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196-154
STATE OF ALASKA y S Z7 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 14AY 1. Operations Performed `�fJ Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operation's owg ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Appr�� ❑ Plug for Rednll ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other: Set Retrievable Scab Liner/� ShulrHi Pool 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Straligraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 196-154 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 6. API Number: 50-029-22704-00-0D 7. Property Designation (Lease Number). ADL 028297 e. Well Name and Number: PBU P7-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. SAG RIVER (Undefined) 11. Present Well Condition Summary'. Burton, Kaity Contact Name: Burton, Kaity Authorized Title: Pad Engineer Total Depth: measured 13242 feet Plugs measured 12950 feet s23ft�hyq RBDMS.l�' MAY 3 1 201 fu mit Original Only We vesical 10054 feet Junk measured 13025,13147 feet Effective Depth: measured 12950 feet Packer measured 9985 feet true vertipl 9951 feet Packer true vertical 8282 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 35-115 35-115 3050 1500 Surface 4988 9-5/8" 34-5022 34-4933 6870 4760 Intermediate 11105 7" 31-11134 31-9186 7240 / 8160 5410/7020 Retrievable Liner 1113 2-7/8" 10000 - 11113 8292-9167 10570 11170 Liner 2215 4-1/2" 11027 -13242 9090-10054 8430 7500 Perforation Depth: Measured depth: 12740 - 13070 feet True vertical depth: 9874-9994 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CrB0 30-10031 30-8313 Packers and SSSV (type, measured and 4-12" Baker S-3 Perm Packer 9985 8282 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 392 28712 662 977 2084 Subsequent t0 operation: 0 0 0 0 0 14. Attachments:(reymred or 20 nnc 25.07025.011, a 25.2x1) 15. Well Clan after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ 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: 318-562 Authorized Name: Burton, Kaity Contact Name: Burton, Kaity Authorized Title: Pad Engineer Contact Email: Kaity.Burtonabp.com Authorized Signature: Date: 510 I I 1 Contact Phone: +1 907 564 5554 Form 10-404 Revised 042017��/ /� s23ft�hyq RBDMS.l�' MAY 3 1 201 fu mit Original Only Daily Report of Well Operations P1-09 ACTIVITYnATF SUMMARY ***WELL S/I ON ARRIVAL*** (Profile modification) RAN 3.70" CENT, 2-3/8" DOGLESS GS TO 4-1/2" EVO-TRIEVE AT 11,480' ELM (No psi change). 3/27/2019 ***JOB IN PROGRESS, CONTINUED ON 3/28/19 WSR*** T/110=2558/844/321 Temp= SI (LRS Unit 42 -Assist Slickline: Brush & Flush) Pumped 19 bbls 180* ds] followed by 90 bbls 180* crude down TBG for B & F for SSL. Pumped 100 bbls 180* down TBG while SL attempts to pull plug. 3/28/2019 ***WSR continued On 03-29-2019**** ***CONTINUED FROM 3/29/19 WSR*** (Profile modification) MOVED 4-1/2" HES EVO-TRIEVE FROM 11,466' TO 11,446' SLM (GR sheared). UNABLE TO PASS 5,702' SLM W/ 3.70" CENT, 2-3/8" DOGLESS GS (Asphaltenes). UNABLE TO PASS 6,000' SLM W/ 3.50" CENT, 2-3/8" DOGLESS GS (Asphaltenes). UNABLE TO PASS 6,018' SLM W/ 3.00" SAMPLE BAILER (Sample of asphaltenes). ABLE TO CLEAN UP RESTRICTION AT 6,000' SLM W/ 2.50" G -RING. DRIFT OUT TUBING TAIL TO 10,050' SLM W/ 4-1/2" BRUSH, 3.50" G -RING. LRS FLUSHED TUBING W/ 20 BBLS OF DIESEL & 80 BBLS OF CRUDE (180*). RAN 3.70" CENT, 2-3/8" DOGLESS GS TO EVO-TRIEVE AT 11,446' SLM (GS sheared). JAR FOR ONE HOUR ON 4-1/2" HES EVO-TRIEVE AT 11,446' SLM (2 hrs total). LRS PUMPED AN ADDITIONAL 100 BBLS OF HOT CRUDE WHILE JARRING. 3/28/2019 ***JOB IN PROGRESS, CONTINUED ON 3/29/19 WSR*** ***WSR Continued from 03-28-2019*** (LRS Unit 42 - Assist Slickline: Brush & Flush) Rig 3/29/2019 down from Psubs. SL on well upon departure. Cv's OTG FWHP=855/855/375 ***CONTINUED FROM 3/28/19 WSR*** (Profile modification) RIG DOWN .125" STAINLESS & SWAP TO .125" CARBON. ATTEMPT TO PULL 4-1/2" HES EVO-TRIEVE AT 11,446' SLM. JARRED FOR 3 HRS ON STAINLESS & 2 HRS ON CARBON (5 hrs total). JOB INCOMPLETE, UNIT W/.160" WIRE COMING TO TAKE OVER. 3/29/2019 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** ***FOUND WELL S/I ON ARRIVAL***(profile mod) RIG UP .160 SLICKLINE TO PULL 4-1/2" EVOTRIEVE W/ MEMORY GAUGES FROM 11,480' ELM 3/29/2019 ****CONT WSR ON 3-30-19**** ****CONT WSR FROM 3-29-19****(profile mod) ATTEMPTED TO PULL 4-1/2" EVOTRIEVE PLUG FROM 11,453' SLM (Jarred 2-1/2 hrs w/ .160" wire) RAN 2-1/4" PUMP BAILER W/ MULE SHOE BTM TO EVOTRIEVE (No recovery) ATTEMPTED TO PULL 4-1/2" EVOTRIEVE PLUG FROM 11,475' SLM (Jarred 1 hrs w/ .160" wire) RAN 2-1/4" PUMP BAILER W/ SNORKLE BTM TO EVOTRIEVE (No recovery) RAN 3.65" DECENT, 3.50" LIB TO 11,453' SLM (impression of evotrieve and junk around F Neck) CURRENTLY RIH W/ PDS 40 ARM CALIPER 3/30/2019 ****CONT WSR ON 3-31-19**** ****CONT WSR FROM 3-30-19****(profile mod) RUN PDS 40 ARM CALIPER FROM 11,450' SLM TO SURFACE (data good). RAN 13'x 2-5/8" STEM & 2-7/8" GR TO JAR DOWN AND MOVE EVO DOWN HOLE. CURRENTLY POOH W/ 4-1/2" EVO-TRIEVE AT MIDNIGHT. 3/31/2019 ****CONT WSR ON 4-1-19**** ****CONT WSR FROM 3-31-19****(profile mod) PULLED 4-1/2" EVO-TRIEVE FROM 11,484' SLM (Originally set at 11,480' ELM) 4/1/2019 ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** Daily Report of Well Operations P1-09 TWO = 780/790/500. Set 4" H TWC #427 @130" w/ Lubricator 839, Performed LTT on TWC (Pass). Converted Tree to WWP Configuration. PT'd against TWC 350/5000 PSI 4/2/2019 (Pass) Charted and Retained. RDMO. ***Job Complete***. FWPs = TWC/790/500. CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Standby while certification and documentation approved. ...Continued on WSR 4-8-19... 4/8/2019 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt ***Continued from WSR4-8-19*** Job Objective: AddPerf, Run liner patch Standby while certification and documentation approved. Replace components on well control stack. 4/9/2019 ...Continued on WSR 4-10-19... CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt ***Continued from 4-9-19*** Job Objective: AddPerf, Run liner patch Continued standby while replacing components on well control stack. Spot in coil unit, begin hooking up hydraulics 4/1012019 ...Continued to 4-11-19... CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt ***Continued from 4-10-19*** Job Objective: AddPerf, Run liner patch Continue Rig up CTU. Begin BOP test. Standby for weather. 4/11/2019 1 ...Job in Progress... CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Inspect equipment and return to work after weather. Begin BOP test. 4/13/2019 ...In Progress... CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Complete practice BOP test. Assemble safety joint. Standby for state rep to confirm if witness test is needed or waived. 4/14/2019 ***In progress*** CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Perform BOP test with state witness. Pull TWC. 4/15/2019 ...Job in Progress... TWO = TWC/800/250 Pulled TWC #427 through BOP stack of WWP w/ lubricator 68-840 4/16/2019 with 11' Extensions @ 130". RDMO ***Job Complete*** Daily Report of Well Operations P1-09 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Rig down valve shop after pulling TWC. Raise mast, stack lubricator up. MU HES memory logging tools/BOT drift bha for sump packer/plug and lower packer assembly. RIH and tag at -11720' CTMD. Obstruction believed to be residual cement sheath and dogleg, POOH. Make up milling/reaming BHA with 3.71" Turbo Scale mill and 3.71" string reamer, RIH. Grabby milling from -11720-11734'. 5 stalls total while attempting to mill. Frequent stalls/hung up when trying to back ream from -11,720 traveling back into the 7" casing at -11,332'. Needed to catch up on fluids and opted to pooh to inspect mill and string reamer. FP surface lines as well as a 5bbl 60/40 cap on the well. Continue pumping min rate with slick 1 %KCL w/safelube until 1000'. 4/16/2019 ***In progress*** CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Continue POOH from 1000' not pumping. Inspect mill/string reamer. Decent amount of wear on turbo scale mill and string reamer. String reamer had metal chunks stuck in fins. Removed turbu scale mill/string reamer. MU/RIH with 3.70" parabolic mill. RIH dry to 13033', Pump online down to 13100'. Backream from 13100 to top of liner -11000'. Unable to dry drift with multiple overpulls from 11600-11800'. POOH. Trim pipe, change pack -offs, chain insp. Make up Venturi with 3.70" mule shoe and RIH. Venturi from top of liner a couple times as well as dry drift from top of liner to 13100'. 10bbl 60/40 meth cap on well. POOH. 4/17/2019 ***In progress*** CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Continue Dry drift to 13100' with 3.70" venturi. Smooth dry drift however experienced more overpulls from 11715-11685. POOH with 3.70" venturi. Experienced chrome drag/reduced pulling speeds from 13100 up to -5000'. Venturi packed with sand and alot of metal debris. RIH w/venturi for round #2. Venturi goes to bottom at 13101 CTM without incident and then back out of the liner while pumping. RBIH for dry drift. Drifted down without any set downs, but then overpulled at 11700. Roll pump and able to continue out of hole. Repeat drydrift successfully. Pinhole coil, POOH. freeze protect well with 39bbI of 60/40. OOH with venturi and venturi is full of sand and a lot of metal debris. Blow down coil and begin rig down. 4/18/2019 **In progress** CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Rig back up. Pump 1.188" drift ball. Make up and RIH with memory GR/CCL carrier, BOT packer drift, and venturi BHA. Tagged at 11800. Became packed off around nozzle/momentarily detained. WHIP would not respond like normal while pumping down the coil. Got coil free by working pipe and dumping coil pressure. POOH with logging/venturi run to see what we picked up. Continued to venturi from 11800 to 10998' (top of 4.5" liner). 10bbl meth cap on well. Inspect venturi, Venturi full of metal debris, no sand. Keep in mind this venturi only went to 11,800'. Remove logging carrier/packer drift. Add 3' of barrel) to venturi junk basket. MU/RIH with 3.70" venturi junk basket. 4/20/2019 **In progress" Daily Report of Well Operations P1-09 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Continue in hole with 3.70" venturi. Venturi from 11000 to 13100 down/up with no issues. Dry drift from 11000' back to 13100. Had one set down at 12027' while dry drifting, 5k overpull. Venturi 50' above/below this point. No issues pooh from 13100 to 11000'. POOH to inspect venturi. OOH with venturi and have -2gts of solid steel chunks. Re -run venturi and did not set down while running venturi (pumping) going down or up in the liner. Shut down pump and dry drift to 13100. PUH to 11000. One modest over pull (4K) at 11868. OOH with that venturi and have a similar 2 qts of steel chunks. Re -run venturi. Venturi down/up from 11000 to 13100 with no issues. Dry drift from 11000 to 13100. One set down at 11040 (liner top?), smooth pickup. POOH, no other over pulls. FP coil and well with 42bbls 60/40. 4/21/2019 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch POOH. Weekly bop test. MU/RIH with 45KB packer drift+HES memory log BHA. RIH no issues from 11000' to 13100' at 45fpm. Log up to 12800' (paint flag). Log up to 9800'. ***In progress*** 4/22/2019 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Continue Log up from 12800' up to 9800' with HES memory log/45KB packer drift. +1' correction on log. Tied into SLB CNL 10-29-96. MU/RIH with 45KB Floo_ard Pr.Set middle element at 12990. Top of PKR at 12988.65'. Lay down setting tools and pick up first pert gun. Tag sump packer, correct depth, and perforate 12837.5-12870' with 2.75" Millenium, 6spf perf gun. Ran back in hole to confirm tag on the sump packer and it has moved down hole to 13012. Discuss with intervention engineer and the current plan forward is to continue perforating. Experience chrome drag most of the way pulling to surface. Winds >30mph when at surface. POP off at QTS to verified gun #1 fired then stab back on and stadby for wind to subside. 4/23/2019 ***In progress*.. CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Standby for wind to subside in order to un -deploy gun#1. Lay down spent gun#1. Cut 100' of pipe for chrome mgmt, chain insp/change packoffs. Makeup and RIH with 2.400" GR/CCL carrier and 3.0" DJN. Bullhead 135bbl of safelube. Tagged down at 13025CTMD. Packer began to move down. Log up to 9800. Paint falg at 12800. POOH. MU/RIH with HES gun#2 32.52' of 2.75" Millenium HMX 6spf. Perforate 12805-12837.5'. POOH. 10bbl meth cap on the well. 4/24/2019 *In progress*** Daily Report of Well Operations P1-09 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch POOH w/ spent gun#2. MU/RIH with HES gun#3 35.52' of 2.75" Millenium HMX 6sfp. Perforate 12772.5-12805. FP well with 10bb160/40. POOH. MU/RIH with HES gun#4 35.52' of 2.75" Millenium HMX 6sfp. Perforate 12740-12772.52. FP well with 10bb160/40. POOH. MU/RIH w/ Baker 4.5" CIBP. Tag top of liner @ 11027', unable to work through 4/25/2019 ***In progress*** CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Continued trying to enter liner w/ CIBP but unable too. POOH and install better bullnose on CIBP and set CIBP at 12950. Perform D1 drills with new day crew. Make up and RIH with 45KB packer drift and 2.4" G carrier. Log from 11400' up to 9800', paint WHITE FLAG @ 11100'. POOH, good data on log -8' correction. Perform D1 drills with night crew. Make up Baker lower packer assembly. 4/26/2019 1 ...In Progress... CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch Set lower KB packer at 11095.51. PUH 15' and circulate in 9.3ppg NaCl in a driller's method kill. POOH while pumping across the top. Well maintained .1 bpm losses throughout deployment. Deploy NS PTSA w/ retrievable seal guide and 1078.1' of 2-7/8" liner. Stab into seal bore @ 11121', verified w/ 2k overpull. Bring pump online down coil to release GH, PU and was -5000# lighter. POOH. Freeze protect well w/ 38 bbls 60/40 methanol. POOH 4/27/2019 CTU #9 with Wellwork Platform - 1.75" Coil, 0.156" wt Job Objective: AddPerf, Run liner patch RDMO 4/28/2019 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (Well work platform) RIG UP SWCP 4516 TO SET UPPER 45KB PACKER, PTSA @ 10,011' MD. 5/7/2019 ***JOB IN PROGRESS, CONTINUED ON 5/8/19 WSR*** T/1/0=0/90/320 Temp=Sl Assist SLine w/ MIT -T (WELLWORK PLATFORM) MIT -T to 2685 psi ***PASS*** Max Applied = 2750 psi Target = 2500 psi Pumped 9 bbls 60/40 meth down Tbg to take Tbg to 2732 psi. Tbg lost 33 psi in 1 st 15 mins and 14 psi in 2nd 15 ins for a loss of 47 psi in 30 min test. Bled Tbg to 300 psi and got 5/8/2019 back -4 bbls. Sline in control of well per LRS departure. FWHP's=300/87/320 ***CONTINUED FROM 5/7/19 WSR*** (Wellwork platform) RAN DUMMY 45KB PACKER, PTSA TO SEAL RECEPTACLE AT 10,003' SLM (No issues). SET 45KB PACKER W/ PTSA (RSG installed in 2.313" x -nipple) AT 10,000' MD. PULL 27/8" FNS FROM . LRS PERFORMED SUCCESSFUL MIT -T TO 2685 PSI. PULL 2-7/8" NS RSG (Metal shavings in body) FROM 11,088' SLM / 11,097' MD. RAN EQ. PRONG W/ TT SLEEVE TO 11,101' SLM (No marks & sleeve pin untouched). BAIL -1 QUART OF METAL SHAVINGS OFF 2-7/8" XX PLUG AT 11,111' MD. 5/8/2019***JOB IN PROGRESS, CONTINUED ON 5/9/19 WSR*** 5/8/2019 Suspension problems on way tojob. LRS Unit 42 takes over'ob Daily Report of Well Operations P1-09 ***CONTINUED FROM 5/8/19 WSR*** (Wellwork platform) BAIL -3 QUARTS OF METAL SHAVINGS FROM 2-7/8" XX PLUG AT 11,102' SLM EQUALIZE & PULL 2-7/8" XX PLUG FROM 11,102' SLM 5/9/2019 ***WELL S/I ON DEPARTURE*** T/1/0=0/100/250. Post Well work platform. Set 4" CIW "H" TWC plug #292 with CIW lubricator #840 @ 122", TWC LTT (PASSED) Reconfigured tree and RU SV torqued to API spects 886 FT/LBS. Pulled TWC # 292. PT'd tree cap to 500 psi. (PASSED) ***JOB 5/12/2019 COMPLETE***. See log for details. Final WHP's 0/100/250. TREE= CIW WELLHEAD = FMC ACTUATOR= BAKERC OKE. ELEV = 42.8' BF- R = 10580 -10630 KOP= 4000' Max Angle = 78" @ 11751' Data n MD = 10747' DaMnTVD= 8800'SS 80, ID = 8.681 • 5022- 7- CSG, 269, L-80 BUTT, .0383 bpf, ID = 6.276• -t Minimum ID = 2.313"@10011' 2-718" X NIPPLE PERFORATION SUMMARY REF LOG: SPERRY GR/CNL/LD ON 10/1456 ANGLE AT TOP PERF: 69'@ 12740' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-38' 6 10580 -10630 S 0520/04 02/17/08 3-38' 6 10650 - 10660 S 0511084 02/1788 2-78' 6 10680-10710 S 1220/13 12/28/17 2-78' 6 10760-10775 S 02rM12 1228/17 3-3/8' 6 10735-10785 S 0521/970187/12 48 3-38' 6 10795 - 10835 S 0983/02 0187/12 3-38" 6 10660 -10885 S 09/03/02 0187/12 3-3/8' 6 10900 - 10910 S 0982/02 0187/12 138' 6 10920 - 10980 S 05120/97 01/07/12 2-314' 6 12740 -12805 O 0425/19 2-3/4' 6 12805 - 12837 O 0424/19 2-3/4' 6 12837 - 12870 O 0423/19 2-12' 6 13020 - 13070 C 11/04/96 L-80 SR, .0058 bpf, D= 2.441' 11113' CRNSCC 0371 bof_ID=6.164' SAFETY NOTE: WELL ANGLE>70'@12707'. P1-09 TBG HNGR FMC @ 30' MD "•4-112" CHROME TBG & 7" CHROME CSG"` 2�3-5'--14-12" CAMOO GALA NIPPLE D = 3.812' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4053 4044 12 KBG2-LS DOME M 16 04/14/18 2 6280 5828 48 KBG2-LS DMY M 0 04/14/18 3 7771 6820 48 KBG2-LS DMY M 0 04/14/18 4 9882 8214 49 KBG2-LS DMY M 0 04/14/18 -� 9985' j -j7" X 412• BKR S-3 PKR ID = 3.875- 10000' 45 FLOGUARD PK R w/PTSA, 10008' 412'HESXNP,D=3.813' 10011'3.70'DEPLOYM84TSLV,D=3.00(427/19) �n� e_�n•wce ru ui"m=a vos- 10031' -j4-112-WLEG,ID=3.958- 10041' ELMD TT LOGGED 0511957 AFTER LARC 159 & EMC LNR HGR D=4.438" PUSHED DH FRUDHOE BAY UNIT WELL: PI -09 PERMIT No: 91961540 APINo: 50-029-22704-00 Sec. 16, T12N, R14E, 1438' FSL & 752' EEL DATE RE.V BY COMMENTS DATE REV BY OOMNIENTS 1185196 014 ORIGINAL COMPLETION 04/17/18 RCB/JMD GLV CIO (04/14118) 03/05/11 PJC DRAVW4C CORRECTIONS 0627/18 JL/JMD SET BIOTRIEV E w /MEMORY GANGES 01/08/12 RRV0 PJC P&A (01/07/12) 0482/19 CJWJMD PULLEDEVOTREVEw/GAUGES 09/12/17 GJB/JMD GLV CIO (09/03/17) 0529/19 EPIXIMD 3 TRP PATCH & ADPE RFS 01/05/18 JTMJMD MILLED CMT/SOZD PI3€S BP Bploration (Alaska) 0357/18 MS/JMD MILLED CMr & PK R DWSET FSH • • 19 61 54 WELL LOG TRANSMITTAL#904757898 29293 To: Alaska Oil and Gas Conservation Comm. June 4, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 JUN 0 8 2018 RE: Production Profile: P 1-09 Run Date: 4/13/2018 CL The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 P1-09 Digital Log file, Interpretation Report 1 CD Rom 50-029-22704-00 JUN 1.8 JB1 Production Profile (Final Field Print) 1 Color Log 50-029-22704-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 0 FRSANC@halliburton.com&AKGDMINTERNAL@bp.com Date: OP//3/P/P Signed: 1/_94, • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 15, 2018 1:59 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GPMA Field O&M TL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK,OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak,Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Burton, Kaity; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK,GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski,Carrie; Montgomery,Travis J; Munk,Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA);AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer P1-09 (PTD# 1961540)Well barriers restored with gas lift valve change out All, Producer P1-09(PTD#1961540)was made under evaluation on 3/18/18 for having sustained inner annulus casing pressure above NOL and failing a warm TIFL. On 4/14/2018 slickline completed a gas lift change out and the well passed a subsequent cold TIFL. The passing TIFL indicates that well barriers have successfully been restored. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCAN O From: GWO Well Integrity Engineer Sent: Sunday, ' - • 18, 2018 7:07 AM To: AK, OPS EOC Specia • 'K, OPS GPMA Field O&M TL; AK, OPS GPMA OSM; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; AK, OPS LPC D .; -ad; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES •: Wells Opt Engr; AKOpsProdEOCTL; Burton, Kaity; 'Regg,James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integn GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops •• • Rep; AKIMS App User; Cismoski, 1 • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION CO ION MAR 2 9 2018 REPORT OF SUNDRY WELL OPERtiR NS ts L 1. Operations Performed Abandon 0 Plug Perforations RI Fracture Stimulate ❑ Pull Tubing 0 Operation Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Cement Squeeze Perfs Elf 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 196-154 3. Address: P.O.Box 196612 Anchorage, Development Cd Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22704-00-00 7. Property Designation(Lease Number): ADL 028298 8. Well Name and Number: PTM P1-09 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 13242 feet Plugs measured None feet true vertical 10054 feet Junk measured 13147 feet Effective Depth: measured 13165 feet Packer measured 9985 feet true vertical 10028 feet Packer true vertical 8282 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35-115 35-115 3060 1500 Surface 4988 9-5/8" 34-5022 34-4933 6870 4760 Intermediate 11105 7" 31 -11136 31-9188 7240/8160 5410/7020 Production Liner 2215 4-1/2" 11027-13242 9090-10054 8430 7500 Perforation Depth: Measured depth: 13020-13070 feet True vertical depth: 9976-9994 feet SCANNED . '4 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 30-10031 30-8313 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 9985 8282 true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: QA9 Intervals treated(measured): ��D�; _��P� n 1, 1[1 Treatment descriptions including volumes used and final pressure: 7�"��pJ U 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 498 29262 1844 2387 2380 Subsequent to operation: 902 29952 444 2162 1964 14.Attachments:(required per 20 AAC 25 070.25 071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 2' Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Burton,Kaity Contact Name: Burton,Kaity Authorized Title: Pad Engineer Contact Email: Kaity.Burton@bp.com Authorized Signature: (- )7Th Date: 3/z-7AB Contact Phone: +1 907 564 5554 Form 10-404 Revised 04/2017 VrL 4L Z;� C/ Submit Original Ortly Pr—To ---Pr ar VR v?. ow RR "RI • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 27, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Plug Perforations (Cement Squeeze) for Well PTM P1-09, PTD #196-154. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • Daily Report of Well Operations PTM P1-09 ACTIVITYDATE SUMMARY CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill Cmt/Cmt Sqz Park on edge of pad until P1-09 gets set up. 12/22/2017 ***In Progress*** LRS Test Unit 6. Assist CTU with Milling Cement. Inlet Well P1-09, Outlet Well P1-13. Begin WSR @ 0100 Hrs. Unit Move, Rig Up, NPT for PRV removal, continue RU, NPT for PRV install, 12/23/2017 torque, &Vessel PT, continue RU, PT. Continue on WSR 12/24/17. CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill Cmt/Cmt Sqz MIRU CTU. MU & RIH w/HES 2.2" Logging Carrier&3.70"JSN. Bullhead 213 bbls of KCL. Perform Initial Injectivity Test. 1 bpm @ 435psi/2bpm @ 467psi/3bpm @ 529psi. Tag TOC/Fill at 10798'. Log from compression up to 9800'. Flagged pipe at 10749.66'. Pooh. Receive good data. (-4'Correction). Correlated to Slb Perf Jewelry Log 19-May-1997'. MU & RIH w/WFT 2-7/8" Motor&2-7/8" Reeves Underreamer(6" blades). Well Testers unable to move fluid down their outlet well P1-13. After troubleshooting with the DSO, confirmed the P1-13 flowline is frozen. Testers are assisting DSO to thaw flowline. RIH past Tbg Tail, displace Coil to Slick KCL. 12/24/2017 ***In Progress*** CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill Cmt/Cmt Sqz MIRU CTU. NU BOP's. Kill well &obtain injection rate. RIH, tag at 10798ft, log for tie-in. 12/24/2017 ***In Progress*** Thaw/Hot P1-13 FL For Testers and coil on P1-09 to take returns. /Pumped 12 bbls neat meth 12/25/2017 and 20 bbls 180*f crude down FL to work ice plug and clear FL/RDMO F/L= 573 CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill Cmt/Cmt Sqz Displaced Coil to Slick KCL. Establish Free-Spin below Tbg Tail. RIH to begin Underreaming taking all returns to tanks(no gaslift) due to frozen P1-13 flowline. Underream to 10860'. Decision to Pooh &wait for the outlet well flowline to get thawed due to wind direction change. Pump gel pill &drop 5/8"ball to open circ-sub. Chase ooh. Freeze Protect Coil &Well. PT MHA at surface& WFT Disconnect was leaking. Little Red Pump truck able to clear hydrate from P1-13 flowline. Switch to Baker tools. MU &RIH w/Baker DB Underreamer w/Chevron Cement Bit(Blades for 7" 29#Casing). 12/25/2017 ***In Progress*** CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill Cmt/Cmt Sqz Displaced Coil to Slick KCL. Establish Free-Spin below Tbg Tail. RIH to begin Underreaming taking all returns to tanks(no gaslift) due to frozen P1-13 flowline. Underream to 10860'. Decision to Pooh &wait for the outlet well flowline to get thawed due to wind direction change. Pump gel pill &drop 5/8" ball to open circ-sub. Chase ooh. Freeze Protect Coil &Well. PT MHA at surface& WFT Disconnect was leaking. Little Red Pump truck able to clear hydrate from P1-13 flowline. Switch to Baker tools. 12/25/2017 ***In Progress*** LRS Test Unit 6. Assist CTU with Milling Cement. Inlet Well P1-09, Outlet Well P1-13. Continue from WSR 12/24/17. Standby for Hydrates in Flowline, POP/Flow Well, Assist CTU. Continue on 12/25/2017 WSR 12/26/17. CTU#8 1.75"CT. Job Scope: Depth Log/Underream-Mill Cmt/Cmt Sqz Continue RIH w/Baker DB Underreamer. Had to shut in well to get past Tbg Jewelry. Underreaming from 10860'to 11024.5'. Had only 1 stall at 10989'. Below 10989'there was little to no motorwork. Stop underreaming at 11024.5'when motorwork was seen, indicating top of Tieback Slv. Drop 3/4" ball to open Circ-Sub. Chase ooh at 80%. At surface, UR blades look good, normal wear. Trim pipe&change packoffs. MU & RIH w/Baker 2-7/8" Motor&3.70" PDC Bit(L050). Dry tag at 11023'. Mill past Tieback Slv into 4-1/2" liner with no motorwork. Continue milling cement with Gel sweeps down to 11144'. 12/26/2017 ***Continue on 12/27/17 WSR*** LRS Test Unit 6. Assist CTU with Milling Cement. Inlet Well P1-09, Outlet Well P1-13. Continue 12/26/2017 from WSR 12/25/17. Flow Well, Assist CTU. Continue on WSR 12/27/17. • • Daily Report of Well Operations PTM P1-09 CTU#8 1.75"CT. Job Scope: Depth Log/Underream-Mill/Cmt Sqz Continue milling cement from 11144'with gel sweeps to 11490'. Stop due to H2S concerns. Resume milling to 11675'. POH. Test BOP's. 12/27/2017 ***In Progress*** CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill/Cmt Sqz Continue seven day BOP test 12/28/2017 CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill/Cmt Sqz Comeplete Weekly BOP test. MU SLB Cementing BHA w/2.5" BDJSN. RIH and killed well w/250 bbls of 1% KCL(1.5 times volume to perfs), established injectivity 1 bpm 413 psi, 2 bpm 481 psi, 3 bpm 557 psi, static 374 psi. Pumped 30 bbl diesel cap. Layed in PowerVis from 5'off bottom 11,786'to top of liner @ 10980'. Pumped 5 bbl fresh water spacer then laid in cement up to 10536'. Shut in choke and pumped 20 bbls cement, no pressure bump observed, cracked choke and laid in final 10 bbls of cement up to 10260'. Shut in choke and pulled to safety @ 8950' pumping pipe displacement. At safety circulated methanol down coil taking 1:1 returns to freeze protect coil to 1000'down hole. Squeezed 8.4 bbls behind pipe(28.4 bbls total behind ppe) and perform hesitation squeeze to 2000 psi. Held for 22 mins before lining up to start contaminating. RIH at 50fpm while maintaining 2000 psi on wellhead pressure with cracked choke from 8946'to 10200'. Bled pressure from 2000 psi to 700 psi. Contaminated cement 9800'to flag at 11679' in three passes. Chased ooh at 80%while washing nipples and mandrels maintaining 1:1 returns. 12/28/2017 **Continued on 12/29/17** LRS Test Unit 6. Assist CTU with Milling Cement. Inlet Well P1-09, Outlet Well P1-13. Continue 12/28/2017 from WSR 12/27/17. Assist CTU. Continue on WSR 12/29/17. LRS Test Unit 6. Assist CTU with Milling Cement. Inlet Well P1-09, Outlet Well P1-13. Continue 12/29/2017 from WSR 12/28/17. Assist CTU, Rig Down, Standby for Well Support, Unit Move. Job Complete. CTU#8 1.75" CT. Job Scope: Depth Log/Underream-Mill/Cmt Sqz Continue chasing ooh at 80%. Jet across BOP's and tree. Run back in and lay in freeze protect from 2500'with 60/40 meoh. RDMO 12/29/2017 **Job complete** (LRS Unit 46- MIT-T Post cement job. Road to location and rigged up. **WSR continued on 1-9- 1/8/2018 18** T/I/0=300/950/190 Temp=SI (LRS Unit 46- MIT-T Posst Cement Job) MIT-T***FAILED*** Pressured up TBG to 1701 psi with 2.33 bbls of 60/40. Lost 381 psi in the first 15 minutes. Estimated LLR of 1.23 GPM while re pressuring. Bled back 1.2 bbls. SV,WV,SSV=closed IA,OA=OTG 1/9/2018 FWHP=295/953/188 T/I/O = 320/950/190. Temp= SI. TBG/IA FL(pre MIT). AL SI @ CV, ALP= 720 psi. TBG FL= @ Surface, IA FL= 5810' (470'Above Sta#02 DOME, 102 bbls). 1/10/2018 SV, SSV, WV= C. MV= 0. IA, OA= OTG. 02:30 T/I/O = 316/955/190. Temp= SI. MIT for LLR. LLR = 1.4 gpm @ 1700 psi &7.2 gpm @ 1970 psi (Eval cement squeeze). T FL @ surface, IA FL @ 5810' (470'Above glm#2 dome, 102 bbls).. Unable to maintain test pressure for MIT. Obtained LLR of 1.4 gpm @ 1700 psi &7.2 gpm @ 1970 psi. Bled TP from 1250 psi to 290 psi in 10 min (1 bbl). Tags &AFE sign hung. Final WHP's = 290/950/190. 1/11/2018 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 15:00 CTU#8 1.75" CT. Job Scope: Mill Cement/CIBP MIRU CT. MU BOT milling assembly with 3.71" reverse clutch mill. Rih and Tag TOC at 11629' ctm. 3/2/2018 ***Job continued on 3/3/18*** CTU#8 1.75"CT. Job Scope: Mill Cement/CIBP Milled cement from 11,675'- 11,775'. Milled 4-1/2" CIBP at 13775'and pushed to 13,147' pumping gel sweeps. Chase ooh at 80%. washing mandrels and BOP's mainating 1:1 returns. Lay in 60/40 from 2500'for freeze protect. 3/3/2018 ***Job continued on 3/04/18*** • • Daily Report of Well Operations PTM P1-09 CTU#8 1.75" CT. Job Scope: Mill Cement/CIBP Cont. Milling/BKR, 4 BLADED OPTI CUT MILL 3.71", OAL=24.55', (MAX OD=3.71"). Tagged cement stringer at 11,629'ctm. Establish free spin. Begin milling cement. 3/3/2018 ***Job in progress*** CTU#8 1.75" CT. Job Scope: Mill Cement/CIBP Tagged cement stringer at 11,629'ctm. Establish free spin. Begin milling cement. 3/3/2018 ***Job in progress*** CTU#8 1.75" CT. Job Scope: Mill Cement/CIBP Riig down CTU and head to slb yard for planned maintenance. 3/4/2018 ***Job complete*** Fluids Summary Bbls Type 449 60/40 Methanol 7825 1% Slick KCL 2228 1% Slick KCL with Safelube 618 Powervis 30 Diesel 20 Crude 12 Neat 39 Fresh Water TREE CM( YaBLI-EAD= • P 10 9 NOTE: WELL ANGLE>70'Q 12707'. ' ACTUATOR= BAKER C - HNGR RIC30'MD 0KB.H..EV= 42.8' '••4-117'CHROME TBG&7"CHROME CSCE"• BF.ELEI/_ t 1 I KOP= 4000 Mu Angle= 78'0 11751' / L 2136_J-14-112'CAMCO BAt-0 NPPLE.D=3.812' J Datum )= 1074T 0 Do(umTVD= 8800'SS, NDR, 20'CONDUCTOR 1331,1+d0 BTC,13=1.750' J— 116' GAS LET MANDRELS M L 9-58"CSG,471,L-80,D=8.681' H 6022' I ST MD TVD DB/ TYPE VLV LATCH FORT DATE ' I 1 4053 4044 12 KBG2-LS' DOIrE, EU 16 06/05/12 IL 2 6280 5828 48 KBG2-LS DOGE NT 16 06/05/12 3 7771 6820 48 'KDOW N G2-LS DOT 16 06/05/12 17'CSG,260,1-80 BUTT,.0383 bpf,D=6.276' I- 9666' X X 4 9882 8214 49 KBG2-LS SO INT 20 09/04/17 Minimum ID = 3.725" 10018' El 9x6'9 7'X 4-112'BKR S3 PMC{ D=3:875" 4-12" HES XN NIPPLE �I � ' ' L1000a' —[4-1/2'FE:S X NIP.43 2' =3.81 [4-1/2"TBG, 12.61,13CR NSCT,.0152 bpf,0=3.958— 10031'j ' ' 10019' —[4-1/2"HES XN NP,D=3.725' PERFORATION SUMVARY N, \ I 10031 ]-14-1n"WLEG,D=3.956" FEF LOG:SF ERRY GR'CN4./LD ON 10/14/96 ' 10041' H ELMO TT LOGGED 05/19/97 ANGLE AT TOP PERF:36' 10680' , Note:Fifer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ , 3-318' 6 10580-10630 S 05/20/04 02117/08 3-3/8' 6 10650-10660 S 05/20/04 02/17/08 , 2-7/8" 6 10680-10710 S 12/20/13 12/28/17 , 10835' CMI SOZ-CLEANOUT DOTH 2-7/8" 6 10760- 10775 S 02/26/12 12/28/17 AF1E32 L AI4.15.8 PPG(01/07/12) 3-3/8". 6 10735 10785 S 05/21/97 01/07/12 III 6 10795- 10835 S 09/03/02 01/07/12 3-3/8' 6 10860- 10885 S 09/03/02 01/07/12 , 3-3/8' 6 10900- 10910 S 09/02/02 01/07/12 3-3/8' 6 10920- 10980 S 05/20/97 01/07/12 , 2-1/2' 6 13020- 13070 0 11/04/96 /111il11027' —7"X 4-1/2'LTP P R,6'TEBACX SLV TOP OF 4-1/2"LMR- 11027' &I-0.0 L M F I)=4.438" L7"CSG,291.13CR NSCC,.0371 bpf,ID=6_184'_I—I 11134' , 1314T CTM -F6l-t MLLED CPO&PKR- PIE)OH(03/03/18) PBTD H 13165' I L4-1/2'1NR, 12.61,L-80 BUTT,0152 bpf,D=3.953' I— 13242' 0'.'.At DATE REV BY C*I.UITS ` DATE REV BY COMIENTS PRUDHOE BAY INT 11105196 D14 ORIGINAL COMPLETION :96/11/12 BSE/JM)GLV 00(06/05112) WELL: P1-09 03/05/11 RLWVPJC BTM PERF CORRECTION ;12/27/13 SET/JI.[) ADPERFS(12/20/13) KIWI No:'1961540 03/05/11 PJC DRA'W 3 CORRECTIONS '09/12/17 GB/JM)GLV 00(09/03/17) AR No: 50-029-22704-00 04/29/11 JwF/PJC PILL BP(04/16/11) 101/05/18 JTIIMJIIU PALLED C T/SQZ©PERFS Sec, 16,T12N,R14E,1438'FSL&752'FEL 12/15/11 MSS/PJC GLV 00(12/13/11) `03/07/18 16/J0.1D PALL®CMI&FKR DH/SET FISH • 01/06/12 FEW/PJC P&A(01/07/12) _ BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, March 18, 2018 7:07 AM To: AK, OPS EOC Specialists;AK, OPS GPMA Field O&M TL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK,OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Burton, Kaity; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer P1-09 (PTD# 1961540) Sustained inner annulus casing pressure above NOL Attachments: P1-09.pdf All, Producer P1-09(PTD# 1961540)was reported to have sustained inner annulus casing pressure above NOL on 3/15/2018. The well failed a subsequent cold TIFL on 3/15/18 and warm TIFL on 3/17/2018. The failing TIFLs indicate an impairment of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. SL—Perform GLV Change out 2. DHD-Warm TIFL 3. DHD-Monitor 4. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua StephensANNEU Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO giobas ood%«swus►r e 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, September 5, 2017 10:06 AM To: AK, OPS EOC Specialists;AK, OPS GPMA Field O&M TL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Burton, Kaity; Duong, Lea; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki,Oliver R;Tempel, Joshua;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer P1-09 (PTD# 1961540)Well barriers restored, MITs Passed All, Producer P1-09(PTD# 1961540)was made under evaluation on 8/17/17 for having sustained inner annulus casing pressure above NOL. On 9/4/17 slickline completed a gas lift change out, set a tubing tail plug, and performed a passing MIT-T to 2715psi and MIT-IA to 3431psi. The passing pressure test confirms two competent well barriers. At this time the well is reclassified as Operable. Please mind fluid packed annuli when bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 ,1O,�., SCANNED SEP 1 2 2017. From: AK, GWO Well Integrity Engineer Sent: Thursday, August 17, 2017 5:10 AM To: AK, GWO Well Inte• '* Engineer; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field O&• • AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, '. S SUPT Special Projects; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Burt. aity; Duong, Lea; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Inte• • AK, OPS FF Well Ops Comp Rep; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgome ravis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Worthington, Aras J Subject: UNDER EVALUATION: Producer P1-09 (PTD# 1961540) High Inner • lus Pressure Over NOL 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday,August 17, 2017 5:10 AM To: AK, GWO Well Integrity Engineer;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM;AK, OPS GPMA Field O&M IL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead; Burton, Kaity; Duong, Lea; Regg,James B (DOA);Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J Subject: UNDER EVALUATION: Producer P1-09 (PTD# 1961540) High Inner Annulus Pressure Over NOL All, Producer P1-09 (PTD# 1961540)was reported to have sustained outer annulus casing pressure over NOL on 08/16/17 indicating a lack of two competent wellbore barriers. The pressures were confirmed to be TBG/IA/OA= 3040/2540/460 psi. At this time the well is classified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Operations: Pop well 2. DHD: Warm TIFL 3. Well Integrity Engineer: Additional diagnostics as needed Please respond if in conflict with plan, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 SGANmED AUG 2 1, 2017 Cell 907-980-0552 Harmony 4530 1 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 2 1 2014 1.Operations Abandon Lf Repair Well LI Plug Perforations Li Perforate (J Other Li AOGCC Performed: Alter Casing 111Pull Tubing❑ Stimulate-Frac ElWaiver ❑ Time Extension❑ Change Approved Program ❑ Operat.ShutdownE Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Developmert0 Exploratory ❑ k 196-154-0 111 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 ' 50-029-22704-00-00 7.Property Designation(LeaseNumber)' 8.Well Name and Number: ADL0028298 • a a f 7 • PTM P1-09 9.Logs(List logs and submit electronic and printed data per 20—0225.071): 10.Field/Pool(s): . PT M Vt _ 'c PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth measured •• 13242 feet Plugs measured 10835 feet true vertical 10055.24 feet Junk measured None feet Effective Depth measured • 10835 feet Packer measured See Attachment feet true vertical 8917.64 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 4988 9-5/8"47#L-80 34-5022 34-4933.43 6870 4760 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 2215 4-1/2"12.6#L-80 11027-13242 9089.78-10055.24 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SC,ANNE® jt �i 4 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 30-10031 30-8313.05 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: RBDMS` t MAY 16 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 163 868 5485 2419 720 Subsequent to operation: 875 20300 2070 2397 2214 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorE❑ Development❑✓ • Service❑ Stratigraphic D Daily Report of Well Operations X 16.Well Status after work: Oil .Q Gas LI WDSPILI GSTOR ❑ WINJ ❑ WAG ❑ GINJ D SUSP ❑ SPLUC❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhaysaa.bp.com Printed Name Nita Summerhays Title Data Coordinator ignatur- erfir/AraP1311 __ Phone 564-4035 Date 1/20/2014 VLF ,5-/Z //4 14 141*/ .7 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028298 ""WELL SII UN ARRIVAL***(Perforating) R/U RISER & PCE FOR 30' DRIFT. 12/5/2013 ***CONT WSR ON 12/6/13*** ***CONT WSR FROM 12/5/13*** (Perforating) LOC TTL @ 10,010' SLM (10,041' ELMD) -31' CORRECTION. DRIFTED 3 x 10' x 2-7/8" DUMMY PERF GUNS TO 10,750' SLM (10,781' CELMD) 12/6/2013 ***** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. **** ***WELL SHUT IN UPON ARRIVAL***(E-LINE ADPERI-) INITIAL T/I/0=2100/1750/450 RIH W/GR/CCL/20'x2-7/8" PJ OMEGA PERF GUN GUN SPECS 6 SPF, 60° PHASED, PEN=36", EH=0.34" CCL STOP DEPTH=10686.5', CCL TO TOP SHOT=3.5' PERFORATED I NTERVAL=10690'-10710' DEPTH CORRELATED TO SLB PPROF DATED 5/1/11 12/19/2013 ***JOB CONTINUED ON 12/20/13*** ***JOB CONTINUED-FROM 12/19/13***(E-LINE ADPERI-) RIH W/GR/CCL/20'x2-7/8" PJ OMEGA PERF GUN GUN SPECS 6 SPF, 60° PHASED, PEN=36", EH=0.34" CCL STOP DEPTH=10676.54', CCL TO TOP SHOT=3.46' PERFORATED INTERVAL=10680'-10690' DEPTH CORRELATED TO SLB PPROF DATED 5/1/11 WELL SHUT IN UPON DEPARTURE, DSO NOTIFIED FINAL T/I/0=2030/1900/450 PSI 12/20/2013 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 3 DIESEL 3 TOTAL N , CO CA N CO M M N 11') st ct CO M CO CO M CO O N- CD 0) sP O O O CD O) cr f` lL) N a t` '- O O a- M CO ' LD h. r- O N- al '4' t` 0) 0) e-- LC) CO N- 0) CO co sT T:1- h- N- N- r` CO CO CO CO 03 0) 0) 0) 0 0 0) C) U) OD CID CID CO CIO CO CIO U) CIO CO U) 0) 0) 0) W Z p a 0 U 0se H 0) co U) co M N h. CO U) — L() M N 0 0 W tY W Y Mn O IN CD O Tr O O 0) CD Tr Tr N- O d d C13Z ce o.al OCD CIoo 00) 0) M in coOCIO 0) M N- Ori M) Tr N-tri JJ p p p O r- N- r- N- r- 000O00000O0) 0) 0) 0 p 0) p - W a Z aoUDaocwaowwU) U) U) w comma) p a I- I-az o a CO CO CO CO CO m R CO O O V' O O O 117 O O LC7 O O 00 O O +• 0100000) CDN- 00a- M00 — tiCIOr` ° CD CO CD CO N- N- N- N- Co 00 CIO 0) 0) 0) O C x 0 0 0 0 0 0 0 0 0 0 0 O O O M R m _ I- I- co O co n Q N H C o .c 0 0 0 O Ln 0 LC) O O O O O CO O J p 00OCI0000) ("1CDICI) — CO ONNN • Q p 00000,000000 000 M 03 too o It 0 V ° 0 C ° NNLL. I� I� 0CLL. 0c0c0cN NNNN ti CICYaaan. aaaaCI 0000 0) < < < < cf) Ci) 0 a) a p O co coC)C) Cc`I Co N N N N N O Q 0 0 0 r- a- a- a- LL c 0 y CO CD C. 0 0) CO CND CO T- CNN N N N N Laj l N N LL Nti N- J W W CL N N N N N \ a— a — 0 W W u W d N N (NI C N N N N J J D p CC Cl 0 LL v0i v0i a Cr 0 E Ca 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0 0 0 0 0 0 0 0 0 0 0 O O O OI I 0 LL N Ce LL aaaaaaaaaaa CL as U rz co) co O cc Q0 0 0 0 0 0 (OLD vo mLO 0 (Or` vr- () ICOM �' CO N- M 7 O N '— W mMco r-- co COW �N 00• CO OO)) (n ct CO O L0M OD LON M M N M O m - O M N 0 CO W O N CO O CO co cr) r M N0) CO CO0M 0 N M CO .- N , 000 „ 0 MOcoNr0 „ Nm M O O mooch Q N r- Lowrn (OLD CO LoNMO � OCOMv- O ON M O N 8 8 M O _N M M CO C Q l _N Cn O � O 0 c9 Q L2 CO O g U e CO > Z J M O *k •NN M N W X 4te- ( CO 1C CO C.) 'Mc') � - CV Na) (0 -0\0 N N N U N ' 4 N N O N- r co w mo C OOO N O to 0 0 J N CD ,- N 0 0 ZZ 00 co 00 W WD wwwQCT Q J J J Q Q W Z OZW0- 0- 13- 00 > Wm OZCLCLIWWWDD UJZZZDav) u) F- Packers and SSV's Attachment ADL0028298 SW Name Type MD TVD Depscription P1-09 PACKER 9985 8239.24 4-1/2" Baker S-3 Perm Packer P1-09 PACKER 11034 9053.28 4-1/2" Top Packer • alb= CIW WELLHEAD= FMCP 1 0 g ' _flf NOTE: WELL MNa"LE>700 12707'. ACTUATOR BAKER C TBG HNGR FMC @ 30'MD OKB.ELEV= 42.8' '""4-112•'CHROME TBG&7"CHROME CSG" 13F.13-EV= I KO_P= 4000` gle Max An = 78'@ 1175V 2135' -14-112"CA MCO BAL-O NIPPLE,D=3.812" Datum MD= 1074T 0 GAS UFT MkNDRaS um TVD 8800'SS 20"CONDUCTOR,133#,H-40 BTC,D=1..750" MAI Dat 9-5/8"CSG,47#,L-80,D=8.68V H 5022' ST MD ND 0EV TYPE VLV LATCH PORT DATE ' 1 4053 4044 12 KBG2-LS DOPE NT 16 06/05/12 I`l 2 6280 5828 48 KBG2-LS DCNJE NT 16 06/05/12 3 7771 6820 48 KBG2-LS DONEE INT 16 06/05/12 T CSG,26#,L-80 BUTT,.0383 bpf,D=6.276' --I 9666' X ^ 4 9882 8214 49 KBG2-LS SO NT 24 06/05/12 Minimum ID = 3.725" @ 10018' z >4 9985' —7"X4-1/2"BKRS-3PKR,D=3.875" 4-1/2" HES XN NIPPLE I I 10008' —14-1/2"HES X NP,D=3.812" 4-1/7 TBG,12.6#,13CR NSCT,.0152 bpf,D=3.958• 10031' ' , 10019' —14-1/2"I-E5 XN NP D=3.725" PERFORATION SUMMA \/ \ —I 10031' H4-1/2"WLEG,ID=3.958" REF LOG:SFERRY GR/CNJLD ON 10/14/96I 10041' —1 ELtid TT LOGGED 05/19/97 ANGLE AT TOP P:RE:36"@ 10680' , Note:Refer to Roduction OB for historical perf data SIZE SPF NTB2VAL Opn/Sqz SHOT SOZ 3-3/8' 6 10580-10630 S 05/20/04 02/17/08 3-3/8" 6 10650-10660 S 05/20/04 02/17/08 , 2-7/8" 6 10680-10710 0 12/20/13 10835' —CMT SOZ-CLEANOUT DEPTH 2-7/8" 6 10760-10775 0 02126/12 •••••�•••••�••• Al-IER LARC 15.8 PPG(01/07/12) 3-3/8" 6 10735-10785 S 05/21/97 01/07/12 •�•�•�•�•�•�•�•. ••••••••••••�• • • 3-3/8" 6 10795-10835 S 09/03/02 01/07/12 ••••••••••••••• 3-3/8" 6 10860-10885 S 09103!02 01/07/12 •0.00.0.0•• •••••••• 3-3/8" 6 10900-10910 S 09/02/02 01/07/12 •••••••••.•.••• ••••••••••••••i 3-3/8" 6 10920-10980 S 05/20/97 01/07/12 •••••❖•••••••• 2-1/2" 6 13020-13070 C 11/04/96 ••••••••❖•••• ••••••••••••••• •••••••• _,• I •••••�••• 1 ••• • 11027 —7*X 4-1/2"LTP F KR,6'TACK SLV •�•�•�•�•, &HMC LNR HGR,D=4.438" TOP OF 4-1/2"LNR 1— 11027' ••••••••• ••••••••. ••••••••. ••••••••. ••••••••. .••••4• , ••• ••••� T CSG,29#,13CR NSCC,.0371 bpf,D=6.184" --I 11134' •••••••• •••••:••. V.v1v0v1 11152' --I TOP OF CMT TAGGED 05!17!$7 11775' —4-1/7 BAKER CBP(05/16/97)1I PBTD H 13165' 1 x'...1/4 4-1/2"LNR,12.6#,L-80 BUTT,.0152 bpf,ID=3.953" —j 13242' '.'.1 A A$' DATE Fel/BY COMMENTS DATE REV BY COMMENTS FRUJ OE BAY IMT 11/05/96 014 ORIGINAL COMPLETION 06/11/12 BSE/JMD GLV 00(06/05/12) WELL: P1-09 03/05/11 RLW/PJC BTM PERF CORRECTION 12/27/13 SET/AD ADPE1 S(12120/13) PERMIT No:1961540 03/05/11 PJC DRAWtIG CORRECTIONS AR No: 50-029-22704-00 04/29/11 JMF/PJC PIAL BP(04/16/11) Sec. 16,T12N,R14E, 1438'FSL&757 FEL 12/15/11 MSS/PJC GLV C/O(12/13!11) 01/08/12 RRW/PJC P&A(01/07/12) BP Exploration(Alaska) STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other In SQUEEZE 10835 -13070 Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ - 196 -1540 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 – 50- 029 - 22704 -00 -00 8. Property Designation (Lease Number) : 4 9. Well Name and Number: ADLO- 028298 a. 8 7 7 310 P1 -09 10. Field /Pool(s): PRUDHOE BAY FIELD / PT MCINTYRE OIL POOL 11. Present Well Condition Summary: j' Total Depth measured 13242 feet c . t Rl1' (measured) 11775 feet 'j true vertical 10055 feed ,y��, V Junk (measured) None feet Effective Depth measured 13165 feet Packer (measured) 2135 9985 11027 feet true vertical 10028 feet (true vertical) 2131 8282 9090 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 133# H -40 35 - 115 35 - 115 Surface 4988' 9 -5/8" 47# L -80 34 - 5022 34 - 4933 6870 4760 Production 9636' 7" 26# L -80 30 - 9666 30 - 8073 7240 5410 Production 1468' 7" 29# 13CR80 9666 - 11134 8073 - 9186 8160 7020 Liner 2215' 4 -1/2" 12.6# L -80 11027 - 13242 9090 - 1055 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 30 - 10031 30 - 8313 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Camco WRDP -2 SSV « _,, . _. . _ -., 21357 2131 4 -1/2" Baker 3 Perm Packer 9985 1 8282 r- , _, -- _ ; `% ; 1.--1 ...` 11027 9090 4-1/2" Top P ker "r� (r- �; ; , , 12. Stimulation or cement squeeze summary: MAR 1 ? „ _ \ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ( N;-151c2 Gtj & Gas Con s , r "' +1 S!`)� Anchorage _ i 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 232 1351 7714 701 Subsequent to operation: 1039 2545 1754 742 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 — Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil – 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ p WAGE GINJ ❑ SUSPO SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Nita Summerhays Printed Name Nita Summerhays Title Data Manager // — /_�/ Si nat � 0 g af goly / 1arta /` =1 i Phone 564 -4035 Date 3/8/2012 (�{ DMS MAR 1 2 3 /6- Form 10-404 Revised 1012C"F9 ° "f1 Submit Original Only P1 -09 196 -154 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P1 -09 11/26/96 PER 13,020. 13,070. 9,976.02 9,994.23 P1 -09 5/16/97 BPS 11,152. 13,070. 9,202.7 9,994.23 P1 -09 5/20/97 APF 10,920. 10,980. 8,993.45 9,047.53 P1 -09 5/21/97 APF 10,735. 10,785. 8,832.54 8,874.55 P1 -09 6/23/99 FIL 10,975. 11,152. 9,043.03 9,202.7 P1 -09 9/2/02 APF 10,900. 10,910. 8,975.41 8,984.43 P1 -09 9/3/02 APF 10,795. 10,835. 8,883.08 8,917.64 P1 -09 9/3/02 APF 10,860. 10,885. 8,939.65 8,961.93 P1 -09 5/20/04 APF 10,650. 10,660. 8,763.58 8,771.52 P1 -09 5/20/04 APF 10,580. 10,630. 8,709.39 8,747.85 • P1 -09 2/8/08 BPS 10,850. 10,860. 8,930.81 8,939.65 P1 -09 2/14/08 SPS 10,735. 10,850. 8,832.54 8,930.81 P1 -09 2/16/08 SQZ 10,580. 10,735. 8,709.39 8,832.54 P1 -09 2/21/08 SPR 10,684. 10,810. 8,790.78 8,895.94 P1 -09 4/15/11 SPR 10,810. 10,850. 8,895.94 8,930.81 P1 -09 4/16/11 BPP 10,850. 10,860. 8,930.81 8,939.65 P1 -09 1/5/12 SQZ 10,978. 13,070. 9,045.73 9,994.23 P1 -09 1/7/12 SQZ 10,835. 13,070. 8,917.64 9,994.23 P1 -09 2/26/12 APF 10,760. 10,775. 8,853.42 8,866.07 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE III MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 1 • ���� P1-09 � ��m�r DESCRIPTION OF ������� ���� �������������� WORK COMPLETED OPERATIONS ��mn�v�����/u��m���u�m'm���nc� EVENT ����������r ��v����'� ��m��v'm�r'�������m |� �' `�����7Q� ` ���� ��cTYvY��J�`�''r��*�������$�����W�����1�`'6��«�"�,=^^ • �^�. 12/1O/2O11**° WELL FLOWING ON ARRIVAL **°(Cement Squeeze) RIG UP8VVCPLANOL|NE#11 LRS F/P F/L AND TBG CURRENTLY RIH W/ 3 5O" CENT, TEL 2.50" SAMPLE BAILER ' ' TEL, ***[}ONTVVSF{ON12V11/11**° �— 1 -----'' 1 '-----'---- ---'-- Squeeze) ----- --------'-----'� 'DRIFT TBGVV/3.50"(�ENT,TEL.3�5O" SAMPLE BA|LER(nooanlp|e recovered), LOC TT AT 10012'GLM. +�CORRTOE�D�1[�1'MO TAG TD AT 10973' G� +29' CORR.= 11,002' ELMD O ( of 'SET SLIP STOP C-SUBAJO414'8LK8 PULL |NT-LGLV FROM Gl7\#1AT4O27'SLyW(4O53'MD) PULL |NT-OGLV FROM 8T/##2A78258'SLyW(O27S'MD) ***C[)NTVVGRON12/12/11°°° 12/11/2011 Assist Slickline with MIT-IA (Pre Squeeze) Road bo|ocaUon.PJGK8. /°°°CmnUnuoVVSF�on12/12/11�° ' -- - L� ---- — -- ------------ -- - - '------ 1�12/2O11**°�ONTVVG�FR�yW13M1/11�° (Cement ' ' SET INT-DGLV IN STA#1 AT 4027 SLM (4053 MD) ! LRGLOAO IA WITH [% �~132 BBLS CRUDE /�TEK�PTTOGET|NT-OC�LV|N8T/#2.UNABLETO S/] ^** GO TO WEATHER HOLD ^** . / ! �----- --' -- --''-----�—f 12/12/2011 10. Temp=SI. WHP's (IA & TBG FL's for FB). ALP=2400 psi | aneG|at casing valve. TBGFL@5O51' and U\FL©surface. SV,WV=closed. SSV,MV=open. IA &OA=opontogauge. 2300 hrs. 12/12/2U11'°**ContinuedVVSR from 12'11-11**° T/K[)=1700/ B19/54O Temp=SI Assist Slickline, Load IA (Pre Squeeze) Loaded IA with 5 bbls neat m | ono|ond134 bbls crude. Slickline unable to set DGLV in station #2. Final !VVH . SV, WV, CV-closed. 8GV, MV, IA, OA-open. ' drill with Slickline what to do if heater caught on fire.*** ! —'— - 12V13/2011'T/KO=2300/1940/500 MIT-IA PASSED to 2500 psi. Freeze Protect Tubing and Flowline. (Cement Squeeze) Pumped 40 bbls crude down Tbg for Freeze protect. Pumped 12 bbls neat meath down flowline to freeze protect. Pumped into the |A with 3bb|o crude bo reach test pressure for K8|7-|A � |A lost 32 psi in 'the first 15 min and 0 psi in the second 15 min for a total pressure loss of 32 psi in 30 min test. Bled IA to 508 psi. �vv Left shut in, notified DSO upon departure. FWHP= 952/506/520. SV, SSV, WV=closed. MV, IA, OA= open. 12/13/2011 *** OFF WEATHER HOLD, CONT WSR FROM 12/12/11 *** (Cement Squeeze) SET |NT'DGLV|NGTA#2ATG258'SLM(627S MD) PULL EMPTY SLIP STOP C-SUB FROM 6414' SLM ***VVELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED *** • • 1/3/2012 ** *CTU #8 1.75" CT * ** Job Scope: Cement Sqz w/ Squeeze Creat and LARC Cement shutting off water production from lower perforations. MIRU ...Continue WSR on 12/4/2012... 1/4/2012 Continued from WSR of 01/03/12. CTU 8, 1.75" coil. Job Scope. WSO with 50 bbl CMT squeeze. Wait on BP WSL changeout. M/U cementing nozzle BHA. PT lubricator. RIH. :Kill well while RIH. RU SLB Cmt'g equip. tagged bottom. 10,980' CTD, PU 10'. « <JOB IN PROGRESS »> 1 /5 /2012:Continued from WSR of 01/04/12. ;CTU 8, 1.75" coil. Job Scope. WSO with 50 bbl CMT squeeze. 'Blend both slurries in batch tanks, run tests & shear slurries. Ran out of Pump time on slurries, dispose both slurries. POOH. FP w160/40. :SLB to reblend w /longer pump time, to — 10 hrs. Wait for blending /testing of new cmt. « «JOB IN PROGRESS »» 1/6/2012 Continued from WSR of 01/05/12. CTU 8, 1.75" coil. Job Scope. WSO with 50 bbl CMT squeeze. `Waiting on new cmt blend to be tested. PT lubricator and RIH. Tag bottom at '10978'. Pick up and flag coil at 10835'. Rig up SWS cementing equipment. Batch up sqz Crete & LARC, preform lab tests. Pump time on Sqz crete is 10 hrs 05 mins, LARC pump time is 10 hrs 47 mins. Pump times run out @ 06:49 AM & 07:46 AM respectively. Injection Rate 1 BPM @ 710 psi WHP. Pump water ;ahead w /cmtr's PT & start pumping Sqz Crete. « <JOB IN PROGRESS »> 1 /7 /2012Continued from WSR of 01/07/12. CTU 8, 1.75" coil. Job Scope. WSO with 50 bbl CMT squeeze. ' Pumped 21 bbl's of Sqz crete with a 12 ml API fluid loss & 30 bbl's of LARC cmt with a 52 ml API fluid loss, placed 31.5 bbl's of cmt behind pipe. (2,1 bbl's of Sqz Crete & 10.5 bbl's of LARC.) Calc TOC before C/O w /BIO was 10,579', Got a : psi sqz, held for 1 -hr. CIO w /Bio to 10,835'. 3 passes, first pass 2:1. Chase out of hole at 2.3 bpm, Jet up /dwn /up across all GLM's and nipples while POH. Freeze protect tubing from 2500 - surface with 60/40 meth. Trap 590 psi WHP. Lay out BHA. PBTD = 10,835'. PJSM. Rig down CTU. N/U Tree cap and PT. Move CTU to SWS shop. «< Job Complete »> 1/12/2012 ** *WELL S/I ON ARRIVAL * ** 3 LOC TT @ 10,035' SLM (10,041' ELMD) _ +6' CORRECTION, TAGGED TOC @ ; 10,844' SLM, (10,850' ELMD) ** *WELL LEFT S/I ON DEPARTURE * ** 1/15/2012; ** *WELL S/I ON ARRIVAL * ** (cement squeeze) SET 4 1/2" WHIDDON C -SUB @ 10,012' SLM PULL DGLV FROM ST #2 @ 6,275' SLM (6,279' MD) RDMO TO D.S. 11 FOR PRIORITY JOB * * * * * *WHIDDON LEFT IN HOLE * * * * ** ** *WELL LEFT S/I ON DEPARTURE * ** DSO NOTIFIED 1/19/2012 ** *WELL S/I ON ARRIVAL * ** (cement squeeze) RIH TO PULL STA #1 @ 4053' MD. ** *CONTINUE JOB ON 01 -20 -12 WSR * ** • • 1/20 /2012: ** *CONTINUE JOB FROM 01/19/12 WSR * ** (cement squeeze) PULLED BTM -INT DGLV FROM STA #1 @ 4043' SLM, 4053' MD SET LGLV IN STA #1 AT 4043' SLM (4053' MD) ** *JOB CONTINUED ON 01/21/12 WSR * ** 1/21/2012 ** *JOB CONTINUED FROM 1 -20 -12 WSR * ** (cement squeeze) SET BTM -INT ORFICE IN STA #2 @ 6275' SLM/6279' MD PULLED EMPTY 4 1/2" WHIDDON FROM 10,012' SLM. ** *WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS * ** 1/22/2012 T /I /0= 725/700/450 ( Meth down IA) Rig to IA . Press.test. / WSR continued on 01- 23 -12. 1/23/2012 T /I /O= 725/700/450 ( Meth down TBG ) WSR continued from 01- 22 -12. Continue 'press. test. Pump 2 bbls neat meth down IA. TBG trackig IA. Job Cancelled, , FWHP= 1120/1120/450. Wing =shut / swab =shut / ssv =shut / master =open / IA and OA open to gauges. RDMO / Standby for weather. Operator notified. 2/25/2012 T /I /O = 1470/1540/440. Temp = SI. T FL (E -Line call in). AL open at casing valve, ALP = 1540 psi. T FL @ 1776' (27 bbls). SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 10:00 hrs. 2/26/2012 ** *WELL SI ON ARRIVAL * * *(ELINE, PERFORATION) INITIAL T /I /0= 1470/1490/450 TOOL STRING: MH22- ERS -EQF43 -UPCT- FIRING HEAD -GUN, OVERALL LENGTH 28', WEIGHT 220 #, MAX OD 2,825, FISHING HEAD DIANETER 1 3/8 OTIS. THE PERF INTERVAL 10760'- 10775', CCL TO TOP SHOT = 8.3', CCL STOP DEPTH = 10751.7' FINAL T /I /0 = 1380/1600/600 PSI ** *JOB COMPLETE * ** WELL LEFT SHUT IN UPON DEPARTURE FLUIDS PUMPED BBLS 7 DIESEL 52 METH 245 60/40 METH 177 CRUDE 694 2 %KCL 120 1%KCL W /SAFE L 205 WATER 111 BIOZAN 1611 TOTAL TREE = ° 0M/ WELLHEAD = FMC • S NOTE: TBG HNGR FMC @ 30' MD ACTUATOR = BAKER C P1 -0 9 ***4-1/2" CHROME TBG& 7" CHROME CSC"' KB, ELEV BF. ELEV = 1 1 KOP = 400■' Max Angle = 78' ®11751' 1 2135' 4 -1/2" CAMCO BA L-0 NIPPLE, ID = 3.812 Datum MD = 10747 Datum 1VD = 8800' SS 120" CONDUCTOR, 133#, H-40 BTC, ID = 1 .750" 1 115' GAS LIFT MANDRELS 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 1— 5022' , ST MD TVD DEV TYPE VLV LATCH PORT [SATE 1 4053 4044 12 KBG2 -LS DOME INT 16 01/21/12 2 6279 5828 48 KB02 -LS SO INT 20 01/21/12 3 7771 6820 47 KBG2 -LS DMY INT 0 10/)8/10 T' CSG, 26 #, L -80 BUTT, .0383 bpi, ID = 6.276" H 9666' 4 9882 8213 49 KBG2 -L DMY INT 0 1 126/96 Minimum ID = 3.725" @ 10018' ►�� 9985' —1T' X 4 -112" BKR S -3 PKR ID = 3.875" 1 4 -1/2" HES XN NIPPLE 1 10008' —14-1/2" HES X NIP, ID = 3.812" 1 10019' 1- -14 -12' HES XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, 13CR NSCT, .0152 bpf, ID = 3.958" H 10031' 10031' 4 -1/2' WLEG, ID = 3.958" PERFORATION SUMMARY 1 10041' — ELMD TT LOGGED 05/19/97 REF LOG: SPERRY GR/CNL /LD ON 10/14/96 ANGLE AT TOP PERF: 33° © 10760' Note: Refer to Roduction D8 for historical pert data SIZE SPF INTERVAL Opn /Sqz GATE 3-3/8" 6 10580- 10630 S 02/17/08 ........ 10835' 1 — CMT SQZ - CLEANOIJT DEPTH • 3 -3/8" 6 10650 - 10660 S 02/17/08 • • • •• •• • ■• ►•••••••∎ 2 -7/8" 6 10760 - 10775 0 02/26/12 ► i i ••••• i . AFTER LARC 15,8 PPG (01107111) t••••••• 3-3/8" 6 10735 - 10785 S 01/07/12 ►�■••••••••••••40 3 -3/8" 6 10795 - 10835 S 01/07/12 l • • •• • • •• •∎ . ■•••••••• 3-3/8" 6 10860 - 10885 S 01/07/12 ►0 3-3/8" 6 10900 - 10910 S 01/07/12 1 4 • :': ❖: ❖: . ►••••••••. 3 -3 /8" 6 10920 - 10980 S 01/07/12 ►•••••••• ••••••••••••∎ • ••••••• ► 2 -12" 6 13020 - 13070 C 11/04/96 •••••• ❖•❖ ►':•••••••••••• • - - - .1,2•••••••••••.'r1 i ♦••• • • • • 4 T' 11027' — X 4 -12" LTP PKR, 6 TIEBACK SLV � •••••••� 8 HMC LNR HGR, 10 = 4.438" 1TOPOF4 -1/2" LNR 1 11027' . - ••• • ••••• •••• ••••••••• i ••••••••• i i •••••••••' i • 1 7' CSG, 29 #, 13CR NSCC, .0371 bpf, ID = 6.184" H 11134' • ••�•�• •• i•••• � • � • � • � • � 1 11152' 1 TOP OF CMT TAGGED 05/17/97 1 11775' 1 - - 1/2" BAKER GBP (05/16/97) 1 1 1 PBTD H 13165' . 1 r 41/2" LNR, 12.6 #, L -80 BUTT, .0152 bpf, ID = 3.953" 13242' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/05/96 D14 ORIGINAL COMPLETION 01/30/12 mew PJC GLV C/0 (01/21/12) WELL: P1 -09 03/05/11 RLW/PJC BTM PERF CORRECTION 02/27/12 JCJ PJC PERFS (02/26/12) PERMIT No: '1961540 03/05/11 PJC DRAWING CORRECTIONS API No: 50- 029 - 22704 -00 04/29/11 JMF /PJC PULL BP (04/16/11) Sec. 16, T12N, R14E, 1438' FSL & 752' FEL 12/15/11 'MSS/ PJC GLV C/O (12/13/11) 01/08/12 'RRWI PJC P&A (01/07 /11) BP Exploration (Alaska) 05/06/11 Sch lumaerger NO. 5738 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska 00 & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ArrN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD P2 -16 _ BBSK -00061 USIT ' 44 04/04/11 1- 3510 -25 BBKA -00101 PRODUCTION PROFILE 'fr. — 7 0.4/04/11 1 - 'v«w 1 P2 -52 BJGT -00027 CROSS FLOW CHECK 1 -'jam` e1f Ol 1 03 -37 BJGT -00028 INJECTION PROFILE - , 1, - 1J - 04/16/11 1 (j 1 2- 421P -13 BAUJ -00076 MEMLDL /'/ft. - /6 04/15/11 1 / es/,? 1 N -11C BH4H -00048 PRODUCTION PROFILE �� --iX,/ U. 04/19/11 1 J,y4, C 1 02 -12C BD88 -00098 MEM CBL ,d. 1 1 ° C) S -120 P1 -09 BD88 -00100 MEM INJECTION PROFILE (/ TO • 3 �_ t3 -• 04/25/11 1 / , 1 BJOH -00024 PRODUCTION PROFILE ,, 'L. 05101/1 1 1 , _ _ 1 • P1 -09 P2-43 BJOH -00024 SCMT 05/02/11 MI' ' 1 1 BG4H -00049 SCMT _,A ° --. _i_ 04/28/11 Lam , 1 1 16 -21 BJGT -00030 PRODUCTION PROFILE i 1 09 -26 BD88 -00104 MEM LDL .. o e'T ! 04/30/11 1 04 -33A BLPO -00095 MEM PROD CTION PROFIL �nl. ti ('S Q 04/30/11 1 / 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E Benson Blvd. Anchorage, AK 99503 -2838 • Jl •N 4 1 2.01', STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other isi FILL CLEAN OUT/ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ UNDERREAM Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory p - 196 -1540 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22704 -00 -00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO- 028298/028297 f P1 -09 10. Field /Pool(s): _ PRUDHOE BAY FIELD / PT MCINTYRE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13242 feet Plugs (measured) 11775 feet true vertical 10055.24 feet Junk (measured) None feet Effective Depth measured 13165 feet Packer (measured) 2135 9985 11034 feet true vertical 10028.02 feet (true vertical) 2131 8282 9096 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 133# H -40 35 - 115 35 - 115 Surface 4988' 9 -5/8" 47# L -80 34 - 5022 34 - 4933 6870 4760 Production 9636' 7" 26# L -80 30 - 9666 30 - 8073 7240 5410 Production 1468' 7" 29# 13CR80 9666 - 11134 8073 - 9186 8160 7020 Liner 2215' 4 -1/2" 12.6# L -80 11027 - 13242 9090 - 1055 3 7500 Liner t. �Y 3 2 011 i tAi t ikED Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 30 - 10031 30 - 8313 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Camco WRDP -2 SSV 2135 2131 4 -1/2" Baker S -3 Pemi Packer 9985 8282 4 -1/2" Top Packer 9096 12. Stimulation or cement squeeze summary: o f */ . Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska Ott & f 's C G41164$100 • 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 678 2926 8051 718 Subsequent to operation: 703 2463 8460 713 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Developments El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG0 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - . - Last ilki i Title Data Manager Signatur: 11111 I �" 1 Phone 564-4091 Date 4/27/2011 w 5.2•11 ����+ APR 2 n �R Form 10-404 Revised 10/2010 RBDII4S A R 2 a LY bmit Oiginal Only ‘/J-4 P1 -09 196 -154 • PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P1 -09 11/26/96 PER 13,020. 13,070. 9,976.02 9,994.23 P1-09 5/16/97 BPS 11,152. 13,070. 9,202.7 9,994.23 P1 -09 5/20/97 APF 10,920. 10,980. 8,993.45 9,047.53 P1 -09 5/21/97 APF 10,735. 10,785. 8,832.54 8,874.55 P1 -09 6/23/99 FIL 10,975. 11,152. 9,043.03 9,202.7 P1 -09 9/2/02 APF 10,900. 10,910. 8,975.41 8,984.43 P1 -09 9/3/02 APF 10,860. 10,885. 8,939.65 8,961.93 P1 -09 9/3/02 APF 10,795. 10,835. 8,883.08 8,917.64 P1 -09 5/20/04 APF 10,580. 10,630. 8,709.39 8,747.85 P1 -09 5/20/04 APF 10,650. 10,660. 8,763.58 8,771.52 P1 -09 2/8/08 BPS 10,850. 10,860. 8,930.81 8,939.65 P1 -09 2/14/08 SPS 10,735. 10,850. 8,832.54 8,930.81 • P1 -09 2/16/08 SQZ 10,580. 10,735. 8,709.39 8,832.54 P1 -09 2/21/08 SPR 10,684. 10,810. 8,790.78 8,895.94 P1 -09 4/15/11 SPR 10,810. 10,850. 8,895.94 8,930.81 P1 -09 4/16/11 BPP 10,850. 10,860. 8,930.81 8,939.65 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • I 1 1 1 . • P1 -09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/14/2011 `CTU #9, 1.75" coil. 0.134" wall (Job Scope: cleanout, pull IBP, underream) RU coil. l ***Continued from 4/13/11 * ** RIH w / 2.25" JSN cleaned out to top of fish. Run #2 [RIH w / hydraulic centralizer & jars & 3.63" JDC hydr release overshot unable to get latched POOH. Run #3 RIH w/ venturi, mule shoe btm w/ tattle tail pin, SD @ 10837', work venturi, POOH. 1 ** *Continued on 4/15/11 * ** / 4/15/2011 `CTU #9, 1.75" coil, 0.134" wall (Job Scope: Pull IBP) ** *Continued from 4/14/11 ** Tag bottom @ 10837' w/ venturi, pump 20 bbls, POOH, recover 2 gal scale from venturi. Run #4 RIH w/ venturi POOH recovered 2 gals scale from venturi. Cut 50' ofi coil for pipe management . RIH w / 1.75" DJN clean out to 10838' Run # 5 RIH w / hydraulic centralizer & jars & 3.63" JDC hydr release overshot, SD on IBP @ 10832' ctm. latch IBP. POOH. ** *Continued on 4/16/11 * ** [ 4/16/2011i*** WELL S/I ON ARRIVAL * ** ASSISTING COIL TUBING UNIT 9 MADE 3 RUNS W/3.68" WIRE GRABS TO 10,904' SLM RECOVERED 2 LARGE IBP ELEMENTS @ 10.904' SLM RECOVERED IBP STIFFENER BAND @ 10,904' SLM IBP original set depth was 10,850 ** *WELL S/O ON DEPARTURE, CTU -9 HAS WELL * ** 1 f 3 4/16/2011. CTU #9, 1.75" coil, 0.134" wall (Job Scope: Pull IBP, Underream) ** *Continued from 14/15/11*** 1Continue POOH w/ IBP. At surface, recover 3.38" IBP. RIH w/ DB underreamer. Got a call from the office to POOH and R/U slickline to fish IBP elements. Slickline recovered all the elements R/D slickline. RIH w/ BOT underreamer, begin underreaming 10750'. ** *Continued on 4/17/11*** l � E i ` E • • 4/17/2011 !CTU #9, 1.75" coil, 0.134" wall (Job Scope: underream) ** *Continued from 14/16/11*** l Underream 10750- 11000', little to no motor work seen, pump geo pills, POOH. Underreamer arms show good wear. RDMO. ** *Job Complete * ** FLUIDS PUMPED BBLS 294 60/40 METH 340 1 %KCL 20 GEOVIS 1 DIESEL 149 XS KCL W/ SL 340 XS KCL 1144 TOTAL TREE = CM/ 1 • WELLHEAD = FMC SAFETY INE: TBG HNGR FM @ 30' MD ACTUATOR = BAKER C P1 -0 9 * * *4 -1 /2" CHROME TBG & 7" CHROME CSG* ** KB. ELEV= BF. ELEV = __ -- a 1 KOP = 4000' Max Angle = 78° @ 11751' 1 2135' I— I4 -1/2" CAMCO BAL -O NIPPLE, ID = 3.812" I Datum MD = 10747' Datum TVD = 8800' SS 120" CONDUCTOR, 133 #, H-40 BTC, ID = 1..750" I 115' 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I — I 5022' GAS LIFT MANDRELS ST 1 4MD TVD D V KBG S DOME LATCH INT PORT 10/08/10 DATE 7" CSG, 26 #, L -80, .0383 bpf, ID = 6.276" H 9666 2 6279 5828 48 KBG2 -LS SO INT 24 10/08/10 — 3 7771 6820 47 KBG2 -LS DMY INT 0 10/08/10 4 9882 8213 49 KBG2 -LS DMY INT 0 Minimum ID = 3.725" @ 10018' ...:24 ►�� 9984' I-17" X 4 -1/2" BAKERS 3 PKR 1 4 -1/2" HES XN NIPPLE I 10008' H4-1/2" HES X NIP, ID = 3.812" 1 I 10018' 1 HES XN NIP, D = 3.725" I 14 -112" TBG, 12.6#, 13CR NSCT, .0152 bpf, ID = 3.958" I—J 10031' 10031' I'-I4 -1/2" TUBING TAIL W/WLEG 1 PERFORATION SUMMARY I 10041' H ELMD TT LOGGED 05/19/97 I REF LOG: SPERRY GR/CNL /LD ON 10/14/96 ANGLE AT TOP PERF: 41 @ 10580' 1 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 1 3 -3/8" 6 10580 - 10630 S 02/17/08 3 -3/8" 6 10650 - 10660 S 02/17/08 1 3 -3/8" 6 10735 - 10785 0 05/21/97 3 -3/8" 6 10795 - 10835 0 09/03/02 ' 3 -3/8" 6 10860 - 10885 C 09/03/02 3 -3/8" 6 10900 - 10910 C 09/02/02 , 3 -3/8" 6 10920 - 10980 C 05/20/97 2-1/2" 6 13020 - 13070 C 11/04/96 ' 'TOP OF 4 -1/2" LNR I—{ 11027' 11034' H 7" BAKER HMC PKR 1 1 ( 7" CSG, 29 #, 13CR NSCT, .0371 bpf, ID = 6.184" I - 1 11134' ow I 11152' H TOP OF CMT TAGGED 05/17/97 1 1••••• ,R4.1`1.4./ L 11775' 1 BAKER CIBP (05 /16/97) 1 1 PBTD H 13165' I II .1.4.1 ( 4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.953" H 13242' )... ......t DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/05/96 D14 ORIGINAL COMPLETION 03/05/11 RLW /PJC BTM PERF CORRECTION WELL: P1 -09 02/19/08 GLMITLH IBP SET & SANDBACK (2/8/08: 03/05/11 PJC DRAWING CORRECTIONS PERMIT No: 1961540 02/19/08 GLM/TLH CMT SQZ PERFS (2/17/08) API No: 50- 029 - 22704 -00 03/14/08 BSE/TLH GLV C/0 (02/19/08) Sec. 16, T12N, R14E, 1438' FSL & 752' FEL 10/17/08 JLC/PJC PERF CORRECTIONS 10/23/10 SWC/AGF GLV CIO (10/08/10) _ BP Exploration (Alaska) 11/01/10 sc NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/IBPSET RECORD 09/15/10 1 1 MPS -43 AYKP -00104 SCMT 08126/10 1 1 P1 -09 BCRJ -00036 PRODUCTION ROFILE 6911121110 1 W -37A BD88.00048 MEM PRODUCTION PROFILE s — 09111110 1 W -31A AZ2F -00084 MEM PRODUCTION PROFILE 09/16110 1 06 -19A AWJI -00112 MEM PRODUCTION PROFILE _ C1 09119110 1 i 12 -05AL1 BAUJ -00050 MEM PRODUCTION PROFILE 09120110 1 1 Pl -16 BCRJ -00049 INJECTION PROFILE 10/06110 1 1 04-03 BCRD -00059 PRODUCTION PROFILE 09127/10 1 1 P -03A A22F -00065 MEM INJECTION PROFILE f 10/06/10 1 1 G -19B AWJI -00114 MEM PRODUCTION PROFILE 10/04/10 1 1 Y -36 BDBB -WDS8 MEM GLS 10/09110 1 1 3- 03/J -33 BCZ2 -00025 PRODUCTION Mi 09/11110 1 1 L -214A BAUJ -00043 MEM INJECTION PROFILE 09113/10 1 An 1 H -01A AWJI -00116 MEM PRODUCTION PROFILE 10114/10 1 1 16.068 BBUO.OW23 PRODUCTION PROFILE BP CORRECTION 06106/10 1 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE 10/16110 1 1 P2 -44 BCRD -00063 PRODUCTION PROFILE 10115110 1 G 1 B-1 3B AYKP -00091 CH EDIT PDC -GR (SCMT) 07102110 1 02 -22B JOAKA0069 OH MWDILWD EDIT 07/07/10 2 1 W -19B BCRJ -00034 CH EDIT PDC -GR (SCMT) 09107110 1 1 I I I OWIYW -SE APBPD3WELL RST REDO-PRINT I 09123/10 1 _ OWDW -NW BBSK -00033 IRST 09/24/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 -� fD I`1 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~~ Mr. Tom Maunder `~~y Alaska Oil and Gas Conservation Commission / ~ ~j 333 West 7th Avenue YJ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any. additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-o7A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA s.so 7n/2oo9 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 ., STATE OF ALASKA ~"? ~~ ALA~A OIL AND GAS CONSERVATION COM~SION MAR 1 1 ~OC$ REPORT OF SUNDRY WELL OPERAT1011~ISka Oi(~ Gas Lens. ~c'rrftmissio-al 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~~NT SQZ Performed: 1 Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ EXplOratOry ~ 196-1540 3. Address: P.O. Box 196612 Stratigraphic ~ SerVICe ~' 6. API Number: Anchorage, AK 99519-6612 50-029-22704-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42.8 KB ~ P1-09 8. Property Designation: `, 10. Field/Pool(s): ADLO-028298 A~OOa'l~i?~~ PRUDHOE BAY Field/ PT MCINTYRE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13242 ~ feet Plugs (measured) 11775 true vertical 10055.24, feet Junk (measured) None Effective Depth measured 10055- feet true vertical 9208 feet i '~ c:~I~N~~U MAR ~. 200 Casing Length Size MD TVD Burst Collapse Surface 4988 9-5/8" 47# L-80 34 - 5022 34 - 4933 6870 4760 Production 9636 7" 26# L-80 30 - 9666 30 - 8073 7240 5410 Production 1468 7" 29# 13CR80 9666 - 11134 8073 - 9186 8160 7020 Liner 2215 4-1/2" 12.6# L-80 11027 - 13242 9090 - 10055 8430 7500 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# 13Cr80 30 - 10031 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Camco WRDP-2 SSV 2135 4-1/2" Baker S-3 Perm Packer 9985 4-1/2" Top Packer 11034 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Daia Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 537 16064 2090 2248 Subsequent to operation: 534 17472 2036 973 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. Sundry Number or N/A if C.O. Exempt: 307-298 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 2/27/2008 Form 10-404 Revised 04/2006 ~ ~~'l,1 Submit Original Only • Perforation Depth MD (ft) 10580' - 10630' 10650' - 10660' 10735' - 10785' 10795' - 10835' 10860' - 10885' 10900' - 10910' 10920' - 10980' 13020' - 13070' P1-09 PERFORATIONS 196-154 Opn/Sqz Perforation Depth TVD (ft) SOZ 8709' - 8748' SOZ 8764' - 8772' O 8833' - 8875' O 8883'- 8917' O 8940' - 8962' C 8975' - 8984' C 8993' - 9047' C 9976' - 9994' • P1-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE 2/15/2008 SUMMARY CTU # 9 w/ 15900' of 1.75" CT. Acid and Cement Squeeze*. Travel to Location. MIRU.**InterAct Publishing**. Make up BHA #1, 2.72" JSN. RIH pumping 20 bbls of 60/40 meth, 155 bbls of 1 %KCI with 0.6% SafeLube at 2.0 bpm. Initial njection rate at 2.0 bpm was 1200 psi., Pump 26 bbls of 12% HCI and lay across peforations. Let soak for 15 mins. *'`*Job continued on ', 2/16/08*** .. __ 2/16/2008 CTU # 9 w/ 15900' of 1.75" CT. "Cement Squeeze for Gas shut off'`. Continued from 2/15/08. *"InterAct Publishing*'` Continue displacing acid into formation 0.9 bpm 415 psi. Over displace by 60 bbls. POOH lay down BHA# 1 and MU & RIH BHA # 2 w/2.67" OD Blount Blaster Nozzle. Load well with 1 %KCI at 4.8 bpm at 1200 psi. Tag bottom at 10,689' ctmd, PUH 10' and flag pipe. Pump 62 bbls of OrganoSeal gel laying in across interval from 10670' to 10580' and squeezing into formation. Pump 17 bbls of 15.8 ppg Class G LARC cement. Appeared to put 1 bbl behind pipe initially, and then an addition 0.5 bbl when reamping from 1600 psi to 2100 psi on WHP. Build pressure to 2650 psi (estimated 2500 psi overbalance at perfs) in 500 psi increments. Hold final squueze pressure for 60 minutes. Contaminate remaining cement with 1.5 ppb Biozan. Washed 30' past flag with Biozan to 10710'. Wash liner and tubing, reducing rate across perforations. POOH chasing sweep to surface, Jet across jewlery and wellhead. Freeze protect 2500'. Close in well with 600 psi. RDMO. Final T/I/O = 600/250/280. **'` Cement step complete'`'* FLUIDS PUMPED BBLS 105 60/40 METH 80 1 %KCI WITH 0.6% SAFELUBE 580 1 %KCI 65 ORGANOSEAL-R 17 LARC 15.8 PPG CEMENT 55 FRESH WATER 902 TOTAL P1-09 Revised Gas Shut Off ~ze. Page 1 of 1 • AAaunder, Thomas E (©DA) From: Maunder, Thomas E (DOA} Sent: Friday, December 14, 2007 9:43 AM To: 'Wamer, Ross L' Cc: Frankenberg, Amy Subject: RE: P1-09 Revised Gas Shut Off Squeeze. I~co-~S~ Ross, Thanks for providing the updated information. The actual work will still provide the isolation desired to conduct the squeeze and as you note the plug is retrievable. Nothing further is needed. f will place a copy of your documents in the file. Good luck shutting off the gas. Tom Maunder, PE AOGCC From: Warner, Ross t_ [mailto:Ross.Warner@bp.com] Serrt: Friday, December 14, 2007 9:28 AM To: Maunder, Thomas E (DOA) Cc: Frankenberg, Amy Subject: P1-09 Revised Gas Shut Off Squeeze, ~~~~Q ~~~ ~ ZQ07 Tom Maunder, The enclosed Word Document is a letter to you concerning a Revised Program for the GSO at well P1-09, Point McIntyre Freld. The other attachments are schematics picturing the changes in procedure. Thanks, Ross Wamer GPMA Production Engineer 250-3441 «t_etter State-Revised, Dec.doc» «P1-09 Dec Revised Plan.xis» «P1-09 Original Plan.xls» ]2/14/2007 • • by .~. ~ ~~~~~ December 14, 2007 Alaska Oil & Gas Conservation Commission Attention: Mr. Thomas Maunder 333 west 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Thomas Maunder: «(~ ~- ~5 `~{ Reference: Sundry Notice for P1-09---Oas Shut-Off Squeeze. \ September 20, 2007 I wrote a letter requesting a Sundry for performing the Gas Shut- off Squeeze at P1-09. You issued a Sundry September 27, 2007, number 307-298. During this intervening time frame we have re-visited this project and made some changes to the original program. The main change is rather than sand back the entire lower portion of this wet! we purpose to set an inflatable bridge plug and cover it with sand to protect the main oil producing sand. This plug is retrievable so we are not permanently isolating the lower portion of the well. I have attached schematics of #~e new plan vs. the original plan to illustrate what we now plan to accomplish. Summary: Step Type Procedure 1 S Pult SSSV. Make gauge and TD run again. 2 C & FB .Knock down WH pressure. Run tie-in log. Set IBP @ 10,850' MD. Ref: SWS Jewelry Log of May 19, 1997. Sand back casing to 10,700. Move unit to P1-06 cleanout 3 S Cap sand with Latex Barite mixture. 4 C & FB Rig up unit again and GSO squeeze. Break up sand cap. Move to PZ- 11A for cleanout. WOC at P1-09 and SL operations. 5 SL Tag TD. Instal[ gas lift design. 6 C Run another tie-in tog. cleanout sand to 10,795' Tom, will your original Sundry cover this change or will you have to issue a New Sundry? I would appreciate your answer at your earliest connivance. We are now planning to commence this work early January 2008. • P1-09 GSO Squeeze If you have any questions please contact: Ross Warner at: 564-5359 or 254-3441. E-Mai{ address: wamerrl@bp.com Sincerely, Ross L. blamer GPMA Production Engineer 2 P1-09 Planned Squeeze Procedure 1 Set IBP 10850 2 Sandback well to -10700 Includes -6 feet of sand cap 3 Cement squeeze upper perfs 4 Cleanout well to 10710 5 WOC 3-7 days. Set GLD 6 Cleanout well to 10795 IOR 700 bopd Cleanout Depth 10795 After Squeeze Last TD 10900 Slick line • Sand Not to Scale Packer @ 9984 Production D From PL Logl EOT @ 10031' Jan. 30, 201 Perforations 10580 96 % Gas Production 10630 10650-10660 •~ 10,700 10735 ~~ 100 % Oil Product 10785 ~~ 41 % Water Produ ' 10795 0% Production 10835 ~ 10850 IBP 10860-10885 0% Production 10900-10910 16% Water 10920 43% Water 10980 Fill ? Packer @ 11034 7" @ 11134' C.IBP with cement @ 11152 4-112" Liner • P1-09 After Squeeze Procedure 1 Sandback well to 10700 2 Cement squeeze upper perfs 3 Cleanout well to 10790 4 POP IOR 700 bopd • Not to Scale Packer @ 9984 Production Data From PL Logging EOT @ 10031' Jan. 30, 2006 Perforations 10580 96 % Gas Production / Squeezed 10630 10650-10660 Cleanout Depth -10790 After Squeeze 10735 100 % Oil Production 10785 ~~ 41 % Water Production Open 10795 0% Production 10835 Sand covered Sand 10860-10885 0% Production Sand covered 10900-10910 16% Water 10920 Sand covered 43% Water Sand covered 10980 Fill Packer @ 11034 7" @ 11134' CIBP with cement @ 11152 4-1/2" Liner • P1-09 Original Plan Procedure 1 Sandback well to 10700 2 Cement squeeze upper perfs 3 Cleanout well to 10790 4 POP IOR 700 bopd Sandback • Not to Scale Packer @ 9984 Production Data From PL Logging EOT @ 10031' Jan. 30, 2006 Perforations 10580 96 % Gas Production 10630 10650-10660 ~~ 10,700 10735 100 % Oil Production 10785 ~~ 41 % Water Productic Cleanout Depth 10790 After Squeeze 10795 0% Production 10835 10860-10885 0% Production 10900-10910 16% Water 10920 43% Water 10980 Packer @ 11034 7" @ 11134' CIBP with cement @ 11152 4-1/2" Liner • P1-09 After Squeeze Procedure 1 Sandback well to 10700 2 Cement squeeze upper perfs 3 Cleanout well to 10790 4 POP IOR 700 bopd Not to Scale Packer @ 9984 Production Data From PL Logging EOT @ 10031' Jan. 30, 2006 Perforations 10580 96 % Gas Production / Squeezed 10630 10650-10660 Cleanout Depth -10790 After Squeeze 10735 100 % Oil Production 10785 ~~ 41 % Water Production Open 10795 0% Production 10835 10860-10885 10900-10910 10920 0% Production 16% Water 43% Water 10980 Packer @ 11034 7" @ 11134' CIBP with cement @ 11152 4-1/2" Liner 11/15!07 NO.4498 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 , } Alaska Oil & Gas Cons Gomm Anchorage, AK 99503-2838 ~~~~ ~~ y ~ ~ 2~~~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Pt. Mac. Milne Pt. Well Joh # 1 nn Ilnecrinfinn rhfn RI Cnlnr Cn MPS-37 11594513 OH LDWG EDIT ~ (0 06/26107 6 2 1 J-25A 11767130 MCNL t~ 60 06/18/07 1 1 OWDW-SW 11483588 _ RST v -~, y~ - ~'~ ~ 11/17/06 1 1 OWDW-NW 11626127 RST (~~ 10/09/07 1 1 OWDW-SE 11225967 RST L) G OU - ! 04/19/06 1 1 M-12A 11216184 MCNL (~ - . ( '~ 04/04/07 1 1 P1-09 11773114 RST t C nj r 04/24/07 1 1 OWDW-SE 11855823 RST .V C°- p-Lj,.. •~ 6 10/28!07 1 1 r~criac v.~.nNVVVtcuUt tttGtlY I tsT SFl9NlNli ANU Kt 1 UKNI~(~„UNt GUYY tAGM I U: BP Exploration (Alaska) Inc. a ~, N } Petrotechnical Data Center LR2-1 „', k'''. ,. 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: r r,try}gNI3"~tta~'r =Ef Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • • • a ~ ~ o SARAH PALIN, GOVERNOR ~~ OJW ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSERQg7'I011T COI'IIrIISSI01~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 278-1433 FAX (907) 27B-7542 Ross Warner Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 ~ ~ l.~ `~v Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, P1-09 Sundry Number: 307-298 '';~~~~ Nd~ ~ 4 Z~D7 Dear Warner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of-approual set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~!'7 day of September, 2007 Encl. Z~ d 9~6~>? ~ ~ ~ ~ ~ v ~ ~ :- STATE OF ALASKA EIS ~ ~ Za~~ AL KA OIL AND GAS CONSERVATION COM~ION ~'~ ~~ 9JL7`~ APPLICATION FOR SUNDRY APPROV~~s~a ail ~ Gas Cons. Cammissian 20 AAC 25.280 ~nchara~e 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Other ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time EMension ^ squeeze Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Weil Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ^ 196-1540 " 3. Address: P.O. Box 196612 6 Stratigraphic ^ Service ^ . API Number: Anchorage, AK 99519-6612 50-029-22704-00.00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property tine where ownership or landownership changes: P1-09 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: ~~ 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028298 a~7~ 9•/~` 42.8 KB - PRUDHOE BAY Field / PT MCINTYRE OIL Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (tt): Plugs (measured): Junk (measured): 13242 10055 - 10055.24 9208 11775 None Casing Length Size MD TVD Burst Collapse Surface 4988 9-5/8" 47# L-80 34 5022 34 4933 6870 4760 Production 9636 7" 26# L-80 30 9666 30 8073 7240 5410 Production 1468 7" 29# 13CR80 9666 11134 8072.96 9186 8160 7020 Liner 2215 4-1/2" 12.6# L-80 11027 13242 9089.78 10055 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See attached - See attached - 4-1/2" 12.6# 13Cr80 30 - 10031 Packers and SSSV Type: 4-1/2" Camco WRDP-2 SSV Packers and SSSV MD (ft): 2135 4-1/2" Baker S-3 Perm Packer 9985 4-1/2" Top Packer 11034 0 0 12. Attachments: Descriptive Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Developm ent ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/25/2007 Oil Q Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by nary rrerJle 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact 0 Printed Name Ross Warner Title Production En leer Signature ~~ ~t..,Phone 564-5359 Date 9/20/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O~.- Plug Integrity ^ BOP T e s t ^ Mechanical Integrity Test ^ Location Clearance ^ t('~~ ^ - - ~ Other: ~~v~QS~ ~ \ ~~0~ ~~~ ~~ ,~~R 2 ~ 1007 Subsequent Form Required: ~ V ~ APPROVED BY /~ ~ . ~ ~~ Approved by: COMMISSIONER THE COMMISSION Date: Y Form 10-403 Revised 06/2006 }{ ubmit in Duplicate P1-09 PERFORATIONS 196-154 Perforation Depth MD (ft) Opn/Sqz Perforation Depth TVD (ft) 10580' - 10630' O 8709' - 8748' 10650' - 10660' O 8764' - 8772' 10735' - 10785' O 8833' - 8875' 10795' - 10835' O 8883'- 8917' 10860' - 10885' O 8940' - 8962' 10900' - 10910' O 8975' - 8984' 10920' - 10980' O 8993' - 9047' 13020' - 13070' S 9976' - 9994' • • P1-09 Purposed Squeeze Procedure 1 Sandback well to 10700 2 Cement squeeze upper perfs 3 Cleanout well to 10790 4 POP IOR 700 bopd Cleanout Depth 10790 After Squeeze Not to Scale Packer @ 9984 Production Data From PL Logging EOT @ 10031' Jan. 30, 2006 Perforations 10580 96 % Gas Production / 10630 ~l~ 10650-10660 ~.~ 10,700 10735 100 % Oil Production 10785 f~ 41 % Water Productic 10795 0% Production 10835 10860-10885 0% Production 10900-10910 16% Water 10920 43% Water 10980 Packer @ 11034 7" @ 11134' CIBP with cement @ 11152 4-1/2" Liner P1-09 After Squeeze Procedure 1 Sandback well to 10700 2 Cement squeeze upper perfs 3 Cleanout well to 10790 4 POP IOR 700 bopd ,] Not to Scale Packer @ 9984 Production Data From PL Logging EOT ~ 10031' Jan. 30, 2006 Perforations 10580 96 % Gas Production / Squeezed 10630 10650-10660 Cleanout Depth -10790 After Squeeze 10735 100 % Oil Production 10785 ~~ 41 % Water Production Open 10795 0% Production 10835 10860-10885 10900-10910 10920 0% Production 16% Water 43% Water 10980 Packer ~ 11034 7" C~ 11134' CIBP with cement ~ 11152 4-1 /2" Liner ~•~ .~ TREE _. ~ WELLHEAD = _.__._.. CM/ -- ACTUATOR = BAKER C KB. ELEV = 44.4' BF ELEV = KOP = 4000' Max Angie = _ __ 78 @ 11751' , Datum MD = ~T,~-_. 10747 Datum7VD 8800' SS 9-518" CSG, 47#, L-80, ID = 8.681" T° CSG, 26#, L-80, iD = 6.276" TOP OF 7" CSG 5022' 9666' 9666' Minimum ID = 3.725" @ 10018' 4-1 /2" HES XN NIPPLE P1-09 • TUBING HANGER: FMC @ 30' MD 14-112" CANICO BAL-O NIPPLE, ID = 3.812" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4053 4044 12 DUMMY S(O BTM INT 114' 1/21/2005 2 6279 5828 48 DUMMY S10 BTM INT 114' 1/21!2005 3 7771 6820 47 DUMMY SJO BTM INT 318' 1/21/2005 4 9882 8213 49 DUMMY SJO BTM INT 7" X 4-112" BAKER S-3 PKR 1000$' I-i4-1/2" HES X NIP, ID = 3.812" 4-112" HES XN N1P, ID = 3.725" 4-112" -fBG; 12.6#, 13CR-NSCT, 0.0152 bpf; ID = 3.958" ~TOPOF4-112" LNR i 10031' I PERFORATION SUMMARY REF LOG: SPERRY GRICNL/LD ON 10/14/96 ANGLE AT TOP PERF 41 @ 10580' Note: Refer to Roductian DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 10580 - 90630 O 05!20/04 3-318" 6 10650 - 10660 O 05!20/04 3-3/8" 6 10735 - 10785 O 05!21/97 3-318" 6 10795 - 10835 O 09(03(02 3-318" 6 10860 - 10885 O 09103!02 3-3J8" 6 10900 - 10910 O 09/02/02 3-3J8" 6 10920 - 10980 O 05120/97 2-1(2" 6 13020 - 13070 S 05/16/97 7" CSG, 29#, 13GR NSCT, ID = 6.184" ~--{ 11134' PBTD '13165' 4-1/2" LNR~ 12.6#; L-80, 0.0152 bpf, ID = 3.953" 13242' 10031' --~4-112" TUBING TAIL WlWLEG 10041' ELMD TT LOGGED 05(19197 11034' I--~ 7°' BAKER HMC PKR 11152' --~TTOP OF CMT TAGGED 05!17/97 11775' ~--~4-1 J2° BAKER CIBP~ DATE REV BY COMMENTS DATE REV BY COMMENTS 01/24!97 ORIGINAL COMPLETION 08/20/02 DTRJKK MIN ID CORRECTION 912-9!3/02 CWS/KK ADPERFS 05/20104 MJA/KAK ADPERFS 0112DJ05 DAV/PJC GLV CJO 01/29/06 RMH/PJC S55V C/O PRUDHOE BAY UNIT WELL: P1-09 PERMIT t`io: x1961540 API No: 50-029-22704-00 Sec. 16, T12N, R14E, 4017.47 FEL 1162.45 FNL BP Explora3ion (Alaska) September 20, 2007 Alaska Oil & Gas Conservation Commission Attention: Mr. Thomas Maunder 333 west 7t" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Thomas Maunder: Reference: Sundry Notice for P1-09---Gas Shut-Off Squeeze. BP Exploration (Alaska) Inc. proposes to perform a Gas Shut-Off Squeeze on well P 1-09. Attached are sketches which illustrate our purposed plans to squeeze off the high gas producing perforations which curtailing production at this well site. Currently the well is operated as a cycled well. This squeeze will restore full time production at P1-09. Summary' Step Type Summary 1 FB Pressure test IA 2 C Coil: Sandback liner and 7" casing & squeeze the upper two sets of perforations. 3 S & FB WOC 3 days. Pressure test squeeze and tag sandlcement top. Install gas lift valves. 4 C Coil: Cleanout sand/cement to 10700 ft. Expose oil producing perforations. 5 O Put well on production. Service work will begin when approval is received from your organization. If you have any questions please contact: Ross Warner at: 564-5359 or 250-3441. E-Mail address: warnerrl @ bp.com Sincerely, ~.~,~,~~ Ross L. Warner .:';.:: ¡--: f~ i l/ i~ (J Schlumberger Fi""ß' ~ ,...) <JML. r!:· !. L. ~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth --~~ ........'~;_. --·{,,".;in~fH:;~~jOL Alcoorags Well Job# Log Description Date BL 13-31 A .;)05- ¡wO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 OS 18-03B .-90 S ~ Of",(Í, 11057071 SBHP SURVEY 12/02/05 1 NK-43 rQ~/-CO I 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /C¡C¡ - 057 11183463 LEAK DETECTION LOG 01/28/06 1 OS 06-22A ¡Q?YJCS7 N/A SENSAlMEM LDL 01/28/06 1 OS 11-26 Iß(ç·~ 134- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 ) 9tç·· /51- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 )r.7-CtcCj· 11058541 RST 11/11/05 1 Z-29 ¡M -C(r.Ç' 11051081 RST 08/10/05 1 L5-09 f C¡C - 1-Y4'- 11090725 RST 11/11/05 1 15-44 ,qr...: - / 1 ð 11194155 RST 01/15/06 1 C-20B ";;0/-1 /4- 11075913 MCNL 08/29/05 1 02-14A .Q03 ·1';<5 11075901 MCNL 07/29/05 1 Z-21 A -90 (- iO 1 11076449 RST 06/30/05 1 F-27 A ';;05-/&4- 10928641 MCNL 09/01/05 1 MPH-15 ~?cr:5" 15'1 11076486 USIT 12/15/05 13-31 A -:::)OS-Iwb 11133211 SCMT 12/23/05 WGI-04 I 7'1 - cSD 11183461 USIT 01/26/06 WGI-04 nq -cst> 11211566 USIT 02/03/06 WGI-08 14c- o¥j 10987559 USIT 01/02/06 WGI-08 þl10 - c4Q 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ..?-,{ r-:}7 ( G Lr Ç¡. ç 2GÛD , ~" 'b B 'lr V ~CI~~E~ i b 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD -- 1 1 1 1 1 1 1 1 - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 :::v~e:y L~ö ) Problem Well Notification: PI-09 (PTD #1961540) ) ) ~f~'1 Subject: Problem Well Notification: P1-09 (pTD #1961540) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 16 Jan 2005 19:27:36 -0900 To:p "GPB, GPMA Area Mgr" <GPBGPMATL@BP.com>, "Rossberg, R Steven" . <~ossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor". . <NSUADWW ellOperatiorisSupervisor@BP.com>, "GPB, Wells Opt Eng" .. . : <QPBWellsOptEng@BP.com>,"AOGCC Jim Regg.(E-mail)..<jim_regg@.adm~.state.ak.us>. "AOGCC WintoilAubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Cop1pletiol1 Supervisor" <NSUADWWL&CompletionSupervisor@BP.coril>, "GPB, LPC DS Ops. Leád" <GPBLPCDSOpsLead@BP.com>, "GPB, Ops Mgr" <GPBOpsMgr@BP.com>, "Parker, R. . Anp.rew" <ParkerRA@BP.com> .. . . . CG: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "C()rcoran, Kevin D (VECO)" <Corcoran~Kevin@BP.com>, "Reeves, Donald p".. <ReevesDf@BP.com> All, Well P1-09 (PTD #1961540) has sustained pressure on the IA and the well has been classified as a Problem well. A TIFL failed on 1/14/05. TIOls on 1/15/05 were T/I/O = 2400/2630/370. The plan forward for this well is as follows: 1. SL: Run DGLVls 2. DHD: Re-TIFL Attached is a wellbore schematic and TIO plot. Please call if you have any questions. «P1-09.pdf» «P1-09 TIO Joe Anders, P.E. Well Integrity Coordinator, Work: (907) 659-5102 Mobile: (907) 943 -1154 Pager: (907) 659-5100, xl154 Email: Plot. ZIP» BP Exploration, (Alaska) Inc. Content-Description: P 1-09 .pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: P1-09 TIO Plot.ZIP TIO Plot. ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 -p¡ess~ /vl:p¡ p 4 ~ ).(Ÿ\ff' .- r Ivh,,,V( 'J-à ðA Zt\úO pSi. . .. I Zb 30 PSi 3(0 fì ì Z4Ðps', bB70r~ 3Z50~- 3DCflr\ D~ Dì¿ ¡: 0 4. 2005 1 of 1 1/24/2005 9:39 AM ) TREE = ---? WELLHE=A D = CNV 'AciüAfoR;;m . BAkER,j. KB. IiBi ;--~_m_--¡4:4ï --~_. .~--. _..." ---~-~.~~_."-~g._.._-~-~_..._. BF. 8...EV = KOP= - ---- -.-..... ,".. - IVax Angle = DaÚim rvv =...-.... t5äÙiin f\i ö;;m.. 4000' " ..._"--"-,.... ... 78 @ 11751' 10 i4iï .. ääõQi§S" 9-5/8"CSG, 47#, L-80, 10=8.681" 1-1 5022' 7" CSG, 26#, L-80, 10 = 6.276" 1-4 9666' 1 TOP OF 7" CSG 1-4 9666' Minimum ID = 3.725" @ 10018' 4-1/2" HES XN NIPPLE 4-1/2"TBG, 12.6#, 13CR-NSCT, -1 10031' 1 0.0152 bpf, 10 = 3.958" 1 TOPOF4-1/2"LNRI-1 11027' 1 PERFORATION SUfvTv1ARY REF LOG: SPERRY GRlCNLILO ON 10/14/96 ANGLEATTOPÆRF: 41 @ 10580' Note: Refer to Production DB for historcal perf data SIZE SPF INTERV AL OpnlSqz [}I\ TE 3-3/8" 6 10580 - 10630 0 OS/20/04 3-3/8" 6 10650 - 10660 0 OS/20/04 3-3/8" 6 10735- 10785 0 OS/21/97 3-3/8" 6 10795 - 10835 0 09/03/02 3-3/8" 6 10860 - 10885 0 09/03/02 3-3/8" 6 10900 - 10910 0 09/02/02 3-3/8" 6 10920 - 10980 0 OS/20/97 2-1/2" 6 13020 - 13070 S 05/16/97 I 7" CSG, 29#, 13CR NSCT, 10 = 6.184" 1-1 11134' 1 1 PBTO 1--4 13165' I 4-1/Z' lNR, 12.6#, L-80, 0.0152 bpf, 10 =3.953" l-f 13242' I ()/\ TE REV BY COIIJMENTS 01/24/97 ORIGINAL COM PLETION 08/13/01 RN/lP CORRECTONS 08120/02 OTRIKK MIN 10 CORRECTION 9/2-9/3!J2 CWS/KK AOÆRFS 05120/04 MJA/KAK A OÆRFS DATE REV BY I~ 1 1 P 1-09 8 L \ 0) I TUBING HANGER FIvC @ 30' MD 2135' 1-14-112" WRDP #HBS 603, SET 07/02/00, 10 = 3.75" 1 ~ GAS LIFT MANDRELS OEV TYPE VL V LA TCH 12 KBG2-LS BTM INT 48 KBG2-LS BTM INT 47 KBG2-LS BTM INT 49 KBG2-LS BTM INT PORT [}I\ 1£ I ST MD TVO 1 4053 4044 2 6279 5828 3 7771 6820 4 9882 8213 g Z>------i 9984' 1-1 7"X 4-1/2" BAKER S-3 PKR I I I D , [ ] I~ a COMI\tENTS 1 10008' 1-1 4-1/2" HES X NIP, 10 = 3.812" 1 1 10018' l-i 4-1/2"HESXNNIP, [)=3.725" 1 I 10031' l-f 4-1/2" TUBING TA IL W/WLffi 1 10041' 1-1 ELMDTTLOGGB:>05/19/97: 11034' 1--4 7" BAKER HIvC A<R 1 ~ 1 11152' 1-1 TOPOF CMTTAGGB:> 05/17/97 1 1 11775' 1-1 4-1/2" BAKERCBP 1 PRUDHOE BA Y UNIT WELL: P1-09 PE~rr No: 1961540 AA No: 50-029-22704-00 Sec. 16, T12N. R14E, 4017.47 ÆL 1162.45 FNL BP Exploration (Alas ka) ........__-......,.-..,,---"""""'-_-......-----~~----.----.._---~................__--...._--,.._----~..-..----~ P1..Q9TIO Plot 4.000 3.000 .. "........_....,-~"--_.- . lð~fi!-'---~----~~. ~ i 2,000.- ,...... ~ ......r...."'...:~:=::::::~~,~r-' ... Ct.. ........."""" . . .. ...... i."~'" .. ~~ JWi .~.... :. ...... 4 ..~. "," ~.., ¡~i..-6¡~.;... ,Hi" .... n 0 111712004 I 11/t7J2004 . I 311 712004 I 5tf7120ö4 ~.m..]-~. I 111.7/2005 ~- +Tb ........,. ,.IA ... OA . OOOA ,( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Repair Well 0 Pluq PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K] 4. Current Well Class: Stimulate 0 OtherD WaiverD Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 196-1540 Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 42.80 8. Property Designation: ADL-028298 11. Present Well Condition Summary: Total Depth Development Œ] Stratigraphic D 9. Well Name and Number: P1-09 10. Field/Pool(s): Pt McIntyre Oil Field 1 Pt McIntyre Oil Pool ExploratoryD Service D 6. API Number 50-029-22704-00-00 measured 13242 feet Plugs (measured) 11775 Effective Depth true vertical 10055.2 feet Junk (measured) None measured 11152 feet true vertical 9202.7 reet Casing Conductor Liner Production Production Surface Length 80 2215 9636 1468 4988 Perforation deoth: Size 20" 133# H-40 4-1/2" 12.6# L-80 7" 26# L-80 7" 29# 13CR80 9-5/8" 47# L-80 MD TVD Burst Collapse 35 115 35.0 115.0 2220 1320 11027 - 13242 9089.8 - 10055.2 8430 7500 30 - 9666 30.0 - 8073.0 7240 5410 9666 - 11134 8073.0 - 9186.4 8160 7020 34 - 5022 34.0 - 4933.4 6870 4760 Measured depth: 10580 -10630, 10650 -10660, 10735 -10785,10795 -10835,10860 -10885, 10900 -10910.10920 -10980 True vertical depth: 8709.39 - 8747.85, 8763.58 - 8771.52, 8832.54 - 8874.55, 8883.08 - 8917.64, 8939.65 - 8961.93, 8975.41 - 8984.43 8993.45 - 9047.53 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 30 RECEIVED 10031 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer 4-1/2" Camco WRDP-2 SSV 4-112" Liner Top Packer @ 9985 @ 2135 @ 11034 : I : . . '.', ') .' J n ~ f! 14 . ~íi~%t(a o.,~ ¿~ Gas Co . /~~ nS.COmm~- . '!!!6ch~, "YOIUn 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Qil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 4.5 6519 2200 Tubing Pressure 908 1332 1413 1751 6.4 4507 2200 15. Well Class arter proposed work: Exploratory D 16. Well Status after proposed work: Oil Œ] Gas D Development ŒI Service D WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Daily Report of Well Operations! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Garry Catron Garry Catron ,.(Jj ~ Cl.~ Contact Printed Name Signature Form 10-404 Revised 4/2004 Title Production Technical Assistant Phone 564-4657 Date 8/4/04 AUG 1 i iuH4 RØJMS Bfl ( P1-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY OS/20/04 Perforate 10580'-10630' 6 SPF, 10650'-10660' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 lREE= WELLHEA D = AClUA TOR = KB, B..B/ = BF. B..EV = KOP= flfax Angle = Datum MD = Datum lV D = -_? aw BAKER C 44.4' 4000' 78@ 11751' 10747' 8800' SS 9-518" CSG. 47#. L-80. ID = 8,681" H 5022' 7" CSG. 26#, L-80. ID = 6,276" H 9666' 1 TOP OF T' CSG H 9666' ~ Minimum ID = 3.725" @ 10018' 4-1/2" HES XN NIPPLE 4-1/2"TBG, 12.6#. 13CR-NSCT, -1 10031' 1 0,0152 bpf. ID = 3.958" 1 TOP OF 4-1/2" LNR 1-1 11027' 1 PERFORATION SUMMARY REF LOG: SPERRY GR1CNLtlD ON 10/14/96 A NGLE AT TOP ÆRF: 41 @ 10580' I\t)te: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE 3-3/8" 6 10580 - 10630 0 OS/20/04 3-3/8" 6 10650 - 10660 0 OS/20104 3-3/8" 6 10735 - 10785 0 OS/21197 3-3/8" 6 10795 - 10835 0 09/03/02 3-3/8" 6 10860 - 10885 0 09/03/02 3-3/8" 6 10900 - 10910 0 09/02/02 3-3/8" 6 10920 - 10980 0 OS/20197 2-1/2" 6 13020 - 13070 S 05/16/97 I 7" CSG. 29#, 13CR NSCT. ID = 6,184" 1-1 11134' I P 1-09 fi) L ~ ( I TLEING H6.NGER FMC @ 30' MD 2135' H4-112" WR[P#HBS 603. SET07/02/00,ID = 3,75" 1 ~ GAS LIFT MANDRELS DEV TYPE VL V LA Ta-i PORT DA. TE 12 KBG2-LS BTM INT 48 KBG2-LS BTM INT 47 KBG2-LS BTM INT 49 KBG2-LS BTM INT I ST MD TVD 1 4053 4044 2 6279 5828 3 7771 6820 4 9882 8213 :8: ~ 9984' I~ 7" X 4-1/2" BAKER S-3 PKR 1 I I 0 1 10008' I~ 4-1/2" HES X NIP. ID = 3.812" 1 1 10018' I~ 4-1/2"HESXNNIP,D=3.725" 1 0 1 10031' 1-1 4-1/2"TLEING TAIL W/WLEG 1 10041' 1-1 ELMDTTLOGGBJ 05/19/97 1 :8: ~ --I 11034' 1-1 7" BAKER HMC A<R 1 1 PBTD I~ 13165' 1 ~. 4-1/2"LNR.12.6#.L-80,O.0152bpf,ID=3.953" 1-1 13242' ~ DA TE REV BY COMMENTS 01/24/97 ORIGINAL COM PLETION 08/13/01 RN/W CORRECTONS 08120/02 DlR/KK MIN ID CORRECTION 9/2-9/3/02 CWS/KK A DÆRFS 05120/04 MJA/KAK A DÆRFS DATE REV BY COMMENTS ~ 1 11152' I~ TOPOFCI\TTTAGGBJ05/17/97 I 1 11775' I~ 4-1/2"BAKERCBPI PRUDHOE BA Y UNIT WELL: P1-09 PERMIT No: 1961540 A A No: 50-029-22704-00 Sec, 16. T12N. R14E 4017.47 FEL 1162.45 FNL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 11/11/03 NO. 3028 Company: State of Alaska Alaska Oil & Gas Cons Corem At'tn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD ~P1-02A _F~-~(..~.~..~ 10672311 RST-S,GMA 09/~4/03 G-12B ~"~, ;--~-/L/~ 10563472 MCNL 09~29~03 D.S. s-02~':~ ~ -~ ~055ss50 ~CNL 0S~0~03 D.S. 5-16~ ~--~ - ~ ~ 10558555 MCNL 06/16103 E-~4A (~ ~"1 ;~.~ ~0660~9 ,ST-S,~aA 0~/~2/03 P~-06 1~ ~- L-%~ ~067438~ ~ST-S,~MA ~0/04/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. RECEIVED Anchorage, Alaska 99508 Date Delivered: i~0V 24 200~) Gas L;ons. ~'nm~n Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FrN: Beth MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julie Heusser, z~' ,~\/" DATE: Commissioner John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-OI April 11, 2001: I traveled to BPX's Lisbume Gas Injection (LGI) and also on to the Point Mcintyre PM-01 location to witness Safety Valve Testing. The AOGCC SVS test reports are attached for reference. As noted 3 failures were observed on both pads; with 2 being repaired and mtested immediately. The third failure a sssv and will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crow did an excellent job. Summary: I witnessed the SVS tests on LGI and PM-01 LGi, 3 wells, 9 components, 1 failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failures, 6% failure rate Attachment; Svs bpx Igi 4-10-0 ljs Svs bpx pm-01 4-10-01js Non Confidential . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark W,,ysocki AOGCC Rep:, Jg,hn H' Spaulding Submitted By: John Spaulding_ Date: Field/Unit/Pad: ,,,Pt, Mclntyre/PBU/PM-01 Separator psi: LPS 460 HPS 4/9/01 - Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number P.SI , PSI Trip Code C,.ode Code Passed GAS or CYCLE 12 1910370 P1-02 1880050 P1-03 "'1~}0130 460 ~50 " 310 P P V "' OiL 'P1-04 'i930630 4604 "700 700 "'P P P ' 0I'~ P 1-05 1930870 460 350 300 P P 9 OIL Pl-06 1961370 460 700 675 P P P OIL P 1-07 1891340 P1-08 1930980 460 1500 1200 P P '13 OIL P~1~9~_.~? i~ 1961540 460 350 300 P P P OIL PI-11 1920860 460: 350 250 P P P OIL . Pl-12 1910130 Pl-13' 1930740 '460 ' ' 1500 " '1150 P - P' P ......... OIL Pl-17 1930510 460 350 280 P P P OIL P1-20" ' 1920940 ~60 350 175 3 P "' P ~/9'/01 OIL P1-2~ 196J240 .......... , , , P 1-24 1961490 Pl'-Gl" ' 192115'0 3600 2900 2850 P P' p ' GINJ Wells: 11 Components: 22 Failures: 2 Failure Rate: 9.09% I-! 90 var Remarks: P1-08 & P1-3 were choked back, hence the ~gl~,,er p, il0,t ,settings P1-20 pilot reset and retested RJF 1/16/01 Page 1 of 1 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Wysoeki AOGCC Rep: 'Jgk~n .H,:, Spaulding Submitted By: John Spauld'mg Field/Unit/Pad: 'Lisburne/PBU/LGI Separator psi: LPS Date: 4/9/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE , LGI-02 1861400 3800 2900 2300 _~ P P 4/9/01 GINJ LGI-04 1880130 LGI-06 1860670 3800 2900 2500 P P P GINJ LGI-08 18605~0 ........ LGI. 10 1860690 3800 2600' 2300 e P P ' GINJ , , LGI-12 1860540 , , , , Wells: 3 Components: 6 Failures: 1 Failure Rate: 16.67~A[[]~o Day Remarks: :.L.G, !-02 Pilot tripped to low and was reset-retested and pgs. s~ RJF 1/16/01 Page 1 of I 010409-SVS LGI Lisburne-js STATE OF ALASKA ALASK/' L AND GAS CONSERVATION COMMISf N REPOR'I OF SUNDRY WELL OPERATIL, NS · Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 3837' FNL, 750' FEL, Sec. 16, T12N, R14E At top of production interval 4150' FSL, 1425' FWL, Sec. 15, T12N, R14E At effective depth At total depth 1162' FNL, 4017' FEL, Sec. 15, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KB 42.88 feet 7. Unit or Property name Point Mclntyre 8. Well number P1 -O9 9. Permit number/approval number 96-154 / 10. APl number 500292270470 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: Effective Depth: Casing Conductor Surface Intermediate Liner true vertical: measured: true vertical: Length 110' 4988' Perforation depth: Size 20" 9 5/8" 11104' 7" 2215' 4 1/2" measured 10735-10785', 10920-10980' true vertical 8789-8831 ', 8950-9004' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# CR13-NSCT @ 0-10031' MD, Packers and SSSV (type and measured depth) 2 13242 feet 10055 feet 11152 feet 9203 feet Cemented Driven 1574 sx CS III & 333 sx 'G' 275 sx Class G 472 sx Class G x 7 PKR @ 9984' MD, 3 4/5 x 4 1/2 WRSSSV @ 2135' MD Plugs (measured) Junk (measured) None. None. Measured depth True vedical depth 110' 110' 5022' 4933' 11134' 9186' 13242' 10055' RECEIVED JUL 22 lggg Alaska Oil & Gas Cons. Commission Anch0r~tge 13. stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 150 10569 8061 0 1500 Tubing Pressure 1000 896 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations _~ Oil ~ Gas __ Suspended __ 17. I hereby certiJy, that the for.egoi[~g is true and correct to the best of my knowledge· Signed ~L~/~'g¢( ~/' Title Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~'~'"~'~'~ P1-09 DESCRIPTION OF WORK COMPLETED ADDED PERFORATIONS Date Event Summary 05-20-1997 05-21-1997 RIH w/3 3/8" HJ II guns and added perforations at: 10920' - 10980' MD All shots at 6 SPF, 60 deg phasing and random orientation. RIH w/3 3/8" HJ II guns and added perforations at: 10735' - 10785' M D All shots at 6 SPF, 60 deg phasing and random orientation. Well' P1-09 GPMA WEB Date' 4/16/99 WRSSSV -- PKR -- NIP -- NIP -- Per[ -- Per[ -- PKR -- TOP OF -- CEMENT CIBP Perf - APl: 500292270400 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Reference SPERRY Log: GPJCNL/LD Last Tag: 11152 SLMD-CORR Last Tag Date: 5/18/97 t Depth AnnotatiOns Well Type: PROD Odg Compltn: 1/24/97 Last W/O: Ref Log Date: 10/14/96 TD: 13242 ftKB Max Hole 78 deg @ 11751 Angle: Angle @ TS: deg @ Angle @ TD: 69 deg @ 13242 Rev Reason: SCH REVISION Last Update: 6/26/98 Depth Comment 10018 10,018' MIN ID (HES XN Nipple) General Notes; Date Note 11/3/96 Tubing Hanger: FMC @ 30' MD 11/3/96 Well Status: NEW Top Of Fluid Depth @ 10493 Last Tag Depth @ 13242 Other(plugs,equiP., etc,) - JEWELRY Depth 'rVD Type Description ID 2135 2131 WRSSSV 4-1/2" CAMCO BAL-O SVLN, ID=3.812"- W/WRDP SSSV (6/5/97) 3.812 9984 8281 PKR 7" X 4-1/2" BAKER S-3 PACKER 2.000 10008 8298 NIP HES X NIPPLE, ID=3.812" 3.812 10018 8304 NIP HES ×N NIPPLE, ID=3.725" 3.725 10031 8313 TT TUBING TAIL W/WLEG ( 10041' ELMD) 5.000 11034 9096 PKR BAKER HMC PACKER 6.000 11152 9203 TOP OF TOP CEMENT, TAGGED 5-17-97 7.000 CEMENT 11775 9607 CIBP 4-1/2" BAKER CIBP 8.000 casing:Strings: ' AIi~: ~: Size Weight Grade Top Btm Feet Description 7.000 26.00 L-80 0 9666 9666 PROD. CASING 9.625 47.00 L-80 0 5022 5022 PROD. CASING 7.000 29.00 13CR NSCT 9666 11134 1468 PROD. CASING 4.500 12.60 L-80 11027 13242 2215 LINER :TUbing strings: All :: : Size Weight Grade Top Btm Feet Description 4.500 12.60 CR13-NS, 0 10031 10031 TUBING G~: Lift: Mandrels/ValveS: Stn MD TVD Man Man VMfr VType rOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 4053 4043~,-KBG2-1 CA DKO-2 1.0 BTM 0.375 INT 2 6279 5828~,-KBG2-1 CA DK-1 1.0 BTM 0.000 INT 3 7771 6820~,-KBG2-1 CA DK-1 1.0 BTM 0.000 INT 4 9882 8213~,-KBG2-1 CA DK-1 1.0 BTM 0.000 INT 0 11/7/96 GLM 0 GLM 0 GLM 0 GLM Perforations:summary Interval TVD Zone Status FeetSPF Date Type Comment 10735 - 8833 - 8875 50 6 5/21/97 10785 10920 - 8993 - 9047 60 6 5/20/97 10980 13020 - 9976 - 9994 50 611/26/9~ P&S'd on 5/16/97 13070 STATE OF ALASKA ALASK/~-~ 'L AND GAS CONSERVATION COMMIS REPOR'I OF SUNDRY WELL OPERATluNS · Operations performed: Operation shutdown __ Stimulate __ Pull tubing __ Alter casing __ Plugging ~ Perforate __ Repair well __ Other __ Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 Location of well at surface FNL, FEL At top of production interval 4150' FSL, 1425' FWL, Sec. 15, T12N, R14E At effective depth At total depth FNL,FEL 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KB 42.88 feet 7. Unit or Property name Point Mclntyre 8. Well number P1-09TL 9. Permit number/approval number 96-154 & 193 / 397-087 10. APl number 500292270400 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Conductor Surface Length Size 110' 20" 4988' 9 5/8" 11104' 7" 2215' 4 1/2" Intermediate Liner 13242 feet Plugs (measured) 10055 feet 13165 feet Junk (measured) 10028 feet Cemented Driven 1574 sx CS III & 333 sx 'G' 275 sx Class G 472 sx Class G Perforation depth: measured 13020' - 13070' true vertical 9976' - 9994' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# CR13-NSCT @ 0-10031' MD Packers and SSSV (type and measured depth) 2 X 7 PKR @ 9984' MD, 3 4/5 x 4 1/2 WRSSSV @ 2135' MD None. None. Measured depth 110' 5022' 11134' 13242' True vedical depth 110' 4933' 9186' 10055' RECEIVED JUL 22. 1999 Alaska 0il & Gas Cons. Commi~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. ORI61 ]AL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 317 2500 486 2100 793 0 0 0 150 1000 I 16. Status of well classification as: Oil~x Gas __ Suspended __Service 5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby cedi~that thcCore.(~oing is. true and correct to the best of my knowledge. g , Title ~;Jv'(L,~/~ Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P1-09TL DESCRIPTION OF WORK COMPLETED SET ClBP AND CEMENT PLUG 'Date Event Summary 05-16-1997 05-17-1997 Set ClBP and Cement Plug. MIRU CTU. PT'd to 4000 psi then RIH w/CT-mounted CIBP. CIBP set at 11775' MD. The plug was then placed on the CIBP using 9 bbls Class G Cement. Estimated cement top at 11185' MD. Tag Cement Plug top at 11152' MD RKB w/3.625" Cent. Tested Plug to 2500 psi for 30 minutes. Well: P1-09 WRSSSV PKR 'NIP NIP Perf Per[ PKR TOP OF CEMENT CIBP Per[ GPMA WEB Date' 4/16/99 APl: 500292270400 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Reference SPERRY Log: GPJCNIJLD Last Tag: 11152 SLMD-CORR Last Tag Date: 5/18/97 DePth Annotations Well Type: PROD Odg Compltn: 1/24/97 Last W/O: Ref Log Date: 10/14/96 TD: 13242 ftKB Max Hole 78 deg @ 11751 Angle: Angle @ TS: deg @ Angle @ TD: 69 deg @ 13242 Rev Reason: SCH REVISION Last Update: 6/26/98 Depth Comment 10018 10,018' MIN ID (HES XN Nipple) General Notes ID 3.812 2.000 3.812 3.725 5.0OO 6.000 7.000 Date Note 11/3/96 Tubing Hanger: FMC @ 30' MD 11/3/96 Well Status: NEW Top Of Fluid Depth @ 10493 Last Tag Depth @ 13242 Other (plugs,.equip., etc.) - JEWELRY Depth TVD Type Description 2135 2131 WRSSSV 4-1/2" CAMCO BAL-O SVLN, ID=3.812" - W/WRDP SSSV (6/5/97) 9984 8281 PKR 7" X 4-1/2" BAKER S-3 PACKER 10008 8298 NIP HES X NIPPLE, ID=3.812" 10018 8304 NIP HES XN NIPPLE, ID=3.725" 10031 8313 'IT TUBING TAIL WNVLEG ( 10041' ELMD) 11034 9096 PKR BAKER HMC PACKER 11152 9203 TOP OF TOP CEMENT, TAGGED 5-17-97 CEMENT 11775 9607 CIBP 4-1/2" BAKER CIBP 8.000 Casing Strings,Al! ~ :i : Size Weight Grade Top Btm Feet Description 7.000 26.00 L-80 0 9666 9666 PROD. CASING 9.625 47.00 L-80 0 5022 5022 PROD. CASING 7.000 29.00 13CR NSCT 9666 11134 1468 PROD. CASING 4.500 12.60 L-80 11027 13242 2215 LINER l'ubing strings, All i Size Weight Grade Top Btm Feet Description 4.500 12.60 CR13-NS, 0 10031 10031 TUBING Gas LiffMandrels/Valves Stn MD TVD Man Man VMfr VType Mfr Type I 4053 4043~,-KBG2-1 CA DKO-2 2 6279 5828~,-KBG2-1 CA DK-1 3 7771 6820~,-KBG2-1 CA DK-1 4 9882 8213~,-KBG2-1 CA DK-1 V OD Latch Port TRO Date Vlv Run Comment 1.0 BTM 0.375 0 11/7/96 GLM INT 1.0 BTM 0.000 0 GLM INT 1.0 BTM 0.000 0 GLM INT 1.0 BTM 0.000 0 GLM INT PerforationsSummary Interval TVD Zone Status FeetSPF Date Type 10735 - 8833 - 8875 50 6 5/21/97 10785 10920 - 8993 - 9047 60 6 5/20/97 10980 13020 - 9976 - 9994 50 611/26/9~ 13070 Comment P&S'd on 5/16/97 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 01/21/99 RUN RECVD 96-154 GR/RES-MD ~L~'5032-13240 FINAL 01/15/97 96-154 96-154 96-154 C~P/DGR/SLD-MD ~5032-13240 C~P/DGR/S~,D-TVD y'4941-10054 GR/RES-TVD ~941-10054 FINAL 01/15/97 FINAL 01/15/97 FINAL 01/15/97 96-154 BHP/GR ~11133-13238 96-154 SSTVD/LDT/CN ~9140-10010 96-154 LDT/GR 'J~?ll133-13238 96-154 LDT/CN/GR '~/i1133-13238 96-154 CN/GR ~iL/ 11133-13238 96-154 CBL/VDT ~9684-11040 96-154 7911 ~CHLUM LDT/DN/GR 96-154 7624 ~PERRY GR/RES/CNP/SLD 96-154 DIRSRVY L~'0-13242 ~\ !! ~L 1- 96-154 STAT PRESS SRVY ~10580-11021 96 - 154 CNTD ~/f~l 0450 - 11021 96 - 154 8133 ~S CHLUM CNTD 96-154 SRVY RPT ~'~ PERRY 0-12537. FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 02/14/97 2-13 03/05/97 03/24/97 1 07/03/97 FINAL 10/02/97 1 10/02/97 SPERR 06/19/98 10-407 R COMPLE~IO~ DAT~, ~ /~/~ ?/ DAILY WELL OPS R /[3/ ) /~I ~/ TO ///~?/~?$ / Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~,Analysis & description received? Are well tests required? ,~~o Well is in compliance Initial COMMENTS Received? ~._~o I:) F! I I._/I ~ G S J:: i~UI r' E S 02-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well P2-09 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 12,537.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) JUi- 'I, q ,~aska Oil & Gas Cons. Commission A~orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563°7252 A Division of Dresser Industries, Inc. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11394 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area 9/3O/97 Floppy Well Job # Log Description Date BL RF Sepia Disk P1-09 97316 CNTD ~ <~ I ~"~ , ,970521 ,, 1 1 1 ,, .... SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. OCT 0 2 1997 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11122 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area All Lisburne Wells (Incl NK-25 &NK-26) 7/3/97 Floppy Well Job # Log Description Date BL RF Sepia Disk P 1-09 STATIC PRESSURE SURVEY 9 7 0 5 21 I I ., ..... ...... ......, SI G N E D: _~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. .HORAGE FAX NO.: 2634894 -' STATE OF ALASKA ' AL. . A OIL AND GAS CONSERVATION OOMMI~,_ , 2N APPLICATION FOR SUNDRY APPROVALS 85-85-97 14:88 P .03 ~l, type of Request: Abandon ~ Alter oaslng __ Repafr well _ Change ..a.,uproved programM 2. Name of Operator ARCO Alaska, Inc. SuspendedX__ 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1438' NSL, 752' WEL, Sec. 16, T12N, R14E At top of production interval 4150' NSL, 1425' WEL, Sec. 15, T12N, R14E At effective depth Al total depth 4128' NSL, 1251' WFL, Sec. 15, T12N, R14E Pull tubing __ .-- Variance __ 5. Type of Well: Development ~ Exploratory __ Stratigraphi~ __ Service ~ Operation Shutdown .._ Re-enter suspended well _ Plugging _X. Time extension Stimulate Perforate _ Other M 6. Datum elevation (DF or KB) 8800 7, Unit or Properly name Point Mclntyre 8, Well number P1-09 Tail 9. Permitnumber 96-154, 96-193 10. APInumber 50-029-22704-00 11. Field/Pool Point Mclntyre f~_t 12. Present well condition summary Total Depth: measured: true vertical: 13242 feet 10055 feet Plugs (measured) None. Effective Depth: measured: true vertJcah Casing Length Conductor I 1 0 4988 Surface 20" 9 13165 feet Junk (measured) None. 10028 feet Cemented Measured depth Driven 110 1574 sx OSlll, 333 sx "G" 5022 True vertical depth 110 4938 Intermediate 11104 7" 275 SX Class "G" 11134 9186 Liner 221 5 4-'12" 472 SX Class "G" Perforation depth; measured 13020-13070' true vertical 9976-9994' Tubing (size, grade, and measured depth) 4-1/2" 12,6# CR13-NSCT 10031' Packers and SSSV (type and measured depth) Baker S-3 Packer 9~84', Baker HMC Packer 11034', Camco SSSV 2135' 13242 1 0055 13. Affachments Description summary of proposal x Detailed Operation program __ BOP sketch __ 4. Estimated date for commencing operation 115. Status of well classification as: ./~ ~' 7,~ / ~-1 ~/?! Oil X Gas Suspended 6, If proposal was verbally approved Name of approver Date ap~r~ved .J Service ,7. I hereby c~fy~_...,/. //"' ,/~/('that~~g~ing is true and correct to the best of my knowledge. ~ i,gn~~ ,,.,c/,.- Title '.~'/~ ~ 1/~ FOR COMMISSION USE ONLY Conditions of approval', Notify Commi.~sion .~o representative may witness Plug inlegrity ~ BOP test ~ Location clearance Mechanical IntegrHy Test ~ Subsequent for required 10- t,¢ (~ Original Signed An_nrdv~d h¥ order of the Comrrlission ...... n . :., ,,, ,-,~,--~- Commi.~.~ioner Date L/C. VIM YV. UUJlII,3LUll Form lO-403 Rev 06/15/88 Approved Copy Returned ORIGINAL J Approval SUI~MIT IN TRIPLICATE ,~ORAGE FR× NO.: 2634894 Larch Test Well 85-85-97 14:88 (P1-09) Application for Sundry Approval Recommended P&S Procedure Objective: , Following two unsuccessful Coil Tubing Unit cement squeeze attempts on April 25 and 27, 1997 (as discussed below) it is requested that the Larch Test Well be plugged and suspended with a Halliburton EZ Drill SV Squeeze Packer set with E-Line as deep as it can be run. This depth is expected to be approximate 11,705' MD which was the maximum depth of a slickline run on 4/23/97 due to well deviation and dog leg severity. A 10' sand cap will be placed on the EZSV and a cement plug placed from that depth to no shallower than 11,150' MD to insure adequate rat hole. It is expected that the cement cap will be 8 bbl (650' in 4-1/2" liner) in volume or less if the plug can not be run deeper. A proposed procedure is listed below. , The reason a plug and suspension status is requested is that the Ivishak interval in the well will not currently produce economically. We plan to leave the test interval suspended in such a fashion that should production and economic factors change, the Working Interest Owners would have the option to re-establish production from the test interval as well as the Sag River formation. , In the event the lower wellbore is not re-entered prior to the planned plug and abandonment of the entire wellbore, tlqe proposed plug back operations for the 4-1/2" tail section, will fulfill the plug and abandonment requirements and intent of regulations in 20 AAC 25.105. Pressure tests on both liner and the 7" production casing prior to perforating have confirmed shoe integrity and thus zonal isolation. P .04 r'^'''' 5 i997 4': ."-,~ ! ~SJ~ 0it .& Gas {Cons. Page 1/:2 .~OR~GE F~X NO,: 2634894 Previous___.w_ork f_l ~.r Sundry Approval No, 3_9.7.,~( 85-85-97 14:89 P.05 Dated 4/1 I , The first CTU cement squeeze attempt on April 25, 1997 was unsuccessful because the CT got stuck on bottom following pumping cement. The cement was washed from the well with slick Biozan fluid and the CT could then be pulled from the well. The welJ has several severe dog legs over 19°/100, which caused the sticking problem. In addition, the formation was found to be very tight with an injection rate of 0.45 BPM at 3700 psi at murface, This high pressure limited the pull which can be put on the CT. The second squeeze attempt on April 27, 1997 was also unsuccessful after trying to breakdown the formation and to use a slick fluid to reduce friction on the coil. No cement was pumped because of high pick-up weight even with the slicker Biozan fluid. The following procedure is recommended to complete the suspension /abandonment of the 4-1/2" tail. Intended Procedure: I . RU Slickline, drift tubing and run dummy EZ Drill SV tool string with 3.66" OD to maximum depth possible. Assure gas is eliminated from the wellbore, Load annulus with diesel/crude as needed. . Notify the AOGCC 24 hours prior to commencing each of the following E- Line and CTU operations. , RU E-Line and set EZ Drill SV to maximum depth possible in 4.5" 12.6# L-80 liner. OD of tool is 3.66" with wells minimum ID of 3.725" at XN nipple, . RU CTU. Lay in a 10' sand cap and cement plug (use lightweight class "G" P&S cement) from to no shallower than 11,150' MD to insure adequate rat hole. it is expected that the cement cap will be 8 bbl in volume or less if the plug can not be run deeper. , woe 12 hours, PT cmt plug to 0.25 psi/ft (2500 psi) or other as required by AOGCC. (Pressure test to be witnessed by AOGCC Representative). Tom J, Walker 263-4496 May 5, 1997 r .,* ,-, ;/ "'" ~" ;99~' 4./85...~ .0JJ .& .688 00n8, Page 2/2 ,4CHORAGE FAX NO.: 2634894 05-05-9? 14:09 P.06 AR~-O Alaska, In(;, - GPMA WELL SC~-~MATICS A P I #: 50029~70400 Completion: 11/03/96 Hanger Type: FMC 7B-' ,: P1-09 .pud Date: 10/03/96 Original RKBE: 44' Top of Formation: Max Hole Allgle: Annular Fluid: DIESEL TO 2500'; w/6.5 SEAWATER BELOW Reference Log: Date: NOTE: Jewelry (J) MD Description 1 2135' 4-1/2" CAMCO BAL-O SSSV, ID=3.812", W/O DUMMY 2 9984' 7" X 4.-1/2~ BAKER S-3 PACKER 3 10008' HES X NIPPLE, ID--3.812' 4 10018' HES XN NIPPLE, ID--3.7;~5" ~ 10031' TUBING TAILW/WLEG 6 11034' BAKER HMC PACKER Mia ID: 3.75" HES XN NIPPLE AT 10018' MD Workover: MD: 1 ~751' Tie In: ICAT I - SSSV I J-1 C-1 G-1 Type: PRODUCER Statug: NE'W Hanger: 30' Angle @ TF: Angle O TO: 70~ Date: JiH2S (ppm) Bottom Description 50_~P_2.D~. CASING 96_~6' CASING 11134' CASING 13242' LINER 10031' 'TUBING Casing and Tubing (C) Size Weight Gratle Top _1 9 5lB" 47fi L-SO O' .. 2 ?" 26# L-80 0' 3 7" 29# 13CR NSCT 9666' 4 4 1/2" 12,6# L-80 11017' 4 1/2" 12.6# CR13~NSCT 0' C-3 J-3 ~) J-5 Mandrel Information (I,G,M) Desc MD TVD ~tn Mandrel GLM 4053' (404.4} 1 CA-KBG2-LS GLM 6279' (5828) 2 CA-KBG2.LS GLM 7771' (6B20) 3 CA-KBG2-L$ GLM 9882' (8213) 4 CA-K~G2.LS Perforation Data (ELM Depths) (P) Interval Zone FT 1 13020'- 13070' }vishak 50' Datum 6800' SS-- 10749' IVD PBTD= 13165' MD 8900' SS= 10865' MD 'rD= 13242' ~ ODValve Type Latch Port TRO Date 1,0" CA DKO-2 8TM INT 3/8" 11/07/96 1.0" CA OK-1 BTM INT 1,0" CA DK-1 BTM INT 1.0" CA DK-1 BTM INT SPF Date Comments 6 11/26/96 60" PHASE, 2-1/Z' GUNS 10,5 gm HMX )$oroo~ Tag = ~ MD Type; ~ c,-~'~ Date: Oil.& (~as Cons. C0rnmis,,,, Revleion Pete: 03112/97 Ravlalon No: 4 ~HCHORRGE FAX HO.: 2654894 05-05-9? 14:09 P.O? 30,1300~ (S1D,), 8~:12. 3'1397 2_60' O.D., (66.0 mm) MAX, TOOL O,D---'"---- (93,O mm) BRI~~ PLLIG ~34.8 mm) 7" O.D. (602 mm) .62" I.D. (4t,1 mm) (635_0 mm) (:~_'~ mm) MAXIMUM CASING I.D. 4,0~ (103.9 mm) (4¥~'-9.5#) (114 mm - 14.14 kg/m) ,~I'ROKE TO 8El" IN 4'~' 9.,5-~ (4.090" I,D,) (10~.9 mm) 4.0' (102 mm) PACKAGED SHIPPING WEIGHT 41 POUNDS * ~ IF REQUIRED BY STRENGTH CHARACTERI.5'13CS OF RIG OR TUBULAR GOODS. EZ DRILL SV SQUEEZE PACKER 4~/~" 9.5-13.5# CASING 4~4' 16# 5~-20,3-24~2# 51/~" 36.4~ HHCHORRGE FI:IX HO.: ARCO Alaska, In(:. Post Office 8u~ ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 2634894 85-85-97 14:88 P .02 May 5, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 via fax and mail Prudhoe Bay Unit - ADL 028297 Completion of Tract Operations Well P1-09 APl #50-02g-22704-00 Dear Mr. Johnston: ARCO Alaska, Inc. completed production testing operations on the P1-09 Tract well on February 23, 1997. Attached please fend Form 10-403 requesting AOGCC approval for us to proceed with plugging and suspension of the test interval in order to recomplete the well in the Point Mclntyre Oil Pool. Current plans do not include the testing of the Sag River formation at this time. We plan to leave the test interval suspended in such a fashion that should production and economic factors change, the Working Interest Owners would have the option to re-establish production from the test interval as well as the Sag River formation. ' In the event the lower welibore is not re-entered prior to the planned plug and abandonment of the entire wellbore, the proposed plug back operations for the 4-1/2" tail section, will fulfill the plug and abandonment requirements and intent of regulations in 20 AAC 25.105. Pressure tests on both liner and the 7" production casing prior to perforating have confirmed shoe integrity and thus zonal isolation. If you have any questions, please feel free to call Tom Walker at 263-4496. Sincerel , J. W. Groth CC: J. F. Branch (Exxon) J. A. Leone (ARCO) I. Springett (BPXA) vix~. .5 ]997 ,Oil .& Was 6ons, ~ch0rage ORIGINAL ANCHORAGE FAX NO.: 7~0 'G* 2654894 05-05-97 14:08 P .01 GREATER POINT MclNTYRE AREA t. Acsnvnct very (~)~) 2~s~8 DAT'I: ~ ~ER OF FA~ C ,. 7 m .. II II II _ . I Il ORIGINAL N~IAY 6 1~7 ~!a~;~ .Oit.&/~a$ Cons. CommiSs' 9 6 --- 1 54. 96 . '154 o, 6 -~ i 54. 9 6 ,,- 'i 5 a. 96 ..... i54. .:. 98 --~ i 5 'i'v'[dua] We]] t:: e r" '~ a 1 s :I: n v ,.'.~ n 't: o r' y DA"rA T DATA .... F'I...US ,.'.ii I-:-: / F,' [-~i S .... H D Z5032 ..... 132/4. 0 . C: N f:'/' P ,iii F:/:{?., L [.': .... t,.i D .,~. 5032 -.- i 3240 ,:? i".! F'/' il:, ,:ii F,,' / S !.. E ..... TVI5 L~.494 1 .... 1005 ~ ~l ~ "^' ,-- ..,,~1 '1 "~ ....., I:!,HI,/:..~R I33 .... i3z ~8 1133 13238 ~i 133-~'13°38 ~'~- 133 .... 13238 79 '1 '1 ~,:£ FI L IJ H k D iF//' g' N / G R ~ r'N p/S LD '/62/: E iq R \/ G R / R E S / .~ ~,l 'l 3 2 4 2 P a,:~j e; 1 Da"ce; 04/~0/a7.:, ,., RUN DA'FE_RECVD F Zr, AL o 'i /'i 5 / 9 7 FZNAL. 0i/'15/97 FZNAI.... 01/15/9'? F .]:1 N A !.. 01 / 'i 5 ,/97 F T. NA!. 02/1a/'97 FINAl ....02/i4/97 FZNAL 02/14/'97 F ..T. i"q A !.. 02/ 'l 4 ,; 97 FZNA~ 0°' a. "97 ,~. ~/'i /... FZNAL.. 02/'14/ ,. 02/I 4/¢9'? 2 ....... 13 03//05//97 03/04 ' ..,.. /97 / ~NCHORAGE FAX NO. : 2634894 04-14-97 STATE OF ALASKA ALA~r,A OIL AND GAS CONSERVATION COMMISSIC APPLICATION FOR SUNDRY APPROVALS ri. Type of Request: Abandon SuspendedX__ Operation Shutdown __ Re-enter suspended well __ 09:05 P .02 Alter caslng _~ Repair well m Plugging _Y,__ Chanl]e approved program _ Pull tubing{...,, variance _ 2. Name o! Operator IS. Type of Well: ARCO Alaska, Inc. / Development ...... ~ Exploratory 3. Address J Stratigraphic P,O. Box 100360, Anchorage, AK 99510 { service Time extension Stimula. te Per/orate Other ~ 6. Datum elevation (DF or KB) 8800 7. Unit or Property name Point Mclntyre 4. Location of well at surface 1438' NSf_, 782' WEL, Sec. 16. T12N, R14E At top of production interval 4150' NSL, 1425' WEL, Sec. 15, T12N, R14E At effective depth At total depth 4128' NSL, 1251' WEL, ,.SEC. 15, T12N, R14E !2. Present Well condition summary Total Depth: measured: true vertical: Effective Depth: measured:. true vertical: Casing Length Size · Conductor 110 20" 4988 s 9- !~" Surface Intermediate · =,* 11104 7" Liner :' 2215 4-'1~" Perforation depth; measured 13020-t 3070' true vertical 9976-9994' Tubing (si4e, 9rads, and mea,~ured depth) 4-1/2" 12.6# CR13-NSCT 10031' 8. Well number P 1-09 Tail 9, Permit number 96-154, 96-193 10. APl number 50-029-22704-00 11. Field/Pool Point Mclntyre 13242 feet Plugs (measured) None. 10055 feet 13168 feet Junk (measured) None. 10028 feet Cemented Measured depth Driven 110 1574 sx 09111, 333 sx "G" 5022.. True vertical depth 110 4938 275 sx Class "O" 11134 9186 472 sx Class "G" 13242 10055 RECE VE APR 1 4 1997 Alaska 0ii & (Jas Cons..6.~_[0~[s_S~t~ Packers and 888V (type and messured depth) Baker S-3 Packer 9984', Baker HMC Packer 11034', Camco SSSV 2135' 13. Attachments Description summary of proposal ~ Detailed operation program __ BOP sketch 14. Estlmated date for commencing operation.,,/,_/ .-/f/,f/¢/ 7 6. If proposal was verbally approved Name of approy.?,,r Cate approved 7. I hereby cer__~hat..th~fo~egoing,/is lrue Snd correct to the best of my knowledge. FOR COMMISSION USE ONLY t15. St,3,tUS of well classification as: Oil X Gas ~ Suspended ..... Service .... ConditiOnS of approval: Notify Commission $o representative m~y witness Plug integrity ~ BOP test ~ Location clearance Mechanical Integrity Test~ Subsequent for req'"~ired 10- Date '~-/ ,!g,l~a, Signed By Oavid W, C0mmis-~inner ~,.nprnv~d hy order of the Commis.~ion J Approval Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~NCHORAGE FAX NO.: 2634894 84-14-97 09:06 P.05 Larch Test Well (P1-09) Application for Sundry Approval Recommended P&S Procedure . It is requested that the Larch Test Well be plugged and suspended with a cement plug placed to 12,920' MD or 100' MD over the top perforation at 13020' MD. , The reason a plug and suspension is requested is that the Ivishak interval in the well will not currently produce economically. We plan to leave the test interval suspended in such a fashion that should production and economic factors change, the Working Interest Owners would have the option to re-establish production from the test interval as well as the Sag River formation. I n t e n d ed_P_r_o_c_e_~ r e: , RU Slickline, drift tubing if necessary. Load annulus with diesel/crude to eliminate gas from the wellbore. 2. Notify the AOGCC 24 hours prior to commencing operations. , RU CTU. Lay in a cement plug from PBTD to 12,200' and squeeze up to 26 bbls cement behind pipe (_+35 bbls lightweight class "G" P&S cmt required), Cement top should be between 12,500' and 12,920' MD. Top open perf is at 13,020' MD. , WOC 12 hours. PT cmt plug to 0,25 psi/ft (2500 psi) or other as required by AOGCC. (Pressure test to be witnessed by AOGCC Representative). Tom J, Walker 263-4496 April 14o 1997 Alaska 0il & Gas Cons, ~choraga ~NCHORAGE FAX NO.: 26~4894 04-14-97 09:06 r~ ARCO~'- "asks, Inc. - GPMA WELL SCHE~' '~'ICS .,: P1-09 APl#: 500292270400 Type: PROOUCI:R =pud Date: 10/03/96 Completion: 11/03/96 Workover: Statue: NEW Original RKBE: 44' Hanger Type: FMC Hanger: 30' Top of Formation: Max Hole Angle: 78° MD;11751' Angle ~ TF: Annular Fluid: DIESEL TO 2500', W/ 8,S SEAWATER BELOW Angle I~ TD: 70° Reference Log: NOTE: C-3 J-2 J-3 J-4 J-6 C-2 Data: Tie In: Date: Jewelry (j) ICAT I - $SSV MD Description 1 2135' 4-1/2" CAMCO EtAL-O $S$V. ID--$.81g", W/O DUMMY ;2 9984' 7- X 4-1/2' BAKER S-3 PACKER J-1 3 10008' HESX NIPPLE, ID--3.81~- 4 10018' HE$ XN NIPPLE, ID--3,725" 5 10031' TUBING TAIL W/WLEG C-1 6 11034' BAKER HMC PACKER Min ID: 3-75" HES XN NIPPLE AT 10018' MD G-1 Casing and Tubing (C) size Weight Grads Top 1 9 $/8" 47# L-80 o' 2 7" 26~ L-8O 0' ,3 7" 29# I~K;R NSCT 9666' 4 4 1/2" 12.6# L-80 11017' 4 1/2" 12.6# CR13-NSCT Mandrel Information Des= MD TVD San Mandrel GLM 4053' (4044) 1 CA-KBGZ-LS GLM 6279' (5a28} 2 CA-KBG2-LS GLM 7771' (6820) 3 CA-KBGZ-LS GLM 98a2' (8213) 4 CA-KBG2-LS Perforation Date (ELM Depths) (P) Intecvel Zone FT 1 13020'- 13070' Ivishak 50' Datum 8flOC' ~$ _- I074~)' ~ PBTD=- 13165' IV~ 8900' SS-- 10865' IVD 'I'D= 13242' N~ IIH2S (ppm) Bottom Description ~020' CASING 9666' CASING 11134' CASING 13242' LINER 10031' TUBING ODValve Type Latch Port TRO Date ~ .0" CA DKO-2 I~TM INT 3/8" 11/07/96 1.0" CA DK-1 BTM INT 1,0" CA OK-1 BTM INT 1.0" CA DK-1 BTM INT SPF Date Comment~ 6 11/28/96 60" PHASE, 2-1/2" GUNS 10.5 gm HMX Tag = 11708' MD Type: SLMD Date; 02/28/97 APR ] 4 ]997 Oit .& Gas Cons. uornrm~- , Anchorage P .04 IRavi~ion Date, 03i12i97 Revision No: 4 -- -- STATE OF ALASKA ALASK/-, ,..,-AND GAS CONSERVATION CO,,/~ivlISSION 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 Inc. 96-154 96-193 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1438' NSL, 752' WEL, SEC. 16, T12N, R14E At top of productive interval 4150' NSL, 1425' EWL, SEC. 15, T12N, R14E At total depth 4128' NSL, 1251' EWL, SEC. 15, T12N, R14E 8. APl Number 50-029-22704 9. Unit or Lease Name Point Mclntyre 10. Well Number P1-09 11. Field and Pool Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 43' I ADL 028298 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 10/03/96 I ~ 0/29/96 I 11/26/96 I N/A MSLI One 17. Total'"'bepth (MD+TV~) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSS.,V set121. Thickness of Permafrost 13242 10055 FTI 13165 10028 FTI []Yes []No I 2135 MD! 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, DIR/FE, CBT, CBL, CNL, GR/RES/DEN/NEU 23. CASING SIZE 20" 9-5/8" ,1 11 4-1/2" WT. PER FT. CASING, LINER AND CEMENTING RECORD 133# 40# 26# 29# 12.6# GRADE H-40 L-80 L-80 13CR80 L-80 SE-FrING DEPTH I HOLE TOP BO-FrOM I SIZE Surface 110' I 30" 34' 5022' I 12-1/4" 30' 9666' I 8-1/2" 9666' 11134'I 8-16!2" 11027' 13242' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD 13020'-13070' 9976'-9994' MD TVD CEMENTING RECORD AMOUNT PULLED Driven 1574 sx Coldset III, 333 sx 'G' 275 sx Class 'G' 472 sx Class 'G' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, 13CR80 10031' 9985' 26. ACID. FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/151 bbls diesel to 2500' 27. Date First Production January 24, 1997 PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Gas Lift OIL-DEL WATER-DEL Date of Test IHours Tested I PRODUCTION FOR /TEST PERIOD · Flow TubinglCasing PressurqCALCULATED . Press. I ~24-HouR RATE 28. OIL-BBL IGAs-MCF GAS-MCF CHOKE SIZE I GAS-OIL RATIO WATER-DEL OIL GRAVITY-APl (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marke, 30. . ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Kuparuk River 10499' 8648' Sag River 12763' 9883' Shublik 12876' 9924' Ivishak 13055' 9989' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed "'~Ld¢--- ~:~,~ ~ ,=~/~¢/'~'~ SteveShulLz ^ Title Senior Drilling Engineer Date - - ~'~" ' ' "J Prepared By Name/Number: Kathy Campoamor, 564-5122 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 §: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility Pt Mac 1 Well P1-09 Rig Doyon 14 Page 1 Date 13March97 Date/Time 03 Oct 96 06:00-10:00 10:00-12:30 12:30-13:30 13:30-15:00 15:00-17:00 17:00-17:30 17:30-06:00 04 Oct 96 06:00-06:00 05 Oct 96 06:00-08:00 08:00-09:00 09:00-09:10 09:10-10:00 10:00-06:00 06 Oct 96 06:00-12:00 12:00-13:00 13:00-13:10 13:10-15:00 15:00-16:00 16:00-17:30 17:30-17:40 17:40-19:30 19:30-21:00 21:00-21:15 21:15-05:30 07 Oct 96 05:30-06:00 06:00-07:00 07:00-07:15 07:15-08:00 08:00-09:30 09:30-10:00 10:00-11:30 11:30-11:45 11:45-12:00 12:00-13:15 13:15-14:00 14:00-14:30 14:30-15:00 15:00-16:30 16:30-17:00 17:00-19:00 19:00-20:00 20:00-21:30 21:30-01:30 08 Oct 96 01:30-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-10:00 10:00-12:00 12:00-12:30 12:30-13:00 13:00-15:00 Duration 4hr 2-1/2 hr lhr 1-1/2 hr 2hr 1/2 hr 12-1/2 hr 24 hr 2hr lhr 0hr 3/4 hr 20 hr 6hr lhr 0hr 1-3/4 hr lhr 1-1/2 hr 0hr 1-3/4 hr 1-1/2 hr 1/4 hr 8-1/4 hr 1/2 hr lhr 1/4 hr 3/4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 1-1/4 hr 3/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr lhr 1-1/2 hr 4hr 2-1/2 hr lhr lhr 1-1/2 hr lhr 1/2 hr lhr 2hr 1/2 hr 1/2 hr 2hr Activity Rig moved 100.00 % Fill pits with Water based mud Rigged up Kelly Washed to 110.0 fl Made up BHA no. 1 Held safety meeting Drilled to 1115.0 ft Drilled to 3289.0 ft Drilled to 3445.0 ft Circulated at 3445.0 ft Flow check Pulled out of hole to 1800.0 fl Drilled to 4750.0 ft Drilled to 5030.0 ft Circulated at 5030.0 ft Flow check Pulled out of hole to 1070.0 fl R.I.H. to 5030.0 ft Circulated at 5030.0 ft Flow check Pulled out of hole to 1070.0 ft Pulled BHA Held safety meeting Ran Casing to 5019.0 ft (9-5/8in OD) Circulated at 5019.0 ft Circulated at 5020.0 ft Held safety meeting Rigged down Casing handling equipment Ran Drillpipe in stands to 3950.0 fl Ran Drillpipe to 4935.0 ft (5in OD) Circulated at 5020.0 ft Held safety meeting Pumped 70.000 bbl spacers - volume (null) Mixed and pumped slurry - 615.000 bbl Mixed and pumped slurry - 90.000 bbl Displaced slurry - 80.000 bbl Circulated at 4930.0 ft Pulled Drillpipe in stands to 1080.0 fl Laid down 1080.0 ft of Drillpipe Rigged down Additional services Installed Casing spool Rigged up BOP stack Tested BOP stack Made up BHA no. 2 R.I.H. to 2945.0 ft Serviced Block line R.I.H. to 4936.0 fl Circulated at 4936.0 ft Tested Casing - Via annulus and string Held drill (Kick (well kill)) Drilled to 5080.0 ft Circulated at 5080.0 fl Performed formation integrity test ~z, o ~'f5 g-t'4 i~,~ Circulated at 5020.0 ft Facility Pt Mac 1 Progress Report Well P1-09 Page 2 Rig Doyon 14 Date 13 March 97 Date/Time 09 Oct 96 10 Oct 96 11 Oct 96 12 Oct 96 13 Oct 96 14 Oct 96 15:00-01:30 01:30-02:00 02:00-02:30 02:30-03:00 03:00-03:30 03:30-06:00 06:00-17:00 17:00-18:00 18:00-18:10 18:10-20:30 20:30-22:00 22:00-23:30 23:30-02:00 02:00-06:00 06:00-00:30 00:30-01:00 01:00-01:10 01:10-01:50 01:50-02:30 02:30-06:00 06:00-20:30 20:30-21:30 21:30-21:40 21:40-23:30 23:30-01:00 01:00-04:00 04:00-06:00 06:00-09:30 09:30-11:00 11:00-11:10 11:10-15:00 15:00-16:30 16:30-18:00 18:00-19:30 19:30-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-20:30 20:30-21:30 21:30-22:00 22:00-22:30 22:30-02:30 02:30-02:40 02:40-03:15 03:15-06:00 06:00-10:00 10:00-10:30 10:30-11:30 11:30-11:45 11:45-12:00 Duration 10-1/2 hr 1/2 hr 1/2 hr 1/2hr 1/2 hr 2-1/2 hr llhr lhr 0hr 2-1/4 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 4hr 18-1/2 hr 1/2 hr 0hr 1/2 hr 1/2 hr 3-1/2 hr 14-1/2 hr lhr 0hr 1-3/4 hr 1-1/2 hr 3hr 2hr 3-1/2 hr 1-1/2 hr 0hr 3-3/4 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 2hr 1/2hr 1/2 hr 5hr 14-1/2 hr lhr 1/2 hr 1/2 hr 4hr 0hr 1/2 hr 2-3/4 hr 4hr 1/2 hr lhr 1/4hr 1/4 hr Activity Drilled to 6075.0 ft Circulated at 6075.0 ft Pulled out of hole to 5020.0 ft Performed formation integrity test t 2. o t'e9 F_lq ~d R.I.H. to 6075.0 ft Drilled to 6265.0 ft Drilled to 6897.0 ft Circulated at 6897.0 ft Flow check Pulled out of hole to 1080.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 6897.0 ft Drilled to 7282.0 ft Drilled to 8511.0 ft Circulated at 8511.0 ft Flow check Pulled out of hole to 6897.0 ft R.I.H. to 8511.0 ft Drilled to 8794.0 ft Drilled to 10002.0 ft Circulated at 10002.0 ft Flow check Pulled out of hole to 5020.0 ft R.I.H. to 10002.0 ft Circulated at 10002.0 ft Drilled to 10218.0 ft Drilled to 10561.0 ft Circulated at 10561.0 ft Flow check Pulled out of hole to 1090.0 ft Pulled BHA Made up BHA no. 4 Tested Downhole measurement tools - Via string R.I.H. to 5020.0 ft Serviced Block line R.I.H. to 10500.0 ft Washed to 10561.0 ft Logged hole with LWD: DIR/FE from 10501.0 ft to 10561.0 ft Drilled to 10757.0 ft Drilled to 11145.0 ft Circulated at 11145.0 ft Pulled out of hole to 10090.0 ft R.I.H. to 11145.0 ft Circulated at 11145.0 ft Flow check Pulled out of hole to 10090.0 ft Laid down 6125.0 ft of 5in OD drill pipe Laid down 3940.0 ft of 5in OD drill pipe Pulled BHA Downloaded MWD tool Held safety meeting Retrieved Bore protector i. )-! ?, ~.i !' . Progress Report Facility Pt Mac 1 Well P1-09 Rig Doyon 14 Page 3 Date 13 March 97 Date/Time 15 Oct 96 16 Oct 96 17 Oct 96 18 Oct 96 19 Oct 96 12:00-13:00 13:00-01:30 01:30-02:00 02:00-06:00 06:00-07:30 07:30-07:45 07:45-08:15 08:15-08:45 08:45-09:45 09:45-10:30 10:30-12:00 12:00-14:00 14:00-15:00 15:00-16:00 16:00-22:00 22:00-22:30 22:30-22:45 22:45-23:45 23:45-00:45 00:45-01:15 01:15-06:00 06:00-06:30 06:30-08:30 08:30-19:00 19:00-20:00 20:00-22:00 22:00-22:30 22:30-00:00 00:00-01:00 01:00-02:15 02:15-03:00 03:00-04:00 04:00-06:00 06:00-23:30 23:30-01:00 01:00-01:15 01:15-01:30 01:30-01:45 01:45-02:00 02:00-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-10:00 10:00-10:30 10:30-03:30 03:30-04:30 04:30-04:45 04:45-05:00 05:00-06:00 06:00-09:00 09:00-10:00 10:00-11:00 11:00-16:30 Duration lhr 12-1/2 hr 1/2 hr 4hr 1-1/2 hr 1/4 hr 1/2 hr 1/2 hr lhr 3/4 hr 1-1/2 hr 2hr lhr lhr 6hr 1/2hr 1/4 hr lhr lhr 1/2 hr 4-3/4 hr 1/2 hr 2hr 10-1/2 hr lhr 2hr 1/2 hr 1-1/2 hr lhr 1-1/4 hr 3/4 hr lhr 2hr 17-1/2 hr 1-1/2 hr 1/4hr 1/4 hr 1/4 hr 1/4 hr 3hr 1/2 hr 1/2 hr 1/4 hr 3-3/4 hr 1/2 hr 17 hr lhr 1/4 hr 1/4 hr lhr 3hr lhr lhr 5-1/2 hr Activity Rigged up Casing handling equipment Ran Casing to 11134.0 ft (7in OD) Rigged up Casing hanger running tool Circulated at 11134.0 ft Circulated at 11134.0 ft Held safety meeting Pumped 90.000 bbl spacers - volume (null) Mixed and pumped slurry - 58.000 bbl Displaced slurry - 415.000 bbl Rigged down Casing handling equipment Installed Seal assembly Rigged up BOP stack Rigged down Kelly Rigged up Kelly Tested BOP stack Installed Bore protector Held safety meeting Rigged up Gyro survey instruments R.I.H. to 2500.0 ft Pulled out of hole to -0.0 ft R.I.H. to 11000.0 fl Rigged down Gyro survey instruments Made up BHA no. 5 Singled in drill pipe to 10700.0 ft Serviced Block line Serviced Kelly/top drive hose Singled in drill pipe to 11057.0 ft Circulated at 11057.0 ft Tested Casing - Via annulus and string Drilled cement to 11134.0 ft Drilled to 11165.0 ft Performed formation integrity test /5. I Drilled to 11185.0 ft Drilled to 11456.0 ft (cont...) Circulated at 11456.0 ft Flow check Circulated at 11456.0 ft Pulled out of hole to 11134.0 ft Flow check Pulled out of hole to 210.0 ft Pulled BHA Made up BHA no. 6 Made up BHA no. 6 (cont...) R.I.H. to 11456.0 ft Circulated at 11456.0 ft Drilled to 11742.0 ft Circulated at 11742.0 ft Flow check Circulated at 11742.0 ft Pulled out of hole to 9700.0 ft Pulled out of hole to 230.0 ft (cont...) Pulled BHA Made up BHA no. 7 R.I.H. to 11547.0 ft Progress Report Facility Pt Mac 1 Well P1-09 Page 4 Rig Doyon 14 Date 13 March 97 Date/Time 16:30-18:00 18:00-03:30 20 Oct 96 03:30-03:45 03:45-04:00 04:00-04:15 04:15-04:30 04:30-06:00 06:00-08:30 08:30-09:00 09:00-09:30 09:30-12:00 12:00-12:15 12:15-13:00 13:00-13:30 13:30-13:45 13:45-06:00 21 Oct96 06:00-11:30 11:30-11:45 11:45-12:30 12:30-15:30 15:30-16:15 16:15-17:00 17:00-19:00 19:00-06:00 22 Oct 96 06:00-06:30 06:30-06:45 06:45-07:00 07:00-11:00 11:00-12:15 12:15-13:30 13:30-18:00 18:00-19:30 23 Oct 96 24 Oct 96 19:30-20:30 20:30-06:00 06:00-15:30 15:30-18:00 18:00-19:00 19:00-20:30 20:30-00:00 00:00-06:00 06:00-08:30 08:30-09:30 09:30-09:45 09:45-10:00 10:00-10:15 10:15-10:30 10:30-13:30 13:30-15:30 15:30-16:30 16:30-16:45 16:45-17:00 17:00-21:30 21:30-21:45 Duration 1-1/2 hr 9-1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/4 hr 3/4 hr 1/2 hr 1/4 hr 16-1/4 hr 5-1/2 hr 1/4 hr 3/4 hr 3hr 3/4 hr 3/4 hr 2hr llhr 1/2 hr 1/4 hr 1/4 hr 4hr 1-1/4 hr 1-1/4 hr 4-1/2 hr 1-1/2 hr lhr 9-1/2 hr 9-1/2 hr 2-1/2 hr lhr 1-1/2 hr 3-1/2 hr 6hr 2-1/2 hr lhr 1/4 hr 114 hr 1/4 hr 1/4 hr 3hr 2hr lhr 1/4 hr 1/4 hr 4-1/2 hr 1/4 hr Activity Reamed to 11742.0 ft Drilled to 11846.0 ft Flow check Circulated at 11846.0 ft Pulled out of hole to 11134.0 ft Flow check Pulled out of hole to 6500.0 ft Pulled out of hole to 230.0 ft (cont...) Pulled BHA Made up BHA no. 8 R.I.H. to 11100.0 ft Held safety meeting Serviced Block line R.I.H. to 11831.0 ft Washed to 11846.0 ft Drilled to 12119.0 ft Drilled to 12247.0 ft (cont...) Flow check Pulled out of hole to 11134.0 ft Repaired Standpipe manifold R.I.H. to 12172.0 ft Pulled out of hole to 11988.0 ft Reamed to 12247.0 ft Drilled to 12420.0 ft Circulated at 12420.0 ft Flow check Circulated at 12420.0 ft Pulled out of hole to 230.0 ft Pulled BHA Made up BHA no. 9 R.I.H. to 11850.0 ft Logged hole with LWD: Formation evaluation (FE) from 11850.0 ftto 11950.0 ft Washed to 12420.0 ft Drilled to 12510.0 ft Drilled to 12684.0 ft (cont...) Laid down 1100.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 11134.0 ft R.I.H. to 12450.0 ft Reamed to 12684.0 ft Drilled to 12790.0 ft Drilled to 12875.0 ft (cont...) Circulated at 12875.0 ft Flow check Circulated at 12875.0 ft Pulled out of hole to 11130.0 ft Flow check Pulled out of hole to 3950.0 ft Laid down 3740.0 ft of 3-1/2in OD drill pipe Pulled BHA Retrieved B ore protector Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Facility Pt Mac 1 Progress Report Well P1-09 Page 5 Rig Doyon 14 Date 13 March 97 Date/Time 25 Oct 96 26 Oct 96 27 Oct 96 28 Oct 96 29 Oct 96 21:45-22:00 22:00-23:30 23:30-03:30 03:30-06:00 06:00-07:00 07:00-07:15 07:15-08:00 08:00-16:00 16:00-06:00 06:00-11:00 11:00-11:45 11:45-12:00 12:00-16:30 16:30-17:00 17:00-17:30 17:30-18:30 18:30-19:00 19:00-19:30 19:30-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-04:00 04:00-05:15 05:15-05:30 05:30-06:00 06:00-07:30 07:30-07:45 07:45-11:30 11:30-12:00 12:00-13:00 13:00-16:00 16:00-17:00 17:00-18:30 18:30-19:00 19:00-20:00 20:00-21:30 21:30-05:30 05:30-06:00 06:00-07:00 07:00-07:45 07:45-08:00 08:00-11:00 11:00-11:30 11:30-12:00 12:00-17:30 17:30-21:00 21:00-06:00 06:00-06:30 06:30-08:00 08:00-08:15 08:15-08:30 08:30-09:15 Duration 1/4 hr 1-1/2 hr 4hr 2-1/2 hr lhr 1/4 hr 3/4 hr 8hr 14hr 5hr 3/4 hr 1/4 hr 4-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 3hr 1/2 hr lhr 1/2 hr 3-1/2 hr 1-1/4 hr 1/4 hr 1/2hr 1-1/2 hr 1/4 hr 3-3/4 hr 1/2 hr lhr 3hr lhr 1-1/2 hr 1/2 hr lhr 1-1/2 hr 8hr 1/2 hr lhr 3/4 hr 1/4 hr 3hr 1/2 hr 1/2 hr 5-1/2 hr 3-1/2 hr 9hr 1/2 hr 1-1/2 hr 1/4hr 1/4 hr 3/4 hr Activity Installed B ore protector Made up BHA no. 10 Singled in drill pipe to 4000.0 ft R.I.H. to 11134.0 ft Serviced Block line Laid down 280.0 ft of 3-1/2in OD drill pipe R.I.H. to 12450.0 ft Reamed to 12875.0 ft Drilled to 13055.0 ft Drilled to 13065.0 ft (cont...) Circulated at 13065.0 ft Flow check Pulled out of hole to 320.0 ft Pulled BHA Serviced Draw works Made up BHA no. 11 R.I.H. to 2000.0 ft Tested MWD/LWD - Via string R.I.H. to 11134.0 ft Circulated at 11134.0 ft R.I.H. to 13034.0 ft Reamed to 13065.0 ft Drilled to 13150.0 ft Circulated at 13150.0 ft Flow check Pulled out of hole to 12300.0 ft Pulled out of hole to 11134.0 ft (cont...) Flow check Pulled out of hole to 230.0 ft Pulled BHA Made up BHA no. 12 R.I.H. to 9500.0 ft Serviced Block line R.I.H. to 11134.0 ft Circulated at 11134.0 ft R.I.H. to 12775.0 ft Logged hole with LWD: Formation evaluation (FE) from 12775.0 ft to 13150.0 ft Drilled to 13185.0 ft Circulated at 13185.0 ft Circulated at 13185.0 ft (cont...) Pulled out of hole to 11134.0 ft Flow check Pulled out of hole to 230.0 ft Pulled BHA Made up BHA no. 13 R.I.H. to 13025.0 ft Reamed to 13185.0 ft Drilled to 13240.0 ft Drilled to 13242.0 ft (cont...) Circulated at 13242.0 ft Flow check Circulated at 13242.0 ft Pulled out of hole to 11134.0 ft Progress Report Facility Pt Mac 1 Well P1-09 Page 6 Rig Doyon 14 Date 13 March 97 Date/Time 09:15-09:30 09:30-13:00 13:00-14:30 14:30-18:00 18:00-18:15 18:15-00:30 30 Oct 96 00:30-03:30 03:30-06:00 06:00-11:00 11:00-13:30 13:30-15:00 15:00-15:15 15:15-18:30 18:30-19:30 19:30-20:30 20:30-00:00 31 Oct 96 00:00-01:30 01:30-02:30 02:30-04:00 04:00-06:00 06:00-07:15 07:15-07:30 07:30-12:00 12:00-13:00 13:00-13:15 13:15-18:00 18:00-18:30 18:30-01:30 01 Nov 96 01:30-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-08:00 08:00-08:15 08:15-08:45 08:45-09:00 09:00-09:20 09:20-09:40 09:40-09:50 09:50-11:00 11:00-15:30 15:30-15:45 15:45-16:00 16:00-19:00 19:00-19:15 19:15-19:30 19:30-23:30 23:30-02:00 02 Nov 96 02:00-03:30 03:30-03:35 03:35-06:00 06:00-09:00 09:00-09:30 09:30-18:00 Duration 1/4 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 1/4 hr 6-1/4 hr 3hr 2-1/2 hr 5hr 2-1/2 hr 1-1/2 hr 1/4 hr 3-1/4 hr lhr lhr 3-1/2 hr 1-1/2 hr lhr 1-1/2 hr 2hr 1-1/4 hr 1/4 hr 4-1/2 hr lhr 1/4 hr 4-3/4 hr 1/2 hr 7hr 1/2 hr lhr 1-1/2 hr 1-1/2 hr 2hr 1/4 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 0hr lhr 4-1/2 hr 1/4 hr 1/4 hr 3hr 1/4 hr 1/4 hr 4hr 2-1/2 hr 1-1/2 hr 0hr 2-1/4 hr 3hr 1/2hr 8-1/2 hr Activity Flow check Pulled out of hole to 250.0 ft Pulled BHA Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Rigged up sub-surface equipment - Downhole equipment Conduct braided cable operations - 5/16 size cable Conducted electric cable operations Rigged down sub-surface equipment - Cable Rigged down Additional services Rigged down Additional services Rigged down Additional services Rigged down sub-surface equipment - Downhole tools Made up BHA no. 14 R.I.H. to 11134.0 ft Circulated at 11134.0 ft R.I.H. to 12647.0 ft Washed to 13242.0 ft Circulated at 13242.0 ft Circulated at 13242.0 ft Flow check Pulled out of hole to 420.0 ft Pulled BHA Held safety meeting Ran Casing to 2215.0 ft (4-1/2in OD) Circulated at 2300.0 ft Ran Drillpipe in stands to 11135.0 ft Rigged up Circulating head Circulated at 11135.0 ft Ran Drillpipe in stands to 13242.0 ft Circulated at 13242.0 ft Circulated at 13242.0 ft Held safety meeting Pumped 20.000 bbl spacers - volume (null) Pumped 50.000 bbl spacers - volume (null) Mixed and pumped slurry - 100.000 bbl Displaced slurry - 101.000 bbl Retrieved downhole equipment - Liner hanger Reverse circulated at 11027.0 ft Pulled Drillpipe in stands to -0.0 ft Retrieved B ore protector Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed Bore protector Ran Drillpipe to 2215.0 ft (2-7/8in OD) Ran Drillpipe in stands to 13165.0 ft Circulated at 13165.0 ft Tested Casing - Via annulus and string Circulated at 13165.0 ft Circulated at 13165.0 ft Tested Casing Laid down 13165.0 ft of Drillpipe Progress Report Facility Pt Mac 1 Well P1-09 Page 7 Rig Doyon 14 Date 13 March 97 Date/Time 03 Nov 96 04 Nov 96 18:00-18:15 18:15-19:15 19:15-22:30 22:30-23:00 23:00-23:30 23:30-23:45 23:45-01:15 01:15-06:00 06:00-12:00 12:00-12:15 12:15-15:00 15:00-16:30 16:30-18:00 18:00-18:20 18:20-18:30 18:30-19:00 19:00-19:30 19:30-19:45 19:45-21:15 21:15-23:30 23:30-02:30 02:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 Duration 1/4 hr lhr 3-1/4 hr 1/2 hr 1/2 hr 1/4 hr 1-1/2 hr 4-3/4 hr 6hr 1/4 hr 2-3/4 hr 1-1/2 hr 1-1/2 hr 1/4 hr 0hr 1/2 hr 1/2 hr 1/4 hr 1-1/2 hr 2-1/4 hr 3hr 1/2 hr 2hr lhr 1/2 hr 1/2 hr lhr Activity Held safety meeting Rigged up sub-surface equipment - Slickline / braided cable Conducted electric cable operations Rigged down sub-surface equipment - Slickline / braided cable Retrieved B ore protector Held safety meeting Rigged up Tubing handling equipment Ran Tubing to 4510.0 ft (4-1/2in OD) Ran Tubing to 7995.0 fl (4-1/2in OD) Tested SCSSSV control line Ran Tubing to 10031.0 ft (4-1/2in OD) Rigged up Tubing hanger Circulated at 10031.0 ft Set Permanent packer at 9984.0 ft with 0.0 psi Set Permanent packer at 9984.0 ft with 4000.0 psi Tested Tubing Tested Permanent packer Rigged up Internal BOPs Rigged down All rams Rigged down BOP stack Installed Xmas tree Removed Hanger plug Freeze protect well - 89.000 bbl of Diesel Freeze protect well - 62.000 bbl of Diesel Freeze protect well - 62.000 bbl of Diesel Installed Hanger plug Rigged down Rig services Al<Ut). EL Well Work Log Date Descril~tion ......... DS-Well 1 1/25/96 INITIAL IVISH~ PERF~-10' OF PROP'D 5ff('rlGl-ff HOL~ P1-09 · SSsv Information: Tubular or Casing Problems , PBTD OOH N/A NO TAG CIE'#2 SINS ' CIE#2 DO'WELl, C/E #3' "MET. CIE #4 ' CIE #5 SWS $1 1,490 DOCT $11,228 $1,464 Diesel (Re~.ov.) 'Diese~"(non Recov) AFL # C'C8 [Class Activity - - AX9372 FDUNDV4LH _ Time '' Log Eniry ' '' OO:O0 MIR,U D'OWELL cTE UNIT #1 (1.7S"; 0.,109" WALL;)(E. BURFI'~ &=SWS UNIT .8293 (G, $CI':I~i/,'~,R.Z,). 11:30 MU 10' 2-1/2" HSD PERF GUN (31J UJ)/CC.L/_ .G. UN GR (4' FROM _C~.L.TO TOP SHOT) ...... 12:20 PT TO 4000 PSI-OK. 12:30 RII:'I 'W/COIL CONN'E~TI.ON../1-11/16" GUN GR/.C.CL/10' 2-1/2' GUN ('F~+AL STRING LENGTH=-23') 13:20 PICK-UP WT @ 5000': 10.7K 14:00 PICK-UP ~ @ 10000': 19K 14:40 'PICK-UP W'T @ 12000': 23.8K ·15:00 ~I'E-IN TO.SW$ C0MP ,E. NSATED NEI~ON/GR LOG DATED 10129/96 {4' SHALLOWT0 REF LOG~, .. 15:10 PICK-UP ~ @ 12880': 28K 15:3.5, LOG UP INTO, POSITION (CC. L..r~_ 13056'), PE'~'F 10060-13070', 6 sPF, 60< .WHP WENT FROM 0 TO 210- PSi. 15:45 FLAG PIPE (eCL @ 13056'), POOH..P. UMPiNG 60/4~). @ 0.3 BPM . 17:25 ON SURFACE- ASF. 18:00 MU 20' 2-1/2." ,HSD PERF GUN (31J OJ)/CCk (2.5' FR~M'CCL..TO TOP SHO'r)-TO..O..K-OUT 4' (FLAG @ 13052) 18:15 PT TO 4000 PS1- OK. 18:25. , RIH W/COIL C. 0.,N,,NECTION/1-11/16" C,C, L/20' 2-1/2', GUN (TOTAL STRING LENGTH'-'-'~I'} ' ' 19:10 HAVI,NG CONTINUITY:, pROBLEMS W/EL (I..NTE, RMITTENT CCL SIGNAL) @ -.4000', *o. --SIGNAL RETURNED. CONTINUE RIH. · i ·1 Ill ill I I I l 2 0:15 MORE CONTINUITY PROBLEMS. A'ITEMPT TO IDENTIFY. CCL SIGNAL COMPLETELY LOST. POOH FROM -9000' 21:4.0. . ON SURFACE..L. OOSE CONNECTION OF GROUNDWIRE IN CABL~ HEAD WAS FOUI~TO BE'I-HE PROBLI~: .. 23:00 RDFN (LEAVE UNITS SPO'I'rED BY WELL). NOTE: WMP HAD GRADUALLY BUILT TO :.800 PSI wHIkE POOI:I W/GUN #1 & DURING GUN ;t2 A'I-I'EMI~'- ,NOTE: PUMPED TOTAL 61 BBLS 60/40 .ME'I'H/WATER WHILE PC)O.II I II · · I Results Summary.- Addres..e each objective listed In Job request '-'e,.:g,:'sPlit~:'.~.;G~'Ci.p!_ek~. cl~annels~ etc. ., ..:.. - INITIALLY PE.R.F BTM 10' (1306,0..70' REF TO TIE-IN .L_OG. 4' SHALLOW) OF 50' PROPOSED W/2-112" HSD. · EL CONTINUITY. P. ROBLEM$ ON 2ND GUN RUN (ABORT). R.DFN. CONTINUE W/2 RE.M~J. NING GUN RUNS IN A_M. · NO TAG · II IIIII Perforat. lng"..'lnterval (BHC~ depths) & Gun. Info, ~[nsert..,moreYlin.es...'.'.a.e...neceeaa_ry} ' . ..... .... Top (ft)' Bottom , SI=F Gram~.EHD/TTP Phasi~g.. Orient OIBIU Zone AdlReperf 1 3064 13074 6 10.5/0,29"/17.3, 60* RAN[:X:]M U UI~ ~ · I I I I I ~ P .or' !;PROF: Well rate (.attach W$30) SgHPS. :.Pump...In .togs (L.**.DI~'.~'PNL,_,et~i) ,;. BOPD: F/ITP: 'MD: '" Tot, Ga@: GOR:; SS: Wc " Pr.,: ' " GL Gas: Choke °' Temp I II I i Signed [?age-No: of EL Well Work Log Date ' Description ' ' ' D~-WelI 1 1 ,/?6/96 INITIAL IVISHAK PERFS (REMAINING.40~)-(I'IG.HT H°LE) P1-09 FTP/ITP PSI , IA PSI OA P~I J SITP Min ID S~SV nipple N/A . · 200 psi 1 psiI 1,100 psi 3.75"0 10018' 4.5.".CAMCO BALO sSev Information Tubular or Casing Problems PBTD · OOH N/A NO TAG 'l , , I III _ CIE#2 SWS-' ClE#;~ IX)WELL CIE #3 MET C/E #4 C/E #5 SWS $16,537 EX)CT $11,228 $2,266 .. Diesel (Reoov.) ' Oleeel (nOn ReCov) AFE # icC~ ]Cla~s Aeti;ity AX9372. FDUNDV4LHI · ,Time ' 'Lo~ Entry . 08.:00 ,DS CTE UNIT#1 (i.75';,.0.-109' WALL)(E. ~URRE, L) & SWS UNIT. #a293"i(~. S~. HWARZ.) ON LOCAT. I.ON. 08:50 PRE-JOB SAFETY MTG. . , 09'C~0 MU 20'. 2-1/2' HSD PERF GUN (31J UJ)/CCL/(~'.5' FROM'C.~. L TO'TOP eHo~ ..... 09:45 PT TO 4000 PSI - OK. 09:55 RIH W/COIL CONNEC~I. ON/1-11/1'~' CCLJ20' 2-1/2" G.,UN (TOTAL sTRING LENGT.=-28~ 10:20 wHP BUILT TO 1500+ PSI. CRACK OpEN CHOKE TO FLOW-BACK TANK & BEGIN PUMPING METH/WTR .3 BPM 11:40 PUWT@ 10000': 20K# 12:15 puWT @ 11500' 24K# 12:30 PU WT @ 12000': 24.3~ 12:40 PU WT @ 12500'i 25K# , · ,.. 12:55 TIE-.IN TO SWS COMP.ENSATED NEUTR~N/GR LOG DATED 10/29/90 (.4' SHALLO~V.TO REF LOG). 13;00 PICK-UP WT @ 13135': 26K 13;05. LOG UP INTo POSITION (~CCL @ 13037.5'),. PERF i':~ ..0~-13060'. 6 sPF, '6(Y'. WHP 1'0~0 PSI. FLOWING TO M.B 1.3:10 =LA(3 PIP. E (cCL @ 13037,,:.5,). POOH PUMPI.NG 60/40 @ 0.3 sPa . 15:00 ON SURFACE, FP FLOWLINE AND TBG TO 400' - ASF. ~ ~':~0 .u eR, Mu 20' =:1~=' HSD ?ERF ~UN 131J UJyCCL (~' ~.0. M ccL TO ~O.~ SHOT~. ~ S'~0 .T TO 3000.S~- O~. . l e:50 R~h w/CmL CO~NECTIO~I.~ 1/15" CC~GUN GR/20' 2-1/2' GUN (TOTAL STroNG LENGTh=~~') 18:45 PU WT @ 11000': 22,$K# · .= ,. ~ ~ . 19:25 ~AKE nE IN PASS. 19:30 LOG CCL UP TO l~mS', SHOOT ~3520'-~0', ~ Sp~, S0~ W/WEL~ ~LOW~NG. LOG Up T'O ~aS0'. POOH. - .. . ~_3:0.o .o~o Ds &,.sws, Os~ To F.Z..OT~CT~e W,/~s ~S~S'C.UDS ~.T~. TONigHT. LEArS.WELL S~ ~F~"Sa... ,Results Summary - A, ddresa es, ch obj,,ectlve listed in ,Job request.-.e.. · SHOT INITIAL. pERF'S 13020'.60' REF TO TIE-IN LOG- (4' SHALLOW TO REF LOG) W/2-1/2" HSD. .. o FP 'I'BG TO 3000' W/CRUDE. · NO TAG I I II .. , , Perfor, aflng Int,eryal (BHCG. dap.th.s} & Gun' lnfo. .(inSert. more..llnes ,as necessary) .,,. .".~ ,.. Top (ft). Bottom apl= G, ramalEHDFrTP Phasing Orien. t OIB,/,U Zone AdlRe~erf 1 3024 13064 6 10,S/0.29"/17.3~ 60e RANDOM U IVIeHAK INmAL PERF ! · . '..'or ,.~..OF= Wa~ r.te (.tt~,=~ wS.~i ' S~.s.. ' BOeO:r F/ITP: MD: Tot. Gas; GOR:. SS: BWPO: . , WC (%): Pres,s: ..... GL Gas: Choke °: Temo-' I II III I Signed Page No. of ~ ~re~e~'~/~r. ~v~'OOT£ , I I L .. "JOB: RTZlhTL# PROG: LRTB1701-05 AS OF: 02/28/1997 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COHHISSION HONTttLY PRODUCTION AND INJECTION REPORI P1-09 TAIL TRACT OPERATION RECONCILIATION PAGE: 1 RUN TIME: 17:51 RUN DATE: 03/13/1997 FIELD - P1-O9 TAll. TRACT OPERATION 6hO OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTII - FEBUARY-1997 TOTAL PIPELINE DELIVERIES FOR ALYESKA FROM LPC LESS DELIVERIES FROM FIELDS OTNER THAN PIOgTL TOTAL PIPELINE DELIVERIES FROM ~109TL LESS LOAD OIL LESS OTflER 011_ NET PIPELINE DELIVERY PLUS LEASE USE CRUDE PLUS INJECTED SLP LESS NGLS TO PIPELINE TOTAL NE'r ALLOCATED PRODUCTION 5,801,29h.00 5,787,789.00 13,505.00 o.oo o.oo 13,505.00 0.00 0.00 2h6.00 13,259.00 FORM 10-1105 I HEREBY CERTIFY THAT ~rHE FOREGOING STATEMENTS ARE TRUE AND CORRECT TO TIlE BEST OF MY KNOWLEDGE. · _~ _ ._ SUPERVISOR PRODUCTION & REVENUE ACCOUNTING DATE: END OF REPORT ORIGINAL JOB: RTZlqTL# PROG: LRTB1700-01 AS OF: 02/28/1997 FORM 10-h05 WELL NUMBER 15-09 APl FIELD NUMBER CLASS CODE 029-2270h-00 0 6h0150 FACILITY TOTAL VOLUME TOTAL MT'II 2 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COHHISSION MONTHLY PRODUCTION REPORT P1-09 TAIL TRACT OPERATION AVG DALLY DALLY DAYS GAS/OIL TUBING AVERAGE AVERAGE PROD RATIO PRESSURE OIL WATER 23 0932 788 576 q56 23 23 END OF REPORT PAGE: 1 RUN TIHE: 17:51 RUN DATE: 03/13/1997 FIELD - P1-09 TAIL TRACT OPERATION 6hO OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - FEBUARY-1997 DAILY TOTAL TGI'AL 1OTAL AVERAGE OIL WATER GAS GAS (BBL) (BBL} (MCF} 537 13259 10q90 12361 13259 10q90 12361 13259 10q90 12361 .. .., ORIGINAL ., ~JOB: RTZlqTL# PROG: LRTB1701-06 AS OF: 02/28/1997 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COHHISSION MONTHLY PRODUCTION REPORT P1-09 TAIL TRACT OPERATION PIO9TL NGLS PAGE: 1 RUN TIME: 17:51 RUN DATE: 03/13/1997 FIELD - P1-09 TAll_ TRACT OPERATION 6qO OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTIt - FEBUARY-1997 LEASE OR UNIT WELL APl NUMBER NUHBER NUMBER 11650 TYPE 50-029-00000-16 P FACILITY TOTAl. FIELD CODE DALLY DALLY DALLY AVERAGE AVERAGE AVERAGE DAYS MTH NGLS WATER GAS PROD TOTAL TOTAL TOTAL NGLS WATER GAS (BBL) (BBL) (MCF) 6q0150 7 9 0 0 28 2q6 0 0 28 2q6 0 0 END OF REPORT OR G1NAL Halliburton Energy Services- Drilling Systems PSL Survey. Report Calculated using the Minimum Curvoturt Method Comlntted #sing IFIN-C. IDDS REI/7.2.2 Vcflical SeclionPlaJ~: 17.1 ! deg. BPX '. Slmod ,Se~c~ Drilling Pag~ I Job No: 00262 Dale: 10/30/96 Tir~: 4:40 pm Wellpath ID: PI-09~ Dat~ Created: 10/I/96 Las{ Revision: 10/30196 'ri Alaska Slale Pla~: Zone! PIMac: PMI P1-09 As-Buil! P1-09M~ Measured lncl ~ (a) (~.) (~s.) [a) (a) (n) (~) TOTAL (a) (~} (~) (~.) Nort~ng Fasting tn) tn) DL$ (~toon) Survey Tool 0.0O 0.00 BI-IA/ti / 1,500 B.H. 100.00 0.30 2OO. 00 0.36 3O0.OO 0.66 400.00 1.87 S00.OO 2,41 60O.OO 3.40 701.00 5.86 800,00 6,60 9OO.OO 6.97 1000.00 7.18 1100.OO 6.'/2 1200,00 4,34 O,OO 44.38 0.00 0.00 { 12 114" HOLE } 93,62 -55.62 100.00 0,06 100,00 N0,79 -155.62 200.00 0.26 100,00 123.55 -255.61 299,99 0.24 100,00 129,57 -355.$9 399,97 -0.55 100.00 116.15 -455.52 499.90: -1.50 100,00 115,68 -555.39 599,77 -2.2'7 100.00 12.S,36 .656,05 700.43 -4.34 101.00 129,81 -754.47 798.85 -8,11 99.00 130,47 -853.77 898.15 -12.74 100.~ 130,07 -953.01 997,39 : -17.58 100.00 128.91 -1052.27 1096.65 -22.19 IOO. OO 128.63 -1151.80 1i96.18 -2S,75 100.00. · . 0.00N 0.00£ 0.00~ 0.00 0.02 S 0.~6E 0.26~ 93.62 0.02N 0,83E O, Ik~t S8.82 0.25 S I.~2E 1.64~ 98.79 1.61 S 3.36E 3,73~115.~8 3.57 S 6,51E 7,4~ 11&79 5.79 S II.07E 12.49~117.61 10.07 S 17.9"/E 20.60~ 119.26 16.64 S 26.46 E 31,2~1~216 24.25 S 35.49 E 42.9~ 124.35 32.21 S 44.89 E 55.2~125.66 39.91S ~4.23 E 67.3~ 12635 45,95S 61.74E 76.96~ 126.66 5994568.11 674303.82 5994568,10 674304,08 5994568,14 674304,65 5994567,89674305.45 5994566,58674307,22 5994564.68674310.41 5994562,58674315,02 5994558.46674322.02 5994552,09674330.66 5994544,69674339.87 5994536,95674349.45 5994529,47674358.96 5994523,61 '674366.61 0.30 0.09 0.47 1.22 0.73 0.~) 2,55 0,89 0,38 0.22 0,48 2,38 0.0 0,3 0.4 0.9 2.1 2.8 3.8 6.4 7.3 7.6 7.8 8.3 10.7 UNKNOWN BPH~PBD BPHC,-PBD BI~{~PHD BI%IG-I~D BPHC,-~D BPHC,-PBD BPHC,-PBD BPHG-PBD BPHG -PBD BPHG-PBD BPHG-PBD BPHG-PBD Halliburton Energy Services- Drilling Systems PSL Survey Report Paga 2 Dale: 10/30/96 Wdlpalh 1I): PI-OgMWD Incl Drift Dir. Su~se~ D~th 1301.OO 3.16 126.35 -1252.5{} 1296,96 -28,07 101.00 1399,00 1.54 118.47 -1350,49 1394.87 -29.22 1500,00 0.6'/ 102.19 -1451,4S 1495.86 -29.44 101.00 1600.00 1702.00 1800.OO 1900,00 2OO0,OO 2100.OO 2200,00 2300.00 2400,00 250O3O 2600,00 2699.00 2799,00 2900.00 3000.00 0.52 99.44 -1551.4'/ 1595.85 -29,33 IOO.00 0.54 94.12 -1653.47 1697.85 -29.16 102.00 0.58 96.52 -1751.46 i'/95.84 -28. P6 95.00 0.65 90.69 -!$51.46 1895.84 -28.71 loo.00 0.81 91.95 d951.45 1995.1B -28.36 100.00 0.98 {,2~99 -2051.43 2095.g[ -27.$3 IOO.00 1.11 $1.27 -2151,42 2195.80 -27.06 100.00 1.18 T/.$2 -2251.40 2295.78 -26.13 IOO.00 1.29 77.27 -2351.37 2395.75 -25,06 100.00 0.98 69.28 .2451,36 2495.74 -23,98 100,00 1.90 312.95 -2551,34 2595,72 -22,73 100.00 1.3'/ 316.88 -2650,30 2694,68 -21.42 99.00 1.13 6.89 -2750.2'/ 2794.65 -19.86 IOO.00 0.85 12.09 -2851.26 2895,64 -18,13 101.00 0.83 12.82 -2951.25 2995.63 -16,67 loo.00 0.84 18.10 -3051.24 3095.62 -15,22 IOO.OO 0.8'/ 19,36 .3151.23 3195.61 -13.73 IOO.00 0.9{ 12.02 -3251.21 3295.59 -12.12 IOO,00 0.89 3.51 3.51 6.O8 8.07 9.89 10.49 12.47 15.10 3100,00 3200.00 3300.00 59.'/$ 60.00 60.17 60 57.61 50.74 -3351,20 -3451,14 -3550.~ -3670.54 -3749,93 -3848."/0 .3~7.12 -4045.12 -4142,24 3720.00 3800.00 3900,00 40OO.00 4100.00 4200.00 3395,58 -I0.49 100.00 3495,52 -'/.61 IOO,00 3595.35 -322 IOO.00 3714.~2 4.21 120.00 3794.31 11.44 3893,0S 22.86 ioo.00 .3991.50 35.75 100.00 40119.50 50.57 IOO,00 4186.62 69.63 100.00 T 0 T A L Clo~re GRID ~¢s Radangular O~sets Dist. Dh. Nofllmg Easting (n) (f0 (fl) (d~.) (n) (fi) 49.951S 66.96E 83,56~126,74 5994519.70 674371.93 52.22 S 70.30E 87.Y'~126.60 5994.517.55 674375.31 52.~ $ 72.07E 89,45~126.32 5994516,82 674377,10 53.18 ii 73.09E 90.3~126,04 5994516,64 674378,12 53.30 S 74.02E 91,21~123.75 $994516,55 674379,06 53.38 ii 74.98'E 92.04~125,45 5994516,49 674380.02 53.45 ii %.05E 92,95~125,10 59~4516,45 674351.09 53.41{ S '/7.32E 94.01~124.67 {994516.45 674382.36 53.40 ii 78.g7E 95.25~124.10 5994516.56 674353.91 $3.15 $ 80.68 E 96.61~ 123.37 $994516,86 674385.71 52.78 $ 82.64E 98.06~i22,56 5994517.27 674387,67 52.3 i $ 84,75 E 99,59~ ! 21.68 59945 IZ79 674389,76 51.76 $' 86.64 E 100.93~ 120.85 5994518.39 50.33 S li6.23 E 99,84~ 120,27 5994519.81 41.34 S 84.22 E 97,11~119.86 5994521.74 46,49 $ 83.52 E 95.5~(~ 119.10 5994523.58 44.71 S 83.80E 95.01~118,11 5994525.31 43,34 S 84.1 i E 94.62~ ! I?,26 5994526,74 41.94 S M,50 E 94.34~ 116 39 ~J14 $28.15 40.52 $ 14,98 E 94.1.~ 115,49 35.9'/S {5,41E 93,88~ 114,53 37.41 $ 15.88 E 93.6 .'~ 113,M ~94532.71 35.16 S 18.33 E 95,07(~ 111,70 ~4535,02 32.03 S 93.10 E 98.4f~ 108,98 5994538,26 26.91 $ 101,73 E 105,23(~ 151,82 ~94543.58 21.97 S 110.25 E 112,42i~ 101,27 ~94548.72 14.18 $ 123,78 E 124.59{~: 96,54 5994556,81 5.43 S 139.16E 139.2~ 9224 5994565.92 4.83N 156.20E 156.28(~ 88.23 5994576.5~ 18,86N 175.41 E 176.42~ 83,8& 5994591.05 674391.64 674391.20 674389.14 674388.40 674388.63 674388.92 674389,27 674389.72 674390.11 674390,54 674392,94 674397,64 674406,14 674414,55 6'/4427.89 674443,06 674¢59.86 674478.73 DLS (d~loofl) 1.18 !.65 0.91 0.15 0.05 0.05 0.09 0.16 0.22 0.13 0,10 0.11 0.35 2.49 0.55 1,0S 0,29 0.02 0,08 0,04 0,16 0.18 2.34 0,52 2,14 2,49 !.82 0,60 2.06 3.09 Dogleg (deg) 11.9 13.5 14.5 14.6 14.7 14.7 14.8 15.0 15.2 15.3 15.4 15.5 15.9 18.4 18.9 20.0 20.3 20.3 20.4 20,4 20.6 20.8 23.1 23.6 26.2 28.2 30.0 30.6 32.7 35.8 Tool BPHG-FBD BHiG-PBD BPHG-PBD BPRG-PBD BPHO.PBD BPEG-PBD BPHG-PBD BPHG-PBD BPHG-FBD BPHG-I:'BD BPHG-PBD BPI-IO-PBD BPHG-PBD BFHG-PBD BPHG-PHD BPItG-PBD BPHG-PBD BPHG-PBD BPEG, PBD BPI. IG-PBD BPHG-PBD BPHC,,.PBD BPRO-I'BD BPHO-FBD BPHG-PBD BPHCrPBD BPHO-PBD BPHO-PBD BPHO-PBD BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Pag~ 3 Date: 1(Y30/96 Wdlpath ID: PI.09MWD 4300,00 17.56 50.54 4238.20 4282.58 4400.00 20,28 50.22 4332.78 43T/.16 4500.00 22.50 $1.39 4425.119 4470.27 ' Vertical S~'tion 93.07 120.18 150.$1 100.00 36.69N 197.14 E 200.$3~ 79.46 5994609.39 674500,04 100.00 57.37N 222.11 E 229,40~ 75.52 5994630.64 674:524.52 100.00 80.41N 25039E 262.98(~1 72.20 $994654.33 674552,25 DLS (rig/lOOn) 2.46 2.72 2,26 rot, leg 31~,2 41.0 43,2 Tool BPHG-PBD BPHG.PBD BPHG.PBD 4600.00 24.57 52.03 4517.57 4700.00 26.41 51.65 -4607,83 4800.00 28.O2 53.47 4696.76 4561.95 4652,21 4741.14 183.37 218,74 255.98 100.00 10S. MN 281.73E 300,?11~ 6933 $9946'79.78 674583,00 100.00 131.73N 315.57E 341.T~ 67.34 5994707.16 674616.21 1130.00 159.51N 351.$8'E 386,355~ 65.61 $994735.78 674651.86 2,09 1.8:5 1,81 4,5,3 47.2 49.0 BPHO-PBD BPHG-PBD BPHO-PBD 4900.00 29.8'7 53.31 .4784.26 4828.64 5000.00 31.,19 :55.56 -4870.31 4914.69 BHA 12 / 1.25° B.H. { 8 1/2" HOLE } 5100.00 34.17 54.61 4954.38 4998.76 295.1}0 335.49 378.17 100.00 185.38N 390.'/3E 433:771~ 64,26 599476,5.54 674690,02 100.00 217.99N 432,18E 484.04~ 63.23 5994796.11 674730.77 100.O0 245.99N 476,56E 537.681~ 62.41 59~.13 674774.41 135 1,90 2.83 50,8 52.7 ,55,5 BPHGPBD BPHG-PBD BPHO-PBD 5200.00 35.85 54.93 4036.28 5080.66 423.59 5300.00 39.22 53.96 -5115.57 5159.95 472.03 5400.00 40.3'/ 55.73 -5192.40 5236.78 522.64 100.00 282.08N $23.43E 594.:~95~61.68 5994862.31 674520.4N 1130.00 317.51N 572.97E 655.0'4~ 61.01 5994898.89 674869.18 100.00 354.35N 625.30E 71874 60.46 $994936.94 674920.64 1.69 3.42 1.61 57.2 60.7 62,3 B?HO-?BD BPHG-PBD BPHG-PBD 5500.00 43,78 53,25 4266.62 5311.00 575.90 5600.00 46.77 52.77 -5336.99 5381.37 633.45 5700.00 48.04 $3.65 -5404.6/ 5449,05 692.92 100.00 393,30N 679.80 E 785.311~ 59.95 $994977.1`5 674974.21 100.00 436.O5N 73634E 855.94~ 59.37 5995021.22 675029,93 100,00 480.13 N 795.50 E 929.1~ 58.89 5995066,66 675087.83 3.79 3.01 1.43 66,1 69,1 70.5 BPEGPBD BPHG.PBD BPHO-PBD 5800.00 50.12 53.71 -5470.16 5900.00 49.54 52.22 453437 6000.00 49.72 51.80 -5599.44 5514.54 5579.05 5643.82 753.61 815.:53 100.00 524.89N 856,38E 1004,43~, `58.50 $~95112,83 675147.64 100.00 Y/O,90N 917,38E 1080,51~ `58.11 5995160.26 675207.54 100.00 617.80N 977.42E 1156.353~ 57,70 $59Y208.54 675266.47 2.08 1.28 0.37 72.6 73.9 74.2 BPHG-PBD BPHG-PBD BPHO-PBD 6100.00 49.67 51.53 -5664.13 6200.00 47.57 51.96 -5730.23 6~00.00 47.'/4 53.41 -5797.59 6400.00 48.7~ 54.89 -5864.16 6500.00 48.62 52.17 -5930.16 660~.00 49.41 52.62 -$995.75 5708.51 5774,61 5841.9'I 5905,54 5974,M 6040.13 940.81 1002.56 1062,67 1122.21 1182.~ 1244.30 6700,00 47.95 52,25 .6061.7'7 6106.15 1305.57 6~00.00 47.73 52.57 -6128.89 6173.27 13~6.07 BHA #3 / I. IY' B.1-L { 8 1/2" HOLE. } 6900,00 47.85 52.89 4196.08 6240,46 1426.28 70(]0.00 47.69 52.65 -6263.29 6307,67 1486.44 100.00 100.00 665.10N 1037.24 E 1232.1f~ .57.33 S995257.23 67532:5.16 100.00 711.56N 1096.15E 1306.85~) 57.01 $595305.06 675382.96 100.00 7-56.36N 1154.93E 1380.5f~ 56.78 $995351.22 675440.67 100.00 800.05N 1215.42E 1455,11~ 56,64 5995396.32 675500.11 100.00 844.70N 1275.83E 1530.12~ 56.49 $~PA42.37 675559,45 100.00 89~.77N 1335.63E 1605.42~) 56.30 $99M19.82 6'/5618,16 100.00 936.55N 1395.17E 1680,36(~l56.13 $~5536,~ 6?5676.59 100.00 981.77N 1453.90E 1754.34(~ 55.97 $995583.57 675734.25 100.00 1026.62N 1512.85E 1828.2~(~ 55.~ Sg95629.g0 675792.12 1071.42N 1571.80E 1902.24~ 55,72 $99~75.97 675850.00 0,21 2.12 !,09 2,05 0,86 1,49 0,32 0,27 0,24 74.4 76.6 77.6 79.2 81.2 82.1 83.6 83.9 84.2 84.4 BPHO-I~ BPHG-FBD BPHG-I:'BI) BPHO,.PBD BPHO-PBD BPH~PBD BPHG-PBD BPHC,-PBD BHtGPBD BPHGPBD Halliburton Energy Services- Drilling Systems PSL Survey Report Page 4 Dale: 10/30/96 Wellpalh ID: ? 1-09MWD Mcasu~ 7100,00 72OO,OO 73O0,00 Ind 48.05 48.67 48.94 Dr~ Dil. TVD Vertical Couno (~) (n) 52,54 -6330,37 6374.75 1546,82 100.00 52.28 -6396.82 6441.20 160732 100,00 52.21 -~2.68 6~07.06 1669.35 100,00 T O T A L Closure GRID Comdinaes Rectangulat O~scts Dist Dir. Nortlfing Fasling (t~) (n) (n) (d~g.) (n) i116.47N 1630.71E 1976,29~ 55.60 5995722,39 675907,83 1162.06N 1689.93 E 2050.91@ 55.49 5995769,36 675965,96 1208.13N 1749.43 E 2126,05~ 55.37 5995816,81 676024,35 DLS (d~10~) 0.37 0.65 0.28 Do~cg 84.8 8:5.4 8:5.7 Surv~ Tool BPHG-PBD BI~IG-PBD BPEG-PBD 7400.00 48.79 52.16 -6528.46 6572.84 1730,99 100.00 7500.00 48.34 52.42 -6594.64 6639.02 1792,27 100.00 7600.00 48.23 52.48 -6061.18 6705.56 1853;16' loo.00 12:54,31N 1808.92E 2201,2~ 55,26 5995864,38 676082.74 1300,17N 1868.23E 2276112~ 55,16 5995911.61 676140.95 1345,66N 1927.42E 2350,69~ 55,08 5995958,49 676199.04 0,15 0.49 0,12 85.8 86,3 86.5 BPItC~PBD BPHG-PBD BPHG-PBD 7700,00 7800,00 7~0,00 48.16 47.41 46J7 52,43 -6727.84 6772,22 1913,96 100.00 $1,63 -6795.03 6839.41 1974,69 100,00 $0,78 -6863.05 6~07,43 2035,39 100.00 8000.00 47.:89 49.77 -6930.77 6975.15 2096.99 100.00 BI00,00 47.52 49,09 -6998.06 7042.44 2159.50 100.00 8200.00 47.6I 51,70 -7065.54 7109.92 2221.18 100.00 4'/.09 48.27 47.79 8300.00 8500.00 51,45 -7133.30 7177.68 2281,82 ir~,00 51,91 -7200,62 7245.00 2342.70 I~.00 51,56 -7267.50 7311.88 2403.88 1~0.00 1391.08N 1986.52E 2425.1~ 55,00 5996005.29 676257.05 1436.65N 2044.90E 2499.12~ 54.91 5996052.21 676314.34 1482.57N 2102.04E 2572,27~ 54,80 5996099,47 676370.37 1529.60N 2158.63E 2645.63~ 54.68 5996147.82 676425.84 1577,71N 2214,81E 2719.30~ 54.54 5996197.24 676480.87 1624.75N 2271.67E 2792.90~ 54,43 5996245.60 676536:59 1670,46N 232929E 2866,36~ 54.35 5996292.66 676593.12 1716.30N 238730E 2940.221~ 54.29 5996339.86 676650.03 1762,35N 2445.68E 3014.50:~ 54,22 5996387.26 676707.29 0.08 0.96 0.82 1.26 0.62 1,93 0.55 1.23 0.55 86.5 87,5 88.3 89.6 90.2 92.1 92.7 93.9 94.5 BPHG-PBD BPHG-PBD BPHQ-PBD BPHG-PBD BPHO-PBD BPHG-PBD B~G-~D B~G-~D B~G-~D 8600,00 87OO.00 8800,00 48.80 49.47 48.48 52.67 :53,93 53,88 -7334.03 -7399,45 -7465.09 7378.41 7443.83 7509.47 2465.03 I00.00 2526.06 1~0.00 2586,47 1~0,00 lg08,19N 2504,60E 3089,10~ 54,17 5996434.48 676765.11 1853,38N 256524E 3164.72t~ 54.15 5996481,09 676824.66 IBTLB2N 262620E 3240.16~ 54,15 59%526,% 676884,55 1.31 1.16 0.99 95.8 96.9 97.9 BPHG-PBD BHtG-PBD BPHG-PBD 8900,O0 48.84 53,71 -7531,15 7Y/5.53 2646,68 100.00 9000.00 48.96 5333 -7~96,88 7641,26 2707.13 100.00 9100,00 48.09 53,49 -7663,11 7707.49 2767,32 100.00~ 9500.00 9600.00 9700,00 9800,00 9900,OO IOOOO.O0 47.13 48.77 50.~ 52.O7 51.11 50.21 49.10 48.45 47.67 53.37 53.46 53.28 54.47 54.39 54.10 53.84 53.37 52.91 -7730,53 -7797.50 -7862,22 -7924.72 -7986.85. -8050.24 -8114.97 -8180.88 -8247.71 7774.91 7841.88 7969.10 8031.23 g094.62 8159.35 8225.26 8292.09 282 .83 2886.66 2948.13 3010.66 3072.98 3134.63 3195.61 3256.07 3316,23 100.00 I00.00 1(]0.00 100.00 IO0.OO 100.00 1OO.O0 100,OO 100,00 1942.1TN 2686.78E 1315,24~ 54,14 5996572,73 676944,06 1986,71N 2747J6E 33~,5~ 54,13 595~618,69 677(R~,77 2031.10N 2807~E 346S,:~1~ 54.12 599C~4,50 677063.05 2075.11N 2867.23E 3539.36~ 54,11 5996709,89 677121.31 2119.36N 2926.86E 3613.61~ 54.09 5996755,55 677179,86 2164.84N 298KO3E 3689J4~ 54.08 $996802.46 677239.93 2210,86N 3051.091] 3767.90~ 54.07 5996849.96 677301.88 2256,44N 3114~E 3846.2~ 54,08 5996897,03 677364.51 2301,63N 31773'98 3923,5~ 54.08 5996943.70 677426.18 2346,46N 3239.23E 3999,81{~ 54.08 5996989,97677486.73 2391.08N 3299.77E 4075,01@ 54,07 5997036.02 677546.19 2435.70N 3~59.28E 4149,39~, 54,06 5997082.04 677604.63 0.38 0.15 0.91 0.96 1,64 131 1,76 0.96 0,93 1,13 0.74 0,85 98.3 (~8.4 99.4 1C0.3 102.0 103,8 105,5 106,5 107.4 1o8, 109.3 Il0.1 BPHG-PBD BPHG-~D BPHC.-PBD BPHG-PBD BPHO-I~D BPHG-PBD B?HC,-PBD BPH(]-PBD BPHO-PBD BPHG-PBD BPHG-PBD BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 5 Date'. 10/30/96 WeHl~th D: PI-OOMWD Measul~ Incl Drffi Sabsea ~ VeflicalCourse TOTAL (i~) (d¢g,>(~.) <it) (~) (ft> (It) (n) Closure GRID Coonlinat~ DLS Cum. DiM. Dk. Noflling Easling Dogleg 10100.00 46.72 52,53 41315.66 11360.04 3:175,$7 100,00 2480.14N 3417.66E 4222,7~ 54.03 5997127,85 677661.93 10200.00. 44.94 52.18 -113115.11411429,72 3434,45 100,00 2523.94N 3474.45E 4294.43~ 54.00 $997172,99 677717,66 10300.00 43.85 51,27 -8456.79 11501,17 3492,02 100,00 2567.27N 11529.38E 4364,33~ 53.9'/ 5997217.61 677771,54 10400.00 42.65 , 50.62 41529.63 11574.01 3548.93 100.00 2610.44N 3552.59E 4432,76~ 53.92 5997262,03 6771123.70 10500.00 40.90 50.14 -11604,20 11648,58 3604,62 100.00 2652.92N 3633.90E 4499,251~ 53.87 5997305,71 677873.99 BHA ~4 / 1.75° B.H. { 8 1/2" I-IOLE } 10600.00 40. I4 43,70 41680,25 8'/24.63 3660,92 100.00 2697.22N 3681,32E 4563.68~ 53.77 5997351.13 677920.34 10700,00 35.4;~ 32,20 41759,35 8803.73 3717,15 100.00 2745.15N 3719.12E 4622.52~ 53.57 5997399.94 677956.99 10800,00 31.11 27,59 41542.94 8887.32 3771.28 100.00 2792.62N 3746.55 E 4672.$3~ 53.30 5997448.05 677983,29 10900.00 25.64 12.78 41931,00 89'/5.38 3818,36 100,00 2836.70N 3763,34E 4732.7t~ 52.99 5997492,51 677999.03 8ulwy Tool 0.99 111,1 BPHG-PitlD 1.80 112.9 BPHG-PBD 1.26 114,2 BPHGI~D 1.28 115.5 BPHO-~D '1.78 I F/.2 BPHG-I~D 4.25 121.5 BPHG-PBD 11.45 129.9 BPHG-PIID $.02 135.0 BPHG-PBD 8.88 143.8 BPHG-PBD 11000,00 26,16 354.61 -9021,10 9065.48 3860,36 100.00 2879.82N 3766.06E 4740.94~ 52.60 5997535.68 678000,73 BNA#5 / 1,~° B,H, { 6' HOLE ] 11167,01 25.06 11311.37 -9171,89 9216'.27 3922.04 167.01 2949.44N 3749.54 E 4770.56~ 51.81 5997604.88 677982.511 11198.75 24.53 331.14 -9100.71 9245.09 3931,88 31.74 2961.47N ,11743.90E 4773,58~ 51.66 5997616.78 677976.66 7.93 151.8 BPItG-FSD 4.24 158.9 BPHM-PBD 9.43 161.9 BPItM-PBD 11230.47 26,37 323.1'/ -9229,36 9273.74 3940.63 31.72 2972.89N 3736.52E 4774.91~ 51.49 59976211.02 677~69.01 11262.15 29,10 313.0'/ -9157.41 9301.79 3948,15 31.68 2983.79N 3726,66E 47/4.01~ 51,32 5997638.68 6779511,91 11294.16 32,61 311.03 -9284.89 9329.27 3955,05 32.01 2994.77N 3714.47E 4771.3'~ 51,12 5997649.37 67'/946,46 12.48 165.8 BPHM-PBD 17.13 171.2 BPItM-PBD 11.44 174.9 BPEM-PBD 11325.81 34.17 305.51 -9311.32 9355.70 3961,32 31.65 3005.54N 3700.79E 4767.$11~ 50,92 5997659.80 67'/932.54 11357,93 35,36 298.00 -9337.72 9382.10 ]96~.92 32.12 3015.15N 3~5,24E 4761.521~}50.71 5997669.O4 67/916.76 11389.83 37.47 296.39 -9363.119 9407.77 3969,23 31.90 3023."/9N 3ffil.39E 4753.95~ 50.50 $9976T/,211 67/899.73 10.79 178.3 BPHM-PBD 13.83 182.8 BPHM-PBD 7~.6 185.1 BPHM-PBD 11418.63 39.$7 2119.34 -9385.88 9430.26 39'/1,01. 28,80 3030.75N 3551,82E 4745.6~ 50.31 5997683,114 67/883.00 11450.20 43.~ 182.32 -9409.56 9453.94 39'/0,50 31.57 3036.40N 3631,73E 4733.841~ 50.10 5997689.01 6T/861.79 BHA ~ / 2.11° B.H. { 6" HOLE ) ' 114115.31 48,02 178.02 -9434.15 9478.53 3967J,3 35.11 3040.'/8N 3607,09E 4717.7~ 49.87 5997692,111 67/838.05 !1516.911 52,60 272.46 -9454.38 9498.76 3962,39 31.67 3042.97N 3582,84 E 4700.68~ 49.66 5997694,41 6T/813.77 11548,80 55,28 Tt0.411 -9473,11 9517.49 3955.45 31,82 3043.62N 3557,13 E 46111.54~ 49.4:5 599769,[,45 6777811.05 115110,2!1 5'~.492~0.90 -9490.54 95114.92 3948.04 31.49 3043.94N 3530.91E 4661.8~ 49.24 5997694. H 67/76[,84 11611.76 $9.$5 269.97 -9506,97 9551.35 3940,33 31.47 3044.14N 3504,07E 4641.69~ 49.02 5997693,71 6T/735.02 11642,92 63,07 265.49 -9521,94 9566.32 3931.25 31.16 30~3.tNN 3476,7'/E 4620.3it~ 48.111 5997691,96 677707.76 11675.42 611,12 261.08 -9535,37 957935 3919.28 32.50 3039J6N 3447,40E 4596.0'~ 411.60 $9T/687.78 67/678,48 17.41 190.1 BPHM-~D 17,81 195.7 BPh~-?BD 16,65 201,6 BPHM-PBD 19.78 207.8 BPHM-PBD 9.81 210,9 BPHM-PBD 7.11 213.2 BPHM-PBD 7.01 215,4 BPHM~BD 16,93 220,7 BPHM..PBD 19,85 227,1 BPHM-PBD Haililmrton Energy Services - Drilling Systems PSL Survey Report Page 6 z Dat~: 10/30/96 " Wdlpath ID: PI-09~ ~ Me. asui~lncl Drift Subsea T3/D VerticalCourse T O T A L (~) (deg,) (deg.) (n) (n) (fl) (n) (f0 (it) BRA #7 / 1.15° BR, { 6" HOLE } 11751,25 7g.3[ 255.36 -9557,21 9601,59 3884.18 7[83 3024.66N 3376.47E 4533,11~ 48,15 BRA #g / 1,15° B.tE { 6" IlOLE.} 11847,03 76.6~ 251.70 -9577,90 9622.28 3832.47 95.78 1998.17N 3286.g0E ~48.83~ 47,63 11941.29 75.92 253.13 -9600,22 9644.60 3780.35 94.26 1970.50N 3199.51E 4365.86~ 47,1:] 12035,93 75.40 251.49 -9623,66 9668,04 3728.02 94.64 Z942.64N 3112.1g'£ 4283.06~ 46,60 12132,39 74.42 251.2g -9648.77 9693.15 3673.64 96.46 1912.9IN 3023.ggE 4198.6~ 46.07 12225,47 72.93 252.43 -9674.94 9719.3l 3622.08 91.08 2885.09N 2939.01E 4118.4~ 45,53 12324,17 71.25 251.42 -9705,29 9749.67 3567.97 9~.70 2855.96N 2849.73 E 4034.53~ 44,94 12356.47 '/!.42 249.79 -9715.63 9760.01 3549.76 32.30' ~45.79N 2820.87E' 4006.91~ 44,75 12390,46 70.91 250.71 -9726.60 9770.98 3530.47 33.99 ~834.92N 2790,59E 3977.96~ 44.55 BRA g9 / 1,15° B.H. { 6" HOLE. ) 12¢22,49 71.36 250.52 -9736.96 9781,34 3512.44 32.03 ~824.86N 2762,00E 3950,76~ 44.36 12515,67 '/5.91 255~93 -9763,17 9807.55 3462.66 93.11~ F/99,12N 2676.43E 3872,7'/~ 43,72 12610,87 73.55 257.49 -9788.18 9832.56 3416.18 95.20 2778.00N 2587.05 E 3796,07~ 42.96 12707.42 69.82 261,54 -9818,53 9862.91 3373.71 96.55 ~/61,29N 2496.97E 3722,85~ 42.12 12770.69 6g.43 263.16 ,9941,08 9~85.46 3348.95 63.27 ~-753.42N 2438.38E 3677,91@ 41.53 12863.91 6g.84 260.53 -9875,04 9919,42 3311,90 93.22 F/41,10N 2352,45 E 3612,16~ 40.64 BEA ltl0 / PACKED ROTARY A~SEMBLY { 6" HOLE } 12959.39 68.74 260,53 -9909,5g 9953.96 3272.07 95,45 ~r/26,46N 2264,66E 3544,32~ 39.7I 1305S.24 68.60 260.17 -9944.45 9988.83 3231.87 95.85 ~11,49N 2176,63E 3477.0~ 38.76 BRA gll/PACKED ROTARY ASSFAiBLY { 6, HOLE } 13103.35 69.13 260.83 -9961,80 10006.18 3211.77 48.11 1'/04,09N 213238E 3443,71@ 38.26 BRA #12/PACKED ROTARY ASSEIVlBLY { 6" HOLE } 13182.00 69.95 264.87 -9989.30 10033.68 3181.51 'R.65 I694.92N 2059.28E 3391,64~ 37.38 PROJECTED TO T.D. 13241.00 69_95 264.87 -10009.87 10054.25 3160.17 60.00 ~659.88N 2003.14E 3353.81~ 36.67 5997671.21 677607.94 599'/642.59 677518.95 5997612.86 677432.35 5997582.94 677345.70 5997551.13 677258.19 5997521.30 677174.01 599'/490.O6 677O85.46 599'/479.22 677056.85 ~997467.64 677026.85 ~9974~6.90 676998.51 599'/429.14 676913.59 5997405.92 676824.75 5997387,08 676735.10 5997377.83 676676.73 599'/363.49 676591,14 $99'F346,77 676503.73 5997329.73 676416.11 ~997321.29 676372.05 $997310.40 676299.21 $997304.04 676243.21 Dogleg TooL 15.33 238,7 BPHM-PBD 4.13 242,7 BPH~-PBD i.68 244.3 BPHM-PBD 1.77 245.9 BPIiIvI-PBD 1.04 246.9 BPH~-PBD !.99 248.8 BPIiM-?BD I.% 250.7 BPHM-PBD 4.81 252.3 BPHM-PBD 2.97 253.3 BPHM-~D 1,51 253.8 BPHM-PBD 7.46 260,7 BPHlvI-PBD 3,00 263,6 BPI-UvI-~D 5.55 268,9 BPHlVI-PBD 3.25 271.0 BPHM-PBD 2.66 273,5 BPI-IM-PBD 0.10 273.6 BPHIVi-PBD 0.38 274.0 BPHM-I:'BD 1.69 274.8 BPItM-FBD 4.92 278.6 BPHIvi-PBD 0,00 278.6 BPHIVi. PBD ARCO Alaska, Inc. Poat Office b.._ ! 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 12, 1997 l co,v~i via faxi~' Mr. Kenneth A. Boyd, Director Division of Oil and Gas Department of Natural Resources 3601 C Street, Suite 1380 '~"- ' ' Anchorage, Alaska 99503-5948 i~' ---' Re: Prudhoe Bay Unit AD/ 2S~297 Completion of Tract Operations ,~,~ Dear Mr. Boyd. ~ This letter serves to notify.~3hlR.~hat ARCO Alaska, Inc. complete~Lpcod'bction testing operations on th~P1-09~Tract well on February 23, 1997. We are proceeding with plugging a~uspension of the test interval in order to recomplete the well in the Point Mclntyre Reservoir. If you have any questions, please feel free to call me at 265-6846. Sincerely, J. W. Groth CC: J. F. Branch (Exxon) J. A. Leone (ARCO) D. W. Johnston (AOGCC) J. E. Pilkinton (ADOR) I. Springett (BPXA) RECEIVED MAR 19 1997 Naska 0ii & Gas Cons. Commission Anchorage ARCO AJ~ Inc. Is a aul~l~lary of AflantlcRIchfleldC~y ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 10, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re' P1-09 Tract Well Ivishak Original Gas-Oil-Ratio Dear Mr. Johnston: In accordance with Alaska Administrative Code Title 20, Chapter 25, Article 3, section 240 ARCO submits the attached Well Status Report and Gas-Off Ratio Test (Form 10-409) for Ivishak production from the P1-09 Tract Well. Should you have any questions or require additional please do not hesitate to call me at 265-6846 or Mike 263-4332. information Morgan at J. W. Groth CC' K. A. Boyd (DNR) J. F. Branch (Exxon) J. Hartz (AOGOC) J. E. Pilkington (ADOR) I. Springett (BPXA) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL STATUS REPORT AND GAS-OIL RATIO TESTS Nameo! Operator ARCO Alaska, Inc. FieldandPool P1-09 Tail Tract Operation Unit or Lease Name ADL 28297 Addre~ P. O. Box 10.0360~ Anchorage, A,K ' 99510-0360 Well Name and No. P1-09 Tract Oper.~ ~ Reporting Period January 1997 Pressures Production During Test APl Number Separator 50- Temp. o F. 22704-00 115 Gas-Oil Ratio Cu. Ft. Per Bbl. 855 All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. my knowledge. mille Senior Engineer Date 3/7/97 INSTRUCTIONS ON REVERSE SIDE Submit in duphcate CI I::! I I--I_ I I~i G S !ii I::! '~./I r' ~::: S WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Cormn. Attn.: Loft Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - P 1-09 March 5, 1997 AK-MM-60136 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Yan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. AP~#: 50-029-22704-00 ?,.k,~ Ctl& Gas Cons. 00m~r~ ,ssicn 3n~or~je 5631 Silverado Way, Suite G · Anchorage, A~aska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10795 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 2/1 1/97 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27/NK-28)] Floppy Well Job # Log Description Date BL RF Sepia Disk P1-09 qbe. 15~ ~ 'Pti I 96344 LITHODENSITY/DUAL NEUTRON/GR 961 029 1 P1-09 , 96344 COMPENSATED NEUTRON/GR 961 029 1 1 , P1-09 96344 LITHO-DENSITY/COMP NEUTRON/GR 961 029 I 1 P1-09 96344 LITHO-DENSITY/GR 961 029 I 1 ,, P1-09 96344 BOREHOLE PROFILE/GR 961 029 I 1 P1-09 96344 CEMENT BOND-VARIABLE DENSITY 961029 1 1 P1-09 'v 96344 SSTVD-LITHODENSITY-COMP NEUTRON 961 029 1 I ,., .' ...... Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Post Office B~.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 1997 Mr. Kenneth A. Boyd, Director Division of Oil and Gas Department of Natural Resources 3601 C Street, Suite 1380 Anchorage, Alaska 99503-5948 Re: Prudhoe Bay Unit Tract Operations on ADL 28297 Commingle Production from Well P1,09 Dear Mr. Boyd: [RES ENG . ~R ENG via fax I GEOL. ASST. ff "' ~. ~ .......... . ..... ~, ..... ~-, [~.. Thank you for your January 10, 1997 approval of Tract Operations for test production for well P1-09. We regret that the interactions and communications between us and the division with regard to this well's exploration tail were not smoother and more efficient. We hope that several recent meetings with your staff have been of value to the ADNR. Our experiences from this well will result in improved communications in the future. ARCO does not agree with the factual predicate for the fifth condition stated in the January 10, 1997 approval letter. When ARCO waived its claim of entitlement to field costs with regard to what was dubbed the "Expansion Acreage" portion of the Pt. Mclntyre Participating Area, it waived its fights only with regard to production from the Pt. Mclntyre PA. Because the P1-09 well test production is allocated to the Tract as a whole and the Tract is now entirely within the Prudhoe Bay Unit, the test production is governed by the 1980 Royalty Settlement which provides for a field cost deduction for all Tracts in the Unit Area. Nonetheless, ARCO will accept condition 5) in your letter of January 10, 1997 with regard to the test production for the 30 day test period, without prejudice to its rights in other contexts. This concession is made because the amount at stake is low, and is outweighed by our desire to advance a relationship and processes that will expedite future approvals of exploration and delineation activities. We will provide a brief written status report on the test after 15 days of Tract Operation as specified in the approval letter. In the meantime, please do not hesitate to contact me with any questions. SinceZy, J. W. Groth RECEIVED JAN 28 1997' Alaska Oil & Gas Cons. Commission Anchorage ARCO Aia~r,a, Inc. I. · 8ul~klary of AUantJcRIchfleldComl:mn¥ WELL LOG TRANSMITTAL To: State of Alaska January 15, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS P1-09, AK-MM-60136 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS Pl-09: ~ (~ -' l,~q 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22704-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22704-00 2" x 5" MD Neutron Porosity, Density & Gamma Ray Logs: 50-029-22704-00 2" x 5" TVD Neutron Porosity, Density & Gamma Ray Logs: 50-029-22704-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company DEPARTMENT OF NATURAL RESOURCES D/VISION OF OIL AND GAS TONY KNOWLES, GOVERNOR 3601 "C" STREET, SUITE 1380 ANCHORAGE, ALASKA 995034948 PHONE: (907) 269-8 784 January 10, 1997 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Attention: J. A. Leone Manager, Greater Pt. Mclntyre Area Subject: Prudhoe Bay Unit Tract Operations on ADL 28297 ~~Cti~fr~lt~Pl-09~ Via Fax (263-4894) and Ma 1 $ 1997 4ta~ Oil & [COMM .. [~ COMM RES ENG ;' SR ENG ~NRO ~1 ~EOL ASST- ~.; STAT TECiL ~ i- -- L FILE J - Dear Mr. Leone: On November 25, 1996, ARCO applied to initiate Tract Operations on ADL 28297 and to commingle production from the P1-09 tract well with production from Pt. Mcintyre wells for processing at the Lisburne Production Center (Application). The following day, the Division received certain requested geological, petrophysical, engineering, and operational agreement information to evaluate the Application. On December 13, 1996, the Division received an addendum to the Application explaining the allocation of production from the P 1-09 tract well through the Pt. Mc Intyre drillsite facilities and fiowlines, and the Lisburne Production Center. A~,e, a rev:ew of all the submitted information, on December 19, 1996, the Division requested additional geological information regarding the extent of the P 1-09 Permo-Triassic accumulation and the extent of any other known or suspected Permo-Triassic accumulations in the general area of the southern Pt. Mcintyre Participating Area (PMPA). This information was provided by ARCO the following day. Based on a review of all the submitted information and numerous discussions with ARCO representatives, the Application is approved for a period of 30 days from the start of test production from the Permo-Triassic interval in the P 1-09 wellbore. Production from the Permo-Triassic interval of the P 1-09 well as a Tract Operation is limited to the 30 days. A brief written status report of the tract operation should be provided to the Division after 15 days of the tract operation. Mr. J. A. Leone January 10, 1997 Page 2 In addition to the 30 day test period, the Application is also approved subject to the following terms and conditions: 1) All production from the Permo-Triassic interval in the well shall be allocated to the lease, ADL 28297. On the monthly royalty report, ARCO shall individually account for the production from the well pursuant to the December 13, 1996 Addendum to the Application. ,~ny deviation from tbJs production allocation procedure must be approved by the Division before it takes effect. 2) The currently approved well test allocation methodology for measuring and allocating gas and hydrocarbon liquids among all the participating areas that share the Lisburne Production Center (LPC) is acceptable and satisfactory for royalty purposes and for allocating gas and hydrocarbon liquids among the PAs and this Tract Operation that will share the LPC facilities. As with the currently approved allocation methodology, the division reserves the right to review and revise, if necessary, the tract well test allocations to insure compliance with the approved methodology. 3) A minimum of two well tests per the 30 day production period must be performed to determine the production from the Permo-Triassic intervals of the P1-09 well. The individual well test data for period of tract production, and the production (oil, gas and water) allocated to the well/tract should be separately reported as part of the monthly Greater Pt. McIntyre Area allocated production report submitted to the division. 4) A gas disposition and reserves debit report that accounts for the gas produced from each participating area sharing the LPC and all utilization of that gas (fuel, sales, reinjection, etc.) is submitted to the Division with the monthly production allocation report. The gas produced and allocated to the Peso-Triassic interval of the PI-09 Well should be separately accounted within the monthly gas reserves and debit report. 5) Consistent with ARCO's other production from this lease, no deductions are allowed from the state's royalty value or share of oil produced from the P1-09 Permo-Triassic Tract Operation. The royalty value of "NGLs" and gas and deductions from the state's royalty value or share of "NGLs" and dry gas allocated to the P 1-09 Permo-Triassic Tract Operation Mr. J. A. Leone January 10, 1997 Page 3 are governed by ARCO's ANS Gas Royalty Settlement Agreement. The royalty value of oil from the Tract Operation is governed by ARCO's ANS Royalty Litigation Settlement Agreement. Sincerely, Kenneth A. Boyd Director CC: David Johnston - AOGCC John E. Pilkinton- ADOR R. A. Janes -BPX Jim Branch - Exxon PB U/PMPA.P 109ractOps .txt TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 3, 1996 Mr. J. A. Leone Greater Pt Mclntyre Area Manager ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Point Mclntyre Tract Well P1-09 Request to Commingle Production Dear Mr. Leone: Your application to commingle P1-09 xvas received November 26, 1996. Your request is to commingle production from the Ivishak and Sag River formations completed in P1-09 with that of the Kuparuk formation of the Pt. McIntyre Pool in surface facilities prior to processing in the Lisburne Production Center (LPC). The Commission approves surface commingling of Sag River and Ivishak production from P1-09 with production from the Pt. Mclntyre Pool for processing at the Lisburne Production Center for a period of one year or until December 31, 1997. Well test based production allocation shall be used to determine P1-09 production volumes. Allocation data and well test data will be supplied to the Commission monthly in both computer file and report formats along ~vith the data from other pools producing to the LPC. Specifically, ARCO shall determine production according to Rule 10, Conservation Order 317A for surface commingling production in production facilities during the period that Sag River and Ivishak formations are tested. The Commission expects ARCO to test the Sag River and Ivishak formations separately. Production shall be reported to Pt. Mclntyre Undefined Pool, code 666150. Downhole wellbore commingling of the Sag River and Ivishak formations with Pt. Mclnt3're Pool fluids from the Kuparuk formation is not allowed. Downhole commingling may be reconsidered later if conditions warrant. Any NGL's produced from P1-09 will be allocated based on actual gas production volumes and NGL process simulation. Process simulations must be updated at least one per year based on NGL samples and results reported to the Commission. P1-09 must be tested at least twice each month. If the well has been shut in and cannot meet the twice monthly test frequency, it must be tested ~vithin five days of startup. All available test separator capacity within the constraints imposed by operating conditions must be utilized for well testing. Optimum test duration and stabilization time will be determined by the operator. P 1-09 Tract Well December ' ~, 1996 Water volumes will be determined by API/MPMS approved methods, or the use of industry proven, on-line water cut measurement devices approved by the Commission. API gravity, will be determined annually by an API/MPMS approved method. Gas samples will be taken and analyzed for composition from each non gas lifted producing well yearly. A semi-annual allocation process review ~vill be held with the Commission. Lisburne Production Center allocation review will be held in March and October each year. In the event of oil production capacity proration at or from the LPC, all commingled pools produced at the LPC, including P 1-09, will be prorated by an equivalent percentage of oil production recognizing mechanical limitations and operational constraints. Please call if you have questions. Sin David W. Chairman Tuckerman Babcock Commissioner XC: K. Boyd, DNR J. Pilkington, DOR P1-09COM.DOC FROM: GPMA ANCHORAGE FAX NO.: 2GJ4894 12-05-96 10:31 P.Ol FAX COVER SHEET To: Jack .Hartz AOGCC From: Mike Morgan, ~~h~ka Inc. Subject~uest for Information Note: Jack, attached is the information I sent to Mike Kotowski at the DNR. I've also have a courier delivering a hard copy of the information to you this morning. Please call me at 263-4332 with any questions. Pages to follow = 28 Faxed to 907-276-7542 Faxed from 907-263-4894 (problems, call 907-263-4948) RECEIVED _DEC 05 11996 Alaska Oil & Gas Cons. Commission Anchore. ge ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Michael R. Morgan November 26, 1996 Mr. Mike Kotowski, Petroleum Reservoir Engineer Department of Natural Resources, Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage, Alaska 99593-5948 RE: P1-09 Request for Information Mike: Enclosed is the information you requested regarding the P1-09 well. Unfortunately, I've not been able to locate a final copy of the executed agreement between ARCO, Exxon and BPX; however, I've enclosed a draft version of the ballot for your review. I will forward a copy of the executed ballot to you as soon as possible. Please consider this information confidential. Thanks in advance for your prompt response on the tract operation request. If you have any questions please call me at (907) 263-4332 or (907) 274-9995. Sincerel ,~ /' M. ~)/Morgan ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED ])cc: GPMA File: Federal/State, Unit Plan of Development ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany List of Attachments: go B. C. D. E. F. G. H. I. Surface Map showing planned well path Reserve Summary Page Petrophysical Summary of Tail Exploration Tail Log Summary with Planned Intial Perforations Kuparuk Log Section Log Summary Top Ivishak Preliminary Post-Drill Structure Map On-Site Geologist Well Summary Draft Ballot Agreement Preliminary Directional Survey ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ¢ .... EX~ON BPX °1'" ADL-~34622 . ADL-365548 ~ i 3 P2-5 !e 2 i ~Pl , ' I ~ · [ P2-20 · *¥,2 P1-'12 ! %i.-1-!4_ d ' R Ucln~re Pad( ......... ~ ~__X ..... AAI-EXXON . a~ '~!-E '... ~.:~.~.:.?~D~,~4 CONFIDENTI[L ,~CO Ail~ki, Inc. "S~~b~(_4 '~~~EL S~. 16, Ivi~hlk firgtt: ~ 161' ~NL, 1216' ~b, S~. 15, T12N-R~4E, UM T~2N-R~4E, Kup~rul fsrget: 1 ~70' FSL, 2~66' FEL, S~. 15, fo~l O~pth: 1311' FNL, 5' FEL, S¢. 16, T12N-R~4E, UM T12N-R~4E, UM ~21/96 96082002A00 Ivishak: Area Net Pay Porosity Sw Recovery Factor Reserves Total Reserves Reference MWD Log: P1-09 Tail/Larch Sag_ River 80 acres Area 100 acres 33 ft Net Pay 39.5 ft 0.153 Porosity 0.19 0.37 Sw 0.31 0.15 80 bbl/acre-ff Recovery Factor 0.08 212000 STBO Reserves 230000 STBO 442000 smo ~.~-~-~ ~d~ ~ ~ ~ /' / 13024 to 13074' MD 58 bbl/acre-ft gBNFIBENII^L RECEIVED ARCO Alaska, Inc. Confidential 11/26/96 Date: Subject: internal ~ponck~ November 6, 1996 Analysis of P 1-09 Exploration Tail From/Location: To/Location: Wayne Campaign Mitch Honeycutt Mike Morgan ATO 1454 ATO 1476 ATO 450 CONFIDENTIAL The subject well was logged over the Sag River and Ivishak intervals. This memo will document the analysis of these logs. This section of the P 1-09 well was drilled with a 6" bit and logged with the Sperry Slimhole 4-Phase MWD Resistivity/GR and Schlumberger Neutron/Density on drillpipe-conveyed wireline. We also collected a after-drilling pass (MAD) of the Resistivity, which highlights the permeable intervals. Data was received and loaded into Mincom and analysed using a standard shaly sand analysis model. Saturation parameters for the Sag River were taken from a Piano report (TSR 95- 46, "Petrology and Petrophysics Sag River Reservoir, North Slope, Alaska", by Klein and Vavra, pg. 29). Ivishak parameters and Rw were taken from local knowledge. Included with the hardcopy of this memo is a plot of the analyzed logs. Pay was summed using a 10% porosity cutoff dUe of the conglomeratic nature of the Ivishak in this well, and 60% water saturation. I interpret an OWC at 10022' TVD (9979' Subsea). This is difficult to pick because it coincides with a signficant decrease in porosity. Ivishak (/Eileen?) contains 32.5' of pay with average porosity of 15.3% (max 22%) and water saturation of 37%. Pyrite streaks at 9983' and 10007' (tvd) may mask minor additional pay. A shaly streak around 10018' should provide a partial barrier to the water below. This conglomeratic Ivishak should flow very well. The Sag pay covers 39.5' with average porosity of 19.1% and Sw of 31%. This interval shows good invasion on the MAD pass, though the well was significantly overbalanced. As a typical frae grained Sag, this section would produce oil at a reduced rate. If you have any questions, feel free to contact me. Thank you. Wayne Campaign CC Kremer, Meg Tubbs, Robert ATO 1482 ATO 1484 1VIIN]OI:IIVO,3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany o PAY ~o I 9 ,,~ ~ I-~ ~ 7~..~~' ~...~ :r:~=~ I~, , NetPax Average~ ~4 91-09 500292270&00 OH RPSIMWD_R-O ~-'--' _ .veloDment ' '~-~' O~ ARCO ~ I~. s~ L~: ~~ ~ T~N, n~ Date: T~ L~: [~S~~L, S~.15,Tl~N, R14E, UPM, G~: ~ Ha~ ~ on: 1.) MWD Su~w & ~ R~s. L~ ' L~on at T~get HoNzon / I I Thi~(+)l WELL F]E COPY J Ang~ D~/ S~I ]s~ow(-~ Th~ F~ Base Permafrost NL .1810 Note #1 T-5 NL NF " · T-3 I NL NF · IK.15 NL/NP -4,950 , L. UGNU Sd. NP -6100 · IW. Sa~ NP -610 · 'K. 12 [SeaJ:~e ~ NP NF · K-10 NP -8252 · K-5 NP NF . · K-2 NP NF · T HRZ 10376 -8482 · K-1 NP NF · ~LUBIK NP .8572 · KUPARUK NP .8592 '. ZONE 'LA" Np .8992 · MituvMch Np -9035 · L~O ' NO/NL NF Illllllllllllllllll IIIIIIIllllllllllll ' ' ' J-K UNCONF. NO / NP NF · , · ~n~k 26.8 11237 ? -9250 -gO79 171 + ?? TJH NP TR / NF TJG 'NP 'NF TJF 48 11483 -94~8 NF 17 NF TJE 52.3 11509 -~L55 NF 69 NF' TJD 63.7 11647 -9524 NF 52 112 60 - ~2;F~. tdt s .ugge~ed this.in~v~ TJC 76.8 1'1843 -9576 NF 98 NF 3- TJE~ interv~ ] 72.9 12223 -9574 -g625 50 + 164 180 ~6- ITJA NP NF NF ~2;Fa .u~ su~ested t~s interv~ 'T~GR 68.5 12742 -9831 -9805 26 + 49 73 24 ' ' ~2;Fadt sugge~ed this interval '~SHU 68.8 12876 -9880 -9878 ... 2 + 58 72 14 - ~2;Fatdt sure.ed ~s interval T SHA 68.8 12876 -9880 -9878 2 + 16 NF TSHB 68.8 12291 -9896 NF NF 15 NF TSHC 6~7 129~2 -9911 NF NF 27 NF TSHD 07 NoINF ' ' 0 TElL NO NO 0 TSAD 68.6 1~6 -9938 -9950 12- NR ~4~X7 TZ4 68.6 13036 -9938 -9950 12- 39 NF 'rz3 68.5 13147 -9977 NF/NA ROP/Sarnp. Pict< TZ2 NR NF/NA TZ2A NR' NFiI~ ' ' T Romeo JR NF / NA TZ1 / lB NR NF/NA TKVK/BaM Sd 'JR NF o~oc' I NL ' ' NF / NO I P~/G¢Dss GasJ NO NFJ 0 0 HOC~h~ 0~! NO NF NF HOT IIIIIIIIIIIIIIIJll IIIIIIIIIIIllll !lllllllllltJll'll IIIIIIIIIIIIIllllllll 0 OOWC/Gross O~ 69.5 13139 -gg92 -10150 158 - I 54 200 146 - P~k ~ 3.3 ohms Powc/H2o ~rex 68.5 '~3139 -9992 NO! ., o o ' TDD 7o 13243 -lOOlO -lO3~ Valid nomenclature. P~ase use one (~ tl~ (NR) Not Reached; (NO) No i; CTR) Truncate~ (F) Fa~ecfi (NL) Not Logged (ND) N(~ Done; (NP) Not Pk~ked; (NF) N~ Forecasted; [N/~ NOt appease ANOMAIJES - Please Chec~ DISCUSSION OF ANOMAUES OWC HOC CDC ROP Lost C~o~ Dr~ng Pro. ems Fau~ng ~2 Formation Markms #1 #1: NO attem~ to m~ marke~s axwe Kin~k #2: Pos~e Patd~ t~se intervWs. NI poa~ fatdts a/e, ~owever, based on ~inner interv~s than expected and confined rno~y to the Ioweg Kingak I Sag-$hut~k ~ may sugge~ some ~ ~ocaJized depositiona} cof~ol vs. fault outs Pa~ DRAFT - PMPA BALLOT No. 96-008A AMENDED AND RESTATED BALLOT AGREEMENT FOR ALLOWING USE OF PMPA AREA EQUIPMENT FOR EXPLORATION OPERATIONS THIS BALLOT AND AGREEMENT ("Agreement") is made and entered into by and between ARCO Alaska, Inc. ("ARCO"), BP Exploration (Alaska), Inc. ("BP")and Exxon Corporation ("Exxon") in their capacity as the Pt. Mclntyre Participating Area ("PMPA")Working Interest Owners ("PMPA Owners"), ARCO in its capacity as the Operator of the PMPA, ARCO in its capacity as a 50% owner of Prudhoe Bay Unit ("PBU") Tract 8 (ADL-28297) ("Exploration Owner"), and ARCO in its capacity as operator of Tract 8 ("Exploration Operator"), collectively referred to as the "Parties." WHEREAS, the IPA Owners, the LPA Owners and the Exploration Operator have executed IPA Ballot 93-168/LPA Ballot 93-039, as amended ("Exploration Ballot"), which allows for the sharing of certain "PBU Facilities and Equipment" (as defined in the Exploration Ballot)with the Exploration Operator; WHEREAS, Exploration Owner drilled an exploratory well ("Test Well") from PMPA Drillsite PM1 into Tract 8 ("Drilling Operations") under PMPA Ballot No. 96-008 and based on the preliminary results of that well wish to amend the terms under which it may conduct testing and production operations of the objective horizon ("Testing Operations"), (which Drilling Operati. ons and Testing Operations shall collectively be referred to as "Exploration Operations"), and desires to use certain PMPA Area Equipment in addition to PBU Facilities and Equipment for such Exploration .Operations; WHEREAS, the PMPA Owners, in accordance with Section 83.02 of the Pt. McIntyre Special Supplemental Provisions to the Prudhoe Bay Unit Operating Agreement CPBUOA"), and other agreements among and between the Greater Pt. Mclntyre Area and IPA Owners, and pursuant to the terms and conditions as described in this Agreement, are willing to CONFIDENTIAL DRAFT CONFIDENTIAL--- share PMPA Area Equipment with the Exploration Owner for use in connection with Exploration Operations. WHEREAS, during Testing Operations, the Exploration Owner's produced fluids will be commingled with PMPA produced fluids and flow through the PMPA drillsite facilities and gathering lines for processing at the LPC; and WHEREAS, the Test Well penetrated the Kuparuk formation at the same location that is planned for PMPA development well P1-09, the Exploration Owner plans to preserve the Kuparuk formation while drilling and testing the Test Well, and the PMPA Owners desire to accept reallocation of costs in the amount of $1.7 MM to reflect PMPA ownership of the wellbore for PMPA operations. NOW, THEREFORE, in consideration of the covenants and mutual promises contained herein, the Parties agree as follows: 1. Use of PMPA Area Equipment Exploration Owner shall be allowed access to and use of all PMPA Area Equipment necessary and appropriate to facilitate Exploration Operations, including without limitation the use of a drilling slot, manifolds, test separators, gas lift gas, and flow lines to the LPC. · Produced Fluids from Testing Operations The Exploration Operator, in order to perform Testing Operations, may place produced fluids into the PMPA Area Equipment if the produced fluids are acceptable (i.e. produced fluids which are free of drilling fluids and other contaminants), at the sole discretion of the PMPA Operator, for recovery. Produced fluids must contain no less than fifteen percent (15%) hydrocarbons by volume. Produced fluids that are introduced into the PMPA Area Equipment will be commingled with the PMPA Owners' CONFIDENTIAL D AFT 17,.,, produced fluids and will be metered or allocated via normal PMPA well testing procedures. · Costs, Fees, Taxes and Royalties In lieu of any charges attributable to Exploration Operations, including processing of produced fluids and disposing of produced water resulting from Testing Operations through Pt. Mclntyre Area Equipment, Exploration Owner hereby grants to the PMPA Owners all of its right, title and interest in and to such produced fluids at such time as they are placed into the PMPA Area Equipment. Exploration Owner shall be solely responsible for payment of all royalty, tax liabilities and/or other assessments, if any, that may become due and payable on the produced fluids and use of gas lift gas attributable to Testing Operations. Exploration Owner shall bear all of the risks and costs of drilling, operating and producing the Test Well 'into the PMPA Area Equipment. The PMPA Owners shall pay all permanent facility tie-in costs for the Test Well and all production costs associated with use of PMPA Equipment. Further, the PMPA Owners shall be responsible for all LPA and IPA facility sharing fees, associated with processing, disposal and or delivery of produced fluids resulting from Testing Operations, provided, however, Exploration Owner shall pay all such LPA and IPA facility sharing fees attributable to the 40,000 stock tank barrels of crude and condensate referenced in Article 4 herein. 4. Allocation of Produced Fluids The PMPA Owners agree to allocate to Exploration Owner the first 40,000 stock tank barrels of crude and condensate produced from the Test Well from the zones lying between the top of the. Sag River formation and the base of the Ivishak formation, as seen in the log for the Pt. Mclntyre 4/3 well (API#50-029217791-1) between the measured depths of 10,561' and 11,016'. Thereafter, oil and gas produced from the Test Well during Testing Operations will be allocated among the PMPA Owners according to CONFIDENTIAL the equity percentages production. and accounting methodologies applicable to PMPA gONFIBENII^L The PMPA Owners acknowledge that replacement of PMPA fluids with Test Well fluids may occur on a continuous basis during Testing Operations. It will be the responsibility of the PMPA Operator to manage the Testing Operations such that ongoing PMPA operations are not compromised. For the purposes of Testing Operations hereunder, all Test Well and Greater Pt. Mclntyre Area ("GPMA")well production shall be produced b y prioritizing all production on a gas-to-oil ratio (GOR)or water-to-oil ratio (WOR) seriatim basis. Thus, Test Well production under this Agreement will not be allowed to flow unless it has a lower GOR and/or WOR than the highest GOR and/or WOR PMPA well being produced, thus ensuring PMPA Owners no loss in oil production and no backout of PMPA oil. 6. Test Well Data Provided to PMPA Owners. Exploration Owner agrees to provide to the PMPA Owners all geological information and well data acquired by Exploration Owner via Exploration Operations. Exploration Owner shall be under no obligation to disclose interpretive data to PMPA Owners. PMPA Owners shall keep all Test Well geological information and well data provided by Exploration Owner confidential, as provided in Article 6 of the PBU Operating Agreement. 7. Reallocation of Cost of Test Well to PMPA Owners. Upon completion of all Exploration Operations by Exploration Owner, including a) plug back of Test Well to base of the Kuparuk formation with four and one-half inch (4-1/2") completion tubing, and b)installation of manifold connections, and provided the condition of the Test Well is otherwise acceptable to the PMPA Owners, the PMPA Owners agree to a reallocation of cost of $1.7 MM from the Exploration Owner to the PMPA .CONFIDENTIAL Owners. If the costs of the Test Well are reallocated to the PMPA Owners as described above, PMPA Owners will also accept all future obligations and liabilities relating to the Test Well, including abandonment liabilities, arising after the reallocation conditions are met. After the reallocation conditions are met, the Test Well will be referred to as P1-09 and treated for all purposes as PMPA Area Equipment. Exploration Owner makes no representations, statements, or warranties except as herein stated. 8. Indemnification of PMPA Owners Exploration Owner hereby agrees to accept liability for all damage to PMPA Area Equipment arising from its use thereof, delivery and redelivery of gas lift gas or the placement of produced fluids in such facilities. To the full extent allowed by law, Exploration Owner agrees to defend, indemnify and hold the PMPA Owners harmless from any and all claims, demands, liabilities, costs (including attorney's fees), assessments, penalties, fines and obligations, including personal injury, property damage and environmental damages, which may result from its use of PMPA Area Equipment pursuant to this Agreement. Additionally, Exploration Owner hereby agrees to defend, ir~demnify, and hold the PMPA Owners harmless from any and all claims, demands, liabilities, costs (including attorney's fees), assessments, penalties, fines and obligations which may result from: 1) the PMPA Owners' refusal to accept produced fluids into PMPA Area Equipment during Testing Operations; 2)the Exploration Owner's inability to obtain access to any PMPA Area Equipment by virtue of use by the PMPA Owners or any other approved third parties; 3) any spill or discharge of fluids by Exploration Owner notwithstanding the cause of such spill or discharge; 4) the PMPA Owners' exercise of any reserved rights under this Agreement or 5)receipt of any produced fluid under this Agreement. 9. Invoicing CONFIDENIIAL DRAFT [;BN[IIIENIIAL All obligations for fees or cost reimbursement hereunder will be processed through a third party billing process whereby invoices shall be issued between the Exploration Operator and the PMPA Operator. Invoices shall be paid in full within sixty (60) calendar days of their receipt. 10. Audit Rights The Parties shall have the right, as provided in the PBUOA, to audit the accounts and records relating to this Agreement for a period not to exceed two (2) years from the end of the year of the invoice. All records and accounts will be made available upon written request. No adjustment shall be made after two years from the end of the year during which Exploration Operations pursuant to this Agreement are concluded. 11. Permits, Approvals and Authorizations The Exploration Operator is responsible for all necessary permits, approvals and authorizations for the Exploration Operations pursuant to this Agreement. Exploration Operator's obligation shall include all necessary permits, approvals, and authorizations for Drilling Operations, Testing Operations, commingled production and production allocation. However, in seeking such permits, approvals and authorizations, the Exploration Operator must coordinate with and be governed by the standards and procedures established by the PMPA Owners and PMPA Operator. 12. PMPA Owners' Reserved Rights Exploration Owner may utilize PMPA Area Equipment only to the extent its use does not conflict with PMPA Owners' operations or other prior authorized third party uses. In the event that there is a conflict between the PMPA Owners and Exploration Owner concerning the use of any facilities or equipment referenced herein, uses required by the PMPA Owners and prior authorized third parties shall take priority. The PMPA Owners reserve the right to close or modify any facility and/or equipment referenced herein, or remove it from the scope of this Agreement. 13. Effective Date C§NFIBENTI[L This Ballot Agreement is effective when approved by the Exploration Operator, the Exploration Owner, the PMPA Operator and a 90% vote of the PMPA Owners. 14. Term The Exploration Owner shall complete all Exploration Operations and plug back the Test Well on or before November 1, 1997, but may terminate Exploration Operations and exercise its rights under Section 7 of this Agreement at any time. Notwithstanding the foregoing, the PMPA Subsurface Development Team can elect to terminate all Exploration Operations associated with the Test Well at any time after the first 40,000 stock tank barrels have been produced by an affirmative vote from two of the three PMPA Owners. Following termination of Test Well production, the Exploration Owner shall promptly plug back the Test Well, after which Exploration Owner's right to utilize the PMPA Area Equipment shall cease. Other terms of the Agreement, in particular those relating to liabilities and payment obligations, shall survive the termination of the Exploration Owner's right to use PMPA Area Equipment. 15. Terminology All capitalized terms found in this Agreement shall have the same meaning as defined in the PBUOA. 16. Counterparts CONFIDENTIAL This Agreement may be executed in counterpart which will be deemed and be treated as a single original instrument. 17. Precedent This document is not intended, nor shall it be construed, to set a precedent for any future agreement among the Parties. 18. Third Party Agreements The PMPA Owners reserve the right to enter into additional agreements for the use of PMPA Area Equipment with other parties without notice to or consent of Exploration Owner. 19. Conflict If the provisions of this Agreement conflict with the provisions of the PBUOA, as amended, including the Pt. Mclntyre Special Supplemental Provisions, the provisions of the PBUOA shall prevail. 20. Rights to Assign Restricted The rights granted to Exploration Owner herein are not assignable, in whole or in part, to any other third parties. IN WITNESS WHEREOF, the Parties have executed this Ballot Agreement on the day opposite their respective signatures. EXPLORATION OWNER ARCO ALASKA, INC. By: Date' Title: EXPLORATION OPERATOR ARCO ALASKA, INC. By: Date' Title: Pt. McINTYRE PARTICIPATING AREA WORKING INTEREST OWNERS ARCO ALASKA, INC. By: Date: Title: BP EXPLORATION (ALASKA) INC. By: Date: Title' EXXON CORPORATION By: Date: Title: Pt. McINTYRE PARTICIPATING AREA OPERATOR ARCO ALASKA, INC. By' Date: Title' ~ARCO Alask. inc. . Geological Morning Report Halliburton Energy Services o Drilling Systems PSL Survey Report Survey Reference: WELLHEAD R~erenc~ World Coordinates: Lat. 70.23.27 N - Long. 148.34.55 W Rtffcren~c GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (fl): 5994568.10 N 674303.82 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Rcfercncc: W'~-~.LHEAD Calculated using the Minimum Curvature Method Computed ~slng WIN-CADDS REV2. 2. 2 Ve, rtical Section Plane: 17.11 deg. Page t Job No: 00262 Date: 10/30/96 Time: 4:40 pm Wcllpath ID: PI-O9M3ArE Date Created: 10/1/96 Last Revision: 10/30/96 BPX - Shared Services Drilling Alaska State Plane: Zone4 Pt Mac: PMI P 1-09 Aa-Built PI-09MWD Meaatred Inci Dritt Sub,ca (n) (deg.) (deg.) (n) 0.00 0.00 0.00 44.38 BI-IA #1 / 1.50° B.H. ( 12 1/4" HOLE } 100.00 0.30 93.62 -55.62 200.00 0.36 80.79 -155.62 TVD Vertical Course Section Len~ (n) (fi) (n) 0.00 0.00 0.00 100.00 0.06 100.00 200.00 0.26 100.00 T O T A L CIo~ure R~ctangular ~ Dist. Dh'. (fl) (fl) (fl) (deg.) 0.00N 0.00E 0.00~ 0.00 0.02 S 0.26 E 0.26~ 93.62 0.02N 0.83 E 0.83~ 88.82 Nor!bingo Easting (n) (n) 5994568.11 674303.82 5994568.10 674304.08 5994568.14 674304.65 DLS (ds/100n) 0.00 0.30 0.09 Dogleg (deg) 0.0 0.3 0.4 Survey Tool UNKNOWN BPHG-PBD BPHG-PBD 300.00 0.66 123.55 -255.61 299.99 400.00 1.87 129.57 -355.59 399.97 50000 2.41 116.15 -455.52 499.90 600.00 3.40 115.68 -555.39 599.77 701.00 5.86 125.36 -656.05 700.43 800.00 6.60 129.81 -754.47 798.85 900.00 6.97 130.47 -853.77 898.15 1000.00 7.18 130.07 -953.01 997.39 ! 100.00 6.72 128.91 -1052.27 1096.65 0.24 100.00 -0.55 100.00 -1.50 100.00 -2.27 .-4.34 -8.11 -12.74 -17.58 -22.19 1200.00 4.34 128.63 -1151.80 1196.18 -25.75 100.00 0.25 S 1.62 E 1.64~ 98.79 1.61 S 3.36E 3.73~ 115.58 3.57 S 6.51E 7.42~ 118.79 5.79 S 11.07E 12.4~ ! 17.61 10.07 S 17.97 E 20.60~ 119.26 16.64 S 26.46 E 31.26~ 122.16 24.25 S 35.49 E 42.9~ 124.35 32.21 S 44.89 E 55.25~ 125.66 39.91 S 54.23 E 67.33~ 126.35 45.95 S 61.74 E 76.96~ 126.66 5994567.89 674305.45 5994566.58 674307.22 5994564.68 674310.41 5994562.58 674315.02 5994558.46 674322.02 5994552.09 674330.66 5994544.69 674339.87 5994536.95 674349.45 5994529.47 674358.96 5994523.61 674366.61 0.47 1.22 0.73 0.99 2.55 0.89 0.38 0.22 0.48 2.38 0.9 2.1 2.8 3.8 6.4 7.3 7.6 7.8 8.3 10.7 BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 2 Date: 10/30/96 Wellpath ID: PI-09MWD Measured 1301.00 1399.00 1500.00 1600.00 1702.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2699.00 2799.00 2900.00 3O00.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3720.00 3800.00 3900.00 4000.00 410000 4200.00 lncl (deg.) 3.16 1 34 0.67 0.52 0.54 0.58 0.65 0.81 0.98 1.11 1.18 1.29 0.98 1.90 1.37 1.13 0.85 0.83 0.84 0.87 0.98 0.89 3.04 3.51 6.08 8.07 9.89 10.49 12.47 15.10 Drift Dir. (deg.) 126.35 i18.47 102.19 99.44 94.12 96.52 90.69 91.95 82.99 81.27 77.52 77.27 69.28 312.95 316.88 6.89 12.09 12.82 18.10 19.36 12.02 21.75 54.67 58.52 59.78 60.00 60.17 60.52 57.61 50.74 Subsea Depth -1252.58 -1350.49 - 1451.48 -1551.47 -1653.47 -1751.46 -1851.46 -1951.45 -2051.43 -2151.42 -2251.40 -2351.37 -2451.36 -2551.34 -2650.30 -2750.27 -2851.26 -2951.25 -3051.24 -3151.23 -3251.21 -3351.20 -3451.14 -3550.97 -3670.54 -3749.93 -3848.70 -3947.12 -4045.12 -4142.24 (n) 1296.96 1394.87 1495.86 1595.85 1697.85 1795.84 1895.84 1995.83 2095.81 2195.80 2295.78 2395.75 2495.74 2595.72 2694.68 2794.65 2895.64 2995.63 3095.62 3195.61 3295.59 3395.58 3495.52 3595.35 3714.92 3794.31 3893.08 3991.50 4089.50 4186.62 Vertical (n) -28.07 -29.22 -29.44 -29.33 -29.16 -28.96 -28.71 -28.36 -27.83 -27.06 -26.13 -25.06 -23.98 -22.73 -21.42 -19.86 -18.13 -16.67 -15.22 -13.73 -12.12 -10.49 -7.61 -3.22 4.21 11.44 22.86 35.75 50.57 69.63 Course T 0 T A L Closure GRID Coordinates Length Rectangular Offsets Dist. Dff. Northing Fasting (a) (fl) (fl) (fl) (deg.) (tt) (ti) 101.00 49.99 S , 66.96E 83.56~126.74 5994519.70 674371.93 98.00 52.22 S 70.30E 87.57~126.60 5994517.55 674375.31 101.00 52.99 S 72.07E 89.45~126.32 5994516.82 674377.10 100.00 53.18 S 73.09E 90.3~126.04 5994516.64 674378.12 102.00 53.30 S 74.02E 91.21~125.75 5994516.55 674379.06 98.00 53.38 S 74.98~ 92.04~125,45 5994516.49 674380.02 100.00 53.45 S 76.05E 92.95(~125.10 5994516.45 674381.09 100.00 53.48 S 77.32E 94.01~124.67 5994516.45 674382.36 100.00 53.40S 78.87E 95.25(~124.10 5994516,56 674383.91 100.00 53.15 S 80.68E 96.61~123.37 5994516.86 674385.71 100.00 52.78 S 82.64E 98.06~122.56 5994517.27 674387.67 100.00 52.31S 84.75E 99.59~121.68 5994517.79 674389.76 100.00 51.76 S 86.64E 100.93~120.85 5994518.39 674391.64 100.00 50.33 S 86.23 E 99.84~120.27 5994519.81 674391.20 99.00 48.34 S 84.22E 97.11~119.86 5994521.74 674389.14 100.00 46.49 S 83.52E 95.5~119.10 5994523.58 674388.40 101.00 44.77 S 83.80E 95.01~118.11 5994525.31 674388.63 100.00 43.34 S 84.11E 94.62~117.26 5994526.74 674388.92 100.00 41.94 S IM.50E 94.34~116.39 5994528.15 674389.27 100.00 40.52 S 84.98E 94.15~115.49 5994529.58 674389.72 100.00 38.97 S 85.41E 93.88~114.53 5994531.14 674390.11 100.00 37.41S 85.88 E 93.67~113.54 5994532.71 674390.54 100.00 35.16 S 88.33 E 95.0'/~111.70 5994535.02 674392.94 100.00 32.03 S 93.10 E 98.46~108.98 5994538.26 674397.64 120.00 26.91S 101.73 E 105.23(~104.82 5994543.58 674406.14 80.00 21.97 S 110.25 E 112.42~101.27 5994548.72 674414.55 100.00 14.18 S 123.78 E 124.59(~ 96.54 5994556.81 674427.89 100.00 5.43 S 139.16 E 139.26(.~. 92.24 5994565.92 674443.06 100.00 4.83N 156.20E 156.28~ 88.23 5994576.58 674459.86 100.~) 18.86N 175.41E 176.42(~ 83.86 5994591.05 674478.73 DLS (dg/100a) 1.18 1:68 0.91 0.15 0.05 0.05 0.09 0.16 0.22 0.13 0.10 0.11 0.35 2.49 0.55 1.08 0.29 0.02 0.08 0.04 0.16 0.18 2.34 0.52 2.14 2.49 1.82 0.60 2,06 3.09 Dogleg (deg) 11.9 13.5 14.5 14.6 14.7 14.7 14.8 15.0 15.2 15.3 15.4 15.5 15.9 18.4 18.9 20.0 20.3 20.3 20.4 20.4 20.6 20.8 23.1 23.6 26.2 28.2 30.0 30.6 32.7 35.8 Survey Tool BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 3 Date: 10/30/96 Wellpath ID: PI-O9MWD Measured Ind Drift Subsea (fi) (deg.) ~(dcg.) (fi) (fi) 4300.00 17.56 50.54 -4238.20 4282.58 4400.00 20.28 50.22 -4332.78 4377.16 4500.00 22.50 51.39 =4425.89 4470.27 4600.00 24.57 52.03 -4517.57 4561.95 4700.00 26.41 51.65 -4607.83 4652.21 4800,00 28,02 53,47 -4696,76 4741.14 4900.00 29.87 53.31 4784.26 5000.00 31.39 55.56 -4870.31 BI-IA #2 / 1.25° B.H. { 8 1/2" HOLE } 5100.00 34.17 54.61 4954,38 4828.64 4914.69 4998.76 5200.00 35.85 54.93 -5036.28 5080.66 5300.00 39.22 53.96 =5115.57 5159.95 5400.00 40.37 55.73 -5192.40 5236.78 5500.00 43.78 53.25 4266.62 5311.00 5600.00 46.77 52.77 -5336.99 5381.37 5700.00 48.1M 53.65 -5404.67 5449.05 5800.00 50.12 53.71 -5470.16 5514.54 5900.00 49.54 52.22 -5534.67 5579.05 6000.00 49.72 51.80 -5599.44 5643.82 6100.00 49.67 51.53 -5664.13 6200.00 47.57 51.96 -5730.23 6300.00 47.74 53,41 -5797.59 6400.00 48.79 54.89 -5864.16 6500.00 48.62 52.17 -5930.16 6600.00 49.41 52,62 -5995.75 6700.00 47.95 52.25 -606 i.77 6800.00 47.73 52.57 -6128.89 BHA//3 / 1.15° B.H. { 8 1/2" HOLE } 6900.00 47.85 52.89 -6196.08 5708.51 5774.61 5841.97 5908.54 5974.54 6040.13 6106.15 6173.27 6240.46 Vemcnl (fl) 93.07 120.18 150.51 183.37 218.74 255,98 295.00 335.49 378.17 423.59 472.03 522.64 575.90 633.45 692.92 753.61 815.53 878.02 940.83 1002.56 1062.67 1122.23 1182.68 1244.30 1305.57 1366.07 1426.28 7000.00 47.69 52.65 -6263.29 6307.67 1486.44 Course T O T A L Closure GRID Coordinates Length Rs~clangula~Offsets Dist. Dir. Northing Fasting 0i) (fi) (t~) (fl) (des.) (fi) (fi) 100.00 36.69N . 197.14E 200.53~ 79.46 5994609.39 674500.04 100.00 57.37N 222.11E 229.40~ 75.52 5994630.64 674524.52 100.00 80.41N 250.39E 262.98~ 72.20 5994654.33 674552.25 100.00 105.14N 281.73E 300.71~ 69.53 5994679.78 674583.00 100.00 131.73N 315.57E 341.96~ 67.34 5994707.16 674616,21 100,00 159,51N 351.88'E 386.35~ 65.61 5994735.78 674651.86 100.00 188.38N 390.73 E 433.7'/~ 64.26 5994765.54 674690.02 100.00 217.99N 432.18E 484.04~ 63.23 5994796.11 674730.77 100.00 248.99N 476.56E 537.68~ 62.41 5994828.13 674774.41 100.00 282.08N 523.43E 594.5~ 61.68 5994862.31 674820.48 100.00 317.51N 572.97E 655.07~ 61.01 5994898.89 674869.18 100.00 354.35N 625.30E 718.73~ 60.46 5994936.94 674920.64 100.00 393.30N 679.80E 785.38~ 59.95 5994977.15 674974.21 100.00 436.05N 736.54E 855.94~ 59.37 5995021.22 675029,93 100.00 480.13N 795.50E 929.16~ 58.89 5995066.66 675087,83 100.00 524.89N 856.38E 1004.4~ 58.50 5995112.83 675147.64 100.00 570.90N 917.38E 1080.51~ 58.11 5995160.26 675207.54 100.00 617.80N 977.42 E 1156.30~ 57.70 5995208.54 675266.47 100.00 665.10N 1037.24E 1232.16~ 57,33 5995257.23 675325.16 100.00 711.56N 1096.15E 1306.85~ 57,01 5995305.06 675382.96 100.00 756.36N 1154.93E 1380.56~ 56.78 5995351.22 675440.67 i00.00 800.05N 1215.42E 1455.11~ 56.64 5995396.32 675500.11 100.00 844.70N 1275.83E 1530.12~ 56.49 5995442.37 675559.45 100.00 890.77N 1335.63E 1605.42~ 56.30 5995489.82 675618.16 100.00 936.55N 1395.17E 1680.36~ 56.13 5995536.99 675676.59 100.00 981.77N 1453.90E 1754.34~ 55.97 5995583.57 675734.25 100.00 1026.62N 1512.85E 1828.2~ 55.84 5995629.80 675792.12 !00.00 1071.42N 1571.80E 1902.24(~ 55.72 5995675.97 675850.00 DLS (dg/100fl) 2.46 2.72 2.26 2.09 i.85 1.81 1.85 1.90 2.83 1.69 3.42 1.61 3,79 3,01 1.43 2.08 1.28 0.37 0.21 2.12 1.09 1.52 2.05 0.86 1.49 0.32 0.27 0.24 Dogleg (deg) 38.2 41.0 43.2 45.3 47.2 49.0 50.8 52.7 55.5 57.2 60.7 62.3 66.1 69.1 70.5 72.6 73.9 74.2 74.4 76,6 77,6 79.2 81.2 82.1 83.6 83.9 84.2 84.4 Survey Tool BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 4 Date: 10/30/96 Wellpath ID: PI-O9MWD Measmed 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 71RIO.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 Incl (deg.) 48.05 48.67 48.94 48.79 48.34 48.23 Drift Dir. (deg.) 52.54 52.28 52.21 52.16 52.42 52.48 Sm mpa (fl) -6330.37 -6396.82 -6462.68 -6528.46 -6594.64 ..6661.18 Section Length (fl) (fl) (fl) TOTAL (fi) (a) 6374.75 1546.82 100.00 1116.47N .1630.71E 6441.20 1607.82 I00.00 i 162.06N 1689.93 E 6507.06 1669.35 100.00 1208.13N 1749.43 E 6572.84 1730.99 100.00 1254.31N 1808.92 E 6639.02 1792.27 100.00 1300.17N 1868.23 E 6705.56 1853.16 100.00 1345.66N 1927.42 E 48.16 52.43 -6727.84 6772.22 1913.96 100.00 1391.08N 1986.52E 47.41 51.63 -6795.03 6839.41 1974.69 100.00 1436.65N 2044.90 E 46.87 50.78 -6863.05 6907.43 2035.39 100.00 1482.57N 2102.04 E 49.77 49.09 51.70 51.45 51.91 51.56 52.67 53.93 53.88 53.71 53.83 53.49 53.37 53.46 53.28 54.47 54.39 54.10 53.84 53.37 52.91 47.89 47.52 47.61 47.09 48.27 47.79 48.80 49.47 48.48 -6930.77 -6998.06 -7065.54 -7133.30 -7200.62 -7267.50 -7334.03 -7399.45 -7465.09 -7531.15 -7596.88 -7663.11 -7730.53 -7797.50 -7862.22 -7924.72 -7986.85 -8050.24 -8114.97 -8180.88 -8247.71 48.84 48.96 48.09 47.13 48.77 50.57 52.07 51.11 50.21 6975.15 2096.99 100.00 1529.60N 2158.63 E 7042.44 2159.50 100.00 1577.71N 2214.81E 7109.92 2221.18 100.00 1624.75N 2271.67E 7177.68 2281.82 100.00 1670.46N 2329.29E 7245.00 2342.70 100.00 1716.30N 2387.30E 7311.88 2403.88 100.00 1762.35N 2445.68E 7378.41 2465.03 100.00 1808.19N 2504.60 E 7443.83 2526.06 100.00 1853.38N 2565.24 E 7509.47 2586.47 100.00 1897.82N 2626.20 E 7575.53 2646.68 100.00 1942.17N 2686.78E 7641.26 2707.13 100.00 19tRL71N 2747.56E 7707.49 2767.32 100.00 2031.10N 2807.92E 7774.91 2826.83 100.00 2075.11N 2867.23 E 7841.88 2886.66 100.00 2119.36N 2926.86E 7906.60 2948.13 100.00 2164.1MN 2988.03 E 7969.10 3010.66 100.00 2210.86N 3051.09E 8031.23 3072.98 100.00 2256.44N 3114.83 E 8094.62 3134.63 100.00 2301.63N 3177.59E 8159.35 3195.61 100.00 2346.46N 3239.23 E 8225.26 3256.07 100.00 2391.08N 3299.77 E 8292.09 3316.23 100.00 2435.70N 3359.28E 49.10 48.45 47.67 Closure DiM. Dir. (fi) (deg.) 1976.2~1~ 55.60 2050.91~ 55.49 2126.05(~ 55.37 2201.2~ 55.26 2276.12~ 55.16 2350.69(~ 55.08 2425.1~ 55.~ 2499.1~ 54.91 2572.2~ 54.~ 2~5.6~ 54.68 2719.3~ 54.54 2792.~ 54.43 2~.~ s4.~s 29~.2~ 54.29 3014.~ 54.22 3089.1~ 54.17 31~.7~ 54.15 32~.~ 3315.2~ ~.14 33~.5~ 54.13 3~5.5~ ~.12 3s~9.~ s4.~ ~6~.6~ s4.09 ~6~.~ s4.0~ 3767.~ 54.07 3~.2~ s4.o8 3923.5~ 54.08 ~999.8~ s4.08 407s.0~ s4.07 4149.3~ 54.~ Northing Easting (fl) (fi) 5995722.39 675907.83 5995769.36 675965.96 5995816.81 676024.35 5995864.38 676082.74 5995911.61 676140.95 5995958.49 676199.04 5996005.29 676257.05 5996052.21 676314.34 5996099.47 676370.37 5996147.82 676425.84 5996197.24 676480.87 5996245.60 676536.59 5996292.66 676593.12 5996339.86 676650.03 5996387.26 676707.29 5996434.48 676765.11 5996481.09 676824.66 5996526.96 676884.55 5996572.73 676944.06 5996618.69 677003.77 5996664.50 677063.05 5996709.89 677121.31 5996755.55 677179.86 5996802.46 677239.93 5996849.96 677301.88 5996897.03 677364.51 5996943.70 677426.18 5996989.97 677486.73 5997036.02 677546.19 5997082.04 677604.63 DLS (dg/lOOfl) 0.37 0.65 0.28 0.15 0.49 0.12 0.08 0.96 0.82 1.26 0.62 1.93 0.55 1.23 0.55 1.31 1.16 0.99 0.38 0.15 0.91 0.96 1.64 1.81 1.76 0.96 0.93 1.13 0.74 0.85 Dogleg (deg) 84.8 85.4 85.7 85.8 86.3 86.5 86.5 87.5 88.3 89.6 90.2 92.1 92.7 93.9 94.5 95.8 96.9 97.9 98.3 98.4 99.4 100.3 102.0 103.8 105.5 106.5 107.4 108.5 109.3 I!0.1 Survey Tool BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD' BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPItG-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 5 Date: 10/30/96 Welipath ID: PI-09MWD Measured lncl Drift (it) (deS.) (deg.) Subsea TVD Depth (It) Vertical Course (a) 10100.00 46.72 52.53 -8315.66 8360.00 3375.87 100.00 10200.00 44.94 52.18 -8385.34 IM29,72 3434.45 100.00 10300.00 43.85 51.27 -8456,79 8501.17 3492.02 100.00 10000.00 42.65 50.62 -8529.63 8574.01 3548.93 100.00 10500.00 40.90 50.14 -8604.20 8648.58 3604.62 100.00 BI'iA//4 / 1.75° B,H. { 8 i/2" HOLE } 10600.00 40.14 43.70 -8680.25 8724.63 3660.92 100.00 10700.00 35.45 32.20 -8759.35 8803.73 3717.85 100.00 10800.00 31.11 27.59 -8842.94 8887.32 3771.28 100.00 10900.00 25.64 12.78 -8931.00 8975.38 3818.36 100.00 9065.48 3860.36 100.00 9216.27 3922.00 167.01 9245.09 3931.88 31.74 11000.00 26.16 354.61 -9021.10 BHA#5/1.83° B.H.{ 6"HOLE} 11167.01 25.06 338.37 -9171.89 11198.75 24.53 331.34 -9200.71 11230.47 26.37 323.17 -9229.36 9273.74 3940.63 31.72 !1262.15 29.10 313.07 -9257.41 9301.79 3948.15 31.68 11294.16 32.61 311.03 -9284.89 9329.27 3955.05 32.01 11325.81 34.17 305.51 -9311.32 11357.93 35.36 298.00 -9337.72 11389.83 37.47 296.39 -9363.39 9355.70 3961.32 31.65 9382.10 3965.92 32.12 9407.77 3969.23 31.90 9430.26 3971.01 28.80 9453.94 3970.50 31.57 9478.53 3967.43 35.11 11418.63 39.87 289.34 -9385.88 11450.20 43.00 282.32 -9409.56 BHA#6/2.12° B.H.{ 6" HOLE} 11485.31 48.02 278.02 -9434.15 11516.98 52.60 272.46 -9454.38 9498.76 3962.39 31.67 11548.80 55.28 270.48 -9473.11 9517.49 3955.45 31.82 11580.29 57.49 270.90 -9490.54 9534.92 3948.04 31.49 11611.76 59.55 269.97 -9506.97 9551.35 3940.33 31.47 11642.92 63.07 265.49 -9521.94 9566.32 3931.25 31.16 11675.42 68.12 261.08 -9535.37 9579.75 3919.28 32.50 T O T A L Closure GRID Coordinates Rectangular Offsets Dist. Dir. Northing Easting (fl) (fl) (fl) (deg.) (n) (n) 2480.14N .3417.66E 4222.73~ 54.03 5997127.85 677661.93 2523.94N 3474.45E 4294.4~ 54,00 5997172.99 677717.66 2567.27N 3529.38E 4364.3:~ 53,97 5997217.61 677771.54 2610.44N 3582.59E 4432.76~ 53.92 5997262.03 677823.70 2652.92N 3633.90.E 4499.25~ 53.87 5997305.71 677873.99 2697.22N 3681.32E 4563.68~ 53.77 5997351.13 677920,34 2745.15N 3719.12E 4622.52~ 53.57 5997399.94 677956.99 2792.62N 3746.55E 4672.83~ 53.30 5997448.05 677983.29 2836.70N 3763.34E 4712.70~ 52.99 5997492.51 677999.03 2879.82N 3766.06E 4740.94~ 52.60 5997535.68 678000.73 2949.44N 3749.54E 4770.56~ 51.81 5997604.88 677982.58 2961.47N 3743.90E 4773,58~ 51.66 5997616.78 677976.66 2972.89N 3736.52E 4774.90~ 51.49 5997628.02 677969.01 2983.79N 3726.66E 4774.00~ 51.32 5997638.68 677958.91 2994.77N 3714.47E 4771.3'/~ 51.12 5997649.37 677946.46 3005.54N 3700.79E 4767.51~ 50.92 5997659.80 677932.54 3015.15N 3685.24E 4761.52~ 50.71 5997669.00 677916.76 3023.79N 3668.39E 4753.9~ 50.50 5997677.28 677899.73 3030.75N 3651.82 E 4745.66~ 50.3 i 5997683.84 677883.00 3036.40N 3631.73E 4733.84~ 50.10 5997689.01 677862.79 3040.78N 3607.09E 4717.78~ 49.87 5997692.81 677838.05 3002.97N 3582.84E 4700.68~ 49.66 5997694.41 677813.77 3043.62N 3557.13 E 4681.54~ 49.45 5997694.45 677788.05 3003.94N 3530.91E 4661.85~ 49.24 5997694.15 677761.84 3044.14N 3504.07E 4641.69(~ 49.02 5997693.71 677735.02 3043.04N 3476.77E 4620.3~ 48.81 5997691.96 677707.76 3039.56N 3447.40E 4596.03~ 48.60 5997687.78 677678.48 DLS (dg/100fl) 0.99 1.80 1.26 1.28 1.78 4.25 8.45 5.02 8.88 7.93 4.24 9.43 12.48 17.13 11.44 10.79 13.83 7.26 17.41 17.81 16.65 19.78 9.81 7.11 7.01 16.93 19.85 Dogleg (deg) 111.1 112.9 114.2 115.5 117.2 121.5 129.9 135.0 143.8 151.8 158.9 161.9 165.8 171.2 174.9 178.3 182.8 185.1 190.1 195.7 201.6 207.8 210.9 213.2 215.4 22O.7 227.1 Surv~ Tool BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHG-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHlvI-PBD BPHM-PBD BPIilVl-PBD BPHlVI-PBD BPHM-PBD BPliM-PBD BPHM-PBD BPHIVI-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 6 Date: 10/30/96 Welipath ID: PI-O9MWD Measured lncl Drift Subsea TVD Verlical Course T O T A L Closure Depth Dir. Deplh Section Length Rectangular Offsets Dist. Dir. (fi) (deg.) (deg.) (fl) (it) (it) (fl) (it) (fl) (fl) (deg.) BHA #7 / 1.15° B.H. { 6# HOLE } 11751.25 78.38 255.36 -9557.21 9601.59 3884.18 75.83 3024.66N 3376.47E 4533.11~ 48.15 BHA #8 / 1.15°B.H. { 6" HOLE } 11847.03 76.68 251.70 -9577.90 9622.28 3832.47 95.78 2998.17N 3286.80 E 4448.83~ 47.63 11941.29 75.92 253.13 -9600.22 9644.60 3780.35 94.26 2970.50N 3199.51E 4365.86~ 47.13 12035.93 75.40 251.49 -9623.66 9668.04 3728.02 94.64 2942.64N 3112.15'E 4283.06~ 46.60 12132.39 74.42 251.28 -9648.77 9693.15 3673.64 96.46 2912.91N 3023.89E 4198.69~ 46.07 12225.47 72.93 252.43 -9674.94 9719.32 3622.08 93.08 2885.09N 2939.01E 4118.44~ 45.53 12324.17 71.25 251.42 -9705.29 9749.67 3567.97 98.70 2855.96N 2849.73E 4034.53~ 44.94 12356.47 71.42 249.79 -9715.63 9760.01 3549.76 32.30 2845.79N 2820.87 E 4006.91~ 44.75 12390.46 70.91 250.71 -9726.60 9770.98 3530.47 33.99 2834.92N 2790.59 E 3977.9(~ 44.55 BHA #9 / 1.15° B.H. { 6" HOLE } 12422.49 71.36 250.52 -9736.96 9781.34 3512.44 32.03 2824.86N 2762.00E 3950.76~ 44.36 12515.67 75.98 255.93 -9763.17 9807.55 3462.66 93.18 2799.12N 2676.43 E 3872.7'/~ 43.72 12610.87 73.55 257.49 -9788.18 9832.56 3416.18 95.20 2778.00N 2587.05 E 3796.0'/~ 42.96 12707.42 69.82 261.54 -9818.53 9862.91 3373.71 96.55 2761.29N 2496.97E 3722.8~ 42.12 12770.69 68.43 263.16 -9841.08 9885.46 3348.95 63.27 2753.42N 2438.38 E 3677.91~ 41.53 12863.91 68.84 260.53 -9875.04 9919.42 3311.90 93.22 2741.10N 2352.45E 3612.16~ 40.64 BI-LA #10 / PACKED ROTARY ASSEMBLY { 6" HOLE } 12959.39 68.74 260.53 -9909.58 9953.96 3272.07 95.48 2726.46N 2264.66 E 3544.32~ 39.71 13055.24 68.60 260.17 -9944.45 9988.83 3231.87 95.85 2711.49N 2176.63E 3477.06~ 38.76 BIO, #11 / PACKED ROTARY ASSEMBLY { 6" HOLE } 13103.35 69.13 260.83 -9961.80 10006.18 3211.77 48.11 2704.09N 2132.38E 3443.71~ 38.26 BHA #12 / PACKED ROTARY ASSEMBLY { 6" HOLE } 13182.00 69.95 264.87 -9989.30 10033.68 3181.51 78.65 2694.92N 2059.28E 3391.64~ 37.38 PROJECTED TO T.D. 13242.00 69.95 264.87 -10009.87 10054.25 3160.17 60.00 2689.88N 2003.14E 3353.81~ 36.67 GRID Coordinates DLS Cum. Northing Easting Dogleg (It) (fl) (dg/lOOfl) (deg) 5997671.21 677607.94 5997642.59 677518.95 5997612.86 677432.35 5997582.94 677345.70 5997551.13 677258.19 5997521.30 677174.01 5997490.06 677085.46 5997479.22 677056.85 5997467.64 677026.85 5997456.90 676998.51 5997429.14 676913.59 5997405.92 676824.75 5997387.08 676735.10 5997377.83 676676.73 5997363.49 676591.14 5997346.77 676503.73 5997329.73 676416.11 5997321.29 676372.05 5997310.40 676299.21 5997304.04 676243.21 Survoj Tool 15.33 238.7 BPHM-PBD 4. ! 3 242.7 BPHM-PBD 1.68 244.3 BPHM-PBD !. 77 245.9 BPHM-PBD 1.04 246.9 BPHM-PBD 1.99 248.8 BPHM-PBD 1.96 250.7 BPHM-PBD 4.81 252.3 BPHM-PBD 2.97 253.3 BPHM-PBD 1.51 253.8 BPHM-PBD 7.46 260.7 BPHM-PBD 3.00 263.6 BPHM-PBD 5.55 268.9 BPHM-PBD 3.25 271.0 BPHM-PBD 2.66 273.5 BPHM-PBD 0.10 273.6 BPHM-PBD 0.38 274.0 BPHM-PBD 1.69 274.8 BPHM-PBD 4.92 278.6 BPHM-PBD 0.00 278.6 BPHM-PBD ....... ~rl'lM MI~rIV~;H~IF-- ~'H~ NU. : 2634854 11-25-96 15:56 P.02 ARCO Alaska, Inc. Post Office Box 10036o Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Joseph A. Leone Mr. Kenneth A. tk)yd, Director Depa rtmen t vf No tural Reso u rces, Division of Oil and Gas 3601 C Street, Suit~ 1380 Anchorage, Al~,ske} 99593.5948 Mr. David W. Jolmston, Chairman Alaska Oil and Gas Ctmservation Commission 3001 Porcupine Drive Anchorage, Alaska 995(')1-3192 RE: Request to Initiate Tract Operations on ADL 28297 and .Commi n~l.e_ Er_oduction from W_ellP1-09 Gentlemen: q(:,..t ARCO Alaska, loc. ("ARCO") requests approval from the Department of Natural Resources, Di¥iskm of Oil and Ga~-, and the Alaska Oil and Gas Conservation Commission to initiate Tract Operations on ADL 28297 and to commingle production from the Pl-09 tract well with production from Pt. Mclntyre wells for processing at LPG ARCO will serve as the Tract operator for ADL 28297. The tract well, Pl-09, was drilled to a total depth of 13,242' MD-RKB from the Point McIntyre Drillsite #1, and has penetrated oil bearing Kuparuk, Ivishak and Sag River formations. Although the wellbore will ultimately be completed as a producer in the Pt. McIntyre pool, a three tt) twelve mcmd~ producticm test of the Permo-Triassic intervals, which are not part of any existing pool or participating area, is planned. Agreements between ARCO Alaska Inc., BP Exploration (Alaska) and Exxon USA are in-place to allow the tract well to be produced into Pt. Mclntyre dril[site fi~cilitie~ and flow]ines, processed at the Lisburne Production Center (LPC), and then c-teljvered to Pump Station No. 1. The production from the well will be allocated based on existing well testing protocols established and approved by the AOGCC, DNR and DaR for other production that is commingled for processing at the Lisbume Production Center, The well is expected to be ready for production on December I, 1996. If you have any quesHon~, or if you would like lo schedule a meeting to review the well, please contact me ~t (90?) 263-4431 or Mike Morgan at (907) 2634332 Sincerely, ' . J,~, L~'me Greater Pt. Mclntyre Area Manager RECEIVED NOV 6 199 Cc: J, 13ranch - Exxm~ Cumpany, USA R. Janes - BP E×ph)ration (Alasko) lac. J. Pilkinton * Alaska Dept. of Revenue ARCO A!eska, Inc. I~ a Sub.~idi,gr'y' al~ A~lanllcRic~ri¢ldGompany Alaska 011 & r~a~ Cons. Commissio[~ Anchorage FROPI: GPFIR ANCHORAGE FAX NO.: . ~J --~ ~RCO AI.A~KA, ,C. -'~' 700'G' ST. ANCHOI:IAG[ AK99~1 26~4894 11-25-96 15:56 P.01 GREATER POINT McINTYRE AREA FAC$~LE ~$MISSION /:az Number (~0'~ 2~ DA1'~ ~ER OF FAG'rS: C + COMi~ANY: FIIOM~ Ill II Il ff .... /111 I I I II .I ! RECEIVED Alaska 0tl & Qa~ Con~. Commission Anchorage STATE OF ALASKA r.. ALASKA OIL AND GAS CONSERVATION COMM, ~SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon L.J Suspend [] Plugging I~ Time Et. lanslon ~ Ped(~rate [] ^tt~r Casing [] Repair Wall [] Pull Tubing [] Variance [] Other _ [] Cllan~e Approved Program [] Operation Shutdown [] Re-Enler Suspended Well [] Stimulate 2. Name of Operator iS, Type of well: 6. Datum Elevation (DF or KB) ARCO Alaska Inc. I [] Development Plan RTE = 42.8 ...... Unit or Property Name ,3. Address Point Mclntyre P.O. Box 196612, Anchorage, Alaska ge51g-6612 4. Location of well at surface [] Exploratory 7. [] Stratigraphic [] Service 8, 14,38' NSL, 752' WEL, SEC. 16, T12N, R14E '9, At top of productive interval 4109' NSL, 2366' WEL, SEC;. 15, T12N, R14E (Planned) !10. At effective depth Well Number Pl.09 'Permit Number g6-154. APl Number $0.029-22704 11. Field and Pool Point Mclntyre N/A At total depth $g20' NSL, 5262' WEL, SEC. 15, T12N, R14E (Planned) 12. Present well condition' sun~rna~ .............. Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Pluge (measured) Junk (measured) ORIGINAL Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth; measured true vertical RECEIVED SEP ,30 1996 Tubing (~ize, grade, and measured depth) Packers and SSSV (type and measured depth) Alaska 011 & ({as Con~. C0mrni~si0n Anchorage 1,3. Attachments 14. Estimated date for commencing operation October 3, 1996 ! 16. If proposal was ~;~ilY'~proved Name of approver Date approved Contact Engineer Name/Numbe~ Jim ~m/th, 6~1.60~6 17. I hereby certify that the foffig~ing is tru~>,~. ~l'~'~ct to the best of my knowledge Signed..,,j ~... r..,:[.~:_~. _~_ ,~I"- 'N~ ~ ~ ,.. ~~ ___ tie 8enior Drilling Engineer "" '"J Comlfl-lsslon Use Only ,m , [] Description summary of proposal [] Detailed operation9 program 0 BOP sketch 1,5. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Kathy Campoamor, 58-4'5 i22 -- Date (~,~__~ Conditions o! Approvah Notify Commission so representative may witness I Approval No. ~_ Plug integrity BOP Test__ Location clear,nco ~ Mechanical Inlegrity Test__ Subaequent form required 10- ~7 __ Approved by order of the Commission David W. ,Johnston Commissioner Date / =cfm 10-403 Rev. 06/15/88 Approved Copy Returned Submit In Triplicate SEP ~? ~96 03:~8PM BP E×P~gR~TI©M P.~ To: B. WondzelI oate: Sept. 27, 1996 From: ,]', Smith Subject: D_e~__en. s~xrface casing s~o~, ~eJl_P1.0~ Shared Services DrilLing requests approval to deepen the surface casing setting depth on the P1-09 well (permit number 96-154) on Point Mclntyre from 3613'MD, 3608'TVD in the SV4 sand to 5027'MD, 4943'TVD which is 50'TVD above the K-15 and still above any potential hydrocarbon bearing i~tervals, Ottr reasoning is as follows: During production casing running operations at 'ID on the P1-24 well (Sept. 26,1996) mud returns were lost near 5300'lV[D in the Sagvsnlrktok formation which contributed to an unsuccessful primary cement job on the production casing mad forced squeeze cementing operations. We believe that the highly developed sands in this interval were unable to support the additional fluid pressures exerted while running this 7" production casing, as such we propose to cover those sands with surface casing on the P1-09 we]/to avoid this problem. We have recently drilled the P1-06 well on fl~e same pad with the deeper surface casing program (casing shoe at 50'TVD above the K-15) and encountered no difficulty with the deeper surface casing program. As with the original program for the P1-09 surface casing cementing, we plan to cement to surface and therefore will increase the lead slurry volume from the original I611sx to 1952sx to accomodate the additional hole interval to be covered. Sincerely, ~ E. Smith SSD Engineer RECEIVED SEP 3 0 199~ ~laska Oil & ~as Cons. Oommission Anchorage FROM: ARCO FAX NO.: 2634966 Post-it" Fax Note 'B71 ~ .~~/M,,~COMPANY, U.S.A. 09-25-96 17:12 P.O1 -- Date ,, IP"~l~s- I Frnm Phone ~ - J F~ ~ Sep~mber 25, 1996 MI'. darne~ Wirte~amer ARCO. Alaska, Irtc. P, O. Box Artchomge. AK g6~10.Oa~o Re: Request for Lea~ of Non~Objecllon for lnterdional Deviati~: ~ M~.~ p~ we, ~'~- Is- ~/ Dear Mr. IAfinegamer, We have revic, we~ the subje~ mqueet t~ drill a deviated Wellbore through the lease ADL 28297 and do not ~ an Qbjeetion to thi~ reqm:st. DRC:ddm ~O:~T 96-G~-68 ~68~£9~ ~"ON RECEIVED SEP 2 ~ 1996' Naska 011 & Gas Cons. Commission Anchorage TONY KNOWLE$, OOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 20, 1996 Steve Shultz Senior Drilling Engineer ARCO Alaska Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Point Mclntyre P 1-09 Revised ARCO Alaska Inc. Permit No. 96-154 Sur Loc 1438~SL, 752'WEL, Sec. 16, T12N, R14E, UM Btmhole Loc 39202qSL, 5262'WEL, Sec. 15, T12, R14E, UM Dear Mr. Schult: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated September 13, 1996 are in effect for this revision. · BY ORDER OF THE COMMISSION dlffEnclosures CC: Department ofFish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL REVISED 09/13/96 20 AAC 25.005 .. [] Drill [] Redrill ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil fla. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 42.8 Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028297 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1438' NSL, 752' WEL, SEC. 16, T12N, R14E Point Mclntyre At top of productive interval 8. Well Number Number U-630610 4109' NSL, 2366' WEL, SEC. 15, T12N, R14E P1-09 At total depth 9. Approximate spud date Amount $200,000.00 3920' NSL, 5262' WEL, SEC. 15, T12N, R14E 09/20/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034622, 1360'I P1-08, 15' at surface 2560 14343' MD / 10393' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 46 °i Maximum surface 3466 psig, At total depth (TVD) 8843' / 4350 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 133# H-40 BTC 115' Surface Surface 115' 115' Driven 12-1/4" 9-5/8" 40# L-80 BTC 3570' 41' 41' 3613' 3608' 1611 sx CS III, 333 sx'G' 8-1/2" 7" 26# L-80 BTCM 10096' 41' 41' 10246' 8437' 275 sx Class 'G' 8-1/2" 7" 29# 13CR80 NSCC 903' 10246' 8427' 11165' 9174' 6" 4-1/2" 12.6# L-80 IBT Mod 3393' 11065' 9082' 14475' 10392' 408 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Anchorage Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared.By Name/Number: Kathy Campoamor, 564-5122 21.1Signedhereby certify that the..f?regoing/~)~,~.~ is~t~rect_~(,~~,~_, to the best of my knowledge c//?¢-~--~'/ SteveShultz .. Title Senior Drilling Engineer Date ~ Commission Use Only Permit Number I APl Number Approval Date I See cover letter P~'--,/'-~t 50- 02¢'- ,2.., 2- 70 (-/ ~- J¢;~'/~¢,I for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes ,,~No Sulfide Measures /'lg~es [] No Directional Survey Required "~ Yes [] No Hydrogen Required Working PressureforBO--PE [] 2M; i-13M; J~ 5M; [] 10M; [] 15M Other: Approved By drlg~nai Signed By by order of ~ ;a ~ Inhngtf')R Commissioner the commission Date J0rl Form 10-401 Rev. 12-01-85 O;:tv Submit In Triplicate Well Name: I P1-09 I Well Plan Summary I Type of Well (producer or injector): [ Producer w/exploration tail Surface Location: 1438' FSL, 752' FEL, Sec. 16, T12N, R14E UM Target Location: 4109' FSL, 2366' FEL Sec. 15, T12N, R14E UM Bottom Hole Location: 3920' FSL, 5262' FEL Sec 15, T12N, R14E UM ]AFENumber: ]AX9371 I I Estimated Start Date: 1 9/20/96 I I Rig: [ Doyon #14 Operating days to complete: I 33 [MD: [ 14475' [ [TVD: [ 10392' I [KBE: 142.8' [ Well Design (conventional, slimhole, etc.): [ Ultraslimhole Longstring w/Exploration Tail I Objective: [ Ivishak Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1858 1853 SV4 3603 3598 9-5/8" casing 3613 3608 Set 9-5/8" casing 10'TVD into SV4 K-15 5088 4993 Lower Ugnu 6768 6143 West Sak 7693 6753 9.5 ppg minimum mud weight required K- 10 10031 8295 HRZ 10379 8525 K-5/HRZ same depth Kalubik 10516 8615 Kupamk 10546 8635 10.0 ppg minimum mud weight required Zone "LA" 11015 9035 Miluveach 11060 9078 Kingak (J3 marker) 11109 9123 7" casing 11165 9174 Set 7" casing at 150' below top "LA" Kingak (J-B marker) 12156 9668 Sag River 12732 9848 Shublik 12966 9921 Ivishak 13196 9993 TD 14475 10393 TD depth to be selected by exploration rep Evaluation Program-. SURFACE INTERMEDIATE EXPL TAIL MWD directional only MWD directional and LWD (GR-RES-DEN-NEUT) surface csg to TD MWD directional with GR-RES from 7" csg to TD. Possible addition of DEN-NEUT-Sonic DP conveyed per exploration re.q,uss, t, r,, RECEiV u Well Plan Summary Alaska Oil & Gas Cons. Gommissio~ Anchorage Page 1 Special design considerations lAn open hole displacement to +/- 10 ppg Flovis polymer/3% KCI water based mud will be performed above the reservoir at the HRZ Surface Mud Properties: [ SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 <15 Production Mud Properties: ] LSND in upper hole to the HRZ DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.2 8-15 20-30 5-15 <30 9-9.5 6-12 10.0 8-15 20-30 5-15 <30 9-9.5 6-12 Production Mud Properties: ] 3% KCL from HRZ thru Kuparuk & Ivishak DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.0 8-15 25-30 12-15 <30 9-9.5 4-6 10.4 8-15 25-30 12-15 <30 9-9.5 4-6 HTHP<15 Directional: ] KOP: [ 300'MD Build at 1° then 2.5°/100' [ Maximum Hole Angle: 49° @ 561 l'MD,maintain tangent at 49° angle and 52.62° azimuth to 10646'MD, turn and drop at 10°/100' to 26° angle and 301° azimuth at 7" casing point (11165'MD). Continue turn & build at 10°/100' to final tangent of 72° angle & 261 o azimuth. Close Approach Well: P1-08 (15'east @sfc) and P1-02(03) (112'east @sfc)will be shut in until surface casing is mn. The PTM-02 is close but has been P&A'ed. There are no deep close approaches. Casing/Tubing Program: Hole Siz6 Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfYVD MD/TVD 30" 20" 1334/ H-40 BTC 115' GL(driven). 115'/115' 12-1/4" 9 5/8" 40.0# L-80 BTC 3572' 41'/41' 3613'/3608' 8 1/2" 7" 26.0# L-80 BTCM 10205' 41'/41' 10246'/8437' 7" 29.04/ 13CR80 NSCC 919' 10246'/8437' 11165'/9174' 6" 4 1/2" 12.6// L-80 IBTMod 3410' 11065'/9082' 14475'/10392' TBG 4.5" 12.6# 13CR80 NSCT 10405' 41'/41' 10446'/8569' Well Plan Summary Page 2 Cement Data: Casing/Liner Lead: Sxs/Wt~ield Tail: Sxs/Wt~ield Comments 9-5/8" shoe at 3613'MD 7" shoe at 11165'MD 4-1/2" contingent liner 1610/12.2/1.92 **350% excess lead in perma,plus 50% excess to top of tail none none 333/15.8/1.15 **50% excess tail & plan 750'TVD fillup which is 752'MD 275/15.8/1.14 409/15.7/1.19 Cold Set IH & Class "G Class "G" w/50% excess. TOC at 9546'+ (1000' MD above Kupamk) Class "G" Acid resistant This will be a "screw-in" cement job on surface casing the lead volume identified is an estimate of the amount required based on historical data, plan to have 2500sx of lead available on location for surface casing cementing. Contacts Name Office Home Pager . James E. Smith Steve Shultz Adrian Clark Drilling Eng. 564-5026 345-8660 275-4015 Drilling Eng. Supr. 564-5405 373-1657 275-9459 Drilling Supt. 564-4720 345-9066 275-1779 Primary_ contacts Company, Title Name Office Phone Fax Alternate Phone Shared Services Rig Supervisor (Doyon 14) Sperry Sun (mud plant) Sperry Sun (@ Doyon 14) Anadrill wireline/DP conveyed ARCO Drill Site Engineers Nick Scales/Kirk White Carl HoefffPete Holtzman Amy Smith Evan Rael Lowell Crane Gordon Pespisil 659-4510 659-2809 659-0204 659-2487 265-6909 265-1544 2634391 6594512 Pusher 6594511 344-1686 349-1340 248-7739 Secondary_ contacts Company, Title Shared Services Drlg Engineer (Doyon 14) ARCO Geologist ARCO Geologist (Alternate) Well Plan Summary Name James Smith Tom Eggert Kevin Frank Office Phone Fax 564-5026 564-5193 265-1663 263-4894 265-6834 RECEIVED SEP 1 G 1996 Alaska Oil & Gas Cons. Commission Anchorage Alternate Phone Pager 275-4015 Home-345-8660 Home-345-0099 Home FAX is same Home-562-5978 Page 3 Drilling Hazards/Risks The original reservoir Kuparuk pressure is 4350 psi at 8800' ss. The expected Kuparuk reservoir pressure is 4250 psi at 8800'ss. The expected Ivishak pressure is on the same gradient as the Kuparuk. Abnormally pressured formations are not expected in this well. Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe. This has caused stuck pipe incidents and bit/BHA bailing Gumbo problems. Coal stringers in the Lower Ugnu have also produced stuck pipe. ReP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. An exemption.from the diverter requirement has been requested for this well. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Well Plan Summary RECEIVED SEP 1 G 199G Alaska Oil & Gas Cons. CommissioH Anchorage Page 4 . ge . . o . . . 10. 11. 12. 13. P1-09 Operations Summary MIRU drilling rig. NU riser and flowlines. Spud well and drill 12-1/4" hole to 300' md. Kick off and build angle to 7° on 120° azimuth by 1000'MD, bring angle back to 0° by 1767'MD and maintain at vertical to 3613'MD (casing point). Set 9-5/8" casing and cement same to surface.. Nipple up BOP's and test same to 5000 psi. Test casing to 3000 psi for 30 minutes. Note AOGCC witness or waiver on the morning report. P/U 8 1/2" BHA, drill 20' new hole and perform LOT. Drill ahead and contiunue build to 48.73°, 52.62° azimuth at 2.5°/100, rate. Hold angle and azimuth to 10546'MD (target#l) then drop angle and turn at 10°/100' to 25.56°angle and 301° azimuth by 11165'MD, TD for 8-1/2" hole. Displace mud to 10.0 ppg 3% KCL at HRZ. IfLWD logs were not obtained while drilling the 8-1/2" hole, run wireline open hole logs. Make a cleanout run if the hole is tight. POOH and lay down drill pipe. Run 7" L-80 and 13 chrome casing and cement same, displacing with mud. Test casing to 3500 psi for 30 minutes. Test surface equipment, PFU 6" BHA, MWD w/GR-RES & 3-1/2" drill string with S-135 DP, drill 20' of new hole and perform LOT. Drill ahead and continue 10°/100' turn and angle build per directional program. When build and turn are complete (71.79° angle, 260.60 azimuth) change BHA's and maintain tangent to TD at 14475'MD, 10392'TVD. Make a cleanout run if the hole is tight. POOH standing back DP. If the Asset requests, additional logs (DEN-NEUT-Sonic) may be run on DP. Depending upon log evaluation the 6" hole may be plugged back to the 7" casing shoe or a 4-1/2" L-80 test liner run to TD. Details to be provided at the conclusion of logging. Run 4-1/2" chrome tubing and completion assembly to place the tubing tail at 100' above the top of the Kupamk. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set packer, test tubing. Test annulus. Secure well, release rig. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Well Plan Summary Page 5 BPX - Shared Services Drilling Alaska Slate Plane: Zone4 Pt Mac · PM1 Pl-09 As-Built Pl-09 Wp7 AWD HALLIBURTON 7,0~' ! 1300 MO STMT ~' CL~VE t S.~o°/lo0 Ft ~.50' e 14oo a~ HORIZONTAL ~ (TRU~ NORTH) SCALE ~00 tr./ m. 40.73' · 67~ ND WELL PLAN PROFILE SUMMARY START MDEND MD PtA.N~IEDACTIVITY S~rt ]~d. Activity 0 300 P:iU 12 1/4" Ve_--t/calHo]e to KOP. 300 1000 :KOP, Start Directiozm_l ~ I.OC~/100' til.l~'each/ug 7.OCr~ on 45.~'-{m'1[h of 120.00~. 1000 1300 Hold uu til reax:hiug ~x[ Ditec tlontd Point. 1300 1767 Staxt Directiollid ~a, 1,SC~'/lO0' tiU.:reaching verd. caL 1767 3613 Hold until re~cl~ing 9 5/8" C~sing Point~ 3613 366:2D:ill out ~ 1/:Z~ Hole, Co~tiuue vertical uutil reac~g ~ext DLrect~c~al Poiut. 3~:2 5611 Stazt DLtec~o~a! ~ 2.50°/100, tillzeac~i~g 48.73.00° o~ A~ixz~t~ of $2.62°. $611 10~4~Holdun~lreac2~ingTa.tget I and~extDLrect~omlpoint~ 10546 1064~Targe[ 1, Start D~ectional ~ 10.00°/10CY t~ll~eac~iug 39.13° ot~ AzLt~uth of48.~3°. 10646 11165$tartD~rectio~al ~ 10.00°/!0(Y tillzeacl~g7~ Ca~ingPoi~t at ~_5.$6° on Az~ut~ of300.gT°. 11165 11700D~ri]lout 6" Ho~e, Col~i~t~e D4rect~onal uutilreacl~ng 71.'7~° ~ ,6,~1~ut~ of :2~0.60°. 11700 13196Hold until re acing T~rget 2. 13196 14475Target ~, Cot~tinue hold t~llreac~ug TD. 14475 TD. CRITICAL PDINT DATA HD lac AzI, TVD N/S E/V TIE IN 0 0.00' 1E0.00' 0 0 N 0 KOP / START 300 0,00'IR0,00* 300 0N 0 DF BUILD R 1.00'/10O Ct END OF BUILD 1000 7,00'120.00' 998 E1S 37 START OF 13007,00'IEO. O0*1296 40S 69 % CURVE 8 1.50'/[00 F'~ 48.73' m 7693 ~U V. Sak END DF CURVE17670.00' 52,62' 176~ 54S 93 B, PermaFrost 18580.00' 5E, TE' 1853 54S 93 ~ SV4 36030.00' 52.62' 3598 54S 93 X START Br 366aO. O0'5~,~' 3657 54S 93 ~ END Dr CURVE561148.73' 52.6~' 5380 420 N 713 ~ L. Ugnu 676848.73' 5E, 6E' 6143 948N 1404 ~ V. S~k 769348,73' 5E,~' ~753 [370 ~ 1956 ~ K-10 1003[ 48.73'5~.6E' 8E93 E436N 3353 ~ K~tublk 10516 48.73' 32.6E' 8615 2658~ 3642 ~ T~ge~ [ / 10546 48,73' 38.68* 8635 867~N 3660 ~ START DF CURVE E 10.00'/100 F~ / Kup~uk ~ START DF 10646 39.[3' 48.~3' 8707 ~715N 37[4 ~ CURVE E [0,00'/t0O ~ ~ Top Zm LA 11015 19.3~'337,64' 9035 ~854~ 3780 ~ Hituveach 11060 g0.36'384,47' 9078 ~867N 3773 ~ J-3 GE Spike~110~ g~33' 318.34' 9183 ~880~ 3761 ~ ENDDF CURVE11700 71.79'~60,60' 95E5 E913N 3365 ~ J-~Nkk. 1~156 71.79'~60,60' 9568 8848N ~937 ~ Sug 1~73~ 7~.79'960,60' ~8"8 ~733N e3~8 ~ Shubtlk 12966 71.79'E60.60' 99gl E717N 2179 ~ CURVE e Io, Eg'/IO0 ?t / T~get e / IvI~h~SAD~ ~5 ............... ~4B, 7~ ~ 10031 ~ K-lO ...................... ~ 49.73' E 1~37~ ND K-5~RZ __~ .................. ~ ~?~' ~ s~ ~ ~mk ----~6~~ ========~==~===~ 4~7~ E 1~6 ~ TG~t t / ~T~T DF ~ ~ to.~'~ ft / K~p~ ................... ~ ~,13' R 10646 ~ $T~T DF ~R~ R t0.~'~ ft 3o. 9e- a tg746 ~ ~ 19.83' R lO94m ~ .................... 4 ~.~. ~ no~ .~ ~ ~ ~ .................. 2g~' · 1t1~ ~ 3-3 GR S ~C~k) 31,39' ~ 112~6 ~o 38.58' ~ [1346 ~ 4~.36' ~ 11446 ~ ~ 57.4&* ~ t1546 N~ ------~ .............. ~ 7t.~s' ~ [~ .~ ~ ~ ~ .......... ~ 71,7~ t tR~2 ~ SeO 3140 ~ T~et R / I~C~AD) V]/R~CAL l~gC~0N P~A.~g: 17.11° {T~rget N~ae TVD NS EV Grid X Gr'ldY Jl CAS/NG PB[NT DATA nD /iD Inc AzI TVD N/$ 5997P94 9 5/8 lq 3613 0.00' 0.00' 3606 54 g 93 E ~aqv,-~,~ ................................. PLOT INFORMATION DRAWING NAME / FILE NAME Pl-O9 wp7 composi~ PIc~/pi Ogvh.~d SURFACE LOCATION PROP05'ED BHL ~a S~ ~e [ 0 ~ ~ 10392.~ I ~ 1~76.35 N~ 5~94~.10 { ~g: ~4,~.~m · ~ ~ ~97.~ ~nRTER.: 4~o [ · Es~d 784.1~ E TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 13, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Shultz, Sr Drlg Engr BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Point McIntyre P 1-09 BP Exploration (Alaska), Inc. 96-154 14387qSL, 752'WEL, Sec 16, T12N, R14E, UM 42772qSL, 2270'WEL, Sec 15, T12N, R14E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. Your request of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) has been approved. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. BY ORDER OF dlf/encl c: Dept ofFish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill [lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 42.8 Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028297 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1438' NSL, 752' WEL, SEC. 16, T12N, R14E Point Mclntyre At top of productive interval 8. Well Number Number U-630610 4109' NSL, 2366' WEL, SEC. 15, T12N, R14E P1-09 Attotal depth 9. Approximate spud date Amount $200,000.00 4277' NSL, 2270' WEL, SEC. 15, T12N, R14E 09/20/96 112. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034622, 1003'I P1-08, 15' atsurface 2560 10990' MD / 9131' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 46° Maximum surface 3466 psig, At total depth (TVD) 8843' / 4350 psig 118. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 133# H-40 BTC 115' Surface Surface 115' 1 15' Driven 12-1/4" 9-5/8" 40# L-80 BTC 3570' 41' 41' 3611' 3607' 16o5 sx CS III, 334 sx'G', 250 sx CS II 8-1/2" 7" 26# L-80 BTCM 10096' 41' 41' 10137' 8427' 230 sx Class 'G' 8-1/2" 7" 29# 13CR80 NSCC 853' 10137' 8427' 10990' 9131' . 19. To be cOmPleted for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured)ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateRECEIVED Production Liner .. AUG 2 9 1996 Na~k~ 011 & G~; 130n;. C0mmig¢on Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the,,f~regoing is an ct to the best of my knowledge SteveShultz ~""~~//~k Title Senior Drilling Engineer Date ....j v ..., Commission Use Only Permit Number?_~,/, ~'-~z[ IAPl Number5o- ~.~..,~... ~ ~_ ,~ 4.~ I Approval Date I See cover letterf°r other -., requirements Conditions of Approval: Samples Required [] Yes ,~ No Mud Log Required [] Yes ~'.No Hydrogen Sulfide Measures '}~Yes [] No Directional Survey Required ,~ Yes [] No Required Working Pressure for BOPE [] 2M; [] 3M; J~ 5M; [] 10M; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BP EXPLOR.~I'iON To: B. Wondzell Date: AOGCC From: J. Smith Shared Services Drilling September 13, 1996 Subject: Wellbore Extension, Well P1-09 Shared Services Drilling has previously submitted an application for drilling permit for the P1-09 well with a Kupamk objective and total depth of 10990'MD, 9131'TVD to your attention. Attached is a permit application for the same P1-09 well to seek approval for drilling and exploration tail extension to the base of the Ivishak formation. Total depth for the well would be 14475'MD, 10392'TVD in 6" hole size at TD. The changes from the original submission are: 1) Surface casing will be cemented to surface with a "stab-in/screw-in" system, 2) deepen 7" casing shoe by 50'MD to allow additional room for a contingent production test liner hanger, 3) increased cement volume on the 7" casing caused by the deeper setting depth, 4) possible addition of a 4-1/2" cemented production test liner 5) revised BHL with the exploration tail. As in the initial application, we request your consideration for a waiver of the diverter on this well. Sincerely, James E. Smith SSD Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order granting ) an exception to spacing requirements ) of Title 20 AAC 25.055 to ) provide for the drilling of the Pt. ) Mclntyre P1-09 delineation oil well in ) the Prudhoe Bay Unit. ) Conservation Order No. 382 ARCO Alaska, Inc. Pt. Mclntyre P 1-09 September ! 0, 1996 IT APPEARING THAT: . ARCO Alaska, Inc. submitted an application dated August 21, 1996 requesting exception to the well spacing provisions.of20 AAC 25.055 (a)(1) to allow drilling the ARCO Pt. McIntyre P1-09 exploration oil well to a bottomhole location within 500 feet of a quarter-section line within an undefined oil pool in the Prudhoe Bay Unit on the North Slope. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on August 23, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: . 3, The Pt. Mclntyre P1-09 exploration oil well will be drilled as a deviated hole with a surface location 1438' from the south line (FSL) and 752' from the east line (FEL) of Section 16, T12N, R14E, Umiat Meridian (UM) and a proposed bottomhole location 1311' FNL and 5' FEL of Section 16, T12N, R14E, UM Offset owners BP Exploration (Alaska) Inc., Exxon Corporation and the State of Alaska have been duly notified. An exception to the well spacing provisions of Title 20 AAC 25.055 (a)(1) is necessary to allow the drilling of this well. Conservation Order N~ ~ q2 September 10, 1996 - page 2 CONCLUSION: Granting a spacing exception to allow drilling of the ARCO Pt. Mclntyre P 1-09 exploratory oil well will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: ARCO Alaska, Inc.'s application for exception to the well spacing provisions of Title 20 AAC 25.055 (a)(1) for the purpose of drilling the ARCO Pt. Mclntyre P 1-09 well is approved. DONE at Anchorage, Alaska and dated September 10, 1996. David W. Alaskfi Oil and Gas C Commission erman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23ra day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or m part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., l0th day after the application for rehearing was filed). BP EXPLORe'ION To: B. Wondzell Date: August 27, 1996 From: J. Smith Subject: Dispensation for 20 AAC 25.035 (7)(b) on P1-09 Well Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on Point Mclntyre 1. There have been 22 wells drilled on the Point Mclntyre 1 pad, none of these wells experienced any difficulty with shallow gas in the interval prior to placement of surface casing. Within the last month, two additional wells (P1-23 and P1-06) have drilled through the shallow intervals without any indications of shallow gas. A clear path for diverter line installation on the P1-09 location is very difficult due to the production facilities which are placed directly in the path of the diverter line. In light of the historical evidence indicating minimal risk due to shallow gas at this location, we conclude that the P1-09 well on the same pad can be safely drilled without the installation of the diverter system. Sincerely, James E. Smith SSD Engineer [WellName: IP1-09 Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 1438' FSL, 752' FEL, Sec. 16, T12N, R14E UM Target Location: 4109' FSL, 2366' FEL Sec. 15, T12N, R14E UM Bottom Hole Location: 4277' FSL, 2270' FEL Sec 15, T12N, R14E UM I AFENumber: i 2C0096 I I EstimatedStart Date: 19/20/96 [MD: [ 10990' ] I TVD: [Rig: I Doyon #14 [ I Operating days to complete: I I 19Z3Z'rkbl I}C~E: 142.8' I I Well Design (conventional, sHmhole, etc.): I Ultraslimhole Longstring Objective: ] Kupamk Sand Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1855 1853 SV4 3601 3598 9-5/8" casing 3611 3607 Set 9-5/8" casing 10'TVD into SV4 K-15 5194 4993 Lower Ugnu 6849 6143 West Sak 7728 6753 9.5 ppg minimum mud weight required K- 10 9945 8293 HRZ 10279 8524 K-5/HRZ same depth Kalubik 10408 8615 Kupamk 10437 8635 10.0 ppg minimum mud weight required Zone "LA" 10890 9035 TD 10990 9131 100'MD below Zone "LA" Evaluation Program: SURFACE PRODUCTION CASED HOLE LOGS MWD directional only MWD directional and LWD (GR-RES-DEN-NEUT) surface csg to TD None Well Plan Summary Page 1 Mud Program: Special design considerations An open hole displacement to +/- 10 ppg Flovis polymer/3 % KCI water based mud will be performed above the reservoir at the HRZ Surface Mud Properties: I SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND in upper hole to the HRZ DENSITY Plastic Yield Point 10 Sec Gel 10 rain Gel pH Fluid Loss (PPG) Viscosity 9.2 8-15 20-30 5-15 <30 9-9.5 6-12 10.0 8-15 20-30 5-15 <30 9-9.5 6-12 Production Mud Properties: [ 3% KCL from HRZ thru Kupamk DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.0 8-15 25-30 12-15 <30 9-9.5 4-6 HTHP<15 Directional: [ KOP: [ 300'MD Build at 1° then 2.5°/100, ] Maximum Hole Angle: 46° @ 5170'MD, drop to 14.6° by 10826MD and mm from 53.18° to 304° by TD at 10990'MD Close Approach Well: P1-07(08) (29.9'east @sfc), P1-08 (15'east @sfc) and P1-02(03) (112'east @sfc)will be shut in until surface casing is mn. The PTM- 02 is close but has been P&A'ed. There are no deep close approaches. Casing/Tubing Program: T Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 133# H-40 BTC 115' GL(driven) 115'/115' 12-1/4" 9 5/8" 40.0# L-80 BTC 3570' 41'/41' 3611'/3607' 8 1/2" 7" 26.0g L-80 BTCM 10096' 41'/41' 10137'/8427' 7" 29.0# 13CR80 NSCC 853' 10137'/8427' 10990'/9131' TBG 4.5" 12.6# 13CR80 NSCT 10296' 41'/41' 10337'/8566' RECEIVED AUG 2 9 1996 Naska Oil & Gas Cons. Commission Anchorage Well Plan Summary Page 2 Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 9-5/8" shoe at 3611'MD 1, shoe at 10990'MD 1605/12.2/1.92 **350% excess lead in perma,plus 50% excess to top of tail none 334/15.8/1.15 **50% excess tail & plan 750'TVD fillup which is 752'MD 230/15.8/1.14 Cold Set III & Class "G Class "G" w/30% excess. TOC-9437' +/- (1000'MD above Kuparuk)If Stump Is. is present need 500' cmt above that sand. Top Out Job (if necessary) 250/14.95/0.96 Top Out--CSII Contacts Name Office Home Pager James E. Smith Adrian Clark Drilling Eng. Drilling Supt. 564-5026 345-8660 275-4015 564-4720 345-9066 275-1779 Drilling Hazards/Risks The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4250 psi at 8800'ss. Abnormally pressured formations are not expected in this well. Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe. This has caused stuck pipe incidents and bit/BHA bailing Gumbo problems. Coal stringers in the Lower Ugnu have also produced stuck pipe. ROP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. An exemption from the diverter requirement has been requested for this well. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Well Plan Summary Page 3 , . , . . . . 9. 10. Pl-09 Operations Summary MIRU drilling rig. NU riser and flowlines. Spud well and drill 12-1/4" hole to 300' md. Kick off and build angle to 7° on 53.18° azimuth by 3611'MD (casing point). Set 9-5/8" casing and cement same to surface.. Nipple up BOP's and test same to 5000 psi. Test casing to 3000 psi for 30 minutes. Note AOGCC witness or waiver on the morning report. P/U 8 1/2" BHA, drill 20' new hole and perform LOT. Drill ahead and contiunue build to 46°, 53.18° azimuth. Hold angle and azimuth to 10436'MD, then drop angle and turn at 10°/100' to 19.55° and 303.85°azimuth by 10990'MD, TD. Displace mud to 10.0 ppg 3% KCL at HRZ. IfLWD logs were not obtained while drilling the 8-1/2" hole, run wireline open hole logs. Make a cleanout run if the hole is tight. POOH and lay down drill pipe. Run 7" L-80 and 13 chrome casing and cement same, displacing with seawater. Test casing to 3500 psi for 30 minutes. Run 4-1/2" chrome tubing and completion assembly. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set packer, test tubing. Test annulus. Secure well, release rig. Well Plan Summary Page 4 :i .43 {3~I~,AL ~ DATA , ,o,.,z~, N~$N ~T~ 800 5,00 105.00 ~ 6~ ,1 ~ 3611 7~3~ ~3,18 :3E~7 8 $ 4]77 WELLPLAN FEASIBILITY STUDY Tkli pJln i. for fem~ibillt',V I~V',l~m only -500 O 503 1 ~00 1500 ~000 ~ 3000 3,500 VERTICAL SECTION PI_~, g~g~ ~t N igC=3 I~ 67r=~03 l]<ig;e Plo~-t~ ! : ; ; :1 TVD gt30.5~ MD 10gB9.C~ VS 4708,88 N/S in340,27 N EYW 3755.85 E .. · ADMINISTRATION [] serv [] wellbore seg [] ann. disposal para req [] ENGINEERING APER DATE ,,,~77 1. 2. 3. 4. 5. 6. 7. @. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Adequate wellbore separation proposed ........... 23. If diverter required, is it adequate .......... ~]~. 24. Ddlling fluid program schematic & equip list adequate 25. BOPEs adequate ........................ 26. BOPE press raeng adequate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84). 28. Work will occur without operation shutdown .......... 29. Is presence of H2S gas probable .............. ON/OFF SHORE , Permit fee atl~ched ........................ Y ~N~'''~' REMARKS Unique well .~e ~d numar ................. W~l Io~inadefin~ol .................. ~Y IN 7~. Well I~ pro~r d~ from o~er~ ......... ~Y ~N ~~~7~ /~~ ~fde~.~w.,~r.p~i.~.d~ .............. ]+~N .~.~ ~~~.~ / ~. ~. ,~~ ) ~5/~.~ . O.e~or on,y ~ ~ ................... /Yi N Operator h~ ~pmpfiate ~nd in for~ ............l Y P e~it ~ ~ ~u~ ~out ~n~don o~e, ...... ]YIN Pe~it ~ ~ ~u~ ~out ~minis~e ~p~ .... [ YIN /~~,~ ~ ~ -/~ ¢ . _~.~ ~~~ ~~[/~ c~ p~ ~ ~prov~ ~fo~. ~s~y w~ ........ .~y) N ................. , Conductor s~ng p~d~ .................. Suda~ ~ing prot~ ~1 ~own USOWs ......... ~N ~~7 C~ vol ~uate ~ dr~late on ~ndu~r & su~ C~ vol ~uate to M~in long s~ng ~ surf ~g ....... C~ ~11 ~ver ~1 ~own pr~uc~e ho~ons ........ ~' N / · ' ' ' ' C~ing d~igns ~ua~ for C, T, B & Ad~uate ~ge or rede piL ............... ~ N If a r~d'l' h~ a 10403 '°r ~ndnmnt ~ '~' ;~~ N ~N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N// 31. Data presented on potential overpressure zones ....... Y/N/ 32. Seismic analysis of shaJlow gas zones ............. /Y/N 33. Seabed condition survey (if off-shore) ........... /. Y N 34. Contact name/phone for weekly progres¢, repo~ ...../¢.. Y N lexp~oratory omyj ./ GEOLOGY: ENGINEERING: COMI~SION: BEW ¢J~ ?/r~?(,?~ DWj JDH <¢~r~ JDN Comments/Instructions: TAB · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ -,/7_,_.~/._~ ~ ~:~ ~IINIT CLASS~ ADMINISTRATION ENGINEERING GEOLOGY . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. /., Permit fee arrayed ....................... ~Y Lease number appropriate ................... Unique well name and number ................. Well located in a defined pool .................. Well located proper distance from ddg unit boundary ..... LY Well located pmper distance from other welis ......... I~ Sufficient acreage available in drilling unit. .......... If deviated, is wellborn plat included .............. Operator only affected party ................... 'Y Operator has appropriate bond in force ............ Y Permit can be issued without conserva§on order ...... Y Permit can be issued wbhout administrative approval .... Y Can permit be approved before 15-day wail ........ Y~ WELL NAME/~, '~c,~--.,,~ /r_.~ _ 4:~ 7 PROGRAM: exp [] d~ r~dl B ~ 0 w~l~re ~ ~ ~n. dis~ / GEOL~ ~ ¢~ UN~ ' //~~ O~FF SHORE REM~KS N N 14. Conductor s~ng provided ................... ~)_ N 15. Surface casing protects ail known USDWs ......... ..~N ~ ~ 16. CMT vol adequate to circulate on conductor & surf csg . . ./.'Y) N 17. CMT vol adequate to fie-in long s~ing to surf csg ...... .'.'~(~ 18. CMT will cover ail known productive horizons ......... ) N 19. Casing designs adequate for C, T, B & Permafrost ..... ~ N 20. Adequate tankage or reserve pit. .............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ........... 23. If diverter required, is it adequate .............. 24. Ddlling fluid program schematic & equip list adequate .... ~_~N 25. ROPEs adequate ........................ (~(.,) N 26. ROPE press rating adequate; test to ~ psig.~_~ N 27. Choke manifold complies w/APl RP-53 (May 8,~) ....... 28. Work will occur without operation shutdown .......... 29. Is presence of H2S gas probable .............. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ 31. Data. presented on potenlJai overpressure zones ....... Y//N ... 32. Seismic anaiysis of shallow gas zones ............ .~ N ' - ' 33. Seabed condition survey (if off-shore) .......... ,cf. · Y N 34. Contact name/phone for weekly pro~. ress reports..../... Y N r~roratory on/y] GEOLOGY: ENGINEERING: COMMISSION: .EW (. JDH ,7,./~:1~ JDN Comments/Instructions: A.'~FORMS'x:he~ist r~v 4~J6 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . ****************************** * ............................ , ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : Pl-09 FIELD NAiViE : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292270400 REFERENCE NO : 97316 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 97/09/24 ORIGIN : FLIC REEL NAM~ : 97316 CONTINUATION # : PREVIOUS REEL : COF~IENT : ARCO ALASKA INC, POINT MCINTYRE, Pl-09, API #50-029-22704-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/09/24 ORIGIN : FLIC TAPE NAM~ : 97316 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~NT : ARCO ALASKA INC, POINT MCINTYRE, Pl-09, API #50-029-22704-00 TAPE HEADER POINT MCINTYRE CASED HOLE WIRELINE LOGS WELL NA~E: Pl-09 API NUMBER: 500292270400 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-SEP-97 JOB NUMBER: 97316 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: KEITH St. GEF~IE SURFACE LOCATION SECTION: 16 TOWNSHIP: 12N RANGE: 14E FAUL: 1438 FSL: FEL: 752 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 44.40 DERRICK FLOOR: 42.90 GROUND LEVEL: 9.00 WELL CASING RECORD 1ST STRING 2NDSTRING 3RDSTRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 5022.0 47.00 7.000 11134.0 29.00 4.500 13242.0 12.60 4.500 10031.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88884.5 88884.5 10984.0 10980.5 10980.5 10964.0 10960.5 10960.5 10909.5 10904.0 10904.0 10856.0 10851.0 10851.0 10825.0 10821.0 10821.0 10789.5 10786.0 10786.0 10740.5 10738.0 10738.0 10728.0 10725.0 10725.0 10677.0 10674.5 10674.5 10630.0 10627.5 10627.5 10572.0 10568.5 10568.5 10564.5 10562.0 10562.0 10546.5 10543.0 10543.0 10532.5 10530.0 10530.0 10518.0 10514.0 10514.0 10480.0 10477.0 10477.0 10473.0 10471.0 10471.0 10467.0 10464.0 10464.0 100.0 97.0 97.0 $ This file contains the cased hole LDWG edit for ARCO ALASKA well Pl-09 CNTD. There are three baseline passes an average pass and three raw data files. Well loggged 21-May-97. The depth adjustments shown above reflect cased hole GR to open hole GR and cased hole NPHI to open hole GR. Ail other CNTD curves were carried with the NPHI shifts. Baseline gamma ray provided by client. $ $ PAGE: **** FILE HEADER **** FILE NAI~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS AugM~ER : 1 DEPTH INCREMENT: 0.5000 FILE SL~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10994.0 10450.0 CNTD 11021 . 0 10450.0 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUPIBER : BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: This file contains CNTDPass #1. shifts were applied to this data. $ LIS FORMAT DATA No pass to pass ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 500754 NPHI CNTD PU-S 500754 O0 000 O0 0 1 1 1 4 68 0000000000 NRATClTTD 500754 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 500754 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTD CPS 500754 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNTD CPS 500754 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 500754 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 500754 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 500754 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 500754 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 500754 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 500754 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA DEPT. 11200.000 NCNT. CNTD -999.250 GRCH. CNTD -999.250 DEPT. 10400.000 NCNT. CNTD -999.250 GRCH. CNTD -999.250 NPHI. CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD TENS. CNTD -999.250 CCL.CNTD -999.250 GR.MWD NPHI. CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD TENS. CNTD -999.250 CCL.CNTD -999.250 GR.MWD -999.250 -999.250 111.380 -999.250 -999.250 175.078 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUbtBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUPmfA2EY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10990.0 10450.0 CNTD 11021.0 10450.0 $ CURVE SHIFT DATA - PASS TO PASS (MEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUt4~ER: 1 BASELINE DEPTH 88888.0 11013.0 11003.0 10983.0 10982.5 10970.5 10965.5 10948 5 10941 0 10931 0 10923 0 10909 5 10878 0 10877 5 10863 0 10849.0 10820.0 10818.0 10797.5 10789.5 10778.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH ClTTD .............. 88886.5 88885.5 11010.5 11000.0 10980.0 10981.0 10962.5 10937.0 10874.5 10845.0 10814.5 10787.0 10967.5 10944.5 10927.5 10918.0 10903.5 10873.0 10858.0 10816.5 10792.0 10775.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 10763 10763 10747 10744 10737 5 10721 0 10717 0 10679.5 10674.5 10665.0 10657.5 10629.5 10622.5 10604.5 10592.0 10590.0 10582.0 10580.5 10574.5 10565.0 10561.0 10554.5 10546.5 10532.0 10531.5 10526.5 10517.5 10507.5 10506.5 10492.5 10489.0 10479.5 10476.0 10466.5 10459.5 10456.5 100.0 $ 5 10760.5 0 5 10745.0 0 10714.5 10677.0 10627.0 10587.5 10579.0 10563.0 10551.5 10529.5 10503.0 10489.5 10477. 10473. 97.5 10759.5 10742.0 10734.5 10718.5 10672.5 10662.0 10654.5 10619.5 10602.0 10590.0 10578.0 10571.5 10558.5 10543.0 10529.0 10524.5 10513.5 10504.0 10486.5 10464.0 10455.5 10453.5 97.0 REMARlfS: This file contains CNTD Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500754 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 500754 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 500754 O0 000 O0 0 2 1 1 4 68 0000000000 CRATCNTD 500754 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 500754 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTD CPS 500754 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 500754 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 500754 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 500754 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 500754 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 500754 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11018.500 NPHI.CNTD 24.827 NRAT. CNTD 4.146 CRAT. CNTD NCNT. CNTD 3265.306 FCNT. CNTD 787.515 CFTC. CNTD 778.986 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1320.000 CCL.CNTD 0.000 DEPT. 10447.000 NPHI.CNTD 45.119 NRAT. CNTD 6.511 CRAT. CNTD NCNT. CNTD 2541.275 FCNT. CNTD 392.894 CFTC. CNTD 396.929 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1260.000 CCL.CNTD 0.000 4.396 3394.427 6.765 2694.187 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE . FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUIV~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10990.0 10450.0 CNTD 11021 . 0 10450.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTD ............................ 88888.0 88884.0 88885.5 11006.0 11003.5 10988.5 10986.5 10983.0 10980.0 10931.5 10927.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 10928.5 10924.5 10922.5 10918.0 10898.5 10894.0 10884.5 10880.0 10879.0 10874.5 10872.5 10867.5 10862.0 10857.5 10851.0 10846.5 10843.5 10839.5 10837.5 10833.5 10826.0 10822.5 10820.0 10817.0 10797.5 10792.0 10796~5 10793.5 10790.0 10787.0 10780.5 10777.0 10778.0 10775.0 10762.0 10759.5 10757.5 10754.5 10742.0 10740.0 10731.5 10730.0 10729.5 10727.0 10722.5 10721.0 10720.5 10718.5 10717.5 10714.5 10708.0 10705.5 10705.0 10702.5 10693.0 10691.5 10686.0 10684.0 10678.5 10676.5 10674.5 10672.5 10657.0 10655.0 10653.5 10652.0 10649.0 10647.0 10629.5 10627.5 10620.5 10618.0 10616.0 10614.0 10608.5 10606.0 10604.5 10602.0 10589.5 10587.0 10584.0 10581.0 10580.5 10578.0 10571.5 10568.5 10564.0 10562.0 10562.5 10560.5 10559.0 10556.5 10550.5 10548.0 10546.0 10543.0 10544.0 10543.0 10532.0 10530.0 10523.5 10521.0 10519.5 10516.0 10509.5 10505.0 10506.5 10503.5 10498.0 10495.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 10 10492.0 10489.0 10488.0 10485.5 10479.5 10477.0 10476.0 10473.5 10475.5 10473.5 10466.5 10464 . 0 10460.0 10458.0 10458 . 0 10455.5 10454.5 10452.0 100.0 97.5 97.5 $ R2~Wna2~fS: This file contains CNTD Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 44 66 1 66 0.5 FT 23 0 FT 68 1 1 ** SET TYPE - CHAN ** ....................................................................................... NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500754 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 500754 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 500754 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 500754 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 11 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) NCNT CNTD CPS 500754 FCNTCNTD CPS 500754 CFTC CNTD CPS 500754 CNTC CNTD CPS 500754 GRCH CNTD GAPI 500754 TENS CNTD LB 500754 CCL CNTD V 500754 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11018.500 NPHI. CNTD 26.851 NRAT. CNTD 4.370 CRAT. CNTD NCNT. CNTD 3270.673 FCNT. CNTD 755.647 CFTC. CNTD 742.423 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1390.000 CCL.CNTD 0.000 DEPT. 10447.500 NPHI. CNTD 44.950 NRAT. CNTD 6.122 CRAT. CNTD NCNT. CNTD 2641 . 588 FCNT. CNTD 409. 613 CFTC. CNTD 398. 090 CNTC. CNTD GRCH. CNTD 78. 313 TENS. CNTD 1255. 000 CCL. CNTD O . 000 4. 655 3447. 832 6. 746 2713. 988 ** END OF DATA ** *~** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 12 DEPTH INC~ 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUM~ERS .......................... CNTD 1, 2, 3, $ REMARKS: The arithmetic average of passes 1,2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 40 66 1 0.5 FT 25 0 FT 68 1 1 ** SET TYPE - CHAN ** ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 500754 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 500754 O0 000 O0 0 4 1 1 4 68 0000000000 iVRAT CNAV 500754 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 500754 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 500754 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 500754 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 500754 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 500754 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 500754 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 500754 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PA GE: 13 ** DATA ** DEPT. 11017. 500 NPHI. CNAV 26. 496 iv-RAT. CNAV 4. 276 CRAT. CNAV NCNT. CNAV 3234.101 FCNT. CNAV 752.146 CFTC. CNAV 733.826 CNTC. CNAV GRCH. CNTD -999. 250 TENS. CNTD 1345 . 000 DEPT. 10447. 000 NPHI. CNAV -999. 250 NRAT. CNAV NCNT. CNAV -999 . 250 FCNT. CNAV -999. 250 CFTC. CNAV GRCH. CNTD 73 . 313 TENS. CNTD 1270. 000 -999. 250 CRAT. CNAV - 999. 250 CNTC. CNAV 4.609 3375.941 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **~* FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER : 1 DEPTH INCRE~fENT: 0.5000 FILE SDlV~VARY VENDOR TOOL CODE START DEPTH STOP DEPTH Clgq~D 11031.5 10440.0 $ LOG HEADER DATA DATE LOGGED: 21 -MAY-97 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 14 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD CNTD CNTD CNTD CNTD $ GAM~A RAY GAM~A RAY GA~A RAY GAM~A RAY COMPENSATED NEUTRON CP 44.2 1249 21-MAY-97 11152.0 10450.0 11021.0 900.0 NO TOOL NUMBER CGRS-A-820 CPLC-A-824 CPLS-A-930 TDIC-A-815 CNC-DA-iO1 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 5022.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 38.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS RAW DATA FROM PASS #1. TIED INTO CNO/SLD DATED 10/14/96 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 15 MADE 3 PASSES AT 900 FPH SANDSTONE MATRIX USED $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE- CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMiB SAMP ELE~ CODE (HEX) DEPT FT 500754 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 500754 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 500754 O0 000 O0 0 5 1 1 4 68 0000000000 TNRAPS1 500754 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 500754 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 500754 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 500754 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 500754 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 500754 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 500754 O0 000 O0 0 5 1 1 4 68 0000000000 CCLD PS1 V 500754 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 16 DEPT. 11031.500 NPHI.PS1 RCNT. PS1 3153.846 RCFT. PS1 GR.PS1 27.969 TENS.PSi DEPT. 10440.000 NPHI.PS1 RCNT. PS1 2453.886 RCFT. PS1 GR.PS1 67.125 TENS. PSi 28.249 RTNR.PS1 692.308 CNTC. PS1 890.000 CCLD. PS1 45.782 RTNR.PS1 376.176 CNTC. PS1 1235.000 CCLD.PS1 4.556 3307.237 0.021 6.489 2581.820 0.000 TNRA.PS1 CFTC. PSi TNRA.PS1 CFTC. PSi 4.829 684.809 6.841 376.583 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMF2VT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH CNTD 11028.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : STOP DEPTH .......... 10442.5 21-MAY-97 CP 44.2 1249 21-MAY-97 11152.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 17 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GAFk~A RAY GAMMA RAY GAM~A RAY GAMMA RAY COMPENSATED NEUTRON 10450.0 11021.0 900.0 NO TOOL ~ER CGRS-A- 820 CPLC-A- 824 CPLS-A-930 TDIC-A - 815 CNC-DA-iO1 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 5022.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 38.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THF2AMAL) : MATRIX: MATRIX DENSITY.. HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS RAW DATA FROM PASS #2. TIED INTO CNO/SLD DATED 10/14/96 MADE 3 PASSES AT 900 FPH SANDSTONE MATRIX USED $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 18 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 44 1 0.5 FT 23 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) DEPT FT 500754 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 500754 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 500754 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 500754 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 500754 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 500754 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 500754 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 500754 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 500754 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 500754 O0 000 O0 0 6 1 1 4 68 0000000000 CCLD PS2 V 500754 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11028.500 NPHI.PS2 24.827 RTNR. PS2 4.146 TNRA.PS2 RCNT. PS2 3265.306 RCFT. PS2 787.515 CNTC. PS2 3424.118 CFTC. PS2 GR.PS2 41.344 TENS.PS2 610.000 CCLD. PS2 0.021 4.396 778.985 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 19 DEPT. 10442.500 NPHI.PS2 RCNT. PS2 2374.085 RCFT. PS2 GR.PS2 82.313 TENS.PS2 48.560 RTNR.PS2 359.457 CNTC. PS2 1280.000 CCLD.PS2 6.791 2548.088 0.000 TNRA.PS2 CFTC.PS2 7. 159 359. 363 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCRE~IENT: O. 5000 FILE SD?4~ARY VENDOR TOOL CODE START DEPTH CNTD 11030.0 $ LOG H~ER DATA DATE LOGGED: SOFTWARE VERSION: TI~IE LOGGER ON BOTTOM: Ti) DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10443.5 21-MAY-97 CP 44.2 1249 21-MAY-97 11152.0 10450.0 11021.0 900.0 NO LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 20 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GAM~A RAY GAM~A RAY GAMMA RAY GAF~4A RAY COMPENSATED NEUTRON TOOL NUMBER CGRS-A-820 CPLC-A-824 CPLS-A-930 TDIC-A-815 CNC-DA-iO1 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 5022.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 38.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS) '. 0 ArEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS RAW DATA FROM PASS #3. TIED INTO CNO/SLD DATED 10/14/96 MADE 3 PASSES AT 900 FPH SANDSTONE MATRIX USED $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELEM CODE (HEX) DEPT FT 500754 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 500754 O0 000 00 0 7 1 1 4 68 0000000000 RTNR PS3 500754 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 500754 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 500754 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 500754 O0 000 O0 0 7 1 1 4 68 0000000000 ClTTC PS3 CPS 500754 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 500754 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 500754 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 500754 O0 000 O0 0 7 1 1 4 68 0000000000 CCLDPS3 V 500754 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11030.000 NPHI.PS3 27.999 RTNR.PS3 4.526 TNRA.PS3 RCNT. PS3 3303.721 RCFT. PS3 729.892 CNTC. PS3 3464.401 CFTC. PS3 GR.PS3 24.172 TENS.PS3 915.000 CCLD.PS3 0.021 DEPT. 10443.500 NPHI.PS3 46.817 RTNR.PS3 6.245 TNRA.PS3 RCNT. PS3 2585.189 RCFT. PS3 409.613 CNTC. PS3 2656.938 CFTC. PS3 GR.PS3 98.125 TENS.PS3 1280.000 CCLD.PS3 0.000 4.798 721.986 6.960 384.788 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-SEP-1997 12:44 PAGE: 22 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/09/24 ORIGIN : FLIC TAPE NA~iE : 97316 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, POINT MCINTYRE, Pl-09, API #50-029-22704-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/09/24 ORIGIN : FLIC REEL NAPiE : 97316 CONTINUATION # : PREVIOUS REEL : COf4~_2Fr : ARCO ALASKA INC, POINT MCINTYRE, Pl-09, API #50-029-22704-00 =.~ Subfile 2 is type: ~S TAPE HEADER POINT MCINTYRE I/NIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM- 60136 TONY PIEPER NICK SCALES P1-09 500292270400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 20-FEB-97 MWD RUN 3 MEL GABEL NICK SCALES MWD RUN 4 MEL GABEL NICK SCALES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 PAUL ROBERTS KIRK WHITE MWD RUN 6 PAUL ROBERTS KIRK WHITE MWD RUN 7 PAUL ROBERTS KIRK WHITE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 PAUL ROBERTS KIRK WHITE MWD RUN 9 PAUL ROBERTS KIRK WHITE MWD RUN 10 PAUL ROBERTS KIRK WHITE MWD RUN 11 JOB NUMBER: LOGGING ENGINEER: PAUL ROBERTS OPERATOR WITNESS: KIRK W~~ ~URFACE LOCATION ~~%%~_ ----,~%9 SECTION: , ~%%~'%~'~ FNL: ~' I~;~%~.-''~'~ FSL: ~ FEL: n~~ FWL: ~ ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GRO~D LEVEL: OPEN HOLE MWD RUN 12 PAUL ROBERTS KIRK WHITE WELL CASING RECORD 16 12N 15E 1438 752 44.38 42.88 9.00 MAR 05 REMARKS: MWD - EWR4/CNP/SLD/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. THIS WELL, Pl-09, IS REPRESENTED BY RUNS 1 THROUGH 13. ALL GAMMA RAY DATA WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS (DGR/SGRC). MWD RUN 1 WAS DIRECTIONAL ONLY. NO DATA IS PRESENTED. 1ST STRING 2ND STRING 12.250 9.625 5022.0 3RD STRING 8.500 7.000 11134.0 PRODUCTION STRING 6.000 13240.0 MWD RUN 13 PAUL ROBERTS KIRK WHITE RECEIVED CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) MWD RUN 2 ..AS DIRECTIONAL WITH GAMMA RAY (SGRC) . MWD RUNS 3 & 4 WERE DIRECTIONAL WITH GAMMA RAY (SGRC) ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP/SPSF), AND STABILIZED LITH-DENSITY (SLD/SBDC). MWD RUNS 5 THROUGH 13 WERE DIRECTIONAL WITH GAMMA RAY (SGRC), AND ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4) . A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED OVER 12748 - 13125' AFTER COMPLETION OF RUN 12. THE WELL WAS DRILLED TO TD AT 13240' ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOGS: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 800 - 20000 ppm MUD WEIGHT: 9.2 - 10.4 ppg FORM. WATER SALINITY: 11500 ppm FLUID DENSITY: 1.0 g/cc MATRIX DENSITY: 2.65 g/cc LITHOLOGY: SANDSTONE. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 4898.0 6810.0 6818.0 6827.0 BASELINE DEPTH GR 4898.0 4897.5 9709.5 9709.0 9733.0 9730.5 9735.0 9733.0 9740 . 0 9738 . 0 9747.0 9745.5 9826.0 9827.0 9912.5 9911.0 9970.5 9969.0 9978.5 9977.0 9991.0 9990.0 10040.5 10040.0 10070.0 10071.0 10078.0 10077.5 10081.0 10079.5 10087.0 10087.0 10095.5 10093.5 10111.5 10111.0 10115.0 10113.5 10134.5 10133.5 10138.0 10136.5 10155.0 10152.5 10156.5 10155.5 10160.5 10158.5 10182.0 10185.5 10201.0 10199.5 10204.0 10202.5 10207.5 10206.5 10212.0 10211.5 10214.0 10213.5 10218.0 10217.0 10222.0 10221.0 10228.5 10226.5 10239.5 10238.5 10243.0 10242.0 10270.5 10270.5 10273.0 10272.5 10276.0 10275.0 10298.0 10296.0 10322.0 10320.0 10352.0 10351.5 all bit runs merged. STOP DEPTH 13213.0 13220.0 11089.0 11097.0 EQUIVALENT UNSHIFTED DEPTH z0356.5 10359.5 10364.5 10367.0 10375.0 10383 .5 10389.0 10394.0 10398.5 10402.5 10409.5 10419.5 10422.0 10425. 0 10431.5 10434.5 10441.5 10445.0 10448.5 10453.0 10457.5 10464.5 10468.0 10473 . 5 10477.0 10481.5 10486.0 10488.5 10494.5 10504.0 10505.5 10530.5 10536.5 10543 .5 10551.5 10556.0 10561.5 10565.0 10573.0 10587.5 10603 .5 10618.5 10627.5 10637.0 10649.5 10674.0 10709.0 10725.0 10745.0 10779.0 10786.5 10818.0 10857.5 10869.0 10895.0 10920.0 10937. 0 10942.5 10960.5 10980.0 10_ .3.0 10360.5 10363.5 10366.5 10373.5 10382.0 10387.5 10392.5 10396.0 10401.0 10408.0 10418.5 10421.5 10425.5 10431.0 10434.0 10440.5 10443.5 10447.5 10452.5 10456.0 10463.5 10466.0 10471.5 10476.0 10480.5 10485.0 10487.5 10494.5 10504.0 10506.5 10530.5 10539.0 10546.0 10555.0 10559.0 10564.0 10567.0 10574.5 10588.5 10605.5 10621.0 10630.0 10640.0 10653.0 10676.0 10710.5 10726.5 10746.5 10778.5 10788.5 10822.5 10858.0 10873.0 10898.5 10923.5 10941.0 10946.5 10964.0 10984.0 10985.0 10999.0 11007.0 11015.5 11047.5 11051.5 13238.5 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: DATA SOURCE TOOL CODE 105_8.0 11003.0 11010.0 11019.0 11049.0 11053.0 13240.0 BIT RUN NO MERGE TOP MERGE BASE 2 5032.0 6897.0 3 6897.0 10562.0 4 10562.0 11146.0 5 11146.0 11457.0 6 11457.0 11742.0 7 11742.0 11846.0 8 11846.0 12421.0 9 12421.0 12876.0 10 12876.0 13065.0 11 13065.0 13149.0 12 13149.0 13184.0 13 13184.0 13240.0 MERGED MAIN PASS. ALL CURVES WERE SHIFTED WITH GR. CN WN FN COUN STAT /??SHIFT.OUT $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Sampl 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 NPHI MWD 68 7 FCNT MWD 68 8 NCNT MWD 68 9 RHOB MWD 68 10 DRHO MWD 68 es Units AAPI OHMM OHMM OHMM OHMM PU-S CPS CPS G/C3 G/C3 Size 4 4 4 4 4 4 4 4 4 4 Length API AP1 AP1 API Log Crv Crv Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 11 PEF MWD 68 1 BN/E 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 928 4 90 995 99 4 90 995 99 4 90 995 99 52 Tape File Start Depth = 13240.000000 Tape File End Depth = 4897.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 233619 datums Tape Subfile: 2 1163 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: CN WN FN COUN STAT START DEPTH 12747.0 12752.0 STOP DEPTH 13117.0 13124.0 MAD RUN NO. MA/D PASS NO. MERGE TOP 12 1 12747.0 MERGE BASE 13124.0 SHIFTED MAD PASS LOGGED AFTER MWD RUN 12. ALL CURVES WERE SHIFTED WITH GR. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 Tape File Start Depth = 13200.000000 Tape File End Depth = 12700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7008 datums Tape Subfile: 3 53 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4897.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: M~_XIM~ ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 6842.0 09-0CT-96 ISC 4.88 CIM 5.46 MEMORY 6897.0 5032.0 6897.0 0 31.7 47.9 TOOL NUMBER P0544CG6 8.500 5022.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 8.90 49.0 11.5 8OO 72.0 .000 .000 .000 .000 .0 98.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STA/qDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT ARCO ALASKA, INC. P1-09 POINT MCINTYRE NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 48 Tape File Start Depth = 6900.000000 Tape File End Depth = 4897.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 245641 datums Tape Subfile: 4 111 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SIZvflVLARY VENDOR TOOL CODE START DEPTH GR 6837.0 EWR4 6810.0 CNP 6817.0 SLD 6836.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10502.0 10475.0 10482.0 10491.0 12-OCT-96 ISC 4.88 CIM 5.46 MEMORY 10562.0 6897.0 10562.0 0 41.6 5~1.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO-DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0594CRNDG6 P0594CRNDG6 P0594CRNDG6 P0594CRNDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 5022.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.20 60.0 9.0 14000 4.2 .330 .170 .200 .460 67.0 137.0 67.0 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (~./ : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. CN WN FN COUN STAT : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA 8.500 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units AP1 API AP1 AP1 Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 FCNT MWD 68 1 CPS 4 8 NCNT MWD 68 1 CPS 4 9 RHOB MWD 68 1 G/C3 4 10 DRHO MWD 68 1 G/C3 4 11 PEF MWD 68 1 BN/E 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 423 Tape File Start Depth = 10600.000000 Tape File End Depth = 6800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 113423 datums Tape Subfile: 5 492 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10466.0 11110.0 EWR4 10438.0 11083.0 CNP 10446.0 11090.0 SLD 10455.0 11099.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMIIM ANGLE: MAXIMUM ANGLE: 14-0CT-96 ISC 4.88 CIM 5.46 MEMORY 11146.0 10562.0 11146.0 0 25.3 40.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO-DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0594CRNDG6 P0594CRNDG6 P0594CRNDG6 P0594CRNDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 5022.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.10 54.0 8.5 20000 4.0 .300 .170 .220 .460 68.0 146.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (~ .j : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA 8.500 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 FCNT MWD 68 1 CPS 4 8 NCNT MWD 68 1 CPS 4 9 RHOB MWD 68 1 G/C3 4 10 DRHO MWD 68 1 G/C3 4 11 PEF MWD 68 1 BN/E 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 9O 220 09 1 4 9O 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 89 Tape File Start Depth = 11200.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 268056 datums Tape Subfile: 6 158 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FiLE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11024 . 0 11405 . 0 EWR4 11031.0 11412 . 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 18-OCT-96 ISC 4.88 CIM 5.46 MEMORY 11457.0 11146.0 11457.0 0 24.5 37.5 TOOL NUMBER P0388SP4 P0388SP4 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.40 60.0 9.0 20000 3.0 .300 .150 .185 .450 68.0 141.7 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 5. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 33 Tape File Start Depth = 11500.000000 Tape File End Depth = 11000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 121432 datums Tape Subfile: 7 98 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11404.0 EWR4 11411.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11690.0 11697.0 19-OCT-96 ISC 4.88 CIM 5.46 MEMORY 11742.0 11457.0 11742.0 0 43.0 68.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NIJMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.4O 70.0 9.0 20000 3.4 .250 .120 .185 .400 68.0 146.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RI/N 6. $ : ARCO ALASKA, INC. : Pl-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 26 Tape File Start Depth = 11800.000000 Tape File End Depth = 11400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 274465 datums Tape Subfile: 8 91 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11670.0 EWR4 11675.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11778.0 11785.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 20-0CT-96 ISC 4.88 CIM 5.46 MEMORY 11846.0 11742.0 11846.0 0 68.1 78.4 TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE ~(DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.40 77.0 8.5 18000 3.6 .280 .130 .185 .450 68.0 146.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: MOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : o0 0 REMARKS: CN WN FN COUN STAT MWD RUN 7. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 17 Tape File Start Depth = 11900.000000 Tape File End Depth = 11650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TP~AILER **** LIS representation code decoding summary: Rep Code: 68 125441 datums Tape Subfile: 9 82 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11778.0 EWR4 11785.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12354.0 12361.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 22-OCT-96 ISC 4.88 CIM 5.46 MEMORY 12421.0 11846.0 12421.0 0 71.3 76.6 TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.40 77.0 9.0 18000 3.8 .220 .130 .200 .560 70.0 146.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 8. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 RPX MWD 68 1 3 RPS MWD 68 1 4 RPM MWD 68 1 5 RPD MWD 68 1 6 FET MWD 68 1 7 ROP MWD 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod AAPI 4 OHMM 4 OHMM 4 OHMM 4 OHMM 4 HR 4 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 46 Tape File Start Depth = 12450.000000 Tape File End Depth = 11750.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 285674 datums Tape Subfile: 10 111 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12331.0 EWR4 12338.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIM UMANGLE: STOP DEPTH 12817.0 12825.0 24-0CT-96 ISC 4.88 CIM 5.46 MEMORY 12876.0 12421.0 12876.0 0 68.4 75.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0497SP4 P0497SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.60 78.O 8.5 20000 3.8 .230 .100 .200 .550 72.0 146.0 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 9. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 39 Tape File Start Depth = 12900.000000 Tape File End Depth = 12300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 135050 datums Tape Subfile: 11 104 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12808.0 EWR4 12815.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13037.0 13044.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 26-0CT-96 ISC 4.88 CIM 5.46 MEMORY 13065.0 12876.0 13065.0 0 68.7 68.8 TOOL NUMBER P0497SP4 P0497SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ICL/POLYMER 10.60 78.0 9.0 18000 4.2 .200 .070 .180 .600 68.0 190.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 10. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 ! OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 20 Tape File Start Depth = 13100.000000 Tape File End Depth = 12800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 290483 datums Tape Subfile: 12 85 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 13 is type: LIS FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13026.0 EWR4 13033.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13122.0 13129.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 27-0CT-96 ISC 4.88 CIM 5.46 MEMORY 13149.0 13065.0 13149.0 0 68.6 68.6 TOOL NUMBER P0497SP4 P0497SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.60 76.0 9.0 17000 3.8 .200 .070 .180 .600 68.0 190.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 11. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 13 Tape File Start Depth = 13200.000000 Tape File End Depth = 13000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 138259 datums Tape Subfile: 13 78 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 14 is type: LIS FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13121.0 EWR4 13128.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13156.0 13163.0 28-0CT-96 ISC 4.88 CIM 5.46 MEMORY 13184.0 13149.0 13184.0 0 68.6 69.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.60 76.0 9.0 17000 3.8 .190 .690 .160 .550 70.0 203.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 12. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 10 Tape File Start Depth = 13240.000000 Tape File End Depth = 13100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 292732 datums Tape Subfile: 14 75 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 15 is type: LIS FILE HEADER FILE NLTMBER: 14 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 13 DEPTH INCREMENT: .5000 FILE SLTMMARY VENDOR TOOL CODE START DEPTH GR 13155.0 EWR4 13162.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13215.0 13222.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 29-OCT-96 ISC 4.88 CIM 5.46 MEMORY 13240.0 13184.0 13240.0 0 69.9 69.9 TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.60 76.0 9.0 17000 3.8 .190 .690 .160 .550 70.0 200.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 13. $ : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 10 Tape File Start Depth = 13240.000000 Tape File End Depth = 13100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 140508 datums Tape Subfile: 15 75 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 16 is type: LIS FILE HEADER FILE NUMBER: 15 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 12 MAD PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12748.0 EWR4 12753.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13119.0 13126.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 28-0CT-96 ISC 4.88 CIM 5.46 MEMORY 13184.0 12748.0 13126.0 0 68.6 69.3 TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11134.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL/POLYMER 10.60 76.0 9.0 17000 3.8 .190 .690 .160 .550 70.0 203.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : . 0 EWR FREQUENCY (HZ) : REMARKS: MAD PASS RUN AFTER MWD RUN 12. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : P1-09 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 A_API 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 Tape File Start Depth = 13200.000000 Tape File End Depth = 12700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TP~AILER **** LIS representation code decoding summary: Rep Code: 68 299740 datums Tape Subfile: 16 94 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 17 is type: LIS O1 **** REEL TRAILER **** 97/ 2/ 9 01 Tape Subfile: 17 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 19 FEB 97 2:04p Elapsed execution time = 8.23 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * . . . ............................ . * ....... SCHLUMBERGER ....... * . ............................ . COMPANY NAME : ARCO ALASKA, INC. WELL NAME : Pl-09 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22704-00 REFERENCE NO : 96344 * ALASKA COMPUTING CENTER * . ............................ ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : Pl-09 FIELD NAME : POINT MCINTYRE BOROUGH ' NORTH SLOPE STATE : ALASKA API~ER : 50-029-22704-00 REFERENCE NO : 96344 J Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/02/ 5 ORIGIN : FLIC REEL NAME : 96344 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, Pl-09, POINT MCINTYRE, API #50-029-22704-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/02/ 5 ORIGIN : FLIC TAPE NAME : 96344 CONTINUATION # : 1 PREVIOUS TAPE : CO~IENT : ARCO ALASKA INC, Pl-09, POINT MCINTYRE, API #50-029-22704-00 TAPE HEADER Point McIntyre OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: ~GE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2NDSTRING P1 - 09 500292270400 ARCO Alaska, Inc. SCHLUMBERGER WELL SERVICES S-FEB-97 RUN 1 96344 Maj cher/YON HAYWOOD/WHIT RUN 2 RUN 3 16 12N 14E 1438 752 44.40 42.90 9.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 11134.0 S Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 3RD STRING PRODUCTION STRING REMARKS: The data was obtained using the TLC drillpipe conveyed logging system. Log was depth shifted to the Sperry MWD GR that was in turn shifted to the SWS CBT logged 2-Nov-96 as per Tom Eggert of ARCO. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE SDN CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 13240.0 11134.0 13217.0 11134.0 BASELINE DEPTH .............. 88888.0 13186.0 13164.5 13159.5 13151.0 13142.5 13135.0 13131.5 13079.0 13059.5 13037.0 12985.5 12979.0 12975.0 12964.0 12952.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... SDN ....... 88890.0 13188.0 13167.0 13164.5 13154.5 13146.5 13139.0 13135.0 13081.5 13062.0 13038.0 12988.5 12980.5 12977.5 12965.5 12955.0 ~ Tape Verification Listing Schlumberger Alaska Computing Center 12941.5 12938.0 12929.0 12916.5 12911.5 12902.5 12894.0 12882.5 12777.0 12765.5 12762.5 12759.5 12751.5 12747.0 12743.0 12719.5 12691.0 12680.5 12667.5 12616.0 12590.5 12555.5 12537.0 12514.5 12462.0 12414.0 12376.5 123 63.5 12333.5 12322.5 123 O1.5 12274.0 12261.5 12255.5 12231.0 12225.0 12207.0 12201.5 12199.0 12185.5 12136.5 12129.5 12087.0 12078.0 12064.5 12056.0 11980.5 11949.5 11883.5 11866.0 11855.0 11851 . 0 11840.5 11826.5 11786.5 12943.0 12939.5 12930.5 12917.0 12913.0 12904.5 12895.5 12883.5 12779.0 12766.0 12763.5 12760.5 12752.5 12749.5 12745.0 12721.0 12693.5 12681.5 12669.5 12617.5 12593.0 12559.0 12541.5 12518 0 12464 0 12415 5 12378 5 12366 0 12335 5 12321.5 12301.0 12275.5 12262.0 12257.0 12231.0 12225.0 12204.0 12197.5 12195.5 12181.5 12135.0 12128.0 12086.0 12079.5 12067.0 12057.5 11978.5 11953.0 11886.0 11869.0 11856.0 11853.5 11844.0 11829.0 11789.5 5-FEB-1997 13:25 PAGE: _S Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 11771.5 11751.0 11727.0 11708.5 11690.5 11657.5 11605.0 11524 0 11510 5 11505 0 11490 0 11469 5 11451 0 11445 0 11418 5 11404 0 11385.5 11316.0 11303.0 11280.0 11274.5 11243.5 11230.5 11225.0 11219.5 11211.0 11203.0 11149.5 11132.0 11108.5 100.0 $ M~RGED DATA SOURCE LDWG TOOL CODE $ ~S: 11774.5 11753.0 11731.0 11711.5 11693.5 11659.5 11608.0 11527.5 11514 5 11507 5 11492 0 11471 0 11454 5 11448 5 11421 5 11406.0 11388.0 11318.0 11305.5 11282.0 11275.0 11243.0 11232.0 11227.0 11221.5 11212.5 11206.0 11151.0 11133.0 11109.0 100.5 RUN NO. PASS NO. I~ERGE TOP MERGE BASE THIS DATA IS THE EDITED AND CLIPPED OH DATA THAT HAS BEEN DEPTH SHIFTED TO THE SPERRY MWD GR THAT WAS IN TURN SHIFTED TO THE SWS CBT LOGGED 2-NOV-96. THE GR WAS SHIFTED TO THE BASE GR AND ALL THE OTHER CURVES WERE CARRIED ALONG WITH IT. $ LIS FORMAT DATA =S Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 1 I 1 4 68 0000000000 TEND SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 MRES SDN OIff4~ O0 000 O0 0 1 1 1 4 68 0000000000 MTEMSDN DEGF O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNT O0 000 O0 0 i 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 =S Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: ** DATA ** DEPT. 13240.000 GR.SDN MRES. SDN -999.250 MTEM. SDN PEF. SDN -999.250 CALI.SDN NCNT. CNT -999.250 FCNT. CNT NPHI.CNT -999.250 CPHI. CNT CFEC. CNT -999.250 CNEC. CNT DEPT. 13000.000 GR.SDN MRES.SDN 0.087 MTEM. SDN PEF. SDN 3.638 CALI.SDN NCNT. CNT 6092.000 FCNT. CNT NPHI.CNT 12.274 CPHI.CNT CFEC. CNT 2835.000 CNEC. CNT DEPT. 12000.000 GR.SDN RIRES.SDN 0.099 MTEM. SDN PEF.SDN 3.867 CALI.SDN NCNT. CNT 1981.625 FCNT. CNT NPHI.CNT 37.601 CPHI.CNT CFEC. CNT 595.969 CNEC. CNT DEPT. 11134.000 GR.SDN MRES.SDN 0.096 MTEM. SDN PEF. SDN 3.449 CALI.SDN NCNT. CNT 1530.000 FCNT. CNT NPHI. CNT 45.844 CPHI.CNT CFEC. CNT 532.734 CNEC. CNT -999.250 TEND. SDN -999.250 DRHO.SDN -999.250 CNTC. CNT -999.250 CRAT. CNT -999.250 ENPH. CNT -999.250 96.031 TEND.SDN 209.380 DRHO.SDN 6.534 CNTC. CNT 3480.000 CRAT. CNT 13.849 ENPH. CNT 5501.000 123.422 TEND.SDN 191.254 DRHO. SDN 8.519 CNTC. CNT 533.531 CRAT. CNT 39.348 ENPH. CNT 2906.836 78.172 TEND.SDN 183.144 DRHO.SDN 6.358 CNTC. CNT 446.781 CRAT. CNT 43.243 ENPH. CNT 2877.875 -402.207 -999.250 -999.250 -999.250 -999.250 96.500 O. 011 5658. 000 1. 418 8. 585 657.500 0.014 1889.875 3.354 31.445 875. 750 -0.161 1598.230 3. 581 38. 975 TENS. SDN RHOB. SDN CFTC. CNT NRA T. CNT ENRA. CNT TENS. SDN RHOB. SDN CFTC. CNT NRA T. CNT ENRA. CNT TENS. SDN RHOB. SDN CFTC. CNT NRA T. CNT ENRA. CNT TENS. SDN RHOB. SDN CFTC. CNT NRA T . CNT ENRA. CNT 1845.000 -999.250 -999.250 -999.250 -999.250 2365.500 2.624 3740.000 1.461 1.944 2168.250 2.514 574.867 3.410 4.878 407. 969 2. 221 465. 875 3. 552 5. 402 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~S Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y LDWG TOOL CODE START DEPTH CNT 11134.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (NIEASURED DEPTH) BASELINE DEPTH 88888.0 13186.0 13164.5 13159.5 13151.0 13142.5 13135 0 13131 5 13079 0 13059 5 13037 0 12985 5 12979 0 12975 0 12964.0 12952.5 12941.5 12938.0 12929.0 12916.5 12911.5 12902.5 12894.0 12882.5 12777.0 12765.5 12762.5 12759.5 12751.5 12747.0 12743.0 12719.5 12691.0 12680.5 12667.5 12616.0 12590.5 STOP DEPTH 11054.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT 8889O. 0 13188.0 13167.0 13164.5 13154.5 13146.5 13139.0 13135.0 13081.5 13062.0 13038 0 12988 5 12980 5 12977 5 12965 5 12955 0 12943 0 12939 5 12930 5 12917.0 12913.0 12904.5 12895.5 12883.5 12779.0 12766.0 12763.5 12760.5 12752.5 12749.5 12745.0 12721.0 12693.5 12681.5 12669.5 12617.5 12593.0 iS Tape Verification Listing Schlumberger Alaska Computing Center 12555.5 12537.0 12514.5 12462.0 12414.0 12376.5 12363 5 12333 5 12322 5 12301 5 12274 0 12261 5 12255 5 12231 0 12225 0 12207 0 12201 5 12199 0 12185 5 12136 5 12129.5 12087.0 12078.0 12064.5 12056.0 11980.5 11949.5 11883.5 11866.0 11855.0 11851.0 11840.5 11826.5 11786.5 11771.5 11751.0 11727.0 11708.5 11690.5 11657.5 11605.0 11524.0 11510.5 11505.0 11490.0 11469.5 11451.0 11445 0 11418 5 11404 0 11385 5 11316 0 11303 0 11280 0 11274 5 12559.0 12541.5 12518.0 12464.0 12415.5 12378.5 12366.0 12335.5 12321.5 12301.0 12275.5 12262 0 12257 0 12231 0 12225 0 12204 0 12197 5 12195 5 12181 5 12135 0 12128 0 12086.0 12079.5 12067.0 12057.5 11978.5 11953.0 11886.0 11869.0 11856.0 11853.5 11844.0 11829.0 11789.5 11774.5 11753.0 11731.0 11711.5 11693.5 11659.5 11608.0 11527.5 11514.5 11507.5 11492.0 11471.0 11454.5 11448.5 11421.5 11406.0 11388.0 11318.0 11305.5 11282.0 11275.0 5-FEB-1997 13:25 PAGE: JIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 11243 11230 11225 11219 11211 11203 11149 11132 11108 100 $ 5 11243.0 5 11232.0 0 11227.0 5 11221.5 0 11212.5 0 11206.0 5 11151.0 0 11133.0 5 11109.0 0 100.5 REMARKS: THIS DATA IS THE EDITED AND CLIPPED CH DATA THAT HAS BEEN DEPTH SHIFTED TO THE SPERRY MWD GR THAT WAS IN TURN SHIFTED TO THE SWS CBT LOGGED 2-NOV-96. THE GR WAS SHIFTED TO THE BASE GR AND ALL THE OTHER CURVES WERE CARRIED ALONG WITH IT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 72 1 0.5 FT 14 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 2 1 1 4 68 0000000000 .iS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 10 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~I CODE (HEX) TEND SDN LB O0 000 O0 0 2 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 2 1 1 4 68 0000000000 ~IRES SDN 0H~24 O0 000 O0 0 2 1 1 4 68 0000000000 MTEMSDN DEGF O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNT O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11134.000 GR.SDN 78.172 TEND. SDN 875.750 TENS.SDN MRES.SDN 0.096 MTEM. SDN 183.144 CNTC. CNT 1598.230 CFTC. CNT NCNT. CNT 1530.000 FCNT. CNT 446.781 CRAT. CNT 3.581 NRAT. CNT NPHI.CNT 45.844 CPHI.CNT 43.243 ENPH. CNT 38.975 ENRA.CNT CFEC. CNT 532.734 CNEC. CNT 2877.875 DEPT. 11053.000 GR.SDN 72.408 TEND.SDN 833.034 TENS.SDN MRES.SDN 0.099 MTE~I. SDN 182.224 CNTC. CNT 1556.919 CFTC. CNT NCNT. CNT 1574.256 FCNT. CNT 426.314 CRAT. CNT 3.731 NRAT. CNT NPHI.CNT 46.632 CPHI.CNT 46.180 ENPH. CNT 42.034 ENRA.CNT CFEC. CNT 488.727 CNEC. CNT 2814.909 407. 969 465. 875 3. 552 5. 402 2361. 000 417.304 4.476 5. 665 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~S Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH LDTD 13244.0 11133.0 CNTG 13215.0 11133.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDTD LITHODENSITY SONDE LDTD LITHODENSITY CART. CNTG EPITHERMAL NEUTRON GR GANfiVA RAY AMS AUX. MEAS. SONDE $ BOREItOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 29-0CT-96 8B0538 830 28-0CT-96 728 29-0CT-96 13243.0 13243.0 11053.0 13243.0 1800.0 TOOL NUMBER DRS-C 2984 NSC-E 907 CNC-GA 125 SGC-SA 1804 AMS-AA 712 6.000 11134.0 11134.0 .IS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 12 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): KCL POLYMER 10.60 81.0 9.0 212.0 0.325 74.0 0.226 74.0 0.447 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: TOOLS DRILLPIPE CONVEYED - TLC SYSTEM NO BARITE CORRECTIONS MADE TO LOG TWO TOOL TURNERS USED TO ORIENT TOOLS DEVIATION AVERAGES 70 DEC OVER LOGGED INTERVAL LOGS RUN ON SANDSTONE MATRIX $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 104 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT JIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE 13 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GR LDT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 HTENLDT LB O0 000 O0 0 3 1 1 4 68 0000000000 TENS LDT LB O0 000 O0 0 3 1 1 4 68 0000000000 ~!~ESLDT OPiMM O0 000 O0 0 3 1 1 4 68 0000000000 MTEMLDT DEGF O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LDT G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DPHILDT PU O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT BN/E O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCNT CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNTG O0 000 O0 0 3 1 1 4 68 0000000000 RTNR CNTG O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CNTG PU O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNTG PU O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCEN CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCEF CNTG CPS O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13244.500 GR.LDT 37.101 HTEN. LDT -2512.991 TENS.LDT MRES.LDT 0.088 MTEM. LDT 209.695 DRHO.LDT 0.013 DPHI.LDT RHOB.LDT 2.351 PEF. LDT 6.629 CALI.LDT 5.466 CNTC. CNTG CFTC. CNTG 2492.007 RCNT. CNTG 5237.141 RCFT. CNTG 2354.604 TNRA.CNTG RTNR.CNTG 2.158 NPOR.CNTG 22.719 NPHI.CNTG 23.323 TNPH. CNTG ENPH. CNTG 16.376 EIVRA.CNTG 2.948 CFEC. CNTG 1487.651 CNEC. CNTG RCEN. CNTG 4165.037 RCEF. CNTG 1470.787 1755.000 20.979 5194.079 2.096 22.719 4385.367 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 14 DEPT. 13000. 000 GR.LDT ~!R~ES.LDT O. 086 MTEM. LDT RHOB . LDT 2.573 PEF. LDT CFTC. CNTG 2642. 956 RCNT. CNTG RTNR. CNTG 1 . 829 NPOR. CNTG ENPH. CNTG 12.939 ENRA . CNTG RCEN. CNTG 4037.396 RCEF. CNTG DEPT. 12000. 000 GR. LDT MRES . LDT O . 099 MTEM. LDT RHOB . LDT 2. 499 PEF. LDT CFTC. CNTG 533. 402 RCNT. CNTG R TNR. CNTG 3.531 NPOR. CNTG ENPH. CNTG 34. 822 ENRA. CNTG RCEN. CNTG 2780. 735 RCEF. CNTG DEPT. 11134 . 000 GR. LDT I~RES . LDT O . 096 MTEM. LDT RHOB . LDT 2.380 PEF. LDT CFTC. CNTG 505. 422 RCNT. CNTG R TNR. CNTG 3.590 NPOR. CNTG ENPH. CNTG 41.154 EArRA. CNTG RCEN. CNTG 2468. 135 RCEF. CNTG 109. 955 209 600 3 955 4114 657 18 962 2 534 1679 066 127.357 191.178 3.569 1840. 741 42. 363 5.214 570. 354 86. 685 183.224 3. 673 1616. 539 43. 945 5. 623 448. 433 HTEN. LDT DRHO. LDT CALI. LDT RCFT. CNTG NPHI. CNTG CFEC. CNTG HTEN. LDT DRHO. LDT CALI . LD T RCFT. CNTG NPHI. CNTG CFEC. CNTG HTEN. LDT DRHO. LDT CALI . LDT RCFT. CNTG NPHI. CNTG CFEC. CNTG 197.893 TENS.LDT 0.014 DPHI.LDT 6.405 CNTC. CNTG 2563.146 TNRA.CNTG 18.343 TNPH. CNTG 1696.279 CNEC. CNTG 758. 960 TENS. LDT O. 018 DPHI.LDT 8. 585 CNTC. CNTG 483 . 402 TNRA. CNTG 43.808 TNPH. CNTG 556.259 CNEC. CNTG 841.728 TENS.LDT 0.026 DPHI.LDT 7.003 CNTC. CNTG 458.216 TNRA.CNTG 45.814 TNPH. CNTG 485.552 CNEC. CNTG 2165.000 8. 014 4461. 526 1 . 820 16.493 4299.110 2250.000 12.342 1841.720 3.539 41.943 2900.586 459.000 19.314 1690.469 3.536 41.394 2730.304 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 15 RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUI~VARY VENDOR TOOL CODE START DEPTH LDTD 13244.0 CNTG 13214.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 12589.0 12589.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDTD LITHODENSITY SONDE LDTD LITHODENSITY CART. CNTG EPITHERMAL NEUTRON GR GAYm~A RAY AMS AUX. MEAS. SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): 29-0CT-96 8B0538 830 28-0CT-96 728 29-0CT-96 13243.0 13243.0 11053.0 13243.0 1800.0 TOOL NUMBER ........... DRS-C 2984 NSC-E 907 CNC-GA 125 SGC-SA 1804 AMS-AA 712 6.000 11134.0 11134.0 KCL POLYMER 10.60 81.0 9.0 212.0 O. 325 74.0 0.226 74.0 0.447 74.0 EPITHERMAL LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 16 MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 0.5 REMARKS: TOOLS DRILLPIPE CONVEYED - TLC SYSTEM NO BARITE CORRECTIONS MADE TO LOG TWO TOOL TURNERS USED TO ORIENT TOOLS DEVIATION AVERAGES 70 DEG OVER LOGGED INTERVAL LOGS RUN ON SANDSTONE MATRIX $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 104 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI~SS MOD ~ S~'~IP ELI~ CODE (H~¥) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 GR LDT GAPI O0 000 O0 0 4 1 1 4 68 0000000000 HTENLDT LB O0 000 O0 0 4 1 1 4 68 0000000000 TENS LDT LB O0 000 O0 0 4 1 1 4 68 0000000000 ~IRESLDT Ohl~l O0 000 O0 0 4 1 1 4 68 0000000000 MTEMLDT DEGF O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LDT G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DPHI LDT PU O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RHOB LDT G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDT BN/E O0 000 O0 0 4 1 1 4 68 0000000000 CALI LDT IN O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 TNR~ CNTG O0 000 O0 0 4 1 1 4 68 0000000000 RTNR CNTG O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNTG PU O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU O0 000 O0 0 4 1 1 4 68 0000000000 TNPH CNTG PU O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU O0 000 O0 0 4 1 1 4 68 0000000000 ENNA CNTG O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 RCENCNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 RCEF CNTG CPS O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13236.000 GR.LDT 48.062 HTEN. LDT -409.611 TENS.LDT ~4~ES.LDT 0.087 MTEM. LDT 210.441 DRHO.LDT -0.057 DPHI.LDT RHOB.LDT 2.306 PEF.LDT 6.605 CALI.LDT 5.632 CNTC. CNTG CFTC. CNTG 3336.556 RCNT. CNTG 5006.548 RCFT. CNTG 3152.585 TNRA.CNTG RTNR.CNTG 1.560 NPOR.CNTG 13.823 NPHI.CNTG 14.461 TNPH. CNTG ENPH. CNTG 16.081 ENRA.CNTG 2.916 CFEC. CNTG 1372.038 CNEC. CNTG RCEN. CNTG 3799.392 RCEF. CNTG 1356.484 DEPT. 13000.000 GR.LDT 95.442 HTEN. LDT 276.957 TENS.LDT ~ES.LDT 0.099 MTEM. LDT 209.810 DRHO.LDT 0.005 DPHI.LDT RHOB.LDT 2.624 PEF. LDT 3.654 CALI.LDT 6.542 CNTC. CNTG CFTC. CNTG 4082.586 RCNT. CNTG 6758.027 RCFT. CNTG 4180.320 TNRA.CNTG RTNR.CNTG 1.530 NPOR.CNTG 10.808 NPHI.CNTG 13.996 TNPH. CNTG ENPH. CNTG 11.937 ENRA.CNTG 2.406 CFEC. CNTG 2206.463 CNEC. CNTG RCEN. CNTG 4962.519 RCEF. CNTG 2196.042 DEPT. 12588. 000 GR.LDT 111 . 828 HTEN. LDT 830. 337 TENS.LDT M~ES.LDT 0.101 MTEM. LDT 199.377 DRHO.LDT 0.037 DPHI.LDT RHOB.LDT 2.207 PEF.LDT 6. 632 CALI.LDT 10.266 CNTC. CNTG CFTC. CNTG 482.428 RCNT. CNTG 1604.229 RCFT. CNTG 450.584 TNRA. CNTG RTNR. CNTG 3. 596 NPOR. CNTG 40. 892 NPHI. CNTG 42.126 TNPH. CNTG ENPH. CNTG 35.761 ENRA. CNTG 5.357 CFEC. CNTG 414.028 CNEC. CNTG RCEN. CNTG 2003.144 RCEF. CNTG 401.252 1204.000 23.636 4965.382 1.515 13.823 4000.380 1335.000 5.004 6023.810 1.539 13.264 5308.671 954.000 29.427 1663.258 3.556 40.714 2306.162 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/02/ 5 MA_XREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIJMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~k4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11133.0 11053.0 CNTG LOG H~ER DATA DATE LOGGED: 29-0CT-96 SOFTWARE VERSION: 8B0538 TIME CIRCULATION ENDED: 830 28-0CT-96 TIME LOGGER ON BOTTOM: 728 29-0CT-96 TD DRILLER (FT) : 13243.0 TD LOGGER (FT) : 13243.0 TOP LOG INTERVAL (FT): 11053.0 BOTTOM LOG INTERVAL (FT) : 13243.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LDTD LITHODENSITY SONDE DRS-C 2984 LDTD LITHODENSITY CART. NSC-E 907 CNTG EPITHERMAL NEUTRON CNC-GA 125 GR GAMMA RAY SGC-SA 1804 AMS AUX. MEAS.SONDE AMS-AA 712 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 19 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 5 6.000 11134.0 11134.0 KCL POLYMER 10.60 81.0 9.0 212.0 0.325 74.0 0.226 74.0 0.447 74.0 EPITHERMAL SANDSTONE 2.65 REMARKS: TOOLS DRILLPIPE CONVEYED - TLC SYSTEM NO BARITE CORRECTIONS MADE TO LOG TWO TOOL TURNERS USED TO ORIENT TOOLS DEVIATION AVERAGES 70 DEG OVER LOGGED INTERVAL LOGS RUN ON SANDSTONE MATRIX $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 20 TYPE REPR CODE VALUE 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 GR LDT CAPI O0 000 O0 0 5 1 1 4 68 0000000000 HTENLDT LB O0 000 O0 0 5 1 1 4 68 0000000000 TENS LDT LB O0 000 O0 0 5 1 1 4 68 0000000000 ~!RES LDT OH~ O0 000 O0 0 5 1 1 4 68 0000000000 MTE~LDT DEGF O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCNT CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCFT CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 TNRA CNTG O0 000 O0 0 5 1 1 4 68 0000000000 RTNR CNTG O0 000 O0 0 5 1 1 4 68 0000000000 NPOR CNTG PU O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNTG PU O0 000 O0 0 5 1 1 4 68 0000000000 TNPH CNTG PU O0 000 O0 0 5 1 I 4 68 0000000000 ENPH CNTG PU O0 000 O0 0 5 1 1 4 68 0000000000 ENRA CNTG O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCEN CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCEF CNTG CPS O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11134.000 GR.LDT 86.685 HTEN. LDT 841.728 TENS.LDT M~ES.LDT 0.096 MTE~.LDT 183.224 CNTC. CNTG 1690.469 CFTC. CNTG RCNT. CNTG 1616.539 RCFT. CNTG 458.216 TNRA.CNTG 3.536 RTNR.CNTG NPOR.CNTG 43.945 NPHI.CNTG 45.814 TNPH. CNTG 41.394 ENPH. CNTG Elv-RA.CNTG 5.623 CFEC. CNTG 485.552 CNEC. CNTG 2730.304 RCEN. CNTG RCEF. CNTG 448.433 DEPT. 11053.000 GR.LDT 72.938 HTEN. LDT 837.492 TENS.LDT f4~ES.LDT 0.099 MTEM. LDT 182.145 CNTC. CNTG 1556.919 CFTC. CNTG RCNT. CNTG 1556.056 RCFT. CNTG 362.186 TNRA.CNTG 3.744 RTNR.CNTG NPOR.CNTG 46.632 NPHI.CNTG 50.541 TNPH. CNTG 46.180 ENPH. CNTG 459.000 505.422 3.590 41.154 2468.135 2219.000 431.734 3.444 42.034 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-FEB-1997 13:25 PAGE: 21 ENRA . CNTG 5.665 RCEF. CNTG 483,141 CFEC. CNTG 496.921 CNEC. CNTG 2814.909 RCEN. CNTG 2639.741 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ $ MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/02/ 5 ORIGIN . FLIC TAPE NAME : 96344 CONTINUATION # : 1 PREVIOUS TAPE : COPk4ENT : ARCO ALASKA INC, Pl-09, POINT MCINTYRE, API #50-029-22704-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/02/ 5 ORIGIN : FLIC REEL NAME : 96344 CONTINUATION # : PREVIOUS REEL : CO~94ENT : ARCO ALASKA INC, Pl-09, POINT MCINTYRE, API #50-029-22704-00
