 17:00 18:30 1.50 485 2,188 COMPZ RPCOM TRIP P RIH F/ 485'T/ 2188' MD (Had to rotate through 7" casing stub @ 1938'6 BPM 442 psi, 70 RPM, 980 Ft/Lbs of free torque, PUW= 66K, SOW= 63K, ROT= 64K. 18:30 20:00 1.50 2,188 1,900 COMPZ RPCOM CIRC P Circ at 2188' MD, 13 bpm with 2020 psi, pull up to 1900' MD. Filled cuttings tank with arctic pack with this rate. 20:00 22:00 2.00 1,900 1,900 COMPZ RPCOM SLPC P Slip and cut 12 wraps of drilling line. 22:00 23:30 1.50 1,900 1,900 COMPZ RPCOM OTHR P Wait on truck load of 140° heated sea water, perform general housekeeping around rig. 23:30 00:00 0.50 1,900 1,900 COMPZ RPCOM OTHR P R/U to circ hot 140° sea water. 7/13/2013 PJSM, R/U took on 140° sea water into pits 2,3 & pill pit, taking returns to 1,2 & 4 pits, pumped 13 bpm with 1650 psi. 4 BUS with deep clean pill, POOH to 187' MD, M/U back off BHA, TIH, Set upper and lower anchor and back out 7" stub with 13 cycles, Circ 3 Btms Up, POOH while pumping out, UD baker back off BHA, M/U 7" dummy run, Tagged up @ 173' and worked down to 214' MD, Called engineer and discussed options, POOH and P/U tandem string mills (8.5" lower, 8-3/4" upper), M/U Baker tandem Mills and took wt at lower 8.5" mill at 19T MD, Page 17 of 44 ` Ak Time L:o s Gate atom' *r To Dur � S. De th . De th :Phase Code ,x « Subcotle T Comme►tt N : _ "'r x ..,.. M 00:00 01:00 1.00 1,900 1,900 COMPZ RPCOM SFTY P PJSM with truck drivers and crew, R/U to pump heated 140° sea water with both mud pumps @ 13 BPM. Filled pits 2 and 3 and pill pit, taking returns back to 1, 2 and 4 pits 01:00 02:00 1.00 1,900 1,900 COMPZ RPCOM CIRC P Pumped four bottoms up @ 13 bpm with 1650 psi, then pumped deep clean pill around. (At this rate we were able to get another 15 +/- bbls of arctic pack out). 02:00 03:00 1.00 1,900 187 COMPZ RPCOM TRIP P POOH F/ 1900'T/ 187' Top of collars. 03:00 04:00 1.00 187 500 COMPZ RPCOM PULD P M/U Baker back off BHA T/ 499' 04:00 07:00 3.00 500 2,224 COMPZ RPCOM TRIP P TIH with back off BHA, filling every 5 stands with fresh water. Bottom of taper mill will be at 2224' and set upper anchor set at 1945' and lower anchor at 1965' MD. PUW=45K, SOW= 65K. M/U head pin and circ hose. 07:00 09:00 2.00 2,224 2,224 COMPZ RPCOM OTHR P Back off 7" casing stub 5-1/2 turns as per Baker Rep. Initial breaking pressure = 900 psi, cycle tool 13 times. 09:00 09:30 0.50 2,224 2,103 COMPZ RPCOM TRIP P R/D hose and head pin, POOH to 1892' (Upper anchor) and 2103' (Taper mill) PUW= 67K. 09:30 10:30 1.00 2,103 2,103 COMPZ RPCOM CIRC P Drop Ball rod and open cric sub with 2050 psi, reverse circ 25 bbls at 4bpm and 350 psi. (Fresh water) to cuttings tank, Circ long way @ 13.5 bpm with 1500 psi till shakers clean up with 3 BU. 10:30 12:00 1.50 2,103 1,067 COMPZ RPCOM TRIP P POOH while pumping out F/ 2103'T/ 1067' 13 bpm with 975 psi, PUW= 50K. 12:00 13:30 1.50 1,067 224 COMPZ RPCOM TRIP P Contiue pumping out F/ 1067'T/224' MD @ 13 bpm with 975 psi. 13:30 16:00 2.50 224 0 COMPZ RPCOM PULD P UD Baker back off BHA F/ 224' T/ surface, Pumped out from 187' to 30' 13 bpm 290 psi. 16:00 17:30 1.50 0 0 COMPZ RPCOM PULD P Pick up replacement 4-3/4" DC's and rack back in Derrick. 17:30 18:00 0.50 0 0 COMPZ RPCOM PULD P R/U GBR to P/U 7" dummy run BHA. 18:00 22:30 4.50 0 214 COMPZ RPCOM PULD P P/U 7" dummy run BHA F/ surface T/ 214' MD, taking weight @ 173' and 214' Called town and discussed with engineer to come out and P/U sting mills. 22:30 00:00 1.50 214 1 35 COMPZ RPCOM PULD I P L/D dummy run BHA F/214' T 35' 7/14/2013 POOH w/ dummy 7" casing run. M/U tandem string mills, Ream out tight spots F/ 198'T/ 222' lost 100 psi, POOH to cross over below 8.5" mill & top of stand of DC's twisted off, UD BHA, M/U overshot BHA, RIH to 1850' tagged fish with 15K, P/U with 10K over to free fish, POOH & UD fish & tools, M/U tandem string mill BHA and ream F/ 160'T/ 250' MD. Page 18• of 44 Ak Ah LJ Date ,. From'== 3To Dur' S. De th E De th Phase Gode Subcode Tn Cornme°ntw�Mf, 00:00 01:00 1.00 35 0 COMPZ RPCOM PULD P Finish laying down 7" dummy run and R/D GBR equipment, Rig break out tongs back up. 01:00 02:00 1.00 0 263 COMPZ RPCOM PULD P M/U tandem string mills, 8.5" Lower mill, 8.75" upper mill, to 150' MD, Bull nose depth @ 263' MD 02:00 02:30 0.50 263 295 COMPZ RPCOM MILL P Get parameter check @ 150' lower 8.5" mill depth, PUW= 43K, SOW= 38K, Rot= 38K, 70 RPM, Tq= 1050 ft/ibs, 10 bpm, 400 psi, TI and tag @ 198' with lower 8.5" mill depth and Bull nose depth at 295' MD 02:30 06:00 3.50 295 343 COMPZ RPCOM MILL P Ream F/ 150'T/ 230' MD, (Lower 8.5" mill depth) with 70 RPM, WOM= 2K, 10 bpm with 400 psi, Highest Tq seen 3500 to 5000 with upper mill @ 200' Back ream F/195' T/ 205' with upper mill 8-3/4". 06:00 11:00 5.00 308 335 COMPZ RPCOM REAM P Continue reaming tight spots F/ 195' (Upper Mill depth) T/ 222' and bull nose depth @ 335' MD with 70 RPM, Tq= 1000/2500 ft/lbs, 10 bpm with 400 psi. P/U and ream out tight spots F161' T/ 185' with 70 RPM, Tq= 1-2.7K, 10 bpm with 400 psi. 11:00 12:00 1.00 335 37 COMPZ RPCOM TRIP T Noticed 100 psi drop F/ 400 psi T/ 300 psi, shut down rotary and pick up with 2000 lbs string loss, POOH and found the 3.5" 1F connection on cross over between lower string mill and top of stand of DC's twisted off. (Leaving stand of DC's and bull nose in hole.) 12:00 13:00 1.00 37 0 COMPZ RPCOM PULD T UD Baker tandem string mill BHA. 13:00 14:00 1.00 0 0 COMPZ RPCOM SVRG T R/U and flush BOP cavities with 12 bpm and 10 RPM. UD tools. 14:00 14:30 0.50 0 0 COMPZ RPCOM PULD T Bring overshot components to rig floor and strap same. 14:30 15:00 0.50 0 0 COMPZ RPCOM SFTY T PJSM for Picking up fishing BHA with Baker. 15:00 16:00 1.00 0 206 COMPZ RPCOM PULD T P/U Baker over shot BHA F/ surface T/ 209' found tight spot at 206' MD. work through. 16:00 17:30 1.50 206 1,850 COMPZ RPCOM TRIP T TIH F/ 209'T/ 1850' MD, set down 15K, P/U 20K over and allow jars to bleed off, Picked up 10K over to free fish. 17:30 18:30 1.00 1,850 207 COMPZ RPCOM TRIP T POOH F/ 1850'T/ 207' MD 18:30 20:00 1.50 207 0 COMPZ RPCOM PULD T L/D Baker fishing BHA, recovered 3 joints of 4-3/4" DC's and Bull Nose. Clear & clean rig floor. 20:00 20:30 0.50 0 160 COMPZ RPCOM PULD T P/U Baker tandem string mill BHA F/ surface T/ 160' MD. 20:30 00:30 4.00 160 250 COMPZ RPCOM REAM P Rem F/160' T/ 250' MD with 10 bpm 300 psi, 70 RPM, Free Tq= 830 ft/lbs, Tq= 1.5 - 2.OK, PUW= 40K, SOW= 35K, Rot= 38K. Page 1'S of 44 r� A& t �i- Date From' To A Dur S. De th .E De th Phase Gode Subcode T '_Commerif_'- °j 7/15/2013 24 hr Summary Reaming out tight spots F/ 160'T/ 272' MD @ mid lower mill with bullnose depth @ 278' MD continue down to 312' MD, Service rig, TIH to 1938' MD top of 7" casing, Circ sweeps around, Back ream out with 13.5 bpm, UD tandem mill BHA, M/U 7" dummy BHA & RIH tight @ 163', 175', 181', 279' and 296' MD, M/U TD and use TD weight with 5 RPM to get past 296' MD, TIH 1938' MD CBU POOH, L/D 7" dummy BHA, M/U 6.125" taper mill BHA to 137' MD. 00:00 01:00 1.00 160 250 COMPZ RPCOM REAM P Continue reaming F/ 160'T/ 250' MD, with 70 RPM, Tq= 800-1500, 10 bpm 300 psi, PUW= 42K, SOW= 39K, Rot= 40K, Rack back one stand of HWT and P/U one stand of DC's and M/U to stand of HWT. 01:00 09:00 8.00 250 312 COMPZ RPCOM REAM P Ream F/ 250' T/ 272' MD, Mid lower 8.5" mill, Bull nose depth @ 278' MD with 70 RPM, 10 bpm 300 psi, Tq= 1-3K, PUW= 42K, SOW= 39K, Rot= 39K. Unable to slide past 272' MD, Continue reaming area out to 312' MD. 09:00 09:30 0.50 312 312 COMPZ RPCOM SVRG P Service Blocks and Top Drive. 09:30 10:30 1.00 312 1,938 COMPZ RPCOM TRIP P RIH F/ 312'T/ 1938' MD, Bull nose depth, Tagged top of 7" with 4K, PUW= 65K, SOW= 65K. 10:30 12:00 1.50 1,938 1,938 COMPZ RPCOM CIRC P Circ with 13.5 bpm 1575 psi, Rotate and reciprocate with 50 RPM, Rot wt= 65K, Tq= 810 ft/lbs, Pumped hi -vis sweep with 13.5 bpm 1575 psi, Pumped 30 bbl deep clean pill and circ till hole was clean. 12:00 14:30 2.50 1,938 250 COMPZ RPCOM REAM P Back ream out of hole with 10 RPM, Tq= 765 ft/lbs, 13 bpm 1530 psi, F/ 1938'T/ 250' M D 14:30 15:30 1.00 250 0 COMPZ RPCOM PULD P UD Baker tandem string mill BHA, F/ 250' T surface, Recovered 28.2 lbs of metal from string magnets. 15:30 16:30 1.00 0 0 COMPZ RPCOM PULD P R/U GBR to make up 7" dummy run. 16:30 18:00 1.50 0 296 COMPZ RPCOM PULD P P/U 7" casing dummy BHA F/ surface to 296' MD, Tight @ 163', 175', 181', 279' and 296'( At 296' had to M/U Top Drive and use Top Drive weight with 5 RPM rotation to get throu ht tight area.) 18:00 19:00 1.00 296 1,938 COMPZ RPCOM TRIP P RIH F/ 296' T/ 1938' MD, PUW= 63K, SOW= 63K, Tag 7" casing stub with 2K. 19:00 20:00 1.00 1,938 1,930 COMPZ RPCOM CIRC P CBU with 10 bpm 690 psi @ 1930' MD. 20:00 21:00 1.00 1,930 296 COMPZ RPCOM TRIP P POOH F/ 1930' T/' MD296' MD, PUW= 63K, SOW= 63K, Pulled 8K over @ 296' MD and at 170' MD. 21:00 22:00 1.00 296 70 COMPZ RPCOM PULD P UD 7" dummy BHA F/296' T/ 70' MD, recovered 36.8 lbs of metal from string magnets. 22:00 22:30 0.50 70 70 COMPZ RPCOM PULD P R/U GBR equipment to L/D 7" dummy BHA. 22:30 23:00 0.50 70 0 COMPZ RPCOM PULD P UD BHA F/70' T/ surface, clear and clean rig floor. Page 20 of 44 Ah Ah "Time 40 ` s NAFI IU ' `I n Date Fr©m' TOhY.h,3 Dur S.=De th. Denth, Phase Code. Subsode 0 ET Comrient4, 23:00 00:00 1.00 0 137 COMPZ RPCOM PULD M/U Baker 6.125" taper string mill IP I BHA F/ surface T/ 137' MD. 7/16/2013 TIH with 6-1/8" taper mill, CBU, POOH, UD BHA, M/U Spear type D BHA, TIH & enter 7" casing and attempt to torque up same, made up to 3980 ft/lbs and slipped off & could not bite the 7" again, POOH check spear, No damage found, P/U 8.5" lower mill and 8-7/8" upper mill and ream out tight spots F/150', 187', 260'335' MD. 00:00 00:30 0.50 137 228 COMPZ RPCOM PULD P Finish picking up 6-1/8" Taper string mill BHA T/ 228' MD. 00:30 01:00 0.50 228 1,924 COMPZ RPCOM TRIP P TIH F/ 228'T/ 1924' MD. No tight spots encountered, PUW= 65K, SOW= 65K. 01:00 01:30 0.50 1,924 1,960 COMPZ RPCOM CIRC P TIH and entered 7" @ 1938' MD, had slight bobble, continue to 1960' MD with 70 RPM, Tq= 875 ft/lbs, 10 bpm 950 psi, PUW= 65K, SOW= 65K, Rot= 65K, Ream up & down 2 X, No Tq or drag, P/U slack off no rotation, set 5 K, P/U and set down lightly 1 K, ream down to 1945" MD, P/U to 1935' MD and CBU with clean returns. 01:30 02:30 1.00 1,960 228 COMPZ RPCOM TRIP P POOH to BHA F/ 1945'T'228' 02:30 03:30 1.00 228 0 COMPZ RPCOM PULD P UD Taper string mill BHA and clean magnets, 03:30 04:00 0.50 0 213 COMPZ RPCOM PULD P M/U Tri-State type D spear BHA to 213' MD, (SIMOPS: take off 300 bbls from active pits to take on 290 bbls of heated 140° sea water) 04:00 05:00 1.00 213 1,925 COMPZ RPCOM TRIP P TIH with spear BHA F/ 213'T/ 1925' and 05:00 06:30 1.50 1,925 1,925 COMPZ RPCOM CIRC P Load pits with Hot sea water and circ 140° heated sea water and flush the 10-3/4" casing with 13.5 bpm and 1610 psi. 06:30 08:00 1.50 1,925 1,946 COMPZ RPCOM OTHR P Enter top of 7" with type D spear @ 1938' MD set down 10K, continue to no go, @ 1946' MD, Made several attempts to tighten the 7" connection, highest torque achieved was 3980 ft/lbs, slips on the spear appear to be slipping. 08:00 09:30 1.50 1,946 0 COMPZ RPCOM TRIP P POOH to check spear F/1946' T/ surface. PUW= 65K. Nothing appeared to be wrong with the spear upon inspection. L/D spear.Discussed with town engineer and will P/U 8-3/4" mill and 8-7/8" mill next. 09:30 11:00 1.50 0 150 COMPZ RPCOM PULD P P/U tandem string mill BHA with 8-3/4" lower mill and 8-7/8" upper mill F/ surface T/ 150' MD Page 21 of 44 Time Logs, "' ��. Date From To"', Dur S. De th .E,e th i?hase` Code Sutieode T Comtent 11:00 12:00 1.00 150 187 COMPZ RPCOM REAM P Ream tight spots F/150', Mid lower mill, 134' mid upper mill, T/ 187' MD, mid lower mill, 171' upper mid mill, PUW=40, SOW= 38K, Rot= 40K, 70 RPM, Free Tq= 800, On Btm Tq= 1.5K, 10 bpm with 300 psi. 12:00 14:00 2.00 187 260 COMPZ RPCOM REAM P Ream tight spots F/ 187', lower mill depth, upper mill @ 171' depth, T/ 260' MD, with lower mill and uipper mill @ 246', with 10 bpm 420 psi, Free Tq= 820, Tq on btm= 2K, PUW= 40K, SOW= 38K, Rot= 38K. 14:00 15:00 1.00 260 260 COMPZ RPCOM SVRG P Service rig, drawworks, Blocks, Top Drive and floor handling equipment. 15:00 00:00 9.00 260 335 COMPZ RPCOM REAM P Reaming tight spots F/ 246' Lower mill, and upper mill @ 246', T/ 335' MD lower mill, and upper mill @ 320' with 10 bpm and 420 psi, Tq on & off 820 ft lbs, PUW= 40K, SOW= 38K, Rot wt= 38K. 7/17/2013 Ream out tight spots down to 337' MD, POOH, L/D Milling BHA, M/U 7" dummy run tight spots @ 162', 203', 211' and 295' MD's, NO GO, POOH & UD dummy BHA, M/U Multi string cutter, RIH Cut casing @ 1943' MD, POOH & L/D cutter, M/U spear BHA, RIH & recovered fish, POOH & UD fishing BHA, M/U csg dress off BHA, RIH, Dress off 7" casing stub, POOH, L/D same, M/U type D spear BHA, RIH and could not get the drag blocks into the 7" casing, POOH & wait on 9" mill from DeadHorse. 00:00 00:30 0.50 245 337 COMPZ RPCOM REAM P Continue reaming tight spots F/ 245' /229' lower/upper mill depths, T/ 337'/321' lower/upper mill depths with 70 RPM, Tq off/on= 750/1500 ft/lbs, PUW= 42K, SOW= 40K, Rot= 41 K, 10 BPM 300 psi. 00:30 01:00 0.50 337 337 COMPZ RPCOM CIRC P Pump sweep around with 13.5 bpm 720 psi. 01:00 02:00 1.00 337 0 COMPZ RPCOM PULD P Lay down tanden string mill BHA 02:00 02:30 0.50 0 69 COMPZ RPCOM PULD P R/U GBR to run 7" dummy run and M/U 7" casing to 69' MD 02:30 03:00 0.50 69 109 COMPZ RPCOM PULD P R/D GBR and M/U Magnets, LBS and jars to 109' MD. P/U first stand of DCs. 03:00 04:00 1.00 109 294 COMPZ RPCOM OTHR P Tagged and took all weight @ 162' MD, cementer @ 142' MD, Work down to 203' MD, Cementer @ 183' MD. Got through and worked stand up and down hitting and taking wt at different depths F/ 162' T/ 203'. Made connection with another stand of DC's worked tight spots F/ 211' Cementer depth @ 191' MD, T/ 294' cementer @ 274' MD, Made up another stand of DC's and stopped completely at 294' MD cementer @ 273' MD try to work past, No-Go. 04:00 05:30 1.50 294 0 COMPZ RPCOM PULD P Set back DC's and UD Jars, LBS, and both magnets, R/U GBR and L/D dummy run BHA Page 22 of 44 Ak Time Logs,h Date From' To ,; z`nt Dur Y S. De th E. de" tFi i'hase Code Subcode T Comment,.t 05:30 07:00 1.50 0 1,943 COMPZ RPCOM PULD P M/U Multi string cutter BHA, TIH and locate collar @ 1952', PUW=62K. SOW= 60K, Rot= 60K, 80 RPM, TQ= 800, Position knifes @1943' MD and make cut, Torque increase to 2300 ft/lbs and ropped to 800 ft/lbs, Staged pump pressure from 600 psi to 1000 psi, Dropped to 370 psi, Rotated for 5 additional min after the cut.. 07:00 08:00 1.00 1,943 0 COMPZ RPCOM TRIP P POOH F/ 1943' T/surface laying down BHA. 08:00 08:30 0.50 0 307 COMPZ RPCOM PULD P P/U Baker spear BHA with 6.22" grapple T/ 307' MD 08:30 09:30 1.00 307 1,945 COMPZ RPCOM TRIP P TIH F/ 307' T/ 1945' MD, PUW= 60K, SOW= 60K, Rot wt=60K, engage cut off stump with grapple. 09:30 10:30 1.00 1,945 0 COMPZ RPCOM TRIP P POOH with fish F/ 1945'T/ surface. PUW= 60K, SOW= 60K. 10:30 11:30 1.00 0 0 COMPZ RPCOM PULD P Remove casing stub from spear, break down spear and lay down, lay down jars and bumper sub. 11:30 12:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig, drawworks, Top Drive, Blocks and crown. 12:00 13:30 1.50 0 421 COMPZ RPCOM PULD P Make up Baker casing dress off BHA F/ surface T/ 421' MD. 13:30 14:00 0.50 421 1,943 COMPZ RPCOM TRIP P TIH F/ 421'T/ 1943' MD, PUW= 65K, SOW= 63K. 14:00 15:00 1.00 1,943 1,948 COMPZ RPCOM REAM P Tag casing stump @ 1943' MD set down 2K, swallow 7" casing F/ 1943' T/1948' MD with 6 bpm 370 psi, 60 RPM, Free Tq= 795 ft/lbs, Tq on= 5.7 ft/lbs, PUW= 65K, SOW= 63K, Set down 3K @ 1948' MD, wash over stump 2 times, encounter taking wt. @ 1945on 3rd attempt, (10K) 15:00 16:00 1.00 1,948 421 COMPZ RPCOM TRIP P POOH F/ 1943' T/ 421' MD 16:00 18:00 2.00 421 0 COMPZ RPCOM PULD P L/D Dress Off BHA F/ 421' T/ surface. 18:00 20:30 2.50 0 491 COMPZ RPCOM PULD P M/U Baker type D spear BHA to tighten 7" casing F/ surface T/ 491' MD. 20:30 21:30 1.00 491 1,948 COMPZ RPCOM TRIP P TIH F/ 421'T/ 1948' 21:30 22:00 0.50 1,948 1,946 COMPZ RPCOM TRIP P Obtain parameters with 4 bpm 190 psi, Free Tq= 750 ft/lbs, PUW= 65K, SOW= 65K, Rot wt= 65K, Tag 7" casing stub @ 1946' MD, Attempt to latch spear, unable to latch spear. We were able to get the bullnose inside 3', but could not engage the grapple. Suspect junk in the ID of the 7' stump not allowing the spear to en age. 22:00 23:00 1.00 1,946 491 COMPZ RPCOM TRIP P POOH F/ 1946' T/ 491; MD 23:00 23:30 0.50 491 0 COMPZ RPCOM PULD P L/D Baker spear BHA F/491' T/ surface. Page 23 of 44 Ah Ah Time Logs - pan r Date a °<,K..w«From! . To Dur S. De th , E.De fh Phase �a,9 Code '' Subcode T =. Gorr}rtierwf ° "'"Al 23:30 00:00 0.50 0 1 0 ICOMPZIiiPCOM OTHR I P Wait on 3rd party, Baker 9" mill coming from DeadHorse 7/18/2013 W/O 9" Mill from DeadHorse, M/U triple string mill BHA, Ream out tight spots in 10-3/4" F/197' MD T/300' MD with upper 9" mill, Most set down seen was 4K. POOH, Wash out stack, R/U and test BOPE. 00:00 01:30 1.50 0 0 COMPZ RPCOM OTHR P Wait on Baker 9" Mill to come over from DeadHorse. 01:30 02:30 1.00 0 108 COMPZ RPCOM PULD P P/U Baker Triple String Milling BHA. Mills- 9.0", 8 7/8", and 8 3/4" Watermelon, spaced out with a flex and one joint of HWDP. Trip in hole F/ surface T/ 108' MD. 02:30 12:00 9.50 108 300 COMPZ RPCOM REAM P Ream out tight spots F/ 197' with lower 8-3/4" mill, 181' Mid 8-7/8" Mill, 140' Upper 9" Mill, PUW= 40K, SOW= 40K, Rot wt= 40K, Free Tq= 800 ft/lbs, 10 bpm= 350 psi. T/ 300' MD 12:00 14:00 2.00 197 300 COMPZ RPCOM REAM P Ream out tight spots F/ 197' with lower 8-3/4" mill, 181' Mid 8-7/8" Mill, 140' Upper 9" Mill, PUW= 40K, SOW= 40K, Rot wt= 40K, Free Tq= 800 ft/lbs, 10 bpm= 350 psi. T/ 300' MD, Slide down F/ 140'T/ 300' MD with upper mill Most set down seen 4K. 14:00 14:45 0.75 300 1,943 COMPZ RPCOM TRIP P TI F/ 300' T/ 1943' MD, Tagged 7" casing stub, pumping 13 bpm= 1500 psi, set down 4K, P/U to 1940' MD. PUW= 67K, SOW= 66K, Rot wt= 65K. 14:45 15:00 0.25 1,943 1,940 COMPZ RPCOM SFTY P Kick While Tripping drill, CRT= 105 sec, AAR 15:00 16:00 1.00 1,940 1,940 COMPZ RPCOM CIRC P Pumped 35 bbl high vis sweep @ 1940' MD, 13 bpm= 1500 psi, 40 RPM, Free Tq= 775 ft/lbs while working pipe.. 16:00 16:30 0.50 1,940 569 COMPZ RPCOM TRIP P POOH F/1940' T/ 569', PUW= 67K, SOW= 66K @ 1940'M D. 16:30 18:30 2.00 569 0 COMPZ RPCOM PULD P IUD Triple string mill BHA F/ 569'T/ surface. 18:30 19:00 0.50 0 0 COMPZ RPCOM PULD P M/U string magnet and swizzle stick to flush out BOP's 19:00 19:30 0.50 0 0 COMPZ RPCOM OTHR P Flush out stack with 13 bpm= 185 psi. 19:30 20:00 0.50 0 0 COMPZ RPCOM PULD P L/D magnet and swizzle stick after flush out BOP. 20:00 21:30 1.50 0 0 COMPZ RPCOM BOPE P P/U 3.5" test joint and set test plug, fill stack and choke manifold with water. SIMOPS: Vac off 290 bbls old sea water from pits and clean pits 2, 3 & 5 take on 290 bbls of clean filtered water. Page 24 of 44 'time Logs Date ` From „To Dur S. De th E. De th Pse haGod'e" ! Subcoe T `'Comment �N 21:30 00:00 2.50 0 0 COMPZ RPCOM BOPE P Test BOPE 250 low 3000 high and chart same, Witness of test waived by AOGCC John Crisp on 7/17/2013 @ 11:40 hrs.Tested with 3.5" test joint, 3.5" floor equipment, IBOP & Lower kelly valve. Koomey draw down: Start= 3050 psi, closing= 1725 psi, 200= 17 sec, Final= 90 sec, 5 Bottles @ 2100 psi avg. Pump efficiency, electric pump= 19 sec, Air= 128 sec. 7/19/2013 Finish testing BOPE, UD test plug and test joint, Blow down lines and choke, M/U wash over shoe BHA, RIH and tagged &' @ 1943' MD, try to slide over no go, rotated over w/ 5 dn. wt. & tq up to 4400 ft/lbs, Pulled off w/ no over pull, displace well over to filtered water & POOH, R/U E -line and camera and get pictures and video. R/D and C/O bails. 00:00 02:30 2.50 0 0 COMPZ RPCOM BOPE P Continue test BOPE with 7" test joint, manual & HCR choke & kill valves, Kill line, choke valves 1 through 16, Blinds, Test flange valves, Closing times Annular= 20 sec, upper VBR= 6 sec, SIM blinds= 6 sec, SIM lower rams= 6 sec, choke HCR= 1 sec, choke kill= 1 sec. 02:30 03:00 0.50 0 0 COMPZ RPCOM BOPE P L/D test joint & test plug, blow down all lines and choke. 0300 03:30 0.50 0 235 COMPZ RPCOM PULD P M/U Baker 7-1/4" ID Wash Over Shoe BHA F/ surface T/ 235' MD 03:30 04:30 1.00 235 1,945 COMPZ RPCOM TRIP P TI F/ 235' T/ 1943' MD, Tagged top of 7" did not slide over. Rotate 20 RPM, slid 2' over the top of the 7" T/ 1945' MD with 4400 ft/lbs of torque. Stopped and pulled up past top of 7" stub. 04:30 06:00 1.50 1,943 1,943 COMPZ RPCOM CIRC P Line up and pump 30 bbl deep clean pill while working pipe and rotating, Followed by clean filtered water with 13.5 bpm with 1733 psi to displace well. 06:00 08:00 2.00 1,943 513 COMPZ RPCOM TRIP P POOH F/ 1944'T/ 513' MD, PUW= 65K, SOW= 65K. 08:00 08:30 0.50 513 0 COMPZ RPCOM PULD P L/D Baker wash over BHA F/ 513'T/ surface. 08:30 09:00 0.50 0 0 COMPZ RPCOM ELOG P R/U HES E -line logging equipment. 09:00 09:30 0.50 0 0 COMPZ RPCOM ELOG P M/U wireline camera assembly. 09:30 10:30 1.00 0 0 COMPZ RPCOM ELOG P RIH with camera, check fluid clarity, unable to see with camera, POOH 10:30 11:00 0.50 0 0 COMPZ RPCOM ELOG P R/D E -line equipment. 11:00 12:00 1.00 0 490 COMPZ RPCOM PULD P M/U Baker wash over shoe BHA F/surface T/ 490' MD. 12:00 12:30 0.50 490 1,940 COMPZ RPCOM TRIP P TIH F/ 490'T/ 1940' MD, PUW= 65K, SOW= 65K. 12:30 13:00 0.50 1,940 1,940 COMPZ RPCOM OTHR P C/O to long bails. Page 26 of 44 Time Logs 'Date,,,,-.,--- From To D; n ur S: De th E. De ttf Phase Gode Subcode 'T ..I Cor&rWont s 13:00 15:30 2.50 1,943 1,942 COMPZ RPCOM ELOG P Tag 7" casing top, P/U T T/ 1942' MD, R/U E-line and space out pups and X-Overs. 15:30 16:00 0.50 1,942 1,942 COMPZ RPCOM ELOG P M/U E-line and camera assembly 16:00 17:30 1.50 1,942 1,942 COMPZ RPCOM ELOG P RIH with E-line and camera, Circ 86 bbls filtered water @ .5 - 3 bpm, 460 psi, Monitor camera for picture quality 17:30 18:30 1.00 1,942 1,942 COMPZ RPCOM ELOG P POOH with a-line and remove rollers from camera assembly and RIH with same. 18:30 20:00 1.50 1,942 1,942 COMPZ RPCOM ELOG P Circ 76 bbls of filtered water @ .5 - 2 bpm125 psi, Monitor camera for quality. 20:00 22:00 2.00 1,942 1,942 COMPZ RPCOM ELOG P R/U truck to pump suction and pump 60 bbls @ 4 bpm 410 psi to clean bottom of stub, slow down to .5 bpm 21 psi while getting video and pictures with camera. 22:00 23:30 1.50 1,942 1,942 COMPZ RPCOM ELOG P POOH with camera and R/D a-line and camera. 23:30 00:00 0.50 1,942 1 1,942 COMPZ RPCOM IOTHR P Change back to short bails 7/20/2013 POOH, Spot filtered water F/ 345'T/ surface, L/D BHA, R/U a-line and camera, RIH to 300"MD and get video and pictures of 10-3/4' bad spots. RIH w/ dp and flush from 384' back to surface with 70 bbls filtered water, RIH w/ a-line for better video and pictures, R/D a-line & tools, M/U taper mill & RIH, clean out 7" do to 1993' MD, CBU, POOH, Make 7" dummy run, stopped @ 297' MD, POOH, M/U triple string mill BHA to 157' tight spots in 10-3/4" casing. 00:00 01:00 1.00 1,942 345 COMPZ RPCOM TRIP P POOH F/ 1942'T/ 345' MD, PUW= 65K, SOW= 65K 01:00 01:30 0.50 345 345 COMPZ RPCOM CIRC P Circ and spot filtered water from 345' T/ surface for camera run. @ 166 gpm, 65 psi. 01:30 02:00 0.50 345 0 COMPZ RPCOM PULD P UD Baker BHA and clear rig floor. 02:00 03:30 1.50 0 0 COMPZ RPCOM ELOG P R/U E-line, move top sheave from board to the blocks and M/U camera assembly to get video and pictures of 10-3/4 bad spots. 03:30 04:30 1.00 0 0 COMPZ RPCOM ELOG P RIH with camera assembly to 320' MD 04:30 05:30 1.00 0 0 COMPZ RPCOM ELOG P RIH with camera on E-line down to 320' MD the quality was not very good but @ 197' to 207' we found a spilt in the 10-3/4" casing. 05:30 06:30 1.00 0 384 COMPZ RPCOM TRIP P TIH with 4 stands of dp to pump 70 bbls of clean filtered water F/ surface T/ 384' MD, PUW= 35K, SOW= 35K. 06:30 07:00 0.50 384 0 COMPZ RPCOM TRIP P POOH F/ 384'T/ surface 07:00 08:30 1.50 0 0 COMPZ RPCOM ELOG P RIH with a-line and camera, Take video and pictures. 08:30 09:30 1.00 0 0 COMPZ RPCOM ELOG P R/D E-line and camera tools. Clear rig floor. 09:30 10:30 1.00 0 483 COMPZ RPCOM PULD P M/U Baker Taper String Mill BHA F/ surface T/ 483' MD, PUW= 42K, SOW= 42 Page 26 of 44 Ah Alk T,�me Lugs ;; .. Date Ffomii Tot. "., Dur F ., S. Deo th E. De th Phase Code -,Sub T !CommentDz 10:30 11:30 1.00 483 1,943 COMPZ RPCOM TRIP P ITIH F/ 483'T/ 1943' MD, PUW= 66K, SOW= 65K. 11:30 12:00 0.50 1,943 1,995 COMPZ RPCOM REAM P Tag stump @ 1943' MD, PUW= 66K, SOW+ 65K, Rot wt= 65K, 40 RPM, SPM= 87, 265 psi, Mill & ream down to 1995' MD inside of 7" casing, No torque and work several times. 12:00 12:30 0.50 1,995 1,995 COMPZ RPCOM REAM P Continue to mill & ream down to 1995' MD inside of 7" casing, No torque and work several times. 12:30 13:00 0.50 1,995 1,993 COMPZ RPCOM CIRC P CBU @ 1993' MD 10 bpm, 960 psi. 13:00 13:30 0.50 1,993 483 COMPZ RPCOM TRIP P POOH F/ 1993'T/ 483MD, PUW= 66K, SOW= 65K. 13:30 14:00 0.50 483 0 COMPZ RPCOM PULD P L/D Taper Mill BHA, F/ 483'T/ surface. 14:00 15:30 1.50 0 293 COMPZ RPCOM PULD P R/U GBR equipment and M/U 7" dummy run F/ surface T/ 293' MD, (Could not get past 293") 15:30 17:00 1.50 293 0 COMPZ RPCOM PULD P UD dummy run and R/D GBR equipment. 17:00 18:00 1.00 0 0 COMPZ RPCOM SVRG P Serevice drawworks, blocks, Top Drive and floor equipment. 18:00 20:30 2.50 0 157 COMPZ RPCOM PULD P M/U triple string mill BHA, Center of 9" mill to Bull Nose = 59', F/ surface T/ 157' MD, Tight spot @ 157' MDD. 20:30 00:00 3.50 157 198 COMPZ RPCOM REAM P Ream tight spots in 10-3/4" casing F/ 106'T/ 198' MD, Bull Nose depth. with 6.5 bpm, 198 psi, 65 RPM, Free Tq= 950, Tq on= 1.2K,- 2.6K. j7/21/2013 Continue reaming out tight area's, POOH, UD milling BHA, R/U and run 7" dummy run down to 162' MD tight spot and could not get through, UD 7" dummy BHA, Service rig, change oil in TD and saver sub, Retest same, UD 4-3/4" bumper sub / jars and magnets, Wait on and M/U 9.5" Baker triple mill BHA, tagged up @ 124' MD, L/D upper mill & one DC, because it was positioned inside the BOP stack, Ream F/ 124'T/ 126' MD. 00:00 04:00 4.00 198 382 COMPZ RPCOM REAM P Reaming tight spots in 10-3/4" casing with triple string mills F/ 198' T/ 382' MD with bullnose and 315' MD with 9" Mill, with 117 spm 220 psi, Free Tq= 950 ft /Ibs, Tq on= 3.2 K, 65 RPM, PUW= 40K, SOW= 40K, Rot wt= 40K. 04:00 06:00 2.00 382 352 COMPZ RPCOM REAM P Continue reaming tight spot at 297' MD with 9" Mill, still showing higher torque (2200 to 3100 ft/lbs) across this area from 293' to 310' MD with 9" Mill. Bull Nose depth F/ 352'T/ 379' MD. 06:00 09:30 3.50 352 106 COMPZ RPCOM REAM P Back ream F/ 352' T/ 106' MD, 80 RPM, Free Tq= 950 ft/lbs,Tq on= 3.2K, PUW= 40K, SOW= 40K, Rot wt= 40K, pump @ 117 spm, 220 psi. Worked tight spots as needed at 290', 230', 190'-160' MD. 09:30 11:30 2.00 106 0 COMPZ RPCOM PULD P L/D Baker triple mill BHA as directed. 11:30 12:00 0.50 0 0 COMPZ RPCOM OTHR tP Clear and clean rig floor off. Page 27 of 44 Time Logs x„„ rth r Dur S. De E. De th Phase, Code Subcode 'f ! Comment w. Date From �46 12:00 13:00 1.00 0 162 COMPZ RPCOM PULD P M/U 7” casing dummy run with GBR and tagged up at 162' MD. Could not get past 162' MD with 7" casing dummy run. Attempt to rotate through with 15 RPM, Free Tq= 480 fUlbs, 2 bpm, 40 psi. 13:00 14:30 1.50 162 0 COMPZ RPCOM PULD P UD 7" dummy BHA F/ 162'T/ surface. 14:30 15:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig, Drawworks, Top Drive, Blocks and Crown. 15:00 18:30 3.50 0 0 COMPZ RPCOM OTHR P Wait on 9.5" mill and x-overs from Baker, C/O oil in Top Drive, C/O saver sub on Top Drive and retest 250 low 3000 high, Good. 18:30 19:00 0.50 0 0 COMPZ RPCOM PULD P Pick up and break out 4-3/4" bumper sub, Jars and string magnets. 19:00 20:00 1.00 0 0 COMPZ RPCOM PULD P I Load shed and rig floor with 9.5" triple milling componets. 20:00 23:00 3.00 0 124 COMPZ RPCOM PULD P M/U 9.5" Triple Mill BHA F/ surface T/ 124' MD, Tagged tight spot @ 124', Had to UD upper 9.5" mill and one DC, because the mill was position inside of the BOP stack. 23:00 00:00 1.00 124 126 COMPZ RPCOM REAM P Ream out tight spots with 9.5" F/ 124'T/ 126' MD (Bull Nose Depth) @ 10 bpm, 180 psi, 70 RPM, Free Tq= 1.4K, Tq on= 3.6K, PUW= 42K, SOW= 36K, Rot wt= 37K. 7/22/2013 Ream out 10-3/4 casing F/126' T/ 208' MD, Back reamed to 83' MD and picked up rest of BHA # 37 F/ 83'T/ 161' MD, Serviced Top Drive, P/U rest of BHA # 37, Continue reaming out 10-3/4" casing tight spots F161' T/253' D. (Total metal recovered from magnets, 287 pounds.) 00:00 09:30 9.50 126 208 COMPZ RPCOM REAM P Ream out tight spots with 9.5" F/ 126'T/ 208' MD bull nose depth, @ 10 bpm, 430 gpm, 162 psi, 70 RPM, Free Tq= 1.4K, Tq on= 3.6K, PUW= 42K, SOW= 36K, Rot wt= 37K. (Pumped 10 bbl hi-vis sweep @ 02:00 hrs, Saw increase in metal returns across shakers) @ 4:30 hrs got back 30 # of metal from ditch magnets, Pumped another 10 bbl sweep 05:00 hrs. 09:30 10:30 1.00 208 83 COMPZ RPCOM REAM P Back ream F/ 208'T/ 83' MD, Bull Nose depth, with 10 bpm, 430 gpm, 162 psi, 65 RPM, Free Tq= 1.4K, On Tq= 3.OK, PUW= 42K, SOW= 36K, Rot wt= 37K. (Total of 141 pounds of metal recovered from ditch magnets.) 10:30 11:00 0.50 83 83 COMPZ RPCOM SVRG P Service Top Drive and make visual inspection of Top Drive. 11:00 12:00 1.00 83 161 COMPZ RPCOM PULD P Pick up the rest of BHA # 37 with upper 9.5" mill F/ 83'T/ 161' MD, PUW= 40K, SOW= 40K. Page- 28 of 44 Ah Ah meLo`s•w�� a1ws �, Date . Fromi To Dur S. fle th. E. De ttr Phase Code Subcode 12:00 18:30 6.50 161 245 COMPZ RPCOM REAM P Back ream F/ 161'T/ 245' MD, Bull Nose depth, with 10 bpm, 430 gpm, 190 psi, 65 RPM, Free Tq= 1.4K, On Tq= 4.OK, PUW= 44K, SOW= 40K, Rot wt= 42K. Pump sweeps every hour. 18:30 19:00 0.50 244 225 COMPZ RPCOM TRIP P Pull up F/ 244'T/ 127' MD and Celan string magnet, (60 pounds of meatl recovered) Wash down to 225' MD with 10 BPM, 190 psi. 19:00 00:00 5.00 225 253 COMPZ RPCOM REAM P Ream F/ 225'T/ 253' MD, Bull Nose depth, with 10 bpm, 430 gpm, 190 psi, 65 RPM, Free Tq= 1.4K, On Tq= 4.OK, PUW= 44K, SOW= 40K, Rot wt= 42K. Pump sweeps every hour. (Total metal recovered 146 pounds this tour) 7/23/2013 Continue to Mill 10 3/4"casing with the Triple Mill assembly from 253' to 345', pulling and cleaning 142 pounds of metal from magnets. Milled until assembly would pass and trip to 1932' without stacking out. Circulated bottoms up and POOH. MU 7" Dummy casing and ran in the hole to 1943' and tagged stump the CBU. MU and RI with Multi -Cutter and made cut at 1958' DPM. 00:00 01:30 1.50 253 253 COMPZ RPCOM REAM P Continue Mill F/ 225'T/ 253' MD, Bull Nose depth, with 10 bpm, 430 gpm, 190 psi, 65 RPM, Free Tq= 1.4K, On Tq= 4.OK, PUW= 44K, SOW= 40K, Rot wt= 42K. Pump sweeps every hour. Mill through tight spots and able to go down with out taking weight. 01:30 02:15 0.75 253 253 COMPZ RPCOM OTHR P Pull up to string magnet @ 137' MD and clean off metal from magnet, recovered 70 pounds of metal. RIH T/ 253' MD and make connection. 02:15 08:00 5.75 253 345 COMPZ RPCOM REAM P Mill F/ 253'T/ 345' MD, Bull Nose depth, with 10 bpm, 430 gpm, 190 psi, 65 RPM, Free Tq = 1.4K, On Tq = 4.OK, PU = 44K, SO = 40K, Rot wt= 42K. Pump sweeps every hour. Ream area tight spots and able to go down with out taking weight. 08:00 08:45 0.75 345 345 COMPZ RPCOM TRIP P Pull out and clean string magnets; 72 lbs recoered of metal. Wash down 127' to 345'420 GPm with 217 psi. 08:45 09:00 0.25 345 345 COMPZ WELCTL SFTY P Kick while tripping Drill; CRT 78 sec. Performed AAR, Good response with crew remaining calm and focused. 09:00 10:30 1.50 345 1,932 COMPZ RPCOM TRIP P Trip in the hole with assembly from 345' 1932'; PU - 68K, SO 68K 10:30 11:30 1.00 1,932 1,932 COMPZ RPCOM CIRC P Circulate and condition at 436 GPM with 670 psi, 60 RPM with 800 torque. 11:30 12:00 0.50 1,932 530 COMPZ RPCOM TRIP P Pull out of the hole to 530'. PU = 68K. Page 29 of 44 Ah r� Trme Log's , Date} °.:From : To , Dur. S.tDe th E. De th phase Code Subcode T =Comment 12:00 13:30 1.50 530 161 COMPZ RPCOM REAM P Back -ream out of the hole from 530' to 161' circulating 10 BPM with 295 psi, 70 RPM with 1 K torque. Work tight spots at 200' and 300'. 13:30 15:30 2.00 161 0 COMPZ RPCOM PULD P LD triple mill assembly from 161' to surface. 15:30 17:30 2.00 0 549 COMPZ RPCOM PULD P MU 7" dummy run for casing and MU assembly to 549'. 17:30 18:30 1.00 549 1,943 COMPZ RPCOM TRIP P Trip in the hole from 549' to 1943' and tag stump at 1943', pull up to 1942'. 18:30 19:00 0.50 1,942 1,942 COMPZ RPCOM CIRC P Circulate and condition hole with 13 BPM with 1130 psi. Recip and Rot at 40 RPM with 710 torque. PU = 65K, SO = 63K and ROT = 65K. 19:00 19:30 0.50 1,942 549 COMPZ RPCOM TRIP P Trip out of the hole with assembly from 1942' to 549'. PU = 65K, SO = 63K. 19:30 21:30 2.00 549 0 COMPZ RPCOM PULD P Lay down BHA, 7" Dummy I assembly. Clean and clear floor. 21:30 23:00 1.50 0 493 COMPZ RPCOM PULD P Pick up BHA, Multi -string Cutter assembly with magnets and HWDP to 493'. 23:00 00:00 1.00 493 1,993 COMPZ RPCOM TRIP P Trip in the hole with the cutter assembly to 1943' to stub, rotate into stub with 15 RPM pumping 2.6 BPM at 280 psi. Locate and confirm collar connection at 1993' with cutters and 5K down weight. 7/24/2013 Continue Make 7" casing cut at 1958' DPM. Verify cut made. CBU. POOH with cutter. Make up 7" casing spear. TIH and retreive Cut joint and fish, POOH and LD same. Fish total length 14.58' with 6.31' of collar to cut. RIH with casing dressing mill and dress casing; 1958' to 1965'. Circulate and pump high Vis sweep, POOH and LD assembly. RU 7" casing equipment and PJSM for running casing Tie -back. MU Tie -back, ES Cementer and run 46 joints 26# L-80 TCII. 00:00 01:00 1.00 1,963 1,963 COMPZ RPCOM FISH P Continue work to locate the 7" casing collar at 1992' DPM. Pull up to locate knives at 1958' DPM ( 6' below the collar) and make cut. Verify cut made with tool pressure drop; 750 psi initial pressure, 590 psi final. 01:00 01:30 0.50 1,963 1,958 COMPZ RPCOM CIRC P Circulate and condition; pump 20 BBI HV sweep 01:30 02:30 1.00 1,958 493 COMPZ RPCOM TRIP P Trip out of the hole from 1958' to 493'; PU = 65K, SO = 64K. 02:30 04:30 2.00 493 0 COMPZ RPCOM PULD P LD Multi cutter assembly as per Baker Rep. Clean and clear floor, stage tools. 04:30 07:00 2.50 0 1,961 COMPZ RPCOM TRIP P MU Spear assembly and trip in the hole to 1958'; PU = 66K, SO = 65K. Tag No -Go at 1961% spear engaged Ito fish. 07:00 08:00 1.00 1,961 499 COMPZ RPCOM TRIP P Trip out of the hole with fish and cut oint from 1961' to 499'. 08:00 10:00 2.00 499 0 COMPZ RPCOM PULD P LD BHA with fish and cut joint; total length of 14.58 with 8.27' to collar and 6.31' below to cut. Cut looked clean and straight. Paces 30 of 44 Ah Ah Date s Frorri''To Dura' S. De th tE:K3e th Phase Code Subcoie Tf""''Cori`ment 10:00 12:00 2.00 0 517 COMPZ RPCOM PULD P I MU 7" casing dressing mill and BHA from surface to 517' per Baker REp. 12:00 12:30 0.50 517 1,958 COMPZ RPCOM TRIP P in the hole with casing dress mill JTrip assembly from 517' to 1958'. 12:30 13:30 1.00 1,958 1,956 COMPZ RPCOM MILL P Dress off 7" casing stump from 1958' to 1965', repeating dressing stump. PU = 67K, SO = 65K. Test overshot without pumps; Good. Pick up to 1956' 13:30 14:00 0.50 1,956 1,956 COMPZ RPCOM CIRC P Circulate and condition; pump 20 BBL sweep high Vis and bottoms up at 13 BPM with 1300 psi while reciprocating and rotating 40 RPM with 750 torque. 14:00 15:30 1.50 1,956 0 COMPZ RPCOM TRIP P Tri out of the hole and LD Dressing assembly 15:30 17:30 2.00 0 0 COMPZ RPCOM PULD P MU mule shoe and magnets with pump -out sub. RIH and flush stack with 13 BPM with 190 psi. LD magnets and muleshoe. 17:30 19:30 2.00 0 0 COMPZ RPCOM PULD P RU 7" casing equipment to run 7' tie -back. 19:30 20:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM for running casing with GBR, Baker, Halliburton and rig crew. 20:00 00:00 4.00 0 1,955 COMPZ RPCOM RNCS P MU Tie -back, ES Cementer, and run 7" casing as per running order to 1955'; 46 joints fof 26# L-80 TCII. PU = 75K, SO = 73K. 7/25/2013 Land 7" Tie -back and PT to 2500 psi for 30 minutes; Good. Pressure up to 3450 psi and open ES Cementer. Establish circulation and RU cement equipment. PJSM for cementing. Pump 150 BBLs of 15.7 cement with 5 BBL chasing plug; 906 sacks. Plug bumped on time and PT with 1500 psi for seating/ check. Wash down lines and flush cement. Pull 75K tension on casing. Monitor well for 30 minutes: Static. ND BOP stack and no cement at surface. Perform Top Cement Job; 3 BBL cement for 62' to fill. Set casing on E -Slips with 75K tension and cut with Wachs cutter. Perform wellhead work. 00:00 01:00 1.00 1,955 1,958 COMPZ RPCOM RNCS P Land 7" Tie -back and pull test exercising at tensions of 25K and slack off, 50K and slack off, and 75K overpull and slack off. 01:00 02:00 1.00 1,958 1,958 COMPZ RPCOM PRTS P Pressure test 7" Tie -back to 2500 psi charted for 30 minutes; Good. Pressure up on ES Cementer and opened at 3450 psi. Established circulation at 5 BPM with 160 psi to verify cementer open. 02:00 02:30 0.50 0 0 COMPZ CEMEN-CMNT P WO Schlumberger to arrive; MU cement head and lines. 02:30 03:00 0.50 0 0 COMPZ CEMEN' SFTY P PJSM with SBG, Halliburton, Baker, and rig crew for cement job. 03:00 04:00 1.00 0 0 COMPZ CEMEN' CMNT P Pump 100 BBL of heated Seawater at 210 GPM with 150 psi Page 31 of 44 Ah Date From Tu Dur ' tS. De th E:`De th Phase Code Subco-de T Comrtient x . 04:00 06:00 2.00 0 0 COMPZ CEMEN- CMNT P Pump cement: 5 BBL fresh water lead after heated seawater, 150 BBL 15.7# cement at 3 BPM with initial pressure of SPP=75 psi, Cem pump=550 psi. Final pressure with 150 BBLs away; SPP=125 psi, Cem pump=485 psi. Drop closing plug with 150 BBLs away and chase with 5 BBLs cement, then 5 BBL freash water. Go to rig pumps; 375 of 1110 strokes (to bump) and cement returns were at the surface. All returns were lined up to the open top tank. 749 strokes later the plug was bumped at 1124 strokes (1110 calculated). 750 psi was final circulating pressure and the plug was bumped and set at 2250 psi to close ES Cementer. 06:00 07:00 1.00 0 0 COMPZ CEMEN- CMNT P Flush and clean lines and blow down. Circulate citric and D110 around to retard returns and truck loads. Monitor well for 30 minutes: Static. 07:00 07:30 0.50 0 0 COMPZ CEMEN' CMNT P RD cement head and equipment. 07:30 09:00 1.50 0 0 COMPZ CEMEN- CMNT P ND BOPE, remove riser, break bolts and raise stack; no cement at surface. Require a Cement top job. Call out cementers. 09:00 09:30 0.50 COMPZ RPCOM SVRG P Service rig and equipment. 09:30 13:30 4.00 COMPZ CEMEN- CMNT P Clean rig lines, pits, and tanks to remove all cement returns. WO cementers. 13:30 15:30 2.00 COMPZ CEMEN- CMNT P Perform Top Cement Job; pump 3 BBL to fill 10 3/4 X 7 for 62' with cement. RD cementers. 15:30 16:00 0.50 COMPZ WHDBO CMNT P Pull 75K tension on casing and set Emergency Slips as per FMC rep. 16:00 17:30 1.50 COMPZ WHDBO CMNT P RU Wachs cutter and cut 7" landing casing with a Cut-off length of 26.29' of 41.11' joint to leave 14.82' in hole. 17:30 20:00 2.50 COMPZ WHDBO RURD P Rack back BOP stack and begin install of pack -offs. 20:00 21:00 1.00 COMPZ WHDBO RURD T WO FMC to get longer spacer for pack -off. Spacer brought out not proper length. 21:00 23:30 2.50 COMPZ WHDBO RURD P Install pack -off as per FMC rep. 23:30 00:00 0.50 COMPZ WHDBO RURD P MU DSA to tubing spool and set onto well head. 7/26/2013 Continue to NU BOPE. When changing rams, cement was found in the stack and ram cavities. Opened ram doors and cleaned cement. Changed bottom rams to 3 1/2 X 6" VBRs. Test BOPE: Good test. Waived test witness by AOGCC, Jeff Turkington; 07:30 7/24/2013. LD testing equipment and install wear bushing; 10 11/16" OD X 9", 1' long. Page 32 of 44 r 1 Ah. is e Logs mN"Gim kii ada .R 'x w33'W Date :, From T'"0wth. De th Phase Gode Subcode 7� .tComment" 00:00 06:30 6.50 0 0 COMPZ WHDBO NUND P NU BOPE; install spool and BOP stack, change out Kill line flange, and pressure test pack -off to 3500 psi for 10 minutes'; Good. Install turnbuckles and riser. Install Secondary Annulus valve. 06:30 12:00 5.50 COMPZ WHDBO NUND P Change out bottom rams to 3 1/2" X 6" variables. Open blind rams cavity to clean out cement. 12:00 16:30 4.50 COMPZ WHDBO NUND P Open blind rams and top rams and clean out cement. close and torque all bolts. 16:30 17:30 1.00 COMPZ WHDBO NUND P RU to test, MU test joint, fill stack and choke manifold. Test Sierra rig monitoring alarm system. 17:30 20:30 3.00 COMPZ WHDBO BOPE P Test BOPE: Test witness waived by AOGCC, Jeff Turkington; 19:30 7/24/2013. Test Ann, LVBR, UVBR with 3 1/2" test joint, Kill, Standpipe, HCR and Manual choke & Kill, Chokes 1-11 & 14-16, HT -38 FOSV and IBOP, Upper IBOP and Lower Kelly valve with 250 psi low and 3000 psi high, charted good tests. 20:30 21:00 0.50 COMPZ WHDBO BOPE P Koomey drawdown test; Starting P = 3025 psi. After closing P =1750 psi. Initial 200: 17 sec recovery, Full rec 92 sec.5 BU bottles with 2150 psi avg. Electric pump efficiency 40 sec, Air 290 sec. Closing times: ANN=18 sec, LVBR, UVBR and Sim Blinds= 6 secs each. "HCR, CH and Kill=1 sec each. 21:00 22:30 1.50 COMPZ WHDBO BOPE P Test Blinds, CH 12, 13, Inner and outer 2 1/16" test spool valves with 250 psi low and 3000 psi high. 22:30 23:00 0.50 COMPZ WHDBO NUND P BD test equipment and LD test joint. 23:00 00:00 1.00 COMPZ WHDBO NUND P Install wear bushing 10 11/16" OD X 9" ID, LD runing equipment. 7/27/2013 Mu 6 1/8" Drill -out assembly and RIH to 1775' hitting stringer. Wash down stand and tag TOC at 1810'. Drill cement with 8 BPM 760 psi, 92 RPM with 1-2K Torque. Drill through ES Cementer @ 1945', as per Baker rep. recommendations, with light WOB and high RPMs. Continue wash down through 7" to tag junk at 2168'. Attempt to wash or drill through with no success. CBU, POOH lay down BHA. Inspect and grade bit to 0/0. Recovered 30# of iron on the magnet, nothing in Junk baskets. Make up 5 3/4" Reverse basket assembly, TIH to tag junk at 2171'. Drop ball and mill through junk to 2177' with 60 RPMs, 8 BPM - 1900 PSI. Observed WOB stayed steady, and penetration rate stopped. POOH, breakout and inspect Reverse basket assembly recovering 4# of iron on magnets and small metal pieces in junk basket. 00:00 02:15 2.25 0 503 COMPZ WELLPF PULD P I PU BHA #42, 6 1/8" Drill -out assembly as per Baker rep. to 503.0 02:15 02:30 0.25 503 503 COMPZ WELCTL SFTY P Perform Kick while Tripping Drill; CRT = 45 sec, announced drill: Good response time and everyone reporting to stations in very timely manner. Page 33 of 44 S TameLo's.J,..kgp Dafe From:''" Tw' tour S. De th E: De th Phase .Code` Subcode T t Cbm' dht � , ,- 02:30 03:30 1.00 503 1,810 COMPZ WELLPFTRIP P Trip in hole to 1775' hitting cement stringers, Kellly up and wash down to 1810' TOC. Bring mud weight up gradually while drilling cement to 9.2 PPG. Correct displacement observed on trip. 03:30 04:30 1.00 1,810 1,944 COMPZ WELLPF DRLG P Drill cement with 8 BPM, 760 psi while Rotating at 93 RPM with 1-2K Torque from 1810'- 1944'. 04:30 07:45 3.25 1,944 1,948 COMPZ WELLPF DRLG P Drill up ES Cementer and cement as per recommended procedure from HES. Lightweight, higher RPM's. 07:45 08:45 1.00 1,948 2,171 COMPZ WELLPF WASH P Continue wash down from 1948'to tag junk (iron) at 2168'. wash down with junk to 2171' until stopped. Attempt to rotate through, no go. Repeat attempts, and set down 15-20K. 08:45 09:15 0.50 2,171 2,171 COMPZ WELLPFCIRC P Circulate & condition mud (viscosified water) @ 8 BPM - 750 PSI, prep for casing test. 09:15 10:30 1.25 2,171 2,171 COMPZ WELLPF PRTS P Rig up lines, and chart recorder. Pressure doiwn kill line and drill pipe to test casing to 3000 PSI - 30 minutes on chart. Good test, bled back 100 PSI in 30 Min. Bleed pressure, Rig down test equipment. 10:30 12:00 1.50 2,171 0 COMPZ WELLPF TRIP P POOH with BHA. Observed correct displacement. 12:00 13:00 1.00 0 0 COMPZ WELLPF PULD P Clean magnets, recovering 30# of iron. Continue breakout & lay down BHA. Clean Junk Baslets recovering little iron. Inspect bit. Bit grade = 0/0/NO/A/1/NO/BHA. Observed a few iron cuttings wedged in bit. Lay down tools. 13:00 13:30 0.50 0 0 COMPZ WELLPF SFTY P Clean & clear rig floor, and pull tools to rig floor for next BHA. Held PJSM with Crew. Discuss safety & Hazard recognition issues. Discuss procedure to make up and run BHA. 13:30 14:00 0.50 0 512 COMPZ WELLPF PULD P Make up BHA # 43, 5 3/4" Reverse basket assembly. Total BHA length = 511.76'. 14:00 15:00 1.00 512 2,171 COMPZ WELLPF TRIP P Trip in hole with BHA # 43. Observed proper displacement. Obtain parameters. Up Wt = 69K, SO WT = 69K. ROT WT = 69K. Pumps at 8 BPM - 1000 PSI. Drop 7/8" ball, and allow to seat in the reverse basket. New pump pressure at 8 BPM - 1900 PSI. Page 34 of 44 Ah Tiir06 Lo `s� � Wlnft bate From' To Dur .•S. De fh E. De th Phase ode,^ Subcode T Commeh4 _ :a,... . 15:00 16:00 1.00 2,171 2,177 COMPZ WELLPF FISH P Tag junk at 2171' DPM. Rotate down milling up allowing junk to get inside basket. Continue follw junk to 2177' DPM, with 10-15K WOB, until oberved penetration rate stopped and pump pressure remained constant. Observed a 300 PSI pressure loss, but torque remained steady, with WOB. Pumps off, blow down top drive. 16:00 17:00 1.00 2,177 0 COMPZ WELLPF TRIP P POOH with BHA #43. Observed proper displacement. 17:00 18:30 1.50 0 0 COMPZ WELLPF PULD P Breakout & lay down BHA. Clean magnet, recovering 15 lbs of iron. Breakout reverse basket assembly. Recovered 3 small pieces of metal in junk basket. 18:30 19:30 1.00 0 511 COMPZ WELLPF PULD P MU same assembly after cleaning and RIH to HW. 19:30 20:00 0.50 511 2,120 COMPZ WELLPF TRIP P Trip assembly to 2120' observing correct displacement. 20:00 21:00 1.00 2,120 2,190 COMPZ WELLPF FISH P Establish circulation with rotation; 8 BPM with 1650 psi. PU=68K, SO=68K, Rot=68K. 65 RPM with 1.9K Torque. Push junk from 2177' to 2190' before stacking out with 15K DN WT. 21:00 21:30 0.50 2,190 1,268 COMPZ WELLPF TRIP P Monitor well, Blow down Top Drive and POOH to 1268'. 21:30 21:45 0.25 1,268 11268 COMPZ WELCTL SFTY P Kick While Tripping Drill: Pitwatch initiated drill with simulated 15 BBL gain, motorman on brake. CRT = 95 sec, well secured in 65 sec. Held AAR to discuss drill and assess. 21:45 22:00 0.25 1,268 1,268 COMPZ WELLPF SFTY P DROP object meeting for discussion following AAR. 22:00 22:30 0.50 1,268 511 COMPZ WELLPF TRIP P Trip out of the hole to HW observing proper displacement. 22:30 00:00 1.50 511 0 COMPZ WELLPF PULD P Stand back collars, and BD BHA; Rev basket and clean magnets. Recovered 3 small pieces of casing and —3 lbs of metal. 7/28/2013 Continue to clean BHA, recovering 3 pieces of metal and 3# of metal from magnets. MU BHA and RIH to 2275'. At connection during rig service it was found the topdrive lubricator pump was not operating. Trouble -shooting and repairs were performed. RIH tag junk at 2275' and mill junk to 2441' circulate and clean hole. POOH and assess recovery; parts of 7" centralizers and numerous other pieces, 25#. Rerun BHA, TIH and tag junk at 2440'. Wash to 2451', circulate and recip and POOH. BD BHA and recovered 7 1/4" piece of 7" casing. Several small pieces of casing and 3 gallons of sand. Boot baskets contained 12 pieces of milled casing, centralizers and 15# of metal cleaned from magnets. Rerun BHA, TIH to 2450' and tagged sand. Washed junk and sand to 2473', circulated high vis sweep and POOH. LD BHA and recover 1 small piece of metal and 15# from the magnets. Make up IBP Retriever Head Catch assembly and RIH. Tag sand at 2473' and wash down to 2480'. 00:00 01:00 1.00 0 511 COMPZ WELLPF PULD P Clean up magnets and PU same I BHA and RIH with collars and HW. Page 36 of 44 Ah n ,. TT►me frogs77 t. gate y=° From' h fca ,. Dur S. De fh E. De tFi` F'hase Code " ! 5ubcode :. T 'Comment 01:00 01:30 0.50 511 2,275 COMPZ WELLPF TRIP P Trip in the hole to 2275' and tag with 10K DN WT. Obsered proper displacement on TIH. MU topdrive to circulate down. 01:30 02:30 1.00 2,275 2,275 COMPZ WELLPF FISH P Establish circulation 8 BPM with 1630 psi, Rot 70 RPM with 1.5K Torque. PU=70 SO=68, Rot=69K. Observed issues with top drive. Pick up off bottom. 02:30 07:00 4.50 2,275 2,275 COMPZ RIGMN7 RGRP T Service topdrive and drawworks; during service the lubricator pump on the topdrive was not operating. Trouble -shooting was performed while the mechanic and electrician were called to the rig. Repairing Lubricator pump on Top Drive. Repair electrical connection. 07:00 09:00 2.00 2,275 2,441 COMPZ WELLPF FISH P Trip in hole with Reverse basket assembly to tag junk at 2275'. Obtain parameters. Up Wt = 70K, SO WT = 68K. ROT WT = 69K. TQ @ 1000 Ft/lbs. Pumps at 8 BPM - 1630 PSI. Continue wash junk allowing reverse basket to catch junk iron. Chase junk down to top of sand. Dry drill junk on top of sand observing increased torque to 3500 Ft/lbs. Make 5' into the sand top to 2441' DPM. 09:00 10:00 1.00 2,441 512 COMPZ WELLPF TRIP P POOH with BHA, observing proper displacement. Monitor well at the BHA. 10:00 12:00 2.00 512 0 COMPZ WELLPF PULD P Breakout reverse basket assembly. Observed basket full, recovering 19" piece of the split 7" casing, along with numerous big pieces of casing and centralizer arms. Clean off magnets, with a total of 25# recovered iron. Observed on the reverse basket cages, that all inside fingers broke off. Crew Change. 12:00 12:30 0.50 0 512 COMPZ WELLPF PULD P Continue clean magnets, and make up BHA # 45 (rerun) with new head and baskets. 12:30 13:15 0.75 512 2,441 COMPZ WELLPF TRIP P Trip in hole with BHA #46. Observed correct displacement. Obtain parameters. Up Wt = 70K, SO WT = 68K. ROT WT = 69K. TQ @ 1000 Ft/lbs. Pumps at 8 BPM - 1630 PSI. 13:15 14:00 0.75 2,441 2,451 COMPZ WELLPF FISH P Tag and dry drill on top of sand at 2441', down to 2444'. Observed increase torque allwing shoe to mill up junk iron. Brings pumps up to swallow junk, after making a total of 10' in the sand down to 2451' DPM. 14:00 15:30 1.50 2,451 512 COMPZ WELLPF TRIP P POOH with BHA #46, observing correct displacement. Monitor well at the BHA. Page 36 of 44 F_ 1 Ah Time,Logs l �� k s r DF eDate T #Cotmen--fm t 15:30 16:30 1.00 512 0 COMPZ WELLPF PULD P Breakout reverse basket assembly. Observed basket packed off with sand and full. Recovered another 7" x 2 1/2" piece of 7" split casing, along with more centralizer pieces, and milled iron. Clean magnets recovering 15# of iron , and 7" centralizer chunks in boot baskets. 16:30 17:00 0.50 0 512 COMPZ WELLPF PULD P Make up BHA #47, (re -run). 17:00 19:15 2.25 512 2,473 COMPZ WELLPF TRIP P Trip in hole with BHA #47, observing correct displacement. Tag top of sand at 2151. Obtain parameters. Up Wt = 70K, SO WT = 68K. ROT WT = 69K. TQ @ 1000 Ft/lbs. Pumps at 8 BPM - 1630 PSI. Wash down through sand to 2473' DPM ( 8' above top of IBP). Observe sand returns on shakers. 19:15 19:30 0.25 2,473 2,473 COMPZ WELLPF TRIP P Blow down Topdrive and lines. PJSM for POOH. 19:30 20:00 0.50 2,473 511 COMPZ WELLPFTRIP P Trip out of hole observing proper displacement to HW. Monitor well - Static. 20:00 22:00 2.00 511 0 COMPZ WELLPF PULD P Stand back HW and lay down reverse circ shoe and recover 1 piece of metal. Junk baskets empty, clean magnets and recover 15# of metal. LD double -pin sub. 22:00 23:00 1.00 0 497 COMPZ RPCOM PULD P MU BHA with IBP retrieveing head, magnets, bumper sub and pump -out sub. PU collars and HW. 23:00 23:30 0.50 497 2,473 COMPZ RPCOM TRIP P Trip in the hole to 2473' and tag sand. Proper displacement recorded Ion trip. 23:30 00:00 0.50 2,473 2,480 COMPZ RPCOM MPSP P Pick up and wash down to 2480' with 8 BPM, 1050 psi. PU= 73K, SO= 70K. Circulate at 2480'. 7/29/2013 Continue to wash down to Upper IBP, engage IBP, deflate and equalize. Pull IBP free and trip out of the hole. LD IBP and RIH to engage Lower IBP. Engage Lower IBP, CBU and POOH. Make up Overshot fishing assembly and RIH to 5181' and tag fish. Pipe was worked up and down with 15K to engage fish. Gained 1 foot to 5182' engaging fish. Well was monitored for 10 minutes with slight flow tapering off. Circulated BU to ensure 9.6 ppg around the hole. Monitored Static. POOH to HW and monitor= Static. 00:00 01:15 1.25 2,480 2,480 COMPZ RPCOM MPSP P Washed down to IBP and pumped 2 high vis sweeps around. Circulate at 8 BPM, 1050 psi. PU= 73K, SO= 73K. Pigm 37 of 44 Ah Ah Tiime Lo" s a " Date From' To Dur S. De th E. De th' Phase . Code Subcode T Comii enf i 11 ii 01:15 02:30 1.25 2,493 2,493 COMPZ RPCOM MPSP P Reduced pumps to 4 BPM, 200 psi and circulated down to the top of the retrieving stem. Observed a pressure increase at the retrieving head overshot. Shut off pumps and slacked off to 2487' with 5K down weight the overpulled 5K, slacked to 1 OK down and overpulled 1 OK and allowed IBP to deflate and equalize for 15 minutes. Slacked off and pumped 2 BPM, 280 psi and work 10K up and down overpulls. IBP pulled free with 75K indicated weight. 02:30 04:00 1.50 2,493 497 COMPZ RPCOM TRIP P POOH with IBP. Observed proper displacement and no swabbing issues. 04:00 05:00 1.00 497 0 COMPZ RPCOM PULD P Breakout and lay down IBP assembly. Observed 1 of 8 of the collets broke on retrieving tool. 05:00 06:30 1.50 0 497 COMPZ RPCOM PULD P Make up BHA # 49, second run of IBP retrieving tool. Repair the collet. 06:30 10:00 3.50 497 5,701 COMPZ RPCOM TRIP P Trip in hole with BHA #49 to 5701' DPM. Observed proper displacement. Obtain parameters. UP WT = 120K, SO WT = 116K. 10:00 11:00 1.00 5,701 5,725 COMPZ RPCOM FISH P Wash down to top of IBP at 5725' to engage. Set down to verify, and then pull 1 OK over to verify catch. Repeat until free, and allow IBP to deflate. Slowly slack off with movement down hole to verify free. Pull up 20' verify no swabbing issue. 11:00 12:00 1.00 5,725 5,725 COMPZ RPCOM CIRC P Drop bar for Pump out sub. Pressure to 2200 PSI to open circ sub. Circulate bottoms up with pumps at 125 GPM - 250 PSI. no gas observed at bottoms up. Crew change. 12:00 12:30 0.50 5,725 5,725 COMPZ RPCOM OWFF P Complete circulate bottoms up. Monitor well - static. 12:30 15:30 3.00 5,725 497 COMPZ RPCOM TRIP P POOH with BHA #49, and fish. Observed proper displacement, with no swabbing issues. 15:30 16:00 0.50 497 497 COMPZ RPCOM OWFF P Monitor well - static. Held PJSM with Crew. Discuss safety & hazard recognition issues. Discuss procedure to breakout & lay down BHA. 16:00 17:00 1.00 497 0 COMPZ RPCOM PULD P Breakout & lay down BHA, rcovering IBP. Clean string magnet with 4# of iron recovered. Send tools out, and pull tools to rig floor. 17:00 18:30 1.50 0 494 COMPZ RPCOM PULD P Make up BHA #50, 5 7/8" overshot with 4 3/4" grapple, magnets, oil jars and pump out sub. PU drill collars and HW and RIH to 494'. 18:30 21:00 2.50 494 5,793 COMPZ RPCOM TRIP P Trip in the hole from 494' to 5793'; PU= 125K, SO= 123K. Proper displacement observed. Page 38 of 44 r\ Ah Date From . To Dur. S. De th "E` De th Phase Code Subcode Ti Cordmentlih 21:00 21:30 0.50 5,793 5,878 COMPZ RPCOM FISH P Establish circulation with 4 BPM and 430 psi. Slack off to 5881' and stack 15K down weight, picked up and slacked off again and realized 1 ' deeper to 5882' engaging fish. Pull up to 5878' and monitor well with slight flow. 21:30 22:30 1.00 5,878 5,853 COMPZ RPCOM CIRC P Pick up string to 5853' and circulate bottoms up with 5 BPM at 665 psi with 9.6 brine. Check mud weight at BU; 9.6 ppg. 22:30 00:00 1.50 5,853 4,088 COMPZ RPCOM TRIP P Monitor the well Static. BD topdrive and POOH to 4088; PU= 97K, SO= 90K. Crew change. 7/30/2013 POOH with fish; XO and muleshoe. Make up Tubing Overshot/Dressoff Assembly and trip in the hole. Dress over tubing stub at 5884' DPM and engage tubing seal assembly. Pull and jar without success. Performed Rig and derrick inspection post jarring operations. Slip and Cut drill line. 00:00 01:30 1.50 4,088 494 COMPZ RPCOM TRIP P Trip from 4088' to 494' observing proper hole displacement. PU= 97K. Monitor well at the HW; Static. 01:30 02:30 1.00 494 0 COMPZ RPCOM PULD P Pull out standing back HW and drill collars. Breakout & lay down OS Assembly. Recovered Bullnose & Crossover Fish. Clean & clear rig floor. 02:30 04:00 1.50 0 490 COMPZ RPCOM PULD P MU BHA; Tubing Overshot/Dressoff assy. PU drill collars and HW Itripping in the hole to 490'. 04:00 06:30 2.50 490 5,883 COMPZ RPCOM TRIP P Trip in the hole to 5883'; PU= 157K, SO= 118K. Install blower hose on topdrive. PU single from pipeshed and Make up. Observe proper displacement. 06:30 10:30 4.00 5,883 5,884 COMPZ RPCOM FISH P Wash over tubing stump at 5884', slack off to stack out at 5891'. Test engagement of grapple; Good. Pick up and bleed jars for straight pull to 35K Over, slack to cock jars, hit jars at 30K, then overpull 50K. Repeat this operation 88 times then release grapple. No progress with pulling seal assembly free. 10:30 12:00 1.50 5,884 5,884 COMPZ RPCOM SVRG P Service topdrive and perform Derrick inspection post jarring operations. Crew change. 12:00 13:00 1.00 5,884 5,884 COMPZ RPCOM SVRG P Continue with derrick inspection until complete. Monitor well; Static. 13:00 14:00 1.00 5,884 5,880 COMPZ RPCOM FISH P Wash over tubing stump with 4 BPM, 465 psi at 5884', slack to 5891'. Engage fish and jar for straight pull to 35K Over, slack to cock jars, hit jars at 40K, then overpull 60K. Repeat this operation 22 times then release grapple. No success freeing seal assembly. 14:00 17:00 3.00 5,880 490 P Trip out of the hole to 490' with ICOMPZIRPCOM,TRIP proper displacement. Page 39 of 44 Ah r Time lo's ��. =h Bate From To Dur S. De tW t?be th Phase Code Subcode T Carn'ment .. - h 17:00 18:30 1.50 490 0 COMPZ RPCOM PULD P Monitor well at HW; Static. Stand back HW and drill collars. Lay down Overshot, Dressoff shoe, XO, top extension sub as per Baker rep. 18:30 20:00 1.50 0 492 COMPZ RPCOM PULD P MU Dressoff shoe, washpipe and dressoff mill as per Baker rep. PU drill collars and HW 20:00 22:30 2.50 492 5,694 COMPZ RPCOM TRIP P Trip in the hole with assembly to 5694' observing proper hole displacement. 22:30 23:30 1.00 5,694 5,694 COMPZ RPCOM SLPC P Cut and slip 116' of drill line. 23:30 00:00 0.50 5,694 5,694 COMPZ RPCOM SVRG P Service rig and topdrive. 37/31/2013 Mill -1' of tubing stump and circulate clean with 2-15 BBL High Vis sweeps. Monitor well= Static. POOH and lay down milling assembly. Pick up Scraper assembly with Bott baskets and magnet then RIH to 5886' and wash over stub. Circulate surface to surface with 8 BPM. Circulate and displace well with clean 9.6 Brine. 1:1 returns on circulation. POOH sideways and lay down scraper assembly. 2# of metal recovered from magnets with no recovery in the Boot Baskets. 00:00 00:30 0.50 5,694 5,694 COMPZ RPCOM SVRG P Service rig brakes and calibrate block position. 00:30 03:30 3.00 5,694 5,886 COMPZ RPCOM MILL P PU single from the pipeshed and RIH and tag stump at 5884' with 139 strokes and 1800 psi, when nose mill entered tubing strokes decreased to 133 and 2150 psi was observed. Milled -1' of tubing with 8 BPM at 2150 psi on bottom, 60 RPM with 2K Torque and free torque of 1.6K and 1860 psi off bottom. Mill to 5886'. Circulate 2X High Vis sweeps around; 15 BBL and 20 BBL. 03:30 05:00 1.50 5,886 5,886 COMPZ RPCOM CIRC P Monitor well with slight flow through tubing, SPR were taken and another 1/2 bottoms up was circulated to ensure balance. Monitor well; Static. 05:00 07:30 2.50 5,886 492 COMPZ RPCOM TRIP P Remove Topdrive blower hose. Trip out of the hole to 492; PU= 125K, SO= 114K. Observed proper hole fill. 07:30 08:30 1.00 492 0 COMPZ RPCOM PULD P Stand back HW and drill collars to BHA and laid down Milling assembly. Mills were inspected and found in good shape. 08:30 10:00 1.50 0 519 COMPZ RPCOM PULD P Make up Scraper BHA and run in the hole to 5197 10:00 12:00 2.00 519 3,641 COMPZ RPCOM TRIP P Trip in the hole to 3641' and crew change. PU= 90K, SO= 85K. 12:00 13:30 1.50 3,641 5,880 COMPZ RPCOM TRIP P Trip in the hole to 5880' 13:30 14:00 0.50 5,880 5,880 COMPZ RPCOM CIRC P Establish circulation with 4 BPM , 530 psi. Slack down to stump at 5886' and tag with tubing dressoff mill with 5K down weight and 35 psi increase when entering with nose mill. Circullae surface to surface with 8 BPM, 1826 psi. Page 40 of 44 Ah r1 Time `Lo ` s ti flue From' o Dur S. Dei th t tie th Phase Code" Subcoc e T Comment ' 14:00 14:30 0.50 5,882 5,845 COMPZ RPCOM CIRC P Displace hole with clean 9.6 Brine circulating and reciprocating from 5882' to 5845', 10 RPM with 2K torque. 9 BPM, 2660 psi. PU= 127K, SO= 118K, Rot= 122K. Dispalced 207 BBLs having 1 to 1 returns to rig. 14:30 15:00 0.50 5,845 5,845 COMPZ RPCOM OWFF P When shakers were clean with returns, Monitor well for flow; Static. 15:00 21:00 6.00 5,845 519 COMPZ RPCOM TRIP P POOH laying down 3.5" drill pipe. Blow down topdrive and continue to 519'. Observed proper returns on trip. 21:00 21:15 0.25 519 519 COMPZ RPCOM SFTY P Kick while tripping drill: well secured in 45 sec, CRT= 75 sec. Perform AAR to discuss drill performance. 21:15 00:00 2.75 519 0 COMPZ RPCOM PULD P Monitor well; Static. Lay down HW, DC and BHA. 2# of metal recovered from magnets and boot baskets had no recovery. laid out and broke down Baker tools as per Baker rep. 38/01/2013 Continue to lay out tools from BHA and clear and clean floor. Flush stack with magnets. Stage completion equipment and rig up. PJSM for running tubing. Run 3.5" completion as per tubing tally and Baker rep. High line power and rig power loss. Run tubing to seat PB OverShot and seals tagged -22 feet high. Call out wireline and perform a je Iry locate run. Rigged down E -line equipment. 00:00 01:30 1.50 0 0 COMPZ RPCOM PULD P Remove wear bushing and flush stack with J whacker and magnets. Magnets recovered 1# metal. 01:30 10:30 9.00 0 5,860 COMPZ RPCOM RCST P Run completion string as per running tally. MU torque 2200 ft -lbs, run to 5860' with PU= 76K, SO= 73K. Run in and tag early -22', re -strap tubing in the shed with no discrepancies. Crew change 0900. 10:30 12:00 1.50 5,886 5,886 COMPZ RPCOM CIRC P Circulate and condition while assessing early tag up. 12:00 13:30 1.50 5,886 5,886 COMPZ RPCOM CIRC P Circulate and condition. LD jt 184 an MU 12" pup to get to the floor; working height. 13:30 14:00 0.50 5,886 5,886 COMPZ RPCOM CRIH P Circulate and place corrosion inhibitor displacing to leave 6 BBLs inhibitor in the tubing. 14:00 17:00 3.00 5,886 5,886 COMPZ RPCOM RGRP T Loss of Highline power and rig power would not come online. Trouble -shoot and restore power. 17:00 17:30 0.50 5,886 5,892 COMPZ RPCOM RCST P Slack down with overshot and seat confirming with pressure and shear pins. Set down with 20K and confirm position and operations for setting packer. 17:30 19:00 1.50 5,892 5,892 COMPZ RPCOM ELOG T Decision made to call out E -line to perform a Jewelery Locate run. Wait for E -Line to show to location. Trouble time is for the tally discrepancy. E -line is part of the trouble shooting, not the problem. Page 41 of 44 Ah r-1 Date. r From hTo Dur S. De th E.'De th=Phase .Code Subcod" F T= Comment . 19:00 21:00 2.00 5,892 5,892 COMPZ RPCOM RURD T RU E -Line and equipment to run logs. Trouble time is for the tally discrepancy. E -line is part of the trouble shooting, not the problem. 21:00 22:00 1.00 5,892 5,892 COMPZ RPCOM ELOG T Run logging run for Jewelery locate. Run Gamma tools and CCL. Trouble time is for the tally discrepancy. E -line is part of the trouble shooting, not the problem. 22:00 23:30 1.50 5,892 5,892 COMPZ RPCOM ELOG T POOH with E -Line. Trouble time is for the tally discrepancy. E -line is part of the trouble shooting, not the problem. 23:30 00:00 0.50 5,892 5,892 COMPZ RPCOM ELOG T Rig down E -Line unit and equipment. Trouble time is for the tally discrepancy. E -line is part of the trouble shooting, not the problem. 8/02/2013 Service rig. Assessment of logging run found the overshot to be in place and tally summed over throughout the run to add to —22 feet high at the surface. Set packer with 3700 psi and sheared simultaneaously, pressured up to 4000 psi to insure packer set. Pull test pulled free, so a pressure check was performed on the IA to make certain seals were still in place and holding. Tested good to 500 psi with no flow show up the tubing. Pull two joints; 183 and 182 and lay down to space -out. MD 8' pup, jt 182, tubing hanger and landing jt. Land hanger and RILDS. Pressure test tubing and IA; Good. ND BOPE, orient tree as per DSO and NU Tree. Test Tree; Good. RU to Freeze Protect well. 00:00 00:30 0.50 5,892 5,892 COMPZ RPCOM SVRG P Service rig and topdrive. 00:30 02:00 1.50 5,892 5,892 COMPZ RPCOM OTHR P Assess plan forward and stage equipment for contigencies. Decision to move forward with completion in place as is and reconcile tally depths with WLM, as to ed by E -line. 02:00 03:30 1.50 5,892 5,892 COMPZ RPCOM PRTS P Drop ball and rod and pressure set packer to 4000 psi for 10 min. When packer set at 3700 psi the pins also sheared. Pressured to 500 psi on the IA to insure seal reatined inte rit - Good check with no flow. 03:30 04:00 0.50 5,892 5,818 COMPZ RPCOM RCST P Lay down 12' pup, jt183 and 182. PU= 72K 04:00 04:30 0.50 5,818 5,857 COMPZ RPCOM RCST P MU 8.22' pup, jt182 for space out. 04:30 05:00 0.50 5,857 5,857 COMPZ RPCOM RCST P Change out bails to long bails for well control contingency planning. 05:00 07:00 2.00 5,857 0 COMPZ RPCOM RCST P Drain stack, MU hanger and landing joint. Land hanger, RILDS, LD tubing handling equipment. Clean and clear floor. Crew change. 07:00 09:30 2.50 0 0 COMPZ WHDBO PRTS P PT tubing 250/3000 psi for 30 minutes. Bleed tubing to 1500 psi and PT IA 250/2500 psi for 30 minutes; both tests good. Bleed both sides to 0 psi. Pressure IA and shear SOV at 2300 psi. Pump 5 BBL 9.6 Brine down IA at 2 BPM with 175 psi, 3 BPM with 310 psi. Page 42 of 44 I"ogs �.. ", £3. 0 "!Time Date Frorn fo ,Dur„nu 5. De #h E. De #h Phase Code Subcod” 1Tu Comm ht ` a' 09:30 11:00 1.50 0 0 COMPZ WHDBO PRTS P Dry rod in BPV and test with 1000 psi from below. Bleed to 0 psi and monitor well for 30 minutes with both sides open to atmosphere; Static. 11:00 12:00 1.00 0 0 COMPZ WHDBO NUND P ND BOPE, blow down lines and RD choke manifold and kill lines, mud cross and hole fill lines. 12:00 14:30 2.50 COMPZ WHDBO NUND P Continue to blow down lines and RD lines, rinse stack and rack back on pedestal 14:30 17:00 2.50 COMPZ WHDBO NUND P ND DSA, FMC prep tubing head and hanger, install SBMS seals, NU adapter. Tree orientation confirmed by DSO (Mick Estes). 17:00 18:00 1.00 COMPZ WHDBO PRTS P Pressure test Adapter/hanger neck seals with 250/5000 psi for 10 minutes; good. 18:00 19:00 1.00 COMPZ WHDBO NUND P NU Tree as per FMC rep. 19:00 22:00 3.00 COMPZ WHDBO PRTS P FMC rep pull BPV and install TWC valve. Pressure test tree to 250/5000 for 10 minutes; Good. 22:00 23:30 1.50 COMPZ WHDBO RURD P Prepare cellar and wellhead, pull TWC valve. RU to freeze protect well. RU LRS and check line up and lines. 23:30 23:45 0.25 COMPZ WHDBO SFTY P PJSM for freeze protect of well with LRS, mud engineer and rig crew. Discussed displacement and safety, knowing where 100% our fluids are 100% of the times. Line up, walk the lines, duck ponds under all connections and procedure. 23:45 00:00 0.25 COMPZ WHDBO FRZP P PT LRS service lines to wellhead. 8/03/2013 Freeze protect well with 212 BBLs diesel at 2 BPM with 700 psi while maintaining 1 for 1 displacement. RU lubricator per FMC and install ISA BPV. Final pressures on IA= 0 psi and Tubing= 0 psi. RD valves on tree and install VR plugs. Test flanges to 5000 psi for 10 minutes. RD lines and clean and clear cellar for move. Release rig at 12:00 8/3/2013. RDMO to 1A-07. 00:00 02:00 2.00 COMPZ WHDBO FRZP P Pump freeze protect diesel at 2 BPM with initial P= 700 psi and final P= 700 psi with a peak pressure of 1400 psi with 180 BBL away. At 212 BBL, pumping was stopped with diesel returned to surface. Shut down with 0 psi on tubing. 02:00 02:30 0.50 COMPZ WHDBO RURD P Blow down all lines and RD for tree 02:30 04:00 1.50 DEMOB MOVE RURD P Stage and PU lubricator as per FMC rep. Test to 2000 psi- Good. With 0 psi on tubing BPV was set. Test BPV for 10 minutes at 1000 psi. RD lubricator. 04:00 06:30 2.50 DEMOB MOVE RURD P Clean and clear cellar, set VR plugs and remove valves. Install companion flanges on IA, OA and test to 5000 psi for 10 minutes. Page 43 of 44 06:30 12:00 5.50 �DEMOBJMOVE �RURD IP �RD rig and prepare to lay down derrick. Rig Released at 12:00 8/3/2013 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jewelry Log: 1 A-08 Run Date: 8/1/2013 Dr AUG 19 2013 / \-1/2013 M K BENDER August 2, 2013 , 2323 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1A-08 Digital Data in LAS format, Digital Log Image file 50-029-20313-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING, A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: 9 ` CANNEV WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUL 2 4 2013 OGCC July 15, 2013 / FJ 0 L�j RE: Multi Finger Caliper (MFC): 1 A-08 Run Date: 7/12/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com lA-O8 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20313-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: schome' Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: String Shot Record, IBP Setting Record: 1A-08 Run Date: 7/7/2013 JUL 17 2013 0GCC July 8, 2013 I E- JqD 4;3oKS The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1A-08 Digital Data in LAS format, Digital Log Image file 50-029-20313-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. hMR�' Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: / Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUL 17 2013 GV July 8, 2013 ( � E" - 0 1�6 RE: Radial Cement Bond Log: 1A-08 Run Date: 7/6/2013 C/1 3 () / / The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1A-08 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-20313-0 Cement Bond Log 1 Color Log 50-029-20313-0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook SCANNED 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliAon.com WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVE JUL 17 2013 July 8, 2013 ice- o q D RE: Multi Finger Caliper (MFC): 1A-08 GP-3 /'LJ Q(�Run Date: 7/6/2013I 2 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1A-08 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20313-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: <�4� Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUL 17 2013 AOGCC July 5, 2013 r 73 -a't3 RE: String Shot Record/ Tubing Cut Record: 1A-08 Run Date: 7/4/2013 � 3 � / �� The technical data listed below is being submitted herewith. Please address any problems or `—� concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1A-08 Digital Data in LAS format, Digital Log Image file 50-029-20313-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating SCANNED Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@hallib .com Date: Signed: L WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Static Bottom Hole Pressure/ Plug Setting Record: 1A-08 Run Date: 6/16/2013 RECEIVED IV JUN 19 2013 AOGCC June 17, 2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of- Matthew £ Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1A-08 Digital Data in LAS format, Digital Log Image file 50-029-20313-00 Static Bottom Hole Pressure Log 50-029-20313-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: ` 10"ry Signed: I akAx d -T ` • • V OF r „F w � � THE STATE Alaska Gas ofALAsKA Conservation Commission GOVERNOR SEAN PARNELL .,, 333 West Seventh Avenue �FALAs, Anchorage, Alaska 99501 -3572 J 2 4 2013 Main: 907.279.1433 %WED Fax: 907.276.7542 Erik Nelson !r- D Sr. Wells Engineer ■ 0 ` - ConocoPhillips Alaska, Inc. l I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A -08 Sundry Number: 313 -294 Dear Mr. Nelson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. ere fCCommissioner DATED this / D day of June, June, 2013. Encl. , STATE OF ALASKA t $ `‘. i'.., 4.n= ,n.. r ;:,,L Li tw AI•CA OIL AND GAS CONSERVATION COMIIOION ` 01 APPLICATION FOR SUNDRY APPROVALS b� 1 20 AAC 25.280 M r,r , , 1. Type of Request: Abandon f Plug for Redrill (" - Perforate New Pool r Repair w ell f ' Change Appr t £d Suspend r Plug Perforations F Perforate - Pull Tubing (✓ , Time Extension E Operational Shutdown E Re -enter Susp. Well (""" Stimulate I`" Alter casing ie ' Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 9 - Exploratory I 178 - 040 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20313 - 00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes F No I✓ 1A - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25647 ' Kuparuk River Field / Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6382 • 6374 ' 6315' 6307' none 5973' Casing Length Size MD TVD Burst Collapse CONDUCTOR 138 16 162' 162' SURFACE 2220 10.75 2244' 2243' PRODUCTION 6341 7 6364' 6356' Perforation Depth MD (16001 -6037, 6041 -6046, Perforation Depth TVD (ft): 5993 -6029, 6033 -6038, Tubing Size: Tubing Grade: Tubing MD (ft): 50 - 6055, 6073 - 6084, 6134 - 6136, 6217 - 6227, 6233 - 62 6042 - 6047, 6065 - 6076, 6126 - 6128, 6209 - 6219, 6225 - 6251 3.5 L - 80 5917 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER • MD= 5927 TVD= 5919 PACKER - BAKER FB -1 PACKER • MD= 6145 TVD =6137 NIPPLE - CAMCO DS LANDING NIPPLE . MD =525 TVD =525 12. Attachments: Description Summary of Proposal ki 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory F Stratigraphic F Development 9 • Service F 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/24/2013 Oil 9, Gas F WDSPL F Suspended F 16. Verbal Approval: Date: WINJ t GINJ t` WAG I Abandoned F Commission Representative: GSTOR F SPLUG F 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson @ 263 -4693 Email: Erik.Nelsonacop.com Printed Name f • c N on yo l/ � Title: Sr. Wells Engineer Signature Phone: 263 -4693 Date / /j Zez3 Commission Use Only " Sundry Number:3\ 3 - -a"► Lj Conditions of approval: Notify Commission so that a representative may witness f F Plug Integrity j BOP Test Mechanical Integrity Test F Location Clearance F Other: 3d n fcs 7 1) 062C L . Spacing Exception Required? Yes D No [,// Subsequent Form Required: / C .-- 4- 0 4 APPROVED BY � � 1 r b / r �� Approved by: COMMISSIONER THE COMMISSION Date: d A roved application is valid for 12 months trom the date of approval. Form 10 -403 (Revised 10/2012) Submit Fore - . Attachments in Duplicate a \ 1GF6//*J5 ORIGiNAL RBDMS JUN 2 0 214. ', f� � \ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 11 June 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 1A -08 (PTD 178 -040). Well 1A -08 was drilled and completed in 1978 as a selective A- & C -Sand producer. In 2007 the well was shut -in for a suspected surface casing leak due to a failed Mechanical Integrity Test — Outer Annulus (MIT -OA). The well was brought back online under a waiver to produce without gas lift in 2010 but has proved to be an intermittent producer without artificial lift. Subsidence is assumed to be the root cause of the casing and tubing issues in this well. The purpose of this workover is to restore the integrity of the 7" production and 10-3/4" surface casing strings in order to provide a stronger wellbore to combat the effects of future. This will be accomplished by pulling the entire existing tubing completion from the well, pulling and replacing the top — 2000 feet of 7" production casing, and cementing the 7" x 10-%" annulus. Cementing the replaced 7" production casing to surface will effectively mitigate the surface casing leak and will provide added strength to the near surface wellbore. A new 3 - %" gas lift completion will be run. If you have any questions or require any further information, please contact me at 263 -4693. Regard , Erik Q. Nelson Wells Engineer CPAI Drilling and Wells a KU P • 1A-08 • Conoc Phillips 8 Well Attributes Max Angle & MD TD AASita 111C Wellbore APVUWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 500292031300 KUPARUK RIVER UNIT PROD 866 2889.99 6,382.0 COMKiriPhillps '''' Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' SSSV: NIPPLE 95 9/5/2011 Last WO: 7/30/2003 33.00 8/30/1978 Well Confiq. -1 A -08, 1/30/2013 12 52 42 PM Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 6,255.0 11/22/2002 Rev Reason: WELL REVIEW osborl 1/30/2013 HANGER,22 Casing Strings _,... Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 24.0 162.0 162.0 65.00 H Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I SURFACE 103/4 9.950 24.0 2,244.0 2,242.6 45.50 K -55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 23.0 6,364.0 6,355.5 26.00 K -55 IF Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, TUBING WO 2003 I 31/2 I 2.992 I 22.0 5,917.3 I 5,909.2 J 9.30 1 L -80 ABMEUE 24-162 Completion Details Top Depth NIPPLE, 525 ( 1, (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Rem Description Comment ID (In) SURFACE, 22.0 22.0 -2.11 HANGER TUBING HANGER 3.500 24-2,244 525.0 524.9 0.44 NIPPLE CAMCO DS LANDING NIPPLE 2.875 1- 5,903.5 5,895.4 3.22 NIPPLE CAMCO 'DS' NIPPLE 2.812 GAS 21593 5,904.6 5,896.5 3.22 LOCATOR BAKER LOCATOR 3.000 ® 5,905.4 5,897.3 3.21 SEAL ASSY BAKER SEAL ASSEMBLY STABS INTO 1986 TUBING PBR @ 5905' 3.000 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 1986 41/2 2.867 5,904.9 6,167.5 6,159.2 9.30 L -80 BTC 3.5x2.875" GAS LIFT, 3,956 Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (°) Rem Description Comment ID (in) 5,904.9 5,896.8 3.21 PBR BAKER PBR 3.000 GAS LIFT, 5,926.9 5,918.8 3.05 PACKER BAKER FHL PACKER 3.000 4.757 It 5,971.4 5,963.3 2.71 BLAST RING 2.867 6,096.2 6,087.9 2.50 BLAST JT 2.992 6,129.9 6,121.5 2.50 NIPPLE AVA PORTED NIPPLE 2.750 GAS LIFT, 6,132.7 6,124.3 2.50 X0 Reducing CROSSOVER 3.5" x 2.875" 2.875 5.400 -4 6,142.8 6,134.4 2.50 LOCATOR BAKER LOCATOR SUB 2.875 6,145.0 6,136.6 2.50 PACKER BAKER FB-1 PACKER 4.000' 6,149.0 6,140.6 2.50 SBE BAKER SEAL BORE EXTENSION 4.000 11. .. 6,159.4 6,151.0 2.50 NIPPLE CAMCO NO GO '0' NIPPLE 2.250 GAS LIFT, 5,858 6,166.9 6,158.5 2.50 SOS BAKER SHEAROUT SUB. ELMD TTL @ 6160' ON !PROF 8/6/2002 2.441 ,� Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth NIPPLE. 5,903 (TVD) Top !no! Top (RKB) (RKB ( °) Description C Run Date ID (in) 5,973.0 5,964.8 2.70 FISH WRP I 4/2/2003 N HOLE 34" TL x 2.70" OD x .987" ID 9/16/2003 5/28/2003 0.000 LOCATOR, 5,905 6,129.9 6,121.6 2.50 SLEEVE AVA T PI SE IN AVA NIPPLE SEAL ASSY, 5,905 PBR, 5,905 Perforations & Slot Shot T o p ( ND) Btm (TVD) Dens PACKER, 5,927 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ( Type Comment 6,001.0 6,037.0 5,992.8 6,028.7 C-4, C -3, 1A-08 8/18/1978 4.0 IPERF Slimkone PRODUCTION, 6,041.0 6,046.0 6,032.7 6,037.7 C-2, 1A -08 8/18/1978 4.0 RPERF Slimkone 5,965 6,050.0 6,055.0 6,041.7 6,046.7 C -2, 1A -08 8/18/1978 4.0 RPERF Slimkone FISH, 5,973 6,073.0 6,084.0 6,064.7 6,075.7 C -1, 1A -08 8/18/1978 .4.0 IPERF Slimkone 6,134.0 6,136.0 6,125.7 6,127.7 UNIT B, 1A -08 1/4/1986 4.0 CMT Squeezed SQZ IPERF, J. e,00146,037 6,217.0 6,227.0 6,208.6 6,218.6 A -5, 1A -08 8/12/1978 4.0 IPERF Slimkone 6,233.0 6,259.0 6,224.6 6,250.5 A-4, 1A -08 8/12/1978 4.0 IPERF Slimkone RPERF, • i • 6,041 -6,046 _ ts . - Stimul ations & Treatments Bottom RPERF, Min Top Max 8tm Top Depth Depth 6,050 -6,055 Depth Depth (TVD) (WD) ' ' (ftKB) (ftK8) (ftKB) (61103) Type Date Comment 6,001.0 6,259.0 5,992.8 6,250.5 Acid Wash 5/29/1982 IPERF, 6,0738,064 6,217.0 6,259.0 6,208.6 6,250.5 FRAC 11/22/1981 Pumped gelled water in "a" sand Frac with 12/18 Carbolite Add wean Cement Squeezes 6,001 Top Depth Btm Depth NIPPLE 6,130 SLEEVE, 6,130 (TVD) (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment CMT SOZ, 6,134.0 6,136.0 6,125.7 6,127.7 Cement Squeeze 1/5/1986 61 c m No General & Safety squeeze 6,134 ; End Date Annotation LOCATOR 1/2/1986 NOTE: WORKOVER FOR SELECTIVE SINGLE COMPLETION 6.143 Fi 0 Mandrel Details PACKER, 8,145 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run SBE, 6,149 (, N... Top (ftKB) (ftKB) 0 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,592.7 2,590.0 5.24 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/2/2008 2 3,955.7 3,949.0 2.33 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/2/2008 NIPPLE, 8,159 3 4,786.8 4,779.9 0.23 CAMCO MMG 1 1!2 GAS LIFT DMY RK 0.000 0.0 2/2/2008 ir SOS, 6,167^ 4 ' 5,400.5 5,393.3 3.30 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/29/2003 5 5,857.6 5,849.6 2.89 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/12/2003 6 5,965.2 5,957.0 2.76 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 12/28/1990 Bent IPERF, Latch 6,217-6,227 FRAC. 6,217 IPERF, 6,2338,259 PRODUCTION, - 238,384 TD,6.382 KUP • 1A -08 . ConocoPhillips i Alaska. Inc. ' KB (ft) Rig Release Date "' 33.00 8/30/1978 Well Canna =1A -08, 1/30/201312: 59.42 PI2 Schematic -AUUaI HANGER,22 - Notes: General & Safety End Date Annotation 7/29/1998 NOTE: Fish tagged on 7/22/98 & pulled from 6085' on 7/29/98 10/13/2004 NOTE: SUSPECT FAILED TUBING IN JOINT BELOW UPPER PACKER @5927' III 2/4/2008 NOTE: WAIVERED WELL - "'WARNING "' GLVs ARE NOT ALLOWED _ 8/25/2010 NOTE: WAIVERED WELL - IA x OA x FORMATION communication CONDUCTOR, ifs 24 -162 NIPPLE,525 SURFACE, 24 -2,244 II II GAS LIFT, 2,593 GAS LIFT, 3,956 IC lull!; lllllll� GAS LIFT, 4,787 OM GAS LIFT, 5,400 GAS II ,858 5,858 Illi NIPPLE, 5,903 LOCATOR, 5,905 SEAL ASSY, 5,905 PBR, 5,905 PACKER, 5,927 • T Li PRODUCTION, 5,965 ir FISH, 5,973 IPERF, 8,001 -8,037 . & . RPERF, 6,041 -6,046 ll RPERF, •, 6,050-6,055 IPERF, II 1 Acid Wash, Ike 8,001 NIPPLE, 6,130 II. . SLEEVE, 6,130 CMT S02, 8,1346,138 Cement squeeze, 6,134 LOCATOR, I 8,143 PACKER, 6,145 SBE, 8,149 NIPPLE, 8,159 IF SOS, 6,167 '..: IPERF, 6,2176,227 FRAC, 6,217 IPERF,_ -- - -- 6,2336,259 . .......... .. PRODUCTION, -' 236,364 TD, 6,382 • • 1A -08 Kupaurk Producer Expense Rig Workover PTD #: 178 -040 Current Status 1A -08 is currently SI awaiting RWO operations. Scope of Work • Pull 3 -W L -80 tbg from well • Run 7" csg scraper, run CBL, cut - pull - replace 7" csg above TOC, cement 7" x 10'/" annulus • MU and TIH w/ new 3 -' /2" L -80 gas lift completion to surface General Well info MASP: 1878 psi Reservoir pressure /TVD: 2490 psi / 6121' TVD (mid -pert of A & C sands) Calculated using gradient from SBHP pressure taken on 31 March 2012 Wellhead type /pressure rating: FMC Gen I 3 -1/8" 5M x 7- 1/16" 5M 7- 1/16" 5M x 11" 5M BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: MIT -IA passed 26 April 2013 MIT -OA failed 29 March 2007 Well Type: Producer Estimated Start Date: 24 June 2013 Production Engineer: Michael Sullivan RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson@conocophillips.com • . Proposed RWO Procedure: Pre -Rig Well Work 1. Obtain updated SBHP, pull lowest GLM, and set new WRP w/ catcher to secure well 2. Set BPV RU, Test, Pull Tbg, and 7" Csg Evaluation 1. MIRU Rig. Accept Rig, take on fluids, pull BPV, and insure well is dead. 2. Install BPV, ND tree, NU BOPE, install blanking plug, function and PT BOPE to 250/3000 psi and annular to 250/3000 psi 3. Pull blanking plug & BPV. Screw in landing jt, BOLDSs, and pull tbg hgr to the rig floor. 4. LD tbg hgr and TOOH sideways w/ 3 -%2' L -80 EUE -Mod tbg NOTE: If tbg does not come free of the PBR then RU HES E -line and cut tbg in 1 full jt above PBR 5. MU and TIH w/ 7" csg scraper assembly on 3 -W IF DP. TOOH and lay down same. 6. RU HES E -Line for CAST -M (or RCBL) and string shot. RDMO HES E -Line. 7" Csg Replacement 1. MU and TIH w/ RBP or IBP and set 500 ft below TOC. PT to 3000 psi and drawdown test same. Dump sand on top of plug. TOOH and lay down RBP /IBP setting tool. 2. ND 11" BOPE and tbg head. Spear and re -land 7" csg in tension. Cut off 7" csg "growth ". NU BOPE on 11" 5M csg head. NOTE: BOPE is now acting as a diverter due to a surface csg leak at — 240 ft MD with a LLR of — bpm. BOPE will be pressure tested once the 7" csg has been removed. 3. MU and TIH w/ Baker MSC. Cut 7" csg with multi- string cutter on drill pipe above TOC. Circ 9 -5/8" x 7" annulus clean. TOOH and lay MSC. 4. C /out lower BOPE pipe rams to 7" solid body. Function test rams on 7" test jt. NOTE: BOPE is now acting as a diverter due to a surface csg leak at — 330 ft MD with a LLR of — bpm. It will be pressure tested once the 7" csg has been removed. 5. Spear and TOOH laying down 7" csg 6. Set test plug in 10-%" csg head. C /out lower pipe rams to VBRs. PT BOPE w/ 3 - %" test jt to 250/3000 psi. Pull test plug. 7. MU and TIH w/ 10-%" csg scraper to top of 7" stub and circ clean. TOOH and lay down same. 8. RU HES E -line and run gyro w/ GR and memory caliper in 10-%" csg from 7" stub to surface. RDMO HES E -line. 9. MU and TIH w/ tandem string mill assembly to gauge csg for installation of new 7" csg string. TOOH and lay down same. 10. MU and TIH w/ dummy for 7" csg and Halliburton ES cementer. TOOH and lay down same. 11. MU and TIH w/ back off tool and back off csg stub. TOOH and lay down same. 12. MU and TIH w/ spear and recover csg stub. TOOH and lay down same. 13. Set test plug in 9 -5/8" csg head. C /out lower pipe rams to 7" solid body. PT BOPE w/ 3 -W test jt to 250/3000 psi. Pull test plug. 14. MU and TIH new 7" csg w/ Halliburton ES cementer. 15. Screw into top of 7" csg. Pressure test 7" csg to 2500 psi. • 16. Open ES cementer and pump cement (calculated plus — 25% excess) into 7" x 10 - %4" annulus Cmt Req'd 15.7 ppg ArcticSet 1 0.93 ft /sk Estimated TOC = 2300 ft MD 138 bbl vol including excess 17. Cmt Pump Schedule (exact volumes will be adjusted according to actual TOC) a. 5 bbls freshwater b. 5 bbls neat 15.7 lb/gal ArcticSet 1 c. 135 bbls 15.7 lb/gal ArcticSet 1 w/ CemNET d. Launch closing plug e. Displace w/ 3 bbl neat 15.7 lb/gal ArcticSet 1 f. 5 bbls freshwater g. XX bbls heated seawater (— 90° F) to bump plug 18. WOC. ND BOPE and land 7" on slips. Cut 7" csg and install packoff. NU tbg head and 11" 5M BOPE w/ VBRs in bottom cavity. PT csg packoff to 3500 psi. PT break below tbg head to 3500 psi. Install test plug in tbg head and PT BOPE to 250/3500 psi for 30 min and record on chart. 19. MU and TIH w/ cement milling assembly and mill out cement and plug. Pressure test csg to 250/3000 psi for 30 min and record on chart. TOOH laying down same. 20. MU and TIH w/ reverse circulating junk basket to clean out remaining debris. TOOH and lay down same. 21. MU and TIH with wash shoe and circulate out sand on top of RBP. TOOH and lay down same. 22. MU and TIH w/ retrieving tool. Release RBP /IBP and TOOH and lay down same. Run 3 -%" GL Completion 23. MU and TIH w/ 3 -%' L -80 GL completion 24. Load tbg and IA with diesel. Stab seal assembly into PBR and space out. PT tbg 3000 psi and IA to 2500 psi 30 min each and record on chart. 25. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 26. Pull 2 -way check. Freeze protect well. Set BPV. 27. RDMO Rig. Post -Rip Work: MIRU HES Slickline 1. Pull BPV 2. Pull SOV from GLM and run GLD 3. Pull catcher sub and WRP 4. Handover to Ops via handover form for POP... Conoco~Phillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~~~~~ ,~as~a tail ~ Cas Cotes. ~rnmissicr Ancttcr'a~e Apri123, 2010 Mr. Dan Seamount Alaska Oil ~ Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 i~g~v~ ~R.os' .' ~^ 3 Dear Mr. Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil).. Each of these wells. was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering.the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru Apri117, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since ~.' Perry ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/23!10 1A.1 F. 14 & 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF ri/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6/2010 1A-05 50029206270000 1811040 SF n/a 6" n/a 4.25 4R/2010 1A-08 50029203130000 1780400 SF Na 10" Na 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" n/a 2.55 4/2/2010 1A-15 50029207110000 1820170 SF Na 4" Na 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" Na 4.25 4/1/2010 1 Q-02 50029212480200 2051420 22" n/a 22" n/a 7.2 4/6/2010 1 Q-03 50029212490200 1842330 27" n/a 27" n/a 3.4 4/6/2010 14-05 .50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 14-06 50029212240000 1842080 32" n/a 32" Na 2.12 4/1/2010 14-10 50029212150000 1841980 32" Na 32" n/a 3.82 4/1/2010 14-15 50029213080000 1850460 22" n/a 22" n/a 2.97 4/1/2010 1 Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1 /2010 1 Y-21 50029223870000 1931020 23" n/a 23" Na 3.82 4/1 /2010 1Y-24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1/2010 1Y28 50029223800000 1930890 28" n/a 28" n/a 5.52 4/1/2010 1 Y 31 50029223810000 1930900 6'8" 0.65 24" 3/21/2010 5.52 4/1 /2010 ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~ .;6~ska Oii `~s 0®ns, ~oi~ss~rr 4r~~florage Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1A-08 PTD 178-040 Brinker Platelet job. Please call MJ Loveland or myself with any questions. Sincerely, ~---~ ..~.W-._..,.,~ ~~- ,_ -~ Perry Klee -_..,, ., 5 <n ~ ' ~~ r~ ~~ ~ ~~~ Well Integrity Projects ~`~.~ V G U ~~~ ~ 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISg (~~~ ~ G8S ~pCIS~ ~OIIUTiISSIOtt REPORT OF SUNDRY WELL OPERATION~rtGnoral~a 1. Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other ^/ Platelet SC repair Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Nu mber: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 178-040 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20313-00 ' 7. KB Elevation (ft}: 9. Well Name and Number: RKB 108' 1 A-08 ' 8. Property Designati 7 f~~'? LD ; ~°C / 10. Field/Pool(s): ~ ADL 2 ALK 2565 / '~ ` Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6382' feet true vertical 6373' ~ feet Plugs (measured) Effective Depth measured 6255' feet Junk (measured) true vertical 6373' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 162' 16" 162' 162' SURFACE 2136' 10-3/4" 2244' 2242' 3580 2090 PRODUCTION 6256' 7" 6364' 6355' 4980 4320 Perforation depth: Measured depth: 6001-6037' 6041-6046' 6050-6055' 6073-6084' 6134-6136' 6217-6227' 6233-6259' true vertical depth: 5992-6028' 6032-6037' 6041-6046' 6064-607 5' 6125-6127' 6208-6218' 6224-6250' Tubing (size, grade, and measured depth) 2-7/g", J-55, 6168' MD. 3-1/2", J-55, 8316' Packers &SSSV (type & measured depth) Baker FHL Packer 5927' and SSSV= NIPPLE SSSV= 524' 12. Stimulation or cement squeeze summary: , ~q_ .~ ~~~ V~~- ~ `~~ Intervals treated (measured) N/A ~~3~'~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation S/I S/I S/I 400 1300 Subsequent to operation S/I S/I S/I 400 1300 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ X Daily Report of Well Operations 16. Well Status after proposed work: _ OilO ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: NA Contact Lovela I% ferry Klein Printed a MJ Lov Title WI Project Supervisor Signature Phone 659-7043 Date ~ ~ .~ r ~ 3:.7 ~7 ~,.. ~ ~ //7 /~ Form 10-404 Revised 04/2004 ~, ~,~ ~/i~t't ~ ~= L~?~ ~~" ~ Submit Origln ( l • 1 A-08 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/30/09 Brinker Plate-et SC Repair -Unsuccessful, Initial T/1/0/00=SI/400/40/00. Rigged up pump to the platelet skid and started pumping diesel down the OA and established a liquid leak rate of 4 bpm @ 1200 psi. 12 bbls pumped. Loaded batch #1 100 - 15 mm heavy platelet spheres and pumped at a rate of 4.0 bpm @ 1250 psi. 40 bbls pumped. Loaded batch #2 50 - 5 mm light platelet cubes and 25 25/10 mm discs and pumped at a rate of 4.0 bpm @ 1250 psi. 40 bbls pumped. Did not see any indication of the platelets sealing leak point. Rigged down pump and platelet skid. Final T/I/O/00= si/325/70/0 Attempt to repair surface casin leak unsuccessful. ~'~ KUP 1 A-08 COIIOCOP~l1~~Ip 5 well Attributes A'"'~""'~ ' Wa111wre API/UWI 500292031300 Fleld Neme KUPARUK RIVER UNIT Well Stetua Maxim PROD um Inclination (°) 5.75 Total Deplh (ftKB) 6,382.0 ... Comment H2 SSSV: NIPPLE 5 (ppm) Date 95 7/12008 Anrlofatlon End Data Last WO: 7/30/2003 KBGrd (fl) 33 00 Rlg Releaaa Dete 8/30/1978 scan : -u-0e tvl 9rzao6 a:i r.3o PM -. . atle- ACNeI Annotation Depth (ftK B) End Date Annotatlon End Date Last Tag' 6,255.0 11/222002 Rev Reason: 8.1 FORMAT UPDATE 8/192008 Casin Strin s CONDUCTOR, tat Caning Oescnption OD Qn) ID (in) Top (ftKB) Sat Depth (ftKB) Sat Deptl1(ND) (flK8) Wt pbaRt) Grade Top Thread CONDUCTOR 16 15.062 0.0 162.0 162.0 65.00 H-40 NIPPLE, 624 j SURFACE 10314 9.794 0.0 2,244.0 2,242.4 45.50 K-55 PRODUCTION 7 6.151 0.0 6,364.0 6,354.9 26.00 K-55 suRFACE. 2d4 2 Tubin Strln s , Tubing Oeacriptlon OD (In) ID (In) Top (ftKB) Sel Depth (flK8) Sat DepM (NO) (flK8) Wt (IbeM) Orede lop Thread ons LIFT, z.se3 TUBING 31/2 2.992 0.0 6,133.0 6,124.0 9.30 E-80 BrdEUEABMOd TUBING 2 7/8 2.441 6,133.0 6,168.0 6,159.0 6.50 J-55 8RD Other In Hole A ll Jewel :Tubin Ru n $ Retrievable Ftsh etc. onsLlFr, 3958 Top (ftKB) Deacriptl on Comment Run Dete ID (In) 524.0 NIPPLE CAMCO DS LANDING NIPPLE 7/29/2003 2.875 2,593.0 GAS LIFT CAMCOIMMG/1.5IDM YIRK///Comment: STA1 22/2008 2.920 ons uFr, d,]6] 3,956.0 GAS LIFT CAMCO/MMG/1.SIDM YIRK///Comment: STA2 222008 2.920 4,787.0 GAS LIFT CAMCO/MMG/1.S/DM YIRK///Comment: WICK STA3 21212008 2.920 5,400.O GASLIFT CAMCO/MMG/1.5IDM YIRK/I/Comment: STA4 7/29/2003 2.920 OAS LIFT, 5,400 5,858.0 GAS LIFT CAMCO/MMGI1.5/DM Y/RK/I/ Comment: STA 5 9112/2003 2.920 5,904.0 NIPPLE CAMCO DS LANDING NIPPLE 7/292003 2.812 OAS LIFT, 5,905.0 PBR Baker PBR 7/29/2003 3.000 s.es9 5,927.0 PACKER Baker FHL PACKER 7129/2003 3.000 5,965.0 PRODUCT ION CAMCO/KBUCVi/DMYBK/// CommerK: CSM HAS SLIGHTLY BENT LATCH STA 6 122811990 2.920 NIPPLE, 5,901 5,971.0 Blast Rlrlgs 93' of BLAST RINGS set with WORKOVER 7292003 2.875 PBR, 5,905 5,973.0 FISH WRP IN HOLE 34" TL x 2.70" OD x .987" ID 91162003 52&2003 0.000 6,130.0 NIPPLE AVA 058 BPL Nipple; AVA 2.75" TPI SET 4/22003 7292003 2.750 6,141.0 PACKER Baker FB-1 PACKER 1/211986 4.000 PACNER, 6,927 6,149.D SBE BAKER S0E 1211966 4.000 6,159.0 NIP Cameo D Nipple NO G O 1211986 2.250 PRODUCTION, 6,167.0 SOS Cameo 1/2/1986 2.438 5.985 6.168.0 TTL 1/2/1986 2.438 a w Perforations l.et n,.. 5911 Top (ftl(B) Btm (kKB) Top (ND) (ftKB) Btm (ND) (RKB) Typo Zone Shot Dena (MOt-° Deb Comrtwnt 6,001.0 6,037.0 5,992.2 6,028.1 IPERF G4, G3, 1A-08 4.0 8l1&1978 Slimkone FISH, 5,973 6,041.0 6,046.0 6,032.1 6,037.1 IPERF G2, 1A-08 4.0 8118/19 78 StimkOne 6,050.0 6,055.0 6,041.1 6,046.1 IPERF G2, 1A-08 4.0 8118179 78 Slimkone IPERF, 6,073.0 6,084.0 6,064.1 6,075.1 IPERF C-1, 1A-08 4.0 8118119 78 Slimkone e,oo1-0,03] 6,134.0 6,136.0 6,125.0 6,127.0 IPERF UNIT B, 1A-08 4.0 1/4/198 6 Squeezed 6,217.0 6,227.0 6,207.9 6,217.9 IPERF A5, 1A-08 4.0 8/12/19 78 Slimkone IPERF, 6,233.0 6,259.0 6,223.9 6,249.9 IPERF A-4, 1A-08 4.0 8!12!19 78 Slimkone 9.81-0,oda Cement S ueez es Top (ftKB) etm (ftKB) Start Dete Descriptio n Comment IPERF 6,134.0 6,136.0 1/5/1986 Cement Squee ze , 9.oso-0,oss Notes: General & Safe End Dete Annotation 7/29/1998 NOTE: Fish tagged on 722!98 8 pulled from 6085' on 7/29/98 IPERF, 111202001 NOT E: WAIVERED WELL-IAx OA communiption 10/132004 NOT E: SUSPECT FAILED TUBIN G IN JOINT BELOW UPPER PACKER @592T 2/42008 NOT E: WANERED WELL-"'W ARNING"'GLVS ARE NOT ALLOW ED NIPPLE, 8,130 IPERF, 8,131-0,138 Cement apueeze, 8.13/ - =_ PACNER, 8,111 SBE, 8,149 NIP, 8,159 SOS, 8,197 TTL, 6,168 IPERF, e.217-0,zz] IPERF, 9,233-0,258 PRODUCTION, 8,361 TD, 9,382 ~ ConoCOPhillips Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 September 22, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1A-08 (APD # 178-040) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1A-08. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Wells Group Team Leader CPAI Drilling and Wells MM/skad ORt® NA! ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Alter Casing [--'] Repair Well ['~ Plug Perforations Change Approved Program [--1 Pull Tubing [~ Perforate New Pool [~ Re-enter Suspended Well [~] 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 3. Address: Stratigraphic [ Service [--1 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20313-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 108' 1A-08 8. Property Designation: 10. Field/Pool(s): ADL 25647, ALK 465 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6382' feet true vertical 6373' feet Plugs (measured) 5950' Effective Depth measured 6255' feet Junk (measured) true vertical 6246' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 162' 16" 162' 162' · ~ ,..,, · SURF CASING 2136' 10-3/4" 2244' 2243' '?~ ~'~? ~..:.i":!... PROD CASING 6256' 7" 6364' 6355' "~' '~'~ ~ '.,' ~ ~.. i' ' ,.~ ., ...... Perforation depth: Measured depth: 6001'-6037', 6041' - 6046', 6050' - 6055', 6073' - 6084', 6134' - 6136', 6217'- 6227', 6233' - 6259' true vertical depth: 5992' - 6028', 6032' - 6037', 6041' - 6046', 6064' - 6075', 6125' - 6127', 6208' - 6218', 6224' - 6250' Tubing (size, grade, and measured depth) 3.5" / 2-7/8", L-80/J-55, 6133'/6168' MD. :Packers & SSSV (type & measured depth) Baker FHL packer, Baker FB-1 packer packers set at 5927', 6141' SSSV= Camco DS Landing Nipple nipple= 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation SI Subsequent to operation 434 2179 4496 262 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory [-'-] Development [~] Service [] Daily Report of Well Operations _X 16. Well Status after proposed work: Oil~'] Gas[]'-] WAG[]--] GINJ [--] WINJ [-'] WDSPL ['-'] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: I Contact Mike Mooney @ 263-4574 Printed Name Mike ,Mooney Title Wells Group Team Leader Signature //f~~ ~,//,~.,~ Phone Date ,,/,,/,~,/~ .~' Prepared by Sharon AIl?up-Drak~ 26~-4F? 12 Form 10-404 Revised~~ SUBMIT IN DUPLICATE ConocoPhillipS Alaska page. 1 of ! Operations summary Report · . Legal Well Name: 1A-08 Common Well Name: 1A-08 Spud Date: 7/22/1978 Event Name: WORKOVER/RECOMP Start: 7/25/2003 End: 7/30/2003 Contractor Name: Nabors3SCompanyM@conoco Rig Release: 7/30/2003 Group: Rig Name: Nabors 3S Rig Number: SUb Phase : : ~DeScriPtion of Operations :::Date:::: :From:To: HOURS iC°de CO:de : .: 7/25/2003 10:00- 17:00 7.00 MOVE MOB MOVE Move rig from Deadhorse to lA Pad. 17:00 - 23:00 6.00 MOVE MOB MOVE Arrive location. Spot carrier sub over well to ensure rig up angle is correct. Pull carrier sub out away from well. Lay herculite down under rig footprint. Move carrier sub over well. Move pipe shed into position. 23:00 - 23:30 0.50 MOVE MOB MOVE Pad has settled. Move rig back 2" and re-level. 23:30- 00:00 0.50 MOVE MOB MOVE Lay out herculite for pits. 7~26~2003 00:00- 00:30 0.50 MOVE MOB MOVE Spot pits. '00:30- 06:00 5.50 MOVE RURD MOVE Continue RU. MU power and lines between modules. Reposition support brackets for standpipe. 06:00 - 10:00 4.00 MOVE RURD MOVE Troubleshoot crownmatic and make up standpipe and cement line to circulation manifold. Install new plug valves in circulation manifold. Took photo of Tree positon for future reference. 10:00 - 13:30 3.50 MOVE RURD MOVE Completed make up of piping, purged for pressure test. Crownmatic repaired. 13:30- 14:30 1.00 MOVE RURD MOVE Raised Derrick. 14:30 - 15:30 1.00 MOVE RURD MOVE Picked up mousehole and marked position in cellar. Supersuck gravel in cellar for mousehole installation. Begin pressure test of standpipe, cement line, and circulation manifold. 15:30 - 18:00 2.50 MOVE RURD MOVE Continue with Pressure test of standpipe, cement line, and circulation manifold. Having some problems with a small internal leak. Hold Pre-tour meeting with night shift. 18:00- 20:00 2.00 MOVE RURD MOVE Continue with pressure test of standpipe, cement line, and circulation manifold. Work air out of system. Pressure test to 5000 psi. H~ld good for 5 min. Bleed off pressure. RU flowline to pits. Do walkthrough of rig. 20:00 - 20:45 0.75 WELCTL NUND DEOOMP Accept rig at 2000. Put lifting cap on tree. Mark adapter flange and tubing head for proper alignment. ND tubing adapter flange and tree. Verify the hanger is a weld neck hanger and that the lifting threads are 3-1/2" BTC. The neck, top of hanger, and neck seal area are in good shape. The seal area and ring groove of the adapter flange are in good shape. 20:45 - 00:00 3.25 WELCTL NUND DECOMP Verify there is no pressure below the BPV. Install blanking plug in tubing hanger. It will take 12 turns to retrieve the blanking plug. Call for wellhead to be sent to valve shop. Stand up BOP stack in cellar. Call Lou Grimmaldi AOGCC Inspector at 2130 to give him 3 hours notice for BOP test. He told us to get pressure on the BOP stack and then call him back. NU 13-5/8" 5M BOP stack. MU choke and kill lines and BOP hoses. 7/27/2003 00:00 - 00:30 0.50 WELOTL NUND DECOMP Finish MU choke and kill line and hoses to BOP stack. 00:30 - 02:30 2.00 WELCTL BOPE DECOMP Install mousehole on rig floor. Fill up stack with water. PU 3-1/2" test joint. MU TIW valve and dart valve on test joint. 02:30 - 03:15 0.75 WELOTL BOPE DECOMP Close blind ram. Test blind ram to 250 psi Iow and 4000 psi high. 03:15 - 04:00 0.75 WELOTL BOPE DECOMP Notified AOGOC Inspector Lou Grimmaldi that blind test looked good. He said we could continue with the test, but he may make us redo it when he arrives. Continue with BOP test. RIH with test joint. Having trouble engaging threads on top of test plug. 04:00 - 05:30 1.501 WELCTL BOPE DECOMP Pull test joint. Recovered test plug on end of test joint beginning of first thread was the only left hand acme thread engage. Break out test plug. Beginning of first thread is damaged. File out thread and make up to running tool. RIH on test joint. Screw test plug into hanger. Took 12 turns to get tight (same as before NU BOP stack). 05:30 - 10:30 5.00 WELCTL BOPE DECOMP Continue with BOP Test to 250 psi Iow and 4000 psi high. Completed BOP Test. Gas alarm and Evacuation alarm test completed. AOGCC Printed: 8/15/2003 12:41:39 PM COnocoPhilliPs Alaska- ~ :~ page2- of 4 OPeratiOnS SUmmary Report Legal Well Name: 1A-08 Common Well Name: 1A-08 Spud Date: 7/22/1978 Event Name: WORKOVER/RECOMP Start: 7/25/2003 End: 7/30/2003 iContractor Name: Nabors3SCompanyM@conoco Rig Release: 7/30/2003 Group: Rig Name: Nabors 3S Rig Number: : Date: .:Fr°m,To iHOurs. Code ::SUb :PhaSe DesCriPtionOfOperatibnS: ii Code i: : :. ::: : :: : :::::: :' 7/27/2003 05:30 - 10:30 5.00 WELCTL BOPE DECOMP Inspector identified some modifications that will be required to be done to the choke manifold. Warehouse delivered completion equipment and 210 jts of 3-1/2" EUE tbg, staged on pad. 10:30 - 12:00 1.50 WELCTL BOPE DECOMP Loaded Pit #1 with 127 bbls of 9.6# brine. Removed the Test Plug & Test Joint. Toolpusher change out. Camco completion hand, Baker fishing hand, & Schlumberger ElL arrived on location 12:00 - 13:00 1.00 WELCTL BOPE DECOMP Well is dead removed BPV (dry rod). Cut riser and prep to install 13:00 - 14:30 1.50 FISH PULD DECOMP Installed Flow riser and picked up tongs, slips, etc. 14:30 - 17:00 2.50 FISH PULD DECOMP Set up Camco spooling unit on the rig floor. Made up Baker Fishing spear with 2.933" grapples and Pack off to joint of tbg with TIW valve on top. Circulated 9.6# brine thru the stack checking pumps and flowlines, and filling the stack. 17:00 - 17:45 0.75 FISH FISH DECOMP Lowered spear into hole and engaged tubing 5' below the hangar. Picked up weight very slowly. Pulled up to 78k and seal assembly came free in the PBR. Hanging string weight 48k. Pulled hangar up to rig floor. Visual on hangar shows it to be in good shape. 17:45 - 19:00 1.25 FISH PULL DECOMP Break down Baker fishing spear. Break off hangar for shipment to deadhorse. Released Schlumberger E/line. Installed TIW in tubing and prepp rig floor to begin pulling tubing string. 19:00 - 19:15 0.25 FISH PULL DECOMP Remove TIW valve begin pulling first joint. CAMCO spooler employee caught his hand between the control line and the spooler. 19:15 - 19:45 0.50 FISH SFTY DECOMP Discuss near incident. Reassign job duties. Floorhand will wipe the control line. Spooler operator will only run the spooler. Reposition spooler to aid in communication and visibility. Slow down spooler speed by limiting hydraulic fluid flow. 19:45 - 00:00 4.25 FISH PULL DECOMP POOH with tubing and control line. Tubing threads and body appear to be in good shape. Lay down tubing in pipe shed. No thread protectors available for 3-1/2" BTC tubing. Pull 57 jts tbg and 2 pups. Check hole fill every 20 joints. All ok. Lay down SSSV with 57th joint attached and break out in pipe shed. No pups installed above or below SSSV. SSSV has been locked out, and it will be junked. Recovered 32 control line bands. Tubing talley says 33 installed. Left 1 band in hole. RD Camco spooler and release Camco. 7/28/2003 00:00 - 02:00 2.00 FISH PULL DECOMP Continue POOH with tubing to 1st mandrel. No pup joints installed above or below mandrel. Could not break out joint above mandrel since we could not get the slips to set on the mandrel. Lay down mandrel with top joint attached. All tubing in good condition. No scale inside. No corrosion inside or outside of the tubing. 02:00 - 04:45 2.75i FISH PULL DECOMP Continue POOH. No pups above or below all mandrels. FMC called at 0345 with word that hanger is in good condition. It passed magnaflux inspection. They will machine new packing groove and buck up L-SO pup on bottom. Pulled down to 1st joint below GLM #3. All pip~ looks good both inside and outside. Collars and pins are in good shape. 04:45 - 05:15 0.50; FISH PULL DEOOMP 2nd joint (#138) below GLM #3 has hard material on outside. Approx. half way down the joint was the first hole at 4308' RKB. Jt 138 has several holes including 1 just above the pin. All holes appear to be from external corrosion. There is no pitting on the inside of this joint. The hard material is lessening on each joint below #138. 05:15 - 08:30 3.25 FISH PULL DECOMP Last joint (#189) below GLM #9 and above the PBR seal assembly has large amounts of corrosion the length of the joint. There was deep pitting visible just below the collar at the top of the joint and some pitting above the lower collar. Also on the the lower side of GLM #9 was large pitting at the connection. Printed: 8/15/2003 12:41:39 PM conoc°PhillipS Alaska Page3 of 4 · · · Operations SUmmary Report · . : Legal Well Name: 1A-08 Common Well Name: 1A-08 Spud Date: 7/22/1978 Event Name: WORKOVER/RECOMP Start: 7/25/2003 End: 7/30/2003 'Contractor Name: Nabors3SCompanyM@conoco Rig Release: 7/30/2003 Group: Rig Name: Nabors 3S Rig Number: Date : From~To: Hours COde~ icSoUdbe ·:Phase: ::: DeScripti°n°fOPerati°ns: : 7/2812003 08:30 - 09:00 0.50 FISH PULL DECOMP All pipe and jewelery in the pipe shed. Inspected GLM's and they appear to be in good enough shape to clean and reuse. Seal Assembly ~n good shape. Found additional hole in joint (#132). 09:00 - 11:30 2.50 FISH PULL DECOMP NORM checked all tubing and jewelery everything checked out good. Marked all tubing indicating it was NORM checked. Unloaded pipe from the pipe shed and staged on pad. 11:30 - 15:00 3.50 CMPLTN PULD CMPLTN Begin Loading Pipe shed with 3-1/2" LS0 tubing (200 joints). Drifted 30 joints with 2.91" rabbit and strapped same. 15:00 - 17:00 2.00 CMPLTN PULD CMPLTN Continued loading the pipe shed and strapping pipe for pipe tally. Completed strapping all pipe. Begin to make up completion pipe tally. 17:00 - 18:00 1.00 CMPLTN PULD CMPLTN Begin strapping jewelry. Unable to drift the pup joints with 2.91". Had warehouse send out some more pup joints. 18:00 - 20:15 2.25 CMPLTN PULD CMPLTN Complete strapping jewelry and pups. Complete running talley of pipe for location of jewelry. (Only 2 pups (10' and 6') drift to 2.91" with teflon rabbit. Call for Y-Pad to deliver lock for 2.875" lock to rig. We will check the pups on location with this lock.) 20:15- 20:45 0.50 CMPLTN SFTY CMPLTN Pre-job safety meeting for running completion. 20:45 - 00:00 3.25 CMPLTN RUNT CMPLTN PU seal assembly, locater sub, and 6' pup joint. MU CAMCO 2.812" DS Nipple and 1 jt 3-1/2" L-80 EUE 8rd AB Mod tubing. MU GLM assembly #5 with 6' pup above and below. Mandrel is 1.5" MMG with DCK-2 shear valve on RKP latch set for 2000 psi casing to tubing. RIH w/14 jts 3-1/2" L-80 EUE 8rd AB Mod tubing. MU GLM assembly #4 with 6' pup above and below. Mandrel is 1.5" MMG with DV on RK latch installed. RIH w/19 jts 3-1/2" L-80 tbg. MU GLM assembly #3 with 6' pup above and below. Mandrel is 1.5" MMG with DV on RK latch installed. RIH w/20 jts 3-1/2" L-80 tbg to 1767'. 7/2912003 00:00 - 07:30 7.50 CMPLTN RUNT CMPLTN RIH w/6 jts 3-1/2" L-80 EUE 8rd AB Mod tubing. MU GLM assembly #2 with 6' pups above and below. Mandrel is 1.5" MMG with DM on RK latch installed. RIH w/43 jts 3-1/2" L-80 EUE 8rd AB Mod tubing. MU GLM assembly #1 with 6' pups above and below. Mandrel is 1.5" MMG with DV on RK latch installed. RIH w/66 jts 3-1/2" L-80 EUE 8rd AB Mod tubing. MU 2.875" DS Nipple. RIH w/17jts 3-1/2" L-80 EUE 8rd AB Mod tubing. Tag PBR. (Had trouble making up the connections between jts 56 & 57, 135 & 136, and 138 & 139. Backed out the pin and checked the seal ring. MU joint again with no problem. All joints made up to 2200 fi-lbs torque.) 07:30 - 09:00 1.50 CMPLTI~ RUNT CMPLTN Up weight on tubing 50k and down weight 46k. Fired up the charge pumpp to see if seals were in the PBR. Did not see any pressure change. Picked up pipe about 15' to circulate. Mud pump doesn't appear to be pumping. 09:00 - 11:30 2.50 CMPLTI~ RUNT CMPLTN Tore into the valves on the mud pump and found some crud in them. Cleared valves and tested pump. 11:30 - 12:00 0.50 CMPLTI~ RUNT CMPLTN Circulated down tbg @ minimum rateand attempted to stab into PBR. Shut down the pump and rotated pipe 2-1/2 turns stabbed seall assembly into PBR. Pressured up on the tbg to 500 psi (held good). Bled back pressure. 12:00 - 12:45 0.75 CMPLTN RUNT CMPLTN Unstung from PBR to space out. Removed joint #186 in preparation for spacing out. The well started to u-tube out the tbg. Monitored for about 30 minutes. 12:45 - 13:30 0.75 CMPLTN CIRC CMPLTN Circulated 9.6# brine down the tbg. App 51 bbls. completed circulation tubibg and annulus balanced. 13:30 - 14:30 1.00 CMPLTN RUNT CMPLTN Spaced out installed 2.25' pup joint 1 joint below the tbg hangar and Printed: 8/15/2003 12:41:39 PM ConocoPhillipS Alaska Page 4 of 4 OPerati°ns Summary Report Legal Well Name: 1A-08 Common Well Name: 1A-08 Spud Date: 7/22/1978 Event Name: WORKOVER/RECOMP Start: 7/25/2003 End: 7/30/2003 Contractor Name: Nabors3SCompanyM@conoco Rig Release: 7/30/2003 Group: Rig Name: Nabors 3S Rig Number: :Date : FrOm:TO :Hours :iCOde SUb: .PhaSe: :: :D~.:scriptiOn'-'~ u,'-'~,~ -~'"~"'"ti°~': COde. · :. 7/29/2003 .13:30 - 14:30 1.00 CMPLTN RUNT CMPLTN made up hangar to tbg string. Spacing out the seall assembly muleshoe 14:30 - 15:00 0.50 CMPLTN RUNT CMPLTN Vaced out the stack and prepared to land the hangar. 15:00 - 17:00 2.00 CMPLTN RUNT CMPLTN Had some problems getting the seal assembly stung baok into the PBR. Had to rotate the pipe a couple of turns to get it to go in. Land tubing hanger. RILDS. 17:00 - 18:00 1.00 CMPLTN DEQT CMPLTN Pressure tested tubing to 2500 psi for 15 minutes, OK. Bled tubing to 1500 psi & tested 3-1/2" X 7" annulus to 2500 psi for 15 minutes, OK. Bled off tubing to zero and sheared the dump kill valve - bled down tubing and casing to zero psi. 18:00- 18:30 0.50 CMPLTN DEQT CMPLTN PJSM. Blowdown stack & choke lines. LD landing joint. 18:30 - 21:00 2.50 WELCTL NUND CMPLTN Set BPV. Set tubing head adapter & tree in cellar. Set BOP stand in oellar. Prep to ND DOPE. 21:00 - 00:00 3.00 WELCTL NUND CMPLTN ND DOPE. NU 13-5/8" X 3-1/8", 5 Ksi Tubing Head Adapter and 3-1/8", 5 Ksi tree. Pull BPV. 7/30/2003 00:00 - 03:00 3.00 CMPLTN SEQT CMPLTN Set test plug. Test packoffs to 5000 psi. Test tree to 250 psi & 5000 psi for 15 minutes. Pull TP. Set BPV. Release rig. (Prepare to move to 1A-28). Printed: 8/15/2003 12:41:39 PM GConocoPhillips Alaska, Inc. (6134-6136) KRU 1A-08 1A-08 APl:1500292031300 SSSV TyPo:ITRDP Annular Fluid:I Reference Log:122' RKB Last Tag:16255 Last Tag Date:l 11/22/2002 Well Type:I PROD Orig 18/30/1978 Completion:I Last W/O:17/30/2003 Ref Log Date:~ TD:16364 ftKB Max Hole Angle:16 deg (~ 2800 Angle @ TS: 13 de.q @ 6001 Angle @ TD:I2 deg @ 6382 I Rev Reason:IWORKOVER Last Update:18/2/2003 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURF CASING 10.750 PROD CASING 7.000 Tubing String - TUBING Size I Top 3.500 0 2,875 6133 PerforatiOns Summary Interval TVD 6001-6037 5992-6028 6041-6046 6032-6037 6050-6055 6041-6046 6073-6084 6064-6075 6134-6136 6125-6127 6217-6227 6208-6218 6233-6259 6224-6250 Top Bottom 0 162 0 2244 0 6364 i I wt I Grade I 162 165.001 H-40 I 2242145.50 K-55 I 6364126.00 K-55 I Bottom I TVD I Wt IGrade I Thread 6133 I 6124 I 9.30 I L-80 I 8rdEUE AB Mod 6168 6159 I 6.50 I J-55 I 8RD Thread IZone I StatuslFt ISPFl'Date I Type I Comment C-4,C-3I 13614 18/18/19781 IPERF ISlimkone c-2 I 1514 18"'18'"19781 IPERFISlimk°re c-2 I 1514 18;18.'19781 IPERFISlimk°re c-1 I I 11 I 4 i8,'18.,19781 IPERF ISlimkone LJNITB I I2 1011:5/19861 I A-5 I 1101 4 18;12.'19781 IPERF ISlimkore A-4 I I 26 I 4 18;12.'19781 IPERF ISlimkone Stimulations & Treatments Interval I DateI Type Comment 6134-6136 1/5/1986 Gas, Lift: Mandrels/ValVes' ........ '.' .... · .' StI MD I TVD I Man I Man I V Mfr I VType I VOD ILatchJ Port I TRO I Date 'l Wv I I IM'rl'r¥,:'el I I I I I IRu"lem"~ 1 2592 2589 CAMCO rv~vlG DMY 1.5 RK 0.000 0 7;29;2003 2139551 394810AMCOI ~.t~K:~ I IDMYI 1.5 IRK 10.0001 0 17,'29.,'20031 3147861 477810AMCOI It~/1G I IDMY11.5IRK 10.0001 0 17'29.;~00:~1 4154001 539210AMCOI ~'~GI IDMY115 IRK 10.000 1 0 17'29'20031 5158571 58~810^MCOI ~VS I I SOV I 1.5 IRK 10.0001 0 17.'29..'20031 3roduction Mandrels/Valves stIMDI Tvo l ,,an I Man IV Ufr IV Type IV ODI,atchI Port I TRO I Date I Wv Mfr Type Run lOl5965159561camc01 KBUG I I DMY 11.o I BK Io.oool o t2/28/199~cmnt - JEWELRY Description CAMCO DS LANDING NIPPLE SET 7,,'29,2003 ID 2.875 2.812 NIP CAMCO DS LANDING NIPPLE SET 7.'29.2003 PBR Baker 3.000 PACKER Baker FHL 3.000 PLUG WRP SET 5/28/2003 0.000 93' of BLAST RINGS set with WORKOVER 2.875 2.750 4,000 SBE BAKER SBE 4,000 2.250 NIP AVA 05B BPL Nipple; AVA 2.75" TPI SET 4/2/2003 PACKER Baker FB-1 NIP Camco D Nipple NO GO SOS Camco 2,438 'l-FL 2.438 Note ed on 7/22/98 & )ulled from 6085' on 7/29/98 WELL - IA x OA communication SECOND LEAK BELOW PULLED ECLIPSE PACKER BETWEEN 4371' AND 4560' RKB Memow Multi inger Caliper Log Resul Summa.ry Company: ConocoPhillips Alaska, Inc. Well: 1A-08 Log Date: January 16, 2003 Field: Kuparuk Log No.: 4934 State: Alaska Run No.: I APl No.: 50-029-20313-00 Pipe1 Desc.: 3.5" 9.3 lb. J-55 BTC AB-MOD Top Log Intvll.: Surface Pipe1 Use: Tubing Bot. Log Intvll.: 6,099 Ft. (MD) Inspection Type' Corrosive & Mechanical Damage Inspection COMMENTS · This log is tied into the Packer ~ 5,927' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 3.5" tubing logged is in good condition. Two ~22% wall penetrations are recorded in joint 138, (~ 4,290' & 4,306', near the location where an LDL located two points of communication. The damage appears in the form of Isolated Pitting. A 3D Log Plot of this interval is included in this report. No othersignificant wall penetrations are recorded. No significant areas of cross- sectional wall loss or I.D. restrictions are recorded. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS · Isolated Pitting (22%) Jt. No other significant wall penetrations (> 16%) are recorded. 138 @ 4,290 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 13%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. Field Engineer: D. Cain Analyst: M. Lawrence Witness: M. Chaney ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: 1A-08 Field: Kuparuk Company: ConocoPhiltips Alaska, inc. Country: USA PDS Report Overview Body Region Analysis Survey Date: January 16, 2003 Tool Type: MFC 24 No. 00387 Tool Size: 1.69 No. of Fingers: 24 Analyst: M. Lawrence [Tubir~g: Nora.OD Weight 3,5 ins 9.3 ppf Grade & Thread Nom. ID J-55 BTC AB*MOD 2.992 ins Nom. Upset Upper len. Lower len. 3.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) penetration body ~ metal loss body 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ioints aq~ly§~e~d (total = 199) pene. 2 190 6 1 0 0 loss 3 189 7 0 0 0 Damage Configuration ( body ) Number of ioints ~_n~[~ed ~tota[ = 4) 4 0 0 0 0 Damage Profile (% wall) penetration body ~ metal loss body 0 50 GLM 1 97 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM ~ Bottom of Survey = 195 100 Analysis Overview page 2 ~ PDS Multifinger Caliper 3D Log Plot Company: ConocoPhiilips Alaska, inc. Field: Kuparuk Well: IA-(}8 Date: January 16, 2003 Description: Detail of Caliper Recordings Over Interval Where LDL Found Two Leaks 4275 Joint 137 4295 ~05 4315 ~20 ~25 0.24 0.19 o.og 0,04 0.1 Well: Field: Company: Country: Survey Date: Percenl Probabilii~ of Hole 20 50 Kuparuk ConocoPhillips Alaska Inc. USA January 16, 2003 PDS Caliper Statistical Evaluation Report Tool: MFC 24 No, 00387 Tool Size: 1,69 inches Tubing I,D.: 2.992 inches Tubing O.D.: 3.5 inches Wall Thickness: 0.254 inches Standard Deviation 0.01 Maximum Probable Penetralion* inches Percent Probability ol Recording a Hole* 1 10 100 Average Rank PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body = 0.254 ins Upset: 0.254 ins Nominal ID: 2.992 ins Body Well: 1A-08 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 16, 2003 MinimumIrDch es Comments PUP PUl:' Shallow pitfing. PUP penetrafion body metal loss body lDamage Profile (% wall) 50 100 I 5 Pipe Tabulations page PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC Ag-MOD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Well: Field: Company: Country: Sun/ey Date: Kuparuk ConocoPhiflips Alaska, Inc. USA January 16, 2003 Deviation) penetration body metal loss body Damage Profile % wall 50 100 Pipe Tabulations page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.3 ppf 1~55 BTC AB-MOD Wall thickness: Body: 0.254 ins Upset = 0.254 ins Nominal ID: 2~992 ins Welk Field: Company: Country: Survey Date: 1 A~08 Kuparuk ConocoPhil]ips Alaska, Inc. USA January 16, 2003 No Deviation) Deviation penetration body metal koss body Damage Profile (% wa ) 50 lO0 Pipe Tabulations page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Penetration Body Projection Well: Field: Company: Country: Survey Date: Minimum ID inches 2.94 ~ ,93 2.90 1A-08 Kuparuk ConocoPhlJ]ips Alaska, Inc. USA January 16, 2003 No Deviation) [ 156 No Deviation) No Deviation) No Deviation) ?83 2.86 2.94 2.87 NO Deviation) penetration body metal loss body Damage Profile (% wa ) 50 100 Pipe Tabulations page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body: 0.254 ins Upset = 0.254 ins Nominal ID: 2-992 ins Well: Field: Company: Country: Survey Date: 1A08 Kuparuk ConocoPhiliips Alaska, Inc. USA January 16, 2003 Body Comments No Deviation) penetration body metal loss body Damage Profile (% wall) 50 100 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 ' pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe iD or extend more than 20% of circumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length = 0.220 feet. Well: 1A-08 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 3.5 ins 9,3 ppf J-55 BTC AB-MOD PDS Report Cross Sections Survey Date: January 16, 2003 Tool Type: MFC 24 No. 00387 Tool Size: 1.69 No. of Fingers: 24 Analyst: M. Lawrence Cross Section for Joint 138 T~ot speed = 54 Nominal iD = 2.992 Nomina} OD = 3~500 Remaining wall area = 99 % Tool deviation = 1 ° at depth 4289.68 ft 1 Finger 2 Penetration = 0.056 ins Isolated Pitting 0.06 ins = 22% Wall Penetration HIGH SIDE = UP Cross Sections page 1 i I I ! i i I I I I PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches .1 -3.17 5.34 3.048 3.047 2.992 3.500 pup 1 2.17 33.06 2.992 3.043 2.992 3.500 1.1 35.23 8.03 3.011 3.015 2.992 3.500 ~up 1.2 43.26 8.19 3.023 3.027 2.992 3.500 ~up 2 51.45 31.63 3.040 3.040 2.992 3.500 3 83.08 30.89 3.030 3,033 2.992 3.500 4 113.97 29,84 3.042 3.044 2.992 3.500 5 143.81 27.85 3.014 3.015 2.992 3.500 6 171.66 31.60 3.028 3,032 2.992 3.500 7 203.26 30.77 3.055 3.054 2.992 3.500 8 234.03 30,14 3.043 3.044 2,992 3.500 9 264.17 31.67 2.992 3.041 2.992 3.500 10 295.84 31.32 3.034 3.033 2.992 3.500 11 327.16 31.37 2.992 3,032 2.992 3,500 12 358.53 31.05 2.992 3.033 2,992 3.500 13 389.58 31,40 2.992 3.032 2,992 3.500 14 420.98 30.65 3.033 3.033 2,992 3.500 15 451.63 30.80 3.020 3.025 2.992 3.500 16 482.43 30,91 3.047 3.046 2.992 3.500 17 513,34 30,97 3,036 3,035 2,992 3.500 18 544.31 31.69 3.028 3.029 2.992 3.500 19 576.00 30.18 3.040 3.042 2.992 3.500 20 606.18 31.39 3.040 3.040 2.992 3.500 21 637.57 31,54 3,034 3.038 2,992 3,500 22 669.11 31.37 2.992 3,032 2,992 3.500 23 700.48 30.07 2.992 3,035 2.992 3.500 24 730.55 31.41 3.041 3,041 2.992 3.500 25 761,96 31.20 3.03 7 3.041 2.992 3.500 26 793.16 29.63 3.038 3.040 2.992 3.500 27 822.79 30.64 2.992 3.043 2.992 3.500 28 853.43 30.77 2,992 3.049 2.992 3.500 29 884.20 31,41 3,038 3.037 2.992 3.500 30 915.61 30,98 3.036 3.037 2,992 3.500 31 946.59 30.11 2.992 3.023 2.992 3.500 32 976.70 31.23 3.023 3.024 2.992 3,500 Well: 1A-08 Field: Kuparuk Company: ConocoPhil]ips Alaska, Inc. Country: USA Survey Date: January 16, 2003 joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 33 1007.93 30.99 2.992 3.035 2.992 3.500 34 1038.92 31.18 3.028 3.030 2.992 3,500 35 1070.10 30,38 3,021 3.029 2.992 3.500 36 1100.48 31.27 2.992 3.025 2,992 3.500 37 1131.75 29.91 2.992 3.029 2.992 3.500 38 1161.66 29.73 3.029 3.029 2.992 3.500 39 1191.39 31,11 3.032 3.031 2.992 3.500 40 1222.50 30.38 3.032 3.032 2,992 3.500 41 1252,88 31.02 3.027 3.027 2.992 3.500 42 1283.90 30.97 2.992 3.031 2.992 3.500 43 1314.87 30.85 3.020 3.023 2.992 3.500 44 1345.72 30.45 3.036 3.037 2.992 3.500 45 1376.17 31.64 3.032 3.033 2.992 3.500 46 1407.81 31.61 3.024 3.029 2,992 3.500 47 1439.42 30.65 2,992 3.028 2.992 3.500 48 1470,07 30,36 2.992 3.016 2,992 3.500 49 1500,43 29,78 3.020 3.024 2.992 3,500 50 1530.21 30.32 3.033 3.030 2.992 3.500 51 1560.53 31,32 3.032 3.031 2.992 3.500 52 1591,85 30,98 3,023 3,026 2,992 3,500 53 1622.83 31.83 3.022 3.023 2.992 3,500 54 1654,66 31,32 3.029 3.022 2.992 3,500 55 1685.98 31,23 3.018 3.019 2.992 3.500 56 1717.21 31.89 3.020 3.023 2.992 3,500 57 1749.10 31.45 3,010 3,013 2.992 3,500 57.1 1780.55 11.87 2.813 2.813 2.992 3,500 ~sv 58 1792.42 30.46 3.032 3.031 2.992 3.500 59 1822.88 30.99 3.043 3.042 2.992 3.500 60 1853.87 31.63 3.020 3.017 2.992 3,500 61 1885.50 30.68 3.028 3.027 2.992 3.500 62 1916.18 30.75 3.028 3,027 2.992 3.500 63 1946.93 31,55 2.992 3.021 2,992 3.500 64 1978.48 31,27 3,004 3,003 2,992 3.500 65 2009.75 31.61 3.024 3.021 2,992 3.500 66 2041.36 30,85 3,022 3.018 2.992 3,500 Joint Tally page 1 I i I I ! i ! i [ ! I I' I I PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal :Type No. ID ID ID OD feet feet inches inches inches inches 67 2072.21 30.75 3.013 3.013 2.992 3.500 68 2102.96 31.76 3.008 3.013 2.992 3.500 69 2134.72 31.27 3.012 3.016 2.992 3.500 70 2165.99 31.24 3.015 3.015 2.992 3.500 71 2197.23 31.28 2.992 3.016 2.992 3.500 72 2228.51 30.12 3.016 3.015 2.992 3.500 73 2258.63 32.01 3.017 3.015 2.992 3.500 74 2290.64 31.07 3.014 3.012 2.992 3.500 75 2321.71 29.88 3.013 3.012 2.992 3.500 76 2351.59 30.76 3.025 3.027 2.992 3.500 77 2382.35 31.38 3.015 3.013 2.992 3.500 78 2413.73 31.48 3.010 3.011 2.992 3.500 79 2445.21 31.47 3.005 3.009 2.992 3.500 79.1 2476.68 6.36 N/A N/A 2.992 3.500 l lm 80 2483.04 31.29 3.007 3.005 2.992 3.500 81 2514.33 30.51 3.014 3.012 2.992 3.500 82 2544.84 30.92 2.992 3.013 2.992 3.500 83 2575.76 31.02 3.023 3.022 2.992 3.500 84 2606.78 31.55 2.992 3.013 2.992 3.500 85 2638.33 30.59 3.010 3.011 2.992 3.500 86 2668.92 31.20 3.014 3.013 2.992 3.500 87 2700.12 31.30 3.010 3.007 2.992 3.500 88 2731.42 31.52 3.008 3.009 2.992 3.500 89 2762.94 31.02 3.017 3.016 2.992 3.500 90 2793.96 30.55 3.015 3.014 2.992 3.500 91 2824.51 31.73 3.018 3.016 2.992 3.500 92 2856.24 31.28 3.014 3.013 2.992 3.500 93 2887.52 30.98 3.017 3.016 2.992 3.500 94 2918.50 31.73 3.008 3.011 2.992 3.500 95 2950.23 31.98 3.006 3.006 2.992 3.500 96 2982.21 31.57 3.008 3.009 2.992 3.500 97 3013.78 31.50 2.992 3.004 2.992 3.500 98 3045.28 31.09 3.011 3.012 2.992 3.500 99 3076.37 29.90 3.006 3.010 2.992 3.500 100 3106.27 31.22 3.001 3.005 2.992 3.500 Well: 1A-08 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 16, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 101 3137.49 29.99 3.007 3.009 2.992 3.500 102 3167.48 30.51 3.008 3.010 2.992 3.500 103 3197.99 31.47 3.011 3.011 2.992 3.500 104 3229.46 30.67 3.021 3.016 2.992 3.500 105 3260.13 31.90 2.999 3.003 2.992 3.500 106 3292.03 31.37 3.000 3.002 2.992 3.500 107 3323.40 31.41 3.014 3.011 2.992 3.500 108 3354.81 31.21 2.995 2.995 2.992 3.500 109 3386.02 29.51 3.014 3.015 2.992 3.500 110 3415.53 30.39 3.000 2.999 2.992 3.500 111 3445.92 29.43 3.006 3.003 2.992 3.500 1i2 3475.35 31.72 2.999 3.000 2.992 3.500 113 3507.07 29.36 3.006 3.008 2.992 3.500 114 3536.43 32.21 2.999 3.000 2.992 3.500 115 3568.64 31.10 3.001 2.997 2.992 3.500 116 3599.74 30.47 2.998 2.996 2.992 3.500 117 3630.21 31.69 2.995 2.993 2.992 3.500 118 3661.90 29.84 2.998 2.999 2.992 3.500 119 3691.74 30.94 3.006 3.003 2.992 3.500 119.1 3722.68 6.20 N/A N/A 2.992 3.500 ;Ira 120 3728.88 30.83 2.997 2.997 2.992 3.500 121 3759.71 31.39 2.990 2.989 2.992 3.500 122 3791.10 30.85 3.007 3.002 2.992 3.500 123 382i.95 30.48 2.995 2.993 2.992 3.500 124 3852.43 30.50 3.007 3.004 2.992 3.500 125 3882.93 28.78 2.987 2.985 2.992 3.500 126 3911.71 29.67 2.990 2.991 2.992 3.500 127 3941.38 31.26 2.993 2.992 2.992 3.500 128 3972.64 31.53 2.999 3.000 2.992 3.500 129 4004.17 31.56 3.005 2.999 2.992 3.500 130 4035.73 30.14 2.988 2.989 2.992 3.500 131 4065.87 29.96 3.003 3.002 2.992 3.500 132 4095.83 29.88 3.004 3.002 2.992 3.500 133 4125.71 29.65 3.001 3.001 2.992 3.500 134 4155.36 30.13 3.007 3.005 2.992 3.500 Joint Tally page 2 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body--- 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 135 4185.49 31.01 3.015 3.012 2.992 3.500 136 4216.50 31.73 2.999 2.998 2.992 3.500 !,,36.1 4248.23 6.30 N/A N/A 2.992 3.500 ~lm 137 4254.53 31.86 2.995 2.996 2.992 3.500 138 4286.39 31.28 2.996 2.994 2.992 3.500 139 4317.67 31.43 2.993 2.992 2.992 3.500 140 4349.10 30.89 2.992 2.990 2.992 3.500 141 4379.99 31.59 2.993 2.998 2.992 3.500 142 4411.58 32.36 2.996 2.996 2.992 3.500 143 4443.94 29.43 2.988 2.990 2.992 3.500 144 4473.37 30.46 2.992 2.992 2.992 3.500 145 4503.83 30.39 3.002 3.001 2.992 3.500 146 4534.22 31.29 2.993 2.988 2.992 3.500 146.1 4565.51 6.30 N/A N/A 2.992 3.500 .~lm 147 4571.81 31.51 2.990 2.986 2.992 3.500 / 148 4603.32 31.75 2.991 2.989 2.992 3.500 149 4635.07 29.48 2.988 2.986 2.992 3.500 ,, 150 4664.55 31.11 2.987 2.983 2.992 3.500 151 4695.66 30.77 3.001 2.999 2.992 3.500 152 4726.43 31.19 2.988 2.982 2.992 3.500 153 4757.62 28.33 2.993 2.990 2.992 3.500 154 4785.95 30.33 2.991 2.989 2.992 3.500 155 4816.28 29.64 2.995 2.994 2.992 3.500 ..1...55.11.. 4845.92 6.42 N/A N/A 2.992 3.500 i lm 156 4852.34 31.35 3.000 2.999 2.992 3.500 4'57 4883.69. 30.82 2.992 2.988 2.992 3.500 158 4914.51 30.90 2.992 2.992 2.992 3.500 159 4945.41 29.87 2.984 2.982 2.992 3.500 160 4975.28 28.43 2.987 2.985 2.992 3.500 161 5003.71 28.02 2.979 2.978 2.992 3.500 i'162 ' 5031..73' 29.76 2.970 2.971 2.992 3.5(J0' 163 5061.49 31.65 3.004 3.002 2.992 3.500 164 5093.14 28.95 2.980 2.979 2.992 3.500 165 5122.09 30.84 2.989 2.985 2.992 3.500 166 5152.93 28.78 2.999 2.995 2.992 3.500 Well: 1A-08 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 16, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 166.1 5181.71 6.30 N/A N/A 2.992 3.500 Im 167 5188.01 28.66 2.986 2.981 2.992 3.500 16~ 5216.67 30.56 2.989 2.981 2.992 3.500 169 5247.23 31.80 2.988 2.979 2.992 3.500 170 5279.03 29.79 2.980 2.965 2.992 3.500 171' 5308.82 27.98 2.971 2.967 2.992 3.500 172 5336.80 29.29 2.982 2.981 2.992 3.500 ~173 5366.09 31.02 2.984 2.982 2.992 3.500 174 5397.11 31.46 2.980 2.975 2.992 3.500 175 5428.57 29.08 2.992 2.991 2.992 3.500 176 5457.65 30.63 2.979 2.978 2.992 3.500 176.1 5488.28 6.21 N/A N/A 2.992 3.500 Im 177 5494.49 31.22 2.988 2.987 2.992 3.500 178 5525.71 30.74 2.977 2.980 2.992 3.500 'i' 79 5556.45 30.26 2.982 2.982 2.992 3.500 '1'80 5586.71 31.33 2.976 2.972 2.992 3.500 18~" 5618.04 30.32 2.984 2.983 2.992 3.500 i82. 5648.36 31.23 2.973 2.970 2.992 3.500 183 5679.59 30.36 2.999 2.995 2.992 3.500 184 5709.95 27.53 2.970 2.975 2.992 3.500 185 5737.48 30.24 2.974 2.977 2.992 3.500 185.1 5767.72 6.80 N/A . N/A 2.992 3.500 lm 186 5774.52 28.20 2.970 2.969 2.992 3.500 i87' 5802.72 31.00 2.995 2.996 2.992 3.500 ...1.88..[. 5833.72 29.50 2.950 2.946 2.992 3.500 !88.1 5863.22 9.24 N/A N/A 2.992 3.500 tim 189 5872.46 32.04 2.944 2.938 2.992 3.500 1'89.1 5904.50 20.84 N/A N/A 2.992 3.500 ,~br 1'89'.2 5925.34 8.82 N/A ' N/A 2.992 3.500 Jacker 190 5934.16 30.95 2.959 2.952 2.992 3.500 190.1 5965.11 6.46 N/A N/A 2.992 3.500 lm i9~' 5971.57 31.54 2.982 2.978 2.992 3.500 192 6003.11 31.24 2.936 2.935 2.992 3.500 193 6034.35 32.61 2.943 2.940 2.992 3.500 194 6066.96 2'9.90 2.952 2.953 2.992 3.500 Joint Taffy page 3 i I' I I i I i I I i ! I PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 BTC AB-MOD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 195 6096.86 N/A 2.992 2.947 2.992 3.500 Well: 1A-08 Field: Kuparuk Company: ConocoPhil]ips Alaska, Inc. Country: USA Survey Date: January 16, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches Joint Tally page 4 an 14 03 0?=3Ia PRI WELLS GROUP 907 659 7314 p.2 i i i KRU 1A-08 Reference Lo~ SURF CASING - TUBING .... Size BoOm 3.500 O 2.87.5 6133 6168 Int,rval TVD 600t - 6O3? 6O41 - 6046 60~2 - 6037 6050 - 6055 6041 ~ 6046 6073 - 6084 6064 . 6076 6134 - 6136 6125 - 6127 6217 - 6227 6208 6224 -6250 StinmllitieetS & T~eatme~ts Interval 6134-6136 Gas Lilt;Mm~drelt, P,/'al~z,s * ..: TVD 6124 6159 . . .. Thread 8RD .. ~limleone Slimkone Stimi~on~ ~tinlkone 8ti~ne Commeltt · . Vlv General. Notes. Vtv Cmnt DescrWtk~n ID Camco TRDP-1A-ENC Baker Baker Fl-IL AVA'05B BPL Nipple 011512002 2,813 3.000 2.750 2.310, 4.000 2.2S0 ' ,?..430, 71:Z2/98 & pulled from 6085' on 7/29/90 WEt L - IA. x OA commurtical~n i 1. Operation Performed: Operation Shutdown., . Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate ~ Plugging Perforate _ Repair well O t h e r __ 6. Datum elevation (DF or KB) 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 589' FSL, 311' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 589' FSL, 311' FWL, Sec. 5, T11N, R10E, UM At effective depth 589' FSL, 311' FEL, $ec.5, T11N, R10E, UM At total depth 589' FSL, 311' FEL, Sec. 5~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 63 8 2' Effective depth: 13. true vertical 6382' measured 631 5' true vertical 631 5' Length Size 80' 16" 2862' 10-3/4" 6364' 7" feet Plugs (measured) feet None feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: RKB 108' 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-8 (WS-12) 9. Permit number 78 -40 feet 10. APl number 50-029-2031 300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 250 sx AS 1 6 2' 1 6 2' 2400 sx PF 2244' 2244' 609 sx Class G 6364' 6364' measured 6001'-6037',6041'-6046', 6050°-6055', 6233'-6259' 4 SPF 120 degree phasing true vertical Same As Above Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 6130', 2 7/8" N-80 set at 6167' Packers and SSSV (type and measured depth) Baker FB @ 6142', Baker FH @ 5923', Camco TRDP-1A-ENC @ 1794' Stimulation or cement squeeze summary A Sand Re-frac See Attached WSR Intervals treated (measured) 6 21 7'- 6 2 2 7', Treatment description including volumes used and final pressure 6073'-6084', 6217'-6227', 14. Reoresentative Daily Averac~e Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 510 640 290 1200 200 Subsequent to operation 1150 2380 630 1300 22O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector m 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 09/12/90 Title SUBMIT IN DUPLICATE ARCO Alaska, In~ Subsidiary of At antic Richfield CompanY ~ELL CONTRACTOR .MARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME C~,,,~ ! WELL SERVICE REPORT IDAYS ~ DATE /-/z S- /-/D ~opru/ l qSr') W-o~g) &CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. I Chill Factor I Visibility .,1®. IWInd v®,' ? knot. Js~~ :' REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL ,, CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS .~, DOWELL .. HALLIBURTON ' - ARCTIC COIL TUBING FRACMASTER ROustabouts, ~'~ ~ ~, ,Diesel ,'~ ~ ~ ~ ~ ~ ' , /~0, ~ ..... Methanol Supe~ision , ~~/~ ' -' -- V Pre-,Job Safety Meeting TOT*L F~LO ~ST~*~ " S'n A~RCO Alaska, In(. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 20, 1987 Transmittal #6088 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lA-8 Static BHP Bottom-Hole Pressure Survey 9-29-87 ~3A-4 Kuparuk Well Pressure Report (Otis) 9-27-87 ~'7'-2B-4 Pressure Build Up Test 10-13-87 ~lL-2 Kuparuk Well Pressure Report(Otis) 9-6-87 ~'lL-15 Kuparuk Well Pressure Report(Camco) 6-9-87 ~lL-8 Kuparuk Well Pressure Report(Camco) 6-9-87 50-029-20313 'A' Sand Static 'C' Sand 02157 Static Static 'C' Sand 'C' Sand Receipt Acknowledged: DISTRIBUTION: D~ 0i1 & Gas Cons. Commission D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, I987 Transmittal # 5966 Return to: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the. following items. Please acknowledge receipt and retUrn one signed copy of this transmittal. 3H-7 CRT 4-I-86. 6202-7597 3N-6 CRT 4-1-86 6061-7583 3N-11 CRT 4-22-86 7600-8675 3N-12 CRT 4-29-86 6396-7965 3H-lO CRT 4-14-86 7462-9130 3J-16 CRT 3-29-86 7704-8727 3J-15 CRT 3-29-86 7400-8398 1A-8 CRT 1-5-86 5755-6154 2Z-7 CRT 4-14-87 8250-8491 2Z-7 C£T 4-12-87 8246-8595 2Z-7 Squeeze & Retainer Record 4-15-87 8250-8491 2Z-7 Squeeze, BP & Retainer Record 4-12-87 8290-8588 - 0 ! 1987 ~ Alask~ 0ii & Gas Cons. Commission ~ Anchorage Receipt Acknowledged: DISTRIBUTION: NSK Drilling Chevron Mobil Date' ~?State of Alaska (~ sepia) SAPC Unocal . VauLt BPAE (film) ARCO Alaska. Inc. is a Subsiaiary of AtlanticRichtieldCompany ARCO Alaska, Inc. PoSt Office Bo~0360 ' Anchorage, Ali i ~'99510'0360 Telephone 907 276 1215 October 31, 1986 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5805 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CET/CEL 1-03-86 Run ~1 5600 CET/CEL 12-21-85 Run #1 4800 CET/CEL 10-22-85 Run #3 8490 CET/CEL 10-09-85 Run #2 6800 CET/CEL 12-15-85 Run #1 5496 CET/CEL 10-30-85 Run #1 5350 CET/CEL 10-17-85 Run #1 5925 CET/CEL 12-17-85 Run #2 8595 CET/CEL 10-05-85 Run #1 6624 CET/CEL 10-19-85 Run #1 5350 - 6300 - 7521 - 8830 - 7406 - 6870 - 8342 - 7726 - 9110 - 8367 - 7527 Receipt Acknowledged: Distribution' ~e .of AlaSk~ BPAE Chevron Mobi 1 NSK Drilling Vault(1 film) SAPC Union · ~ ARCO Alask.-", thC. is a Subsidiary of AtlanticRichfieldCompany ARCO AIz, ska, I'nc. ,- . Post Office !~' 100360 Anchorage, A._~ka 99510-03'60 Telephone 907 276 1215 September 2, 1986 Mr. C, V. Chatterton ,, Alaska Oil and Gas Conservation Co~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Kuparuk River Field _ Production Surveys - Dear Mr. Chatterton' In Compliance with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey.informa- tion for the second quarter of 1986. Production survey information consists of production logs and production tests as identified in Attachment 1. Production logs (spinners) identified in this attachment will be sent under separate cover. Note that several initial spinners not previously submitted to the State are being submitted at this time. If you have any questions concerning the information reported~ please contact me at (907) 263-4935. Sincerely, V. L. Ferguson Senior Operations Engineer VLF'pg'O074 ~ Y' Oil & Gas Cons. Oomm!ssiorl . ~,~-,C~ Alaska, :nC. i= ~ ~ub~;'~;e,v of Atlant!cRichi~etc~Cor"..~any ARCO Alaska, Inc. ~ i=~ Post Office B~,,~'" 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 18, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1A-8 Dear Mr. Chatterton- Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L140 Enclosure If : :CEIVED F E B 2 1 1986 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA % ALASKA d~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I--Ixx GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. ~ 78-40 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20313 4. Location of well at surface 9. Unit or Lease Name 589' FSL, 311' FWL, Sec.5, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 589' FSL, 311' FWL, Sec.5, TllN, R10E, UM 1A-8 At Total Depth 11. Field and Pool 589' FSL, 311' FWL, Sec.5, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 108' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 07/22/78 08/04/78 08/30/78*I N/A feet MS L 1 17. Total Depth (MD+TVD)6382,MD & TVD 18.Plug Back Depth (MD+TVD)6315,MD & TVD YES19' Directional Survey[] NO I~X I20' Depth where sssv set1797 feet MD I21' Thickness °f Permafr°st1700' (approx) 22. Type Electric or Other Logs Run D IL/SP/GR, BHCS/GR/Cal, Mi crolog, FDC/CNL/GR/Cal, Dipmeter, CBL/VDL/GR, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.U# H-tO ' Surf 162' 24" 250 sx AS cmt 10-3/4" 45.5# K-55 Surf 2244' 13-3/4" 2400 sx PF cmt 7" 26.0# K-55 Surf 6364' 9-7/8" 609 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) 6233' - 6259' 3-1/2" 6168' 5927' & 6145' 6217' - 6227' 6073' - 6084' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 6050' - 6055' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6041' - 6046' 6134' - 6136' 100 Sx Class G 6013' ' 6037' 6001' - 6013' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 11/20/78 F1 owl ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCr WATER-BBL CHOKE SIZE IGAS-OILRATIO 11/20&12/13 /78 547.8 TEST PERIOD I~ 35,923.7 17,708.5 -- 1"I 493 Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 115 ps 0 24-HOUR RATE I~ 1574 776 -- 26.00 APl 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED F E B 2 1 1986 Alaska Oil & f:;;,~,s C.,'..'.qs, G~mmission Form 10-407 * NOTE: Tubing was pulled & well recompleted 1/8/86. DAM/WC12 Submit in dupticate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MA~:~KERS FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk Sand 6000' 6000' N/A Base Kuparuk Sand 6315', . 6315, '. 31. LIST OF ATTACHMENTS Well History (workover) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · y~ Associate Engineer Signed ~ ~ Title Date ~44-I~1~ _ 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 { ~., At~CoOiiandGasCompanF g~"-' ~ ~ . · Well History- Initial. Report- Daily - I [~,trUctlone- pr'oars'and, submit the "Initial' Report" on the first Wednesday after a well is spudded or workover operations are started. · Dally work prior to spudding should be summarized ~n: the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O; no, AFE 894397~ ~ . County. parish or borough I State North Slope Borough '1 Alaska Lease or Unit Title ADL 25647 Recompletion IWell no. lA-8 W/O ARCO w.I, Pflor statue If · W.O. 56.24% 1/03/86 1/04/86 thru 1/06/86 ' 50- bbls.' cUJesel/~ cln~ tbg-?.. 'Pull" ACte~:Co kill well' w/Lttesa~.: a .9.5 PPg brine v/o · ~ co. 9~ 9 ppg, kli~..vetI',, obsess, veil. cakln~. ~u=~-vol~ spoc::Brtd'sesai, pt-ll~ Loss race: 27 7'r'~ 6364~. . 63t57 PBTD~: ~ltr~-p~?~:~ - ~?.;.)- - · 9.9' ppg NaCI/N~-'~' ~ispI-'pilt-~::. SqZ,.Bztdgea~~ P~}~inte.-perle w/final press of 1000 pe~.~ Dt~p~ ~n--~ se~ BPV,: ~ ~ree, ~ & ts~ BOPg. Pull B~$~': ~lI: .hF~;~.ff~g~3~ tbgi.-ch~ collars to nillin~' as~y~"~~off PRT in pkr, POH~-. RIE v/mill shoe on wshpfpe, ~1~ 6315' ~TD. ~'g:-CST ~o8 Complete mlll.'g pkr~ E[E v/spear, [sh pkr, Pea, lull ret'y. ~n blt & scrpr8, clrc hole cln. ~ CBT log. 7" @ 6364' 6315' PBTD, POM w/BHA 9.9 PPg NaC1/NaBr Fin rn'g CET. Prep to sql. Perf v/4" gun, 4 SPF, 90° phasing f/6134'-6136'~. SeC BP @ 6160', Retnr @ 611G*. RIM w/stinger on DP, est IR, sqz 100 sx CI "G" cmo v/.8% D-28, .3~% CD-31 & .1% D-6. CIP @ 2145 hfs,.1./3/86, Rev out excess & WOC~ TIH, DO retnr & hard cmt to BP, circ, POH~, RIH w/R-3 pkr, tst sqz perfs to 2000 psi, bled. to 1500 psi. Tst 7" above "C" sands to 3500 psi; OK, POH w/R-3, Re-rn CET; cmt coverage good. TIH w/bit, DO BP & CO to PBTD. Filter brine, POH.. R CEIVED FEB 2 1 1986 The above is correct For form preparatlor~ and distribution, see Procedures Manual, Section 10. Drilling, Pages 88 and 87. Drilling Superintendent · ARCo Oil and Gas Company- Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Reporl" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire Operation if space is available. Accounting cost center code District ICounty or Parish Alaska I North Slope Borough Field JLease or Unit Kuparuk River J ADL 25647 Auth. or W.O. no. ~Title AFE 894397 J Recompletion State Alaska IWell no. 1A-8 W/O WWS 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover Date and depth as of 8:00 a.m. 1/07/86 1/08/86' API 50-029-20313 JA.R.Co. W.I. 56.24% IDate 12/30/85 Complete record for each day reported Iotal number of wells (active or inactive) on this i est center prior to plugging and I bandonment of this well I our I Prlor status if a W.O. 0300 hrs. 7" @ 6364' 6315' PBTD, Rn'g compl 9.9 ppg NaCl/NaBr POE. RIH w/bit & scrprs, circ, POH. Make JB/gage r~g~ run. Rn Bkr FB-1 pkr & set @ 6141.5' (WLM), RD SOS. PU CA & RIH. 7" @ 6364' 6315' PBTD, RR' Diesel in tbg & ann RIH w/3½" compl, stab in btm pkr, space out & lnd tbg. Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree to 250/5000 psi. Displ ann w/diesel. Set BPV. RR @ 0600 hfs, 1/8/86. Moving to DS 2X-8. Note: SSSV @ 1797', FHL pkr @ 5927', FB-1 pkr @ 6145', TT @ 6168'. Old TD Released rig 0600 hrs. Classifications (oil, gas, etc.) 0il Producing method Flowing Potential test data INew TD ] PB Depth , 6315 PBTD Date IKind of rig 1/8/86 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation a~l distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCOAaska, lnc. r ~ .. Post Office BoX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED F'E ! 3 1986 AlasKa 0il & b~.~s Cc:ns. Gu~iiHlJssJon AnchoraDe STATE Of ALASKA --- -- ALASKA L..r- AND GAS CONSERVATION CO,,.,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operationX~ 2. Name of operator 7. Permit No. ARCO A1 aska, I nc. 78-40 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20313 4. Location of Well atsurface 330' FSL, 330' FWL, Sec.5, T11N, RIOE, UM 9. Unit or Lease Name Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 108' RKBI ADL 25647 ALK 465 For the Month of January , 19 86 10. Well No. 1A-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 0300 hrs, 12/30/85. Killed well. ND tree. NU BOPE & tstd. Pulled tbg. Milled & fished for pkr. Ran CET. Perf'd f/6134' - 6136'. Set bridge plug & retainer. Squeezed w/100 sx Class 6 cmt & tstd. Rerun CET. Set FB-1 pkr. Ran 3-1/2" completion assy. ND BOPE. NU tree & tstd. Displaced well w/diesel. Secured well & RR ¢ 0600 hrs, 1/8/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 3-1/2", 9.2#/ft, J-55, BTC tbg. 5SSV ~ 1797', FHL pkr 8 5927', FB-1 pkr (~ 6145', tailpipe ¢ 6168' 14. Coring resume and brief description None 15. Logs run and depth where run CET - depths not available 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED F ~. G 1 3 1986 Alaska Oil & Gas Cons. commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~n ~ ~6~ TITLE Associate Engineer DATE 1'~/'8~ N©TE--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR31 R ,, ? I 8~ Submit in duplicate ARCO Alaska, Inc. ~ i! , Post Office Bo~( 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 5, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1A-8 Dear Mr. Chatterton- Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L59 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i STATE OF ALASKA ~', ALASKA OiL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of Well Surface: 330' FSL, 330' FWL, Sec.5, T11N, RIOE, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 78-40 8. APl Number 50-- 029- ? (~, 1 ~, 9. Unit or Lease Name 10. Well Number 1A-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. RKB 108' ADL ~_5647 ALK ~.65 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing '[~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) all pertinent details and give pertinent dates, including estimated date of starting any i 13. Describe Proposed or Completed Operations (Clearly state proposed work, for Abandonment see 20 AAC 25.105o170). Accepted rig ~ 0300 hrs, 12/30/85. Killed well. ND tree. NU BOPE & tstd - ok. Pulled 3-1/2" tubing. Milled & recovered pkr. Ran CET. Perf'd f/6134' - 6136'; squeezed w/lO0 sx Class G cmt. Tstd 7" csg to 3500 psi - ok. Set FB-1 pkr @ 6141.5'WLM. Ran 3-1/2" completion assembly. Tstd tubing to 2500 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel. Secured well & released rig ~ 0600 hrs, 1/8/86. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~6 ~ ~ Title Associate Enqineer The space belc~ for Commission use Conditions of Approval, if any: Date Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU13/SN05 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. 'i ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1A-8 Dear Mr. Chatterton' Enclosed is a Sundry Notice for 1A-8. We propose to convert this well to a selective single completion. Since we expect to start this work on December 25, 1985, your earliest approval will be appreciated. If you have any questions, please call Jeff Qu~ntana at 263-4620 or myself at 263-4944. Sincerely, Gruber Associate Engineer JG/tw SN/L083 Enclosure RECEIVED A!aska 0i~ & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i ' STATE OF ALASKA ~ ALASKA O'~L AND GAS CONSERVATION COw, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx[~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 330' FSL, 330' FWL, Sec.5, T11N, R10E, UN 5. Elevationinfeet(indicate KB, DF, etc.) RKB 108' 6. Lease Designationand SerialNo. ADL 25647 ALK 465 7. Permit No. 70-40 8. APl Number 50- 029-20:313 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A-8 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. operationally~ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start= December 25, 1985 BOP equipment will be tested weekly and The o 'c 9 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space beJ/q/w for Commission use Conditions of Approval, if any: Approved by. BY LONtqlE 'l, SIIITi' I Approved Co~ ~,eturneci ,,5 .~ By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate (JLQ) $N/121 ARCO 'Alaska, Inc~,.T.~, Post Offic~ ~ i 100360 , Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DAT~: 09-05-85 TkANSNITTAL NO: 5332 K~TURN TO: ARCO ALASKA, INC. KUPARUK_ OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANC~OKAGE, AK 99510 TRANSMITTED .HERLMITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONL SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS PRESSURE DATA 1H-3 -~ PBU 2A-I---- 'C' SAND PBU 2B-12,-" 'C' SAND PBU 2C-U 'A' SAND PBU 2V-2 - 'A' SAND PBU 2V-5 ~ 'A' SAND PBU 03-07-85 08-03-85 08-01-85 08-16-85 07-27-85 06-25-85 SEi)UENCE OF EVENTS FROM WELL SERVICE REPORTS/PRESSUPJJ DATA lA-8 ~'~ bBHP & NI$C. iA-5 PBU & MI SC. lA-3'~''' PBU lA- 3--- Pt~U lB-2-- 'C' SaND P~U lB-2..-- 'C' SAND PBU lB-5 / ~T~TIC TEMP.LOG 08-22-85 08-14-85 08-12-~5 0~-11-85 0S-05-85 08-06-85 0~-15-~5 1E-21--' RUN BHP & MISC. 08-03-85 1F-5 "~ PBU 'A' & 'C' b~qD (ISLTD) U~-18-~5 1F-5// PBU 08-17-85 1G-15~' 'C' SAND PBU 1G-15~- 'A' ~AND PSU & MISC. 1G-15/ 'C'. SAND PBU IR-10..-" BHP & MISC. 1P,-9_/ BHP & FII~C. iR-12 _..- BHP & MISC. 2A-1/ 'C' SAND PBU 2A-1''/ 'A' SAND BHP 2A-l"' 'C' SAND PBU 2A-13~. BHP & MISC. 2B-13.-- 'A' SAND BhP 2B-13-- 'C' SAND PBU 2B-i3--~ DATA FROM ~HP SURVEY 2B-13~ 'C' SAND PBU 2C-8/ PBU 2G-16" PBU 2G-16/ PBU RLCEIP~ ACKNO~LEDGED: 08-10-85 08-06-85 08-09-85 08-15-85 08-15-85 08-19-85 08-04-85 08-04-85 08-03-85 0~-25-85 0~-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 DIST~{IBUTION: BPAE D~.ILLING W. PASHER B. CURRIER L. JOHNS?ON EXXON CHEVRON ['~OOIL P~ILLIPM OIL D & M NbK CLERK J. k~T~iELL *PLEASE NOTE--DISTRIB- UTION CONTINUED ON NEXT PAGE. /~, .,:'- f',..., S .J. ATJ~ OF xi/A..,l.,.,aS KA UNION ": K.TULIN/VAULT ':":",'..?.'~.~" ~,'o,?;,..:_ .... ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.~.T..~ ' .Post Office i : 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 i:~..'ETURN TO' ARCO ALA.':'.,'I(A, INC. ATTN' RECORDS L, LERK A'i' R - t -! t .:- B F',O, BOX i00360 ANCHORAGE, Al< 995'1~ 'Y'F:.:ANS'HITTED I.IEREWITH ARE THE FOLI_.rjWING F.:'.ECEIPT AND RETURN ONE SZ6NED COPY OF /.;'E'r.~ tENCE OF i 2 G - 'I 6 2 C - 9 :2 B--- 2 2Z-5 2D-.--~ DATE' AF:Fi'.IL t9, TRAN~,HITTAI.. NO' I'l"li'~M S, F I.. E A,,, E TH I $ "I'RANSH I TTAI.., EVENT.?: · FL. LJID ID F'L!HF' GELLED WATER F'BLI ' FLUID ID STATIC BHP F'BU ,..,,' I.. SURVEY FLOWING 'BHP BATCH FRAC 412/85 4/t4/85 416-7185 416185 4/6185 4/3-5/85 415/85 4/2/85 F:'A (:; [: 2 C) F A r'..; I( N 0 W/.. E: D G E '::ECEIPT ACKNOWLEDGED' '::F' AE 'i-,'., C tJR R I E F,' ';:I-.IEVRON · e, DIY. TR'!BUTION' DF;~I L.t_ I NC-. !.4. F'A,~I-.!E.R !_. JOHNSTON EXXON MOBIL F'I-! ]: !._!_. l P.~ OIL r-,~ ~, CLERK J RATHMELL " RECEIVED APR 2 1985 Alaska Oil & 8as Cons. Commission DATE' Anchoca~ __ U N ]: 0 N K. '[~L I N/VAUL T . · ARCO Alaska, Inc. "-% post Offi ,c~x 100360, Anchorage, ~laska 99510-0360 Telephone 907 276 1215 I) A T E · A !::' F< I I.. I ''-~ ~ ..., ....... TRAN;~i'iZ 'T"I"AI... NL] ·..;.'::'t .:~., '7 F:'t;:'., G E 2. 0 F' 'E T U F.'. t',! ]'.' r3 · A F:; C: ['J A 1._ A ,?:.' I.( A, ]: i,.! C, . , · c, I"' .t:. ', : A T T N R E C O 1-7 T) ,.:. .... L.. ~:. F... I,, , A 'T O ..... i i ~ .5'- [: F'~ C),. T:; ..n. X I O (.) ,'.'; 6 A i',! r' ..... I..I r'i I7 (:'~ G E, A K 9 ";.;-. _.,':" t ,'.',~: '!:;:;.*.~i':J.,S.'HZTT~!:~) ~ .t E: ?;: IT. L! ]: ]" H ARE ]"HE: F'C)L. LOt4]:i':IG 'J:'~'lii:H,".;;, F:'L.E.A,.?.r::.' ACI<NC)WI...F:I)GF' ;:.- ....... c. L.'[ ] '=" l" A i',.! ..r,, F.: E: T U i-7 N n. ....... N 1:= 21 C.,. i:! E D C 0 I=' Y []F T H I ,? T F:; A H 2 H I T T ,,'--~ L E] (~ U E N C: E 0 F' E \:; E N 'i" 3' · .Ft...U T. D F'LIHF'. GELLED WATER .E',A'TCI-I FLUID ID 2TATIC BHF' F'~ t.J t-- , ~"' J j r.', ~; .D'. './ F'LONING .r.,'H F' F" F,' A C ¢,, r£ i.'..' !'J. 0 !4 I_ E .T) G E D · P,~ 1T I r:,: fj · ........... l,.:J ~" '" ""' '"' F;: :. I" f-I ,.~ r': EXXON PH]i L.L I F',:?, O];L. J, F; r;:',, T Fli"i E L. L. ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany I) A 7' E: · ARCO Alaska, Inc. Post Office/,r-~x 360 Anchorage, iaska 99510 Telephone 907 277 5637 Date: 1/03/8.5 Transmittal No: 4951 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B ~. P.O. Box 100~0 ., //A~rage, AK 99510 · ~/~ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. TORQUE 'TURN-: PPiES~U~' ~' TEMP "sURVEYS 1Y-16 12/15.~' 16/84 Gauge 1Y-10 12/17, 18/84 f/64009 lA-8 12/10, 11/84 f/64009 /cat .. Receipt Acknowledged: B. Currier BPAE Chevron D&M Date: ~1,~,,~ v,, ~ u~ Cons. Commission DISTRIBUTION D. rill~ng W. Pasher Geology' G. Phillips Mobil Phillips Oil NSK Ops. J. Rathmell Anchorage State-Of AK Sohio Union Well Files ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany To: . Date: Wm. Van Al~..n/Sate · . 31 AUgust, 1983 Atlantic RitChfield Company Arco Alaska, Inc. Ti~SMI.TTAL of AK From: EXTENSION/EXPLORATION' · . o. .. Transmitted herewith are the following: Mud logs f'rom the following wells: lA-5 "~'. " g-ll-81 1A-8'{~West Sak .12) ' 7-22-78 1B-5~West Sak 7) '11-27-77 1-1-81 1C-5 x " 2-9-81 1C-6'× 3-1.-81 1D-4-' 12-31-79 1D-8~West Sak. 8) 4-7-78 1F-5J' 8-20-82 1G-4~- · 10-12-82 1H-3-~ 7-24-82 1H-6j 5-19-82 1Y-14j 2-4'83 2C-6 '~ 7-8-83 2C-7,~ .. , . 6-29-83 ~ . 2X-2 f 7-2-83 2Z-4- -,' 6-10-83 Also: included is an expanded' core' log from well 2X-2,-·7-2-83. A blueli~e copy and a Sepia is provided for each well.. · ' .R~. eipt Acknowledge:' .. R'~turn receipt to: Arco Alaska, Inc. At tn: XM~XMM0~ E. P.O. Box 100360 Anchorage, gaY. Date: McAlister · , Prepared by: B.Byrne 99510 KUPARUK ENG ! NEERI I',E; TRAN~,~ i T'FAL #/?~.~--- TO' William VanAlen ~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following- PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, /~EASE RERJRN RECE i pT TO: ARCO ALASKA, I !'~. ANCHORAGE, AK. 99510 ARCO A~aska, Inc. -- Post Office B~. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 JulY 6, 1982 C. V. Chatterton State of Alaska 'Oil and Gas Conservation Conm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Enclosed are Sundry Notice Subsequent Reports for KuparukWells lA-5 and ~tA~8 which cover the acid stimulation. Sincerely, ~E. A. Simonsen EAS/er cc: L. B. Kelly -AST 303 w/Attachment L. M. Sellers - ANO 332 w/Attachment ARCO Alaska Inc is a subsidiary of Allanl~cR~ch ,Jo~Compaq, , i, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc, 78-40 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20313-00 4. Location of Well 9. Unit or Lease Name .... Kuparuk River Unit SL: 311' FWL, 589' FSL, Sec. 5, T11N, RIOE, UM BHL: 311' FWL, 589' FSL, Sec. 5, T11N, RIOE, UM 10. Well Number 1A-8 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and serial No. K U p ar u k KB:I 0O ' I ADL 25647 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field River 0il Poo NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. 'Describe PropOsed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Kuparuk Well lA 8 was stimulated with 12°' - ,o HC1 acid in the Upper, Middle and Lower Sands on May 29, 1982. A coiIed tubing unit was used squeeze 3738 gaIions of 12°' ,o HCi with mud and slit remover into the perforated intervaIs 6001-6037' 6041-6046' 6050 6055' 6073 6084' , , -- , -- 6217-6227', 6233-6259'. Nitrogen was used to dispiace and underbalance the wellbore, The well was fiow tested for 5,4 hours at an average oil rate of 1983 BPD and a gas rate of 1715 MCFD. All circulated and produced fluids were flowed to stock tanks and then deIivered to a waste disposaI weIi. The wei1 is presentiy fiowing to the Centrai Production Faciiity. A-28 the best of my knowledge. RECEIVED JUL 2 0 J982 Alaska 0il & ?.s. Cons. Commis.,~, ~,,cnorage 14. I hereby ~rtify that t~'e foregoing is true and c_orrect j;.o Signed /.~/~~'~'"'~// /~__ ~, t, 7 ~2 .~~~~r~ /ne s~e oelow ~r uomml~ use Con,ions of Approval, if any: Regional Operations Title Engineer Date Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 , ,'~F'"- STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CL,,VlMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IZ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Aiaska, Inc. 78-40 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 5o- 029-20313 4. Location of Well SL: 589'FSL, 311'FWL, BHL: Same as above 5. Elevation in feet (indicate KB, DF, etc.) 100 ' RKB Sec 5, T11N, RIOE, UM 6. Lease Designation and Serial No. ADL 25647 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-8 (WS 12) 11. Field and Pool Kuparuk River Kuparuk River Field Oil Poo 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate (~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to stimulate the Kuparuk Sands with acid. Acid wiii be spotted with a coiied tubing unit with BOP assembiy tested to 4000 psi. AiI circuiated and flowed fiuids wiii be diverted to tankage on iocation. The weii wiii be tested subsequent to the stimulation. Expected start date is May 29, 1982. A-18 Subsequent Work l~eporte~ RECEIVED MAY 2 6 1982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. , ~'il~:;;ace b~~w ;or Cdm~ission u Conditions of Approval, if any: Approved by ORIG! A[ SiGr ED BY T~!?~:TE C. SMITH Area Operations Engineer Title Approved ~opy Returned By Order of COMMISSIONER the Commission Date Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - ' '~' ' ' STATE OF ALASKA ~, ALASKA(....._ AND GAS CONSERVATION C ,..MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 78-40 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 5o- 029-20313 4. Location ofvvell atsurface 5~'FSL, 311 'FWL, Sec 5, T11N, R10E, UM 9. Unitor Lease Name Kuparuk 25647 At Top Producing Interval Same as above 10. Well Number 1A-8 (WS 12) At Total Depth Same as above 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 108' RKB ADL 25647 Kuparuk River 0il Pool 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116'N°'ofC°mpletions 7/22/78 8/4/78 8/30/78I -- feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MID+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of PermafroSt 6382' 6382' 6315' 6315' YES [~ NO [] 1991 feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR, BHCS/GR,/CAL,_ Microlog, FDC/CNL/GR/CAL, D1pmeter, CBL/VDL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE.WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 162' 24" 250 sx AR 10 3/4" 45.5# K-55 Surf 2244' 13 3/4 ?/~OOsx Permafrn.~t. :mt. 7" 26# K-55 Sut'f F;36/~' 9 7/Fi" F;O9 .~× ('la_~_~ 6 cmt. 24. Perforations open to' Prb~l'LiC'~ion (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6233 ' -6259 ' 3 1/?" 597~ ' 5887 ' 6217' -6227 ' . 6073 ' -6084' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - 6050'-60551' . w/4 SPF . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL, USED 6041 ' -6046' 6013 ' -6037' 6001' ~6013' 27. PRODUCTION TEST Date First Production . I Method of Operation (FIowing, gaslift, etc.) . 12/25/81 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 11/20'12t'31/78 54'7,8 TEST.PERIOD I~ 35923.7 1770R.-5 .. !"I 493 Flow Tubing Casing pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press..' 24-HOUR RATE 157 77g -- 2¢,_fl° APT 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,, N/A CONTINUED ON REVERSE SIDE .'1'',.' '' i"i,Submit in duplicate 29. . ~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH · GOR, and time of each phase. Top Kuparuk River Form. 6000' 6000' Base Kuparuk River Form. 6314' 6314' ¢ ~.. · ._ 31. LiST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ) Area Ops. Engr. I~R ~- O'~8~ 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- lng 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 Pe:.:el,:.!.:/,?:r~r~, $ r'nonsen Tran-~.mi-t~d herewith are the fcllo:,.,'ing' ;:OT~L ' SEPIA., F- FILM, T - TAPE TO' - ?,FA./]! 1 ARCO Alaska, Inc. ~ Post Clfice ~r~ 3 Anchorage. Alaska 99510 ~ elephone 907 277 5637 June 29, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchor'age, AK 99501 -i"3 ENG ~- 4- ENG 1 OEOL ,3 OEOL STAT TEC FILF: Subject: Renaming Former West Sak Wells Dear Sir: ARCO Alaska, Inc. has recently changed the names of three of its West Sak wells to Kuparuk wells. The changes are as follows- Old Name API# New Name West Sak #7_ 50-029-20237 Kuparuk B-5 - West..~Sak~_ ~ 50-029-20266 Kuparuk D-8 "West Sak #1;~.""~ 50-029-20313 If these changes meet your approval, we will begin immediately to refer to these wells under their new names on future state permits and reports. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG'sp .cc: D. S. Smiley D. Sampert J. Pawelek S. Ja ime J. Merri tt .IUL 0 ]. , 98i An,:,n0rago ',ARCO ~il and Gas~,~mpany North Slope [~trict Post Office Box 360 Aqchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1981' Mr. Hoyl e Hamil ton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Lake State #1 DS 17-5 West Sak #12 DS 11-14 DS 2-18 DS 2-17 RES ENG 2 ENG ENG 4 ENG ] G~OL / .CTAT TEC I STAT TEC CON'FF.-R: Fl[F: Dear Sir: Enclosed please find: l) A Sundry Notice of intent detailing the work to be per- formed on Lake State #1. 2) Two (2) copies of the gyroscopic survey for DS 17-5. 3) An updated completion report including production test data for West Sak #12. 4¸) Two (2) copies each of the updated completion report and the gyroscopic survey for DS 11-14 and DS 2-18. 5) The gyroscopic survey for DS 2-17 is being rerun. The required updated completion report and gyroscopic survey will be submitted as soon as data becomes available. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:sp Enclosures Alaska Oil & G~: Oo,~s. Commissior~ Anci~ore.§o ARCO Oil and Gas Company is a Dtvi~[-': *: ~r, hc,qichfieldCompany / / Fo'~- m P--7 SUBMIT IN DU.P .... *TE* STATE OF ALASKA (see other In- structions on OIL AND GAS CONSERVATION COMMITTEE reverse side) WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLI I DRY[-'] Other b. TYPE OF COMPLETION: NEW WORK DEEP- r---i PLUG i--1 WELL r~ OVER r'--~ DIFF. EN I I BACKI I RESER.r--1 Other 2. NAME OF OPERATOR Atlantic Richfield Cumpany 3. ADDRESS OF OPERATOR P.O. Box 360~ Anchoraqe~ AK 99510 4. LOCATION OF WELL (Report location clearly ancl in accordance with any State requirements]* At surface 311'E & 589'N of SW cr Sec 5, TllN, R10E At top prod. interval ~eported below 311'E & 589'N of SW Cr Sec 5, T1]N, R10E At total depth 311'E & 589'N of SW cr Sec 5, TI1N, RIOE 13. DATE SPUDDED7/22/78 !14' 8/4/78DATET.D. R EACH ED 115. DATEs/30/78COMP, SUSP, OR ABAND. 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK MD&TVDI20. IF MULTIPLECOMPL., 6382'MD & TVD 6 & TVD ' sln.g~e' 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* Top Kuparuk Sa,,d 6000'MD & TVD Base Kuparuk Sand 6315'MD & TvD 5. APl NUMERICAL CODE 50-029-20313 6. LEASE DESIGNATION AND SERIAL NO. ADL 25647 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. ~ O~/~V,,DCAT 10. FIELD AND POOL, Kuparuk River 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 5, TllN, R10E 12. PERMIT NO. 78-40 16. ELEVATIONS (DF,RKB, RT, GR, ETC)* 117. ELEV. CASlNGHEAD 108' RKB (EST) I J 21. ROTARY TOOLS INTERVALS ~RILLED BY CABLE TOOLS . [23. WAS DIRECTIONAL SURVEY MADE no 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/GR~ BHCS/GR/CAL~ Microloq~ FDC/CNL/GR/CAL~ Dipmeter~ CBL/VDL/GR 25. CASING RECORD (Report all strings set in well) CASING SIZE WEIGHT, LB/FT. GRADE DEPTH SET (MD) HOLE SIZE I CEMENTING RECORD AMOUNT PULLED 16" · 65# H-40 162' 24" 250 sx Arctic Set cmt 10-3/4" 45,5# ' K-55 2244' 13-3/4" 2400 sx Permafrost cmt 7" 26# K-55 6364' 9-7/R" 609 sx Cla_~s G cmt 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 6233' - 6259' 6217' - 6227' 6013' - 6037' 6073' - 6084' 6001' - 6013' 6050' - 6055' 604]' - 6046' 30. 26. LINER RECORD TUBING RECORD SIZE TOP (MD) I BOTTOM (MD) SACKS CEMENT* PACKER SET (MD) 5887' 27. SCREEN (MD) SIZE DEPTH SET (MD) · 3~" 5926' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DATE FIRST PRODUCTION DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) Flowing 11/20/78 DATE OF TEST. 11/20/7@-12/13/78 FLOW TUBING PRESS. 115 psi HOURS TESTED 547.8 CASING PRESSURE 0 psi CHOKE SIZE I PROD'N FOR H I TEST PERIOD CALCULATED OIL-BBL 24-HOUR RATE i ~ 1574 31. DISPOSITION OF GAS [Sold, used for fuel. vented, etc.) flared 32. LIST OF ATTACHMENTS I WE LL STATUS (Producing or shut-In) S I OIL-BBL. GAS-MCF. WATER-BBL. JGAS-OIL RATIO I35'923'7 I 17,708.5 I '- I 493 GAS--MCF. ~.- WATER-BBL, lOlL GRAVITY-APl (CORR,) I 776 [ ~ ~ t~ r_ ~l ~w~- r~6.00 API Drillinq - Perforating History 33. I hereby certify that the.~oregoing,~pd atta~IT~d information is cop3plete and correct as determined from all avail,;~t~l~;l~,c~r{~] ~t GmS Cons , *(See instructions and Spaces for Additional Data on Reverse Side) 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: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28' Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD !. 35. GEOLOGIC MARKERS , NAME MEAS. DEPTH TRUE VERT. DEPT · . ' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. , · · · · DRILLING - PERFORATING HISTORY~~,,,. ~1~. ~ 25647 No. ~ ~~ API 50-029-20313, ADL 25647, PERMIT NO. 78-40 Spudded well @ .0700 hrs 7/22/78. Drld to 2260'. Ran DIL/SP/GR, BHCS/GR/CAL logs. Ran 10-3/4" 45.5# K-55 csg set @ 2244'. Cmtd w/2400 sx Permafrost cmt. Drld float shoe & 10' new hole.. Tstd form to 12.0 ppg equiv. Drld to 6002'. PU core bbl Core #1, 6002-6088' · . , rec 86' 6088-6119' ' ' , core #2, , rec 31 ; core #3, 6119-6209' ' ' ~ ' 6244-6333' ' , rec 87 , core ~4, 6209-6244', rec 36 ; core #5, , rec 86 . LD core bbl. Drld to 6382'. Ran DIL/SP/GR, Sonic/GR, microlog, FDC/CNL/GR/CAL logs. Took velocity sur. Ran dipmeter. Took sidewall cores. RU & ran 7" csg w/shoe @ 6364'. Cmtd w/609 sx Class G cmt. Opened lower FO. Pumped 396 bbls clean wtr followed by 20 bbls 2% caustic wtr. Cmtd w/300 sx Permafrost' cmt, 14.8 ppg slurry. Disp1 w/9 bbls wtr & 5 bbls cmt in HW DP. Closed lower FO. Did Arctic Pack job thru upper FO. Disp! mud w/lO.6 CaCle wtr. Ran CBL/VDL/GR & CCL logs. Ran 3-1/2" tbg w/pkr @ 6145 . Perf'd 6233-6259' & 6217-6227' w/4 shots/ft. Flowed on 1/2" choke. SI well. Ran HP pres recorder. Pulled tbg. Set BP @ 6168'. RIH w/3-1/2" tb§ w/pkr @ 5891' Perf'd 6073-6084', 6050-6055', 6041-6046', 6025-6037' w/4 shots/ft. FloWed on 1/2" choke, 160 psi surf pres 1390 bbl/day. Flowed well on 64/64 choke @ 211 psi pres, 964 bbl/day. Ran bot hole pres sur. -Reperf'd 6050-6055', 6041-6046' & 6073-6084'. Unable to shut well in. Killed well. Displ CaC12 wtr w/diesel Reperf'd 6073-6084', 6050-6055', 6041-6046' w/2 shots/ft. PerfTd 6013-6037' ~ 6001-6013' w/4 shots/ft. Ran HP & Amerada pres. gauges. Flowed well on 1" choke. Surf flowing pres 257 psi, 1119 bbl/day. SI well for pres reCording. Drld BP. Ran junk bskt & gauge ring. Ran 3-1/2" tbg w/wireline guide @ 5926', FB-1 pkr @ 5887'. Installed tree. _Pulled dummy gas lift valve. Displ CaC12 w/diesel. Reran dummy gas lift valve. Flowed well for clean up. Flowed on 64/64 choke w/pres 220 psi, 1092 bbl/day. SI well. Set SSSV & BPV in tree. Released ri9 @ 0600 hrs @/30/78. January 4, 197 9. Atlantic Richfield Company North American Producing Division Post Office Box 360 Anchorage, Alaska 99510 Attention' Thomas L. Holland General Landman Reference' LO/NS 78-149 (78-36) LO/NS 78-150 (78-36) Gen tl emen' Thank you for your letters of October 19, 1978 and November l, 1978. The lease operations to conduct production tests including the burning of 25,000 barrels of oil as outlined in your letter dated October 19, 1978 has been reviewed along with the request for the expansion of the flare pit contained in your letter dated November l, 1978. Both are approved subject to the following stipulations' 1. Gas must be flared while conducting the production tests. 2. A completion report must be submitted within 15 days upon termination of permit activities. This report shall contain the following information. Ae Be Actual routes of travel and actual location of all camps depicted on a USGS topo map. List the vehicles used for any off-road travel that may have taken place. Ce All additions to original application. 10-J3LH De E. Statement of clean up activities. Time Spent in each campsite. F. Methods of disposal Ethel H. Nelson Leasing Manager of garbage and other camp debris. ,, hfieldCompany North Amer~ Producing Division North Ala/- *istrict Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 11, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' West Sak 25647 No. 12 Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report detail- ing the work done on the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV-cs Enclosures Form ~3-403 REV. ~.-'~t)-~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L [7-1 GAS !--'1 WELLL~-I WELL L--.J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 311'E of 589'N of SW cr. Sec. 5, TllN, RIOE 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 1 08' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Rel 5. APl NUMERICAL CODE 50-029-2031 3 6. LEASE DESIGNATION AND SERIAL NO. ADL 25647 7. IF INDIAN, ALI..O¥¥EE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME West Sak 25647 9. WELL NO. 12 10. FIELD AND POOL, OR WILDCAT Kaparuk River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, TllN, RIOE 12. PERMIT NO. 78-40 =orr, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ~ ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING I I ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Production ~ (Other) (NOTE~ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent ~letllll, and give pertinent dates, Including estimated date of starting any proposed work. Began rigging up for production test, 11/9/78. RU surface equip. Tstd equip. RU & tstd lubricator. Perf'd 6233' - 6259' & 6217' - 6227' w/4 shots per ft. Flowed well. Ran HP & Sperry Sun press bombs. Cont flowing well. Ran flow meter ,& FDL. Ran press re- corders. Began flowing & tstg well on 11/21/78. Test continued thru 12/20/78. Ran bottomhole press buildup survey. Ran & set SSSV. Released well @ 0600 hrs 12/21/78. 16. I hereby certify t_hat the fore. going is true and correct SIGNED _ . ~--- TITLE District Drilling Enqinee. rmATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side Form No. 10-404 REV. 3-1 .?,.0 SUBMIT tN DUPLICATE STAT'-. F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O.F DRILLING AND WORKOVER OPERATIONS WELL WELL 2. NAME OF OPERATOR Atlantic Richfield Company OTItER 3'. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 311'E & 589'N of SW cr Sec. 5, Tl~lN, RiOE' APl NUMERICAL CODE 50-029-20313 6. LEASE DESIGNATION AND SERIAL NO. ADL 25647 7. IF INDIAN-ALOTFEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Kupar, uk River 11"SEC. T. R. M. {BOTTOM HOLE OBJECTIVE) Sec. 5 Tl lN, RtOE 12. PERMIT NO. 78-40 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of November, 1978 Began rigging up for production tst~ 11/9/78. RU surface equip. Tstd equip. RU & tstd lubricator. Perf'd 6233' - 6259' & 6217' - 6227' w/4 shots per ft. Flowed well. Ran HP & Sperry Sun press bombs. Cont flowing well. Ran flow meter & FDL. Ran press recorders. As of November 30, cont to flow & tst well. I NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the · oil and gas conservation committee by the 15th of the succeeding month,unl~ otherwise directed. of ALASKA TO: F Hoyle H. Hamilton Div. of Oil ~ Gas FROM: Pete Nelson DMEM DATE: November 6, 1978 FILE NO: TELEPHONE NO: SUBJECT: Enclosed is a copy of the referenced lease operations as presented b3 Sohio. Please review and send us your comments. If we have not heard from you by November 20, 1978, we will assume that you have no objections and proceed with our approval. LO/NS 78-153 (78-131) Snow Road ~ & Exploratory W. Sak #4 ' CC,;,?'.~: J FtL.,:: (~/J D.O.G.C. No, tuber 6, 1978 LO/NS 78-149 (78-36) AtlanticRichfieldCompany North Ameri~an Producing Division Alaska Re~ '~ , Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 30, 1978 Mr. Holye H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 · .. .. ._~-"C'. [ ~,:c .... I ', i .... ~ I~ y' ............ ~~,~8, I ..... '-3"~',~.~.~ ~ It l~ ] ......~;. ~.~ .1,~ ..~ ...... .. '.'~ C,/':'~ ....... REV "[ ..... SEC CO~FE'R~ --~.; ....... Subject: West Sak River 25647 No. 12 Permit No. 78-40 Dear Sir: Enclosed please find a Sundry Notice outlining our' plans for the above-menti oned wel 1. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:3h Enclosure Form 10-403 RE~. 1-10-73 SubmI t "1 ntentlon$" in Triplicate & "Subsequent Reports" In Duplicate ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O1L F~ GAS F"l WELLm ~ m WELL OTHER z NA~E OF OP'ERAT6R Atlantic Richfield Company 3. ADDRESS oF OPERATOR ?. O. BOx 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 311'E & 589'N of SW cr Sec. 5, T11N, R10E 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 108' RKB Check Appropriate Box To. Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20313 6. LEASE DESIGNATION AND SERIAL NO. ADL 25647 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 0. UNIT, FARM OR LEASE NAME West Sak 25647 9. WELL NO. 1·2 10. FIELD AND POOL, OR WILDCAT Kuoaruk Ri vet 11. BEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T11N, R10E 12. PERMIT NO. 78-40 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT sHOOT OR ACIDIZE REPAIR WELL (other) Production PULL OR ALTER CASING MULTIPLE COM PL~EI' E ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SHOOTING OR ACIDIZING .ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. ·DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of .. starting any proposed work. Atlantic Richfield Company proposes to conduct a continuous three week production test on West Sak 25647 No. 12. The purpose, of the test is to prove reservoir production rates for Kuparuk development and gain more definite relative permeability data as well as define potential.well bore waxing. The well will be flowed through a heater and separator with disposal of produced well fluids by a Noralco burner. Open pit burning will be a back-up method if equipment malfunctions are encountered. Estimated start date' 11/13/78. (This space for State office use) CONDITIONS C~ J:k~:U~ROVAL, IF ANY:' . TITLE T IT LE District Drilling Engineer See Instructions On Reverse Side 10/30/78 DATE · , Approved Copy. R~i'urned 02-00tB iR~v. 10/761 ,~ATE 0,~ ALASKA TO: F~Hoyle Hamilton 0 & G Chris Guinn NCDO Scott Grundy F & G Doug Lowery DEC C. GEOL DATE: October 25, 1978 2 ENG F.E No: Lo/Ns 78- . (78-3 Amendmen¢ Nes¢ sak~ j ~ cs~o~ .... FROM: Pete Nelson DMEM (~0~ SUBJECT: 3 GEOL .... We11 - Arco 12- ........ ~V"-'-~-- Attached is a copy of ~ letter of request for an amendment to Atlantic Richfield's referenced Lease Operations. Please review these operations ~ ~. - and send us youn comments as soon as possible. If we have not heard from you by November 8, 1978, we will assume that you have no objections and proceed with the approval. o/ 0/7 ,:%~/ North A~.~.e~ric,""' Prodocing Division North A I,[ .;trict Post OffiCe Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 19, 1978 ..; 001'2 0 1978 Ms. Ethel H. Nelson Leasing Officer Div Division of Minerals & Energy Managem~n~~ime~a~s & State of Alaska Anchorage, Ak, 323 East 4th Avenue Anchorage, AK 99501 Re: LO/NS #78-36 West Sak 12 Well North Slope, Alaska Dear "Pete": In accordance with our recent telephone conversation, this letter constitutes Atlantic Richfield Company's request for an amendment to the captioned Lease Operations Permit to conduct production tests, to determine reservoir performance of the Kuparuk ~ormation. The tests will be conducted over a three-four week period beginning about November 6, 1978. The program calls for a total of 25,000.barrels of crude oil to be produced into a test separator. From the separator, the oil will be placed in storage tanks, then burned with a Norelco burner (our environmental conservation department is applying separately for an open-burn permit). Since the Brinkerhoff Rig #59 infrastructure is still at the site, no new rig equipment will be needed. It is estimated that approximately eleven persons will be housed at the rig camp during testing. No new gravel or water is needed. Due to the short time period involved, we respectfully request your verbal approval of this permit by Nov~nber 2, 1978. If further information is needed, please advise. Very truly yours, ATLANTIC RICHFIELD COMPANY Thomas L. Holland · General Landman cc: Mr. William A. Copeland J. Scott Grundy Douglas L. Lowery tlanticRichfieldCompany North American Producing Division Alaska Distr~ Post Office ',x 360 Anchorage, Alaska 99501 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska Division of Oil and Gas Conservation 3001 Porcupine Dr. Anchorage Ak. 99501 · Attn: Tom Marshall WELL }I~2.4E: ARCo, W. Sak St #12 DATE:_. September 10, 1~7R .,L RECEIVED ",:F ¢ 2 ~'~)t978 Anc~or~g8 TYPE OF SAMPLES: dry ditch NIE,,fBER OF BOXES: four S~M3PLES SENTI 100 - 1630 1630 2920 2950 - 4390 4390 - 6382 "SHI~T INIATED BY: \ REPRES~TATIVE: WHEN YOU HAVE RECEIVED THESE SAMPLES.~ PLEASE ~0TE ANY DISCREPANCIES AND }4AIL THIS FORM TO: Atlantic Richfield Co. P. O. Box 360 Anchorage: Alaska 99510 Attn- R. L..]~rooks TITLE: Palco. Aide - ~ AttanticRichfieldCompany North American Producing Division Alaska Region Post Offi~ox 360 Anchorage, Alaska 99,510 Telephone 907 277 5637 ST~MPLB TRANSbII TT:-UL SHIPPED TO: State of Alaska Division of Oil and Gas Conservation 3001 Porcupine Dr. Anchorage, Alaska 99501. Attn: Tom Marshall DATE' Sept. 29, 1978 OPERATOR- ARCo N~\'~: SAMPLE TYPE: SAMPLES SEaNT: core chip~ Box #1' core 1 & 2 2' Core 3 & 4 3: core 5 W. Sak #1-2 NUMBER OF BOXES: 3 RECEIVED c F ? gci 1978 DiviSion ef Oil & G~s Ooi~servatie, Anch0r~ee SHIPPED BY: UPON RECEIPT OF THESE SAMPLES PLEASE NOTE .~'~Y DISCREPANCIES AND MAIL A SIGNED ~/COPY OF THIS FOPCI'TO' ATLFdNTIC RICHFIELD CO. P. O. BOX 360 Anchorage, Alaska 99510 Attn- R. L. Brooks DATE Atlantic' Richfield Compz North Alaska I)istrict T P~A~,~ S..'-[ ITT AL State Of Alaska Division of Oil and Gas Conservation 3001 Porcupine Drive To: Anchorage, Alaska From: Date: September 29, 1978 __ Transmitted herewith are the follo~.ling: West Sak River State # 12 Field Prints, 1 blueline and 1 sepia each. Dual Induction Laterlog Borehole Compensated Sonic Log Compensated Neutron Formation Density Log · Proximity Log Microlog Continuous Dipmeter Log Borehole Geometry Log Mud Log (100-6382 ft.) R.A.McIntosh/North Geological 2", 5" Run 1,2 ~',5''/ Run 1,2 ~'5" Run 1 ~" Run 1 ~' Run 1 ~" Run 1 ~'2 ' ' ..... RECEIVED t978 Oil & Gas .Anchorage Receipt ackno~ledge: '~P, eturn receipt to: Atlantic Richfield Company North Alaska District ~.,.~~-~' Attn'DistrictGeologist P.O. Box 360 Anchorage, Alaska 99510 Date: ~27 o .. · ! · . 4'-,6 EXHIBIT #2 - LOCATION PLAT AtlanticRichfieldCompany North Amer~.an Producing Division Alaska Post Office aox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 18, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: West Sak River State 25647 No. 12 Dear Sir: Enclosed please find a Completion Report along with the Drilling History for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer FMB: j h Attachments ~ .> SUBMIT IN D. ~'CATE* STATE OF ALASKA ~' {'See other st ructions on OIL AND GAS CONSERVATION COMMITTEE reverse side~ I.[ i i i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* W ELI. W ELL R ~ Other TYPE OF COMPLE~ON: w E i, L OV E ~ ~ X n.~C K n~sv ~. Other ~ 2. NAME OF OPERATOR Atlantic Richfield Company 3.ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOC~,T[ON or wELL'(Report location clearly and in accordance with any State requiremet~ts)* At surface 311'E & 589'N of SW cr Sec. 5, TllN, RIOE At top prod. interval reported below ~to't~ ~d}89'N of SW cr Sec. 5, TllN, RiOE 311'E & 589'N of SW cr Sec. 5, T11N, RIOE 13. DA. TE SPUDDED J li.' DA:T'tl T.D. RF-.A. Ci-I~D.[15. DATE.CO,Mr I;USp O1~. Al/AN]). ]1~.' 7/22/78 8/4./.78 J 8/30/78 I API NLrM. E, KICA.L CODE 50-029-20313 ~'?LF-~E DES~N~k~O~' .~V SEAM,. ~o. ADL 25647 7. IF IND1A2/, A.LLOT~EE OR TRIBE NA1V/~ 8. UNIT,FA.R/VI OR LF~%SE NAME hlc3t ~ ....... .~ 9. WELL NO. i0. FZEL~ A~n~POOL, O~ WmDC~,T Kuparuk River I{OW iVI2kNY* ROTARY TOOLS 6382'MD & TVD ~6315'MD & TVD Single 22.PRODUCING !N'rEHVAL(S), OF THIS COM~T£ON--TO,P, BOTTOM, NAME (MD AND TVD)- Top Kuparuk Sand 6000'MD & TVD Base Kuparuk Sand .~62i5'MD & TVD 24. TY-PE ELECTRIC AND OTHER LOGS RUN I1. SEC., T., R,, M,, (BOTTOM HOLE OBJECTIVE) Sec. 5, TllN, RiOE 12, PEHAIIT N'O. 78-40 ELEVATIONS /DF, RKB. t~'1~, GR, ETC)*]IT. EI.,EV. CASINGHEAD 108' RKB (EST) ~l .... INTERVALS DR/I, LED BY l' ' CABI,E TOOI.,8 23. WAS D!RECTION,kL ! t SURVEY MADE i, DIL/SP/GR, BHCS/GR/CAL,_ Microlog, FDC/CNL/GR/CAL, Dipmeter, CBL/VDL/GR _ i i ii · CASING RECORD (Report all strings set in well) 16" IH-40 t J 24,,' i 250 sx Arctic em i0-3/4" 45.5# !K-55 I 2244' i3~;3/4' 2400 sx Permafrost cmt 26# i I K'Z. 55 ! 6364' 9-7/8," 609 sx Class G cmt II I 3-1/2" 5926' §887' . 11 26. f i i ~ i iii i 28. PERFOR. AT~ONS OPF=2N TO PRODU~'~IOlq (interVal size and number) 6233' 6259' ,.,. : ':~' 29. SIZE DEPTH SEX' (MD) ~ PACKER SET (MD) ! iff i i i ACID, S~:OT, ~';'{AC'I'URE, C~;IENT SQUEEZe, ETC. o37 D:~z 1N2'ERVAL (MD) 6217' - 6227' 6013' - 6 ' 6073' - 6084', 6001'- 6013' 6050' - 6055' 6041' - 6046' 30. I~I%ODUCTIObl DATE FIRST PI-IOi-)UCTION [ ~ODUCT1ON MEI.[iOD (FlowiDg, gas lift, pumping--size and type of pump) ~%~(~TUS (Producing or A , / OI~EDL. Gz%~CF. ~VATE~BBL. J G>kS-OIL I I i D~.TZ o~' TruST. JlCOURS TESTD 'JcI~IOXE SIZE JPP. OD'N FO,3. FLOW, TU,BING ICASJ~'G PRESSURE JcALc~¥D OILB~L. GAS--~VICF. 1. WZL~BBL, J OIL GRAVITY-A.PI (COR3:L) ],. tTEIgT WITNESSED BY 32. LIST OF ATTACHMENTS . Drilling HistorY~ 33.'I herebY' certlf that the foregoing an attached information is complete and correct as determined from all-available records *(See InstructiOns and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interwa! reported in item 30. Submit a separate report (page) on this form, adequately identified, for each addition~al interval to be seperately produce~, show- ing .the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the locatiOn of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMM'~R¥ OF' FORMATION T,~.~'I'S IN('I,UI)'IN'(; 'INTE~v'AL 'rr..S'rEn. i;i~s.s'tJrtE DAa-A ~ "~u~covb~Ir.s. o~' oiL',' OAS, WATEll AND MUD I I I I I ........ . ~fl. C~ILE DATA, A'I'I'ACI[ HRIE~ D~IP~ONS O~ LITtlOLOGY, POEO~Y, FHA~R~, APP~ ~ II I I I i i · iii i ii ii I II I I DRILLING HISTORY WEST SAK 25647 No. 12 API 50-029-20313, ADL 25647, PERMIT NO. 78-40 Spudded well @ 0700 hrs 7/22/78, Drld to 2260'. Ran DIL/SP/GR, BHCS/GR/CAL logs. Ran 10-3/4" 45.5# K-55 csg set @ 2244'. Cmtd w/2400 sx Permafrost cmt. Drld float shoe & 10' new hole. Tstd form to 12.0 ppg equiv. Drld to 6002'. PU core bbl. Core #1, 6002-6088', rec 86'; core #2, 6088-6119', rec 31'; core #3, 6119-6209', rec 87'; core #4, 6209-6244', rec 36'; core #5, 6244-6333', rec 86'. LD core bbl. Drld to 6382'. Ran DIL/SP/GR, Sonic/GR, microlog, FDC/CNL/GR/CAL logs. Took velocity sur. Ran dipmeter. Took sidewall cores. RU & ran 7" csg W/shoe @ 6364'. Cmtd w/609 sx Class G cmt. Opened lower FO. Pumped 396 bbls clean wtr followed by 20 bbls 2% caustic wtr. Cmtd w/300 sx Permafrost cmt, 14.8 ppg slurry. DisPl w/9 bbls wtr & 5 bbls cmt in HW DP. Closed lower FO. Did Arctic Pack job thru upper FO. Disp} mud w/lO.6 CaCI? wtr. Ran CBL/,VDL/GR & CCL logs. Ran 3-1/2" tbg w/pkr @ 6145 . Perf'd 6233-6259' & 6217-6227 w/4 shots/ft. E_lowed on 1/2" choke. SI well. Ran HP pres recorder. Pulled tbg. Set BP @ 6168' RIH w/3-1/2" tbg w/pkr @ 5891'. Perf'd ,6,073-6084' 6050-6055', 6041-604~', 6025-6037' w/4 shots/ft. .F~lowed on 1/2 choke, 1~0 psi ~390 bbl/da~. Flowed well on 64/64 choke @ 211 ~si pres, 964 bbl/d~. Ran bot hole pres sur. Reperf'd 6050-6055', 6041-6046' & 6073-6084';~. Un-able to shut well in. Killed well. Displ CaC12 wtr w/diesel Reperf'd 6073-6084', 6050-6055', 6041-6046' w/2 shots/ft. Perf*d 6013-6037' ~ 6001-6013' w/4 shots/ft. Ran HP & Amerada pres gauges. Flowed well on 1" choke. Surf flowing pres 257 psi, 111_9 bb!/das. SI well for pres recordi~ng. Drld BP. Ran junk bskt & gauge ring. Ran 3-1/2" tbg w/wireline guide @ 5926', FB-1 pkr @ 5887'. Installed tree. Pulled dummy gas lift valve. Displ CaCl2 w/diesel. Reran dummy gas lift valve. Flowed well for clean up. Flowed on 64?64 choke w/pres 220 psi, 1092 bbl/day. SI well. Set SSSV & BPV in tree. Released rig @ 0600 hrs 9/30/78. · _ .. Atlant~cRichfieldCompany North American Producing Division North Alasl~, istrict Post Office-._Jx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: West Sak 25647 No. 12 Permit No. 7840 Dear Sir: Enclosed please find a Monthly Report of Operations for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer FMB: lr Enclosure I DIR RECEIVED AUG 1 6 197'8 Division of Oil 8ncJ Gas C0nserva~i0n No. Il- 1-70 STATE Or ALASKA SUBMIT I/¢ DL~LICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS WI~LI, 2. NAME OF OP~P..ATOR Atlantic Richfield Company i ~'~S b~ b~m~ro~ ..... P. O. Box 360, Anchorage, Alaska 99510 4. LOC~ON OF W~_t,L 311'E & 589'N of SW cr Sec. 5, TllN, RIOE 50-029-20313 6 LEASE DESIGbIATION AXD SEI~IAL NO. ADL 25647 ? IF INDIA~, ALO~ ~Eh OR TRIBE NAME 8, L~."IT FAP,~ OR LEASE NAME West Sak 25647 ~ WELL' NO ........ 12 10. Fi~L~ A_ND POOL. OH WILDCAT Kuparuk River Pool -n. s~c., T., R., ~i,. (,om'o~ ~6E& .......... Sec, 5, IllN, R10E, I~. PEP,/VIIT NO. 78-40, "13. RF.~(D~ TOTA'L DE~TH kT"~/~D OF MONTH, CHA~NGF. S IN HOLE SIZE, CASING A~ C~NG JOBS INCLL'~i~G' 'DEP~ SET ~ VOL~ USED. P~O~TIONS. ~TS ~ ~SULTS ~ISHING JO~. J~g ~ HO~ ~D $1DE-~C~ED HOLE ~D ~Y O~a SIGNIFIC~T ~G~ m aO~ m~ITIO~S- Report of Operations for the Month of J.u.ly, 1978 Spudded well @ 0700 hrs 7/22/'78 Drld to 2260' Ran DIL/SP/GR, BHCS/GR/CAL logs. Ran 10-3/4" 45.5# K-55 csg set @ '2244'. Cmtd w/2406 sx Permafrost cmt. Drld float shoe & 10' new hole': Tstd form to 12.0 ppg equiv. Drld to 6002'. As of July 31, PU core bbl. Core #1, 6002' -6088', rec 86'. RECEIVED AU6 1 6 1978 Division of Oil and Gas G~}ns(;~vatiOI1 Ai'~Chotag'~ .m~.~~::~('.:~,,~~,"~"'~'?~~ District Drill, lng Engine~L~ Il I I Il Ill" I I I ' I Jl Jl I I I I I I I Il ,Or~--,..o,, o. t,i.,o,, i. ,.,.,,.d ,o, ...~ ~.,..da, ~.t~,'...rd,..' ;' ,,..,.t., ~, o,.,0.~.,, .,d j;t"~%,.d ,, d.,,=,..~,, oil omd gas conservat~n commiflee by the 15~ of the suoc~ding mn~, ~le~ otherwise directed. AtlanficRichfieldCompany North Amer~.a.,Producing Division North Alask =~ ~rict Post Office box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 15, 1978. Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- West Sak River State 25647 No. 12 Dear Si r' Enclosed please find three copies of the As Built survey for the above-mentioned wel 1. Very truly yours, K. K. Lenz Engineering Associate KKL'jh Enclosures R F:. C [~[\/E D JUI~ 1 9 1978 Anchora:rje Protracted Section Corner Y: 5 970 085.88 X: 539 87'6 .i6 LAT, TO© I 9'45.1 TO" N LONG. 149°40'35.TI 3"W ! 6 5 7 8 ! 311 I I I! 11 ~ WEST SAK No. 12 i ¥: 5 9?0 676.85 i I × = 540 181.5 I - J LAT. 7'0© I 9' 50.967" N LONG. 149© 40'26.705"W E LEV. 68.4 Pr o t r a c[e_ d_ _'__s e ?..! o__n___L_j_n~_ ..... ~ ....................... N 89°40' 51" E 5279.49 819 0o!8' 25._! NOTES I. VERTICAL CONTROL BASED ON BRITISH PETROLEUM M,S.L DATUM 2. CONDUCTOR ELEVATION IS TOP OF CONDUCTOR. ;5. ALL BEARINGS AND DISTANCES ALASKA STATE PLANE ZONE4. : *-~. :'-i: ~.,~., . ...: r. f,....-- .'~M ,:'.~'-~PFR['r. . .REG 5TERED Arq- ,H~ STATE OF A.~A ,~,F-q~; '.~4T ~H~S PL. AF REPRESENTS A LOCATION " , ~ ~ .. (", -~it ," ;},M[ ~;~.' '~:, Af;F ?T~iEP DE TAILS ~E CORRECT AR",":N¢ 393665 - ~Hv; N~-~KUP-14-SAKIZASB-78: ATLANTIC RICHFIELD CO. WEST SAK No. 12: LOCATED tN SW I/4 OF PREP&RED BY HEWiTT v LOUNSBURY t.~ ASSC,C ?~'" w ¢-,tr, AVE,, ANCH()fl~AGE,A',_ A~KA CHKD, BY PC ! rL D. 8K,, 78-120 Conservatic~ ~y 11, 1978 WeSt Sak 25647 %12 Atlantic Richfield .Permit No. 78-40 F. M. B~ District Drilling Eng~ Atlantic Richfield ~ P. O. Box 36'0 An~., Al~ 99510 Dear Sir: .F~clo~d is the. approved application for peri, it %o drill the .above referenced, well at a locatic~ in Section. 5, Township I1N, R~nge 10E, U.M. well sarape, core., ch~, and a mud :log are required. A d/rectional s~ .is not re, red. ~any ri%~ars in Alaska and their dra~ systems, l~a~e been .classified as i~t for the spawning or x..~.ation of anadrczx~s fish. OFmrations in these ~ are subject to ~ 16.50.870 and the regulations promulgated the~~ (Title 5, Ala~a ~strattve ex~). Prior to ~ing ope~t~ ~ maybe contactsd by the ~mbitat Ooor~ator's office., De~t of Fish and Game. Pollution of any waters of the. State is prd%~ited by ~ .46, Chap~ 03, Article ~7 and the. regulations ~gated there~ (Title 18, Alaska ~istrative ~., 70') ~ by ~ ~al Water Pollution Control Act., as .~1, Prior' to ~cing operations ~ may be contacted by a 'repz~entative of the De~t of Envir~tal Con~tic~. Pursuant to ~. 3.8.40, Local i~e. Under State Leases, the Alaska De~t of Labor is being notified of ~ is.~mm~e of this ~t to drill. notified so. that a repz~sentative of the Divis~ maybe present ~ wi~ss testing of blowout preventer equi~nt before surface, casing shoe. is drilled.. F. Mo Brown -2- W. Sak %12 M~y 11, 1978 In the event of suspensic~ ~r ~t please give this office adequate advanoe notification so that we may have a witness .present. O. K. Gilbzeth, Jr. Chai~n Alaska Oil and Gas Cc~a~ervatic~ Ccm~t~ De~t of Fish and Game, Habitat ~%.=ction w/o e~cl. De~t of En~ta! C~n~~c~ w/o encl. De~t of Labor, Su~sor, Dabor Law ~l,i,~oe Division w/o encl. 'h.-- . :-,:::: .,:: ...... :.... . . ~ <:,, } ;1,, ' - .:_ ~y 20, .1978. . ~ - -::..~. . of. ~ ~ .'~ ~ ~~ ~~ ~y 1, 1978. - ..::/::::;:: .- :. . - :;... -.. :~ ...... · . . :-f:~ ~. ,~:fz -': <: "-: - :.'. ':'"' .- ' · ' ' . ' 7%~:i* ¢ 3:. ~:~ '- ' ,- : _-.::::?~}i' :.: . :-':18 ~ 75.080. · 6.-'~s~~r discd~~ ~ meet ~PA seco~S~y treatment standards ~--. consistire' ~ 30 m~/1 ~0D, 3O m~l ~ ~lids, a~ 20O fe~l oolifoxm~ per 10O mill~s. If the sewage treatment plant can meet these star, at,Is as the effluent leaves the plant, a ~e . ~ resources. 8.' All putrescible wastes ar~ sewage sledge shall be incited in an ~ unit. Wood, paper and ~rdtz~rd my be open-~ (no ite~ may be burned in a manner that will casse black smoke ~ssi~). residue frum the above refuse my be placed in a "false start" well hole, or if th/s is not possible, it may be buried in the pad.~r re- ..,.~.-::':.-;.:" '.': '"'--"--::.-:>~serve pit, ~r backhaulet to an a~ location. A minimuu of two (2) feet ~r ~ material sb~l~- be placed over this residue upon ~:'.~x~pletion of the operation.. Non-burnable items such as ~~. ~ ~lV ~ D MAY - 9 1978 O:vision of Oi! and 6as Conservati¢ May 4, 1978 ' ' i" . ~ "-.~. 9~.-,.If the reserve pit is within 100 feet of a fl~h stream o~. _water_ sup- AtlanticRichfieldCompany North Ameri~,~ Producing Division North Alaska' I~I '~trict Post Office B~'x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 17, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 SubjeCt· West Sak 25647 - No. 12 Dear Sir' Enclosed herewith is our Application for Permit to Drill West Sak 25647 - No. 12 and a $100.00 filing fee. An As-built survey will be sent as soon as it is available. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form 10-401 SUBMIT IN TRIPL,CATE REV. 1-1-71 (Other instructions on rever~ side). STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [~] b. TYPB OF WELL WELL []] OTHER 2. NAME OF OPERATOR Atlantic Richfield Company DEEPEN 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 ShNGLE~ MULTIPLE aPI No' 50-029-20313 6. LEASE DESIGN__~ON AND SERIAL 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME West Sak 25647 9. WELL NO. 12 10. FIELD AND POOL, OR WILD~AT Kuparuk River Il.SEC., T., R., M., (BOTTOM HOLE OBJECrlYE) At proposed ptod. zone ' D;vi$10n o{ 0it arid Gas Oon.,,,,v~uo' et,,,,," Section 5, TllN, RiOE Same as Above . · Anchor?~, m" 13. DISTANCE IN. MILF~ AND DI~0N FROM NEAREST TOWN OR POST OFFICE~ 12. Approx 30 miles from Deadhorse, Alaska 14. BOND INFORMATION: ~Statewide Oil & Gas Bond #8011-38-40 (Federal Insurance ~q~t $100 000 Surety and/or No. ' 15. DISTANCE FROM PROPOSED * LOCAI'ION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to neazest drig, uuit, ii* any) 4950' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, Fl'. 8000' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Not Surveyed approx 85' GL ,No. OF ACRES IN LEASE 2560 19. PROPOSED DEPTH 6500'TVD 17. ND.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START May 16, 1978 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE ,, SIZE O~ CASING ' ' WEIGHT ~ER FOOT GRADE { ' SETTING DEPTH ,Qua,ntity of cement ...... 32" 16" 65 H-40I ~5' GL '' Cmt to surf'- approx 350 ft3 ...... 13-3/4" 10-3/4'i' ' ' ' 45.5 K55 2200 Cmt.. t'o surf approx..!.8OO'ft'3' .. 7 ".. , 7" 9-/8 .. . 26. K55 1,7500' Cmt to surf. pipe.- approx.1400 fi '" .......... " i Arc. tic .Pack from 2000' .to surf I . · ... . ,, ,. :3 The Atlantic Richfield Company proposes to drill a Kuparuk River development well to approx; 6500'. Selected intervals will be logged, cored, and tested.. A 20" x 2000 psi annular diverter will be installed on 16" conductor while drilling surface hole as per Division of Oil and Gas requirements. A 13-5/8" x 5000 psi BOP stack consisting of one annular preventer, one blind preventer and two pipe ram preventers will be installed and tested on the wellhead for the remainder of the drilling and testing. The BOP stack will be tested to 3000 psi weekly during the course of the well. The well will be completed with 3-1/2" N-80 tubing. Non-freezing fluid will be left in any uncemented annuli thru the permafrost area. Perma- frost is estimated to be not below 1650 ft. A certified survey plat will be submitted before spudding. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: Il' proposal is to deepen give data on present productive zone and proposed n~w productive zone. If Proposal i~ to drill or deepen diroct~nally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer progr~n. (This space for State office use) s^~,PL~ A~D CORE cmos ~QU,RED I MUD ~ ~o[ m~,o~L su~v REo.m~o [] YES [~ NO D^~. April 11, 1978 CONDFFIONS OF APPROVAL, IF ANY: [] NO JO'IHER REQUIREMENTS: A.P.1. NUMERICAL CODE 50-029-20313 PERMIT NO. 78-40 APPROVAL DATE. *See Instruction On Reverse Side mLEDistrict Drilling Eng. CONFIDENTIAL DISTRIBUTED' DATE May 11, 1978 TO: STATE of ALASKA · · · ~Chris ~6k~inn, NCDO Scott Grundy, F & G Doug Lowery, D~C O. K. Gilbreth, Div. O & G FROM:Pete T~nd Manag~t Officer DATE: 4/3/78 FILE NO: TELEPHONE NO: SUBJECT: LO/NS 78-36 A~CO West Sak #12 Well Copies of the referenCed proposed lease operations have been sent direc you by AR~O. Please review and send. your_~~t__s _to,. me as so~~si Thank you. -- ~- - ' . I C~C;L "' *"OL 3 G~OL. ~ .... REV . .. DRAFT---/'--- APR 'l "- D;vl~ion of Oil and G~s CoR6e, rv~,don Anchomg¢ tAtl~fieldcompany North ,~rican'Producing North ~!1~,. District Post Offic .mx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 3, 1978 Divi81oll Ms, Ethel H. Nelson Land Management Officer' Division of Minerals and Energy Management State of Alaska 323 E. 4th Avenue Anchorage, Alaska 99501 Subject: LO/NS #78-36 West Sak #12 Well North Slope, Alaska Dear "Pete": Atlantic Richfield Company hereby requests a lease operations permit for our West Sak #12 well project, the particulars of which are set forth below: 1. Location: Common corner of Sections 5, 6, 7 and 8, TllN, R10E, Umiat Meridian. 2. State Lease: ADL-25647. 3. Timing: Projected spud date is May 20, 1978; preliminary pad construction should commence by May 5, 1978. Drilling is scheduled to be completed and the rig moved off-site by July 10, 1978. 4. Construction: The drill pad will be approximately 400' x 600' and will be 5' thick. A flare pit, 150' x 150' x 5', will be located 200' from the pad (see Exhibit #1). 5. Access: To access the drill site, construction of a gravel road is proposed, as shown on Exhibit #2. This road would be an extension of the existing all-weather road. Construc- tion would begin at the present terminus in Section 9, TllN, RiOE, Umiat Meridian, and extend westward along the high surface elevations to the proposed West Sak #12 Drill Site, located within TllN, R10E, Umiat Meridian. The roadway, as the Kuparuk Spine Road, will have a base width of 42 feet, and a crown width of 24 feet. Gravel will be compacted to a minimum of three feet from the crown to the base, and the sides will be sloped at 3:1. Exhibits #3.and #3a show a typical cross-section of the proposed road extension. This design minimizes the environmental effects of the project, and takes into account the projected long term uses of the road as the Kuparuk core area is developed. The proposed roadway extension crosses the Ugnuravik River. At this crossing, and wherever the placement of the road- way might disrupt natural surface drainage patterns, culverts will be installed. The type of culvert~..~__will be a corrugated metal type similar to that used for the l~r._~..~ ~d~ our West Sak #7 project (LO/NS #77-111). - .... ~' Ms. Ethel H. Nelson, Land Management Officer Division of Minerals and Energy Management State of Alaska page 2 March 31, 1978 6. Gravel: Construction of the road and pad will require approxi- mately 75,000 yd- of grave1. Gravel Site "B", located in Section 8, TllN, RllE, will be used as the source of this gravel. Since Gravel Site "BU is at its maximum economic depth, gravel will be taken from the back pit area. Th~s will require the removal of approximately 44,000 yd- of overburden. 'All stipulations contained in Gravel Site "B" approval will be complied with. Travel to and from the gravel source will be on existing roads. 7. Water: An estimated 1,500 barrels/day of water will be needed in support of drilling operations. Sources for this water are pothole lakes in Sections 7-16, and Section 18, TllN, R10E, U.M. 8. Drilling: Tentatively, Brinkerhoff Rig #59 is being assigned the drilling of this well., and will be moved to the site proposed herein over existing spine roads, gravel roads, and the road extension proposed herein. A fifty-man mobile camp will accompany the rig to the drill pad. A Neptune Microfloc PC-12 sewage treatment plant, designed for 100 people, and owned and operated by Brinkerhoff, will be used. The unit is rated at 8,000 gallons per day. A lagoon will be constructed at the pad to contain effluent discharge from the sewage unit. All putrescible wastes and sewage sludge will be incinerated. 9. Spill Prevention and Control: Drilling plans include measures for the control of any spills that may result from operations. Exhibit #~ addresses the main activities proposed to remedy any such occurrence, and a more specific, detailed plan has been prepared for use by drilling personnel. The Company Spill Prevention Control and Countermeasure Plan is used and will be available on-site during all drilling operations. We wish to proceed with development of this area as soon as practicable by spudding the well before breakup of the Kuparuk River. We realize this puts some time pressure on the State, and we stand ready to meet with you and such other agencies as are necessary to expedite our request. Therefor, your review and comment~~will be appreciated. Should you have any questions or ~formation in this importan~ matter, please advise. Very truly yours, ATLANTIC RICHF'IlgLD ~.O~,~NY Thomas L. Holland EXHIBIT f/4 GENERAL S PCC PLAN ~.'~ WEST SAK ~/12 Atlantic Richfield Company proposes to drill a Kuparuk exploratory well with a surface location at the common corner of Sections 5, 6, 7 and 8, of TllN, R10E, Umiat Meridian. A new 400' x 600' x 5' gravel pad Will be placed for the well. The object of the well is' to test and evaluate the Kuparuk River Sands. No gas cap is expected and minimum oil rate expected is 2000 BOPD. Spilla§e.Prevention The rig contracted to drill this well will be equipped with all standard biowou~ control equipment. As required by the Department of Natural Resources, Division of Oil and GaS Conservation, the blowout control, equipment is tested on a routine basis. The Atlantic Richfield Company on-site supervisor periodically discusses drilling., testing, and well control procedures with responsible Contract supervisors to insure all personnel are instructed in tripping practices and operations of blowout preventer systems. Blowout drills are scheduled weekly for each crew. Control and Countermeasure Spills from uncontrolled wells can be divided into two classes. Small spills can be directed to existing well site sumps; these sumps will accommodate 20,000 barrels. The oil trapped in the sumps would be trucked to existing burn areas or injection facilities. Should a large spill occur, a snow, ice, and/or gravel berm. could be built to the east. r The collection basins are sufficiently large to contain all flow until a relief well is drilled. .Adequate amounts of heavy equipment, vacuum trucks, and absorbent materials are currently available at Prudhoe Bay to clean up an oil~ spill, following containment. CROWN WIDTH 24' 4'2 ' BASE WIDTH AtlanticRichfieldCompany KUPARUK ROAD EXTENSI TYPICAL ROADWAY CROSS SECT EXHIBIT #3 - ROAD CROSS-SECTION I :qOTE' 31AMETER VARIES 2'-5' DEPENDING' ' END SECTIONS ' ' ~, ,' , · "' ' e, * 'l ~ ' ' * "' ' ' 'e , '' ~ · '*'ce ~ ' * I' "e ~l* .. ' ' __ _.. ~:~'.X_ ._..~.:' ~N-~'~'6~'C'~'~'~"'"" ~~~,~- "~-'~~,.N,UU~ o.~% ..-:,. ,~:,:'-~',.-.._ ,--~ ...... ~. · .. ~ ~]' . , ,,x~. ~;. ,... .:/LA.-'.-'.~/I, , . · .. o. · . 1' . KUPARUK ROAD E'XTENSIO · o . TYPICAL ROADWAY CROSS 8ECT~¢ WITH CULVERT PLACEMENT , . EXHIBIT #3a - ROAD CROSS-SECTION w/CULVERT INSTALLATION --- CHECK LIST FOR NE1q %~E.T,T, PERMITS Cc~npsn...v. Yes No Remarks 1. Is the permit fee attached ' . ................... ~ 2. Is well to be located in a defined pool .............. __ 2~ 3. Is a registered survey plat attached ................ 4. Is well located pr .oper distance from property line ......... 5~ Is well located proper distance from., other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... /~ ~ is well tobe deviated (~ ~' · · · · · · · · · · · · · · · · · · · · · · · 8. Is operator the only affect, ed party . ............... /jzgk,' 9. Can permit be hpproved before ten-day wait ............. //a)F 10. Do~s operator have a bond in force ................. fl~ 11. Is a conservation order needed ................... 12. Is administrative approval,needed ................. 13. Is conductor string provided · . ..... 14. Is enough cement used to circulate on conductor and surface .... /~' 15. Will cement tie in surface and intermediate or production strings . ~ill cenent cover all known productive horizons 17, Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst . 19. Does BOPE have sufficient pressure rating - Test to ~oo psig . /~ 20. Has DMEMapproved Plan of Operation ................ Additional Requirements: I rem A~pp~ove Da ! ~: -(1) Fee ~ K __,~/_ z/.~_2[ (2) Loc. /~K (3) Admin. /~o~ -'7-z/-7~ (4) Casg. Well Histo.ry 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. R ,EY' S ~ OUSTON TAPE 24-MAR- LENGTH: 132 BYTES REEL NAME: RDSM1935 COMMENTS: . . SERVICE NAME: DIGITS TAPE CONTINUATION NUMBER: ~ASHARE TAPE 'PREVIOUS FILE NAME: COUN: 0.00 STAT: 50.00 DATE: 78- 8- 5 RILEY'S DATASHARE (HOUSTON L.I.S. DATA FORMAT SPECIFICATION WELLSITE TAPE 24-MAR-S2 PAGE: 3 TYPE NAME SIZE REP ENTRY 66 DATUM SPECIFICATION BLOCKS: 2 SP MU 7 ! 0 ! 4 ! 68 3 ILM OHMN 7 12 44 1 4 ! 68 8 GR GAPI 60 31 0 ! 4 ! 68 9 DT US/F 60 5~ 32 ! 4 ! 68 RI DATASHARE iHOUSTON L WELLS~ TAPE 24-MAR-82 PAGE~ 4 .............................. DEPTH I-DEPT 2-SP 3-ILM 4-ILD 5-558 6-GR 7-DPHI 8-GR 9-DT 6100.000 6100.000 -26.100 7.853 7.044 10.333 75.120 11.844 68.660 89.600 6000.000 6000.000 -36.280 7.625 4.896 9.125 81.040 9.510 81.500 87.000 5500.O0O 5400.000 5500.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 5400,000 -999.000 -999,000 -999.000 -999.000 -999,000 -999.000 -999,000 '999°000 4900.000 4900.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 4800.000 4800.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 4300.000 4300.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 -999.000 4200.000 4200,000 -30.070 2.673 2.641 3.256 98.250 24.030 91.210 113.170 3700.000 '3700.000 -36.580 3.563 3.453 3.936 70.440 23.232 68.150 118.220 3600.000 3600.000 -37.600 4.315 4.129 3.593 74.170 26.358 70.680 118.700 FILE NAME: DIGITS,001 MAX RECORD LENGTH: 01024 BYTES NE XT.~...F~ I bE.--.-NAME: TAPE TRAILER: LENGTH: 132 BYTES TAPE NAME: 08747-01 DJ~.: ......~_SZOS/Q5 SERVICE NAME: DIGITs TAPE CONTINUATION NUMBER: NEXT .TAPE~ NAME: COMMENTS: SEPVI. CE NAME: DIGITS REEL CONTINUATION NUMBER:
