Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
176-024
• 1(~ lZ~~ PBU_03-02_o,~mitigated_2008-0710.txt ~~ ~ ~~ ~ Z OPERABLE: 03-02 (PTD #1760240) OA pressure stabilizationFrom: NSU, ADW Well Integrity Engineer [NSUADWWe1lIntegrityEngineer@BP.com] Sent: Thursday, July 10, 2008 8:21 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, wells Opt Eng; GPB, optimization Engr Cc: Wellman, Taylor T; Colbert, Chris M; Holt, Ryan P (ASRC) ~ ~~~,lp~ Subject: OPERABLE: 03-02 (PTD #1760240) oA pressure stabilization ~1`~j°~ _ Follow Up Flag: Follow up Flag Status: Yellow All, well 03-02 (PTD #1760240) has been reclassified as operable. A continuous oA bleed was conducted from 6/27 to 7/2. Since then, the wellhead pressure have been monitored and the oA pressure has stabilized at 120 psi. The source of the oA repressurization is stiTT unclear and t ere ore a team of experts is being assembled to study this and similar wells. For now the well may be produced as is. Please let me know if you have any questions. Thank you, Anna Dube, P.E. well Integrity Coordinator GPB wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~a 1~~~~ ~~tn ~ ~ ~~~~ From: NsU, ADw well Integrity Engineer Sent: Tuesday, June 17, 2008 8:00 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (F51/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: wellman, Taylor T; Nsu, ADw well Integrity Engineer; Colbert, Chris M Subject: UNDER EVALUATION: 03-02 (PTD #1760240) Sustained OA Casing Pressure All, well 03-02 (PTD #1760240) has been confirmed to again have sustained casing pressure above 1000 psi. The wellhead pressures were tubing/IA/oA equal to 1600/1590/1350 on 06/14/08. The well has been reclassified as under Evaluation to evaluate the well for an internal dispensation and AoGCC Administrative Approval to operate the well at a higher oA pressure limit. A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna Dube, P.E. well Integrity Coordinator GPB wells Group Phone: (907) 659-5102 Page 1 • • PBU_03-02_oA_mitigated_2008-0710.txt Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, May 04, 2008 2:57 PM To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well operations supervisor; GPB, wells opt Eng Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer subject: 03-02 Reclassified as operable All, The oA pressure of 03-02 has remained stabile at 800 psi since 4/20/08. There is no reason to believe that the oA pressure cannot be maintained under MAASP indefinitely in the well's current condition. The well has been reclassified as operable. Please notify well Integrity if the oA pressure builds. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 23, 2008 9:37 AM To: GPB, Area Mgr East (F51/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW well operations supervisor; GPB, wells opt Eng Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: 03-02 and 03-08 Reclassified as Under Evaluation All, wells 03-02 and 03-08 have been reclassified as under Evaluation to diagnose the source of the building oA pressure. Gas sampling of the oA and IA gas verified that the wells do not have IAxoA communication. An attempt to quantify the gas inflow into the OA with a gas meter was unsuccessful, as the rate was too small. The plan forward for these wells is as follows: 1. WIE: Monitor oAP until stabile with well online (this is most likely a pressure above MAASP. Please DO NOT bleed the OAP.) 2. DHD: Once the maximum obtainable pressure has been established, maintain an open bleed on the oA in an attempt to deplete the gas source. 3. WIC: Eval for dispensation for continued operation with oAP above currently set MAASP. operations: Please do not bleed the oA pressure of these wells until all of the diagnostics are complete. I will follow up with an additional email once this is the case. Please do not hesitate to call with any questions or concerns. Thank you, Page 2 • • PBU_03-02_o~mitigated_2008-0710.txt Andrea Hughes well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Page 3 PBU 03-02 PTD 176-024 ~- I U -- U~j d;001.I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• ^~~~^ ^^ ^~~~^ 3,OOi; 2:000 1,000 '',, ~~ ~ I + ~ ,._,. ~ .,,., ~ .......,.7,,. .. ,, ~,.. I'lA:.'1 %IC1 1~1~1,~1 ~I, hIS~i ~I b: i-;'(I, fl~r/l,l,~i fl"; 11~~, 111%i li~' II~~~I 1(iS> (I~~: j.~jrl!! 11'0'~~'11i~1 (!f (I jo'1~1;~s i{I-,/j .Q /1~4J (I~;iiGl rrl`r? 1~11ifr i~/UI:~ Ii, ~l~ir'f1Y • UNDER EVALUATION: 03-02 (PTD #1760240) Sustained OA Casing Pressure Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, June 17, 2008 8:00 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2lCOTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Wellman, Taylor T; NSU, ADW Well Integrity Engineer; Colbert, Chris M Subject: UNDER EVALUATION: 03-02 (PTD #1760240) Sustained OA Casing Pressure Attachments: 03-02 TIO PIot.BMP; 03-02.pdf All, Well 03-02 (PTD #1760240) has been confirmed to again have sustained casing pressure above 1000 psi. The wellhead pressures were tubing/IA/OA equal to 1600!1590/1350 on 06/14/08. The well has been reclassified as Under Evaluation to evaluate the well for an internal dispensation and AOGCC Administrative Approval to operate the well at a higher OA pressure limit. A TIO plot and welfbore schematic have been included for reference. «03-02 TIO PIot.BMP» «03-02.pdf» Please call with any questions. Thank you, Anna ~Du6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, May 04, 2008 2:57 PM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: 03-02 Reclassified as Operable AI I, The OA pressure of 03-02 has remained stabile at 800 psi since 4120108. There is no reason to believe that the OA pressure cannot be maintained under MAASP indefinitely in the well's current condition. The well has been reclassified as Operable. Please notify Well Integrity if the OA pressure builds. Please call with any questions or concerns. Thank you, 8/29/2008 UNDER EVALUATION: 03-02 (PTD #1760240) Sustained OA Casing Pressure Page 2 of 2 Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 23, 2008 9:37 AM To: GPB, Area Mgr East (FSS/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: 03-02 and 03-08 Reclassified as Under Evaluation AI I, Wells 03-02 and 03-08 have been reclassified as Under Evaluation to diagnose the source of the building OA pressure. Gas sampling of the OA and IA gas verified that the wells do not have IAxOA communication. An attempt to quantify the gas inflow into the OA with a gas meter was unsuccessful, as the rate was too small. The plan forward for these wells is as follows: 1. WIE: Monitor OAP until stabile with well online (this is most likely a pressure above MAASP. Please DO NOT bleed the OAP.) 2. DHD: Once the maximum obtainable pressure has been established, maintain an open bleed on the OA in an attempt to deplete the gas source. 3. WIC: Eval for dispensation for continued operation with OAP above currently set MAASP. Operations: Please do not bleed the OA pressure of these wells until all of the diagnostics are complete. I will follow up with an additional email once this is the case. Please do not hesitate to call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/29/2008 PBU 03-02 PTD 176-024 4 3,000 2,000 1,000 0 3M 7!2008 6 -- i 7 -psi .....................................~D3~2'TT~~'1t!'1....... .... -~- Tbg f- IR -~1r OA OOA ~ OOOA 4M 12008 4M 6x2008 5l2r1008 SM 7!2008 6M /2008 6M 702008 7f2C2008 i • TREE = 7-1116" MCEV OY WELLHEAD= FMC ACTUATOR= ~ ~ ~AXLESON KB. ELEV = 61; BF. ELEV.- KOP = _ 3504' Max Angle = ~ ~ 56 @ 6403' ~~ DatumMD= 11113' DatumTVD= 8800'SS 9-518" CSG, 47#, L-80, BTC, ID = 8.681" 13-318" CSG, 72#, MN-80, ID = 12.347" • 1997' 2696' ~ Minimum ID = 4.50" @'10476' 5-112" HES X NIPPLE {MILLED) 5-1(2" TBG, 17#, 13CR-80, VAM TOP, .0232 bpf, ID = 4.892" 5-1/2" TBG, 17#, 13CR-80, .0232 bpf, ID = 4.892" J i 10403' I PERFORATION SUMMARY REF LOG: BHCS ON 05/01/76 ANGLE AT TOP PERF: 37 @ 10975' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnJSgz DATE 3-318" 4 10975 - 10994 S 08!28!89 3-3/8" 6 10992 - 11010 S 08/28!89 2-1/2" 4 11020 - 11044 O 05125191 3-318" 4 11055 - 11089 S 08128/89 3-3/8" 6 11100 - 11120 S 08/28/89 3-318" 6 11120 - 11140 S 08128189 3-318"' 6 11120 - 11140 S 08!28!89 ? 4 11156 - 11175 S 06105(85 3-118" 1!4 11179 - 11195 S 08128189 ? 4 11210 - 11245 S 06105185 3-318" 6 11220 - 11240 S 08/28/89 3-118°' 1i4 11220- 11245 S 08/28(89 ? 4 11260 - 11310 S 06105/85 PBTD -~ 1 9-5,18" CSG. 47#, MN-80, ID = 8.681 °' -{ 11 03-02 S~ NOTES; ***5-112" CHROM E TBG"** 2125' -i 5-1/2" HES X NIP, ID = 4.562 1987' 9-518" HES ES GEMENTER GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 5 3554 3551 11 MMG DOME RK 16 04!08!07 4 6133 5601 54 MMG SO RK 20 04/08/07 3 7777 6606 49 MMG DMY RK 0 03104/07 2 9028 7405 50 MMG DMY RK 0 03/04/07 1 10223 8187 46 MMG DMY RK 0 04108!07 10294' -~5-1f2" HES X NIP, ID = 4.562 10315' 9-518" X 5-112" BKR CR S-3 PKR, ID = 4.750" 10340' 5-112" HES X NIP, ID = 4.562 10405' 5-112" TBG STUB 10411' 9-5/8" X 5-1;2" UNDUE OVERSHOT 10426' 9-518" X 5-112" TIW HBBP PKR WIPOSfiNE LATGH, ID = 4.75" 10461' 5-112" PRKR SWS NIP, ID = 4.562" 10476' 5-112" HES XN NIP {MILLED 03/03!07), ID = 4.50" 10488' 5-112" TT w! MULESHOE, ID = 4.55" 10478' ELMD TT -LOGGED { 10/13!95} 11730' ~~ FISH -RUBBER FROM IBP {02!22194} 11735' FISH-HES ED 15R-E3 PRONG (06!24!94} 11740' FISH - RTTS FKR ELEMENTS (06124!94} 11745' FISH -TWO 112 X 2' BOW SPRINGS {0$/26!90) DATE REV BY COMMENTS DATE REV BY COMMENTS 05108/76 ORIGINAL COMPLETION 06/24/94 LAST WORKOVER 03/07107 N4ES RWO 04108107 CJN(PAG GLV Cl0 04111107 DCRrPJC DRLGDRAFTCORRECTIONS PRUDHOE BAY UNIT WELL: 03-02 PERMCf No: 1760240 API No: 50-029-20203-00 SEC 11 T10N 815E 4839.62 FEL 3907.84 FNL BP Exploration (Alaska) 1. Operations Performed: MrJcnorage o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 176-024 ~ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20203-00-00 - 7. KB Elevation (ft): 61' ( 9. Well Name and Number: PBU 03-02 - 8. Property Designation: ADL 028328( 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11750 ( feet true vertical 9382 - feet Plugs (measured) None Effective depth: measured 11635 feet Junk (measured) 10898 true vertical 9286 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 72' 72' 1530 520 Surface 2696' 13-3/8" 2696' 2696' 5380 2670 Intermediate Production 11722' 9-518" 11722' 9359' 6870 4760 Liner ~iCANNED APR 0 9 2007 Perforation Depth MD (ft): 11020' - 11044' Perforation Depth TVD (ft): 8787' - 8806' 5-1/2", 17# 13Cr80 10488 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker 'S-3' packer 10315' 9-5/8" X 5-1/2" TIW HBBP w/ Positive latch 10426' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 10400'. Cut and pull 9-518" casing from 1997'. Run 9-5/8" (47#, L-80, TC-II) tieback to surface. Cement w/ 138 bbls Class 'G' w/ Gas-Blok (775 cu ft /668 sx). Clean out and run new Chrome tubinQ. 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 307-010 Printed Name Terrie Hubble Title Technical Assistant . '~rV..o cl '-Un O':>! 0 ~ Prepared By Name/Number: Signature IV 1 rr:\.J .~ I i"'. I : ¡ Phone 564-4628 Date 3 Oì Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 U t\ IlJ I i\Ll\ L RBDMS BFlAPR (I 3 2007 Submit Original Only RECEIVED MAR 3 0 2007 REPORT OF SUNDRY WELL OPERATIONS Alask 0" &. " a, Gas Cons. Commission ~ . STATE OF ALASKA ..,t.";¡-1'I7 ALA OIL AND GAS CONSERVATION COM ION tt::\"\\ ::> Di~ital Wellfile . Well Events for SurfaceWell - 03-02 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 03 -> 03-02 Date Range: 17/Dec/2006 to 18/Feb/2007 Data Source(s): AWGRS Events Source Well AWGRS 03-02 AWGRS 03-02 AWGRS 03-02 AWGRS 03-02 Date 02/18/2007 02/12/2007 02/12/2007 02/11/2007 AWGRS 03-02 02/10/2007 8wGR5 03-02 02/09/2007 AWGRS 03-02 02/09/2007 AWGRS 03-02 AWGRS 03-02 AWGRS 03-02 AwGRS 03-02 02/08/2007 02/08/2007 01/30/2007 12/17/2006 . Page 1 of 1 Description PULL BPV POST RIG MOVING ON WELL API VALVE SHOP SET BPV PRE RIG WORK API VALVE SHOP (Continued from 02-11-07 WSR) MIT OA to 2000 psi, PASSED (Rig prep) - Freeze protect flowline, RD tubing, RU OA, Pressure OA to 2000 psi w/ 3.5 bbls crude, Start testing, PASSED, 1st test lost 50 psi in 15 min, Lost 20 psi in 2nd 15 min, lAP increased 10 psi in 15 min & 0 psi in 2nd 15 min, PASS, Bleed WHP's Final WHP's=O/Vac/O T/I/0=450/0/620 Circ Out / CMIT TxlA to 2000 psi, PASSED / MIT OA to 2000 psi, INCOMPLETE (Rig prep) - Pump 30 bbls crude down flowline to verify flow path for returns, Pump 5 bbls meth, 1043 bbls 2% KCI water & 160 bbls 70* diesel down tubing taking returns up IA through jumper to flowline, U-tube TxlA to put FP in place CMIT TxlA to 2000 psi - Pressure TxlA to 2000 w/ 5 bbls diesel, Start testing, Passed 1st test (45 min test) T/I lost 40/40 psi in 15 min, Lost 30/30 psi in 2nd 15 min, Lost 20/30 psi in 3rd 15 min, PASS, Bleed TxlAP (Continued on 02-12-07 WSR) Fluid support for circ out ****CONTINUED FROM 8-FEB-2007**** 4-7/16" CHEMICAL CUT 5-1/2" TUBING AT 10,396 FT, DEVIATION AT CUT 44 DEGREES, T/I/O 200/0/650 ***JOB COMPLETE*** T/I/O= SHUTIN/0/600 BALANCE= 1100 CONTROL= 1500 FMC WELLHEAD GEN I RETRO GEN IV, 7" MCEVOY TREE INITIAL BLEED PORT PRESSURE= 200 PSI, BLED TO ZERO ALL BUT ONE LDS FUNCTIONED, ONE WOULD NOT BREAK FREE ATTEMPTED TO TURN WITH BAR EXTENTION, MARKED WITH WHITE MARKER. THE REST OF LDS'S WERE RETORQUED TO 500 FT/LBS, ( LDS'S WERE PRETTY LOOSE) TESTED VOID TO 5000 PSI; 1ST 15 MIN. LOST 500PSI RE-PRESSURED TO 5000 PSI 1ST 15 MIN. LOST 250 PSI (5%) 2ND 15 MIN. LOST 0 PSI (PASS) P/O INITIAL PRESSURE 100 PSI, BLED TO ZERO FUNCTIONED ALL LDS'S RE- TORQUED TO 500 FT/LBS TEST TO 3000 PSI; LOST 350 PSI RE-PRESSUED TO 3000 PSI 1ST 15 MIN. LOST 150 PSI 2ND 15 MIN. LOST 50 PSI (PASS) T/I/0=400/0/640 Assist E-Line (PRE-RWO) Test Cast Iron Bridge Plug, MIT tubing to 3000 psi. PASSED Pumped 23,5 bbls crude, Loss 200 psi 1st 15 min, Loss 50 psi 2nd 15 min, Bled back to normal. 8 bbls crude bled back, FWHP's=400/0/640 BAKER COMPOSITE BRIDGE PLUG SET IN 5-1/2" TUBING AT 10,451 FT. SMALL CHARGED TUBING PUNCH INTERVAL 10,373-10,375 FT. 2X12' STRING SHOT OVER 10,386-10,298 FT. RIH FOR 4-7/16" CHEMICAL CUT OF 5-1/2" TUBING AT 10,396 FT, DEVIATION AT CUT 44 DEGREES. ***CONTINUED 9-FEB-2007*** *** WELL SI ON ARRIVAL *** (pre composite plug / chem cutter) RIH W/ 4.5 CENT. W/ JOC, PULL PRONG @ 10464' SLM. PULLED 5 1/2 PXN PLUG BODY @ 10469' SLM ***WELL LEFT 5/1*** T//O= SSV/50/720. Temp= 51. AL line is disconnected. OA FL (OA FL Campaign). OA FL is at surface, http://digitalwellfile.bpweb.bp,com/W ellEvents/Home/Default.aspx 3/3012007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/18/2007 08:00 - 11 :30 3.50 RIGD P POST Lower derrick. Rig down sub base, pits and pipe shed. AOGCC - Gave 24-hr. notice of impending BOPE test. 11 :30 - 13:00 1.50 MOB P PRE Move rig down pad to well 03-02. 13:00 - 17:00 4.00 MOB P PRE Spot sub, pits and pipe shed. Raise and scope derrick. 02:45-hrs.: AOGCC - Lou Grimaldi waived witness BOPE test. Taking seawater into rig pits. Accept rig at 17:00-hrs. 17:00 - 20:00 3.00 RIGU P DECOMP Rig up lines to Tiger tank. Rig up floor. Take on 120 degree seawater. 20:00 - 21 :00 1.00 WHSUR P DECOMP P/U lubricator & pull BPV. UD same. 21 :00 - 21 :30 0.50 KILL P DECOMP Hold PJSM & pre-spud mtg wI all hands. Pressure test lines to 3500 psi, Ok. 21 :30 - 23:00 1.50 KILL P DECOMP Open well. SITP = 0 psi, SICP = 0 psi. Begin circulating well. Pumped 4 BPM, 1250 psi. After 3500 stks, pressure increased to 1580 psi. Tbg pressure became erratic. At 4500 stks. Slowed pumped to 3 BPM & pressure dropped to 1480 psi. Con't to pump to 6500 stks, pressure 1560 psi. SID & check tiger tank returns. Recovered 380 bbls. Wells group[ experienced same erratic pressure when they circulated well. 23:00 - 00:00 1.00 KILL P DECOMP SID. tiger tank valves frozen. RlU line into tank & vac out 200 bbls. Attempting to save diesel. 2/19/2007 00:00 - 02:00 2.00 KILL P DECOMP Con't to circulate well. Pump 3 BPM pressure gradually increased to 1800 psi. Slowed pump to 2.5 BPM, 1590 psi. Pressured up to 1700 psi @ 11500 stks & then dropped off to 1460 psi @ 11879 stks. Had diesel returns @ 9300 stks & got 100% clean hot water returns @ 11500 stks.. SID & monitor well. Well dead. Pumped total of 700 bbls. 02:00 - 02:30 0.50 KILL P DECOMP RlU chart & pressure Composite tubing plug to 1000 psi. Held test for 24 min. Pressure dropped 50 psi in 8 min, then dropped 25 psi in the next 16 min. OAP = 300 psi. Test Ok. 02:30 - 03:00 0.50 KILL P DECOMP Open & monitor well. Well dead. RID test equip. Blow down lines. 03:00 - 03:30 0.50 WHSUR P DECOMP P/U tee-bar & install TWC in tubing hanger. 03:30 - 04:30 1.00 WHSUR P DECOMP RlU test equip. Attempt to pressure test TWC to 3500 psi from top. Pressure bled off 600 psi in 4 min. Master valve stem leaking. Grease same & retest. Still leaking but slower 300 psi in 3 min. Pressure test from bottom side to 1000 psi, Held Ok. 04:30 - 05:00 0.50 WHSUR P DECOMP Call for 2nd TWC & lubricator. 05:00 - 07:30 2.50 WHSUR P DECOMP P/U lubricator & pull TWC. Install new TWC in tbg hanger & UD lubricator. Grease manual master valve. Test TWC to 1000-psi from below. Good test. Test to 3500-psi. Pressure bled off 200-psi in 15 minutes. Considered this a good test. UD lubricator. 07:30 - 10:30 3.00 WHSUR P DECOMP Vac out and N/D Tree. Fit test 9" L.H Acme XO. Good fit. 7-1/2 turns to makeup. Function lockdown screws. Left one lockdown screw backed out due to galled threads. 10:30 - 13:30 3.00 BOPSU P DECOMP N/U BOPE. 13:30 - 18:00 4.50 BOPSU P DECOMP PUMU 3-1/2" and 5-1/2" test joints. Fill stack wlwater and function rams and annular to remove air. Prepare to test BOPE. Pressure up stack to begin testing and lockdonw screw packing leaking. Tightened LDS and still leaking. Drained Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 stack and FMC will changeout lockdown screw assembly. Crew change. Check PVT alarms & inspect derrick. PIT BOPE per AOGCC/BP requirements. Test BOPE to 250-psi LP x 3500-psi HP. Test annular preventer to 250-psi x 3500-psi HP. Did not test kelly, -51 below WC. Will test kelly when we pick it up. Lou Grimaldi wI AOGCC waived witnessing BOP test. Tested wI 3 1/2" & 5 1/2" test its. No failures. RID test equip. 23:30 - 00:00 0.50 WHSUR P DECOMP P/U lubricator to pull TWC. 2/20/2007 00:00 - 00:30 0.50 WHSUR P DECOMP Pull TWC & UD lubricator. 00:30 - 02:00 1.50 PULL P DECOMP RlU 7 " casing tools & equip. MIU landing it & X-overs. 02:00 - 02:30 0.50 PULL P DECOMP M/U landing it into tubing hanger wI 7 LH turns. BOLDS. P/U & pull tubing hanger to floor. Hanger started to move wI 160K. Work string up to 235K & completion came free. Pulled to floor wI 25-30K drag. 02:30 - 03:30 1.00 PULL P DECOMP Cut control lines. Break out hanger, landing it & X-overs. UD same. 03:30 - 05:30 2.00 PULL P DECOMP M/U circulating head & circulate bottoms up. Had some diesel in annuilus. Circulating @ 5.75 BPM @ 230 psi. Pumped 445 bbls. Blow down lines. RID circulating head. 05:30 - 09:30 4.00 PULL P DECOMP POOH & UD 7" x 51/2" completion 1x1 through pipe shed. Maintaining constant hole fill. Pipe is dragging 10-20K over string weight. At 43 jts. OOH pipe dragging 20-25K over string weight. Worked pipe free and resume POH. UD SSSV at 54 its. OOH at 09:30-hrs. Control line wadded up on top of SSSV. Recovered 44 control line bands. Assuming one band per joint, there are 10 bands left in hole. 09:30 - 10:00 0.50 PULL P DECOMP RDMO SLB control line spooler. 10:00 - 10:30 0.50 PULL P DECOMP Resume POH UD 7" Tubing. Laid down a total of 64 its. 7" Tubing. Tubing condition looks good. No noticeable corrosion or holes in pipe. XO from 7" to 5-1/2" laid down and good condition as well. 10:30 - 18:00 7.50 PULL P DECOMP POH UD 5-1/2" production Tubing. 18:00 - 18:30 0.50 PULL P DECOMP Crew change. Check PVTs & inspect derrick. 18:30 - 19:00 0.50 PULL P DECOMP Finisk POOH & UD completion. Total recovery is as follws: 64 jts, 7" 26#,13 Cr-80 NSCC tubing, 1-7" Camco SSSV Assy, 194 its, 5 1/2", 17#, 13 Cr-80 NSCC tubing, 1 - 19.29' cut off it of 51/2" tubing, 9 - 51/2" GLM Assys, 1 - 5 1/2" "X" Nipple Assy. Also recovered 46 SS bands, possibility of addtional 10? bands left in hole. 19:00 - 20:00 1.00 PULL P DECOMP RID tubing handling tools. RlU tools for 3 1/2" DP. 20:00 - 21 :00 1.00 PULL P DECOMP Clear & clean rig floor. 21 :00 - 22:30 1.50 CLEAN P DECOMP Load, Tally & M/U BHA #1 as follows to dress off tbg stub. WP Shoe, WP Ext, WIO Boot Basket, XO, Scraper, 2 . Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9' 6 1/4" DCs, XO. TL = 323.74'. RIH wI same. 22:30 - 00:00 1 .50 CLEAN P DECOMP P/U 1x1 & RIH wI BHA #1 on 31/2" DP. 40 its in hole. 2/21/2007 00:00 - 06:00 6.00 CLEAN P DECOMP Con't to P/U 3 1/2" DP, 1x1 & RIH wI BHA #1. Ran in hole wI 300 its. 06:00 - 06:30 0.50 CLEAN P DECOMP Crew change. Check PVT alarms & inspect derrick. 06:30 - 07:00 0.50 CLEAN P DECOMP Tag 5 1/2' in on Jt # 318 @ 10400' DPM. 165K up wt, 118K down. Pick up kelly, 128K rotating wt. 07:00 - 08:00 1.00 CLEAN P DECOMP PJSM. Rotate down on over stub, seeing a bit of resistance, Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/21/2007 07:00 - 08:00 1.00 CLEAN P DECOMP proabably the conrtolline bands that were left in the hole. 2nd & 3rd time down over stub, no resistance, able to swallow 10' & get over stub from 10400-10410' wlo rotating, OK. 08:00 - 10:30 2.50 CLEAN P DECOMP PJSM. Pump Hi vis sweep around @ 5 1/2 bpm, 1400 psi, 735 bbls total pumped, no losses. 10:30 - 15:00 4.50 CLEAN P DECOMP PJSM. Stand back kelly & POOH. 15:00 - 16:00 1.00 CLEAN P DECOMP PJSM. UD BHA, recovered approximately 2 gallons of scale & (1) piece of control line. 16:00 - 18:00 2.00 EVAL P DECOMP PJSM. N/D flow nipple, nipple up shooting flange, spot & rig up Schlumberger Eline. 18:00 - 18:30 0.50 EVAL P DECOMP Crew change. Check PVT alarms. Inspect derrick. 18:30 - 20:00 1.50 EVAL P DECOMP Finish RIU SWS equip & pack off. Pressure test to 500 psi, Ok. 20:00 - 00:00 4.00 EVAL P DECOMP RIH & log wI US IT tool from 10,360'. 2/22/2007 00:00 - 05:00 5.00 EVAL P DECOMP Con't to run USIT log from 10,360' to surface. 05:00 - 06:00 1.00 EVAL P DECOMP UD USIT tools. Load & RIH wI string shot. Plan to shoot 1974-1986' w/3 strand charge. 06:00 - 08:00 2.00 EVAL P DECOMP PJSM. RIH wI 3 strands x 12' of string shot, position same across collar @ 1981' ELM. Fire string shot, OK. POOH wI E line. 08:00 - 10:00 2.00 EVAL P DECOMP PJSM. Rig down E line, nipple down shooting flange, nipple up flow nipple. 10:00 - 12:30 2.50 DHB P DECOMP PJSM. Pick up Halliburton 9 5/8" Retrievable bridge plug, RIH & set @ 2763' DPM. Center of element @ 2759', top of fishneck @ 2752' DPM. 12:30 - 13:00 0.50 DHB P DECOMP PJSM. Pressure test RBP @ 1000 psi 110 minutes, charted, OK. 13:00 - 15:30 2.50 DHB P DECOMP PJSM. Dump 2200# of 20/40 river sand on top of bridge plug. 15:30 - 17:00 1.50 FISH P DECOMP PJSM. Rig up Little Red Hot Oil, take on 9.8 ppg brine & heat same to 120 degrees. 17:00 - 18:00 1.00 FISH P DECOMP Displace well to 9.8 ppg brine heated to 120 degrees. Pumped 4 BPM @ 300 psi. Pumped total displacement of 203 bbls. 18:00 - 18:30 0.50 FISH P DECOMP RIH & tag top of sand @ 2705'. 18:30 - 19:30 1.00 FISH P DECOMP POOH & stand back 3 1/2" DP. 19:30 - 20:00 0.50 FISH P DECOMP UD RBP running tool. Load, Tally & MIU BHA #2 to cut 9 5/8" casing as follows: Multistring Cutter, XO, Stabilizer, XO. TL = 9.64'. 20:00 - 21 :00 1.00 FISH P DECOMP RIH wI BHA #2 on 20 stands of 31/2" DP. 21 :00 - 22:30 1.50 FISH P DECOMP Cut & slip 84' of drilling line. 22:30 - 00:00 1.50 FISH P DECOMP M/U Circulating head & locate casing collars. Collars running 15' deep DPM vs loggers depth. Located collars @ 1916, 1955 & 1997'. Space out cutter as follows: 61 jts DP + 9.96' DP Pup + 26' kelly + 9.64' BHA = 1977'. 2/23/2007 00:00 - 03:00 3.00 FISH P DECOMP Hold PJSM Check Check Bleed off on annulus. Check circulation out to tank. Line from Choke manifold out to tank frozen. Thaw out lines. 03:00 - 04:00 1.00 FISH P DECOMP Bleed off OA from 170 psi to 0 psi. OA valve was problematic. Could not fully open valve could only get 6 turns. Work valve & check wI valve shop. Finally valve opened full 18 turns. Cycle openlclose & insure valve holding. 04:00 - 05:00 1.00 FISH P DECOMP Space out kelly & cut casing @ 1977' DPM depth. P/U, SIO = 40K. Rot 42K. 40 RPMs, 4.1 BPM @ 740 psi. Free torq = 60 Amps. Cut wI 90 amps ( 1800 ft-Ibs ) Rotated 30 min String bounced & torq to max. SID. P/U & verify cut. P/U & close in Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/23/2007 04:00 - 05:00 1.00 FISH P DECOMP bag. Attempt to circ. Pressure up to 500 psi. no retums. RIH to cut & con't to rotate, 4 min as before & string torqed to max. P/U & tool stuck. Work string up to 75K & tools came loose. Pull up 8' & attempt to break circ. Pressure up to 650 psi. broke to 500 psi. No returns. SID pump & pressure dropped to 220 psi. Observe annulus & pressure increase very slowly to 30 psi from 10 psi. Open wlo continuous returns, OAP bled to 0 psi. 05:00 - 06:30 1.50 FISH P DECOMP Bleed off DP & open bag. set back & blow down kelly. UD DP pup & M/U circulating head. Circulate down DP & up DP/9 518" annulus. Attempting to thaw & lower viscosity of Arctic Pack. Pump 4.6 BPM @ 1000 psi. 06:30 - 08:00 1.50 FISH P DECOMP PJSM. Discuss options. Opt to pump 100 bbls of 140 degree diesel down 13 3/8" x 9 5/8" annulus. Little Red encountering frozen air system. Opt to close bag & pump heated 9.8 ppg brine down drill pipe & up 9 518" x 13 3/8" annulus. Pump @ 3 bpm, initial circulating pressure 800 psi, taking returns thru choke to open top tank, observing back pressure due to thickness of arctic pack of 150 - 200 psi initially. Pumped 120 bbls with final circulating pressure of 650 psi, seeing approximately 70 psi on return line. Recovered 140 bbls to open top tank. 08:00 - 09:30 1.50 FISH P DECOMP PJSM. Little Red up and running. Test lines to 3500 psi, OK. Line up and pump 140 degree diesel down 9 5/8" x 13 3/8" annulus @ 2 bpm 1650 psi, taking 9.8 ppg brine returns to pits, 100 bbls diesel total pumped. Let 'er soak for an hour or so. 09:30 - 12:00 2.50 FISH P DECOMP PJSM. Line up & pump 9.8 ppg brine down DP & up 9 5/8" x 13 3/8" annulus, taking diesel I arctic pack thru choke to tiger tank. Shut down mid stream and perform a quick pressure test on 9 5/8" x 13 3/8" annulus @ 1100 psi, rock solid, bleed off & continue displacing diesel I arctic pack out @ 4 bpm I 850 psi. 120 bbls pumped. 12:00 - 14:00 2.00 FISH P DECOMP PJSM. Line up & pump down 95/8" x 13 3/8" annulus wI 120 bbls 150 degree diesel @ 2 bpm I 800 psi, taking dirty returns to pit 1. 14:00 - 15:00 1.00 FISH P DECOMP PJSM. Allow diesel to soak, rig down Little Red Hot Oil Services. Empty open top tank. 15:00 - 16:00 1.00 FISH P DECOMP PJSM. Circulate diesel out of 9 5/8" x 13 318" annulus @ 5 bpm 11200 psi. Bleed pressure & open bag & circulate well bore to clean 9.8 ppg brine. 16:00 - 17:00 1.00 FISH P DECOMP Pump 5 BPM @ 900 psi & flush DP I 9 5/8" annulus. 17:00 - 18:00 1.00 FISH P DECOMP Monitor well. Start POOH & stand back 31/2" DP. 18:00 - 19:30 1.50 FISH P DECOMP Con't to POOH & stand back 20 stands of 31/2" DP. 19:30 - 20:00 0.50 FISH P DECOMP Break out & UD cutting assy. Clear & clean rig floor. 20:00 - 21 :00 1.00 FISH P DECOMP P/U running tool. M/U tool into Pack-off. Put 1 full LH turn in tool & release Pack-off. UD running tool. 21 :00 - 21 :30 0.50 FISH P DECOMP Crew change. Check PVT alarms. Inspect derrick. 21 :30 - 22:00 0.50 FISH P DECOMP P/U 95/8" spear as follows: Bull Nose, Pack Off, Spear, Spear Ext., Stop Sub, XO. TL = 14.58'. Engage spear into 9 5/8" casing. BOLDS. P/U wI 119K & pull hanger to floor. Pulling wI 102K. UD Spear Assy. 22:00 - 23:00 1.00 FISH P DECOMP R/U 9 5/8" casing tools & False Bowl. 23:00 - 00:00 1.00 FISH P DECOMP Circulate well. Had gas to surface. Pump 6 BPM @ 220 psi. 2/24/2007 00:00 - 01 :00 1.00 FISH P DECOMP Con't to circulate well. Had gas to surface. Pumped 2 complete Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/24/2007 00:00 - 01 :00 1.00 FISH P DECOMP volumes. SID Still getting some gas bubbles. Monitor well No flow. Fluid level fell slowly. Appears to be gas breaking out of residual Arctic Pack. 01 :00 - 03:30 2.50 FISH P DECOMP POOH & UD 9 5/8" casing. Connections very tight. Having to beat on collars to break free. Pulled 13 jts. Hole not taking correct fill. 03:30 - 05:00 1.50 FISH P DECOMP RlU circulating head. Break circulation, annulus loaded wll Arctic Pack. Plugging flow line. Clear flow line. Con't to circulate until well cleans up.well. Recover additional Arctic Pack. 05:00 - 15:30 10.50 FISH P DECOMP Con't to POOH & UD 9 5/8" casing. Collars tight, recovered 49 jts & cut off jt, (21.56'). Recovered (9 1/2) centralizers. Pieces of some are missing. 15:30 - 18:00 2.50 FISH P DECOMP Clear I clean rig floor. Attempt to fish bottom half of bow spring centralizer off of tubing spool, hanging up at pipe rams. Opt to nipple down to fish same. 18:00 - 18:30 0.50 FISH P DECOMP PJSM. N/D BOPE. Clear & clean rig fllor.Crew Change. Check PVTs. Inspect derrick. 18:30 - 19:30 1.00 FISH P DECOMP NID BOPE & set stack back. Fish out 1/2 of a bow string centralizer & single piece of metal bow. (Total of 10 full centralizers recovered wI a few partial bow springs missing). 19:30 - 21 :00 1.50 FISH P DECOMP Install Test Plug. N/U BOPE. 21 :00 - 21 :30 0.50 FISH P DECOMP RlU & Attempt to test break. No good. Test plug leaking. 21 :30 - 22:30 1.00 FISH P DECOMP Drain stack. Pull test plug & inspect same. Re-instasll test plug & RILDS. 22:30 - 23:30 1.00 FISH P DECOMP Pressure test break. LP 250 psi, HP 3500 psi, OK. Had trouble wI tbg head lock down screws leaking. RID test equip. Note: Lost #2 motor on rig, pistion when thru engine block. 23:30 - 00:00 0.50 FISH P DECOMP Drain stack. Pull Test Plug. 2/25/2007 00:00 - 02:00 2.00 FISH P DECOMP P/U & M/U BHA #3 as follows: Washpipe Shoe, 1 Jt Washpipe, WIO Boot Basket, XO, Scraper, Bit Sub, Bumper Sub, Jars, Float Sub, XO, 9' 6 1/4" DCs, XO. TL = 337.65'. RIH wI same. 02:00 - 02:30 0.50 FISH P DECOMP RIH wI BHA # 3 to wash over casing stub. 02:30 - 03:30 1.00 FISH P DECOMP Circulate well. Gas to surface. Pumped 6 BPM @ 450 psi. Recovered additional Arctic Pack. 03:30 - 04:00 0.50 FISH P DECOMP P/U single & tag top of csg stub @ 1977'. Rotate over & Con't in hole wI remainder of jt. P/U kelly Break circulation & wash down over stub located collar @ 1997' & con't down to 2002'. P/U Wt = 55K, S/.O Wt = 52K, Rot Wt = 56K. 25 RPMs, 4 BPM @ 230 psi. Torq = 2.5-3K ft-Ibs. 04:00 - 07:00 3.00 FISH P DECOMP Circulate well clean. 4 BPM @ 230 psi. 07:00 - 07:30 0.50 FISH DECOMP Service rig, check crown 0 matic, PVT system, OK. Notified AOGCC rep John Crisp of impending BOPE test, due tomorrow. Recieved verbal permission for a 24 hour extension, as we will be running I cementing 9 5/8" casing at that time, and will perform the BOPE test directly after cutting said casing and nippling back up. 07:00 - 08:30 1.50 FISH P DECOMP POOH wI BHA #3 & stand back 31/2" DP. 08:30 - 11 :30 3.00 FISH P DECOMP PJSM. Collars covered with & filled with arcftic pack, circ out same. Stand back collars, UD wash pipe assembly. 11 :30 - 13:00 1.50 FISH P DECOMP Clear I clean rig floor af all arctic pack. 13:00 - 15:00 2.00 FISH P DECOMP PJSM. Pick up back off assembly. Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/25/2007 15:00 - 17:00 2.00 FISH P DECOMP PJSM. RIH wI back off assembly on 3 1/2" DP, filling DP every 5 stands. 20 stands total, (2) pups.. 5.89' & 8.96', & (2) singles ... 30.99' & 32.12', putting bottom anchor @ 2013', & top anchor @ 1987'. 59K up wt, 59K down wt. 17:00 - 18:00 1.00 FISH P I DECOMP PJSM. Pressure up to 1400 psi to set lower anchor, bleed pressure, set 25 - 30K down. Pressure up to 3000 psi top set top anchor, set 10K more on it & set rotary slips. Pressure up to 4500 psi to achieve initial break, = 45,000 ftllbs of torque at the collar. Observed pipe turn to the left 1/2 turn. Continue backing off total of (5) turns wI final back off pressure of 800 - 1000 psi, or 8000 - 10000 ftllbs of torque. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 FISH P DECOMP POOH & stand back 31/2" DP. 19:00 - 21 :00 2.00 FISH P DECOMP Break out & UD BHA #4. 21 :00 - 22:00 1.00 FISH P DECOMP Clear & clean rig floor. 22:00 - 22:30 0.50 FISH P DECOMP P/U & MIU BHA # 5 as follows: Bull Nose, Spear Pack Off Assy, Spear & Grapple, Spear Extension, Spear Stop, Bumper Sub, XO, DCs, XO. TL = 297.83'. 22:30 - 23:30 1.00 FISH P DECOMP RIH w/17 stands of 31/2" DP. P/U & RIH w/2 singles. 23:30 - 00:00 0.50 FISH P DECOMP P/U kelly, RIH & engage spear into cut off jt 10.5'. PIU w/2K. Rotate 12 turns to left. P/U & fish is free. P/U Wt, SIO Wt & Rot Wt = 55K. 2/26/2007 00:00 - 00:30 0.50 FISH P DECOMP Set back & blow down kelly. 00:30 - 01 :30 1.00 FISH P DECOMP UD 2 singles. POOH & stand back 31/2" DP. 01 :30 - 02:30 1.00 FISH P DECOMP Stand back DCs. Break out spear & UD cut off jt. Recovered 19.85' cut off jt wI pin. No damage to pin. Break down & UD spearassy.. 02:30 - 04:30 2.00 CASE P TIEB1 RID DP tools. RlU torq Turn Equip. False bowl & casing handling tools. 04:30 - 14:00 9.50 CASE P TIEB1 Hold PJSM. Review Casing running procedure. P/U & RIH wI 9 5/8" 47#, L-80 TCII tie back string. Torq turn all TCII connections to 17500 ft-Ibs. Used Jet Lube Seal Gard on all connections. Run total of (50) jts + (2) pups....14' & 18'. Tag 33' in on Jt #51. 14:00 - 16:00 2.00 CASE P TIEB1 PJSM. Establish parameters, 90K up wt, 90k down. Pick up, see slight overpull, slack off to neutral wt, musta caught a thread on the tag. Go ahead and make it up, 13 turns total, 12,000 ftllbs final torque at surface. Pull test to 250K, OK. Make up crossovers and headpin to pressure test. 16:00 - 17:00 1.00 CASE P TIEB1 PJSM. Pressure test 9 5/8" casing to 2000 psi, OK. Pressure up and open cementer @ 2950 psi, OK. 17:00 - 18:00 1.00 CASE P TIEB1 PJSM. Nipple down to set emergency slips on 9 5/8" casing. 18:00 - 18:30 0.50 CASE P TIEB1 Crew change. Inspect derrick. Check PVT alarms. 18:30 - 19:30 1.00 CASE P TIEB1 NIU BOPE. & choke line. 19:30 - 20:00 0.50 CEMT P TIEB1 RlU cement line & circulating hose. 20:00 - 20:30 0.50 CEMT P TIEB1 Test breaks to 500 psi on BOP prior to cementing. 20:30 - 23:00 2.50 CEMT P TIEB1 Circulate & heat well bore to 85 degrees. Pump 4 BPM @ 30 psi. Spot in trucks & RlU SWS cementing equip. Pumped total of 550 bbls. 23:00 - 23:30 0.50 CEMT TIEB1 Blow down lines. Load Wiper Plug in cementing head. 23:30 - 00:00 0.50 CEMT P TIEB1 Hold PJSM wI all hands. Review cementing procedure & assign personnel to cementing tasks. 2/27/2007 00:00 - 02:30 2.50 CEMT P TIEB1 Cement well as follows: Pump 5 bbls of FW. Pressure test Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/27/2007 2.50 CEMT P TIEB1 00:00 - 02:30 02:30 - 04:00 1.50 CEMT P TIEB1 04:00 - 05:30 1.50 CASE P TIEB1 05:30 - 07:00 1.50 WHSUR P TIEB1 07:00 - 13:00 6.00 WHSUR P TIEB1 13:00 - 17:00 4.00 BOPSU TIEB1 17:00 - 18:00 1.00 BOPSU TIEB1 18:00 - 18:30 0.50 BOPSU TIEB1 18:30 - 19:00 0.50 BOPSU TIEB1 19:00 - 20:00 1.00 BOPSU P TIEB1 20:00 - 21:00 1.00 BOPSU TIEB1 21 :00 - 00:00 3.00 BOPSU TIEB1 2/28/2007 TIEB1 00:00 - 04:30 4.50 BOPSU P 04:30 - 05:00 0.50 BOPSU TIEB1 05:00 - 06:00 1.00 BOPSU TIEB1 06:00 - 07:00 1.00 BOPSU TIEB1 07:00 - 11 :30 4.50 BOPSU TIEB1 11 :30 - 15:00 3.50 BOPSU TIEB1 15:00 - 17:00 2.00 BOPSU TIEB1 17:00 - 18:00 1.00 CLEAN P CLEAN 18:00 - 18:30 0.50 CLEAN P CLEAN 18:30 - 19:30 1.00 CLEAN P CLEAN 19:30 - 20:30 1.00 CLEAN P CLEAN lines to 4500 psi. Mix & pump 138 bbls of 15.8 ppg Class "G" wI Gas-Blok. Pumped @ 5 BPM. Pressure averaged 300 psi. SID & SI. Drop plug & open up to displace. Displaced @ 6 BPM wI 148.6 bbls of 9.8 ppg brine. Pressure increased from 600 to 975 psi. Open to open Top tank wI 105 bbls away. Had cement returns w/116 bbls. Slowed pump to 2 BPM @ 135 bbls. Bumped plug wI 148.6 bbls to 2100 psi & close ES cementer. Hold for 2 min, OK. Bled off pressure & got .8 bbls back. Holding OK. Blow down lines. RID cementing equip. Remove cementing head. Suck out 9 5/8" prior to cuttting. NID BOPE. P/U off spool. PJSM. Cut 9 5/8" casing using Wachs cutter. Laid down cut off piece... 28.10'. PJSM. Stand BOP stack back out of the way, dress cut on tubing stub. NIU new 13 5/8" 5M x 13 5/8" 5M tubing spool. Install pack off, 1st time it went in cocked, remove same, inspect seals & re install. Changed out packing on several lock down screws. Test pack off to 3800 psi I 30 minutes, OK. PJSM. Set test plug, NIU 13 5/8" x 5M BOPE. Attempt to test and found the Test Plug leaking (verified through Annulus Valve) as well as the Door Seal on the Pipe Rams. Drain out the BOP Stack. Pre-tour checks and PVT Alarms. Perform Derrick inspection. Pull Test Plug and inspect. The Rubber seal is damaged and not in good shape. Call FMC and Tool Service and have new Test Plug delivered to location. Wait on Test Plug to arrive on location. Re-tighten up Door Seal on Pipe Rams. At 19:00 hrs, the UCA on the cement is at 1,000 psi compressive strength. Set Test Plug and RILDS to energize. Perform weekly test on BOPE per BP I AOGCC Regulations to 250 psi low and 3,500 psi high. The state's right to witness the test was waived by John Crisp. The test was witnessed by the WSL, Tourpusher and Driller. Continue testing BOPE per BP I AOGCC Regulations. The Annular Preventor test failed as well as the Upper and Lower Kelly Valves. The Accumulator was not tested due to failing Annuluar Preventor test. All other tests passed. PJSM with all hands on ND BOP Stack. ND BOP Stack. PJSM. NID test spool. PJSM. Remove annular preventor cap, remove worn out element. Install new element, install cap. PJSM. Set test plug. Nipple up BOPE. PJSM. Test annular preventor @ 250 I 3500 psi, OK. Test Lower Kelly Valve, OK. Clear I clean rig floor. Pre-tour checks and service Rig. PU and MU BHA #6 as follows with Baker rep: 8 1/2" Bit, Junk Basket, Junk Basket, Bit Sub, Bumper Sub, Jar, XO, (9) 6 1/4" DCs, XO. OAL = 303.70'. TIH with BHA #6 on 3 1/2" DP from the Derrick. Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 2/28/2007 20:30 - 21 :00 0.50 CLEAN P CLEAN In with 55 Joints of DP and tag TOC 14' in on Joint #56 = 1,965'. PU and MU Kelly. UW = 55K , DW = 60K. 21 :00 - 00:00 3.00 CLEAN P CLEAN Pressure test the Upper Kelly Valve to 250 psi low and 3,500 psi high - failed. Replaced the valve and re-tested - OK. Test the Accumulator - OK. 3/1/2007 00:00 - 05:00 5.00 CLEAN P CLEAN Line up to circulate and establish parameters. UW = 55K, DW = 60K, RW = 57K. Rotating at about 30 RPM with free torque = 1,200 ft-Ibs (60 Amps). Break circulation at a rate of 3 bpm I 90 psi. Begin drilling out the Shoe Track with approximately 3-5K WOB and 1,500 ft-Ibs of torque (75 Amps). Fell through and milled out to a depth of 2,017'. 05:00 - 06:30 1.50 CLEAN P CLEAN Circulate a 30 bbl hi-vis sweep around to aid in cleaning up the well bore at a rate of 5 1/2 bpm I 200 psi. 06:30 - 07:30 1.00 CLEAN P CLEAN PJSM. RIH, (25) stands total, tag top of sand 25' in on single @ 2705' DPM. 07:30 - 09:00 1.50 CLEAN P CLEAN PJSM. Circulate 40 bbls Hi Vis sweep, chase wI seawater @ 5 bpm I 540 psi. Siginificant amount of rubber back. 09:00 - 10:00 1.00 CLEAN P CLEAN PJSM. POOH w/3 1/2" DP & shoe track milling BHA. 10:00 - 10:30 0.50 CLEAN P CLEAN PJSM. UD BHA, empty junk subs. .. , cement & some metal shavings. 10:30 - 11 :00 0.50 CLEAN P CLEAN Clear I clean rig floor. 11 :00 - 12:30 1.50 CLEAN P CLEAN PJSM. Close blind rams & pressure test 9 5/8" casing from surface to top of sand @ 2705',3500 psi 130 minute test, charted, good test. Bleed all pressure, open blind rams. 12:30 - 13:30 1.00 CLEAN P CLEAN PJSM. Pick up Reverse circulating junk basket assembly. 13:30 - 14:30 1.00 CLEAN P CLEAN PJSM. RIH wI RCJB on 3 1/2" DP, 25 stands. 14:30 - 15:30 1.00 CLEAN P CLEAN PJSM. Kelly up & establish parameters. 69K up wt, 69K down. Bring on pump @ 5 bpm 11450 psi. Rotating @ 15 RPM, 2000 ftllbs torque free spin. Slack off & tag 10' in on kelly @ 2703'. Wash I rotate on down to 2713', seeing some resistance, indicating junk. 15:30 - 17:30 2.00 CLEAN P CLEAN PJSM. POOH wI RCJB assembly. 17:30 - 19:00 1.50 CLEAN P CLEAN Break down and empty out BHA #7 Junk Baskets. Recovered the whole Rubber Cone and about half of the Ring. Also recovered a lot of Rubber chunks and cement chunks. The Baskets were full and the Scraper had some cement and rubber wedged inside the grooves. MU BHA #8 the same as BHA #7 without the Scraper to re-run in the well. 19:00 - 20:30 1 .50 CLEAN P CLEAN TIH with BHA #8 on 31/2" DP from the Derrick. 20:30 - 21 :30 1.00 CLEAN P CLEAN In with 75 Joints of DP. PU and MU Kelly. UW = 69K, DW = 69K. Tag TOS @ 2,708' (5' higher than where we cleaned out to the first run). Break circulation at a rate of 5.3 bpm 11 ,500 psi. Engage Rotary Table at 30 RPM with 1,300 ft-Ibs of torque (65 Amps). RW = 70K. Work RCJB down to a final depth of 2,724' where we buried the Kelly completely. 21 :30 - 22:30 1.00 CLEAN P CLEAN Mix and pump a 30 bbl hi-vis sweep around to aid in cleaning up the wellbore and lifting the sand to surface so it won't fall back down. Circulating at a rate of 5.3 bpm 11,700 psi. Pumped a total of 235 bbls with rubber and pieces of metal back to surface with the sand. 22:30 - 23:30 1.00 CLEAN P CLEAN TOH with BHA #8 standing back DP in the Drrick. 23:30 - 00:00 0.50 CLEAN P CLEAN On surface with RCJB Assembly. Break down and inpsect Junk Baskets. Recovered the other half of the Ring, (7) chunks of Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 3/1/2007 23:30 - 00:00 0.50 CLEAN P CLEAN cement and (1) Allen Wrench Headed Bolt. Re-make up BHA as BHA #9. 3/212007 00:00 - 01 :00 1.00 CLEAN P CLEAN TIH with BHA #9 on 3 1/2" DP from the Derrick. 01 :00 - 01 :30 0.50 CLEAN P CLEAN In with 76 Joints of DP. PU and MU Kelly. UW = 70K, DW = 70K. Break circulation at a rate of 5 bpm 11,500 psi. Engage Rotary Table at 35 RPM with free torque = 1,300 ft-Ibs (65 Amps). Work the RCJB down to a depth of 2,734' three different times. 01 :30 - 02:30 1.00 CLEAN P CLEAN CBU at a rate of 5 bpm 11,550 psi to lift sand out of well. Got small pieces of rubber back with the sand. Pumped a total of 285 bbls. Blow down and set back the Kelly. 02:30 - 03:30 1.00 CLEAN P CLEAN TOH with BHA #9 standing back DP. 03:30 - 04:00 0.50 CLEAN P CLEAN On surface with RCJB. Break down and inspect Junk Baskets. Recovered (5) Bow Spring Centralizer pieces, (1) chunk of cement, rubber and duct tape. Due to Centralizer pieces decide to re-run same BHA. MU BHA #10 (same as before). 04:00 - 05:00 1.00 CLEAN P CLEAN TIH with BHA #10 on 3 1/2" DP. 05:00 - 06:30 1.50 CLEAN P CLEAN In with 76 Joints of DP. PU and MU Kelly. UW = 70K, DW = 70K. Break circulation at a rate of 5 bpm 11,800 psi. Engage Rotary Table at 35 RPM with free torque = 1,300 ft-Ibs (65 Amps). Work the RCJB down to a depth of 2,745'. Pump a 30 bbl hi-vis sweep around at a rate of 5 bpm 11,600 psi. 06:30 - 07:00 0.50 CLEAN P CLEAN Service rig, check crown 0 matic, pit volume totalizers, derrick inspection, OK. 07:00 - 07:30 0.50 CLEAN P CLEAN PJSM. POOH w/3 1/2" DP 07:30 - 11 :00 3.50 CLEAN N RREP CLEAN PJSM. Install safety valve, close pipe rams. Open blind I shear ram doors & inspect, find broken cap screw wI missing head. Remove blind shear rams & replace with blind rams. 11 :00 - 12:30 1.50 CLEAN P CLEAN PJSM. POOH wI remaining 31/2" DP. 12:30 - 14:00 1.50 CLEAN P CLEAN PJSM. Break down BHA, empty RCJB, recovered (2) broken bow springs. 14:00 - 14:30 0.50 CLEAN P CLEAN PJSM. Close blind rams, pressure test agains 9 5/8" casing & bridge plug @ 250 I 3500 psi, OK. 14:30 - 15:00 0.50 CLEAN P CLEAN PJSM. RIH wI RCJB & collars. 15:00 - 16:30 1.50 CLEAN P CLEAN PJSM. RIH w/3 1/2" DP. 16:30 - 18:00 1.50 CLEAN P CLEAN PU Kelly. Wash down to the top of the RBP @ 2,757' while pumping 5 bpm 11,500 psi. 18:00 - 19:30 1.50 CLEAN P CLEAN Service Rig. TOH with BHA #11 standing back DP in the Derrick. 19:30 - 21:00 1.50 CLEAN P CLEAN On surface with RCJB Assembly. Recovered about 1/2 of a Bow Spring Centralizer. Break down and lay down BHA components with Baker rep. PU and MU RBP Retrieving Tool Assembly with Halliburton rep. 21 :00 - 22:00 1.00 FISH P CLEAN TIH with Halliburton Retrieving Tool Assembly on 3 1/2" DP from the Derrick. 22:00 - 22:30 0.50 FISH P CLEAN PU and MU Headpin. Close Annular and reverse circulate a DP volume to ensure the DP is clear at a rate of 4 bpm I 400 psi. Pumped a total of 32 bbls. 22:30 - 23:30 1.00 FISH P CLEAN Latch onto 9 5/8" RBP @ 2,757' per Halliburton rep. Work overpull up to 30K and the Plug came free. Work up and down past set depth a couple of times to verify we had the Plug - OK. 23:30 - 00:00 0.50 FISH P CLEAN CBU at a rate of 5 bpm I 350 psi. Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 3/3/2007 00:00 - 00:30 0.50 FISH P CLEAN Continue CBU. Pumped a total of 179 bbls with clean fluid returns seen at surface, no signs of gas. 00:30 - 01 :30 1.00 FISH P CLEAN TOH with 9 5/8" RBP and Retrieving Tool standing back DP in the Derrick. 01 :30 - 02:30 1.00 FISH P CLEAN On surface with the 9 5/8" RBP. Had pieces of rubber caught up in the Dogs of the Plug. Nothing was on top of the Plug. The Plug was in really good shape. LD whole Assembly with the Plug in the Pipe Shed. 02:30 - 04:00 1.50 CLEAN P CLEAN PJSM. PU and MU BHA #12 as follows: Mill, XO, Shear Guide Sub, (4) Jts of PAC Pipe, XO, XO, Junk Basket, Junk Basket, Bit Sub, Bumper Sub, Oil Jar, XO, (9) 6 1/4" DCs, XO. OAL = 434.85'. 04:00 - 10:00 6.00 CLEAN P CLEAN TIH with BHA #12 on 3 1/2" DP from the Derrick, 105 stands. 117K down wt, 154K up wt. 10:00 - 14:00 4.00 CLEAN P CLEAN PJSM. Pick up (1) single, tag 20' in @ 10,425' DPM. UD single, pick up kelly. Establish parameters. 162K up wt, 120K down wt, 140 K rotating wt. Bring on pump, 4 bpm 1700 psi. 4000 Wlbs of torque freespin off bottom. Sickle on down & wash thru tag spot @ 10,425', tag composite bridge plug @ 10,451'. Mill up bridge plug in about 15 - 20 minutes w/5 - 10K WOB, 1500 Wlbs of on bottom torque max. Through bridge plug, total losses, no returns @ 4 bpm. Mill 4.455" ID XIN nipple to 4.5" ID. Push bridge plug on out end of tailpipe. Total loss of returns through out operation, averaging 120 bbls Ihr. 14:00 - 00:00 10.00 CLEAN P CLEAN PJSM. Stand back kelly. POOH & UD 3 1/2" DP, constant hole fill. 100 -120 bbls I hr loss rate. Pulled and laid down 320 Joints of DP. Lay down (9) 6 1/4" DCs. 3/4/2007 00:00 - 01 :00 1.00 CLEAN P CLEAN On surface with BHA #12. Break down and lay down components with Baker Rep. 01 :00 - 01 :30 0.50 CLEAN CLEAN Clear and clean Rig Floor. Pull Wear Ring. 01 :30 - 03:00 1.50 CLEAN CLEAN RD 3 1/2" Handling Equipment. RU Stabbing Board. 03:00 - 04:30 1.50 RUNCO RUNCMP RU 5 1/2" Handling Equipment. RU Nabors Casing I Torque Turn Equipment. 04:30 - 05:00 0.50 RUNCMP PJSM with Nabors, Baker and BP Reps. Discuss running order and hazards associated with running Completion. 05:00 - 06:00 1.00 RUNCMP PU Overshot Assembly, (1) Joint of Tubing, X Nipple Assembly with RHC-M and Packer Assembly. Bakerlok all three connections below the Packer. Average loss during the night tour = 150 bph. 06:00 - 06:30 0.50 RUNCMP Service rig, check PVTs, derrick inspection, check crown 0 matic, OK. 06:30 - 00:00 17.50 RUNCMP PJSM. Run 5 1/2", 17#, 13Cr Vam Top HC Tubing, torque turning each connection to 6,580 Wlbs, using Jet Lube Seal Guard thread compound, running GLMs and other jewelry at depths specified in program. Constant hole fill, 150 bbls (+ -) I hr. 3/5/2007 00:00 - 05:00 RUNCMP Continue RIH with 51/2",17#, 13Cr, Vam Top HC Tubing Completion. Torque Turning all connections to a make up value of 6,580 ft-Ibs. Utilizing Jet Lube Seal Guard on all connections. Maintaining constant hole fill with seawater while RIH. Loss rate approximately 150 bph. 05:00 - 06:00 RUNCMP In with 243 Joints of 51/2" Tubing. PUW = 184K , SOW = 115K. PU Joint #244. PU Joint #245. Tag the Shear Pins in the Printed: 3/12/2007 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-02 03-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2007 Rig Release: 3/6/2007 Rig Number: Spud Date: 4/12/1976 End: 3/6/2007 Overshot Assembly 22' in on Joint #245. Continue RIH and no-go 26' in on Joint #245'. Space out calculations show no Pup Joints needed. Lay down Joint #245 and Joint #244. 06:00 - 08:30 2.50 RUNCMP PJSM. P/U space outjt, 40.51'. Make up hanger. P/U landing joint, land hanger, RILDs. Rig down casing tools. 08:30 - 10:30 2.00 RUNCMP PJSM. Rig up Hot Oil, test lines to 3000 psi, OK. Shaft that runs burner fractured. 10:30 - 12:30 2.00 RUNCMP PJSM. Rig down Hot Oil Unit, another one on the way from DS 17. 12:30 - 15:30 3.00 RUNCMP PJSM. Rig up Hot Oil. Pressure test lines to 3000 psi, OK. 15:30 - 19:00 3.50 RUNCMP PJSM. Pump 140 degree seawater wI corrosion inhibitor down I/A @ 2 bpm 1500 psi, no returns. Pumped 450 bbls and shut down Little Red. 19:00 - 22:00 RUNCMP Drop ball and rod down the Tubing with Baker rep. Pump 44 bbls of hot seawater down the Tubing behind the ball and rod. Close Blind Rams and pressure up to set Packer. Pressure test the Tubing to 3,500 psi for 30 mins, charted - OK. It took 8.7 bbls to achieve test pressure. Bleed the Tubing down to 1,700 psi. Continue filling up the IA with hot, inhibited seawater down the IA. Pumped 64 more bbls down the IA to fill up. Pressure test the IA to 3,500 psi for 30 mins, charted - OK. It took 10.5 bbls to achieve test pressure. Bleed the Tubing and observe the DCR Valve shear @ 1,200 psi on the Tubing. Confirm by pumping in both directions at a rate of 3 bpm I 200 psi. 22:00 - 23:00 1.00 WHSUR P RUNCMP PU T-bar and set TWC with FMC rep. LD T-bar. Test from below to 1,000 psi for 10 mins, charted - OK. Test from above to 1,000 psi for 10 mins, charted - OK. 23:00 - 00:00 1.00 BOPSU P RUNCMP PJSM. ND 135/8" BOPE. 3/6/2007 00:00 - 01 :30 1.50 BOPSU P RUNCMP Continue ND BOPE. 01 :30 - 03:00 1.50 WHSUR P RUNCMP Wait on FMC rep to round trip to his shop for the Hanger Protector pulling tool. He was unable to remove it without the pulling tool. Pull Hanger Protector - OK. 03:00 - 05:00 2.00 WHSUR P RUNCMP NU Adapter Flange. NU Tree. 05:00 - 06:00 1.00 WHSUR P RUNCMP Test the Hanger void and Packoff to 5,000 psi for 30 mins with FMC Rep. Test the Tree with diesel to 5,000 psi. RD Test Equipment and drain the Tree. 06:00 - 07:00 1.00 WHSUR P RUNCMP PJSM. P/U lubricator, pull 2 way check valve, UD lubricator. 07:00 - 09:30 2.50 RUNCO RUNCMP PJSM. Rig up Little Red Hot Oil, pressure test lines to 3500 psi, OK. Pump 150 bbls diesel down IIA @ 2 bpm 1500 psi, taking seawater returns up tubing to pits. 09:30 - 10:30 1.00 RUNCO RUNCMP PJSM. Open II A to tubing & allow diesel to U tube from IIA to tubing. 10:30 - 13:00 2.50 WHSUR P RUNCMP PJSM. Set BPV. Test BPV from the bottom with Hot Oil @ 250 11000 psi, OK. Rig down Hot Oil. Nipple down secondary annulus valve. Secure well. Rig Released @ 13:00 hrs, 03-06-2007. Printed: 3/12/2007 12:00:07 PM e 0 og escrlptton ate o or Z-20 11686722 PRESS/TEMP SURVEY 02/26/07 1 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A 11661127 MEMORY STP 01/30/07 1 NK-43 11686716 PRODUCTION PROFILE 02/17/07 1 C-06B N/A MEM PROD PROFILE 02/25/07 1 05-31A 11686719 SCMT 02/19/07 1 03-02 . 11626072 USIT CORROSION EVALUATION 02/22/07 1 03-02 11626072 USIT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22/07 1 4-18/S-30 11638613 USIT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24 11549359 RST 12/26/06 1 1 U-06BPB1 40011873 OH EDIT MWD/LWD 05/01/05 2 1 U-06B 40011873 OH EDIT MWD/LWD 05/08/05 2 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WI! 03/15/2007 NO. 4184 r70-09</ Company: State of Alaska Alaska Oil & Gas Cons Gomm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay J b# L D D BL CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. 3 2007 Petrotechnical Data Center LR2-1 SCANNED APR 0 . 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: J4 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN.: Beth,) Received by: G-_ Iii! lip ~ ;¿, '{Iurf . . SARAH PALIN, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNED JAN 1 9 2007 ~~o ;)...q \' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, Well Name: PBV 03-02 Sundry Number: 307-010 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this l:J-aay of January, 2007 Encl. t /) (\}} ~ ~ /11' \ \\' J)T~ J/ J'17 ep( (/{1/vl /~ RECEIVED . STATE OF ALASKA ~\h') ALASKA OIL AND GAS CONSERVATION COMMISSION January 8, 2007 APPLICATION FOR SUNDRY APPROYAt..oil and Gas Conservation Commission 20 AAC 25.280 Anchorage 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend ~ Repair Well ~ Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Re-Enter Suspended Well o Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation: 10. KB Elevation (ft): ¡ ADL 028328/ 61.0 'F,U ..... ................ iXXy·i.1/iy.YX/y..··.y·11.y·..··y· .... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 11750./ 9382 ( 11635 Casina Lenoth Size Strur.tural Conductor Surface Intermediate Production Liner 4. Current Well Class: .I 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 176-024 ,/ 6. API Number: 50-029-20203-00-00 / 8. Well Name and Number: PBU 03-02 ,/ 11. Field I Pool(s): / Prudhoe Bay Field I Prudhoe Bay Pool . . " Effective Depth TVD (ft): Plugs (measured): 9286 10471' TVD Burst Junk (measured): 11730' CollaDse MD 78' 2696' 20" 13-3/8" 72' 2696' 72 2696' 1530 5380 520 2670 11722' 9-5/8" 11722' 9359' 6870 4760 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: 11020' - 11044' 8787' - 8806' 7" x 5-1/2",26# x 17# 13Cr80 Packers and SSSV Type: 9-5/8" X 5-1/2" TIW HBBP wI Positive latch packers and SSSV MD (ft): 10426' 7" Camco BAL-O SSSV 2099' 14. Well Class after proposed work: o Exploratory 181 Development 0 Service Tubing MD (ft): 10488 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencina Ooerations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name 3,avid Reem Title Drilling Engineer \,\ /ì Jlg'/I _ 'bl.-! ./ V February 15, 2007 Date: 16. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Signature Phone Prepared By Name/Number: Date ¡.. 5' ~ 07 Sondra Stewman, 564-4750 , Commission USé Only Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~BOP Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number:" ~n '1_0 J 0 Other: -; 5 OO~C;\ OO~ -\-e<;.~ ~~~')M' S· SF! \,~"H(_ -", ~.~ ~___', ~ ] 8 2007 Subsequent Form Required' 4() {fL ADoroved av, --r~ ~ ~COMMISSIONER Form 10-403 Revised 06/2006 ~"""¡l/' ~uINAL APPROVED BY THE COMMISSION Date /-/7--ðr Submit In Duplicate # . . DS 03-02 Rig Workover Scope of Work: Pull 7" x 5-%" 13Cr-80 completion, cut and pull 9-5/8", run and cement new 9-5/8" premium threaded casing, run 5-%" 13Cr-80 "stacker-packer" completion. MASP: 2300 psi Well Type: Ivishak Producer! Estimated Start Date: February 15, 2007 Pre-ri 0 1 S 2 E 3 F 4 0 5 0 6 re work: Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Drift 5-1/2" chrome tubing for composite plug/chem. cutter. Pull PXN plug from tubing tail. Set 5-1/2" composite plug in 20' pup joint @ 10451'md. Chemically cut 5-1/2" CHROME tubing @ 10396'md (middle of 1st full joint above TIW HBBP packer). Depths referenced to Doyon 16's Tubin Summar dated 6/23/1994. Circulate well with seawater and freeze-protect with diesel thru the cut. CMIT TxlA to 3500 psi. MITOA alread com leted with assin test to 2000 psi 10/27/06, Bleed WHPs to 0 si. Set a BPV in the tubin han er. Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-1/2" x 6" VBR pipe rams. Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 7" x 5-%" tubing string to the cut. 3. Run USIT log and determine TOC in 9.625" x 13.375" annulus. 4. Set 9.625" retrievable bridge plug -800' md below logged TOC. 5. Mechanically cut and pull the 9.625" casing just above TOC. 6. Run and fully cement new 9.625" premium connection casing, land on slips in wellhead, install and test new pack-off. 7. Drill out shoe-track and PT casing to 3500 psi f/30-minutes. Retrieve RBP. 8. Mill up 5-1/2" composite bridge-plug and push remnants out the end of tubing tail. 9. Run 5-%" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at -10310' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. " TREE = FMC GEN I WB...LHEAD= FMC ACTUA TOR= OTIS KB. B...EV = 61' BF. B...EV = KOP= 3504' Max Angle = 56 @ 6403' Datum MD = 11113' Datum ND= 8800' SS 03-02 SAFETY NOTES: 9-5/8" CSG LEAK NOTED DURING RWO ....CHROME 7" & 5-1/2" TBG.... CALIPER NOTED CSG RESTRlCTIONS@ ?????', POSSIBLY CEMENT - SEE 02/21/06 E-MAIL IN NS WELL ALE Minimum ID = 4.560" @ 10367' PARKER SWS NIPPLE . 2099' 7" CAMCO BAL-O SSSV NIP, ID = 5.94" 7" X 5-1/2" XO, 10 = 4.87" I 13-3/8" CSG, 72#, MN-80, ID = 12.347" I GAS LIFT MANDRa..S MD ND DEV TYÆ VL V L TCH 2936 2936 5 215-YLB-1 [)MY T-2 5131 4922 41 215-YLB-1 [)MY T-2 7143 6197 51 215-YLB-1 [)MY T-2 7825 6638 49 215-YLB-1 [)MY T-2 8435 7028 51 215-YLB-1 [)MY T-2 8818 7270 50 215-YLB-1 [)MY T-2 9322 7594 49 215-YLB-1 [)MY T-2 9781 7892 49 215-YLB-1 [)MY T-2 10233 8194 46 215-YLB-1 [)MY T-2 10339 8268 45 215-YLB-1 [)MY T-2 PORT DATE o 10/25/06 o 10/25/06 o o 1 0/25/06 o o o o o o 7" TBG, 26#, 13CR-80, .0383 bpf, ID = 6.276" I 2538' 5-1/2" PARKERSWS NIP, ID 4.560" 9-5/8" X 5-1/2" TNV HBBP PKR W/POSITIVE LA TCH, ID = 4.75" 5-1/2" PRKR SWS NIP, 10 - 4.55" 5-1/2" TBG, 17#, 13CR-80, .0232 bpf, ID = 4.892" H 10488' I 5-1/2" TUBING TAIL W/MULESHOE, ID = 4.55" PERFORA TION SUMMA RY REF LOG: BHCS ON 05/01/76 ANGLEATTOPÆRF: 37 @ 10975' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 10975 - 10994 S 08/28/89 3-3/8" 6 10992 - 11010 S 08/28/89 2-1/2" 4 11020-11044 C OS/25/91 3-3/8" 4 11055 - 11089 S 08/28/89 3-3/8" 6 11100 - 11120 S 08/28/89 3-3/8" 6 11120 - 11140 S 08/28/89 3-3/8" 6 11120 - 11140 S 08/28/89 ? 4 11156 -11175 S 06/05/85 3-1/8" 1/4 11179 -11195 S 08/28/89 ? 4 11210 - 11245 S 06/05/85 3-3/8" 6 11220 - 11240 S 08/28/89 3-1/8" 1/4 11220 - 11245 S 08/28/89 ? 4 11260 - 11310 S 06/05/85 10478' B...MD TT - LOGGED 10/13/95 I IPBID H 11750' ~ 9-5/8" CSG, 47#, MN-80, ID = 8.681" H 11772' I -j FISH - RUBBER FROM IBP - 02/22/94 I -J FISH-HES ED 15R-E3 FRONG - 06/24/94 I -j FISH - RTTS PKR B...Erv18\/TS - 06/24/94 I -J FISH - TWO 1/2 X 2' BOW SPRINGS - 08/26/90 DATE 05/08/76 06/24/94 05/19/01 06/24/02 02/22/06 05/30/06 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RN/TP CORRECTIONS BHC/TLH PERF CORRECTION PJP/TLH CSG RESTRICTION NOTE DTM WB...LHEAD CORRECTION DATE REV BY COMMENTS 10/25/06 OTR/PAG GLV C/O 10/26/06 WTS/PAG SET PXN PLUG@ 10471' FRUDHOE BAY UNIT WB...L: 03-02 PERMIT No: 76-024 API No: 50-029-20203-00 SEC 11 T10N R15E 4839.62 FB... 3907.84 FNL BP Exploration (Alaska) ), TREE = W8..LHEAD= ACTUATOR= KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MO = Datum lVD= 7-1/16" 5M FMC OTIS 61' 3-02 Proposed 3504' 56 @ 6403' 11113' 8800'SS 9-5/8", 40#/ft, L-80 TC-II fully cemented in place w/15.8 ppg class "G" gas-blok cement 13-3/8" CSG, 72#, MN-80, 10= 12.347" I 5-1/2" TBG. 17#, 13CR-80. .0232 bpf, 10 = 4.892" I I UNIQUE MACHINE OVERSHOT 5-1/2" TBG, 17#, 13CR-80, .0232 bpf, 10 = 4.892" PERFORA TION SUMMARY REF LOG: BHeS ON 05/01/76 ANGLE AT TOP PERF: 37 @ 10975' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OATE 3-3/8" 4 10975 - 10994 S 08/28/89 3-3/8" 6 10992 - 11010 S 08/28/89 2-1/2" 4 11020-11044 C 05/25/91 3-3/8" 4 11055 - 11089 S 08128/89 3-3/8" 6 11100 - 11120 S 08/28/89 3-3/8" 6 11120 - 11140 S 08/28/89 3-3/8" 6 11120 - 11140 S 08/28/89 ? 4 11156 -11175 S 06/05/85 3-1/8" 1/4 11179 - 11195 S 08/28/89 ? 4 11210 - 11245 S 06/05/85 3-3/8" 6 11220 - 11240 S 08/28/89 3-1/8" 1/4 11220 - 11245 S 08/28/89 ? 4 11260-11310 S 06/05/85 5-1/2" HES "X" NIP, 10 = 4.562" GAS LIFT MANDRB..S MO TYPE VLV 5.5" x 1.5" OCR 5.5" x 1.5" DMY 5.5" x 1.5" DMY 5.5" x 1.5" DMY 5.5" x 1.5" DMY 5.5" x 1.5" DMY 5.5" x 1.5" DMY 10461' 10476' 10488' IPBTD H 11750' r-- 9-5/8" CSG, 47#, MN-80, ID = 8.681" H 11772' I DA TE REV BY COrvtÆNTS 05/08176 ORIGINAL COMPLETION 06/24/94 LAST WORKOVER 05/19/01 RtflP CORRECTIONS 06/24/02 BHClTLH PERF CORRECTION 02/22/06 PJPlTLH CSG RESTRICTION NOTE 05/30/06 OTM WELLHEAO CORRECTION OA TE REV BY CO 10/25/06 OTRIPAG GLV C/O 10/26/06 wrS/PAG SET PXN PLUG@ 10471' 5-1/2" HES "X" NIP, 10 = 4.562" 9-5/8" x 5-1/2" BAKER S-3 PACKER 5-112" HES "X" NIP, 10 = 4.562" 5-1/2" PARKER SWS NIP, ID = 4.560" 9-5/8" X 5-1/2" TIW HBBP PKR W/POSrrlVE LA TCH, 10 = 4.75" 5-1/2" PRKRSWS NIP, 10=4.55" 5-1/2" HES XN NIP, 10 = 4.55" 5-1/2" TUBING TAL W/MULESHOE, ID = 4.55" FISH - RUBBER FROM IBP - 02/22/94 I FISH-HES ED 15R-E3 PRONG - 06/24/94 FISH - RTTS PKR aEMENTS - 06/24/94 FISH - 1WO 1/2 X 2' BOW SPRINGS - 08/26/90 PRUDHOE BAY UNrr W8..L: 03-02 PERMrr No: 76-024 API No: 50-029-20203-00 SEC 11 T1 ON R15E 4839.62 Fa 3907.84 FNL BP exploration (Alaska) MEMORANDUM TO: Julie Heusser, Commissioner THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 15, 2001 Tom Maunder, P. I. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Ddll Site 03 JanUary 15~ 2001: I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble was BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-1'4-01 due to blowing snow & chill factor of-50 degrees. Testing was conducted in a safe & efficient manner. Two failures were witnessed. The AOGCC 'test report is attached for reference. 21 wellhouses were inspected during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat or lights are installed in wellhouses for producing wells. SUMMARY: I witnessed SVS tests, in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed. 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1.15-00jc NON-CONFIDENTIAL SVS PBU DS 03 1-15-01jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test RepOrt Operator: BPX -' Submitted BY: John Crisp Date: 1/15/01 OPerator Rep: Mark Womble Field/Unit/Pad: prudh, ge ,,,Bay Field DS 03 AOGCC Rep: John Crisp Separator Psi: LPS 185 HPS 690 . Well· Permit Separ' set. L/P Test Test Test Date Oii, WAG, GiNJ, Number Number 'PSI PSI .Trip Code Code Code Passed GASor,~YCLE 03-01 1750~50 185!" 150 100 P P OIL 03-02 1760240 185 150- 120 'P P OIL 03-03 1760390 185' 150 110 P P 0IL ,, 03-04 1760510' .' · , 03-05 1760570 · 03-06 1760600 .. , 03-07 1760530 03-08 1760730 ' 185 . .150 130 P P ~ OIL , 03-09 1790220 1851 150 100 P P OIL 03-10 1790210 · , 03-11 1790470 · 03-12 1790580 03-13 1790710 ' · , 03-14 1790820 185~' 150 100 ..P P OIL 03-15A 1930150 185 150 '100 P P OIL , , 03-16A '1970330 · 03-17 1791020 · ,, 03,18A 1930420 ' 03-19 1830920 . 185 1501 90P P. OIL , , 03-20A 1930470 185 ' 150 100P P OIL 0~-21 1831120 185 150 100P P " OIL , 03-22 1831230 690 600 420 P P OIL 03-23 1831270 185 '150 0 1 P OIL ,, 03-24A 1980060 690 600 530. P. P ' . OIL , 03-25A 1930230 · 03-26 1831510 185 150 I10- P P OIL ,, , · 03-27 1840620 185 .150 100 P P OIL 63-28 1840720 ' , 03-29 1840790 185 150 110 P P OIL , 03-30 1840830' 185 1'50 90 P P OIL ,,, 03-31 1840920 185 150 140 . P P OIL 03-32A 19405401 185 150 '110 P' P' OIL , , 03-33A 1970390 , 03-34B' 2000110 185 150. 0 . 1 P OIL 1/18/01 Page 1 of 2 SVS PBU DS 03 1-15-01c.xls 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 i i i 03-35 1910800 185 150 90 P' ' P OILI 03-36 193'0190 ' · , Wells: 21 Components: 42 Failures: -2 Failure Rate: 4.8% Ulgo oar Remarks: ~ ~ o~a~ Paee 2 of 2 SVS PBU DS 03 1-15-01c.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing x Alter casing Repair well x Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1903' NSL, 688' EWL, SEC. 11, TION, R15E At top of productive interval 1318' NSL, 4390' WEL, SEC. 10, TION, R15E At effective depth 1361'NSL, 4791' WEL, SEC. 10, TION, R15E At total depth 1369' NSL, 4839' WEL, SEC. 10, TION, R15E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development X Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE -- 61 7. Unit or Property name Prudhoe Bay Unit 8. Well number 3-2 9. Permit number/approval number 76-24~Conservation order #258 10. APl number 50- O29-2O203 11. Field/Pool Prudhoe Bay Field~Oil Pool feet feet Plugs (measured) FCO sand plug to 11050' MD Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True vertical depth AUG $1 1994 0il & Gas Cons. Commission Anchorc~e feet Tubing (size, grade, and measured depth) 7", 13CR80- tubing to 2538' MD; 5-1/2", 13CR80 Tubing to 10488' MD Packers and SSSV (type and measured depth) TIW "HB-BP" packer w/positive latch @ 10426' MD; 7" Camco SVLN @ 2099' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation ReDresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certif t at the fore lng is true and correct to the best of my knowledge. Signed ~t .~~"'~ Title OrillingEngineerSupervisor --orm 10-404 R{v 06/15~81~ U Date ~'.~f" (~ SUBMIT IN DUPLICA BOROUGH: NORTH SLOPE/~''' UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 04/05/94 12:01 SPUD: RELEASE: 06/23/94 06:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 04~08/94(1) TD: 0 PB: 0 NU BOPE MW: 0.0 LOWER DERRICK & MOVE ONTO WELL. RAISE & SECURE DERRICK. MOVE RIG OVER WELL, LEVEL, SET IN SEAH20 CUTNGS & SLOP TANK. RIG ACPTED @ 20:00 HR TAKE ON SEAH20 RU T/CIRC. RU LUB. & PULL BPV. RD LUBRICATOR. CBU TO BAL. WELL ND TREE & ADPTR FLG. CHECK TIE DOWN STUDS. TS T/RT=20.58' BRIDGE CRANE COULDN'T CLEAR TBG.HNGR W/BOPE. DROPPED Bl-rM RAMS ON STUMP. MOVE BOPE STACK OVER WELL. FLG UP BTTM RAMS T/TBG. SPOOL & SET REMAINING STACK ON & FLG UP. 04/09/94 (2) TD:I 1750 PB:11635 FINISH TESTING BOPE MW: 8.5 Seawater NU 13-5/8 T/5000. TRI RAM BOP STACK. TEST BOPE. RU PULL HNGR. RU LUB. PULL BPV. RD MU LNDG JT. PULL HNGR. & LD. RU T/CBU. GAS & CRUDE IN RETURNS. TOOH. LD COMP. STRING 7" & SSSV. C/O T/5.5 TBG EQUIP. PULL 119 JTS OF 5.5 & 8 GLM'S. LIH= 60JTS & 8 GLM'S. CLEAR FLOOR, PU 5" DP. FNSH TESTNG BOPE. 04/10/94 (3) TD:I 1750 PB:11635 TIH W/JET CUTTER MW: 8.5 Seawater TEST BOPE PU FSHNG ASSY & BHA. TIH PU 5" DP. DBL CUT DL. TIH PU 5" DP T/7745. TAG TOP OF FISH. ENGAGE FISH W/OVERSHOT. PIPE PARTED, TOOH. RCVRD. 12 JTS, 5.5" TBG & 2 GLM'S. TOP OF FISH @8303.83. W/COLLAR LOOKING UP. RU & LD FISH. RU ATLAS WL. TIH W/JET CUll'ER. TOOL HUNG UP @10387. IN 1ST. GLM. 04/11/94 (4) TD:I 1750 PB:I 1635 LD FISH MW: 8.5 Seawater PULL JET SHOT FREE, PU T/10350 & CUT TBG. PULL T/8649 HANGUP IN TOP GLM. WORK FREE, TOOH. RD ATLAS WL. PU SPEAR ON FISH ASSY, TIH T/TOP OF FISH @8304. ENGAGE FISH, TOOH W/38 STDS. THREADS PARTED ON TOP OF NO. 8 GLM. TOP OF FISH @ 8650. PU EXTEN. & SPEAR. SERV. RIG. TIH T/8297, PU DP, KELLY, BREAK CIRC. ENGAGE FISH, SET BACK KELLY, TRIP OUT. W/35,000 # FISH. RU TBG EQUIP. LD FISH. 04/12/94 (5) TRIP OUT MW: 8.5 Seawater TD:I 1750 PB:11635 LD FISH. RECOVERED 5 GLM. ASSY-35 JTS. TBG & 23' CUT OFF. PU MILLING ASSY. TRIP IN 84 STNDS. PU 55 JTS F/SHED. PU KELLY MILL STUMP 10315 T/10317.5. TOOH W/MILL LD MILL & JUNK BSKTS. MU OVERSHOT ASSY. TIH T/10317. PU KELLY, BRK ClRC, ENGAGE FISH. SET BCK KELLY. TOOH. WELL:DS 3-2 TYPE:DEV RIG:DOYON 16 ACCEPT: 04/07/94 CODE:3 04/13/94 (6) CHANGE FISHING ASSY MW: 8.5 Seawater TD:I 1750 PB:11635 TOOH RECOVER FISH 34', 5.5" TBG CONNECTION BROKE OFF LAST SUPV:EDP GLM. PU SPEAR ASSY. TIH W/BHA & DP. CUT DL. TIH, PU KELLY. SPACE OUT, ENGAGE FISH. SET BACK KELLY. TOOH. MISS RUN. SPEAR WAS SHEARED. PU NEW SPEAR & BUMPER JARS. TIH W/SPEAR FISHING ASSY. PU KELLY, BREAK CIRC. ENGAGE FISH. WORK UP T/110000# OVER STRING WT. HITTING JARS, LOST WT. TRIP OUT. LOST GRAPPLE OFF SPEAR. CHANGE FISHING ASSY T/SHORT CATCH OVERSHOT. 04/14/94 (7) FISHING W/SPEAR @ 10358 MW: 8.5 Seawater TD:I 1750 PB:11635 TIH W/8.25X60VRSHT. PU KELLY. BRK CIRC. ATMPT T/ENGAGE SUPV:EDP FISH @10358. TOOH LD OVRSHT. PU MLNG ASSY 3.75X1.25. TIH. KELLY UP. BRK CIRC. TAG FISH @ 10356. MILL INSIDE FISH T/10370. SET BK KELLY. TOOH F/SPEAR ASSY. LD MILL ASSY. PU SPEAR ASSY. TIH. PU KELLY BRK CIRC. FSHNG W/SPEAR @10358 TOP OFF GLM. 04/15/94 (8) PU 9-5/8 BAKER TEST PKR MW: 8.5 Seawater TD:I 1750 PB:11635 SET BCK KELLY. TRIP OUT W/FISH. RECVR'ED GLM/5.5 PUP/2 JTS SUPV:EDP 5.5 TBG/5.5 PUP SEAL ASSY BRK & LD BAKER TOOLS. PU & STRAP 3-1/8 DCS & 4.25 MILL 9-5/8 CASG SCRAPER 12 6.25 DCS. JARS 12 HWDP. TIH. PU KELLY. WASH THRU PKR ASSY & TAIL PIPE. PULL BACK ABOVE PBR @ 10484. CBU 3400 STRKS MILL STARTED T/PLUG. REV. OUT. TEST CASG T/3500 LOST 425 TOOH LD DCS & MILL. PU 9-5/8 BAKER TEST PKR. 04/16/94 (9) TIH W/FISHING ASSY MW: 8.5 Seawater TD:I 1750 PB:I 1635 TIH W/BAKER 9-5/8/TEST PKR T/10478. SET PKR/PRESS ANNUL SUPV:EDP T/3500. REPAIR SURF. LEAK. TEST F/30 MIN. OK. RIG & CIRC. CLEAN HOLE W/INHIB. SEAH20. SET BACK 50 STDS DP. LD DP & BAKER TEST PKR. PULL WEAR BUSHING. RU WEATHERFORD CASG TOOLS & RUN 5.5 & 7 COMP. STRING. RD WEATHER. TBG EQUIP. RUN IN WEAR RING. MU FISHING ASSY. TIH PICKING UP DP. 04/17/94 (10) TIH PU DP. MW: 8.5 Seawater TD:I 1750 PB:11635 TIH W/OVERSHOT PU DP. SET DOWN ON FISH @1359. PU 100K OVER SUPV:EDP STRING WT. DROPPED 1.7/8 BALL. PU KELLY, PRESS UP T/2000. 2WICE PULLED 14K OVERSTRING WT. ROT. 22 TURNS. RELEASE K ANCHOR. TOOH W/DP T/FISH. RELEASE OVERSHOT OFF TBG COLLOAR. RU WEATHERFORD TBG TONGS. TOOH. LD COMP. STRING T/PKR LATCH. RD WEATH. TBG EQUIP. TEST BBOPE. PU PAKR MILL ASSY. TIH. PU 34 JTS GRE DP. KELLY UP/BRK CIRC. TAG FISH @2412. MILL FISH T/2415 MILL WT DROPPED OFF 5000. PULLED OFF FISH. ~ n TOOH F/SPEAR ASSY. RIH THRU MILL AREA, FISH FELL DOWN HOLE. R ~E (~ ~ IV TIH PU DP. AUG 3 ] 1994 Aisska 0il & Gas Con~. Commission Anchor;..~e WELL:DS 3-2 TYPE:DEV RIG:DOYON 16 ACCEPT: 04/07/94 CODE:3 04/18/94 (11) FISHING @ 10440 MW: 8.5 Seawater TD:I 1750 PB:11635 TIH. PU KEg BRK CIRC. ENGAGE FISH W/PRESS INCREASE, SET SUPV:EDP BACK KEL. TOOH. NO FISH. LEFT GRAPPLE IN HOLE. LD SPEAR ASSY. PU 4-5/8 MILL ON 15' EXTENSION. TIH T/10414. PU KEL. BRK CIRC. WORK & MILL THROUGH FISH 15'. TOP @ 10440. TOOH F/SPEAR. LD MILLING ASSY. PU SPEAR. TIH. PU KEL. SPEAR FISH @10440. 04/19/94 (12) TIH W/SHIFT. FORKS &PKR MW: 8.5 Seawater TD:I 175O PB:11635 TOOH W/FISH ON SPEAR, HUNG UP ON BOWL PROTECT. PU SUPV:EDP RETRIEVING TOOL & PULL PROTECT. RECOVER FISH. LD TOOLS & JUNK FROM X NIPPLE ASSY. PU 3-1/16 DCS & 4-1/8 MILL. RIH. REPAIR HYROLIC LINE, TIH. CUT DL PU KELY, BRK CIRC, ROTATE & WASH THRU PCKR & TAIL PIPE F/10448 T/10638. PULL BACK OUT OF PKR. CLOSE PIPE RAMS, PRESS CASG T/2000, BLED BACK T/1000. GETTING RETURNS F/9-5/8 ANNUL. TOOH F/TEST PKR & HALIB. SHIFTING FORKS. LD 3-1/8 DCS. & 4-1/8 MILL. PU HALIB. T/SHIFTING FORKS & BAKER TEST PKR. & TIH. 04/20/94 (13) RUNNING COMPLETION MW: 8.5 Seawater TD:I 1750 PB:11635 TIH T/2500. FO CLOSING @2414. SET PKR PRES. T/3500. LEAK SUPV:EDP OFF. REUSED PKR. PULLED BCK THRU FO. RIH T/2700. SET PKR @2700. PRES.T/3500/15 MIN. OK. TIH T/10467. SET PKR/TEST CASG T/3500/20MIN. OK. TOOH STD BCK 48 STNDS. DP. LD DP/BHA PULL WEAR BSHING CLOSE BLINDS. TEST CASG. T/INSURE FOS. IS SHUT. OK. RU WTHRFRD T/RUN COMP. STRING. RUN 5.5 17# CR13-80 TBG. COMP STRING. 04/21/94 (14) ND BOP STACK MW: 8.5 Seawater TD:I 1750 PB:11635 RAN 5.5 & 7" 13CT80 COMP. STRING. T/SSSV. MU 7" CAMCO SVLN SUPV:TBC SSSV. CONECT CNTRL LINES, TEST T/5000. CON'T RUN'NG T/EXISTING PBR @ 10884. RU CIRC SWEDGE LINES. CIRC WHILE LOCAT. TAILPIPE ASSY IN POLISHED BORE RECEPTICLE. PRES. INCREASE CONFIRMED LOCAT. RD SWEDGE LINES. SPACED OUT. INSTAL TBG HNGR/CNTRL LINES. TEST LINES T/5000. DROPPED SET'NG BALL/STEM ASSY. INSTAL BLANKING PLUG IN HNGR. MU LNDG JT. LAND COMP STRING/TBG HNGR IN WELL HEAD. RD OTIS & TBG RUN'NG EQUIP. ND BOP STK. SET BK. HAD T/DROP OUT BTTM RAM ASSY DUE T/HEIGHT CONSTRAINTS W/TBG SPOOL. 04/22/94 (15) RIG RELEASED MW: 8.5 Seawater TD:I 1750 PB:11635 COMP. ND BOP STACK & SET BK. NU ADAPTOR FLANGE/X-MAS SUPV:TBC TREE/CONTROL LINES. TEST T/5000. RU LUBRICATOR. PULL BPV/RD LUBRICATOR. RU TOP TREE ADAP. PRESS COMP STRING T/3500. SET PKR/TEST COMP STRING/30 MIN. PKR SET @ 10436. TEST ANNUL. T/3500/30 MIN. W/1700 ON TBG STRING. BLED OFF PRESS. PRESS THE ANNUL. SHEAR OUT RP VALVE W/2975. FRZ PROTCT T/2000 W/127 BBLS DIESEL. SECURE TREE. INSTALL BPV. RELEASE RIG @ 16:00 HOURS 4/21/94. RECEIVED AUG $ I 1994, msska 0il & Gas Cons. Commission Anchor' .~e WELL:DS 3-2 TYPE:DEV RIG:DOYON 16 ACCEPT: 06/08/94 CODE:3 (1) 06/09/94 (16) NIPPLE UP BOPE MW: 8.5 Seawater TD:I 1750 PB:10852 MOVE RIG AROUND PIT F/DS-3-26. TAKE ON SEAWATER, RU ON TREE T/CIRC. RU LUBR. PULL BPV. CIRC OUT FRZ PROTECT. CBU. OBSERVE WELL. SET 2-WAY CHCK. ND TREE & ADPTR FLNG. NU BOPE. (2) 06/10/94 (17) TD:11750 PB:10852 LD COMP STRING MW: 8.5 Seawater COMP. BOPE RIGUP. A'I-I'EMPT TEST ON BLIND RAMS. APl RING LEAKED BETWEEN TBG SPOOL & BOP'S. WOULDN'T TIGHTEN UP. REMOVE BOP STACK & REPLACE RING. TEST BOP'S. LEAK BETWEEN MUD CROSS & BLIND RAMS. RD BOPE & REPLACE RING. NU BOPE. 2-WAY CHK LEAKED. MU LNDG JT ON HNGR. TEST HYDRIL T/2500. OK. CLOSED TOP RAMS. TEST BOP BODY & CHOKE MANIFOLD/OK. THREAD ON LNDG JT LEAKED. PULL JT. VARIANCE T/COMP. TEST WHEN OUT OF HOLE W/COMP STRING GRANTED. INSTALL LUBR. PULL BPV. MU LNDG JT. PULL & REMOVE HNGR. PULL & LD COMP. STRING. (3) 06/11/94 (18) TIH W/OVERSHOT EQUIP. MW: 8.5 Seawater TD:I 1750 PB:10852 LD COMP STRING. CLEAN TBG EQUIP. & FLOOR. RD TBG RUNNING EQUIP. SET TEST PLUG. CHANGE RAMS AROUND. INSTALL SHEAR RAMS. TEST BOPE. RUN WEAR BUSHING. RD TEST EQUIP. PU FISHING ASSY, 12 6.25 DC'S & 3.5 DP. (4) 06/12/94 (19) TD:I 1750 PB:10852 CUT & SLIP DL MW: 8.5 Seawater TIH W/OVERSHOT PU 3.5" DP. MILL OVER FLAIRED END OF TBG T/HOLLOW MILL @ 10371. TOOH. NO FISH. CHANGE OVERSHOT CONFIGURATION. TIH PU KELLY TAG FISH @10371. MILL OVER FISH T/10379. TOOH, RECOVER CUTOFF JT/PUP X/NIPPLE/2 PUPS/LATCH LD OVRSHT ASSY. PU PCKR MILLING ASSY. RIH. CUT & SLIP 57.5' DL. RECEIVED ~tJ(.; 3 1 1994 ;~.~a ~jti & 6as Cons. Commission Anchor~ ~e WELL: DS3-02 RIG: DOYON16 ACCEPT: 6/8/94 (5) 06/13/94 (20) LD FISH. MU OVERSHOT ASSY MW: 8.5 Seawater TD:I 1750 PB:10852 TIH W/MILLING ASSY. PU KELLY. BREAK CIRC. TAG FISH @10436. MULL 9-5/8" PKR T/10442. TOOH. LD ASSY, CLEAN BOOT BUCKETS & LD. PU SPEAR ASWSY & TIH. PU KELLY. TAG FISH @ 10442. TOOH W/FISH. LD SPEAR ASSY & MU OVERSHOT ASSY. (6) 06114194 (21) TD:I 1750 PB:10852 TOOH W/PACKER MW: 8.5 Seawater TRIP IN W/OVERSHOT ASSY. PU KELLY. TAG TOP OF FISH @10485. FISH SAME. TOOH. LD FISH. CHANGE BHA T/PCKR MILLING ASSY. W/PRT. TIH W/MILLING TOOL. TAG PACKER @ 10485. MILL ON PACKER 10500 T/10503. PACKER MOVED DOWN HOLE. CBU. GAS @ BTTMS UP. PUT THRU CHOKE. TOOH. PCKR HANGING UP. TRIP OUT SLOW. (7) 06/15/94 (22) TD:I 1750 PB:10852 WASHOVER FISH @10732 MW: 8.5 Seawater LD FISH. CLEAN BSKTS, PU SPEAR ASSY. SLIP & CUT DL. TIH PU 3.5 DP. KELLY UP TAG FISH @ 10665. POOH LD FISH. RECOVERED TBG COLLAR, PUP 1 JT TBG & COLLAR. LD SPEAR ASSY. PU OVERSHOT ASSY. TIH. PU KELLY TAG BTTM @10695. TRQ PROBLEMS DOWN HOLE. TOOH RECOVERED 1 JT TBG - BAD. LD OVERSHOT ASSY. PU 1 JT WASH PIPE W/WASH OVER SHOE. TIH WASH T/BTTM. TAG @ 10701. FISH TOP @ 10732. PUMP VIS SWEEP. (8) 06/16/94 (23) RIH W/8.5" MILL MW: 8.5 Seawater TD:I 1750 PB:10852 WASHED DOWN W/BURNING SHOE/WASH PIPE ASSY 10701 T/TOF @ 10729. CBU POOH W/WASH PIPE ASSY & LD. PU 8.5" MILL. MU BHA. RIH T/10660. WASH T/TOF @ 10729 - 10750. NO PROGRESS. POOH/INSPECT MILL. EMPTY BOOT BSKTS. RECOVER 16# METAL-NO GRAPPLE. SLIP & CUT DL. PU NEW MILL W/3 BOOT BSKTS & RIH. (9) 06/17/94 (24) TD:I 1750 PB:10852 POOH W/REV CIRC. JET BSKT MW: 8.5 Seawater RIH W/MILLING ASSY T/10750. REV. CIRC HOLE CLEAN. RECOVER CMT/METAL. MILL UP JUNK, CMT F/10750 T/TOP OF SAND PLUG @10857. CON'T MILL UP JUNK & SAND T/10876. DECREASE IN MILL RATE/PUMP HI VIS SWEEP T/CLEAN HOLE. POOH F/REV ClRC JET BSKT. MILL WAS .5" UNDER GUAGE. 70% WEAR. 35# METAL RCVRD. PU 8.5" REV ClRC JET BSKT. MU BHA. RIH T/10826. POOH W/REV ClRC BSKT ASSY T/PU BIT. RECEIVED AUG 3 1 1994 0il & Gas Cons. Commission Anchor~.e WELL: DS3-02 RIG: DOYON 16 ACCEPT: 06/08/94 (10) 06/18/94 (25) RIH W/REV. CIRC JET BSKT MW: 8.5 Seawater TD:I 1750 PB:10891 COMP POOH W/REV. CIRC. JET ASSY. PU 8.5 MILL TOOTH BIT. MU BHA W/NB STAB. RIH ON 3.5 DP T/10814. MU KELLY CBU. RECOVER (:;MT. POOH W/BIT LD STAB. PU REV CIRO, MU BHA. RIH T/10831. MU KELLY. POOH W/REV CIRC JET BSKT. SLIP & CUT DL. MU NEW ASSY. (11) 06/19/94 (26) TD:I 1750 PB:I O898 (12) TESTING CASG MW: 8.5 Seawater RIH T/10814. MU KELLY. WASH DOWN T/TOP OF FILL @ 10891. CLEAN SAND OFF F/10891 T/10898. POOH W/REV. (::;IRC JET BSKT. RECOVER SMALL CHUNKS OF CMT. TEST BOPE EQUIP. WITNESS BY J.SPAULDING, AOGCC REP WAS WAIVED. PU 8.5" BIT, MU CASG SCRAPER, BHA & RIH T/10840. CBU. POOH W/BIT & SCRAPER. LD. CLEAN PITS WHILE POOH. MU 9-5/8" RTTS. TEST PKR. RIH T/10835. SET PKR @ 10835. FLUID LEAKING BY PKR. PU T/10815. RESET. PRESS UP T/3500. BLEED OFF T/3000 IN 15 MIN. HELD @ 3000. 06/20/94 (27) RUNNING COMPLETION MW: 8.5 Seawater TD:11750 PB:10898 TEST CASG F/10815. BLEED PRESS CHECK SURF. LINES. NO LEAKS. PU T/PKR SETTING !@ 10455. TEST CSG T/3500. OK. CSG LEAKING IN MORE THAN 1 AREA BELOW 10600. DISPLACE HOLE W/INHIB. SEAH20. POOH W/TEST PKR. LD DP. PULL WEAR BUSHING RU T/RUN COMP. (13) 06/21/94 (28) TD:I 1750 PB:10898 RU OTIS T/RUN CNTRL LINES MW: 8.5 Seawater RUN COMP/JT COUNT SHOWED DISCREPANCY. 4) 5.5 JTS OMITTED BETWEEN GLM 5 & 6. POOH LD TBG T/GLM 9. ADD 4 JTS TBG BELOW GLM. DISCUSSION W/OPS ENG. REP INDICATED THIS WOULD BE SUFFICIENT T/ALLEVIATE POTENTIAL GAS LIFT DESIGN PROB. RESULT: GLM 1-5 ON DEPTH W/PROGRAM. 6-8 ARE LOW T/PROGRAM & 9-10 ARE ON DEPTH. CON'T. T/RUN 5.5 7" COMP T/SSSV. RU OTIS T/RUN CONTROL LINES. R'ECEIVED A/JG ~ 1 & t~as Cons, Commission Anchor; ue WELL: DS3-02 RIG: DOYON 16 ACCEPT: 06/08/94 (14) 06/22/94 (29) TD:I 1750 PB:10898 RIH W/WL T/RETRIEVE BALL MW: 8.5 Seawater MU SSSV INSTL CNTRL. LINES. TEST T/5000. RUN 5.5 7" COMP T/PKR SET'NG DEPTH DROP BALL/BAR. MU HNGR/LNDG JT/H/U CNTRL LINES & TEST T/5000. LAND COMP STRING/TBG HNGR IN TBG SPOOL. RILDS. L/D LNDG JT. SET 2-WAY ND BOP STACK. NU X-MAS TREE. TEST TREE/HNGR T/5000. RU LUBR. PRESS STRING T/4000 T/SET PKR. RTRNS ON ANNUL/PRESS BLED OFF 800 IN 30 MIN. PRESS ANNUL T/900. FULL RTRNS BALL/BAR DIDN'T REACH XN NIPL/PCKR DIDN'T SET. TRY T/FREE BY FLUSHING DOWN TBG THEN CASG ONCE MORE. SUSPENDED CPS T/PREVENT EXCESS FLOW PAST PKR. CON'T T/PRERARE F/RIG MOVE WHILE WAITING ON WL UNIT. RU WL LUBR. RIH RETRY DUMMY VALVE IN SSSV. RIH W/WL TO FIND BALL/BAR. (15) 06/23/94 (30) TD:11750 PB:10852 RETRIEVE EQULZNG DUMMY MW: 8.5 Seawater RIH W/SL T/OBSTRC'N @ 8475 WLM. WORK LINE, CONT RIH T/RHC PLUG IN XN NIP'L PRESS TBG/BLED OFF SAME RATE/POOH RECOVER BALL. SET PLUG IN SWS NIP'L ABOVE PKR T/ISOLATE COMP. STRING. PRESS/LEAKOFF SAME. PULL RP VALVE IN TOP GLM. REPLACE W/DUMMY VALVE. PRESS/BLEED OFF IS SAME. RP VALVE WASN'T SHEARED. RD OTIS. RU SCHLMBRGR. MADE SPINNER TOOL. LEAK IN LOWER MOST GLM W/DUMMY EQLZNG VALVE. RD SCHLMBRGR. RU OTIS T/PULL EQLZNG DUMMY/COUNDN'T FIND. PULL PLUG F/SWS NIPPLE. C/O TOOL TYPE & RIH T/RETRIEVE DUMMY EQLZNG VALVE. (16) 06/24/94 (31) TD:I 1750 PB:10898 RIG RELEASED MW: 8.5 Seawater COMP RUN T/RETRV PRONG F/DUMMY EQLZG VALVE. DIDN'T WORK. REDRESS TOOL, ADD lB. WENT T/LOWER MOST GLM. INSPECT lB/PRONG MIS'NG F/EQLZNG VALVE. MU PLUG RETRV TOOL T/KICK OVER TOOL. RETRV EQLZNG VALVE ON 2ND ATTEMPT. SET DUMMY VALVE IN LOWER MOST GLM. W/TBG OPEN TEST ANNUL T/3500/30 MIN. NO PRESS LEAKOFF. DROP BALL/PRESS TBG STRING T/3700. LEAKOFF T/2900 15 MIN. NO RTRNS ON ANNUL. BALL NOT SEATED CORRECT. IN RHS PLUG. BLED OFF PRESS. REPLACE DUMMY PLUG W/RP VALVE IN UPPER GLM. RD OTIS. PRESS ANNUL T/3000 T/SHEAR OUT RP VALVE. FRZ PRTCT ANNUL/TBG T/2000 W/DIESEL. SET BPV. SECURE X-MAS TREE. MOVE RIG OFF. RELEASE @18:00 HRS. 6/23/94. Signature Date RECEIVED AUG 1 1994 Atask~ Oil & Gas Cons, C~mrnission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shUtdown Pull tubing X 2. Name of Operator ARCO Aiaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1903' NSL, 688'EW1., SEC. 11, TION, R15E At top of productive interval 1318' NSL, 4390' WEL, SEC. 10, TION, R15E At effective depth 1361' NSL, 4791' WEL, SEC. 10, TION, R15E At total depth 1369' NSL, 4839' WEL, SEC. 10, TION, R15E 12. Present well condition summary Total depth: measured true vertical Stimulate Plugging Alter casing. Repair well x 5. Type of Well: Development X Exploratory. .. Stratigraphic .... Service. . ORIGINAL feet feet i i Plugs (measured) Perforate... Other 6. Datum elevation (DF or KB) KBE = 61 feet 7. Unit or Property name Prudhoe Bay Unit '8'. Well number 3-2 g. Permit number/approval number 76-24/Conservation order #258 10. APl number 50- 029-20203 11. Field/Pool Prudhoe Bay Field/Oil Pool FCO sand plug to 11050' MD Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Size Cemented Measured depth True vertical depth AUG 1 0 1994 Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 7", 13CR80- tubing to 2538' MD; 5-1/2", 13CR80 Tubing to 10492' MD Packers and SSSV (type and measured depth) Baker SABL-3 packer @ 10436' MD; 7" Camco S VLN @ 2109' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Aver~,ge production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas SUspended . Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l~u~ ~ ~~'~ TitleDrillin~lEn~lineerSupervisor Form 10-404 Rev 06/15/88 Date ~ -~ -°1 U, SUBMIT IN DUPLICATE~ BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 3-2 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/05/94 12:01 SPUD: RELEASE: 06/23/94 06:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 04/08/94 ( 1) TD:l1920 PB:11764 04/09/94 ( 2) TD:l1750 PB:11635 04/10/94 ( 3) TD:l1750 PB:11635 04/11/94 ( 4) TD:l1750 PB:11635 NU BOPE MW: 8.5 Seawater LOWER DERRICK & MOVE ONTO WELL. RAISE & SECURE DERRICK. MOVE RIG OVER WELL, LEVEL, SET IN SEAH20 CUTNGS & SLOP TANK. RIG ACPTED @ 20:00 HR TAKE ON SEAH20 RU T/CIRC. RU LUB. & PULL BPV. RD LUBRICATOR. CBU TO BAL. WELL ND TREE & ADPTR FLG. CHECK TIE DOWN STUDS. TS T/RT=20.58' BRIDGE CRANE COULDN'T CLEAR TBG.HNGR W/BOPE. DROPPED BTTM RAMS ON STUMP. MOVE BOPE STACK OVER WELL. FLG UP BTTM RAMS T/TBG. SPOOL & SET REMAINING STACK ON & FLG UP. FINISH TESTING BOPE MW: 8.5 Seawater NU 13-5/8 T/5000. TRI RAM BOP STACK. TEST BOPE. RU PULL HNGR. RU LUB. PULL BPV. RD MU LNDG JT. PULL HNGR. & LD. RU T/CBU. GAS & CRUDE IN RETURNS. TOOH. LD COMP. STRING 7" & SSSV. C/O T/5.5 TBG EQUIP. PULL 119 JTS OF 5.5 & 8 GLM'S. LIH= 60JTS & 8 GLM'S. CLEAR FLOOR, PU 5" DP. FNSH TESTNG BOPE. TIH W/JET CUTTER MW: 8.5 Seawater TEST BOPE PU FSHNG ASSY & BHA. TIH PU 5" DP. DBL CUT DL. TIH PU 5" DP T/7745. TAG TOP OF FISH. ENGAGE FISH W/OVERSHOT. PIPE PARTED, TOOH. RCVRD. 12 JTS, 5.5" TBG & 2 GLM'S. TOP OF FISH @8303.83. W/COLLAR LOOKING UP. RU & LD FISH. RU ATLAS WL. TIH W/JET CUTTER. TOOL HUNG UP @10387. IN 1ST. GLM. LD FISH MW: 8.5 Seawater PULL JET SHOT FREE, PU T/10350 & CUT TBG. PULL T/8649 HANGUP IN TOP GLM. WORK FREE, TOOH. RD ATLAS WL. PU SPEAR ON FISH ASSY, TIH T/TOP OF FISH @8304. ENGAGE FISH, TOOH W/38 STDS. THREADS PARTED ON TOP OF NO. 8 GLM. TOP OF FISH @ 8650. PU EXTEN. & SPEAR. SERV. RIG. TIH T/8297, PU DP, KELLY, BREAK CIRC. ENGAGE FISH, SET BACK KELLY, TRIP OUT. W/35,000 # FISH. RU TBG EQUIP. LD FISH. RECEIVED AUG 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL : DS 3-2 OPERATION: RIG : DOYON 16 PAGE: 2 04/12/94 ( 5) TD:l1750 PB:11635 04/13/94 ( 6) TD:l1750 PB:11635 04/14/94 ( 7) TD:l1750 PB:11635 04/15/94 (8) TD:l1750 PB:11635 04/16/94 ( 9) TD:l1750 PB:11635 TRIP OUT MW: 8.5 Seawater LD FISH. RECOVERED 5 GLM. ASSY-35 JTS. TBG & 23' CUT OFF. PU MILLING ASSY. TRIP IN 84 STNDS. PU 55 JTS F/SHED. PU KELLY MILL STUMP 10315 T/10317.5. TOOH W/MILL. LD MILL & JUNK BSKTS. MU OVERSHOT ASSY. TIH T/10317. PU KELLY, BRK CIRC, ENGAGE FISH. SET BCK KELLY. TOOH. CHANGE FISHING ASSY MW: 8.5 Seawater TOOH RECOVER FISH 34', 5.5" TBG CONNECTION BROKE OFF LAST GLM. PU SPEAR ASSY. TIH W/BHA & DP. CUT DL. TIH, PU KELLY. SPACE OUT, ENGAGE FISH. SET BACK KELLY. TOOH. MISS RUN. SPEAR WAS SHEARED. PU NEW SPEAR & BUMPER JARS. TIH W/SPEAR FISHING ASSY. PU KELLY, BREAK CIRC. ENGAGE FISH. WORK UP T/il0000# OVER STRING WT. HITTING JARS, LOST WT. TRIP OUT. LOST GRAPPLE OFF SPEAR. CHANGE FISHING ASSY T/SHORT CATCH OVERSHOT. FISHING W/SPEAR @ 10358 MW: 8.5 Seawater TIH W/8.25X6 OVRSHT. PU KELLY. BRK CIRC. ATMPT T/ENGAGE FISH @10358. TOOH LD OVRSHT. PU MLNG ASSY 3.75Xl.25. TIH. KELLY UP. BRK CIRC. TAG FISH @ 10356. MILL INSIDE FISH T/10370. SET BK KELLY. TOOH F/SPEAR ASSY. LD MILL ASSY. PU SPEAR ASSY. TIH. PU KELLY BRK CIRC. FSHNG W/SPEAR @10358 TOP OFF GLM. PU 9-5/8 BAKER TEST PKR MW: 8.5 Seawater SET BCK KELLY. TRIP OUT W/FISH. RECVR'ED GLM/5.5 PUP/2 JTS 5.5 TBG/5.5 PUP SEAL ASSY BRK & LD BAKER TOOLS. PU & STRAP 3-1/8 DCS & 4.25 MILL 9-5/8 CASG SCRAPER 12 6.25 DCS. JARS 12 HWDP. TIH. PU KELLY. WASH THRU PKR ASSY & TAIL PIPE. PULL BACK ABOVE PBR @ 10484. CBU 3400 STRKS MILL STARTED T/PLUG. REV. OUT. TEST CASG T/3500 LOST 425 TOOH LD DCS & MILL. PU 9-5/8 BAKER TEST PKR. TIH W/FISHING ASSY MW: 8.5 Seawater TIH W/BAKER 9-5/8/TEST PKR T/10478. SET PKR/PRESS ANNUL T/3500. REPAIR SURF. LEAK. TEST F/30 MIN. OK. RIG & CIRC. CLEAN HOLE W/INHIB. SEAH20. SET BACK 50 STDS DP. LD DP & BAKER TEST PKR. PULL WEAR BUSHING. RU WEATHERFORD CASG TOOLS & RUN 5.5 & 7 COMP. STRING. RD WEATHER. TBG EQUIP. RUN IN WEAR RING. MU FISHING ASSY. TIH PICKING UP DP. RECEIVED AUG 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorags WELL : DS 3-2 OPERATION: RIG : DOYON 16 PAGE: 3 04/17/94 (10) TD:l1750 PB:11635 04/18/94 (11) TD:l1750 PB:11635 04/19/94 (12) TD:l1750 PB:11635 04/20/94 (13) TD:l1750 PB:11635 TIH PU DP. MW: 8.5 Seawater TIH W/OVERSHOT PU DP. SET DOWN ON FISH @1359. PU 100K OVER STRING WT. DROPPED 1.7/8 BALL. PU KELLY, PRESS UP T/2000. 2WICE PULLED 14K OVERSTRING WT. ROT. 22 TURNS. RELEASE K ANCHOR. TOOH W/DP T/FISH. RELEASE OVERSHOT OFF TBG COLLOAR. RU WEATHERFORD TBG TONGS. TOOH. LD COMP. STRING T/PKR LATCH. RD WEATH. TBG EQUIP. TEST BBOPE. PU PAKR MILL ASSY. TIH. PU 34 JTS GR E DP. KELLY UP/BRK CIRC. TAG FISH @2412. MILL FISH T/2415 MILL WT DROPPED OFF 5000. PULLED OFF FISH. TOOH F/SPEAR ASSY. RIH THRU MILL AREA, FISH FELL DOWN HOLE. TIH PU DP. FISHING @ 10440 MW: 8.5 Seawater TIH. PU KEL. BRK CIRC. ENGAGE FISH W/PRESS INCREASE, SET BACK KEL. TOOH. NO FISH. LEFT GRAPPLE IN HOLE. LD SPEAR ASSY. PU 4-5/8 MILL ON 15' EXTENSION. TIH T/10414. PU KEL. BRK CIRC. WORK & MILL THROUGH FISH 15'. TOP @ 10440. TOOH F/SPEAR. LD MILLING ASSY. PU SPEAR. TIH. PU KEL. SPEAR FISH @10440. TIH W/SHIFT. FORKS &PKR MW: 8.5 Seawater TOOH W/FISH ON SPEAR, HUNG UP ON BOWL PROTECT. PU RETRIEVING TOOL & PULL PROTECT. RECOVER FISH. LD TOOLS & JUNK FROM X NIPPLE ASSY. PU 3-1/16 DCS & 4-1/8 MILL. RIH. REPAIR HYROLIC LINE, TIH. CUT DL. PU KELY, BRK CIRC, ROTATE & WASH THRU PCKR & TAIL PIPE F/10448 T/10638. PULL BACK OUT OF PKR. CLOSE PIPE RAMS, PRESS CASG T/2000, BLED BACK T/1000. GETTING RETURNS F/9-5/8 ANNUL. TOOH F/TEST PKR & HALIB. SHIFTING FORKS. LD 3-1/8 DCS. & 4-1/8 MILL. PU HALIB. T/SHIFTING FORKS & BAKER TEST PKR. & TIH. RUNNING COMPLETION MW: 8.5 Seawater TIH T/2500. FO CLOSING @2414. SET PKR PRES. T/3500. LEAK OFF. REL'SED PKR. PULLED BCK THRU FO. RIH T/2700. SET PKR @2700. PRES.T/3500/15 MIN. OK. TIH T/10467. SET PKR/TEST CASG T/3500/20MIN. OK. TOOH STD BCK 48 STNDS. DP. LD DP/BHA PULL WEAR BSHING CLOSE BLINDS. TEST CASG. T/INSURE FOS. IS SHUT. OK. RU WTHRFRD T/RUN COMP. STRING. RUN 5.5 17# CR13-80 TBG. COMP STRING. RECEIVED AUG 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL : DS 3-2 OPERATION: RIG : DOYON 16 PAGE: 4 04/21/94 (14) TD:l1750 PB:11635 04/22/94 (15) TD:l1750 PB:11635 04/23/94 (16) TD:l1750 PB:10852 04/24/94 (17) TD:l1750 PB:10852 04/25/94 (18) TD:l1750 PB:10852 ND BOP STACK MW: 8.5 Seawater RAN 5.5 & 7" 13CT80 COMP. STRING. T/SSSV. MU 7" CAMCO SVLN SSSV. CONECT CNTRL LINES, TEST T/5000. CON'T RUN'NG T/EXISTING PBR @ 10884. RU CIRC SWEDGE LINES. CIRC WHILE LOCAT. TAILPIPE ASSY IN POLISHED BORE RECEPTICLE. PRES. INCREASE CONFIRMED LOCAT. RD SWEDGE LINES. SPACED OUT. INSTAL TBG HNGR/CNTRL LINES. TEST LINES T/5000. DROPPED SET'NG BALL/STEM ASSY. INSTAL BLANKING PLUG IN HNGR. MU LNDG JT. LAND COMP STRING/TBG HNGR IN WELL HEAD. RD OTIS & TBG RUN'NG EQUIP. ND BOP STK. SET BK . HAD T/DROP OUT BTTM RAM ASSY DUE T/HEIGHT CONSTRAINTS W/TBG SPOOL. RIG RELEASED MW: 8.5 Seawater COMP. ND BOP STACK & SET BK. NU ADAPTOR FLANGE/X-MAS TREE/CONTROL LINES. TEST T/5000. RU LUBRICATOR. PULL BPV/RD LUBRICATOR. RU TOP TREE ADAP. PRESS COMP STRING T/3500. SET PKR/TEST COMP STRING/30 MIN. PKR SET @ 10436. TEST ANNUL. T/3500/30 MIN. W/1700 ON TBG STRING. BLED OFF PRESS. PRESS THE ANNUL. SHEAR OUT RP VALVE W/2975. FRZ PROTCT T/2000 W/127 BBLS DIESEL. SECURE TREE. INSTALL BPV. RELEASE RIG @ 16:00 HOURS 4/21/94. NIPPLE UP BOPE MW: 8.5 Seawater MOVE RIG AROUND PIT F/DS-3-26. TAKE ON SEAWATER, RU ON TREE T/CIRC. RU LUBR. PULL BPV. CIRC OUT FRZ PROTECT. CBU. OBSERVE WELL. SET 2-WAY CHCK. ND TREE & ADPTR FLNG. NU BOPE. LD COMP STRING MW: 8.5 Seawater COMP. BOPE RIGUP. ATTEMPT TEST ON BLIND RAMS. API RING LEAKED BETWEEN TBG SPOOL & BOP'S. WOULDN'T TIGHTEN UP. REMOVE BOP STACK & REPLACE RING. TEST BOP'S. LEAK BETWEEN MUD CROSS & BLIND RAMS. RD BOPE & REPLACE RING. NU BOPE. 2-WAY CHK LEAKED. MU LNDG JT ON HNGR. TEST HYDRIL T/2500. OK. CLOSED TOP RAMS. TEST BOP BODY & CHOKE MANIFOLD/OK. THREAD ON LNDG JT LEAKED. PULL JT. VARIANCE T/COMP. TEST WHEN OUT OF HOLE W/COMP STRING GRANTED. INSTALL LUBR. PULL BPV. MU LNDG JT. PULL & REMOVE HNGR. PULL & LD COMP. STRING. TIH W/OVERSHOT EQUIP. MW: 8.5 Seawater LD COMP STRING. CLEAN TBG EQUIP. & FLOOR. RD TBG RUNNING EQUIP. SET TEST PLUG. CHANGE RAMS AROUND. INSTALL SHEAR RAMS. TEST BOPE. RUN WEAR BUSHING. RD TEST EQUIP. PU FISHING ASSY, 12 6.25 DC'S & 3.5 DP. RECEIVED AUG 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL : DS 3-2 OPERATION: RIG : DOYON 16 PAGE: 5 04/26/94 (19) TD:l1750 PB:10852 04/27/94 (20) TD:l1750 PB:10852 04/28/94 (21) TD:l1750 PB:10852 04/29/94 (22) TD:l1750 PB:10852 04/30/94 (23) TD:l1750 PB:10852 CUT & SLIP DL MW: 8.5 Seawater TIH W/OVERSHOT PU 3.5" DP. MILL OVER FLAIRED END OF TBG T/HOLLOW MILL @ 10371. TOOH. NO FISH. CHANGE OVERSHOT CONFIGURATION. TIH PU KELLY TAG FISH @10371. MILL OVER FISH T/10379. TOOH, RECOVER CUTOFF JT/PUP X/NIPPLE/2 PUPS/LATCH LD OVRSHT ASSY. PU PCKR MILLING ASSY. RIH. CUT & SLIP 57.5' DL. LD FISH. MU OVERSHOT ASSY MW: 8.5 Seawater TIH W/MILLING ASSY. PU KELLY. BREAK CIRC. TAG FISH @10436. MULL 9-5/8" PKR T/10442. TOOH. LD ASSY, CLEAN BOOT BUCKETS & LD. PU SPEAR ASWSY & TIH. PU KELLY. TAG FISH @ 10442. TOOH W/FISH. LD SPEAR ASSY & MU OVERSHOT ASSY. TOOH W/PACKER MW: 8.5 Seawater TRIP IN W/OVERSHOT ASSY. PU KELLY. TAG TOP OF FISH @10485. FISH SAME. TOOH. LD FISH. CHANGE BHA T/PCKR MILLING ASSY. W/PRT. TIH W/MILLING TOOL. TAG PACKER @ 10485. MILL ON PACKER 10500 T/10503. PACKER MOVED DOWN HOLE. CBU. GAS @ BTTMS UP. PUT THRU CHOKE. TOOH. PCKR HANGING UP. TRIP OUT SLOW. WASHOVER FISH @10732 MW: 8.5 Seawater LD FISH. CLEAN BSKTS, PU SPEAR ASSY. SLIP & CUT DL. TIH PU 3.5 DP. KELLY UP TAG FISH @ 10665. POOH LD FISH. RECOVERED TBG COLLAR, PUP 1 JT TBG & COLLAR. LD SPEAR ASSY. PU OVERSHOT ASSY. TIH. PU KELLY TAG BTTM @10695. TRQ PROBLEMS DOWN HOLE. TOOH RECOVERED 1 JT TBG - BAD. LD OVERSHOT ASSY. PU 1 JT WASH PIPE W/WASH OVER SHOE. TIH WASH T/BTTM. TAG @ 10701. FISH TOP @ 10732. PUMP VIS SWEEP. RIH W/8.5" MILL MW: 8.5 Seawater WASHED DOWN W/BURNING SHOE/WASH PIPE ASSY 10701 T/TOF @ 10729. CBU POOH W/WASH PIPE ASSY & LD. PU 8.5" MILL. MU BHA. RIH T/10660. WASH T/TOF @ 10729 - 10750. NO PROGRESS. POOH/INSPECT MILL. EMPTY BOOT BSKTS. RECOVER 16# METAL-NO GRAPPLE. SLIP & CUT DL. PU NEW MILL W/3 BOOT BSKTS & RIH. R£CEIV£D AUG 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL : DS 3-2 OPERATION: RIG :DOYON 16 PAGE: 6 05/01/94 (24) TD:l1750 PB:10852 05/02/94 (25) TD:l1750 PB:10891 05/03/94 (26) TD:l1750 PB:10898 05/04/94 (27) TD:l1750 PB:10898 05/05/94 (28) TD:l1750 PB:10898 POOH W/REV CIRc. JET BSKT MW: 8.5 Seawater RIH W/MILLING ASSY T/10750. REV. CIRC HOLE CLEAN. RECOVER CMT/METAL. MILL UP JUNK, CMT F/10750 T/TOP OF SAND PLUG @10857. CON'T MILL UP JUNK & SAND T/10876. DECREASE IN MILL RATE/PUMP HI VIS SWEEP T/CLEAN HOLE. POOH F/REV CIRC JET BSKT. MILL WAS .5" UNDER GUAGE. 70% WEAR. 35# METAL RCVRD. PU 8.5" REV CIRC JET BSKT. MU BHA. RIH T/10826. POOH W/REV CIRC BSKT ASSY T/PU BIT. RIH W/REV. CIRC JET BSKT MW: 8.5 Seawater COMP POOH W/REV. CIRC. JET ASSY. PU 8.5 MILL TOOTH BIT. MU BHA W/NB STAB. RIH ON 3.5 DP T/10814. MU KELLY CBU. RECOVER CMT. POOH W/BIT LD STAB. PU REV CIRC, MU BHA. RIH T/10831. MU KELLY. POOH W/REV CIRC JET BSKT. SLIP & CUT DL. MU NEW ASSY. TESTING CASG MW: 8.5 Seawater RIH T/10814. MU KELLY. WASH DOWN T/TOP OF FILL @ 10891. CLEAN SAND OFF F/10891 T/10898. POOH W/REV. CIRC JET BSKT. RECOVER SMALL CHUNKS OF CMT. TEST BOPE EQUIP. WITNESS BY J.SPAULDING, AOGCC REP WAS WAIVED. PU 8.5" BIT, MU CASG SCRAPER, BHA & RIH T/10840. CBU. POOH W/BIT & SCRAPER. LD. CLEAN PITS WHILE POOH. MU 9-5/8" RTTS. TEST PKR. RIH T/10835. SET PKR @ 10835. FLUID LEAKING BY PKR. PU T/10815. RESET. PRESS UP T/3500. BLEED OFF T/3000 IN 15 MIN. HELD @ 3000. RUNNING COMPLETION MW: 8.5 Seawater TEST CASG F/10815. BLEED PRESS CHECK SURF. LINES. NO LEAKS. PU T/PKR SETTING !@ 10455. TEST CSG T/3500. OK. CSG LEAKING IN MORE THAN 1 AREA BELOW 10600. DISPLACE HOLE W/INHIB. SEAH20. POOH W/TEST PKR. LD DP. PULL WEAR BUSHING RU T/RUN COMP. RU OTIS T/RUN CNTRL LINES MW: 8.5 Seawater RUN COMP/JT COUNT SHOWED DISCREPANCY. 4) 5.5 JTS OMITTED BETWEEN GLM 5 & 6. POOH LD TBG T/GLM 9. ADD 4 JTS TBG BELOW GLM. DISCUSSION W/OPS ENG. REP INDICATED THIS WOULD BE SUFFICIENT T/ALLEVIATE POTENTIAL GAS LIFT DESIGN PROB. RESULT: GLM 1-5 ON DEPTH W/PROGRAM. 6-8 ARE LOW T/PROGRAM & 9-10 ARE ON DEPTH. CON'T. T/RUN 5.5 7" COMP T/SSSV. RU OTIS T/RUN CONTROL LINES. R£C£1V D AUG 0 1994 Oil & Gas Cons. Commission Anchorage WELL : DS 3-2 OPERATION: RIG : DOYON 16 PAGE: 7 05/06/94 (29) TD:l1750 PB:10898 05/07/94 (30) TD:l1750 PB:10852 05/08/94 (31) TD:l1750 PB:10898 RIH W/WL T/RETRIEVE BALL MW: 8.5 Seawater MU SSSV INSTL CNTRL. LINES. TEST T/5000. RUN 5.5 7" COMP T/PKR SET'NG DEPTH DROP BALL/BAR. MU HNGR/LNDG JT/H/U CNTRL LINES & TEST T/5000. LAND COMP STRING/TBG HNGR IN TBG SPOOL. RILDS. L/D LNDG JT. SET 2-WAY ND BOP STACK. NU X-MAS TREE. TEST TREE/HNGR T/5000. RU LUBR. PRESS STRING T/4000 T/SET PKR. RTRNS ON ANNUL/PRESS BLED OFF 800 IN 30 MIN. PRESS ANNUL T/900. FULL RTRNS BALL/BAR DIDN'T REACH XN NIPL/PCKR DIDN'T SET. TRY T/FREE BY FLUSHING DOWN TBG THEN CASG ONCE MORE. SUSPENDED OPS T/PREVENT EXCESS FLOW PAST PKR. CON'T T/PRERARE F/RIG MOVE WHILE WAITING ON WL UNIT. RU WL LUBR. RIM RETRV DUMMY VALVE IN SSSV. RIH W/WL TO FIND BALL/BAR. RETRIEVE EQULZNG DUMMY MW: 8.5 Seawater RIH W/SL T/OBSTRC'N @ 8475 WLM. WORK LINE, CONT RIH T/RHC PLUG IN XN NIP'L PRESS TBG/BLED OFF SAME RATE/POOH RECOVER BALL. SET PLUG IN SWS NIP'L ABOVE PKR T/ISOLATE COMP. STRING. PRESS/LEAKOFF SAME. PULL RP VALVE IN TOP GLM. REPLACE W/DUMMY VALVE. PRESS/BLEED OFF IS SAME. RP VALVE WASN'T SHEARED. RD OTIS. RU SCHLMBRGR. MADE SPINNER TOOL. LEAK IN LOWER MOST GLM W/DUMMY EQLZNG VALVE. RD SCHLMBRGR. RU OTIS T/PULL EQLZNG DUMMY/COUNDN'T FIND. PULL PLUG F/SWS NIPPLE. C/O TOOL TYPE & RIH T/RETRIEVE DUMMY EQLZNG VALVE. RIG RELEASED MW: 8.5 Seawater COMP RUN T/RETRV PRONG F/DUMMY EQLZG VALVE. DIDN'T WORK. REDRESS TOOL, ADD IB. WENT T/LOWER MOST GLM. INSPECT IB/PRONG MIS'NG F/EQLZNG VALVE. MU PLUG RETRV TOOL T/KICK OVER TOOL. RETRV EQLZNG VALVE ON 2ND ATTEMPT. SET DUMMY VALVE IN LOWER MOST GLM. W/TBG OPEN TEST ANNUL T/3500/30 MIN. NO PRESS LEAKOFF. DROP BALL/PRESS TBG STRING T/3700. LEAKOFF T/2900 15 MIN. NO RTRNS ON ANNUL. BALL NOT SEATED CORRECT. IN RHS PLUG. BLED OFF PRESS. REPLACE DUMMY PLUG W/RP VALVE IN UPPER GLM. RD OTIS. PRESS ANNUL T/3000 T/SHEAR OUT RP VALVE. FRZ PRTCT ANNUL/TBG T/2000 W/DIESEL. SET BPV. SECURE X-MAS TREE. MOVE RIG OFF. RELEASE @18:00 HRS. 6/23/94. SIGNATURE: (drilling superintendent) DATE: ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Transmittal #: 94054 P.O. Box 100360, . ',horage, AK 99S10,~~, '4~ska Oil & Sas Cons. C°rn~ission Well ~Log Date Numberi (M-D-Y) '~O--]i({O ~ 1-05ST [ 6-21-94 ~-i,,,,Ocr f 1-17 i 6-20-94 ~Z- [...Zq ! 2-20 i 6-18-94 c~O~i~Z2.."' ~ 2-28 ! 6-28-94 :, Tool Type Prod Prof Run, Sc~e / Prod Prof I IBP Settin(:j Rec Leak Detection' Contractor 1, 5II 1,1 "&5" SCH i SCH 1, 5" SCH 1,2" & 5" SCH scH SCH SCH SCH 3-2 ~ 6-22-94 4-2 I 6-17-94 I 4-30ST, 6-25-94 4-40 ~ 6-25-94 4-43 ! 6-23-94 i 4.44 [ 6.20-94 4-45 6-25-94 5-03A 6-9-94 5-03A ~ Leak Detection ~" Patch Set Rec I ? Perf Rec ! ./ Perf Rec ! .- Comp Rec · ] / PerfRec ] ,"'" Perf Rec !" CDN Slim I GR 1,1 "&5" , 5II 1, 5" 1,5" , 5II SCH 1, 5" SCH 1, 5" SCH 1,2" &5" 1, 2" &5" SCH SCH i 6-9-94 \~ 5-03A I 6-9-94 5-13 i 6-17-94 l .- Leak Detection 5-33 [ 6-29-94 -' Perf Record 6-8 I 6-15-94 TDTP 6-12A 6-24-94 ~- Perf Rec f 7-6 ! 6-28-94 f PerfRec ! 7-26 f 6-19-94 PerfRec 9-05A f 6-21-94 f PerfRec 9-05A !'6-22-94 / Perf Rec 9-30ST~ 6-29-94 '" DuaI Burst i 11-6 6-22-94 -~'Pmd Prof ~ 11-29i 6-27-94 .-" Perf Rec 12-02 ~ 6-28-94 t,,-" Prof 12-7A ! 6-27-94 -"Leak Detection 12-19 6-27-94 Prof ~ 12-23 6-28-94 Prof 12-28 ~ 6-27-94 Prod Prof ~t---i 13-08 ! 6-30-94 ~' Perf Pmf 14-24 f 6-15-94 ~ CNL ~ 14-39 f 6-19-94 Detection 14-39 ~ 6-19-94 Leak Detection c/7-- ~,2.-- ~ 16-28 f 6-20-94 ] / PerfRec CDR 1, 2"& 5" SCH 1,1" & 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1,5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, l"& 5" SCH 1, 5" SCH 1, 5" SCH SCH 1,5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 1" &5" SCH 1, 2" SCH 1, 5" SCH * DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompmty ARCO Alaska, Inc. Date: Subject: From/Location- Telephone: To/Location: June 21, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Number j 1-05ST 1-06 1-25 1-29 -3o 3-19 4-36 5-11 ~ 9-18 ~ 9-25 11-36 j 13-31 13-35 14-03 14-03 16-23 16-23 17-02 18-02 18-04 18-19 Transmittal #: P.O. BOX 1'00360, /.,,¢.horage, AK 99510,~~ 94049 ILog Date Type (M.D.y) i Tool ua .ur t 6-13-94 I / Dual Burst 6-14-94 1' Perf Record !, Reco 6-14-94 !"" Dual Burst ! 6-08-94 1/ CNL 6-07-94 i,,' Tubincj Cutter ! 6-05-94 i-/ Perf Record 6-11-94 !'"'- Perf Record 6-12-94 1 ,-"Cutter Record 6-11-94 I" Dual Burst 6-13-94 t / InjProf 6-14-94 I / Inj Prof 6-i4-94 i -/ injProf 6-11-94 I f Perf Record 6-07-94 t /' Perf Record 6-09-94 i ~ Perf Record 6-09-94 1/ Perf Record Run,~ 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" I 5" 1 5" I 5" 1,5" 1,5" 1 5" i 5" I 5" 1 5" I 5" ! 5II 6-15-94 ! ,~ Prod Log ! 1, 5" 6-15-94 ! ~. Dual Burst I 1, 5" 6-13-94 l~'Leak Detection ! 1, 5" 6-10-94 i f Alpha Tubing i 1, 5" 6-6-94 if ProdProf i 1,1 "&5'' 6-12-94t / Perf Record i 1, 5" ! 6-12-94 If DualBurst l 1,5" 6-10-94 ft_eak Detection 1, 1" & 5" Contractor Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch * The correct AP! # for 1-05ST is 50-029-20076-00 Number of Records: E. DoGroy Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska- ARCO Alaslm, Inc. Is a Subsldla~/of AllantlcRIchfleidCompany ARCO Alaska, Inc. Date: Apr 14, 1994 P.O. Box 100360, ~-. _borage, AK Transmittal #: 94034 99510,~ ~, Subject: From/Location: Telephone: To/Location: ARCO Cased Hole Finals John. E. DeGrey/ATO- 1529 (907) 263-4310 Distribution ~ Well ...Number c[~..~ 01-09A 77--5'7i; 01-11 ~ ~-17.~.; 01-33 o3-ol Log Datei (M-D-Y)1 04-02-94 iv' Per[Record 03-25-94 i TDT-P 03-28-94 !/, 03-27-94 Contractor i 7t~-7,q i 03-02 03-22-94 q S-~ ?..! 03-19 03-22-94 -'/q .~03-29 i 03-18-94 t .~'",, 03-29 03-27-94 f ~'q-~7..i 03-31 03-27-94 Tool Type i Run, f Scale i I 5" I 5" 1 5" 1 5" TDT-P Perf Record Leak Detection Bridge Plug Leak Detection Bridge Plu,g Bridge Plug 03-29-94 i TDT-P 04-43 03-29-94 i/ CNTG [ 03-10-94 !/ USlT 04-44 i 03-13-94 iv' USIT Sch Sch Sch i , ~ Sch ~ Sch i Sch .! Sch [ Sch Sch Sch 04-45 i 03-29-94 ! .,' USIT Cement 05-08 i 03-14-94 Iv' Prod Profile 06-19 i 03-18-94 i,/ Per[ Record 07-08 ! 04-03-94 ? Per[ Record i 1 5" , i 1 5" i 1 5" i I 5" i' 1 5" 07-23 i 03-21-94 i'/ Bridge Plug i 1 5" 09-01 103-30-94 1,,' Prod Profile i 1, 1"&5" Sch 09-02 i 03-17-94 i,/ Prod Profile i 1, 5" Sch 09-03 i 03-29-94 ' 1 / Prod Log [ 1, 1"&5" 09-19 i 04-01-94 1¢' Perf Record i 1, 5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch <~S- 2..~ 09-27 i ~,- (¢0i 11-04i ~l,.?qi 11-17 ~ ~5 Z0~ 11-24A ~ ~-~ 12-06A ~Z-~ 13-20 ~-'57.. i 14-03 !//14-28'" ~1 8 i'~14-28. §5-FIZ_-' 14-35 ~2-'t 5~ 16-04A i 03-16-94 i,/ Prod Log ! 1, 5" 03-22-94 i" Per[ Record i 1, 5" 03-16-94! ," Patch setting ! 1, 5" 03-29-94' ~,/ Per[ Record i 1, 5" 03-18-94~" Prod Profile I 1, 1"&5" 03-15-94 i~' Leak Detection i 1, 1"&5" 03-28-94 i" CNL i 1, 5" 03-19-94 i / Prod Profile ! 1, 1"&5" 03-15-94 i./Leak Detection I 1, 5" JVC' ~ ~ 03-28-94 ! Patch Setting ! 1 5" 03-21-94 !/ Bridge Plug i 1, 5" iv" CNL ~ 1, 5" Sch Sch 03-17-94 Sch 03-15-94 i¢ Per[ Record ~ 1, 5" I sch 16-18 i 03-14-94 i¢-'Leak Detection i 1, 2"&5" i Sch ~ ~ ~ J 16-28 i 03o14-94 ~ ~ Per[ Record i 1, 5" ~ 5" 18-08 i 03-20-94 i,/ TDT-P ~ 1, Number of Records: 38 ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany ARCO Alaska, Inc. Date: Subject: *From/Location: Telephone: To/Location: P.O. Box 100360, ~horage, AK Jan 28, 1994 Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 94016 i Well i Log Datei Tool Type Run, I Contractor I Nurrberl (M-D-Y) I P0(~L~,~ ~ + Sca,l~ ! i,,,! tSch 7'N5~i 1-11 I 1-14-94 ! Perf Record i 1, 5" ~--!~l 1-22 ! 1-13-94 ~ Bridge Plug ~r~ (/al, 5" ~'0-2..~I 2-29A ! 1-18-94 t CNL f~ 1,5" ;f¢-&q [// 3-2 I 1-19-94 ih\ Bridge Plug O~ 1, 5" I ~ 3-2 'i 1-15-94 i LeakDeterminlF~tP~, 5"/T'~J~ '7/~-~I 3-16 ~ 1-10-94 i Perf Record i - 1, 5" Number of Records:24 DoGroy 3-22 3-22 ! ~,3-22 3-35 3-36 ! 4-13 5-35 5-35 9-13 9-30st 11-12 2-16A 15-7 15-7 17-13 ~ 18-1 f 1-19-94 1-16-94 !0\ Bridge Plucj iL~,~ 1, 5" ! Leak Determin t¢~-S !. ~du~'; 'T~ Sch Sch Sch Sch Sch Sch sch' t~ Sch ,~,(¢~ch r~. i ' Sch ~l~,.c..h '~ch Sch 1-10-94 l 1-21-94 l 1-20-94t Prod 1-15-94 t Ini Profile 1-18-94 t IBPSettin¢ 1-18-94 I Prod 01-14-94 Leak Detect 1-22-94 Leak Detect !~?~/ Perf Recordf" 1, 5 1-19-94 I Leak Detect 1-17-94 ! Tubing Cutter i Coml Record 1-22-94 Cutter 1-17-94 Puncher 1-8-94 Patch Settinc 1-20-94 Dual Burst TDTP PBOE Document Control i 1, 2"&5" Sch Sch Sch 1, 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1, 5" Sch Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ~:~state 'of Alask~ Mobil ..>, .~.~. - ..... ~ RECEIVED FEB O 1 1994 Alaska 0il & Gas Cons. Commission Anchorage Please acknowledge receipt by signing and retuming a copy of transmittal. By: ,.~/t~m~J~'~-~ ~ Date: ARCO Alaska, Inc. Is a Subsidiary o! AtlantlcRlchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-1-92 REFERENCE: ARCO CASED HOLE FINALS 1-4 3-24-92 Prod Profile 3-2 3-19-92 Prod Profile 3-10 3-20-92 InJ Profile 3-17 3-21-92 Inj ~o~e 3-22 3-20-92 ~od ~o~e 3-24 3-22-92 ~od ~o~e 4-1 ~ ~ ~ 3-23-92 ~od ~o~e ~-~_~ 3-23-92 G~Je~~ - 3-23-92 ~od ~o~e 9-471-~° 3-2~92 ~od ~o~e 9-6 3-20-92 ~od 11-4 3-30-92 ~od ~o~e 11-12 3-22-92 ~od ~o~e 11-24 3-23-92 ' ~od ~o~e 12-20 3-23-92 ~j ~o~e 18-163~-?/3-24-92 PITS R"n 1, 5" Camco Run 1, 5" Camco R;m 1, 5" Camco R~m 1, 5" Camco R,_m 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco R;m 1, 5" Camco R-- 1, 5" Camco R-n 1, 5" Camco Run 1, 5" Camco R-n 1, 5" Camco R~n 1, 5" Camco 'R~_m 1, 5" Cmnco R~n 1, 5" Camco Run 1, 5" Camco Please sign and return thee attached copy as receipt of data. RECEIVED BY_~~"~ ~ H,.,. Am , ny: R E C E IV E D Sonya Wallace APPROVED ATO-1529 MAY l l 1992 Trans#9209~' ....... Alaska Oil & Gas Cons. Commissiori Anchorage # CENTRAL FILES # CHEVRON D& M # EXTENSION EXPLORATION # EXXON MARATHON # PHILLIPS PB WELL FILES R&D # BPX # STATE OF AI2~KA TEXACO # MOBIL ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS [5.345.34 12-18 1-264F2 13-16 13-19 2-9-92 17-1 1-~ Production Profile Run 1, Static Tempemtur~ la~ L InJ proffie l~m 1, ~'~' Leak ~ Run 1, Jewelry ....... l~m 1,~' Prod Profile Run 1, I2ak Detect .. . -;.. Run 1, Prod Profile ~ 1, Prod Profile Run 1, In] Profile Run 1, In] Profile . ..... ~ 1, InJ Profile Run 1, InJ profile ~ 1, InJ profile Run 1, Prod Profile Run 1, Prod Profile ]~m 1, Please sign and return the attached Copy as receipt of data. RECEIVED BY CKlnco camco CAInCO ~co ~co ~co ~co ~co Have A Nice Day! Sonya Wallace ATO- 1529 RECEIVED "....~,....APRd,,. 01 1992 · ' ,l~Oil & Gas Cons. Commission APPROVED__~_"'_____Anchorage Trans# 92052 ~ · # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL ' * The' R-n Date on this log is 1-23-92. PB WELL ~ R&D # BPX # STATE OF ALAS~ TEXACO STATE OF ALASKA ALASKA! ~. AND GAS CONSERVATION CC '/~iSSION ta REPORT'OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown -~. Stimulate X Plugging -.- Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1903' FSL, 688' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1318' FSL, 4390' FEL, Sec. 10, T10N, R15E, UM At effective depth 1361' FSL, 4791' FEL, Sec. 10, T10N, R15E, UM At total depth 1369' FSL, 4839' FEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stra~graphic 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit feet 8. Well number 3-2 9. Permit number/approval number 76-24 10. APl number 50 - 029-20203 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11750 feet 9382 feet Effective depth: measured 11635 feet true vertical 9286 feet Casing Length Conductor 78' Surface 2635' Production 11661' Plugs(measured) Size 20" 13-3/8" 9-5/8" Junk(measured) Cemented 300 sx PF II 5400 sx PF II 1100 sx CI 'G' & 105 sx PF II Measured depth True vertical depth 78' 78' 2696' 2696' 11722' 9399' RECEIVED Perforation depth: measured 11020-11044' true vertical 8791-8810' Nu V - 4 19911 Alaska 0il & (~as Cons. Commission Anch0ra,qe Tubing (size, grade, and measured depth) 7", 29#, L-80 to 2804' MD; 5-1/2", 17#, L-80 from 2804-10630' MD Packers and SSSV (type and measured depth) 7" Otis RPB SSSV @ 2234' MD; Baker SAB packer @ 10520' 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data _ OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2875 8637 9697 9437/" 17692 229 Tubing Pressure 357 396 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ._.. 16. Status of well classification as: Oil x_.~_ Gas-- Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -.. Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 76R/6 DCR/MRM cc; RW: .IWP DS 3-2 DESCRIPTION OF WORK COMPLETED TUBING PATCH, CTU CEMENT SQUEEZE, & ZONE 4 FRACTURE TREATMENT 3/16/91: Ran a Leak Detection Log indicating a tubing leak at 3065' MD. 4/1 8/91: MIRU & PT equipment to 4000 psi, then RIH w/CT & washed tubing above leak from 2800 - 3000' MD. Pumped 100 bbls of Hot Water, then 10 bbls of 15% HCI w/10% Xylene. Displaced w/Meth Water. Rigged down. 4/22/91: RIH & set a 5.5" OD (3.0" ID) tubing patch from 3056 - 3076' MD (seal to seal) over leak at 3065' MD. POOH. Rigged down. 4/24/91: A Water Shutoff CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4500 psi, then RIH w/CT & fluid packed the wellbore w/seawater. Pumped 75 bbls of PYA cement, squeezing the perforations (located above cement plug), at: 10973 - 11010' MD (Z4) 11020 - 11044' MD (Z4) 11054 - 11088' MD (Z4) 11100 - 11140' MD (Z4) 11156 - 11180' MD (Z4) Ref. Log: BHCS 5/1/76. Placed 8 bbls of cement behind pipe & held 3500 psi maximum squeeze pressure for I hour. Contaminated cement & cleaned out contaminated cement from wellbore. POOH. Rigged down. 5/6/9 1: MIRU & PT equipment to 4000 psi, then RIH w/CT & pumped 40 bbls of Sand Slurry (20/40 mesh sand), on top of the cement plug, to place a pre-frac sand plug to 11086' MD. Rigged down. 5/26/91: Reperforated: 11020 - 11044' MD (Z4) Ref. Log: BHCS 5/1/76. 6/2/91: MIRU & PT equipment to 8000 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the open perforations above the sand plug (listed above). Pumped: a) 500 bbls Pre-Pad, @ 40 bpm, followed by b) Shutdown. ISIP @ 2022. Resumed pumping: c) 319 bbls 40# Crosslinked Pad w/5% Diesel, @ 25 bpm, followed by d) 355 bbls Cross Linked Slurry, @ I - 10 ppg, followed by e) 312 bbls Flush, followed by f) Shutdown. ISIP @ 2640. Placed a total of 65,000 lbs of Proppant into the formation. Rigged down. 6/5/91 - 6/13/91: Performed proppant fill cleanouts to 11120' MD. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Returned well to production & obtained a valid welltest. A scale inhibition treatment is pending. ARCO ALASKA, INC. P.O. BOX tee360 /--% ANCHORAGE, ALASKA 995' --DATE: 8-2-9t REFERENCE' ARCO CASED HOLE FINAL£ 1-4 · 3-t6-9t 2-3. 5-22-9t 3;-2 · 4-22-9i 3;-2 · 5-26-9i 3-22 · 7-t3-9t 3;-27- 3.t5-9t 7~ 5-27' 7-t 3-9t ~' c/5-i ~_.L' 7-t 4-9t 7-4' 6-22-9i 7-23- 3-30-9i 7-28- 5-25-9t 9-4- 5-t 6-9t 9-8- 5-i -9i -35' 7-i 4-9i -43. '7- t 5-~ ~ 9-46- 5-6-9i ** t t-25- 7-t 4-9t *** t6-9A · 6-3-9t F'ERF RECORD PERF RECORD CCL PERF RECORD PDK-tee/GR/CCL RERF RECORD PDK-tOO/GR/CCL CNL COLLAR LOG RERF RECORD COLLAR LOG TUBING PATCH PERF RECORD PERF RECORD ' RDK-tOO/GR/CCL-BORAX CCL-PERF RECORD JEWELRY-COMRLETION RECORD PERF-JEWELRY RECORD CNL PERF RECORD RUN i, 5" RUN t, 5" RUN RUN t, 5" RUN t, 5" RUN t, 5" RUN t, 5" RUN t, 5" RUN t, 5' RUN RUN t, 5' RUN t, 5" RUN t, 5" RUN RUN i, 5' RUN t~ 5' RUN RUN RUN t, 5" RUN t, 5" PLEASE J~IGN AND RETURN ]'HE ATTACHED COPY A$ RECEIPT OF' DATA. RECEIVED BY~~~_____~ HAVE A NICE DAY! $ONYA WALLACE ATO-t529 AF'F'ROVED~ TRAN$$ 9 HL$ HL$ HLS HL$ ATLAS HL$ ATLAS &'CH HL$ HL$ HL$ HL$ HL$ HL$ ATLAS ATLAS' HL~' HL$ $CH HL$ DISTRIBUTION CENTRAL FILE~¢ CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R& D BPX STATE OF ALASKA TEXACO £C£I Com.. * THE CORRECI'ED LOG INTERVAL FOR 9-46 I$ i4488'-iSt60', ** THE CORRECTED AP l$ FOR tt-25 I$ 50-029-20488-8t. *** THE CORRECTED API~ FOR i C-gA IS 50-029-205~8-0i. ., /.o/ ! .. 3'"' '''~ '":' .... ":' '::~'''' 9 'i L.~i:' t::', K k) iii] ~ ;::' C'i" .[ 0 N a.. ;.2 :.'.. / ~ ,.. :.!' ..-. !!Y- 4 ..... i 6 .... 9 '! C 0 !... t... A R /F:'iii: i:.'.: i:: S ..... i 6 4 .... '?'...- ? 'i I N ,.! !ii] (."; 'l" i (ii N '"~' .... ':' 'i 4 ..... ~ ;3""'":;' 'J "' f';I ..... ' '""': ...... ' :" I. ........ L..tql"..,- I" I::.l",J' · .:...'.. ~ · ., ..., . --.- ? .... , , .t.,. J ,.. ....... ':':' '-'- "i "",i 2. '.'" '? '" 5 A b," I....[ F' 'T' J":~ A f'.* '"' :" i:: i :".. ,":' ..... ('"l ', ..., ,'".. D iii""" '! 4 'i .... 2 ':':~- .... 9 i !::' E F-: F' R E C 0 F.'. D ,.:., ..-- 4 4 .... :; ':': .... 9 'i tS'" ill ...... L..' f:.",' ' :': / F:' !:il '"' 1::' .... ! ...,' i ,1 o., .........." 4, J!: 3 ,:.."'> 8 9 '~ '.[,;'4. ,.,~::,_ ,.,:" ':". i 0 9 .... '~ ./.'~ 4 .... 'f ? .... 9 "i C 0 L.. L. A F;..' / P I:[ ~:'.: F:' '~ 'i .... i,...'?' ,.."~;- ,.;."" .::?, .... o,. ~ pRf'..... P~ ...... t T ]. i'..~"-~,.. ~ ~ .... :i S ..!'.'; .... 3 :")"" 9 'i F:' F;..' 0 D U C '!" I C! N 'i ' ~ .... ;::~'f:; ":. ..... i 6 .... 9 '1 r';" s... , ......", I .... to.. 'i 2 .... 'i 7 ::~.... ~:!; .J .... 9'1 F' R 0:0 U C'I" :I: 0 · i2 .... 'i'7 4 ..... !~!:-9'i CCL.. '~ ?. ..... ':, 8 4 .... ~, .... ? 'i 1"'t;.'. 0 D ij C: T I 0 N · i '"' .... '::,) .... ~ 'd '1 ,, ~. ~.. L.. A R .," I::' t![ I:;..' !::' ,...: '1 :.. 4 '~ "' ...' 9 ;","il '! 2.... 2 'i ";' .... 6 .... 9 'i I::' Ii-: R t:.' F;.'. E C.:O 1:;.'. g 'j 4 --- 'i ~ ..... J ? ..... 9 'i i::' lii:R F' F;..' Iii: C: 0 R D 'i 6 "-' 5; k."; "" 2 '? "-' 9 'i I N ._t E C: T I 0 N '! ":.-"'"' 6 Li!: --' ~ g - 9 '~ ........ I N ,J E C: T I 0 iq D A'¥'A~ ,'f H A I:;.' 0 i'..! t,,J I !... S 0 i'..! A'T 0 .... i [} 2 ? I) I ,S; T R :!: B L.I T ]: 0 N A I::l I::' R 0 V ii!: D C E N T R A L. F' I L E $ :~: F:' !"! .[ I.. I... Ll: F:' $ C;t"lli[VRON PB WEL. I.. F'I!...ES' J[::, & M I:;.'. & D [:. X T E N 210 N E. X F'L 0 R A T I 0 N :Il: B P X E X X 0 N :~ ,:.:.: 'i" A T E: UF' A L. A 5' K A H A F:.'. A l'H 0 N T E: X A C 0" HOB I L :.":' T H E: ........ ' '" .... :,": ...... I.,OI.,.I.,iE:,t....'¥'E]ID AF']: F:'OI:;: ~2-'8B I5' 995 ~ ~.} DATE' 4-4-9t .. F;:. Ii" F Ii':: i"( F N C E: A R C 0 2-i9 3-2 3-.'.4 5 .... i':'} 4-26 6 .... 2i 7 .... i6 '?'-.34 'i i-.9 i i --- 2 i :5-i 9 i i S-23A i '5- i i6-2 i 8- t F'I..F'ASE SIGN CASED HOLE F:INAL$ P R 0 iD U C l' I 0 N P R O F: 1' I.. E L E A !< Dii:' 'T E: C'F I O N 5'F'I NNER/I'IE MF' : I N J E C T I C] N I N,.J E [; T I 0 N F' 11- S F'I TS F,i'-,- I N J E C T :1:0 N /T E N F:' F' 11' S F:' R O D U C: T I O N P R O I::'I L l_"i: I N ,J E C 1" I O N INJE:CTION I N,J E C T I O N F'ERF BRFAI<-I)OWN 5' F' I N N E R / I N J Ii'" C 1' I O N F'I 1'5' RUN i, ..)'::'" RUN t, '2"&'5" RUN' i , 5" RUN t , 5" i::.' . I:;..'UN t , ..,. RUN i , R U N "'~ ':""" · "% ,F -'"' R U N t , '5" RUN i , 5:" RUN I, 5" RLJN t , ..;.'::'" RUN i, 5" RUN t, 5" Iq UN t , 5" RUN t,..,":"" 5" RUN t ,. RUN i, 5" AND RETURN 'tHE ATTACHED COPY AS RF'CEIF"F OF DA'I'A~ I:;:ECE I VE:D BY HAVE A N:[CE ,'.f H A F~:ON WIL.$ON ATO-t 529 .,>....~;;~-.; ~,'.:'~,i~ :.7 - ' ?;,!.: .:.... ,, , ..... ~ .. .., .....~......~, ~,~,~..,~l,~..~,~ ........... ~ ......... ~,,D I $1' R I BUT I ON ........... .;,; .~ .x,~.~,- ,. CI-IE:~i~ ""~-~-" . :- ....... :~ '~ ,..; ~. ~.?, ., ~.... H~ ~~":~i?Z .'~ ,~.,. ....... THE CORRECT AF'I~ F'ORF~,,t:'~;: ~:. IS 50-029-20544, . , ,,~ ' "~. z.' -., ~ DAY..! .............................. F'HILLIF'S -F:'B WELL... FILES R & D BPX ......................... ' .... STATE OF ALASKA TEXACO ........ , ,, ................... %... .................................. ¢% ........ '~ ~ I"IFQ3' C A M C 0 C A H C C) C A i"l C 0 i..i R [ C A H C 0 C A H C 0 I..i F;..' ;S' I-.i R ,!i.' C A M C O C: A H C 0 C ~::'~ ~"i C 0 H R $ H R HI.;,'S ALASK/ )L AND GAS CONSERVATION C~, .MISSION REPORT SUNDRY WELL OPERATIONS STATE OF ALASKA ,..-,,, ,.:. Stimulate.,.._ Plugging..,... Perforate X Alter casing ---. Other X 1. Operations performed: Operation shutdown Pull tubing -~- 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1903' FSL, 688' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1318' FSL, 4390' FEL, Sec. 10, T10N, R15E, UM At effective depth 1361' FSL, 4791' FEL, Sec. 10, T10N, R15E, UM At total depth 1369' FSL, 4839' FEL, Sec. 10, T10N, R15E, UM i2. Present well condition summary Total depth: Repair well ~ , , Type of Well Development Exploratory Stratigraphic Service X , RECEIVED MAR 2 6 t991 Alaska Oil & Gas Cons. Commission Anch0raoe measured 11750 feet Plugs(measured) true vertical 9382 feet 6. Datum of elevation(DF or KB) 61 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-2 9. Permit number/approval number 76-24 10. APl number 50 - 029-20203 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 11635 feet true vertical 9286 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 78' 20" 300 sx PF II 78' Sudace 2635' 13-3/8" 5400 sx PF II 2696' Production 11661' 9-5/8" 1100 sx Cl 'G' & 105 sx PF II 11722' True vertical depth 78' 2696' 9399' Perforation depth: measured 10973-11010'; 11020-11044'; 11054-11088'; 11100-11140'; 11156-11180' true vertical 8754-8783'; 8791-8810'; 8818-8845'; 8855-8887'; 8895-8914' Tubing (size, grade, and measured depth) 7", 29#, L-80 to 2804' MD; 5-1/2", 17#, L-80 from 2804-10630' MD Packers and SSSV (type and measured depth) 7" Otis RPB SSSV @ 2234' MD; Baker SAB packer @ 10520' 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment 14. Treatment description including volumes used and final pressure .... Re.oresentative Daily Average Production or Injection Data OiI-Bbi Gas-Md Water-Bbl Casing Pressure Prior to well operation 2834 7828 9242 -- Tubing Pressure 357 Subsequent to operation Tbg. patch &/or RWO p~.nding to fix tubing & possible casin, 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x..i. Gas__ Suspended__ Service leaks 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE%-~ DS 3-2 DESCRIPTION OF WORK COMPLETED CTU CEMENT PLUGBACK FOR WATER SHUT-OFF 1/6/91: A CTU Cement Plugback was pedormed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Tagged bottom w/CT, then pumped 31 bbls of Sand Slurry, to cover leaking squeezed perforations at: 11180 - 11195' MD 11210 - 11245' MD 11260 - 11310' MD Ref. Log' BHCS 5/1/76. Displaced CT w/gelled water, then pumped 2.5 bbls of expanding cement w/aggregate, on top of the sand plug, to isolate the leaking squeezed perforations (listed above). Contaminated & jetted excess cement from wellbore. POOH. RD. I/719 1: RIH & tagged top of cement cap at 11254' MD. POOH. RD. Currently the well is shut in for further investigation of leaks diagnosed in the well, Future work on the well may involve a Tubing Patch installation &/or a Rig Workover. RECEIVED Alaska Oil & Gas Cons. Commission ;~nchorage ,,,-% ARCO ALASKA.. lINC,. P ,. 0,, BOX ANCHORAGE, ALA,'~KA 995, i (-:) ' DA"f'E · · 9- 2,3-9,9 RIEFERENCE' ARCO CA,~ED HOLE FiNAl_i:: RECEIVED SEP 2 6 1990 &laska Oil & 6as C;ons. 6ommission Anchorage ..... l,-,..,... F:'Li JG t:;..'UN '~ --'::" ,...'::' - 'i t 8 --- ..:'., i --- '::;', ,':;., T .,.'r E - ]: N / E - .L. ;' i r.:' _ ,., ,.~-,= 8-'--",":'.-':;".':; F'F.:ODUCTiF~N F'ROF rLE F,,'UN 'i , ':~" ...... ,.:-i .... , :-., -: :, _ ,:-..:, ¢, P.RODUC.'f"rON ,. ,,.. .......... .: .::, .... ..:) ......... r.', r.', ~"'~ ~::' 'r L. E I:;; U N ¥, -- i ;.;':'.; 8 -- '::,.,...,_'::' -- ~.:,, ,-:;.., .,.'r ,N ...,~F-"_ C.. 'i' l ._.r'-'- N, F' ,i:;', ~"i._ ,i:-' I ,..~ ~ [:; F: I_i N :.'3--"~.,:'-'~,...., 8-'::"::--9¢.,_ ~ . .. F'RODUC'TIOi"-,!. F:'ROF'iI_[:.:/'F'IT':''': ,.:. RUN i :,~ 4 ---'--:''.:', 9.-:'";'-9¢-':', 'rF'HF' F,'UN ·. :~ .,: ...· . ..... ['~ r'~ r.;, ~;, r.- ~ ~ ';" i[ 0 N [:" ~ I ~"~ i '.5: :' 5-i 'i 8---3 ~; -':.':":':) ,'..~i".: ......... ,.-~,-,, ,','- .... 5_.--~,~,.~ ~..- c,_.~, , :3-(;'~:~, .. CO[_LAR/F'::ptz~_ .., RIJN i., ~';..," · .',,~ .:,~: 7-.'3¥ c~, _ 8 ._ c., ,:.},. ~,, ..l' TS i";,' U i".~. ':.'., .at ':;' i,':; o,.:, F'l.--'i-q'F I;:r:eRF'P, I;.:UN i, ':'"':" '::".-- 4 3,.c;,, - 'i '.5:- 9':-";,, r':O LLAR/PEF'.F... i:;.' t. ...... IH i · i, "i .-- ?8- 2 7-".-? ~;:,. .~T N.JEf""r T ON. ..,.., i:";'i'}F' ! L_E. ,, _ RLIN 2 , """ '.., i 'i-- i:..,':::' 8 - 27 - c;,, ,:-".',. F'R 0 .D U i":.., T, ,T [],. N. e e 0 F ]: :...i ,...i:: iR U N i 3-2,:5 8.-3i.-9e (;t;: CORRELAT:r.C~N RUN i, i 4--3a, 8-27-0."(-), Pg'ODUCi"[ON,,. F'F:OI::' ]: LE: F.'.tJN t , ..,."":" F'LEASE :~7iGN AND RETURN THE ATTACHED COF'Y A~ RF'CE]:F'T OF DATA~ R EC:E]:VED BY .~..~ HAVE A NIE:E DAY! APPROVED ~i'RAN 3'¢- 9,: C A ¢~ C O. C A ¢.i C C) C ,'::; i"-'~, C 0 C A ¢! C: G C ,,':'.": i"-'! C (3 f;; .,'-':',: b C 0 A "[' i.. A ,::-:." i-.i F;.'. :~CH A-['LAX C A f,i C 0 C A M.' C: 0 CAMCO CAHCO D i £'TR iBUT I ON CENTRAL FILE~ CHEVRON D&M EXTEN£ION EXPLORATION EXXON MARATHON MOBIL F' I"t I L L I F' ~' i"':'B WELL F R" ¢,: B F'X ~,.-"- ,':_-_..~TAT!F OF' ALA;~-'I<A TEXACO · '.~ THE C::OF.'.-c-~r'.-.'CTED AF'I~ FOR 4-2(-'.~ !2 5:,'3,-,'..}29-2C~996. :~':.,~. THE C:ORI;,'ECTED AF'i¢- FOR '7-,7,3 :[:::7 ."5(::)-,:'::,29-2i8~9,, ARCO Alaska, In Prudhoe B,., Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 8, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS.3-2, Approval No. 9-665 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 3-2)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/~'~IL AND GAS CONSERVATION ( VIMISSION r~ REPOR'I OF SUNDRY WELL OP£RATIONSu ! t5 A [ 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1903' FSL, 688' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1318' FSL, 4390' FEL, Sec. 10, T10N, R15E, UM At effective depth 1361' FSL, 4791' FEL, Sec. 10, T10N, R15E, UM At total depth 1369' FSL, 4839' FEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory StraUgraphic Service 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-2 9. Permit number/approval number 76-24/9-665 10. APl number 50 - 029-20203 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11750 feet Plugs(measured) 9382 feet Effective depth: measured 11635 feet true vertical 9286 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 78' 20" 300 sx PF II 78' 78' Sudace 2635' 13-3/8" 5400 sx PF II 2696' 2696' Production 11661' 9-5/8" 1100 sx Cl 'G' & 105 sx PF II 11722' 9399' Perforation depth: measured 10973-11010'; 11020-11044'; 11054-11088'; 11100-11140'; 11156-11180' true vertical 8754-8783'; 8791-8810'; 8818-8845'; 8855-8887'; 8895-8914' Tubing (size, grade, and measured depth) 7", 29#, L-80 to 2804' MD; 5-1/2", 17#, L-80 from 2804-10630' MD Packers and SSSV (type and measured depth) 7" Otis RPB SSSV @ 2234' MD; Baker SAB packer @ 10520' 13. Stimulation or cement squeeze summary 6...V' ~: ~,,#~: Intervals treated(measured) See attachment :~/IAF~ .~ Treatment description including volumes used and final pressure ;. i~::~.~-~:~. ~,.~ .~ ,~ Representative Daily Average Produ~ion or Injection Data Anch0ra~a .' OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 14. Prior to well operation Subsequent to operation 1217 3149 11000 -- 483 4692 6974 4853 -- 549 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~..~,~~.~-~.~,/~,~,~'c-~¢,~¢_..- Title Operations Engineering Manager Date ..~---,.~--~o Form 10-404 Rev 06/15/88 ,',A,". n ~ n------ SUBMIT IN DUPLICATE DS 3-2 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF 8/23/89: MIRU. Removed SSSV. Tagged bottom at 11460' MD. Surged well. Made post surge tag run to 11459' MD. POOH. Rigged down. 8/24/89: MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. RIH w/CT and loaded well w/300 bbls of Crude, then washed perforations at: 10973 - 10992' MD Ref. Log: BHCS 5/1/76. 10992 11020 11054 11100 11175 11220 11240 - 11010' MD - 11044' MD - 11088' MD - 11140' MD - 11195' MD - 11240' MD - 11245' MD Pumped 122 bbls 120 bbls 120 bbls the following treatment: 12% HCI w/25% Xylene, followed by, 12% HCI - 3% HF, followed by, 12% HC1. Displaced CT w/Diesel while POH to GLM station #8 at 8650' MD. Pumped 5 bbls of 15% HCI down CT to wash GLM stations #1 thru #8 while pulling out of hole. Rigged down. Flowed well. 8/25/89: MIRU, and RIH making trips to change out GLV's w/DGLV's. GLV's in stations 1 thru 8, were replaced w/DGLV's. Loaded well w/seawater and pressure tested 9-5/8" casing to 2000 psi. Pressure held 1 hour at 2000 psi - OK. POOH. Bled off 9-5/8" to 1000 psi. RD. 8/27/89: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/608 bbls of seawater. Pumped 33 bbls 10973 - 10992'MD 10992 - ll010'MD 11020 - l1044'MD 11054 - l1088'MD 11100 - lll40'MD 11175 - 11195' MD 11220 - l1240'MD 11240 - 11245'MD cement, squeezing perforations: Ref. Log: BHCS 5/1/76. The squeeze was aborted after pumping 33 bbls due to pump problems. Pressured up to 1500 psi on cement while pumping 84 bbls of contaminant. Cleaned out contaminated cement from wellbore w/612 bbls of XCD, after placing 10 bbls of cement behind pipe. POOH. Rigged down. DS 3-2 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF 8/28/89: MIRU, and made post squeeze tag run to 11321' MD. POOH. Rigged down. 9/13/89: MIRU, and RIH to DGLV at station #1. POOH w/DGLV, then RIH and located a 5/16" OGLV into station #1. Tagged bottom at 11450' MD. POOH. Rigged down. 9/15/89: Reperforated: 10973 - 11010' MD 11020 - 11044' MD 11054 - 11088' MD 11100 - 11140' MD 11156 - 11180' MD Reft Log: BHCS 5/1/76. Note: (Perforation interval : 11156 - 11175' MD, was squeezed previously - 6/5/85). Returned well to production and obtained valid production test. ARCO ALA£KA., liNC. P..O. BOX i6,(')S6(') ANCHORAGE, ALA;~K A D A T E · ~'-) - o, - '~', '3 REFERENCE' ARCO F'RE&'$URE DATA i -i 9 i i -! "7--8'-.-.-' BHF'--;;:TA'TIC C;RADIENT · i-25 i ~---8-F39 BHF'--:~TATIC GRADIENT ='--,:~, ~ -8,- BHF ....FLOWING GRADIENT S-'~ ~,~.-~ ~ .... 8°, BH~, .... FLOWING GRADIENT ~;--6 ~i'-i3-89 BHP--FLOWING GRADIENT S "- 6 'i J - ~ 6 - 89 B H F .... S' T A T I C (]-R A D I E N T :5-8 i i ..-i 2-89 BHF'--FL. OWiNG GRADIEN'i' G-20 ii-9-89 BHF ....FLOWING GRADIENT :,-~.i i i -i ~:~--8(;' BHP--FL. OWING GRADIENT ~ '~"' -9-89 .m-~:,~ ii BHP--STATIC GRADIENT ~,~-- ~ ~:~ i i-i 6,-89 --, u-',~,,v--~"FAT I C GRADIENT -~ o, BHP--F'RE~SURE FALL-OFF 7--~4 ii-i5~-89 BHF ....PRESSURE FALL-OFF 9-~ i(b-27-89 BHF ....FLOWING GRADIENT 9-24 i i-i~A-°°,., ~, BI--IF'--STATIC GRADIENT -.~4 ~-~6-89 BHP--~TATtC GRADIENT ~6-9 ~-~-89 BHP--STATIC GRADIENT ~6-~8 'i~-~9-89 BHP--~TAT!C GRADIENT ~7-~S ~-9-89 BHF'--STATIC GRADIEN'f' Pt_EASE SIGN AND F:I.ETURN THE ATTACHED COPY AS 1:;,' '" F: - ~' E. _. -L.~ VED BY HAVE A NICE DAY~. 'DALLY HOFF'ECKv"''::~':: ATO-'i 529 FEB 1 3.1990 Oil & Gas Cons. Anchomgei I;.'.ECE l F:' r OF APPROVED ~._~, ~_ TRAN$.$ 9~ CAMCO CAMCO CAMCO C A M C 0 C A M C 0 C: A M C 0 CAMCO CAMCO C:AMCO CAMCO CAMCO C A P. C 0 (.'.AMC(] CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DATA, D I $.TR I BUT I ON CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON F'HILI_IF'S F'B WELL FILES R & D BF'X STATE OF ALASKA 'TEXACO ARCO ALASKA, INC. P.O, BOX ANCHORAGE, ALASKA 995i 0 DATE' i~.°-5-8o, REFERENCE: ARCO CASED HOLE FINAL£ 2-25 ii-9-89 S'2 ii-ii-89 3-6 i t -i 3-89 S-8 i i -i 2-89 S-2~ i i '-9-89 S-"t,. t t -i 0-89 4-27 ti-i2-89 5-27 it-i2-89 6-i tt-8-89 7-3 ti-6-89 tS'-26 it-8-89 PRODUCTION F'ROFILE LEAl< DETECTION PRODUCTION F'ROFILE INJECTION PROFILE F'RODUCTION PROFILE PRODUCTION PROFILE F'RODUCTION PROFILE INJECTION PROFILE GR-COLLAR LEAK DETECTION F'RODUCTION PROFILE LEAK DETECTION RUN t, 5" RUN t, 2'&5' RUN t, RUN RUN t , 5" RUN t , 5" RUN t , ~" RUN !, 5' RUN i, RUN t, RUN i, RUN l, PLEA.DE SIGN AND RETURN .THE ATTACHED COPY AS' RECEIF'I' OF' DATA CAMCO CAMCO CAMCO CAMCO CAMCO (]AMC[] CAMCO CAMCO CAMCO CAM(;(] CAM[)(] CAMCO DISTRIBUTION CENTRAL FILES $ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION '~ BPX EXXON ~ .$TAI'E OF ALA.S'KA MARATHON ~ TEXACO MOBIL * THE CORRECTED AF'I$ FOR 3-2t I$ 50-029-20990. ** THE CORRECTED API.$ FOR 4-27 I$ 50-029-2t50~. ARCO ALAS'KA, INC~ I::'~ O, BOX t (')()36~ ANCHORAG, IE, AI_AS'K A ? , 995i ¢, DATE:' ~t .... 8-89 F'..'I!"'FI.:':RENCE' ARC(] CAS'ED HOLE F:INAL.~J S- 2 t ()- t S '"' 89 Iii: P i i... 0 G 5'- t i ()-28'-89 COLI_AR/F:'ERF .,.':~' -' t 8 t (~ -' 28 "" 89 P R. 0 D U C T I 0 N F'A C K E: R 6-'7 ~ ~ -2""89 COLLAR/F'ERF 9-"i (') . i i-'5-'89 CC)LL..AF;t/F'ERF: i 4'-:5S i 0-29-89 COLLAR/F:'EF<F i 5-i ~5 i i -S-'89 COLL. AR/F:'ERF 1 5-i '7 i (3'-27'-89 CNL-'GAMMA i 5""2~ i 0-'28-89 CPE i 5'-2E:' i (!'""29',"89 PAL R!!i:C E ]: V E D B Y RUNS' i &2,..,':'" RUN t , 5" RUN t, ...;':~" RUN t , 5" RL.IN I , 5" R U N t , .5" RUN i , 5" R U N t , .5" kLtN t, i/2"&i" F(I. JN t , ':~"., HAVE A NICE DAY! .S'AL.L.Y I"IOF:FE:CK ER ATO-t 529 I) I STR I BUI'i ON ~ CENTRAL FILES ~' ~- F'I-! i LLI F'S' ~" CHEVRON I::'B WELL FILES '!i' D & M R & D · -"- EXTENS'ION EXPL. OR~TION "~. BPX ~ EXXON ~ ;~TATE OF ALAS'KA MARATHON " ... TEXACO ~~ MOBIL . THE CORRECI'ED API~ FOR t5-i7 IS .50.-029-.2tt26~ Ali:CO ALAJ~KA, INC, F'~O, BOX i 0(.)36(~ AN(:;I.-IOIRAGIE, AI_AS'KA 995t 0 DATE' t t-.8--89 R E F' E F;,' E N C E ' A R' C: 0 Pt A rj NE T I C '1" A F' EL ( 5' ) W I '1'1..I I... 15' T I N (~;. ( 5' ) t -.-":'5 t 0....,..........-89 D,~N ," 2 i 18 & t-26 i(')-'2t .... 89 D,S'N (3 ~/8") ...ICIB~:tS639X :~'"2 t0'"'i:$-'89 I='DK-'iOG ($ F:'AS'~') 5-28 i O"'i 3-'89 F'DK'"i OO F:~:~: c E: ]: v E: [: ~-:~ Y' .......................... , ........................ ~sl~ ~mml~llJn 011 & Gram ,-,- ~'AL. LY HOFFECK I:'~R ~F'F'ROVED ._ ATO""~ D29 'I'R~N~':.,t- 89 Oil ~ons. (SEN' ' FRAI.. FII, E~' (CH) CHEVRON I'AHHA$ BROWN (OH) EXXON HARAI'HON HOB I L F' H I I.. L. I F' 5' PB WELl.., FILE:5,' ~' BF'X · ,-"$'I'~TE OF ~I.,~..S'K~ T E X A C 0 ARCO ALASKA, INC. F'.O. BOX JOOS6(~ ANCHORAGE, ALASKA DATE' -J G-J 7-89 REFERENCE' ARCO CASED HOLE FINALS i -"5 t e_ i i -89 ~-~. i O-i S-89 ._ S-28 i O-i S-89 '.'~ 4-S t G-6-89 ~6-i S 9-27-89 ~" 6-2J 9-28'-89 9-i 7 9-29-89 9-26 i O-i 4.-89 '~i i -t 8 i ~-i S-89 i 4-t i ~-8-89 i 4-i 6 9/24-2~/89 i 4-2 i 9-S8-89 i 7-i 0 ~, --m0-89 i 7-i ~ t ~-~-89 i7 JS t0-~-89 i 8-9 9-29-89 COLLAR/PERF F'DK-i O~ F'DK- i ~ GR/CCL & PERF RECORD PRODUCI'ION PROFIL. F PRODUCTION PROFILE INJECTION F'ROFILE PDK-i O~ COLLAR/PERF COLLAR/PFRF LEAK DETECTION INJECTION PROFILE '~ INJECI'ION PROFILE COLLAR/PERF COLLAR PITS RUN RUN RUN RUN RUN RUN R'UN RUN RUN RUN RUN RUN RUN RUN RUN RUN FLEA.~E SIGN AND RECEIVED BY HAVE A NI.E DAY! SALLY FtOFF'ECKER ATO- i 529 RETURN THE ATTACHED COPY AS RECEIF'T OF' DATA. Oil & Gas Cons. v Anchorage ._ DISTRIBUTION L;EN/RAL FILES ~ PHILLIPS ~ CHEVRON F'B WELL FILES D & M R & D · · .-'"' EXTENSION EXPLORATION $ BPX .,"- EXXON ,$ STATE OF ALASKA MARATHON. ~ ~ TEXACO ~ MOBIL 5" 5' 5' 5" 5" 5" 5" 5" 5" t" 5" 5" 5' 5" 5" ATLAS ATLAS ATLAS SCI-! CAMCO CAMCO CAMCO ATLA.~ Al'LAS AY'LAS CAMCO CAMCO CAMCO Al'LAS Al'LAS CAMCO ARCO ALASKA, INC F'. O, BOX t ANCHORAGE, ALASKA 995 DATE' 9-27-89 REFERENCE: ARCO CASED HOLE FINALS ,~ ~.4 9-t 8-8c~ COLLAR/PERF 3-2 9- t 5-89 COLLAR/PERF 4- t 9-7-.89 NO I SE 5-ti '?-8-89 SPINNER SURVEY 6-2~ 9-t 4--89 CNL-GAHHA '?-27 7-2~-8~ PERF RECORD ~i t~ 7-24-89 F'ERF REL, 0RD t t-t 2 7-23-89 F'ERF RECORD ti-t7 9/ti--t2/89 COLLAR/F'ERF t 2-t S 9-t 7-89 COLI_AR/F'ERF t 4-~t 9-t t -89 COLLAR, F'ERF' RUN t , .5' RtJN t , 5' RUN t, i ' RUN ~ , 5" RUN ~ , 5' RtJN i , .5" RUN t , .5 ' RUN t , 5" RUN i , 5 ' RUN ~, .5 ' RUN i , 5 ' F'LEA,~'E SIGN AND RETURN THE. ATTACHED COPY AS RECEIPT OF DATA, ATLAS' A]'LA~" 5' C H HLS A'FLA~' I.{i_,~ HL$' HL;~ ATLAS AI'LA~' A'I'LA~g' HAVE A NICE DAY! ~ OCT - 2 l~O~ .~. APPROVED .~__ SALLY HOF'FECKER A T O- t 5 2 9 518.Sk8 0;1 & Gas Cons. Anchorage DISTRIBUTION CENTRAL FILES CHEVRON · EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES' R & D BPX £,TATE OF ALA;~'KA TEXACO ARCO Alaska, Inc.~ Prudhoe Bay ,.ngmeering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager ORlu NAL August 2, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-2, Permit No. 76-24 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DCR/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 3-2)Wl-3 RECEIVED AUG o ]989 A, laska Oi~ & Gas Cons, CommissJ'oli Anch0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/~-~'iL AND GAS CONSERVATION APPLICA I'ION FOR SUNDRY AFr ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing Re-enter suspended well Time extension Stimulate Vadance Perforate X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development x Exploratory Stratigraphic Service 4. Location of well at surface 1903' FSL, 688' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1318' FSL, 4390' FEL, Sec. 10, T10N, R15E, UM At effective depth 1361' FSL, 4791' FEL, Sec. 10, T10N, R15E, UM At total depth 1369' FSL, 4839' FEL, Sec. 10, T10N, R15E, UM Other X~ 6. Datum of elevation(DF or KB) 61 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-2 9. Permit number 76-24 10. APl number 50 - 029-20203 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11750 feet 9382 feet Effective depth: measured 11635 feet true vertical 9286 feet Casing Length Size Conductor 78' 20" Surface 2635' 13-3/8" Production 11711' 9-5/8" Plugs(measured)R E C E IV E D Junk(measured) AUG u 1989 Cemented Alaska 0il & Gas C~,a6till~li~ 300 sx PF II ' ~ Anchorage ~139' 5400 sx PF II 2696' 1000 sx CI 'G' & 105 sx PF II 11722' True vertical depth 139' 2696' 9399' Perforation depth: measured 10973-10992'; 10992-11010'; 11020-11044'; 11054-11088'; 11100-11140'; 11175-11195'; 11220-11240'; 11240-11245' true vertical 8754-8769'; 8769-8783'; 8791-8810'; 8818-8845'; 8855-8887'; 8915-8931 '; 8951-8967'; 8967-8971' Tubing (size, grade, and measured depth) 7", 29#, L-80 to 2804' MD; 5-1/2", 17#, L-80 from 2804-10630' MD Packers and SSSV (type and measured depth) 7" Otis RPB SSSV @ 2234' MD; Baker SAB packer @ 10520' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation August 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby.~,ertify that the foregoing is true and correct to the best of my knowledge. .Signed 4,~ ~~~~ ~---'-- Title Operations Engineering Manager 15. Status of well classification as: Oil x Gas Suspended Date FOR COMMI~RION IJ~F ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance .~o z.~ Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Commissioner I Approval No. ~;~... ~ ~ Approved Copy Returned Date ~' '~ -~ , Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE D.S. //3-2 ~'~ CTU Profile Modification Squet-.e Preliminary Procedure Objective: The purpose of the proposed workover is to cement squeeze the existing perforations, decrease production from the V2, and increase production from the Z1 by modifying the perforation scheme after the squeeze. 1. RU slickline. Surge well with 2000 psi and tag fill. 2. RU CTU. Conduct perforation acid wash. 3. Flowback well for 24+ hours and obtain welltest. 4. RU CTU. Cement squeeze all perforated intervals. Volume of cement pumped will be sufficient to cover all perforations. The intervals to be squeezed are as follows: (Ref BHCS 5/1/76) Perforations (MD) 10,973 '-10,992' 10,992'-11,010' 11,020'- 11,044' 11,054'- 11,088' 11,100'-11,140' 11,156'-11,175' 11,175'-11,195' 11,210'- 11,220' 11,220'- 11,240' 11,240'- 11,245' 11,260'- 11,310' Interval (Zone) Zl (4) Zl (4) Zl (4) Zl (4) Zl (4) v2 (4) V2 (3) V2(3) V2(3) v2(3) v2(3,2) Comments Open - FSD Open - FSD Open - FSD Open - FSD Open - FSD Squeezed Open - LSD Squeezed Open - FSD Open - LSD Squeezed - Leaking 5. Hold 3000 psi squeeze pressure for 60 minutes. 6. Contaminate cement. 7. Jet out contaminated cement. Clean out wellbore to PBTD. 8. W.O.C. for two weeks. 9. Re-perforate as indicated below: (Ref BHCS dated 5/1/76) Proposed Perfs (MD) Interval (Zone) Density 10,973'-11,010' Z1 (4) FSD 11,020'-11,044' Z1 (4) FSD 11,054'- 11,088' Z1 (4) FSD 11,100'-11,140 Z1 (4) FSD 11,156'-11,185' V2 (4) LSD 11,185'-11,195' V2 (4) LSD * 11,210'-11,245' V2 (3) LSD * 11,260'-11,310' V2 (3,2) LSD * * Denotes perfs that will be deferred until water handling capacity is increased. 10. Return well to production. Current Status: Producing on gas-lift. Estimated Reservoir Pressure: 3780 psi at 8800' subsea Estimated Reservoir Temperature: 197OF 6 4 2 I I COILED TUB],Nt3 UNIT BOP EOM ! PMENT 1. 5000 PSI ?" W£LLHEAD CONNECTOR FLANG£ 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ~X)0 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX ,,H]REL]NE BOP EOUIPHENT 1. 5000 PSI 7" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-DFF ARCO AI..ASKA: liNC,. F'.,F.)., BOX i ANCH[)RAGE, AI...A,.%'KA 99.51 (.) i:;.I.:'FEiRF"t',,IP "' AtR'.C[I F'i:i'EiSS!.!t:i'F!; I')AI'A BHI::'-I--. !,.[!!,! .'[ Nf;- GF;.'A'I] ! ~HP-..,~"I"AT T I': C;R'AI') T ~N'T BHF ....S"TATT[; !',iR., ~' TIIENT.. ~ REF'I..ACE,S: T. IHF'.-FI..Ob. ITN.F, ~R'ADIIF. NT I-IN TF;.'AN,~MI;T'Ii"AI. ~:RR;):'~;'i T,.q'S!tFI) 4.-.R.--t::tR I::'I..t!!i~SE ,¢];GN ANf;, RF;T!.!I:i'N T!-IE AT'f'A[.'.HF~.fl~:'Y ,¢¢,S' I-,"[!'[';F'[F'T Cons. F'F."][;gY BENN.F...TT~//~$¥,B Oit & Gas f'll::' DATA.. .f) I~' Iq,' ,_., T., I RI. IT ]' AN fl; A M r'. I11 r.~ 1' .T..'~ CENTRAl... FILES EXTENYlON E; "/-." F' I.. 0 R A T 1' .Et N H A F,.' A'f' HFiN AR'C[} AI...AgKA., TNC ,. P, f.]~ B{'I× t 00:~60 AK![.-;t--I(}i:;~AF..;.F.:, AI...AgKA 995~'i G DATE · 4-t 2-8R DATA i3HF'--Fi...[iLd T NJ; [$R'AD ]i ENT PI...F~;,~F] ,~IGN ~NI) RI.-TTLIR'N THE AT .FI) COPY ¢~,~ R'ETCF]'F'T OF' DA'FA., FI~VE ~ NTCE DAY' F'E f.; fT, Y ~ ~,'I"D-. ~ Alaska TF;.'.AN2 '"'c)°")~t ~ ~r' ,..1~ J..) ~.'......~ AF'f':'I:~OV E D D 7; ,.?TF,'. T T:~I.I T T NN C A M C, 0 [.'.EEN T R At.. F'.HEVROF~ ."- '~0 _ . E¥'X'ON M~RATH['IN ~ MOA]El.. ARCO ~' ~" .... A,...A,.,KA , T. Nr'. P., 0., BI]'/ ~ OO.:~60 A NC 140 r.~'A r.; [.:.., AI...A ?.,'1(' A I)A T .F.. ' 4-7- .R. 8 . I'~' I!!' F- E' I:? [-7. i'4 C: f.!: · A R r.: O C ~ S E .1.) 14 f'] !. I:!: F:' 1: f.,! A F:' [:' A ;",'; [:' ."..'.' ]' [:, t"J A i'-,l.l) t:;: li!i 'f' ! I r.;., KI '1" 14 !!." .,-::; 'f' 'f' A 1": I-.I 1!! f') fi'.' f. i I::' Y A ~; I:;.,_r:' f": !::' ]' I:, 'f' f'l I::' , ',', ', ...... ' REEE! /E I--lAVE f--', NJ]CE' OthY' ~aska 0il 8, 6as Cons. 6ommission F:' I::: f; f:,: Y l:{ [-.] N N E: T 'f' /~nchoraoe ;-", 'i" f'i - t "": '''~ o . ..-' ...-. , f) T 5.' 'f' F-;.: T F-,' I I'1" T !"i hJ I) A'¥ A. f': A 1,4 r: f'~ r'. A N f':. f'~ r: A/'t f't f'~ f': A i'q fi fi f-: (-.', H I'] f'l r'.' A H C f'! r: A H f": [I r: th H C rl ARCO AI._A~KA, TNC. ANCHORAGE: AI...A~KA 99'5 REFERENCE' ARCO CASED I~AI._~ FTNAI. t-t~ t2-5-~7 3-t ~T~~?' ~t-5-~7 5-4 t2-t6/t~-~7 4-12 5-4 tt-~S-87 7-6 t~-?--~7 7-t~ tt-6-n7 7-t7 i6-t tt-?A-R'7 iT-i t~-A-g7 P..Ol...l .AR C. CII.. I. AR./F'~RFCIRA'I'TON COl._ I...AR/P .F-.RF ORA T T ON IS, gL I.AR/F'ERFE1RAT.TCIN C, Ftl._l._ A R/F'ERFF. IRAT .T. nN CO. I.. [. AR/F'~RF..rlRATT CIN CI.-t. !.. I., AR ! F'F.R F' fi R A'1' .T. FIN .COl.. I.. AR/P.F..RI--F1RATTFIN COI..I .AR/P~.RFCIRA T T C fl!..l... AR / F'F.. RFnRA T .T. ON f~ll. i...I. AR/F'FRFORAT .T. FIN COl.. I... A R / F' .F.-RFO RAT ~ .CIN P. Fll.../.AR .C. f]l. t.. A R./F' .P-. R F FIR A'F 1~ ON P, gl_l. AR/F'FRFF. IRAT.T ON F'I...EA,S'F. ,.x-'TF.,N AND RETt r:...- .-,,~!,~ ! & ~as Cons Commissl~ HAVF/ A NI ~'~, Oil& Gas. Con. ~ /~qcnsrag9 PEf.;*Y BF..NNETT ATCl-'i ~ .,.'2. 9 TI::.',AN,~ 588t 67 /~ AF'F'RF.) V .F..D_ 0 '[ ,~TR T RI IT T FIN RI.IN RI. IN RI.IN RI IN RIlN RI, IN RI.IN RI.IN RUN R'!.IN RI. IN. RI.IN RI.IN RI.IN DATA. ATI ATi. AT! .A.? ATI. A% ATI..A.~ ATI AY: ATI A ~' . Afl. A.~ ATI A.? ATI._A,S' A'T I.. A.-'(' ATI .AZ,," ATI .. A..? ,,~ T I.. AX' ATI .A.~ · ~ CEN TF,'AI... F l I...F..-..? ~ PI--I 11...t... I F',.9 ~ CHEVRON F'l~ WELl... FTI.. D & M ~ EYT .F..N,~ T ON E'XF't..IqRA T T nN '"..: .~';' A F' C. -,--"-.F. )4'/r] N . "~"~TATE .,. FIF .. A I... A.~'k' A . HARATHON ~ TFYA .P. FI - MI]nil · ~- ...... ANCHORA6E!i~ At~,AYKA 9 9 '5 ~ 0 D A'T' t?': ~ .? ....'i/:.... P,'7 R li:i I::' E R 15.'!i N C E': A I:i' C 0 N A f'.4 N I!!i T iii C '" I,.I/I. :r :.?'T' t N f; "1" A I::' E ,., 3- 2 J 'J .... 5 4.... 8'? M A 6, T A l::'i!!: :Il: E C C S 5 9 9 !::'!'~J./. - ~ 0 0/f':, R :';~ .... S :'.'=, ~ 5 .... ~ '.55-... 8'7 M A f; T A t::' E Il: E C C :'.;i. 2 ¢.) ~ F:' D I./. .... ~ 00 / r; I::,.' J ~ '~ 2 ~ ~ ~ c'.; .... ~!~ 7 M A {; T A F' }!!' '"' E C "~ O !!5; I./. .... ......... ,,. C S .... I::' l') 5 0 0/{'; R ~ 6 .... 2 0 ~ ~ .... ~ 4 ..-. 8 '? M A (; 'Y' A F:' I!!: :~I: E f:: C' :'~; :2 o 0 !::' D I./. .... ~ o o / r; I:~'. F'I...EASt!!i Y;If;i'J ANT',' J:;:F:'!r'lll:i'k~ 'T'l..lt!!' ,/:5~=)TA[5:I--~'~ ~:'Y Al:: l:i'r,;~S:l::':rt::"T' Or-:' TSA'T'A. ~-.1,.5 v Iii: ;.::, N :!: {;: t!i; ..'~ A Y ~ AIt~ 011 & ~a~.O°ns. Comm|~lolli ~onorago P l!il [;. ('.-; Y B E H N 1!!i T 'I" A'T' 0 .... 'i ':~; 2 C,:' T R A N,!';' :~ fi!'7 6 9 2 ~ A F:' F:' Fi', O V E .'0 ................... '..~ ...................... , .............. D I Y 'T' I:.:.' I B [.I T .T 0 ATI A ,".:: ATI. A.5.' A'T'I A.? A'I" I AY Al... A S K A STATE OF ALASKA :~"~ ALAb~A OIL AND GAS CONSERVATION CON,,~,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] / 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1903'FSL, 688'FWL, Sec. 11, TION, R15E, UN At top of productive interval · 1318'FSL, 4390'FEL, Sec. 10, TION, R15E, UM At effective depth 1361'FSL, 4791'FEL, Sec. 10, TION, R15E, UM At total depth 1369'FSL, 4839'FEL, Sec. 10, T10N, R15E, UN 5. Datum elevation (DF or KB) 61' RKB Feet 6. Unit or Property name Prudhoe Ba,y Unit 7. Well number 3-2 8. Approval number 7-RlE . 9. APl number 50-- 029-20203 10. Pool Prudhoe Bay 0il Po, 11. Present well condition summary Total depth: measured true vertical 11750feet 9382 feet Plugs (measured) Effective depth: measured 11635 feet true vertical 9286 feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Conductor 78 20" 300 sx PF 11 139' 139' Surface 2635 13-3/8" 5400 sx PF 11 2696' 2696' Production 11711 9-5/8" 1000 sx Class G & 11722' 9399' 105 sx PF 11 Perforation deoth: measured 10992-11010' 11020-11044' 11100-11140' 11156-11175' (squeezed), 11175-11195', 11210-11220' (squeezed), 11220-11245', 11260-11310' (squeeze true vertical 10973-10992', 11054-11088' ,SS 8703-8718', 8726-8745' , 8790-8822' , 8834-8845' (squeeze 8845~-8865', 8877-8887' (squeezed), 8887-8906', 8917-8958' (squeezed), 8688-8703', Tubing (size, grade and measured depth) 8753-8780' 7" 20# !_-80 to 2804'MD; 5½" 17# L-80 from 2804' to 10630'MD' Packers and SSSV (type and measured depth) RPB SSSV @ 2234'MD, SAB Packer @ 10520'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 3400 3100 9700 -- 470 4300 3900 10000 -- 500 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,.,~. Form 10-404 Rev. 12-1-85 Title Operations Engineering Manager Date ,, d) d) Submit in Duplicate~.. DS 3-2 Daily Report of Well Operations Add Perfs 11/5/87 MIRU. PT equipment to 3500 psi. OK. SI wel 1. RIH w/gun #1' CCL/GR/3-3/8", 20' Jumbo Jet, 4 SPF @ 90°/120° phasing. Open well. Shot 11068-11088'. S.I. well. POH. All shots fi red. RIH w/gun #2- CCL/GR/3-3/8" Jumbo Jet, 4 SPF @ 90°/120° phasing. \ Open well. Shot 11054-11068'. S.I. well. POH. All shots fi red. RIH w/gun #3' CCL/GR/3-3/8" Jumbo Jet, 4 SPF @ 90°/120° phasing. Open well. Shot 10973-10992' S.I. well. POH. All shots fi red. OOH. Open well, RD. Well turned over to DS-3 Operator. STAT17/3-2 ~"~ STATE OF ALASKA ~'"" AL/-,._.'A OIL AND GAS CONSERVATION CO,,.,VllSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforat 'e~ Other [] '2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~ Anchora_qe, AK 99510 4. Location of well at surface 1903'FSL, 688'FWL, Sec. 11 TION R15E UM At top of productive interval ' ' ' 1318'FSL, 4390'FEL, Sec. 10, TION, R15E, UN At effective depth 1361'FSL, 4791'FEL, Sec. 10, TION, R15E, UM At total depth 1369'FSL~ 4839'FEL~ Sec. 10~ TION~ R15E~ UM 11. Present well condition summary Total depth: measured 11750 feet true vertical 9382 feet Plugs (measured) Effective depth: measured 11635 feet Junk (measured) true vertical 9286 feet Casing Length Size Cemented 5. Datum elevation (DF or KB) 61' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 3-2 · 8. Permit number 76-24 9. APl nun~r_20203 10. Pool Prudhoe Bay Oil Pool R[CEIVED ^iaska Oil & Gas Cons. ComraissiGr~ Measured depth Anchor~j~ Vertical depth Conductor 78 20" 300 sx PF 11 139' 139' Surface 2635 13-3/8" 5400 sx PF 11 2696' 2696' Production 11711 9-5/8" 1000 sx Class G & 11722' 9399' 105 sx PF 11 Perforation depth: measured (squeezed), 11175-11195' 11210-11220' (squeezed) 11220-11245' 11260-11310' true vertical 8845-8865', 8877-8887' (squeezed), 8887-8906' , 8917-8958' (squeezed) Tubing (size, grade and measured depth) ~-'" 17# L-80 from 2804' to 10630'MD' 7", 20#, L-80 to 2804' MD; ~2 , , Packers and SSSV (type and measured depth) RPB SSSV @ 2234 'MD~ SAB Packer @ 10520 'MD 12.Attachments Description summary of proposal {~ Detailed operations program [] 8703-8718' 8726-8745' 8790-8822' 8834-8845' 10992-11010' 11020-11044' 11100-11140' 11156-11175' (squeezed) (squeezed) 13. Estimated date for commencing operation October 27, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertify that the foregoing is true and correct to the best of my knowledge ' ' ' '"' Title S,gned ~//~'~~ Operations Engineering Manager Date · Commission Use Only approval Notify commission so representative may witness I Approval Conditions of No. [] Plug integrity [] BOP Test [] Location clearanceJ ! "'~(_J/,~,,~ ":-~'~' by order of Approved by ~¥ ~""~[ ¢, S~JT~ Commissioner the commission Date~ -~D ' STAT[7/3-2 S A Dige~ (263-4290) ~ Submit in triplicat~. Form 10-403 Rev 12-1-85 BOP sketch [] ARCO Alaska, Inc. proposes to add perforations in DS 3-2 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operations. Proposed Perforation Intervals: 10973-10992' MD (19') 11054-11088' MD (34') Ref: BHCS 5/1/76 R CEIVEI) Alaska ()ii & Gas ,,%ns. Commission Anr:hora. f!e STATE'OF ALASKA ~ ~ ALASK~OIL AND GAS CONSERVATION G,~q~IMISSION WELL COMPLETION ,OR REC-OMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number // ARCO Alaska, Inc. 76-24 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20203 4. Location of well at surface 9~ Unit or Lease Name 1903' FSL, 688' FWL, Sec.11, T10N, ELSE, UM Priudhoe Bay Unit ~ At Top Producing Interval 10. Well Number 1318' FSL, 4390' FEL, Sec.10, T10N, R15E, UM 3-2 ,., , At Total Depth 11. Field and Pool 1369' FSL, 4839' FEL, Sec.10, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 61'I ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/12/76 05/01/76 05/08/76*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11750'MD, 9382'TVD 11635'MD, 9286'TVD YES ~ NO [] 2234' feet MDI 1900' (approx) 22. Type Electric or Other Logs Run D I L/FDC/Cal/GR/CNL, BHC/GR, Mul ti -shot 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE !TOP BOTTOM HOLE SIZE CEMENTING RECORDi AMOUNT PULLED 20" 94.0# H-40 Surf I 78' 32" 300 sx PF II 13-3/8" 72.0# MN-80 Surf 2696' 17-1/2" 5400 sx PF II 9-5/8" 47.0# i~lN-80/Soo 9." Surf 11722' 12-1/4" 1100 sx Class G & 105 ,'~x PF II 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10992'-11010'HD 8764'-8779'TVD 7"/5-1/2" 10630' 10520' .,. 11020'-11044'MD 8787'-8806'TVD 11100'-11140'MD 8851 '-8883'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , 11175'-11195'MD* 8910'-8926'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11220'-11245'MD* 8947'-8967'TVD 11156'-11310' 315 bbl 15% HCL Perforated w/6 Spf, 60o phasing *Perforated w/1/4 spf, 0° phasing ,., 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June, 1977J. Flowing Date of Test Hours Tested PRODUCTION FOR OI L[BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-01L RATIO 07/18/77 2.0 TEST PERIOD ~ 134 52.5 0 15° 32/64 392 Flow Tubing Casing Pressure CALCULATED oIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr) Press.1507 0 24-HOUR RATE ~l~ 1608 630 0 27° AP I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN 1 ~5 1997 Alaska 0il & Gas Cons. C0mmissio,~ *Note: Workover performed 5/2/87. ~_~_~-_ _, ....... t__, Form 10-407 WC3/z:DANI submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29- ~. 30- ; .. GEOLOGIC MARKE£,S "¢-ORMATION TESTS : . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochi t 10970' 8747' N/A Base Sadlerochit 11628' 9280' 31. LIST OF ATTACHMENTS Addendum (dated 5/18/87) 32. I hereby certify that the foregoing is true and Correct to the best of my knowledge , Signed ~//~)~ ,/)/~ .2 ~j~ / .~'//~[ _,- Title Ass°el a~;e EngTM Date ~P'~/-~ 7 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 Wellsi Gas injection, water injection, steam !njection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ Combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in Other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 2'7. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM_ WELL: 4/13/87 5/04/87 3-2 Rn S/L; tag fill @ 11,562'. Set AVA plug in DB nipple @ 10,705'. Perform long term tbg/cs$ tst. Bled csg to 0 psi, left 250 psi on tbg to ensure freeze protection. R__el'd wel~l to Production. Dril~ 'Supervis~f~ ~ STATE OF ALASKA ~ AL~, A OIL AND GAS CONSERVATION CCI,. .SSION REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other WORKOVER 2. Name of Operator ARCO Alaska. Inc. 3. Address P.0. Box 100360 Anchora~e~ AK 4. Location of wel,I at surface 99510-0360 1903' FSL, 688' FWL, Sec.11, T10N, R15E, UM At top of productive interval 1318' FSL, 4390' FEL, Sec.10, T10N, R15E, .UM At effective depth 1361' FSL, 4791' FEL, Sec.10, T10N, R15E, UM At total depth 1369' FSL~ 4839' FEL~ Sec.10~ T10N, R15E, UM 11. Present well condition summary Total depth: measured 11,750'MD true vertical 9382 'TVD Effective dePth: measured true vertical Casing Length Conductor 78' Surface 2635' .Production 11,71!' 11,635 'MD 9286 ' TVD Size 20" 13-3/8" 9-5/8" ' 12. 13. feet feet 5. Datum elevation (DF or KB) RKB 61 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 3-2 8. Approval number 7-?~,1 9. APl number 50---nt<~_~n?n~ 10. Pool Prudhoe Bay Oil Pool Plugs (measured) None feet feet Junk (measured) None Cemented Measured depth 300 sx PF II 139'MD 5400 sx'PF II 2696'MD 1100 sx Class C & 11,722'HD 105 sx PF II Perforation depth: measured. 10,992'-11,010'MD, 11,020'-11,044'MD, 11,100'-11,140'MD, 11,156'-11,195'MD, 11,210'-11,245'MD, 11,260'-11,310'MD true vertical 8764'-8779'TVD, 8787'-8806'TVD,8851 '-8883'TVD, 8895'-8926'TVD True Vertical depth 139'TVD 2696'TVD 9399'TVD 8938 ' -8967 'TVD, 8978 '-9019 'TVD Tubing (size, grade and measured depth) 7"/5-1/2", L-80, tbg w/tail (~ 10,630' Packers and SSSV (type and measured depth) SAB pkr t~ 10,520'& RPB SSSV ~ 2234' .Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. C0mmissi0r~ Anchorage Representative Daily Average Production or Iniection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Feet 14. Attachments r. 1 ~l~ry) Daily Report ~[a~e°l'i'~p~?a~tioHn~ Copies of Logs and Su~eys~ Run [] 15. I hereby certify that the foregOing is trUe and~'orrect to the best of my knowledge ~' ,,~---. ~ ~, -~o~"'2 Form 10-404 Rev. 12-1-8~/ Date.~-//-~'7' Title As?ciete ~neer Submit in Duplicate (Dani) SW02/25 / ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICOunty. parish or borough ]State Alaska North Slope Borough I Lease ADL 28328 or Unit ITitlo Workover Field Prudhoe Bay Auth. or W.O. no. ASll51 Exp / ASl169 Cap Alaska JweI'f_°'2 WWS #1 API 50-029-20203 Operator ARCO W.I. A/~CO Alaska, Tac. Spudded or W.O. begun IOate [Hour IPr or status Workover 4/17/87 0830 Hrs. Date and depth as of 8:00 a.m. 4/20/87 4/21/87 4/22/87 4/23/87 Complete record for each day reported 21.66% if a W.O. 9-5/8" @ 11,722' 11,635' PBTD, RIH W/3½" DP 8.5/8.3 ppg sea wtr/frsh wtr Accept rig @ 0830 hrs, 4/17/87. Att bleed, off w/o success. Displ well w/seawtr; did not receive 8.5 ppg @ surf. Pmp 113 more bbls dn tbg w/7.6 ppg rtns. SITP = 50 psi, SICP = 100 psi. Tbg went on vacuum. Pmp 50 bbls dn tbg. RU S/L to pull tbg plug to spot pill. RIH to pull equalizing prong, POOH; could not get on prong, RD Camco. ND tree, NU & Cst BOPE. Spear tbg & pull hgr to flr. TOH w/3½" tbg. Hole tak'g proper fluid. Chg rams to 3½" & tst; OK. TIH to 2670', set pkr & tst csg to 1500 psi. TIH to 5500', set pkr & tst csg to 1500 psi. TIH to 6000', set pkr & tst csg to 1500 psi. Cont to TIH w/3½" tbg. 9-5/8" @ 11,722' 11,635' PBTD, TOH w/fsh 8.5/8.3 ppg sea wtr/frsh wtr RIH w/RTTS to 10,007', set pkr & tst csg to 2000 psi. RIH to 10,542', tst csg to 2000 psi. Att to tst perm pkr & plug to 2000 psi; bled to 200 psi. Re-tst; bled to 1000 psi. POH w/RTTS. PU OS, TIH, tag PBR @ 10,574', latch onto PBR & att to tst DP; had comm w/300 psi. Rotate K-anchor, TOH w/fsh. 9-5/8" @ 11,722' 11,635' PBTD, LD 3½" DP 8.3/8.5 ppg frsh wtr/sea wtr TIH w/K-anchor on DP, latch pkr @ 10,615', tst ann to 2000 psi. Tst tbg plug dn DP to 2000 psi; OK. Rotate K-anchor off pkr, POH, LD 30 its. RIH w/RTTS & storm vlv, set pkr @ 85'. ND BOPE. Chg tbg spool & pack-off, tst to 5000 psi. NU & tst BOPE. TIH. latch storm vlv, TOH, LD 3½" DP. 9-5/8" @ 11,722' 11,635' PBTD, TIH w/7" tbg 8.3/8.5 ppg frsh wtr/sea wtr LD 3½" DP & K-Anchor. RU & RIH w/7" tbS. The above is correct Signa~ IDate 5/7/87 ITitle Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company ~, Uaily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish IState I Alaska Lease or UnitADLNOrth28328Slope Borough Complete record for each day while drilling or workover in progress Field Prudhoe Bay Date and deptl~ as of 8:00 a.m. 4/24/87 4/25/87 thru 4/27/87 4/28/87 4/29/87 4/30/87 Alaska IWell no. 3-2 9-5/8" @ 11,722' 11,635' PBTD, LD 7" hgr 8.5 ppg sea wtr Rn 182 its, 5½", 17#, L-80 & 65 its, 7", 26#, LTC tbg, space out. PU 7" tbg hgr, attach contrl in, tst to 5000 psi. Fluid fell 12' in ann. Lower hgr below annular, tst pkr to 1500 psi; OK. Displ well to diesel. 700 psi on tbg, 550 psi on ann when fin'd displ'g. Att to bleed dn. Bled total of 49 bbls, press still holding @ 700 psi on tbg & 550 psi on ann. Displ well to sea wtr, CBU & prep to TOH & LD tbg. 9-5/8" @ 11,722' 11,635' PBTD, TOH w/pkr assy 8.7 ppg sea wtr LD 7" tbg & GLM's. Chg rams to 3½", tst to 5000 psi. PU FTA #1, RIH, mill over pkr. Pmp 70 bbls LiteSal pill, bullhead to perfs. Rev circ. Well flowing. Wt sea wtr up to 8.7 ppg, cir~ ,~ & kill well, TOH. PU FTA #2, RIH, sting into pkr, pull free, ~~1~ TOH w/pkr assy. 9-5/8" @ 11,722' !987 11,635' PBTD, Att to fsh pkr 8.7 ppg sea wtr il& ~ .-C0~S. C0~I~iSSi0~ TOH; stuck pkr in FO @ 2624', ~ar free, TOH. PU spear, T S A~C~ ~ fsh @ 2624', jar, TOH; pin parted on XO above spear, spear still in pkr @ 2624'. TIH w/8-3/8" shoe, mill pkr @ 2624', TOH; 90' fsh hung up & fell back to 2624'. Fin TOH; lost shoe in hole. T[H w/PRT, sting into pkr, grapple would not hold, TOH. MU 7-1/2" spear. 9-5/8" @ 11,722' 11,635' PBTD, LD 3½" DP 8.7 ppg sea wtr PU modified spear, fsh mill shoe off of pkr @ 2624'. TIH w/pkr mill, hammer pkr & tail assy free, chase to btm (127' below btm perf @ 11,437'). LD DP to 11,810', circ, monitor hole~ TOH & LD 3½" DP. i 9-5/8" @ 11,722' 11,635' PBTD, Rn compl string 8.7 ppg sea wtr TOH, LD fsh'g tls. RIH w/FTTS & FO fingers; close & tst FO's @ 2415' & 2624' to 2000 psi. TOH, LD 3½". RU $chl, rn CCL/GR/JB to 10,750', TOH, RD Schl. Chg to variable rams & tst to 3000 psi. RU & begin rn'g compl string. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 5/07/87 Drilling Supervisor ARCO Oil and Gas ComPany Daily Well History-Final Report Instructions: Prep~re and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I County or Parish I Alaska Field ILease or Unit I Prudhoe Bay Auth. or W.O. no. ~Title I AS1151 Exp / AS1169 Cap wws #1 Operator 1A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date I Workover 5/01/87 Complete record for each day reported 9-5/8" @ 11,722' Date and depth as of 8:00 a.m. I Accounting cost center code State North Slope Borough Alaska I Well no. ADL 28328 I 3-2 Recompletion API 50-029-20203 cost center prior to plugging and I 21.66% labandonment of this well I Hour Prior status if a W.O. 4/17/87 0830 Hrs. Old TD Released rig 1400 Hrs. 5/02/87 11,635' PBTD, GR/JB rn 8.7 ppg sea wtr TIH w/compl string; tagged @ 5128' & unable to rn deeper. TOH 7 stds, TIH & tagged @ 4908'. TOH, LD tbg. RIH w/magnet to 4650', wrk to 4785', TOH. TIH, latched @ 4795', wrk to 5115', TOH. TIH w/8-1/2" GR/JB to 8600'; appears to be moving junk dn hole. 9-5/8" @ 11,722' 11,635' PBTD, RR 8.7 ppg sea wtr Cent rn'g GR/JB on braided in to 10,650'. TOH to 5000' & TIH to 10,600', RD Otis. RU & rn 45 its, 7", 26# & 182 its, 5½", 17#, L-80 LTC Mod tbg w/SSSV @ 2234', SAB'Pkr @ 10,520', TT @ 10,630'. Freeze protect 500'. Set pkr, tst ann to 2000 psi & tbg to 2500 psi. ND BOPE, NU tree, tst packoff & tree to 5000 psi. RR @ 1400 hrs, 5/2/87. New TD Date 5/02/87 PB Depth Kind of rig 11,635' Rotary Classifications (oil, gas, etc.) Oil IType completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Supervisor O&G 5784 STATE OF ALASIiA ALASKA OIL & GAS CONSERVATION COi-R.[ISSiON B.O.P.E. Inspection Report In~ctor Location: Sec T R M ~Contractor /f!~,/f~.~ Ri Location, General Well Sign~_ General Housekeeping. 'Rig. Reserve pit Hud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Visual Audio DOPE Stack 2mnuiar Preventer Pipe. Rams Blind Rams Choke Line Valves ti. C.R. Valve Kill Line Valves Check Valve Test Pressure ' Representative ~ oo~ ~, .~..~ ~W ~,? w ~' _ Permit # ,' Casing Set ~ ft. ACC~ATOR SYSTEM - . -. Full Charge Pressure ~'~oo psig Pressure 'After Closure_ ,/,,~ psig Pump incr~ clos. pres. 200 psig. Full Charge Pressure Attained: ~ min~ec. psig Controls: Master Remote Upper Kelly~ /Blinds switch cover Ball Type Inside BOP Kelly and Floor Safety Valves / Test Pressure ,~%-'~ / Test Pressure . Test Pressure / Test Pressure Choke Manifold ~-~2est Pressure No. Valves No. flanges Test Results: Failures Repair'or Replacement of failed equipment to be made within Commission office notified. Adjustable Chokes Hvdrauically_operated choke / Test Time ~-~ .... hrs. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector STATE OF ALASKA ,~"~ ALASN, . OIL AND GAS CONSERVATION COMM.~31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1903' FSL, 688' FWL, Sec.ll, T10N, R15E, UN At top of productive interval 1318' FSL, 4390' FEL, Sec.10, T10N, R15E, UM At effective depth 1361, FSL, 4791, FEL, Sec.10, T10N, R15E, UM At total depth 1369' FSL, 4839' FEL~ Sec.lO~ TION~ R15E~ UM 11. Present well condition summary Total depth: measured 11,750 ' MD feet Plugs (measured) true vertical 9382 ' TVD feet 6. Unit or Property name Prudhoe Ba), Unit 7. Well number 3-2 feet 8. Permitnumber 76-24 9. APInumber 50_029-20203 10. Pool hoe Ba None Effective depth: measured 11.,635'MD feet Junk(measumd) None true vertical feet 9286'TVD Casing Length Size Cemented MeaSured depth Conductor 78' 20" 300 sx PF II 139'MD Surface 2635' 13-3/8" 5400 sx PF II 2696'MD Production 11,711' 9-5/8" 1100 sx Class G & 11,722'MD 105 sx PF II ~ueVerticaldepth 139'TVD. 2696'TVD 9399'TVD Perforation depth: measured See attached sheet. true vertical See attached sheet. ~bing(size, gradeand measured depth) 5-1/2", 17#, L-80 to 10,573'MD 4-1/2", 12.6#, N-80 From 10,621' Packers and SSSV(type and measured depth) Camco Bal-O SSSV @ 2133'MD; Baker SAB pkr @ 10,621'MD [}PD0 ' ';n,',. Anchorage to 10,766'MD 12.Attachments Description summary of proposal [] Detailed operations program · BOP sketch 13. Estimated date for commencing operation April 10~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed- ~,~ff/~/~.,,~..,~./l_/j,..l,.A.~ Title Associate Engineer Commission Use Only (JMV) SA2/39 Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity I~ BOP Test [] Location clearanceJ ~,.. ~¢...,~ commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate DS 3-2 Workover Procedure 1. RU slickline unit. Pull SSSV. Run and set blanking plug in 4-1/2" Camco "DB-6" nipple with a 2.25" AVA reduction bushing @ 10,705'. Bleed off tubing pressure and observe well for static conditions. 2. RU wireline unit. Tie-in and perforate tubing @ 10,565'. 3. Set BPV. 4. MIRU workover rig. 5. ND X-mas tree. NU BOP stack and test same. 6. Displace well with 8.7 ppg NaC1. 7. PU Tri-State spear and shear seal assy out of BOT PBR. 8. Pull and lay down 5-1/2" tubing completion assy. 9. Pressure test 9-5/8" csg against packer/tailpipe assy to 2000 psi. Test 9-5/8" packoffs to 3000 psi. 10. RIH w/new redressed seal assy on 7" x 5-1/2" tapered completion string using plastic coated tubing, GLMs, 7" SSSV nipple and tubing hanger. Crossover to 7" above uppermost 5-1/2" GLM. 11. Sting into PBR barrel. Space out, displace well to diesel and land tubing. 12. Test tubing and completion assembly to 2500 psi. 13. Set BPV. ND BOP stack. NU X-mas tree and test to 5000 psi. 14. Release rig. Pull BPV. 15. RU slickline. Retrieve blanking plug from tailpipe nipple. 16. Set BPV. 17. Secure location. Perform long term tubing test. SA2/39b Wel 1 3-2 APPLICATION FOR SUNDRY APPROVALS BLOCK 11 (cont.) Perforation Depths: MD TVD 10,992 -11,010 11,020 -11,044 11,100 -11,140 11,156 -11,195 11,210 -11,245 11,260 -11,310 8764 -8779 8787 -8806 8851 -8883 8895 -8926 8938 -8967 8978 -9019 Anticipated Bottom Hole Pressure: 3850 psi Workover Fluid: 8.7 - 9.4 ppg brine RKB RKB RKB RKB RKB RKB SA2/39a ANNULAR PREVENTER § PIPE RAMS 5 BLIND RAHS 4 TUBIN6 HEAD ;5 1. 1.3-.3/8" CASING HEAD 2. 9-5/8" CASING HEAD .3. 5000 PSt TUBING HEAD 4. 15-5/6" - 5000 PSI BLIND RAMS 5. 1.3-5/8" - 5000 PSI PIPE RAMS 6, 1.3-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2.ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING R E C E iV E D Ar]chor~g~ 1. FILL BOP STACK AND ~ANIFOLD ~ITH A~CTIC DIESEL, 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, P~EDETE~HINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, g. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE HANIFOLD. 4. TEST ALL COHPONENTS TO 250 PSI AND HOLD FO~ 10 HINUTES, 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FO~ 10 HINUTES, BLEED TO ZERO PSI, 5. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS, 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 HINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAH OF CHOKES, BLEED DOWNST~EAH P~ESSURE TO ZERO PSI TO TEST VALVES. TEST ~EHAININ6 UNTESTED ~ANIFOLD VALVES. tF ANY. WITH 5000 PSI UPSTREA~ OF VALVE AND WITH ZERO PSI DOWNST~EAH. BLEED SYSTEH TO ZERO PSI, 9, OPEN PlPE RAHS. BACKOFF RUNNING JT AND PULL OUT OF HOLE, CLOSE BLIND RAHS AND TEST TO 5000 PSI FOR 10 HINUTES, BLEED TO ZERO PS!. 10. OPEN 8LIND ~AHS AND ~ECOVE~ TEST PLUG. HAKE SUrE HANIFOLD AND LINES ARE FULL OF ARCTIC DIEgEL AND ALL VALVES ARE gET IN THE D~ILLIN6 POSITION. ] 1, TEST STANDP!PE VALVES TO 5000 PSI. 12, TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOHEY PUHP, 15, RECORD TEST INFORHATION ON BLOWOUT PREVENTER TEST FORH. SIGN AND SEND TO DRILLING SUPERVISOR. ~4. PERFOR~ COHPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 21 , 1986 ARCO A£aska, I;~.. P.O. Box i00568- Anchorage, Alaska DATE: February 2 6, ~987 REFERENCE: ARCO Cased HoLe Final t-t& 8-5i-86 Reperf. Record 5-2 2-5-8? CoLLar & Perf. Log 5--6 8-25-86 Perf. Record ?-25 ~-24-87 CoLLar & Perf. Log 9-t5 t-25-87 CoLLar & Perf. Log t 4-50 t - .~n-87~. PDK-~ O0 ~6-~? 8-n9-86.- Perf. Record ~6-2~ 8-24-86 Perf. Record Rui~ ~, 5' Sch Run t, 5' Gear Rut, ~, 5' Sch Run ~-2-5 5' Ge,ar Run ~, 5' Gear Run ~, 5' Dre~ Run ~, 5" Sch Run ~ , 5' Sch Please sigo and Recei red By_ HAVE A NICE DAY~ Rosanne F'eek ATO-i 529 re.t ur~ 'the attached copy ~ ceipt' of data. Oil & Gas Cons ~missi0n Anchorage TRAN$ ~871J5 Approved DISTRIBUTION Central Fi [es Chevron D & M' Ex'tension Explorafio~ Exxon Mara fhon Mob i L Phi llip~ PB Well Fi les R & D Soh i o ~"~"~iS'ta'te' of Alaska ........ ~,~ ~ Texaco ARCO ALaska, Inc I::' ~ O. Box AOc:horage, A DATE: October 24 , t986 REFERENCE: ARCO Ca zed Hol_e Final S--2 t8-t1'-86 ' Temp. Log 9-28 1 0-t 5-86 Temp. Log t6-t7 t0-t5-86 Prod. Profi Le/Water t 6-2t t 0-~ 6-86 Prod ~ Run Run t, :5" Holdup Run Profi [e/FD/WaterHo[dup Run ~, 5". CSAI~O Camco Camco Camco F'l. ea~e ~ign and re~urn the att/~ched copy_as receipt of data. Ro~a nne Peek -0il & Gas Cons. ¢ommissio~ A T O- t 5 2 9 ~chorage TRAN$ ~8667t DISTRIBUTION Central Fi [e~ Ch eYr D & M Extension Exp [orat ion E x x o n Marathon Mob i L ~ Phi !. L i p.~ I::'B WeLL F'i Le~ ' R & D ~'~ $ohio -.-'"' State of ALa.~;l<a '"'..' Tex~co " ~ STATE OF ALASKA ~ ~ ALAb,~A OIL AND GAS CONSERVATION COM.,,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 61' RKB ' 3. A~dre~s ....Box 100360, Anchorage, Alaska 99510 6. Unit ~ru~oeer Pr ertYBP~yameonit 4. Location of wellatsurface 1903' N & 688' E of SW Cr. Sec. Attop °fproductiveinterval 1318' N & 4390' E of SE Cr. Sec. At effective depth At total depth 11, T10N, R15E, UM 10, T10N, R15E, UM 1369' N,& 4839' W of SE Cr. Sec. 10, T10N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 11750' feet Plugs (measured) 9382 ' feet 7. Well number DS 3-2 8. Permit number 76-24 9. APl nu0n~9e_r20203 50-- 10. Pool Effective depth: measured 11635 ' feet true vertical 9286 ' feet Casing Length Structural Conductor 78' Surface 2696' Intermediate Production 11772 ' Liner Perforation depth: measured 10992-11010'; 11020-11044' true vertical Junk (measured) Prudhoe ~t~ta~3{{~ml. Emygu S EP 3 0 1986 Alaska 0ii & Gas Cons, C0mr Anchorage Size Cemented Measured depth 20" 300 Sx 78' Bel Pad 13-3/8" 5400 Sx 2696' True Vertical depth 78' 2696' 9-5/8" 1205 Sx 11772' 9403' ; 11100-11140'; 11156-11195'; 11210=11220'; 8763-8779'; 8786-8805'', 8848-8878'; 8891-8920'; 8932-8940'; 8955-8959' ~bing(size, grade and measured depth) 5½", 17#, L-80 at 10579'; 4½", 12.6#, N-80 at 10766' Packers and SSSV(type and measured depth) Baker SAB Packer at 10621'; Camco Bal-0 SSSV n~ppl~ at 21~' 12.Attachments 11240-11245' 11260-11310' ; 8983-9023' Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereb/~ertify th/~t)the/~or~);)ing is true and correct to the best of my knowledge Signed ~//~,~x/~'~_ . . Title ~)~ Commis~on Use Only Conditions of approval [] Plug integrity Approved by Notify commission so representative may witness [] BOP Test [] Location clearance Commissioner by order of the commission Date /' ~ -~/--~ feet~~ Jssion Form 10-403 Rev 12-1-85 W. W. Patterson, ATO-1500, x4372 Submit in triplicate DRILL SITE 3-2 PACK-OFF GLM INSTALLATION PRELIMINARY PROCEDURE . . MI and RU electric line unit. Perforate 5-1/2" tubing at approximately 6392'MD (6000' TVD) Flag line. GIH with retrievable pack-off GLM system and WAK on Baker #20 setting tool. Set pack-off GLM assembly straddling orifice at 6392'MD (6000' TVD). Perforate 5-1/2" tubing at approximately 3513'MD (3500' TVD) Flag line. GIH with retrievable pack-off GLM system and WAK on Baker #20 setting tool. Set pack-off GLM assembly straddling orifice at 3513'MD (3500' TVD). RECEIVED S EP o 1986 Alaska Oil & Gas Cons. Com~i'~ ~¢, Anchorage WWP3/36 1. 5000 PSI ?" WELLH[.AD CONNEC'I'OR IrLANG[ 2. 5,000 PS,~ WIRELINE RAMS (VARIABL[ ..B. 5000 PS~ 4 1/6" L UBR~CA'I'OR 4. 5000 PSi 4 1/6" FLOW 'I'UB[ PACK-OFF 2 RECEI /£O SEP 3 0 1986 Alaska 0ii & Gas Cor~,~, Anchorage I,I ! REL ! NE BOP EOU l PMENT · I I i i ii ii ! i ARC(] Alaska, Inc. F:'.O~ Box i00360 Anchorage, Alaska 995 ~ ~) DATE' JuLy 4 6, t986 REFERENCE · ARCO Cas'ed L~'-'~,.. 7'"2--86 S'-9 6-2S-86 S'- i 6 6'-20'"86 S-Si 7-2-86 S-S2 7-S/4-86 S-SS '7-4--86 S--S4 7-4/5--86 { 2-2'7 6-20/2{ -86 i 4-"5 7-'6-86 Ho Le Fine Prod profi Le Run i 5' Camco GRLog Run i 5" Camco Injec1:ion/t:emp R~n t 5" Camco F'rod prof i Le Run t S" Camco Prod profi Le Run t 5" Camco Prod profi I.e Run t 5' Camco Prod profi Le Run t ~" Camco Injection/letup Run t S' Camco X-Y CaLiper Log R'L~n t ~" Camco Pl. ea.se .~ign and F:.'.ecei vecl By, HAVE: A NICE DAY! L. i nda I..lu Lc ATO--i 529 TRANS ~:8~ copY~ce i pi: o'~a 1:a ~ 1986 Alaska Oil & Gas Cons, commission Anchomoe D I STR I BU'f' I ON · "' Cen1:ra I. Fi Les' ""-..Chevron D & M · .-'"' E x t: e n ~; i o n E x p L o r a t: i o n · "' E: x x o n M a r a 1: h o n '"' Mob i I. · .-'"' I::'h i I. I. i p s' PB WeLl. Fi I. es' R & D '"'-.. $ o h i o -.-'"' $1:a'~e of A l.a~l(a '"' Texaco C) C) :() A T Iii: · ,J a 'n u. a 'r' y 2 2:: 'i 9 8 6 I:t'. E F:' E: I:~: E N C E: ' A F;.: r; r) C: a ~.~' e d H(:)Le F:'inaL Temp L..o9 CF:'S/Sp i nne¥ [:]F:'X./,?p J nnei" E- (] *::' ~ ...... i 'ri <:i i ~ d t t:-: t 4 i i J t !, t..-: t [ ::, ~..., l ,::: :., =... t.: ~.. z ...:t .:> t ..:.... ,:.. i i:.' 4' ~ ,. ,.':.- .::t .5:,' ('."." .5'.'.' . ':ii /I ~ ~ ~ J::: ,:.:.:, ,'.:: (-:-:, i v (..'-.'. ,.':J B':...,' I-.! A V E ~'-"~ N ]1 C Iii] g A Y ! ,~o.,~ 0~1 &,, .~s Cons. Commission (.:-:. I. L y i"'i(:: }::'...':'t '~" i. ,.'..'~ 'n,::l A 'i" O .... i.,.;. ,....:".:',- F' C) T !::' J I. E' A J..:'!i .'."i: J'.'.' ..::'1 P,.C.I,. Box t OG:iz.,6('.'.' I L"!;" I !5:" I '.5:" i I!!;" Ca thc: Ca mc: o Came: o Alasta Oil & Gas Cons. Commission finchorage ARCO Alaska, Inc. ~ Post Office ~ :10360 Anchorage. ~.,.,,SKa 99510 Telephone 907 276 1215 Date: October 21, 1985 Reference: ARCO CH Finals 2-10~' CET Log 3-2J CET 3'11-85 '~6-10 ~CET 3-6-85 7-2-- CET 3-8-85 9-16 ~ Gamma Ray 4-27-85 11-12"CBL 12-13-$4' 13-4 --CCL/Perf 5-8-85 13-25~EPL 13-98'CNL 13-98'CNL 14-2z CET 14-4' CET ~'14-7-' CCL 14-34 ~CET 15-12'CET 'iT-13-CET 17-14~CET 6-30-85 Run 1 5" Sch 4-13-85 8-14-85 8-14-85 6-29-85 6-29'85 4-5 -85 3-~0-85 ' 3-9-85 3-23-85 3-4-85 3-3-85 1 5" Sch 1 5" Sch 1 5" Sch (Recomputed) 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch iI 5" Sch (Epithermal-Recomputed) 15 5" Sch (Thermal-Recomputed)' 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch If 5" Sch . ~' · 1 5" Sch 1 5" Sch 1 5" Sch of d a~a~ Please sign as receipt Para Lambert . ATO 1429C Trans 365 Chevron '~' Phillips -~ D & M PB Well Files Expl. Services" R & D Ext. Exploration ~ Sohi~ Marathon Tmxaco - Mobil ARCO Alaska, Inc. ! Post Office Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 16, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: DS 3-2 Dear Mr. Chatterton. Enclosed is a Sundry Notice for DS 3-2. We propose to add gas lift mandrels to the tubing string. We expect to start this work on November 10, 1985. If you have any questions, please call me at 263-4944 or Eric Witten at 263-4968. Sincerely, d. Gruber Associate Engineer JG/EBW/tw SN/L061 Enclosure ECEIVED Alaska 0it & Gas Cons. ConlmJssior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA :~"~, ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1903' FNL, 688' FEL, Sec.11, T10N, R15E, UN 7. Permit No. 7~-2~ 8, APl Number 50- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-2 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool RKB 61' I ADL 28328 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repairs Made [] Other [] Repair Well [] Change Plans [] Pull Tubing ~pl Other m~itt Pulling Tubing [] (Note: Report multiple co etions on Form 10-407 with a sub ed Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to add gas lift mandrels to the tubing string as follows: 1. Set BPV. ND tree. NU BOPE and test. Pull BPV. 2. Pull out of PBR. 3. POH and LD tubing. 4. RIH with new tubing and gas lift equipment (tubing will be 5-1/2" x 7" tapered). 5. Space out and land tubing. 6. Set BPV. ND BOPE. NU tree. Pu]l BPV. 7. Re]ease rig. A subsequent su~ndry will be submitted following the completion of this workover detailing the completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested ~ ~lr'v~r~i~t~rk. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: November 10, 1985 SEP 2 0 ]985 A~aska b~ & Gas Cons. Commission Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~_/?j~j~ ~ Title Associate Engineer The space belo~/~or Commission use Date COnditions of Approval, if any: Approved by Approved Copy By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 (EUW) 5N/090 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. /*~ ' Post Office B,... ~00360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 16, 1985 Reference: ARCO CH Finals 3-2 PLS 8-10-85 ~ 3-27 Spinner 9-1-85 ~ ~ 9-3 Spinner 8-30-85 ~'~ 9-3 Fluid ID 8-31-85 Run 1 5" DA 1 5" Camco 1 5" Camco 1 5" Camco Please sign as Received by Pam Lambert ATO 1429C Trans 319 receipt of data. Alaska 0il & Gas Cons. Commission Anchorage ChevroW Phillips~ D & M PB Well Files Expl. Service~ R & D Ext. ExploratiOn Sohi~ Marathon Tsxaco ~ Mobil~ ARCO Alaska, Inc. ~ Post Office B(, ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 10, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 3-2 DS 3-27 DS 3-28 DS 3-29 DS 3-30 Permit No. 76-24 Permit No. 84-62 Permit No. 84-72 Permit No. 84-79 Permit No. 84-83 Enclosed is the Completion Report for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/cb Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 3-2)W4-3 Pi(DS 3-27)W4-3 Pi(DS 3-28)W4-3 Pi(DS 3-29)W4-3 PI(DS 3-30)W4-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -? ~ STATE OF ALASKA -,.-k~ ALASKa. AND GAS CONSERVATION CO~ .211SSION 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. 76-24 ' 3. Address 8. AP~I Number . . P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20203 4. Location of well at surface 9. Unit or Lease Name 1903' N & 688' E of SW cr Sec. 11, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1318' N & 4390' W of SE cr Sec. 10, TiON, R15E, UM DS 3-2 At Total Depth 11. Field and Pool 1369' N & 4839' W of SE cr Sec. 107 T10N~ R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Prudhoe Oil Pool 61' RKB~ ADL 28326 12. Date Spudded 13. DateT.D. Reached, 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. N°.°fC°mpleti°ns 04/12/76 05/01/76 05/08/76 N/A feet MSL S~ngle 1,7. Total Depth (MD+TVD) ilS. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11750' MD 9382' TVD 11635' MD 9286' TVD YES~ NO[]I 2133 feetMD 1900' (Approx.~ 22. Type Electric or Other Logs RUn DIL/]~DC/CALTp~.R/GR/CN~; BBC/(~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · SOO-q5 10R =~ Pl~ TT ~m~ 24. Perforations. open to Production {MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and; number) SIZE DEPTH SET (MD) PACKER SET (MD) *10992'-11010' MD *added on 8-10-85 5~" 10766' ~n~, . '11020'-11044' MD w/6 SPF *11100 ' -11140' MD 26. ACI D, FRACTUR E, CEMENT SQUEEZE, ETC. 11156'-11175' MD **re-perf'd on 8-10-85 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED **11175'-11195' MD w/1 shot/4 ft N/A 11210'-11220' MD **11220'-11245' MD TVD of perfs': ' 11260' -11 11 nl M~ 876/: '-90!9' 27. PRODUCTION TEST Date First Production I IVtethOd of Operation (Flowing, gas lift, etc.) June 1977[ Flow~n~ Date-of Test Hours Tested PRODUCT/ON FOR' OIL'BBL GAS-MCF WATER-BBL CHOKE SIZE /GAS-OIL RATIO 7-18-77 2.0 TEST PERIOD I~ 1 ¥. ";~ 0 15-3~ I~.~/ lOlL GRA~/'i¥~Y:API (c~'r~' Flow, Tubing Cas~.ng Pressure CALCULATED OiL-BBL GAS-MCF WATER-BB L Press. 3.507 0 24-HOUR RATE ~ 160R R'~O 0 97° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED SEP1 Alaska 0il & Gas Cons, Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ...;. · . .... G.Eo~oGiO. MARKERs . . . I 30 .............. ' ' . ' . .. : i: . .i ,. i!':.": :.. '..: . · NAME Include interval test{~d, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit -10,970 ' 8747 ' Base Sadlerochit 11,628' 9280 ' : · 31. LIST OF ATTACHMENTS , . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~~~~ Reg. Oper. Engr. Signed v- - - Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. f Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 10, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 3-2 DS 3-27 DS 3-28 DS 3-29 DS 3-30 Permit No. 76-24 Permit No. 84-62 Permit No. 84-72 Permit No. 84-79 Permit No. 84-83 Enclosed is the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells Very truly yours, D. F. Scheve DFS/JEB/cb Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 3-2)W1-3 PI(DS 3-27)Wl-3 Pi(DS 3-28)Wl-3 P1 (DS 3-29)W1-3 Pi(DS 3-30)W1-3 RECEIVED Alaska 0~1 & 6as Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-24 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20203 4. LocationofWell Surface: 1903' FSL, 688' FWL, Sec. 11, T10N, R15E, OM At total depth: 1369' FSL & 4839' FEL, Sec. 10, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 61' I 6. Lease Designation and Serial No. ADL 28328 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-2 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate} (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 8-10-85. RU perforating unit and pressure tested equipment. RIH w/gun #1 to shoot 11220'-11245'MD (1 Shot/4 ft; 7 shots total). Shut in well, POOH, all shots fired. RIH w/gun #2 to shoot 11220'-11240'MD (6 SPF). Shut in well, POOH, all shots fired. RIH w/gun #3 to shoot 11175'-11195' MD (1 shot/4 ft; 5 shots total). Shut in well, POOH, all shots fired. RIH w/gun $4 to shoot ll120-11140'MD (6 SPF). Shut in well, POOH, all shots fired. RIH w/gun $5 to shoot lll00'-lll20'MD (6 SPF). Shut in well, POOH, all shots fired. RIH w/gun #6 to shoot 11020'-11044'MD (6 SPF). Shut in well, POOH, all shots fired. RIH w/gun #7 to shoot 10992'-11010'MD (6 SPF). Shut in well, POOH, all shots fired. Secured well, RD. Ref: BHCS ~-1-76 RECEIVED 0,~ ~ c,-us C0r~s. C0rnmissJ0, Anchorage 14. I hereby c/~rtify that the foregoing is true and correct to the best of my knowledge. /? Si.n.d T,t,e The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: August 23, 1985 Reference: ARCO CH Finals _~i-iA ~ CNL 5-17-85 Run 1 5" GO '~'~1-9' Spinner 8-17-85 1 5" Camco 3-2' Spinner 8-17-85 1 5" Camco ~3-4~'~ Spinner 8-17-85 1 5" Camco 4-9~ Spinner 8-19-85 1 5" Camco Received by ;-;, ' . r',..~...;~.,;~ rt ? 27X .... :'": Pam Lambert ATO 1429C Trans 286 Chevron Phillips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon Texa co Mobil ARCO Alaska. Inc. ts a Subsidiary of At ~nti~C~i~-hf ,- ~ .... 99~'i 0 O~..-,-r.:'. Nr'~v~::,mher 2, i'984 :,.~-..,"r:r,~:,'-.zu, r: ARC:O Cased Hot. e F~'r'.,al..s i 0-- 'i 7 ...... i iii:-- O 4 ' Te m F:' e r a I' ti r e R 5:F, i r~r~er L. og Fi:. ,?p i r.,r.,er L. og F-:..' l':, ~':, :::.. !' h '~'" ..... * C a ...... ,., ~.;.. ~. £-.': ~" Iii i l'i .3: i o i'l EF:'I... F':,' R e c: o r ,::i R e c: o r d · . f Alaska Oit & Gas Cons.P. ommlss~on' ' .. ,'-.:= ¥ P'ICP aT' LaTid A 'f' [} -" 'i'.; 4. 2. 9 F: Ch (aVl" i) & Exp Lora-t: i o'o :'-.;er v i c:c-:,:i:: E:' 4- ~..x't'E'IqS.: i nl-~_ t..xp LoI-a~ i. Oiq E x x o ;q get±y Ma r a '? h o '.,'~ Mobi L ~";r'hi t E: & F:' ! t ...I 1.. F'hi L L i p:=:: F:' r u. c] h (::: c.:, .T.~: .,..-i y t.,J e L i. R & D 'Y'bh io ,?ta.4:..e o'f" A l.a.'..~l..'.a F:' i L e ~: ARC° Alaska, Inc. /~'~ Post Office B _.~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 19, 1985 Mr. C. V-. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dri~ve AnChorage, AK. 99501 SUBJECT: DS 3-2, 3-3, 'and 3-15 Dear Mr. Chatterton' Enclosed workover tubing. are Sundry Notices for the subject wells..~ We propose to the above wells installing new gas lift equipment and This work is scheduled beginning November, 1985. If you have any questions, please call me at 263-4610. T. L. Fithian Area Drilling Engineer TLF/ELC/tw .SN/L018 Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I-1 COMPLETED WELL OTHER [] 2oNameof Operator ARCO Alaska, Inc. 3. Ad~r. es~). Box 1003(;0, Anchorage, AK 99510 4. Location of Well Surface: 1903' FSL, 688' FWL, 5ec.11, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 61 ' 12. I 6. Lease Designation and Serial No. ADL 28328 7. Permit No. 76-24 8. APl Number 50- 029-20203 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-2 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~;~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date ofstarting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a workover on 3-2 in October, 1985, to install gas lift mandrels. The workover will be executed in the following manner= 1. Install blanking plug in packer tailpipe assembly. 2. Circulate well to brine workover fluid. 3. MIRU workover rig. 4. ND tree. NU BOP stack and test. 5. Pull 5-1/2" completion assembly. 6. Run 7" x 5-1/2" tapered tubing string with gas lift mandrels. 7. ND BOP stack. NU tree and test. 8. Displace we, ll to crude oil, leaving diesel cap on annulus. 9. Pull blanking plug and install SSSV. 10. Secure well and release rig. RECEIVED 2 2 ]985 Alaska 0JJ & [~aS CONS. Commission Anchorage A subsequent sundry will be submitted following the completion of this workover detailing the new completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. 14. I hereby certify that the/ff)regoing H Signed "~ Z-' '~'~ '~ The space below for Commission use is true and correct to the best of my knowledge. Title Area Drillinq Enqineer Date Conditions of Approval, if any: Approved by Approved Cogy Returned By Order of COMMISSIONER the Commission Form 10~,03 Rev. 7-1-80 (ELC) SN/036 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ;".AYE' November 2, i9'8'" £.,'.. ~ REFERENCE' ARCO C'ased Ho Le Fins D~ ~-;. i -8 i D, ~';, 3-24 I O--i 2-.8-"-:- D,.?, 3-26 i0-!4-82 -"" - '-"." '-; 9 ---,.~ -8 ,i. [.'., ~<-...', ~, ._:,._ D :'7 ~.:- · n -'-i S-c''z~ ):) ~ :'--,'. 6-. 2..i 'i 0 .... i -<'%--8 4 - : .'r: ~:,. 'i ,:.. -'. 'i ,, : .... ,- :..-, ' ':':-'-' ' ;"'"-' 'i 'i __ c:.:,:,., · ; -': -.. C:.' .4 D ~.' 'I ";"'-' ':" 4 .,-:-,_ 'i ,' · '2' _. -") i_1 "' ' '-, ' ~...r: ,. 2? ,. i .... -.' r' -- Cl, .... :::, :+ D S i ";"'-"-"'~ -' ..... .,.. : -i -'84 :~-. n, .1' i 4-- i ::.-' o_ .,': _. ,:: .,'... ·. ,~, ~, ~- ~. ~..., ..y :...~ ¥", <" 4 c:' .-"'~ /: .,_.'..'..~ i4"-i'"' '::"- '..? ~...~ j _2 '-' -%~.: 'Y P ~ z':t, i 4-3'J ,.,-i ,'-84 P ~ .'-.-." ~ ! 4- --.S i 8 -- i6 --84 n .:., :...-. ~-:.:_., 8-i4--84 i..- ;. ... 1:_-} ~: 'i r.:- .-.. r, .'.::-' .... ,; ~-.': .... c:, .~ ~ ~ , _.'- -- ~:: -'.:.: ~._: .: ~:' ~...: -y D,."?, i 5-20 8-i 4--84 ¥,, : :.., S ~ ':. 4-'~ ..'.}H c:: :.':-" a-i.. e PLease sign and 'r'e±u.'r'n f. he ai'i'ached c:c.:.:.r.::'.-.,--' a.'..' 'rec:eiF.:t c:.f cia'~'a',.,. R .-:: e i veal :-:'..:..-'_ .... HAVE: A .Ni'-'~'' il)AY! i.... iS. ,,,-:-v" L Ly Hc i:':..':'.~'r, i..::': ~"~d A "[' I-J -' '~_ ~.2r;:~.-.' r' . ~ AlasKa Ch ev'r on Exp Lora I' i o'n ~:,':,r v i c:ez .... Ex t:e'ns+, i on .Exp Lora +. i o'n Ex xon ARCO Alaska, Inc. Post Office BO,"'~O Anchorage, Al,_ .a 99510 Telephone 907 277 5637 February 16, 1983 Reference: Arco Pressure ,-,pata ,, '. -.'.~ D.S. 2-26 2-2-83 Static Survey Camco D.S. 3-2 1-28-83 Build-up Camco 1-28/28-83 Build-up Survey Report D.S. 3-15 1-14-83 Build-up Otis · 1-14/15-83 Build-up Survey Report D.S. 12-14 12-5-82 Build-up Otis 12-5-82 BUild-up Survey Report ease sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 143 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS SOHIO MARATHON CHEVRON D&M STATE 0~~-~ DALLAS ~ CAROLINE SMITH ~las~a ARC© Alaska, Inc. Post OflicP-~qox 360 Anchorag .laska 99510 Telephone 907 277 5637 March 8, 1982 Reference: ARCO PRESSURE DATA D.S.3-1'I 2/11-13/82 Pressure Survey D.S.3-4 1-16/18-82 Pressure Survey .. D.S.3-2 2/10/82 Pressure Survey sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 16 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY ~RATHON STATE OF ALASKA CHEVRON Gas, Cons. ARCO Alaska, Inc, Post Office Bf.~60 Anchorage, /:' ~a 99510 Telephone 907 277 5637 January 21, 1982 Reference: ARCO PRESSURE DATA D.S.9-3 .. D.S.3-4 D.S.17-6 D.S.3-2 D.S.17-1 D.S.9-1 D.S.16-16 D.S.16-1 D.S.4-7 D.S.9-8 D.S.16-11 D.S .9-5 D.S.9'15 D.S.4-6 D.S.9-6 D.S.3-18 D.S.9-4 D.S.9-12 D.S .9-10 D.S.3-6 D.S.3-7 11.!~0/81 Pressure Surve~ 11/20/81 " " 11/15/81 " " 11/19/81- " " 11/15/81 " " 11/21/81 " " 11/15/81 " " 11/14/81 " " 12/2/81 " " 11/15/81 " " 11/14/81 " " 11/22/81 " " 11/24/81 " " 11/25/81 " " 11/16/81 " " 11/19/81 " " 11/21/81 " " 11/20/81 " " 11/20/81 " " 11/18/81 " " 11/18/81 " " DISTRIBUTION ~~en retur~ sign and the attachedNORTH GEOLOGY R&D copy as receipt of DRILLING data. PHILLIPS D.S,9-6° 12/9/81 D.S.9-6 1/1/81 D.S.9-17 12/10/81 D.S.9-6 12/23/81 ,,~D.S.9-6 11/30/81 D.S.12-9 1/4/82 D.S.12-10 1/3/82 D.S.12-12 1/2/82 D.S.12-11 1/2/82 D.S.16-9 1/8/82 EXXON MOBIL GETTY D&M Pressure Survey II 11 !1 II II I1 II II II I! !1 II I! II I1 II Mary F. Kellis North Engineering SOHIO MARATHON CHEVRON GEOLOGY STATE OF ALASKA Transmittal #902 ARCO AlasKa. inc. is a $~t;.s~dlar'y o! AHant~cflichlie~dCo,-npany ARCO Oil and Gas/,..~mpany North Alasl~ ~istrict Post Office box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 13, 1981 Reference: ARCO Pressure Data D.S.3-2 3/27/81 Pressure D.S.9-3 3/29/81 Survey ......3 E !"..i G [ 4 ENG ..... s r, ,T STAT TEC-] "CONFER: [ FILF! ..... ~'/Please sign and return the attached copy as receipt of data. Mary F. Kellis North, Engineering Transmittal #179 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG~ MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division o! AllanticRichfieldCompany ARCO Oil and Gas Company Post OIf~co _ .;x 360 ;,ncnor~qo. Alaska 9~5!0 Tete~hon~ {~07 277 5S37 August 8, 1980 Reference: ARCO Cased Hole Logs ~ 6/27/80 Caliper Run 1 D.S. 3-3 6/27/80 Caliper Run 1 5" D.S. 12-4 6/14/80 ACBL/VDL Run 1 5" " " " Diff. Temperature Run 1 5" " " 6/14/80 Fluid Density _~7 Run 1 5" " " 6/15/80 Fluid Density Run 2 5" " " " Sonan Run 1 5" " " " Spinner/Flowmet er 5" "D.S. 12-4 6/15/80 Diff. Temperature Run 2 5" ~/Please sign and return the attached copy as receipt of data, K. J. Sahlstrom North Engineering TRANSMITTAL #536 DISTRIBL~rlON North Geology Exxon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology ~rathon State of Alaska Chevron Alaska ARCO Oil and Gas Company is, a DI,lision of AHandcRichfieldCompany .,\ n c,q o r a'~,_ ,laska '3D5 10 Telephone gO7 277 5637 August is 1980 Reference. ARCO Magnetic Tapes D;~5/18/80 Tape #60520 ~_~S..__~-2~2~9/~0 Tape #60264 -::~]S. Nz'[ 5/15/80 Tape #60502 D.S. 4-15 11/27/79 Tape #60154 , D.S. 5-5 5/16/80 Tape #60500 ~se sign and return tile. attached copy as receipt of data. K. J. Sahlstrom North Engineezing TRANSMITTAL #511 DISTRIBLrFION North Geology F~x~x o n R & D bIob i 1 Drilling Getty Eng. Mm~ager' Phillips D & ~I Sohio Geology ~.Iarathon State o£ Alaska Ote¥~on / : AF~CO Oil ,ina Gas Company ,s a D,v,s~on ol Atlanhc R,chlieldCompany ARCO Oil and Gas Company '!~':~ ,, · . i- .--..''~:..:.,;.~: '- :. '.' '.,":' ?,'; 5¥i:'.; March 24, 1980 Reference' ARCO Cased Hole Logs 6/12/79 Spinner Flo~neter 5" 6/17/79 Spinner Flolog 5" · . - 6/2/79 Spinner Flo~neter Run 1 5" D.S. 5-15 6/15/79 Spinner Flowmeter 5" ease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL # 201 , ,, · .., DISTRIBI~ION North Geology R & D Drilling Eng. ~bnager Geology State of Alaska Exxon Mobil Getty Phillips · Sohio blarathon CheYTon ARCO Oil and Gas Company ! · ' . ~ -. ! -, : · ~. March 18, 1980 Reference: ARCO Cased Hole Logs z/ /8o z D.S. 3-2 2/10/80 EPL Run 2 5" D.S. 14-8 2/16/80 Dummy Gun Run Run 1 S" .S. 14-8 2/16/80 .Thru-Tubing Caliper Run. 1 PleaSe sign and return the attached copy as receipt of data. 2 fi S" Csame log:) K. J. Sahlstrom North Engineering TRANSMITTAL # 170 DISTRIBL~ION North Geology Exxon R & D Mobil Drilling Getty Eng. b~nager Phillips D & M Sohio Geology ~rathon State of Alaska Chevron December 18, 1979 'N / Reference' Enclosed are Pressure Surveys for the following A~RCO wells' 8/7-8/79 Camco ,, D.S. 4-6 11/19/79 Gearhart-Owen D.S. 5-2 8/27-28/79 Camco D.S, 7-2 - 11/4/79 Gearhart-'(~ven I).S. 7-14 11/10/79 " D,S, 9-3 10/27-28/79 Camco I).S. 9-1:2 10/24-25/79 Oamco Please sign and return the attached copy as receipt of data. K. J, Sahlstrom North Engineering 5'19 ])iSTRIBUI'!OX Nort]t Ceo].ogy R & ]') h'illing Brig. Hanager C;eol o~y State of Alaska Mobil getty Piti ], l So]~io Chon'on North Arnz~'~roducing Division North Ala Post OfFice ~ox 360 Anchorage, Alaska 99510 Telephon s~ 907 277 5637 .September 4, 1979 KVP -- ' 'i RES __ I J__.2.ENG .... J 3 I 4 FILF: .................... Reference- ~nclosed are reports from a pressure survey on ARCO .~p~elaD.S. 3-2 dated July 2, 1979. se sign and return the attached copy as receipt of data. Very truly yours, K, J. Sahlstrom North Engineering TRANSY4ITF.~ # 309 DISTRIB0'FION North Geology Kxxon Dri] 1 ing Mobil Eng. Manager Getty R & D . Sohio Ceo log)' Marathon State of Alaska Phillips D & M Chevron Po'..l OHice lBox Anchoraco - Ala3ka 0.3518 Telephol )7' 277 5837 August 23, 1979 Re ference · ' I l__kSrArr '..r Enclosed are Pressure Surveys for the following ARCO wells' :. 2-1 2-2 C D.S. 2-6 .S 2-9 ', jD.S. 2-1 D S 2-5 S 2-2 Hesvlett Packard pressure Data 8/2/79 " 8/10/79 " ,, 6/27/79 ..~"'¢'~','~-/}'/-/vO ,, 4/30-5/1/79 4/18/79 4/20/79 " ,, 3/11/79 ', ,, 3/7/79 ' ,, ,, 3/10/79 ,, ,, 3/ .3/79 ,, ,, BHP Buildup and Flow Profile Survey II please sign and return the attached copy as receipt of data. Very truly ),ours, R. A. Bellinger North Engineering TRANSMITTAL # 286 Di STRI BUI'I ON Nortlt Geology 1)ri 11 i. ng Eng. ~!anager Ceology Sta~e oF Alaska Exxon ~x lob i 1 (;et ty Sob io ,xI;t r;t tl ~on' P}~J. 1 [iI)s Chevron I-'OS[ UiilCO J'.{ox ~50 Anchor~'-"~aska 99510 Telepho, 7 277 5337 August 17, 1979 Reference' Enclosed are ~the following Cased Hole logs.: 9/25/78 Differential Temperature Log 9/25/78 6/27/79 Spinner Flolog 6/27/79 D.S. 3-2 6/27/79 Casing Collar Log 6/27/79. WGI-1 8/7/79 Compensated Neutron 8/7/79 Please sign and return the attached copy as receipt of data~ Very truly yours, R. A. Bellinger North Engineering TRANSMITTAL # 277 DISTRIBUI'ION North Geology F.x xon Drilling Mobil Eng. ~Ianager Getty R. & D Sohio Geology Marathon · State of Alaska Phillips D & bi Chevron Post O,'~ox 380. AnchoF daska 99-5'10 Telephone 907 277 5837 August 7, 1979 Reference' Enclosed are Cased Hole Logs. for the following ARCO wells: D.S. 7-14 6/8/79 6/4/79 6/6/79 6/5/79 Compensated Neutron Run: 2 5!: Spinner Log S" Spinner Log 5" Spinner Log 5" Please sign and return the attaChed copy as receipt of data.~/' Very truly yours, ~. A. Berlin§er North Engineer~n§ TP&NSMITrAL # 254 DISTRIBUFION North Geology · Drilling Eng. Manager R&D Geology State of Alaska D&M Exxon Mobil Getty Sohio blarathon Phi 11 ips Chevron ARCO. Oil and Ga~"~mpany Alaska Post Office r~ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 16, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchora§e, AK 99501 Subject: DS 1-6 Permit No. 75-13 DS 2-3 Permit No. 70-41 DS 2-11 Permit No. 77-63 Perm.it No. 77-71 Permit No 76-24 Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report and Completion Report detailing the work done on the above-mentioned wells.. Very truly yours, P. A. YanDusen District Drilling Engineer PAV: cs Enclosures RECEIVED ARCO Oil and Gas Company Is a Division Of AllanlicRichfleldCompany Form SUBMIT IN DUP~-,. ~TE* .o '- STATE OF ALASKA (see other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la.,¥~ o~ w~L,: o~,~Lr~ GAS ~ WELLL_J DRY ~-~ Other b. TYPE OF COMPLETION: NEW WORK I---~ DEEP- PLUG [--! DIFF. ~ Producing WELLE~] OVER I I EN F--1BACK.I I RESER.I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR - P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1903'N & 688'E of SW cr Sec ll, T10N, R15E' UM At toP prod. interval reported below 1318'N & 4390'W of SE cr Sec 10, T10N, R15E, UM At total depth 1369'N & 4839't~ of SE cr Sec 10, T10N, R15E, UM 5. APl NUMERICAL CODE 50-029-20203 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 3-2 (14-10-10-15) 10 FIELD AND PODL ORWILQCAT 'Pru~Jlioe B~ Field Prudhoe Oil Pnnl 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 10, T10N, R15E, UM 12. PERMIT NO. 76-24 ~3. DATE SPUDDED4/12/76 114.DATET'D'REACHED5/1/76 !15'DATE COMP' SUSP' OR ABAND'5/8/76 128'I16'ELEVATIONS IDF'RKB'RT'GR'ETC)*Pad E1 ev'. 61' RKB 117.ELEV'CASINGHEAD DEPTH HOW MANY* 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS ll,750'MD 9382'TVD ,635'MD 9286'TVD I Single All None 22. PRODUCING INTERVAL(S), OF THIS COMPLETION -- TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL SURVEY MADE Top Sadlerochit 10,970'MD 8747'TVD' Base Sadlerochit 11,628'MD 9280'TVD Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/FDC/Cal iper/GR/CNL, BHC/GR 25. CASING RECORD (Report all strings set in well) CASING SIZE DEPTH SET {MD) HOLE SIZE 20" 94# Vetco ' bel 32" 72# Butt 9-5/ Butt CEMENTING RECORD AMOUNT PULLED 26. ?~ PERFORATIONS OPEN TO PRODUCTION ~11,285' - 11,310' .t.~;'-q -~11,260' - 11,285' ~ ¢'~11,210' - 11,245~ LINER RECORD 27. SIZE i TOP (MD) BOTTOM (MD) SACKS CEMENT* (Interval, size and number) 11,156' - 11,195' w/4 shots per ft. .TUBING RECORD SCREEN (MD) SIZE DEPTH SET {MD) PACKER SET (MD) 766' 10,621' 29. ACI____D, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTEr'AL(MD) I AMOUNT AND KIND OF MATERIAL USED 11,156-11,31'0' 1315 bbl 15% HC1 I 30. DATE FIRST PRODUCTION IPRODUCTION June 1977 I Flowing DATE OF TEST. JHOURS'TESTED ICHOKE SIZE PROD'N FOR 7-18'77 2.0 1 5032/64 ITESTPERIO2 FLOW TUBING CASING PRESSURE CALCULATED OIL-BBL. PRESS.1507 0 - 1608 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) Reinjected 32, LIST OF ATTACHMENTS PRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) I WELL STATUS (Producing or I shut-mn) Produci n9 OIL--BBL. GAS--MCF. WATER--DB L. I GAS--OIL RATIO I I 5 .5 .I0 I GAS--MCF. WATER--BBL. I OIL GRAVITY-APl (CORR.) 630 I 0I 270 API ITEST WITNESSED BY 33. I hereby certify that the foregoing and attached information is cop3plete and correct as determined from all available records. S,GNED..~/~'- ~~ T,TLE District Drilling Engineer *(See instructions and Spaces for Additional Data on Reverse Side) DAT. 7/16/79 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report o.'~ this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ; 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME None MEAS. DEPTH TR0'E VER'~.' Top Sad]erochit 30,970' 8747' ., ," Base Sadlerochit 11,628' 9280' ., · 36. C~)RE DATA, A~'TAcH BRIEF 'DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS ,. AND DETECTED SHOWS OF OIL, GAS OR WA'FER. ,,, · None Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L ITl GAs I'--I WELLI" ! WELLi I 'OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1903'N & 688'E of SW cr Sec ll, ~10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 61' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20203 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 3-2 (14-10-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 10, T10N, R15E, UM 12. PERMIT NO. 76-24 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L.~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING ~~)~1( )0X~ ACIDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.15ROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 6/18/79 Rigged up for acid job. Acidized with 315 bbl of 15% HC1 followed by 118 bbl diesel ~/7'% U66. Displaced with 274 bbl of diesel. Shut in for 1 hour. Flowed well for clean'up. Shut in well. Released well to Production Department 6/22/79. NOTE: verbal approval to acidize was received by C. J. Sevcik from Russel Douglas on 6/22/79. 16. I hereby certify that the foregoing is true and Correct 7/1R/7q (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side North American Pro-:~ucing ~;~" Anchorage, Alaska 99510 Te!ephcme 907 277 533'7 April 10, 1979 ,. Reference: Enclosed is the following pressure-survey- ~. DS 3-2 3/27/79 Please sign and return the ~opy as receipt Sincerely, of data/~~ V.G. Reimers North Engineering I%~NSHI TTAL #149 DISTRIBUTION North Geolo~, Drilling Eng. Manager R&D >~ -. ~ . ~..~.,~:~ ,. ,.. Exxon Mobil Getty Sohio ~ra~ton. ~illips Chevron North Alaska Distr~ct Post Anchorage, ~-~la ..... '-39510 Telephone 907 277 5837 October 24, 1978 .. Reference: .... - , Enclosed are the 'following Pressu~iBuild~p Surveys: DoS. #3-4 9/16-17/78 D.S. #3-6 9/19-29/78 9/14-15/78 Please sign an return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #525 ~D TO: $~ ATF~ OF North Alaska l)istrict: T R A N g ~\I I T T A ], Fro;Il: J. A. P, oclK)n/R. A._Lo~ue ;'~'an2-;n~it'.ted herc:v:kth are the :following for the subject we].].' Scale Xerox Sepia -"BL Line Acid or Fracture Treatment Log · ............ BlIP Buildup & Flm~' Profile Survey - . Borehole Geometry Log Carbon Oxygen Log · Casing Collar Log Cement-Bond Log . ........... 7- Compensated Neutron LOg - Cased llole Core Analysis - Interval Core No. ....... -- Core Description (S. xlC)- Interval ..... Core I)escription (Cony.) - Core No. Directional Surv.ey - .......... - Single Shot ~ l'bltishot ']5]gineering Product. ion- Log '~ .... 7~: .....Fluid Analysis · Fluid Density gamn~a Ray Location Plat -Nonthly Well Test l%ta ~Iud Log Perforating Record State Reservoir Pressure Report Surveillance Reports Temperature Log - T.VD Logs - [kiel Induction Laterolog ......... - Compensated Formation Density Log - Compensated Neutron-Fmm~ation 9ensity Log - Borehole Compensated Sonic Log - Porosity Log :cce:i.pt: Aclamw]edged By: "lease Return Receipt To' Ms. R. A. dgue At]antic Rich'Eield (:ompany P. O. }.',.ox 360 Anchorage, Alaska 99510 RECEIVED. Atlantic. RichfieldCompany North Americeq Producing Division - "' ...... North Alask~"~"'"~rict- Post Office B,~.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 16, 1.978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' ~]~S~3~.]~ 31-10-10-15 ) Permit No. 75-75 ~14-10-10-15) Permit No. 76-24 DS 3-3 (13-11-10-15) Permit No. 76-39 DS 3-4 (11,13-10-15) Permit No. 76-51 DS 3-5 (31-14-10-15') Permit No. 76-57' DS 3-6 (11-14-10-15) Permit No. 76-60 DS 3-7 (11-15-10-15) Permit No. 76-53 DS 3-8 (31-15-10-15) Permit No. 76-73' Dear Sir- Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, Frank M.. Brown District Drill ing Engineer /am Attachments F'orm P.- 7 SUBMIT IN DUPLICATE* STATE OF ALASKA (Seeoth,~r m- st ructioBs on OIL AND GAS CONSERVATION COMMITTEE ~ .... '~ i I L I I I WELL C~MPLETION OR RECOMPLETION REPORT AND LOG* 1.a. TYP~ O~ WELL: oil ~ W ELI. W ~LL DB ~ Other b. TYP~ O~ COMPLE~ON: WELI. OVER EN BACK RESVR. Other . D~t,~ ~m 8. UNIT,F~ OR L~SE NAME , , ~u~,,,~ ~. ~',,,~ o~ o~,~on . Prudhoe Bay Unit Atlantic Richfield. CompanS ,. wm~o. ~. ~ o~ o~o~ Bs 3-~ (14-10-10-15) P.0. BOx 360, gnchora~e, ~K 99510 4. LOe~r~O~ OF W~L[ (Re~ort ~ocat~on c~e~r~ and in accordance w~th an~ ,State At ~ufface 1903'~ & 688'[ of S~ cr Sec ]], I10~-R]5[, ~ it top prod. lnt~rval reporte~ below 1318'~ $ 4390'W of SI cr Sec 10 I10R-R15[ ~g Sec 10 I10~-R15[ At total dep~ ~ ~ ~ 1369'R & 4839'~ of SI cr Sec 10, I10R-R15[, ~ 76-24 4-12-76 5-1-76 [ 5-8-76 ·. 28' Pad Elev. ~J' RKB1 11,750'~B, 9382'WB~ 11635" ~, 9286'W~~, aow~.$~n~le - ~o~,,gll ~oo~ ~one ~. P~OD~CING [NT~VAL(S), O~ ~IS CO~P~TIO~TOP, BOSOM, ~ ~MD ~D ~)* 23. WAS ~ SURVEY lop Sadleroch~t 10,970'~B, 8747'W~ Base Sadler0ch~t 11,628'~, 9280'W~ ~ Yes 24. TX~E E~CT~IC AND OTH~ ~OGS CAS~G ~¢O~D (~eport all s~rings se~ in well) 20' 94~ Vetco [ H-40~78' h~l. nd ~. . ~00 s~ Ce~mafrost !! cmt 13-3/8" 72~ B,tt ~ JMN-Rfl J ~figfi'. .J 17-1/P"j sann ~ P~maq~ncf II cm~ ii ~ I I OP~ TO PRODU~ON (interval, size and number) 29. - ACID, SHOT, F;~kC~'URE, C~%IENT SQUEXZE, ETC. ~l ,285' - 11,310' ~-~'~v~ ~1,260' - 11,285' : N/A. $~11,210' - 11,245' ~ 11,156' - 11,195' w/4 shOts per ft. AP1 NUNIF2i/CAL CODE 50-029-20203 LEASE DESIGNATION AND SERIAL NO. ADL 28328 IF INDIA-N, ALLOTTEE OR TRIBE Pr,Jdhn~. Ray Fi el d-Prudhoe SEC.,om~c~ivE~ ~'' a'' Z.,~BOT~O~ ~)~ Pool EST PI-tODU ION FP~ODUCT1ON MEftiOD (FlowiDg, gas lif~, pumping--size and type of pump) IrC'ELL ST~',KIJ~t..(,P~oducin~ or I P~'nd,~ci no DATZ ~i~"rf~?''~, ~[~URS TESTD CI-tOKE SIZE PROD'N PO,R OI~BEL. 7-18-77 2.0 15° 32/64 ~' ] l_q4 G.-tS--MCF. WATEiI--BBL. ~'LOW, TUBING i CASbNG PRESSURE CALCUI.~TE~D OI~BBL. GA~IXCF. Wk~BBL. I OIL GRAVITY-~I (CO~,) t~SS. 4 [ ' ~24-HOUR RA~ I J [ 11 27© ~PT 1507 ~ 0 :' , - 31. ~sPo~n'xo~ o~ o*s (8old, ~ed for ~ei, t Re~n~ected 32. LIST OF ATTACHMENTS J 52~ 5 i 0 I ,,392 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all~ailable records SIGNED ~_~ .~ TITLE Oi strict OrA 11 ing Engineer OATZ _-~- *(See Instructions and Spaces [or Additional Data on Reverse Side) iNSTRUCTiONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in cther spaces on this form and in any attachments. , Items :20, anti :22:: If this well is completed for separatc, prcduction from more than one interval zone (multiple completion), so state i.n item 20, and in item 22 show the p~c. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ackJitional data pertinent to such interval. Itom26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). .... :4. SUMM'&R'Y OF POI'{MATION TESTS INCLUDiN¢; IN'I:ERvAI- T'~+ED, PH~UR~ DATA ~ ~OV~I~" OF OI'L~ GAS, ' .... WA~ AND MUD Top Sadlerochit 10,970' 8747' Base Sadlerochit 11,628' 9380' 3~. C~RE DATA, Aqq'ACI[ ~RIEF D~I~O.~ O~ ~ITJ~OGY, PORO~TY, FRAC~R~. A~~ "~.~ _ DISTPdBUTED TO: STATE OF OF DIVISION OIL & CAS North Alaska Distric~t Engineering T RAN S M I T TA L J. A. Rochon/ R. A. Lo~C~.._e_ .......... Date: _. /o~-~.,~17/ Well Name' Transmitted herewith are the following for' the subject well' . Run No. Scale. BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core' No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot b'Mltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray ' Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog ~dlog- Interval Sample Log (A. R. Cd.) - 'Interval Synergetic Log TVD-DIL · TgD-Porosity Log . Xerox. Sepia BL Line Rec6ipt Aclmo2oledged For: Date.: Please return receipt to' . < A/~t~: Mr. ~onoVan Jackson ~At~antic Richfield Company ~rth Alaska Engineering P. O. Box 560 Anchorage, Alaska 99510 DRILL SITE NO. 3-2 PERFORATE AND CLEANUP RECORD AFE NO. 391409 APRIL 16 - APRIL 20, 1977 Drill Site No. 3-2 was drilled to a bottomhole location in the southwest corner of Section 10, TION, R15E, Prudhoe Bay Field, through the Sadlerochit Formation. Depths of interest are as follows' RKB Top of Sadlerochit Gas/Oil Contact (Not Present) Subsea Datum Level Perforations Water/Oil Contact Base of Sadlerochit PBTD (4/18/77)' No junk in hole Measured Depth.. Subsea Depth Zone O' (+61') 10,970' 8685' 1 O, 836' 8580' 11,114' 8800' 11,156-11,195' 8834-8865' ll ,21 0-11,231 ' 8877-8894.' 11 , 231-11 , 245' 8894-8906' 11,260-11,310' 8918-8958' ll ,384' 9018' 11,624' 9216' 11,590' 9188' UBS Cong. LBS LBS A differential temperature survey was run by Schlumberger from 100' to PBTD for future use as a base survey for monitoring reservoir fluid movements. Schlumberger then ran a cased hole GR/CNL/CCL log, which was subsequently used by Dresser Atlas for depth correlation during perforating. The first'gun run was a 25' gun fired from 11,285-11,310' M.D. The well was flowed on a 36/64" choke for five minutes after firing, with 350 psi FWHP. As turbine metering equipment was not available, BFPD rates were determined by tank gauge of cumulative flow per time period. Tank gauge rate after the first gun run was 3472 BFPD, with SIWHP of 1225 psi. With the well flowing on a 36/64" choke at 500 psi FWHP, the second 25' gun was fired from 11,260-11,285' M.D., increasing FWHP to 600 psi. Final FWHP was 450 psi with SIWHP of 1250 psi. Tank gauge rate was 25 bbls in ten minutes or 3600 BFPD. While again flowing on a 36/64" choke with 750 psi FWHP, the third gun was fired from 11,230-11245' M.D. with a 100 psi increase in FWHP at the end of five minutes. Tank gauge rate was 6048 BFPD, with SIWHP of 1270 psi. The fourth gun was fired while flowing on a 40/64" choke with 975 psi, perforating 11,210-11,230' M.D. The FWHP increased about 25 psi, with 1300 psi SIWHP. Tank gauge rate was 6120 BFPD. The fifth gun was fired while flowing on a 36/64" choke with 1125 psi, perforating 11,175-11,195' M.D. The FWHP showed an increase of 50 psi, with a SIWHP of 1310 psi. Tank gauge rate was calculated to be 5904 BFPD. Although this 20' Drill Site No. 3-2 Perforate and Cleanu/~'~:ecord ~" Page 2 gun had fifteen misfires per 80 total shots, the interval was not reperforated due to wide scattering of the misfires by both depth and phase, as well as the noted increase in flowing wellhead pressure. With the well flowing on a 44/64" choke at llO0 psi FWHP, the sixth gun was fired from 11,156-11,175' M.eD., increasing FWHP to 1125 psi. The SIWHP was 1350 psi with a tank gauge rate of 3768 BFPD over the ten minutes of flowing. AT this time, Camco rigged up 'an Amerada subsurfess pressure recorder to obtain pressure data. After making gradient stops with the bomb, the well was flowed to the test tank for a total of two hours on a 40/64" choke. Initial static SIWHP was 1375 psi, with FWHP 6f 1375 psi after one hour. Final FWHP was 1450 psi. The drawdown volume flowed by tank gauge was 441 bbls in two hours, giving a calculated rate of 5292 BFPD. The Amerada recorded a final drawdown of 222 psi, res~lting in an estimated productivity index of 23.8 STB/day/psi- drawdown. Final SIWHP was 1600 psi by surface gauge. The total estimated surface volumes of reservoir fluids produced during perforating and drawdown are as follows' Cumulative oil production, STB Cumulative gas production, MSCF Average solution GOR, SCF/STB 391 293.2 750 From Amerada gradient surveys, the static bottomhole pressure at the recognized' subsea datum level of 8800' s.s. was 4361 psi. As fishing operations were required to retrieve the Amerada when it was pulled from the wireline, no BHT was recorded. RDJ 5/31/77 North Alaska District Engineering T RAN S M I T TA L To' From: RECEIVED JUN 2 1977 Division o~ 0ii & ~ Oon~arvation Ant, borage J. A. Rochm~./D. R. Jackson. Date' June 14, 1977 Well Nmne: Transmitted herewith are the following for the subject well' Run No. Scale ---I _ Differential Temperature Survey BHC Sonic/Caliper Log BI. lC Sonic/Caliper - Gmmna Ray Log BHC Sonic/Gamma Ray I,og Caliper/CCI, Cement Bond Log/\q)L Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Intenna.1 Core No. Core Description (SWC) - Interval 'Core Description (Cony.) - Core No. l)ireCtional Survey - Gyro Single Shot ~'bltishot Ih-i].1 Stem 3'est - 'rest No. Dual Induction Laterolog Format.ion Density Log Formation Dens.i. ty I,og/Gan~na Ray Gamma Ray/eCL l,aterolog Locat:i. on Plat M:i. crolaterolog Microlog Mudlog- Interval Sample Log (A. R. Co. ) - Interval Synergetic Log T\rD- DI L TVD- Porosity Log D.S. #3-2 Xerox Sepia BL Line · J ea. ~ ea. ICeceipt Acknowledged For' Please return receipt to: ~]lt(L5 Igchfield Company North Al. aska Engineering Manager P. O. Box 360 #486 To' Date: June 7, 1977 North Alaska District Engineering · T RAN S M I T TA L From: J. A. Rochon/D. j~. Jackson -. . . Well Name' D.S. #3-2 Transmitted herewith are the following :for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neut¥on-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot Mul'tishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log' Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat ~Hcrolaterolog ~Rcrolog ~Mdlog - Intex~al Sample Log (A.R. Co.-~ - Interval Synergetic Log %~D-Porosi{y Log *l__~g_llar Xerox Sepia BL Line . Receipt Acknowledged For' Date'. (~vcP .~, /d?~?f-/ Please retu~ receSpt to' c RichfSeld C~an7 ~h ~aska EngSneering Manager P. O. Box 360 . ~chorage, Alaska 99510 #467 TRANSMI TYAL CON 'IDEN.TIAL' "]"'o: o ["ATE' OF AI..~S.I¢.~ ~. · ... .... . -->-DI':{/1sION "OF OiL t~ ~ J. A- Rochon/p. Hellstrom-.' . · Ifell N-_?.-~ :.. Date' ~. '.M~y ]0~1q77 . · , Transmitted herev~-~h are the £Ol!owing for the subject wall:. o. · , Scale :Ro~ No, - - . BHC S6~c/C~~r "~-" ' BHC SO~c/C~ar - G~a Ray J~og Xerox .. Sepim :.- . . ~'.. *~ .o . · . . _ . · '..-~_ _-. _._ '~._ = BHC Sonic/G~-~z Ray,. Log . J -- Caliper/eCL -. .." - .- ..... '~-~-Cement Bona Lo~/t,/~L ' - ' C~~at~ Fo~~on ~~_~ L~g. _.' . .~ ~~~ate& Neu~dn Log . -. . ... Core ~~ - . - Core' No- Core D~s~iption (Cony.) - Cqre No- ' .... - ~ In~uc~oa. Late~olog "'-- - ~a~on Da~i~ Log . ~'-' -~--~~~on ~i~ Lo~a~ Ray- . _ '-. _ . -- Laterolog ',. '. ' ~ ' Lo~tion Plat . ' ~mlog. ' ~~oZ - ' ' S~le Log (A.R.CdO-Inte~) -' : - : S~erge~c Log '- ~-Porosi~ Log . ~_, _ , _ .... , · ~._ ........ ~ -.. ...... ~, ~ ~ -._ .... .- - . ,, . ; - -- --~ - -T .,- -" . "- ' . ~e-eipt Act~owledged For: ..Date: . . ., Atlantic Richfield Co.,.-p. any #553 North Alaska Engineering P. O. Box .360 Iq. Case return receipt to: , Atlant~bRichfieldCompany North American Producing Division North Alas~/'*~"~.trict Post Office. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Dril ~--'~ri 1 Dri 1 Dri 1 Dril Dril Site 3-~(31-10-10-15) Site 3-2~. 14-10-10-15) Site 3-3 (13-11-10-15) Site 3-4 (11-13-10-15) Site 3-5 (31-14-10-15) Site 3-6 (11-14-10-15) Permit No. Permit No. Permit No. Permit No. l-'--~ C. GEOI:~~.. / -'l--C-~..I:~3., / .... F-~ "~'°' "F-- !' '1 '3 ,';N~'~" I' . -' ~ .-, C..-~L ] 30:;C L ! . . I sec I COlqfER: FILE: ~fi-24 ~6-51 Permit ~o. 76-57 Permit ~o. 76-60 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Encl.osure EECEIVED ,t\l ,.- Form 10-403 REV. 1-10~73 Submit "1 ntentions' in Triplicate & "S[Ibsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON .WELLS (Do not use this form for proposals to drill or to deepen Use ',APPLICATION FOR PERMIT---~' for such proposals.) WELL! I OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1903' & 688'E of SW cr of Sec. 11, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 61' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20203 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Drill Site 3-2'(14-10-10-15) 10. FIELD AND 1:~3OL, OR WILDCAT Prudhoe Bay- Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 10, T10N, R15E, UM 12. PERMIT NO. 76- 24 )orr, or Other Data' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L=_J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ~ ALTERING CASING SHOOT I N G~O'R~'A~-iI~iZrN G"t'--~. I ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS: (Clearly state all Dertlnent ¢letalls, anti give pertinent dates, Including estimated date of starting any Proposed work. Began operations @ 0600 hrs on ,4/15/77. RU & tstd perf manifold. Tstd BOP to 5000 psi OK. Ran temp _su~r~m-y~-. ~Put~m~y~l~-~ .... )ta_n~ GR/C~,6.35' .... tolO, SQQ'. P e r ~,5~' -_~~:~-11,260 ' - 11 '285 '~0' - 11,2~4~5 '~'? 11,210' - 11,2~0'.',,.~/~ ~;~.~,.,u -z-.,..+~..~,_<,~,,oo -,,,,/o ~.w sno[s per Ti. K~m-~raa D0mD. Kan a set tlapper -~'~T9'6~'~@'~2~3'~'; ~Tstd~ba3a~nce:'"E'~E'0ntrol lines to 5000 psi OK. Bled press above flapper valve to 0 psi held OK, Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept @ 0600 hrs on 4/27/77. RECEIVED !AY 1'2 1977 Division ~f 0il 16. I hereby certify that the foregoing is true and correct SiGN ED ~./~'Z- ~/~{' /~~ T,TLE District Drillinq En~inee? DATE .I ~j~ ~ (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side · 02-001B STATE of ALASKA DE:PAR~~ OF HATURAL RESOURCES Division of 0ti and Gas Conse~vatlon J--Hoyle H. Hamilton/~ '~~ _ TO: Chie~ Pe~le~ Eng~n~). ~ ..... ~n Le~~n Pet~le~ !n.s~ctor~ DATE : l~y 3, 1977 SUBJECT: Subsurface Safet.v Valve and Surface Controlled Safety Valve Tests on Arco*s DS 3-2 TUesda~.v,_Aprtl 26, 1977 - ! ~Par~ my.~._a[ 2:!5 PM.for a 2:45 PIq 'showup. -'~' ~45 'PM"-~r~re-"'~a ~n'-'~ ~ght'1~ fo~ ~adhorse [ a~d ~n ~adhorse at 6:10 PM a~ p~~ ~ ~tl! si~ ~9 ~ I. con~c~d Mark Major, drilling fo~n, w~ a~ts~ ~sts ~uld ~ a~t midnight. ~dneSday,_ April ~7, tg~- ~rk ~jor p~ck~_F,~,up, at 12:15 AM, but ~sts ~"'~' 3'2'd~d ~t'"~i'n' ~ti~~'''2:'~ ~ d~ to ~c~ica,1 difficulties. The ~s:~D:~;~sj~...,,'~ , ~3~,~' ~''' The SS--.s. clos~ .,--sbu, ,n .b'ng ~s ~ closed ~ p~ssu~ ~s~m b!~ ~o 1~ '~g ~ ~j~o~d ~o~ ~J~ mJnu~s. The S~9 ~s ~n o~n,~ ~nd p~ssu~ ~e ~ ~o' SS~ bl~ ~o 7~ psJg e~ ~~d fo~ ~ve m~nu~es~ T~-~e~ v~l~ ~ S~V ~ ~ c.los~ ~nd ~ests ~ conclud~ ~ 2.2 ~. A ~etd Jn,s~~ ~~ ~s pr~pe~ ~h ~he or~gin~l g~n to ~k ~jo~, · ~p~ ~i1~.,~o ~ ~jnes ~nd · cep~ ~c~ ~ ~hJs ~po~. ~n ,~~~;- ~ ~ss~ s,~c~sful sssv ~nd SC~ ~e.s~s on A~co's DS 3-2. ~u~s~. ~ F~J~. ~1 ~...~d. Zg,..197_7.- ~es~ SS~'s on BP's ~-4, ~-~ and ~7.':""' ~'-"'-'-' ...... ' ......... ' _.. ~~de~. Apr~l .~30. 197~ - ~."de~~, De~d~rse a~ 11 :~ ~ vJ~ BP ch~e~ · Satisfactory..' Type Inspection '-Yes.-~ No Item (..)--Loca~i'on,General ( ) ( ) 1. Well Sign () () () () () () sati sfactory-i' Type InSpection Yes .-N° I'tem ( ) BOPE' Tests . -, (.) ".(~::)' 15. "Casing -set @ ., 2. General .Housekeeping. ( ) ('-) .16. Test f'luid-( )wtr.--~--~ )mud (i') oil' 3. Reserve--Pit-( )open( ';)':filled ( ) ( ) 17. Master Hyd. Control. Sys.- psi. g ( ) ( ) 18. N2 btls. , , ii , psig- 19 Remote Controls _ () () 4, Rig ('l~)~afets Valve Tests 5. SurfaCe-No. Wells 6. Subsurface-No. Wells .( ) Well Test Data .7. Well Nos. , , () () ( ) ( ) 20. Drilling spool- "outl,ets ( ) ( ) -21. Kill Line-( ) Check valve ( ) ( ) 22. Choke Flowline ( 1 HCR valve ( ) ( ) 23. Choke Manifold No. valvs flgs i( ) ( ) 8. Hrs. obser ,__, , ( ) { ) 24."Chokes-( )Remote( )Pos.(,~dj. ( ) ( ) 9. BS&W , , , ,.~ ( ) ( ) 25. Test Plug-( )Wellhd(')csg( )non~ ( ) ( ) 10-. Gr. Bbls~----, , , ( ) ( ) 26. Annular Preventer,____psia ( ) Final Abandonment ( ) ( ) 27. Blind Rams,_____psig ( ) ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams __.psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig ( ) ( ) 14. Pad' leveled ( ) ( ) 31. Safety Floor valves-( )BV ( )Dart Total inspection observation time /~hrs/das~ Total number leaks and/or equip, failures Remarks days or when ready AtlanticRichfieldCom pany North Amer~,Producing Division North Alasl~ Strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1977 Mr. Hoyle Hamilton STate of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 DIR .. Subject: Dril. Z_~ite 3-1' (31-10-10-15) Permit No. 75-75 ~ill S!_te 3-2~ (14-10-10-15) Permit No. 76-24 Drill Site ~-3 (13-11-10-15) Permit No. 76-39 Drill Site 3-4 (11-13-10-15) Permit No. 76-51 Drill Site 3-5 (31-14-10-15) Permit No. 76-57 Drill Site 3-6 (11-14'-10-15) Permit No. 76-60 Dear Si re: Enclosed please find a Sundry Notice outlining our plans' for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure RECEIVED IXvi~ion of 0tl 8nd Gas O~n~orvatlon Form '10-403 /--~, Submit °'i ntentions" In Triplicate REV. '1-10-73 & "Su~.~ent Reports" In'Ouplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (C)o not u~e this form for proposals to drll'l or to ce~-pen U~e "APPLICATION FOR PERMIT--~' for such prccc~als~) OwLLLLI~',',G'ASE LL [=--I .OTHER NAME oF OPERA?OR Atlantic Richfield Company ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF Atsu,ace 1903' & 688'E of SW cr of Sec. ll, TION, R15E, U 13. E~_EVATIONS .',Sr.~.v whether DF, RT, GR, etc.) 61 'RKB -14. Check Appropriate Box To Indicate Nature of Notice, Re 5. Apl NUMERICAL CODE .,, 50-.029-20203 .... 6, LEASE DESIGNATION' ANO SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8'. UNIT, FARM OR LEASE NAME Prudhoe Bay. WELL NO. Drill Site 3-2 (14-10-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 10, T 10 N, R 15 E, UM 1.2. PERMIT NO. 76- 24 3crt, or'Other Data NOTICE OF INTENTION TO: TEST WATERSHU~T-OFF [~ PULL OR ALTER CASING FRACTURE TRE~,T MULTIPLE COMPLETE SHOOT OR ACiD~ZE ABANDON* - REPAIR WELL CHANGE PLANS (Other) Perforate SUBSEQUENT REPORT OF: WATER SHUTqDFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZtNG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROP~'SED OR COMPLETED OPERATIONS (Cleart¥ ~ate all Dertirfent ~letall$, and 91ve pertinent dates, including estimated ~late of starting any pro~.~!~cl work. Atlantic Richfield Company proposes to perforate' selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi Wp wireline lubricator, tested to working pressure, will be utilized with all wireline work. Ail perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The down hole safety valve will be installed and tested upon conclusion of job. Estimated start date- April 26, 1977 RECEIVED MAR 2 1977, Anohoragm TITLE Di stri ct Drill i ng Engineer, DATE., ~A) ,AT (This space for Sta;e office use) '"~:CONDITIONS OF APPROVAL.. IF ANY: See Instructions On Reverse Side ., , DATE 3-30-77 Approved ¢op¥ Refumed Atla~ ,'~i~-~ ichfieldCompany North Ame~'~Producing Division North Alask,. ~J~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 21, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources' 0il and Gas Division 3001 Porcupine Drive Anchorage, AK 99504 RE: DS 3-2 (14-10-10-15) Permit No. 76-24 Dear Sir: We are enclosing the Well Completion Report along with the Well History and Directional Survey for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/j r Enclosures DlVlglOhi O~ OiL AH, P OA3 Form ~ t- SUBMIT IH DUi~:- _.L~ TE * STATE 'OF ALASKA (See other in- siructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: ' ~II, ~;AS WELL WELL Other b. TYPE OF COMPLETION: NEW [~ WOIIK [---] DEEP-EN [---] PLUG ~'~ DIFF. [--] BaCK nESVR. Otherg,, D nd a__sre_._e_ %VELL OVER 2. NAME OF OPERATOR ' Atlantic Richfield ~9mpa, ny 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, AK 99510 d~. LOCATION OF WELL -(-Report location clearly and in accordance with anll State requirements)* At surface 1903'N & 688'E of SW cr Sec 11, T10N-R15E, UM At top prod. interval reported below 1318!N & 4390'W of SE er Sec 10, T10N-R15E, UM At total depth 1369'N & 4839'W of SE er Sec 10, T10N-R15E, UM OKtGINAL $. A~I NUiVIERICAL CODE ~. ~S0-029-20203 6. ~E DESIGNATION A_ND SERLAL NO. ADL 28328 ~. IF I~I~, a~ OR ~IBE Na ~. UNIT,Fa OR ~SE MaE Prudboe Bav - ~ (14-10-10-15) ~ P~L, OR W~CAT Prudhoe Bay-Sadlerochit n. SEC., T., R., M., (~OM HO~ POOl O~IVE) Sec 10, T10N-R15E, ~ 12. P~IT ~O. 76-24 13. DA. TE SPU'DDED ~-12-76 '/1- ~ow 1VIANY* ROTARY TOOLS 11750' & 9382' 695' & 9286' ._ ,qin~la All 22. PRODUCING INTeRVAL(S), OF THIS COMFLETIO~q--zPOP, BOTTOM, I~'AME (MD AND TVD)* Nnne - I 5-8-76 28'Pad Elev. (61ffRKB I INTERVALS DR[LLZD BY 24. TYPE ELECTRIC AND OTHEi% LOGS RUN D,IL, FDC/Caliper/, GR/C~L, BHC/GR ~-$. CASING RECORD (Report all strings set in well) CABLE TOOLS , N ~'1T1 i~ 23. WAS DIRECTIONAL SURVEY NL~DE Yes lb ft '- ~ smuts. Da SET. OW.D) S~E Cm~WTING =CO~ { aO~ PU~ 20" 94~/ vetco [ H-40 }+78' bel D~32" q00 mw pm~m~rnm~ ~ omc 13-3/8" 72~/ Butt' [ ~-80[~696' t r~ Is ~ r~ .~ a~ ~ r::.>, I 5-1/~" 10,,766' 10_621' i U ~ ~JG/ i DI~=TI-I INTF, RVAL (MD) 2 1970 [ N/A , O~ ~ODU~ON DITD FIRST PiOD~C~ON [ BODUCTION ~ETI{OD (?lowing, gas litt, pump~--size and t?pe of pap) N/~A DaT~ OF TruST. ~O~S T~ '~O!~E SIZE [~OD'N FO~ O~MEL. ~CF. , . .: I ,' . 1 . 82. LIST OF ATTACHMENTS AMOUNT ;d~lD KIND O,F M_~TE~AL USED WELL STATUS (Producing or sLut-in) UnDerforated Comnlet ~on WATER~B-B~. [ GAS-OIL I i WA~B~. lOlL GR~V~Y-~I (C~.) TEST WITNESSED BY Drillin~ History and Directional Survey SS. I hereby certify thatth~attached ,nformatlSn is complete and correct as determined from all'available records SIGNED TITLE DATE - *(See Instructions and S~ces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report' and I'og on. all types of lan:Is and leases in ,Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) f'oi"~Jepth measure- ments given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcJucin9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce,."l, show- ing the adkJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). '34. SUMM~ItY OF' FORMATION T~.~'I'S IN¢:LUDIN(;' IN'1'E~VAL TIE'TED, PHF. ssUF~E DATA. ~'~OV~I~ OF OI~ GAS. ' ...... 35. G~GIC MARK~ WAT~ AND MUD Top Sadlerochit 10,970' 8747' Base Sad!erochit 11,628' '9280' ~;. , . ~.,,.. . , .. ~ ~. ,.,~.. ~f~..~,~ ~.~.~: ,~._ ~.~ ....... . .... ... .... ~ .~.~ ...... ~,~. ~.. ..... ~ ....... ~ ~ .......... ~ ~.. , , .i ~L I I ' ' I I 1 ' ~ ~'' ':~" ' ' ' ' "'' I "' ' ' '" ~ -- .......... ..... ' ....... ~' ..... '" ' " . ""'~';-:"'*'~ ....... ~'~ : ' ':' : - ~=,,;, ,~,',,,,i ;,,il ..................... ~ ',~. , , ATLANTIC RICHFIELD COMPANY DS 3-2 (14-10-10-15) API 50-029-20203, ADL 28328, Permit No. 76-24 DrillinR History Spud @ 0700 hrs 4-12-76. Drilled 17-1/2" hole to 2750'. Ran 13-3/8" 72~ MN-80 Buttress csg w/shoe @ 2696', FC @ 2614. Cemented w/5400 sx Permafrost II cmt. Circulated 13-3/8 x 20" annulus thru 2-3/8" risers, blew dry, pumped 150 sx permafrost II. ND 20" BOP, cut 13-3/8" csg, installed and tested p~cko~f. NU 13-5/8" BOPE and test. Drilled FC, shoe and formation to 2760'. Tested formation w/0.65 gradient. Directionally drilled 1Z-l/4" hole 11,750', POH w/multi-shot. Ran DIL, FDC/Caliper/GR/CNL and BHC/GR logs. RU and ran 9-5/8" 47f~ MN-80 & SO0-95 Buttress csg w/shoe @ 11,722', FC @ 11,636' and FO's @ 2360' & 2414'. Cemented w/llO0 sx Class G cmt. Cemented 2nd stage thru FO tool @ 2630' w/lO5 sx PF II. Opened upper. FO @ 2414' and pumped 330 bbls Arctic Pack w/less than 1% water cut on last 69 bbls pack. Tested upper FO w/3000 psi. RIH w/8-1/2" bit and 9-5/8" csg scraper to top of cmt @ 11,516'. Drilled to 11,635', tested 9-5/8" csg w/3000 psi. Reversed hole to diesel w/flow test between steps. In- stalled and tested 5-1/2" rams. Ran 5-1/2" 17f~ L-80 A-B Modified 8rd tubing'w/tail @ 10,766' and packer @ 10,621'. Tested control lines and NU tree. Pulled dummy valve, set packer and tested casing and tubing. Ran dummy gun and reran dummy valve. Released rig @ 0600 hrs 5-8-76. Suspended oil well. JOB NUMBER Eastman w/ ipstOckl A PETROLANE COM~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Rich£ield COMPANY D. S. 3-2 WELL NAME Prudhoe Bay LOCATION A476 TYPE OF SURVEY S0115 Multi-shot DATE 4-29-76 SURVEY BY Jay Martin OFFICE Alaska C,.QM RL E_T. I.QN_RERORY_ ,NiA-~-.20- ~-i.R-7-a- ...... " A_T_L.A N T_.. I.C__R [ CH E.I_E_L.D__.C.O., ......... D_ -. ...................................................... RI_LL_ $iT.E,__3 .... 2- ...................................................... q_AG N E T. IC__~ ULT. I S H 0 T___S U R V_ EY_. ........................... KB-ELE_V_,__~_$_.ET_o .................................................... ' ......................... R E CORD _QE__$ URVE_¥..: ALL ..... CA L, CL~L_A~._I.O.N.5....P E R FO RN E D._B_Y. ..... i B_M ........ E.L.EC_TRONiLC__COMP_U_T..F.R . __ZR_U.E__ ~_E_._A_S_, __DB. I ET___VEB_T_ I_CA L ...... S_U B ................. lER_Tit__ A N G.LE .......... O..E P.T_.H ........... S E A ............. D.I R D M DEG.,_ ZO_IALCO.OR DOC,~..i~EG C-L.-....O.:_.%_U_.. RL_E_..5 .............. $FrVF. R-I-T-Y- $.EGT-.I.ON ' ~AN.CE-, ~_ANGLi_ .......... -OEG-/-1-OOF'-T ........D-I~-AN C.,E- D_._~_. $_ . 7 ~.3,: .... 0__,_5. 7_22.._99.. ~ 661_.9_9__ .S--Il_W__ _LL3_...13__S ...... 814 Q~_3.0_ ........813,99 ....... 7...5.2.,'_99 ....... .$i ._&B__E ....... 1_1:3..,.55____&_ ........ 2-~.,.5_9__E ..... ..__9_0_.5~_0' 45 .....904,.99 ...... 843...,99 $ _7/,_E .... .,1,_i3.,92_S____ 25-,_5_1_..E 99_6 ,Q~5.0., 9.9_5__,_9..8 '_9 3 ~,_98__N__88_E ......... __1_0_8__7.0 30 .... 1.0.8_6,97_ 1025.:..9~. ........ N__@.9__L ..... lA_z+_,_0.4_.5 .....2_7_,_8.3__E ____ _k1_7.._8 .0_1_5L__1.1.7_7_,9_7 k 116, _9.7 ..... N__86_E .... 1.14 ,_0,.2_._S_ ..... 2.8-.42-- E _1/.63~ 0-_3_0___12.6.8.,_9_7.. LZ07...9.7 _S.__i:6_W. :].~/~.._/~8__$ , 28,-80 E _13_61_ Ch_3_O .... 13_6_0_,97 ..... 1299,9_7 ......S_._28_. E ......... 1_15_,2.8__S ..... 28.,-88__F: .... 12 Q,..B2__S__l.3__4.5__]._6__E~_O_.3_7./,_ _ ! 20,.9_9--~__L3_~_7~_E~~ 00 1 !99_9_,_9~ 1_9_3.8_:.9~.___N~ '_85 E .... _1.1_8_,_85_S_ _. 20 9 ~. 9.5 2 0 3:3 ,__9_5 28_,_68 E . _~_0_._17 E 1Zl.,.9_3__sL_i3__3.&_Z_7_E,___~,..7_4.1 ! 22.._ ,_4 ~-&__13___5_4_45__ E-__O_,.&15 .... 1 2 Z_,_4:..3_$__I.{L_I_6,1OL_E .... 0_,_62.._4 ~. L_DB. !EL_V.E._R...I_~._~AL ............. 5WB ............ DR.I_E! ............... I.Ol AL.COQRDI.NAIE.&i ............... £._L_Q..._5._ U_.. R_E... S .............. 5EV.E~i._T_Y .D. .... [',:l ........... _~ D. EG, _: D ....... N $ 2 222 ,.9~ 2.5~.6., 9.~ ..... 2.5.05,.93_ N .... 2.59 9_,.9 ~. ....... 278.8,.9Z N 22 eB_~_~_161 ~ ~.0 .... S ... ~.~8 ,.? 1 .... S. ....... ~6.2 Z ,~7 ..... S_. 3.713. ,. 16 ........ .... ~_8.8_9~ ,_.6_ 9 ........ ~9.7 7., 20 ....... ~3.l_~[_~0_.__~_lL~__~.10.,./~_.k._Si_[~L6j_,.Oi~.~_d5 w 4~2.&,_55___ ~_~5_7 ,..55 .... MEA$, DRIFT DEPTH ANG I.._E ~ D .M. .~.E..G_, ..... D ........ I~ ....... S TRUE . _ ................................ DOG_LEG DE P Ti"j ..... ¢.E_A ......... B..~_R_~¢.. D I S T..AD.g.E___, .AbJ Q LE~__D. EGZl..O0 F_I _ D-L.%T-ANCE- -- ~9-3-,-0-5--- 7.5..~o.0~._ 8-]-6.,-7-!- -- 8-8-],-...0-7--- ~f~Z__&5 ..... 15_ ......... 5 Z3_7_,. 8_9_ .... 5..17 6, 89 ...... S._7.9_.W ................. 217 · 25 ...... $ ............. .99~,.5.~..~ -: &O-~-.._O-~-. 5__7_Z_39_-5_7._~ .............. ~... 8~2 ............ 1.~.2-, .1~-- _ _5.~_~.~ ..... ~_~.._3Q. ........... 5.~_0.~...~_~ .... ~.2.~.1_,.~ ~ ......... 5_..8.0 ...... W. .......... 229, ~ 1 .... S ....... ~_QS.9..,2.0.__W_~.O..8_~Z~._5__ lT.___~a_,.~__~ ....... ~.,..~50 ~0-7~..,-7-~ ~~..%_~_~,~~_6~_.~3_~ _ ~_Q.~,_9.~ 5,8 Q._.W .... 2.~.1 ,..~.8__.~ ~,.&~_~_~~ZO__S_Z~__5~.~.5..,...~ ...... __,~ 8_~.3... 9 Q.. ~ 9 ........ .5.&Z6..,. 62 ..... 9.~ 6.~ ,..6 Z ........ &..7 9_....W .............. 2.~.6,96 .... & ......... Z..Zg&~._~ ........ 12Z ~.~9.~ .... S-, .7.~ ........ 0 ..... ZO--.w- .............. Z,..188 .~-2-~-9-,-7~- ~.9..~..~__.~& .... 0 .... ~.~_8_~,Q_~_ ...... 5.4~J_,.0.6 ...... ~._....SQ_._~ ............. Z. 6 7,_8.9 ....... 5 ......... I.Z 7_O_,%&~ .. ZZ9_~,._l_L...&.. 7.8 .... 6030 54__0 ~539,9~ .... 9_~_~_8._,9_~ ....... &,._7~,__.~ Z.8..,k,.6.~._.i___l,~_~.~,~_~3_~.,.6.5 .... &_.7..8__i,O__Z__W 6123 ~ ~ ...... 9 ..... ~.~.e.~_.'~_~ ....... ~_~ ~...~_.,__~Z ......... $__.8.0..._.w .............. 29_5..., ~_ 8_._5 ..... 1~1.8_,._~_~_~~_~_~_,..~ ..... &, 7 ~_~._Z2_ 6310 34 0 ,~704,5~_ ~..~ ..~ .... $ ..... 8,0_.W __ 3.~.!_.~5~ ___1.~.6..7.~_~ _ L~Q_~,..Q.9 ...... $~7_8_.,2.6_.l..Z_.w~__ ~.~0..0_0 !59-~- .~ 9_7 _~5 ....O_ ~_.8.~.k,_&5 _.~.7_50,_6 ~__ &_8.O__~ .... 3.6,8..,.Z9 S ...... %718_.5~~~5_3,_&.5 .... S_ ~.&--.32--.-3&-.'~ ...... ~,-~-8-- .~6_~._5A~_ 5_9, ZQ_,&8 _5_8 59,5 8 .... 5__81 .~ .... ~_TZ, 70 .... & ~&,~___~_~_~_9~5.,2.0 .... &__7.8.._~.3 ~6'~...[.LO_ 6.0.~J_,..Z~_.~.9_!O.,_15 .... 2 .... 8.%_~ ........ 39_6.,..Z.9_~.__Z.~_,~~O 5 5 ,..8.9_~__..18__~3 ........ 696 ~_~2~5.bQ~_7..,..~___6 OZ6_, _89 ....... 5 ,..81 ._,.~ ....... ~.0..8 ,.0.2__.5 .... 2 og&_~~ ___213.0..7 9__ 5_ .-7. 8 .... 57 ..... 37 ~ ....... O. 26 ~-~ 212 4 ,~-- 7058 ~__.0 .........~J~.~__~.6_~ ...... .b.083 ,_66 .... S ...... 8.Z_..~ ._~1.9.,..5_6_~ .... 216~_1 Z ~,_ ~.0~,_60_&._79 ........ .... ~ ~3_.~1 .... 0 ..... 6.2 59_~..8Z ..... 619 8..,_8Z ..... 5 ....... 82_~ ........~ ~...5.~.S 23.07_.~~ .... 2-3~-9., 09 &--7-.9 ........ 9.--5~.....w ......... 1,0..~8 -234~ ,0~- ~ 7 ~ I_.~.Q__~Q .... 6.3_1~.0 ......6.2 ~_8.,.50 ........ &__81__W. ._~ 5 Z,~_~_._~_7~.O~__ 2_~ 2&..., 6 5 ..... &.'..-19 _.1~ ...... 6 ~ .......... ~., 20 8 ...... 24i-5,59- .... 7.525 .... ~ 9___30_. 66_~O_.,~5 .... 6 379 ,.55 ...... S- 82_W .... ~_7_2., 95_ _5 .... 2-5-2~_~_ ~5&5_,.36.- ~---7-9 ..... ................... . _... RE.CQRD__QE_.&LLR.VE.¥.] __ _ __ALk__f~AN.2NLkL[.Q~$_~E[(EQBL~LED_.. B¥_L_EL~_VL_ELECIB_Q~LLC_CQL~ELLT_E~E ~E_A_,5_L D I~tE_T___.V_EB.I_iC, AL ................... S_U B .................. DE..T,_E. Z .......... ..T_ O IAL_C...Q0.F~D_.iNA_T_ES ' D_E.P_'I~_~ AJ':tGL,.E__D_E P,T_L-i_ ............. &EA~._ _ . D_,T,..R. EC,. D_ .... M ................................................... BEG, DOC,---bEG -C.-. L-O--.-S-.-..U..-.R-.-g--$ S-E.-V-ER...[..-T.--Y D-I-,.S-T~E, .............. A~.G.L.E- ........ DEG../..I, 0-O F-T---'--I;~ I-,S-T~-F,,-. D- ~ ....... $ _Zll_l__~8 50 65_62-,,_68_ .... 6_SQl_,..&8 ..... .5.._8.1_i~L ....... ~-9-3.,.0.8 .... S ........ £6&CT..,-2-2_i_~- .2.Ll-O-5-,,S& .-. $. -~.9--Z.9-.. 56. -- W .............. 0-,81-5-- 7 89 7 ;,,, 9 10 6_6..8_.Q.~_2.Q. 6.6.2,..;t.,.1.0__,S_&l___w. .......... 5.Lf,_0-z~..-L2.7_..c2.&.,_&8_.W _28..~5-,-&.7_-S.--:7-9-,.,B..z,~-23--i,,~---0.,,-.LS-5 7cz9_0 a,._9 5.0 _.~_7_4,5,.0_9 ..... d6&_4..,.09. ....... &_8!.._W ~26tl.~__.S___Z86.8_,,_73-W --2r9-,¥6-~5-7---5----19---56 ZT---W .... O,-7-20--... 2-9-1-O-,-~.~ __8_QS_.zt.~O___O 6.&0.5,_6.],_ ...... ~..7.&&,_.6l ....... S ........ 82__.W_ ....... 53_6_,_7.&_._S_ ....... 2 ~L&.9,,_8,.6__~. _2.gaS_,.-&.d_..S_.7...g._~_9__l. ~, W- ........... 0..,.8-32-- 2-98.2,-43+-- --~(~111 -- ~-- 'd ~I-- 8J--l'----& O-- ..... ~ 9 ZZ,_.&Q ..... &_.8.1_N. ...... 5_6.&,_7_L._.S~ 3.i~,_7_9__W ._3.2D_Q,..6.6_....S_..-L9 _.,L-~6__QQ._W ........0-,-.2.&9-- 3 8 5il_.,~_L_ 0 7.1Q_L,_.QS___7_Q~_Q,_Q_8_ ...... S__8_1_ ~ ......_..5_9.1.._,_Q5__.S____3:29_7_,...33 .... w . .~L!..6..c2.,_95__.S__~.9_..&.9__f0__~L__.__0_,_0.f.lO ._~._6__~...:L_,5..1. ..... (P. ....... 1.;L,%8....,_9_8_. ....... 7.0.~..7 ,.98 .......... 5.._8..Z_.~_ ............. 6Q.Z.,_.QZ_5.. ..... 33_5.8_,..0..~_._.~ ...... a&2..1. ~7 5! .... 0 .7_2=..1_8..,_.1_~ 7_.1__5._'7_,_...1_;~ .... SS_.~. w _¢;L.,I.J~,_5..5__,,5.____34_80,L~? .... ~_ ~9_~..,A0__&.__7.9__.5_5__LZ",__W 8830 50 0 72_Z.7..:2,_9... ....... _7_Z.:L6_...Z9 _,5 .... 8.9. W ....... _~.Z~.,.~Q_,5_._.3..%LL,_6.9,_...~_ ~_5_6_,k,,_r, zd.. 8 9 ~___5_Q .......... 0_ .... .7. _3 .~_7_ ,_. .7_ ], ..... _? 2.~6_,_7.], ...... $_.....8~.....~_ ............. 6.2.9....Q_? ...... .5... ........ ::55..8.3_,_.1Z W. .... .36_3..Z,_9 7_ _5...80_ _9_Q_L.,.,.,.,~Lkg._.9.5 33Lg.~t.,/..8___7_~7_.,_;L8. .... ,,,%_8.~_~ .- 6 3 7_,.Z2.,_.,%__~(zfk.._62__~._ 37.0_cz,.&:L_&__a0_.._&.._.33.~,~L_ _O_,-8-..%.8 _ _% 7 0-~,-],-0-- __9_Ll?._..,q._9__....~___7_8_.%8_,_6._9_ ..... 73,97_.,.6_~_ ..... S__.8.4___~ ........ ~q.~,...7__~._....,S .... 3.TZ6_,_21.__E .... 33.._&1..,_5 8 .... & ..80__.1! ...... 0__~ ........ 0_,._00.0 5.11~ ")Z-- 9Z0_6_...~tg_.....5_5_ ..... -LS_lR_,20 ....... .7_&5_8_,. 2. 0_ ..... ,5__. 82..__.. ~ ......... 6_.53_,_5L_ S ........ 3.7. 9_Z,_6.L_~L 585_.5 ,.~..3_ .... aL&86 &9 .... 6.5_ 7_6_9_C2..,_5.5 ....... 763..8_.,_5.5 .... & _ 8. ,5_. .. ._ t,"L ...... 6_7_7.,_7.6_.S_ ...... /-~EI0_,3~_)L~_6_7.,_2E~ .... .9..~_7.9....~..c2..../L~. ..... ?_7..~.~.*..6.Z't'... 7698.,.6.4._ ..... S. 8_5....W ............ 6_8._~._.,~ .... 5_...Z+.QS1,_lO w 4_.l.2LS_,_f,2.L_'.S_..8.0._.29_..1.f2_W_ ._0.00o z+_133 9 5 7_ ~._-~_c2__~5____Y 8_8_~0_,_6 9___7.. Z_5_9__,_69 ........ ~__ 8_6___'~_ .......... ~L8_.9_,_.5_6_ ..__& ...... ~15_Z,_3_6 W 4~2._0_9_,_Z2 9_7__6_Z___/-t9____5. _7_8.8.ZJ_15_ 7_8_& L,_ :L5 _._`5 .... 8_6__~/_ ....6_gA.,_.5_Z_S ....&ZZ3_,~Z w /-LZ.80_,.0_ZL..&. 8D_&9_....~0_.~ ....... C~,.LT-0 ..-~..-7-.5-,~,5-3-_ _.lQ~4..7._&.8._ ..... O ....... _8. O.6_6_,...6Q___SL0..t,,tS.,..60 .... 'S.....&5 ...... ~ ....... _7.0...9_,..82.,__.,5_ ..... /.'-.-~33 ,--z~L--W 4._.489_,-_[i8 _LE.I.Tg__~'Z__5 ..... 8_.12...1i..,_2.Q i:iQ61,...7..0 ....... `5_. .. 8.5._..W_ __.7..1. io.1.5__S .... ..4....5_0%,.Q_8__W____~t.5_5."L,_5..4__S_..&D_..5.8__Lg_.~/_ ............ 1,..,,.Z7-3 -- &.,'i.5-~.,-8..;L-. ._1..02.%3 _..4, f:L ........ O ..... &1.93_,_3_5___8.1.3.2._,_35 ....... ,5. 8.7.._.W .............. 7_1.9,_3_1_._,5 ....... ~.5.69--,.fL_9--.W----_~.ZS_,.4& $... 10885 37 45 10977 37.10 11069 37 0 11162 36 45 11255 36 5 11348 36 0 11442 35 5 11536 34 10 11750 :B:B :).5 9381. 5 21,3 -'70 _ 5373,-7-1-- .5-<~25~-7-~-- ..... iN~E E D 0LA'I EB__tP~UE_.. YERT, ! C A L .... DE P.,-T H& ~..,--CO ORD, I, NA I.ES--A N D-'~ CGO 5 ' ,JR.E.&--F~-~-.G tV-EN-DE D-,T-H 5 _COJiE_ L,,tEAAU R E D T_RUE_ .................... : _V_E~I,,I CAL ,IQIAL_ .... _C.0.O.[{B_L~AZES - , D F.R.IL~ .¢.._L._-O__,S:.._U _._~._..E SUB-- D-:-~-- 08.]26_ ............. O_8kO. 0 9 %.0_ 116.2_8 , I.RWE _ M EA S U EEB_.__NLE~T_LCALSU B___NtD~_I..VD_. .__~/[R/_L<;AL, DEB_T_H D EPI H ..... SEA_D I,¢ F_ERENCE ....... COJM~.~C-T-I-ON~---- -T-O-T-AL- .... (OORD-I-NA.7..E-$ .............. 2661 .............................. Z66.1 · . _ 26.00 · ......... 0 ............................. 0 ............................... 1-t 6. ,.72---,S ............... 3 4 · .03 - E -- 2,76 1 28&L. 296_] .;~.O_~L__ 3 !62. 32_62 3362 ~._~63 3~.64 27 61 ,___ZZOQ.L ...... _u2 2._8:61._,__2800 · ............ Q ........................ O __2_96L,__ Z~OQ ~ .............. 0 0 3.Q&L~___3_O_O.(I, ....... d ! 3_161, ....J..l~O_, ................ 1 ......................... O 3.2._dl., .... 3 20.0, ................ 1 .O 336_L, J_~_Q O, ............... 1_ ...... Q 3 &_61,____~.~+_O_Q, ................... 2 --1-1-:7-,-2 2 -.$ ......... --35.,-9 5 -E --.1-'£5-- 2-1-5 ............... 40 ,. 6-0--- E ....... 1~1~.-34--S- ......... 47..3-3--6--- .1-10-.-5a----$ .................. 51 ,-7 0--6-- i-1-3.0-~---S ............ ffl. 50 .... E. 1 ! 8 · 3 ~__..5_ ........ &&,.S.9--.E ;i,-26.--75-.--$ .............. ~7- · t ~- E---- · 35..61_. ..... ~.5 0 O., ................. 3 1¢5-¢a5-.-$ ....... 21.8--8 E ........................................................... ~URE D_ DEELT_L-L_AL',tQ__O_T_HER_DA.TA._. FOR_EV E. RY-.E-VE N-..tOO..-..F.E [I---O F--.,S U-B--& i& A-DE-P T H ,- _ T_R.U E MEA~URED______A~_~T_I~ AL_~ 5 ...... ~ D --T .¥ D .YE R.T-LCA L. DF_[::,_I.L-i DEE.IH ....... S. EA__DI.FF.-tERENCE .......... C~OR RF,-CT-IONt .-- T-O-T-.A ~---<2.~R D I N-ATE,5 3.6_67__. 366.1_, ___~.6.0.Q, ...................... 6 ..................... 31.7.0.___ 23..7_61.., ........ 3._7..00.., ..................... 9 ............................... 23 1.-~, ~,_..7_z+_ $ ........... 24,7;~ -- W .............................. 3J32~ . . SIi6.3._L__3.80.O., .... ]...4__ ...... 3_9_8_3 .3.9.61., ........ 3.9.0.0.., .............. 20 .............................. 6__ ............................ 156.,.4-5---S ................... 9 0 ,-5 3--W .............. _ . /~.0[3_9___~ ' 4_0_6_3._., ......... .&0 0Q., ............ 28 ............................ .41 °_9 :/ ~.161_L.__q.1. 0.0..., ..... :3..8 ........... __ . ~_~_LO _._%_2 6.1.., ......... Z+ 2..00.~ ............ ~9 ..................................... 11. . . . k.Z~5 _43 61., .......... ~3D..0.., ............ 6.~ ........................................ 1..5 4 542 ~.~.61..~ ....... ~.~.00, ....... 8.1 ..................... 12 '4 66_Z~_. . _ _4.56.1_, ..... ~.5 00 ~ ....... 3. 0_3 ........................... '_..2,2 4 79 0 _ ~_6. 6_1, ...... _46.00__,._ ...... 129. ................................ ;_._26 4~ 19 ........ '._ .q.,7_6.1_.., __ .zi7.00.., ....... 1.5.8 2_9. · 160---21--,~ ............... !"'3'0'"48 ...... W '~V--- 16.2 ,-23--$ .................. .162, 3-8--.S-.- ........ 22-5, 5-1 ..... W ......................................................................... 3-6-1-. Z.3.--.~$,- ...... 2-80.., 6-6- VJ--' .153-,-.92--~ ......... -1.5 2 ,._OS-.-S ...... -/,+ 1.-1-,-. 9- 2L.W 1!i_4_.,_~O__,5 ............ A.8.-7-,. 5. 9. 1.A~,.2.9.-S ............ 5 O~5..1 _~8.61., ........ &.800., ........... 1.90 ..................................... 32_ ....................... ~1 5.1 ,. 8..7_.S_ ................. 6_5~ ,. 9-7-_.~ 51_8~ 49_.6_ 1_.. .... ~.9 O. O_.,. ............ 2 2.2 .................................. __32. 1b:Z,2.9.._~ .......... ..7.. 2~ 9..,.~3 ...... 53.3. 8 5.Q.6.1.,___~..0..00., ..... 2 .~ 7 ~.~_ _1.23.{i,!.,5_.£ ............ 54~i . ~...1_63., ........ ~R.i..Q0, ...... 29/-+ ................................ 2~..7 .... ~_ ........................ 20 2.-.96._... S ................ 920..,.06-.._~ 5 595 ._~.2._61., ...... ~..2.00 · ........... .3.34 ..................................... %.0 ......................................... 223.,5 9 E ......... 10.16,9..8.. , 2_z~2 5 3.§.L.,. ~__3_Q_0_,_ ..... 3.82 6] 9 9 ~_~._6_1.:._ _~.4_Q.0, .......... 4 3.8. .............................. 0_6.6 ............556.3._.: .... 5.5_00._, ......... 50_.5 ................................. _6.7. 23_6 __ .5_6.6J~.___~fQ.0_L 5.75 ...... 7 0 6~_O 8 5_7_'6.1..,_ 5_7._0.0_,. ..... _6.~_7_ 7_2 582 _58_6_L,--_f8.00., .......... .?21 7_%3 59_6_1_:. 5.9_0..0_~_ _..:7.9.2 .......' __21 Z_qD_,.SA...S_ ...... 21_6 2.._5A_S .......... 12-~1 · 2.86,-9-~---5 ............ 1-3-7.2 ?. 1.2L,_2.A--.,S .... 3 3-5.,_6.0__~ ...... 16_Z,~6,_5.5.-W .3.5.9-,_7 .:L-S ........ 118..7.,.-3.-3- W :3 ~R 3_ ,_4_0_,5 .... 3.8 6920 7084 7245 7402 7556 7 70..8 78.6.2 80.1..-5. .......... 6062, · 6000, 63. 6_1_,_ 6_3,_00.., ....... 92..2~ 6 ~_~6 1.k.., ._6_ ~IQO_~ ..... 3 84 6361, 6300:_ ...... 10_4.! 646 ~ ,__ __6.f6_3._,__.6~D-0_.L__lL%.7__ 6661_:. .6_60_0..:_ lZ0Q__ _ 6.-7_61._,_,6_7_.0.0_, ...... 12...5~. ....... .... ~'.2~ 69_6_1_.,. .... 6.9 0.0.., ......... 13.67. ..... __~83 7._0_6 L, .... ~D.O.Q, ...... 1_4.26 ............................. 59_ 5_83~:L0__S ........ 32~/3 .A_4__.W _M EAS U.B_.E~. __O F.,_P__'T_~...A N D__O '[J:tLF.~._DA~A__ EOR_._E.V_F..~Y__EV_F_N._iD0 F_.EE%_D_E-SJA~F. JA_DgP_TH-, .- _ _MEASURF. D ~.EP_I~ ..... S.EA_:D_IE EER£L!LC E ....... C 0R.R~T_L0%.I T OT-At,, ,- COO RO-IN-A-TE-& 8 64 6 '7 _]._6_!_, ...... _'7~_0_0._, ...... .:.]._~,¢L8_5 .................................. __.5.9 ..... .__.~,_.3_z,__.& ........... 33.7Z-0-~5-.1. .... W 7:.2..6.&.o ......... _.7_Z.O~.., 73 %;L. ........ .7_3_P_0_,,___l,J.9_~. 115 7461 · 7400,_ 27 _], ._ 7_,5._6..1:, ......... 7_,5D_0_,. 42 6 .. . 7_6_63,_~__3_6.0_0.,__,1.7_65 .5, 81 _L7_6_.1,_, ......... 7_7_Q_0_, 8804 8960 9887 L~96_1_... ~3_Qi)_,__,Lc22_6__ 52. _ 7_ao_,..as__.%~&:~L:~...&.-5__~.L _ 10 0 3 9 8~_6__~....I ....... __8_ODD_, ......L9.7_8 ......................... --__52 1 0 1. 8 6 8 l~_l., ......... _8_i__0_0_,___2.02._.5 ....................... 4:7. :L..Q~ 2__9 ...... ._.8~.,__8.gDD_, __?._0~.L_ ___~ 1_0_~6 8 ...........__83_.61., .... _83_Q0_, .... .2.191 ............................... 10 60 3 84 6.,!,~ ..... _8_~_0__~ ..... 3._1_4_2 .......................... _3_.5_ 10..Q3_~ ~+ 85_61...____~sD_0_,___Z_l._7_~ !_0_8_6Z ...... ___~_61_, ..... _8_6_0Q_, ........ 2_2D1 ........................... 7_.0.9_-_ 32___,5 ........ 7_]._7J_2..~_~5 ......... :.~-5-.3.5.,~1.-1 - W. 7 2 !-~-~kS--S ........ ' 7-2.-.1.-..~0-~ ........ '7-2_0_,_0_6__,S ............ -4-&2-5-.O-9---W -- -'7~3-.-I.,?--S ........... 10 98 8 8_7_6_L, .... 8.Zg_G-' ..... _'2.22,2_ .................... 26 ...... _____&g_8_._5_g__$ 11.2_ 3 8 ' _8~.1._,____8_99.0., ...... 22:ZZ ............................ 2. 1 136 2 __9. 0 62_, ........ 9D.Q.Q_,. ...... 2. 3_01_. _ 2.¢+_ ......... 1 14 ¢ ~+ , 9..L6.,l_:___9.1.0D_, ...... 232..3 ............ 2_ , ' 'i : SCALE' .i "= 500 ..... . . ............ ATLANTIC. RICHFIELD'COMPANY DRILL SITE 3-~- ~ '~" TANGENTIAL .AVERAGE , MAGNETIC ' ALL_DE ARE-:TVD.- ...... ' - ~ ' ' ~ ' ~- ~ .... 7'-' I .......................... , ........... x ......... ~ .... r ....................... -r-- - . .............. -I--; ........... ! ' ! /..!--- 1'40~l ....... '~ ...... i'~-=--7 .... ~'--~--'-'~--- i ...... ¥' '"~ ........ -:--'--; .................. "' ........ i '-7"-'? ~ .................... :. .... !- _:: .... ........ - ..... -. yFFmCAt,__SEC'r. oN!:-- , , :~ SCALE -lO00 '- ..... i ....... ~ ..... ~ ....... ; ........ : ...... i ...... ~-~ .......... 'I- 'C . ,~ .......... :"~'; X'~- . -~' ; ..... [ ...... : ....... ~ .... -_-i-'t.-! ~,°°.1- ......... ~ .... ~ ........... ~ ........... ~. ......... ~ ......... ,,_=_ ........ _, ........... ATLANTIC mC~F~ELD.-COMPAN¥~?-~---,~--~ . -' !: ...... ! '..' -?"~, .... ~---"= .... :'~ ..... ~ ...... ~ .... : ......... ? -'- :-'~ ...... .'-~--: ...... :-~ ........ ,:--~-~'- ! ...... 7- ~ ' ~ · A6NETIC ' MULTI - .... .-- - .--!3-::-i-WI'-.- ...... ---:- ..... .... ~. ........: ..... : ;-'----- ~-~- ..... :. I-: ........ ~ ........ :--?-} .... :__:_ L_! ....... %._.;_ -.-. ;~.:._1_ :-~-.-~ ' L..~. ' ~ .... _j_~ ! _ %~:.~,,~..~._~. _.'_ , , ._.~ ~ t _ _. ~ .... I . : ! ..' i_ ! .:..' ~ : · , '~-~ ................ ,~ ' ' !: ............ ...... ]-"~*' '~ '-'7'~:-'* ........................................ !- ' ' ' J-. ~! ............. !t ..... ii ................ ~ . *~ ................. ;+; ' ': ...... I ¢ i_.-: '_- _ .! ;%_' .7:2;; ~V/.¥Z'.~, _1_ i2-2 _ ;'E iZ_T- ~ _: .;Y;t."- ~_..'_.2 Z J. - '__" ;'_ ;; 'i '_ i_ 7"7- :.-i:__ .--2_7J_I.- (~ ........ ,~"' '~4 ........ ~f ........................... -i!~-ii i! ~ -~'i-- "--" '~ , ;i -' .............. ' t = ...... ~ ...................... i ' i '¢ ......... i. 1 ................., I" ..... f ~' .... ~ .... f" ...... ; ir''~= ¢--~'-'- ---" ,~ '~'~--~- ' ~' ', = i- ~~~ ~ ........ ¢ ..... ~ .. . , ' .~..~., . . ~ ' i.] ~. ! ! ' ! :. !'' ~-~-' ;- ' i ' t ' - ~-I ~-:--i ~ ...... i -~ - ~'''''' ...... J'z. ....... !~. ......~. .....: i .... i'-T ............ -'-7i--~ ..... T-';--x ............. ........ r'-', ..... ..... i-l'": .... --7-.-l'-:-x-,,'X-'l~':--:-'~: i' ....... ~ ...... " .... : ..................... ? ....: .... ~ ........ % ........ ~'J ' ~-:-,-7--'-' .....Tm'-. ..... '~':--: ........ ~ .... ~': ..... ira-: ...... J~: ......... ; ...... i ........................... ;-- ; -4. .... ~- ....................... ' --= .......... ~- ........ 4 ..... : ......... .... f j'- ........ i .... i ": ........ ~ /'.-. ;i__ LJ'.i _J'-i-; iJU;-'-;.2!iJY--{ .... ~'-'C-:-'-:'--:--¢---?-:-'--'"---?;'-.-- ~ ' -~: : I , ~ , AL'L. 'DEPTHS i ................. ~ ......... .{--'_-Z2 I J:-"L:'.-----~ --.' ........... , ___ __. '.. ......... ,,._- ....... ......... ~ ............... : ............ ~ ....... --'i- -;-'~- ....... ~. ...... :- -;'--: -~"? i '- ' ''~ i ........ i ' -; .... I" - .......... i .... :--:--: .... ~--:'- .......... : ............ ??": ~ i'-- -L .......... ~--. i';.';.-' _. -_;; ;: , · . , ............. ' '- 'i, ..... ' ............... : 4_.:- .................... ;! ................. . l ................. . r ........... i ........ ~ ....... : F'- ........ r ,----- .... i ....:" ; ..... ~ "-,-: "i '-' ......... ' ~ ....... .... ~ i _'"- ]:- :- :--:--: -:- ;- '- 5~ ....................................................................... t . '~ . ~ ..... t. ! , ..... 7---~-? ............. ,~ .... ~ ..... _L .~ - ..... : ..... " .......... ' _--_-:-._-;-Li_ ;--.' %! _: '; ' ] ;-.;' '-~; ~_'--;; ~ZE?Z-T,F?t-~Z; :-- .... ~ ' ' ' ................... ' ' - --. ' q --I .....,' ' '____.~ ..... '":.i;_-,.Z___i2.-t '?--T% ..... -~ ..... ~ .i ---~ ..... ' ' ' ............. " ..... r ~ ......... ~--~ ' ' ' ............ ~ ........ Li'i_~-Z_..: iZ[ ....... ~ ............ ..... ' , I ...! ......... " ......... ~-- ............. ' ..... : ..........~ ............ ~'"I'-~ .............. · - t ' ~ ' _ ............. ~ ........... ~ ! , ............ ': ......... ~-' .... ~ '"~ i--~ ....... ~ .... '~'-: .... , ' ' .... :-'----~-'--'-: -.~ -" i..L-.L-._-~ .- .......... r--~ ' ;-'-i----; ! i · --:- - , , '~T'~-- ~ ' i ~ - ~ ..... ? " ......... i ......... ~ ..... ~ .............., ..... : ....................... . ..... -I~ ...... -;--: .... :---~- -i-- -: -- ~ : ...... i 76,OO ' .! ...... :4 ......... i ......... i --~ .....__:__:__ :. _ _u ;---~--=--i-u_!--~--: -~-----~ ----:-x- ........, . iu' ....... ~ ...... ~ ......~ _ ._ - .......... ..................................... .: ! , :-'-'. ..... : ..... : .......... 1: '---: ...... -f- 2-i ....... i ........... 'i .............. ZE~_Z--:LZ ~ ~ ' ~ '" ' ' 'l ............. ~ ............ r--~ ......... ~ .......:--_~- -' ........... :: ......... , ............. ~ ...... _-~-~'~ _q7_~77/_!-:~i~.21 _12' !Jz' ___-;_-2i'--?"'-~ _--i ......... i-_-/ 2 .... .................. '~ ............. ' ......... ~ - --7--~--:--T--i '-~ '- -; · ~! · .--4--' -__u .... t :__2 ......... _L .-. : ...... .,;-~ ..-~ ........ j ............. ~ ........... _ : ~ , i ........~ .... : ...... |': ..... ~ ............... -' .... ! ..... i ....... i-'~-' .-'7'-7--" :--F',--;--~ '1--~ T-'., .~,. :¢ . , , I ........ · ...........i' .......................... ?'-~-" -~ .... T-' - F~- '7 ........ 7'---i'-';--"' -.'- ........ h--~ ........ ~ ............ m _._ ~_..; ...... ]..._~__.~__~ ..... -h- .:--'-- -J .......... ) ' _._2_:_. -i ~ ~ ' ~ ~, ~ - / '.' ~~- -i- · .~, ~ ~ : .~ LOCATED IN .THE APPENDIX UI WFL ~ IPR LOG [21 CALIPER SURVEY [21-VOLAN CURVE DATA UI STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER: , ~RichfieldCompany North Amer.f~%Producing Division -~'z% North Alaslt~ .strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 3-2 Permit No. 76-24 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Very truly yours, C. R. Knowles D±str±ct Drill±rig Engineer Enclosure CRK/BDR/j 1 ~c)rm No. ]~'. B- I-?0 STATE oF 'ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS 1. WELL WELL OTHER 2. NAME OF OP~LATOR Atlantic Richfield Company .'% ADbRESS OF OPERA~'OR P. O. Box 360, Anchorage, AK 99510 4. LOCA~ON OF WF.J~L 1903'N & 688'E of SW corner Section 11, TION~RI5E, UM AP1 NLrMERICAL CODE 50-029-20203 LEASE DESIG]~ATION AND SE"RIAL NO. ADL 28328 ? IF INDIA~, ALOI l ~:~ OR TRIBE NAME 8. L.~IT FAH~ OR LEASE NAME Prudhoe Bay 9 WELL NO DS 3-2 (i4-i0-i0-15> 10 F~ A_ND POOL. OR WILDCAT ?,rudhoe Bay - Sadlerochit Pool sEC., T.. R.. ~,.. ¢~orroM HO,.~. Sec 10, TION-RI5E, UM PERMIT NO. 76-24 13. RE~ORT TOTAL DIEPT~I AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/VD VOLUMES USED, PERFORATIONS. TESTS ~ RESULTS FISHING JOB~ JUNK IN HOLE A. ND SIDE-TRACKED HOLE AND A~Y OTI-IER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. Report on operations for the'month of April. Spud @ 0700 hrs 4-12-76. Drilled 17-1/2" hole to 2750'. Ran 13-3/8" 72# MN-80 Buttress csg w/shoe @ 2696', FC @ 2614. Cemented w/5400 sx Permafrost II cmt. Circulated 13-3/8" x 20" annulus thru 2-3/8" risers, blew dry, pumped 150 sx Permafrost II. ND 20" BOP, cut 13-3/8" csg, installed and tested packoff. NU 13-5/8" BOPE and test. Drilled FC, shoe and formation to 2760'. Tested formation w/0.65 gradient. Directionally drilling 12-1/4" hole @ 11,592' on May 1st. 14/1 hereby certify t~ t~e/fo~ego~ ~ ~ue and correct North Amer'~-~'~,roducing Division Atlang~RichfieldCompany ~ " North Alaska ~ ..rict ~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 3-2 (14-10-10-15) Dear Sir: Enclosed please find Sundry Notice describing a change in the measured depth of the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer /ii Enclosure MA ' 6 1976 DM,SION OF OIL AND GAS ANCHO~AG~ Form P--3 REV. 9-30-69 S~brntt "Intentions" in Trtplicat~ & "Sul~equent klepol-ls" in Duplicate STATE O-F ALASKA OIL AND GAS CONSERVATION COMMIT'lEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dr/Il or to deepen Use "APP],ICATION 'FOR ~'El~iI'i'~' 'for such 'proPosals.) 5. AP1 NLTiVI,E~CAJb CODE 50-029-20203 6. LF_,A~E DEF~IGNATION A_ND SERIAL NO. ADL 2832 8 2. NA~IE OF OPEI:IATOR Atlantic Richfield Company ADDRESS OF OPERATOR P.O. Box 360~ Anchorage, Alaska 99510 4''OCATIONOFW~'lg03'N & 688'E of SW cr Sec 11, T10~, R15E~UE At surface Prudhoe Bay 9. WELL DS 3-2 (14-10-10-15) 10. FI~Lr~ A~D POO1., OR Wll-nCAT Prudhoe Bay-Sadlerochit Pool 11. SEC.. T., R.. M., (BOTTOM HOLE OBJECTIVE} TARGET: 1320'N & 1320'E of SW cr Sec 10, T10N, R15E, UM Sec 10, T10N, R15E 13. ELEVATIONS (Show whether DF, RT, GH, etc. 12. ~E~HT ~O. 61'RKB 76-24 Check~n~B~x Toindi~ NatumofNOtice, Re~o~,orOther Data NOTICE OF INTDNTION TO: FRACTURE TREAT .~iULTIPLE COMPLETE //HOOT OR ACIDIZE ABANDONS i ..... ,Other} . ~ FRACTt'RE TREATMENT ALTERING CASING 8HOOTING (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DERCRIBE PnOPOS£D OR CO.MPLETED 0PERATION8 (Clearly state all pertinent details, and give pertinent dates, including estimated date of 8tarring any proposed work. 'The Atlantic Richfield Company proposes extending the'measured depth of this well from 11,400' to 11,800'. Although the course length is greater, the True Vertical Depth of 9,360" will remain the same. The remainder o~ the proposed well program will be unchanged. M, ,f 6 976 DIVI.~IOIq OF OI/ AND GA3 ANCRO~AGF 16. I hereby certify that the ~ore~oln~ t~true and correct (This space for State office use) C0SDm0~S or ~,m~,~,L, ~ Ass: See Instructions On Reverse Side DATE ,- . 1976 Pru~oe My ~ 3-2 Atlantic Richfield State PenaJt No. 76-24. C. R. ~les Otstrtct OrtllJag Englneer Atlanttc Richfield P. O. Box 3~ A~chora~-, Alaska 99510 Oear Sir: Enclosed is the. appeoved application for permit to drill the above referenced well at a locaM~ in Sect~o~ 10, Township 1ON, Range. 15E, Well samples, core chips and a ~ log are not required. A directional survey is required. Ma.ny rivers in .Alaska ~ their dralna~ systems have been classified as !mpo~nt for ~ .spawning or. migration of anadromous fish. Operations ~ areas are subject to AS 16.50,870 aad the m~lattoes promulgated thereuader (Title 5, Alaska Administ~tive .Code_). Prior to comme~ct~ ~ratioRs you may be contacM by the ~bltat Coordinator's office, Depart- meat of Fish and Polluttoa of any wa~ of the Stato is prohibited by AS 46, Chapter 03, A~t¢le 7 and ~ regulatteas ~lmulgated thereunder (Title 1'8, Alaska Admtntstratl~ ~, Chapt~-70) and by the Federal Water Pollution ContrOl Act, as amended, Prior to c~cing operations you may be contacted by a represen~ive air the Oepartment of Envirormm~tal Conservation. Pursuant to A~ 38.40, Local Hi.~ Under .State. Leases, the Alaska Department of Labor is .:~.iag notified of'-*~ issuance of this .penait to drill. To aid-us in scheduling f~eld.work, we- Would appreciate your notifying this office., within 48 hours after the well .is spudded. We would also like to be notified so that a representative of the-. Otv!sl.on may be present to witness t~sting of bl~t preventer, equipme~qt before surface casing shoe is drilled. In the ev~t of ,s~to~ er~' a~t please give this offtce adequate ~l~ nottflcatto~-so tt~t ~. my have a wt'~ present. Very t~.ly ~., O. K.. itl~tb, Alaska 0tl and G~s Cowserv~tton. Co.~lttee EaClosure Departm~t of Fish ~t ~, Habibt 'Section w/o eric1. Depart of ~vlrom~l Conservatton.w/o encl. Depart of Labor, ~rvtsor, Labor Law. Compliance Division ~/ encY. BPALASKA INC. STREET · TELEPHONE {907)279 0644 3111 - C - i~,~AR $ - I976 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 March 2, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director Re: ARCO Well DS 3-2 (14-10-10-5) P. R. Judd District Drilling Engineer PRJ:cmc Attachment cc: Atlantic Richfield Company, Mr. C. R. Knowles (w/attachment) Gentlemen: Attached is our signed statement of non-objection for the drilling of the subject well by Atlantic Richfield Company. Very truly yours, BP ALASKA INC. AtlanticR~!chfieldCompany North Americar~'"'oducing Division ' North Alaska D~,.., Ict ' Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 17, 1976 Mr. G. D. Taylor BP Alaska, Inc. Box 4-1379 Anchorage, AK 99509 Dear Sir' Rec'd FEB 22 ]976 We propose to drill our DS 3-2 (14-10-_10-15) from a surface location in Sec 11, T10N, R15E, UM to a bottom hole location in Sec 10, T10N, R15E, UM. Both the sections are on ARCo-Exxon leases. We propose to complete this well for production within 1500 feet of the lease line. State regulations define the operator of a lease, offsetting such a proposed well as an "affected operatoTM and require the consent of the affected operator. In the case of DS 3-2 (14-10-10-15), BP Alaska operates the offsetting lease. Please indicate your consent in the matter by signing below and on the enclosed copy° Please forward one copy to the Division of Oil and Gas and return one copy to us. yoUrs very truly, C. R. Knowles District Drilling Engineer CmK: cs Enclosure CONSENT IS HEREBY GIVEN AS NOTED ABOVE f~_., Signat re ' ~ Title BP Alaska, Inc. ~te AtlanticRichfieldCompany North Amerr'"'~Producing Division · ~ North Alaska ..,,~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 17, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE' DS 3-2 (14-10-10-15) Dear Mr. Gilbreth: Enclosed please find our Application for Permit to Drill DS 3-21 along with the $100.00 filing fee and temporary survey plat. For your information, as well as for the State Department of Labor, this well will be directionally drilled from a surface location on Lease ADL 28327 to a target in Lease ADL 28328. The effective date for both leases is October 1, 1965, with a termination date on March 27, 1984. Attached is a copy of a letter to the offsetting operator, BP Alaska, InC. A signed copy of this consent letter shoUld reach You shortly. Yours very truly, C. R. Knowles District Drilling Engineer CRK:cs Enclosures Form 10-401' REV. 1-1-71 SUBMIT IN TRIPLs~,(fE (Other instructions on STATE OF ALASKA i ~.,;) ~ [ OIL AND GAS CONSERVATION CO TTEE , 9, 5:!976 PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL b. TYPE OF WELL WELL WELL OTHER DEEPEN r-1 DIViS~ON Ofa 01[ AND GAS SINGLE MULTIPLE < D 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska, 99510 .... '" ' 4. LOCATION O17 WELL ^t'urfacelg03'N fi 688'E of SW cr Sec 11, T10N, R15E, UM At proposed prod. zone 1320'N ~ 1320'E of SW cr Sec 10, T10N, R15E, UM API# 50-029-20203 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF I'NDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 3-2 (14-10-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Ba¥-Sadlerochit Pool I 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 10, T10N, R15E 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOh~qN OR POST OFFICE* 12. Approx. 5 miles northeast of Deadhorse 14. BOND INFORMATION: T~E Statewides~retyand/orNo. Federal Insurance #8011-38-40 ~mo.nt $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, il'any) 1320' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST %~LL DRILLING, COMPLETED, OR APPLIED FOR, FT. 3500' (DS 1-9) ~21.ELEVATIONS (Show whether DF, RT, CR, etc.) 22' Tundra, 28' Pad, 61.' RKB 23. 16. No. OF ACRES IN LEASE 2560' 19. PRESSED DE~H 11,400' · PROPOSED CASING AND CEMENTING PROGRAM 17. NO,ACRES ASSIGNED TO TillS WELL 320 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START March 25, 1976 SIZE OF HOLE SIZE OF CASING ~IGHT PiR FOOT I GRADE - SETtiNG DE~It Quantity of cement .... 26" 20" ..... 94# t-40 100±. Circ to surf. 350 sx PFii 17-1/2" 13-3/8" 72# MN-80 2700± Circ-to surf approx. 5000 sx PF'" '12-.1/4" ..9-5/8'.' 47#- MN,-80 11400±- 1st stage w/approx 1500. sx Class~ 8 RS~95 2nd sta~e 300'±-cmt column above . . . 2600 w~approx 125 sx of PFII II G The Atlantic Richfield Company proposes to directionally drill this well .to ll,400'ND (9360'TVD) to produce the Sadlerochit zone. Logs will be run over selected interva].s. A 20-3/4", 2000 psi, Hydril pr.eventor will be used on the 20" conductor. A 13-5/8", 5000 psi, Hydril, 2 13-5/8", 5000 psi, pipe rams and one blind ram will be used on the 13-3/8" casing. The BOP equipment will be pre. ssure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen directionaJly, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout pre~ente~ program. 24. I hereby certify that th~Foregoirt~is True and Correct (This space for State office .use) SAMPLES AND CORE CHIPS REQUIRED m, Y s, DIRECTIONAL SURVEY REQUIRED [~. YES [] NO MUD LOG [] YES CX)NDITIONS OF APPROVAL, IF ANY: [~l NO OTHER REQUIREbiENTS: A.P.I. NUMERICAL CODE 50-029-20203 PERMIT NO. 76- 24 APPROVAL DATE TITLE ChR *See Instruction On Reverse Side Ham0.~ 4, 1976. DATE ...March >4, 1976 - ' L _' i0 Ii 15 !~,, CERTIFICATE OF SURVEYOR HEREgY CERTIFY THATI AM PROPE. RLY REGISTERED AND LiCENSEDTO PRACTICE LAND SURVEYING tN THE. STATE OFALASKA AND THAT THIS PLAT REPRE- SEF'~TS A LOCATION SURVEY MADE ~ MEOR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER ..DE-TAILS ARE CO.RR,ECT. AS WELL ,o._1 LAT. 70°14~01.509" LONG. i,0,.8° 16' 2 '~.'/'/'~'' Y 5 9~8 074.68 X 71:3 90~'/~5 WELL LAT. LONG. No. 2 70Ol4'00.:39:3" Y It 9:37 96L9:3 148°t6'a2.056" X 71:3 9~1.P. 5 WELL No. :5 LAT. 70013' 59.2:38~ Y 5 9:37 8~5~.8 LON~ 14'i~0t8'21 .:535" X 71:5 959.7:5 DIVISION 'OF OIL AMD GAS O' F_.XlSl'IINI~ WELL OR-CONDUCTOR PIPE ARCO No. HVL No.33-DSS-76 I ATLANTIC RICHFIELD CO. AS BUILT DRILL SITE No. :3 WELLS No. I ~. ~ 3 LOCATED IN PROTRACTED SECTION II,TION,RISE, U.M. ,~',-~c~~'~, Alaska DiStrict Engineer-~ · . CON i.0 NIIAL ¢ R A N S M I T T AL DI. STI~IBUTED TO: STATE Ot ALASKA .. om & CAS · Date' 19 ,luly 1976 Well Name' D.S.#3-2(11-10-15) Transmitted herewith are the following for the subject well' Run No. Sca~e 1 1 BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (~VC) - Interval Core Description (Cony.) - Core No. Directional Survey - GYro Single Shot Multishot Drill Stem Test - Test No. i Dual Induction Laterolog 2'"'~5~'' Fomation Density Log Formation Density Log/Gmmna Ray Laterolog Location Plat Microlaterolog .. bticrolog Mudlog- Interval Sample Log (A.R.Co.)-Interval) Synergetic Log TVD-DIL TVD-Porosit¥ Log 2"&5" Xerox Sepia BL Line V' Receipt Acknowledged For- // Please return receipt to: (h~. lantic Richfield .Company 'Nor'th Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99510 o. CHECK LIST FOR NEW ~'~ELL PERMITS Company Yes No Remarks 1. Is the permit, fee attached ..................... 2. Is well to be located in a defined pool .............. 3. I~ a registered survey plat attached ................. ~ 4. Is well located proper distance from property line ......... ~ 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... ~,~ ~,, Is well to be deviated ....................... ~ 8. Is operator the only affected party ................. 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond in force ......... , ........ .K~ ll. Is a conservation order needed ................... 12. Is administrative approval, needed ................. 13. Is conductor string provided. ....... ' ' ,~ 14. Is enough cement used to circulate on conductor and surface .... /~ Will cement tie in surface and intermediate or production strings . 16. Will cement cover all kno~,~n productive horizons .......... 17. Will surface casing protect fresh water zones ........... ~'. 18. Will all casing give adequate safety in collapse, tension & burst . 19. Does BOPE have sufficient pressure rating ............. Additional Requirements' Approval Recommended' Geoloqy Engineering' TRM HWK W/~. OKG ,~ ~ )qHH ,cs Revised 1/15/75 Well History File APPE'NDIX 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 APPENDIXi. No special'effort has been made tochronologically organize this category of information. g ECEIVED LIBRARY TAPE PAGE 1 OF 2 Company ARCO ALASKA INC. Alaska 011 & Gas Cons. Commis~lOlll Ai~o;~om~lu Well D.5. 3-2 ECC# ~3199 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA'" Da t e_j..1/14./. 8 7 DELIVERY DATE 1'2/14/87 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale I t FILES 1-3 I " CCL Casing Collar Locater ..DKT100 400-600 LS Long Space " SS ~.Sh°rt Space .L I " 000-54000_ G1 tGate. 1 " -72000 G2 .Gate 2 " ]~2000 GR [Gamma ~ay t " )-100 BKL IBackground Lonq Space' " )-300 BKS IBackground Short Space " ~-300 MeN [Monitor ,, CSS ..Capture .Short Space " .... ...ISS Inelastic Short Space " MSD ' Mean Std. Dev. ,, 8-0 SGMA Sigma " 60-0 I RATe IRatio of CaptureCounts " .~ ~3-3 ..... RICS [Ratio or.Inelastic to. Captu~'e" . 43-0 RIN !,Ratio of Inelastics " 14-4 RBOR Borehole Ratio 3 to -1 Page 2 of 2 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska~ Inc. Well D.$. 3-2 ECC#~ 3199 Field P rudh.oe Bay · County, State North Slope, Alaska'" Date 11/14/87 DELIVERY DATE 12/!.4/8.7 Curve Name (Abbrev.) Standard Curve Name FILE 4 Average Sigma Logs Used Scale PDK-100 60-0 SGAV , RNAV RCAV RTAV GR Average RIN Average RICS Average Ratio Gamma Ray Pass 1~ 14-4 43-0 33-3 0-100 *~-REEL HEADER REEL NAME : DAT~ : ORIGIN : FSY$ SERVICE N~ME: ~i~LiS REEL CONTINUaTiON NUMBE~: 01 PREVIOUS REEL N~= : COMHCNTS: ~EqSE~:~. _ LENGTH: 132 ~YT=S .... ' ~: ** T~PE PE~DER . ~ TAPE N~ME : DATE : ORIGIN : FSYS T~PE CONTiNUST!O~ NUt,Em: 31 PREVIOUS TAPE N~E : COMMENTS: LENGTH: 1~2 ** FiL= FiLE N~i,l=: P~SS 1,01 SERVICE VERSION ~ : t DATE: ~5/11/2~ ~AX PECORD LENGTh: 1~24 ~YTES FILE TYPE: LO PREVIOUS FILE NAYE: . ** iNFORmATION R_:CORDS ** MNEN CONT~NT5 ~PlN : 500E~20203 CN : ARCO ~L[SK;~ INC. WN : D,S, FN : PRU£HOE BAY COUN : NORTH S[~OPE STAT : ALASK~ LOC : 150.00 FORMAT UNI TS ~NTRY 5LOC~,S TYPE ENTRY DESCrIPTiON iIii IiilI 4 1 DEPTHS DECREASE 8 6C,0 PR&YE SP~CING 9 ,lIN FRAME SPACING UNITS 11 12 MAXIMUM FRAMES/RECORD 0 TERY'INATOR -0,500 LEVEL SPACING DATUM SPECIFIC/~TION BLOCKS CURVE REPR NAME CODE SIZE SAMPL: UNITS immm mmml CCL 68 4 1 DIM CURVE SPD REPR CCD: SIZE SAMPLE UNITS IIIi lImm 68 4 1 F/MN G1 68 4 I CPS G2 68 4 1 CPS MON 68 4 1 CPS ~KS 68 4 1 CPS !SS 68 4 1 C~S MSD 68 ~ 1 SU RBOR 68 4 1 DIM ~iCS 58 4 1 DiM GE1 S GR BKL DSS SGMA RATO RIN 68, 68 CPS CPS SU DiM DIM ** ~ORMAT ** ENTRY BLOC~S TYPE ENTRY gES£~ZPTION IIm-- 4 1 DEPTHS D~CRE~SE '~? .lIN ~R~E SPACING UNiT~, ~ 11 lP ~XZ~'''~ ~RA~a: ~/R =CC.:R2 O T~PiN~T-SR -0.300 LEVEL S~CZNG CnTUN SmmCT~iraTZON 51 ~rK,.~ · ~URVE REPR N~.ME CODE SZZ: S~HPL_: LN=TS rtL 68 4 1 glu ,~.~ LS 62 4. 1 ~PS G1 68 4 1 CPS G2 ~8 4 1 CPg MON 68 4 I C~S 5KS 68 ~ 1 CPS ISS 68 4 I CPS HSD 68 4 I SU R$OR 68 4 1 DIM RIDS 68 & I DiM U~VE S ElS KL SS ATO IN RE o R COCE mm m m 6~ SIZ: 4 4 6~ 4 S&~PLE 1 1 1 1 1 1 1 1 1 UNITS F/MN C:S CPS CPS SU DIM BiN ** D~TA ** DEPTH 11417,CC0 FT 3479.909C M CCL O.O00 SmD O.CCO G1 ~359. .363 G~I~ 41175 . ,,~9~ MON 325.967 BKL 369.965 ISS 3202~8.C0~ SGMA 2G.148 RBOR 1.329 RIN 9I~02 LS 62 5KS RiCS 1389.861 1019.898 C.144 3C.134 SS GR CSS R.~TC 17298.270 146.572 1C628.940 12.653 ':PTH 1140C CCC ~'T 347~.7£7C N~ .. CCL O.COO SPD 1 G1 873.867 GElS 3326 MON 323.3~4 BKL 30 ISS 292666.30~ SGM~ 3 RBOR 1.76~ RIN 1 DEPTH 11300.CC0 FT 3444.247C 4.449 7.410 9.200 8.428 0.602 LS BKS MSD RICS 317.072 90.333 434.756 1.759 62.824 SS GR CSS R~TC 6494.316 160.437 4658 5~ 20.813 CCL G1 MON ISS RBOR .. .. ' ."- '-- . · _ 168.3G0 SPD 1 5617.492 GElS 9845 431,48~ BKL 241 332593.800 SGM~ 2 1.635 RIN 3.999 6.310 8,321 2.9~6 9.333 LS G2 MS~ RICS 1483.355 1298.661 2582.765 1.176 2C.0C5 SS GR CSS RATO 24771.610 986.791 16625.140 16,751 CCL 0.000 SPO 14 G1 861 5.852 GElS 116989 MON 506.492 5KL 2556 ISS 347770.300 SGM~ 20 ~OR 1 .557 RIN 9 DEPTH 11100.0C,3 FT 3383.287£ M CCL 0.000 SPO 14 G1 1C281.360 GElS 1304C6 MON ~57 ~ ~ ._.~2 BKL 43~5 ISS 356a32.4C0 SGMA 22 REOR 1.4~7 RIN 9 CEPT~ 11C0C rco ST ~5p ~'370 ~ -- CCL C'. GOO $:--"3 1 c G1 11406.570 GEtS 125173 MOt.,'. 537.4C.0 5KL 271 ~ iSS 3475~3.10:0 $ G ~'4~ 19 REOR 1 .~93 RIN ~, ~mT- lOgO0.CCO FT 33Z2.327C >i CCL O.,,CC S~D 1 3 G1 5c32.~17 GElS lZ9725 ~ON 539.674 8KL 197,5 !SS 3¢~5~.800 SGM~ 34 RBOR 1.567 RIN 7 CEPT~ 10~00 CCC ~=T 3~-~1 847C .~ CCL 2.~50 SmO 13 G1 4533.906 GElS 126937 MON 548.942 BKL 1715 iSS 356502.900 S G ,.'"! ~36 R'BOR I .6~' ~ RiN 9 "-': ' DEPTH 1074~.500 FT 3275.235C M . CCL 0.000 SPS 13 G1 639.936 GElS 12C78 MON 91.991 BKL 1739 ISS 37586.240 SG~ 25 RBOR 1.733 RIN 8 .993 LS .300 G2 .147 EKS .036 MSD .073 R!CS .74m LS 3c5 ~KS ,113 .002 qiCS · . 1 O0 G2 .29~ 5KS .332 MSO .633 RICS 1961.931 2351 .388 2748.571 C.759 16.025 216t .319 24t 6.55C 4452.91'0 0.~31 14.139 245!~.755 ~19 r-~Z4 2 '~ ~ '~ ~'1C C.3~~ 13.642 .gg~ L$ 1619.3C3 .50~ ,32 643.644 .627 ~KS 2155.117 .e71 ~SC C.6~7 .823 RICS 1~.445 .99¢ LS 1294.719 .100 G2 429.1e5 .7C3 5KS 1811 .946 ~-24 i'~ ~ '" 0 .2C3 RIDS 17.956 .999 LS 9.999 . uu G2 79 992 .~26 5KS 1619.839 .844 MSD 6.115 .681 R!CS 19.179 3479.9090 ~?~ 23~0 SS G~ CSS R~TC SS icss R~TC SS DSS R,TC SS GR DSS ~TC SS GR CSS R~TO SS GR CSS R4TC 33183.290 907.036 21701.440 16.$8~ 4C143.1~0 1179.095 25237.910 1~.735 25~7Z..'"~0 16.393 $7~.977 ~2413.950 21.229 3 C 40,~. 230 687.032 19859.610 23 45~ 2989.702 777.0¢7 1959.804 299.000 ~,.:-.',-;:'"'~: SERVICE N~ME: VERSION N : 1 DATE: 85/11/ -" MAXIMUM LENGTH: FILE TYPE: LO NEXT FIL~ NAME: ** FILE TRAILER ** ,:~LE. NAME: PAS¢~ 1.01 1024 ** FILE HEADER # Z ** FILE NAME: P~SS 2.0'2 SERVICE NAME: VERSION # : 1 n,,~'r=. .~/~ /~n :' MAX RECORD LENGTk: 102~, FiLE TYPE: LO PREVIOUS FILE NA~E: -* INFORMAT!CN RECORDS BYTES MNEM CONTENTS APIN : 5002920203 CN : ARCO ~L~SKA, WN : D.S. 3-2 FN : P~UBHOE 5. A:Y COUN : NORTH SL~FE ST~.T : ALASK.~ LCD : 15S.C. 3 ** ;CRMAT ** UNITS ENTRY RL TYP$ :NTRY ~ 8 6 C. 0 ~ 9 ,JIN F 11 12 ~ 0 T -O,5OS L uATUM SP!:C 0~,~ E SCR I PT ! ~TICN $LOCKS CURVE REPR N&ME CO~u SIZE ¢~,.PLE"M UNIT~ CCL 68 4 I BZM LS 68 4 I CPS 61 68 ~ I CPS G2 68 ~ 1 CPS NON 68 4 I CPS BKS 68 4 I CPS ISS 68 4 I CPS MSD 68 & I SU RBOR 68 ¢ I elM RiCS 68 4 I ** ;ORMAT ** CURVE N~ME SPD SS GElS GR 8'KL CSS SGMA RSTO RIN CODE 68 68 68 68 SIZE 4 4 4 S~NPLE 1 1 1 1 1 1 1 1 1 UNITS F/NIN CPS CPS A~I ENTRY BLOCKS -'-TYPE ,:.i '. ' ..:, :..: 8 11 0 ENTRY I D 60.0 F .1IN F 12 M T -O.50C L DATUM SPECIFIC OE$£RIPTION EPTHS DEC,EASE RAME SPACING. R~E SPACING UNITS AXiMUM FRAMES/RECORD ER~:!NATOR EYEL SPACING ~ITION BLOCKS ..- CURVE REPR '--"., ~.- NAME CODE · ~:.: .. :-. SIZE. SAMPLE UNITS CURVE NAME · REPR CODE SIZE SAMPLE UNITS . CCL 68 4 I DZM SPO ~8 4 LS 68 4 1 CPS SS 68 ~ G1 68 4 I CPS GElS ~8 4 G~. ~8~ 4 I ~.~':~S, G~ 6g ~ MON 68 4 I CPS BKL 68 & 5KS 6~ 4 1 C~S CSS 68 4 ZSS 68 4 1 CmS SGMA ~ 4 MS~ 68 4 I SU R~TO ~ 4 R~OR 65 4 1 DIM RIN 6~ 4 ** DATA DEPTH, 114~3~ ._~rmC FT q~4~.~ .,~5C M F/MN CPS CPS AP1 CPS ~i SU DIM CCL 0 " .... D 1 I'S ,$ ~,.,'u .~ :3 0 ge'"' .WS 'D ~7.~ ~S . . · ,. j., . · 51 57 ~: ,.q,..4, 2 ~ GElS 39736.C20 .,.~ ,< 1-$ 5'¢. 73 z, GR MON ~8 ~7 &KL 479,952 5K~ 1¢4g 89= *SS iS~- xO'~-o9 ~ro qG!'~& 18 6~'~ rqq,D-' ~ ,,., .... _ ~ , . u 7~d '~TC RSO.R 1.424 RiN 9.4~5 RICS ~1 la24$.~0 1~. ~1,5_ DEPTH 11,cOO.CCO FT 3474.727C H C* ' ~'~ 07~ SS ~L O.COO SPO 1~.7e9 LS ;. .... 51 -'_'202.9O:J GElS 35C19.1c. 0 GE 541.2;6 GR MON, 3~,..~.c~_ E~L .~19.1C9 ~KS 415.0~C., CSS ~YSS ._2872~A, ~.73~'~, SGM~ 27.&P~_. MS3 1 .,.A29 R~TC R~OR 1.55:5 ~IN 10. ~0,3 RiCS 4~ 7~/ 9299.~7 152.P$8 8144.~77 17.953 DEPTH 11300.C0C FT 34~4.247C M CCL 1303.800 SPO 14.999 LS 1347.479 SS G1 5863.469 GElS 93769.440 G2 15C6.316 GR MON 439.SC9 &KL 25~5.371 5KS 25~7.3~2 CSS IDS 3P24~9_ . .;~,j ~¢GM~.. .~1.751. MqD.~ 1.0~C R~TC RBOR 1.575 RiN 9.209 PICS 19.6C2 1062, .-915 1~4~0,350 18.202 DEPTH 11200.C00 FT 3413.7a7C N CCL 351.300 SPO 15.9~$ LS 7.015.412 ' SS G1 ~651 .246 G,=tS 117317.700 g2 2434.303 GR MON 523.952 8KL 22~4.~95 5KS Z5L1 .78C CSS ISS 353193.500 SGM~ 19.371 HSD C.252 RATO RBOR 1.533 RIN P.231 RICS 15.053 33913.010 Q00.585 22002.020 16.824 DEPTH 11100.CC0 FT ~3:$3.2~7C M CCL 9z, 1.~O SmD 15.315 LS 2458.9_-',2 SS 61 12051.~,20 G=IS 12~C50~ . sm'~,~.~ G2 =z*x,_..~_,. :~4~.~ GR, NON 555.919 BKL 2220.&97 B~S 2892.2~ CSS IDS 3=56e0. . .600 SG~, lO..,~&a. NSD F_.62c.- RATO RBOR I .442 RIN 8.797 RiCS I 3.375 DEPTH 11C00.060 FT 3352.807C M 4£~40.=$0 1543.298 Z6592.~70 17.204 CCL 5451850 ~,~DD. 15 . 781 LS 23~7, .18~. SS G1 11653.290 GElS 123714.000 G2 3386.491 GR MON 555.931 BKL 3~24.C23 BKS 3093.125. CSS I$S 353566.800 SGMA 19.146 HSD C.318 RATO RBOR 1.445 RiN $.7C8 RICS 13.754 40787.770 1140.463 25706.370 17.359 DEPTH lOgO0.COO FT 3322.3276 M CCL O.O00 SPD 15.458 LS 1493.142 SS G1 5329.258 GElS 142284.700 62 581 .313 GR 35090.650 859.343 ISS 37t9~7,, ·'~eO~,~ SGMA ,,x5.9~5 RBOR I .545 RIN 8 · ,~G 2 MSO RICS DEPTH 10800.CCC FT 3291.847C M l--lmmmmmImim--mm--I--mmmImm--ImmlI CCL O,CO0 SPD 15.458 G1 x950.x63 G;1S MON 539.339 5KL 1~71.C~4 ISS 350779.100 SG~ 37.919 ~0~ 1,595 RIN 9.C54 D:PTH 10745.5~0 , , LS G2 ~KS ~ISS STARTING 3:-PTri =!1~]],,Cl~JC ;T C.38~ 1 6/. 324 1149.903 3C7 C.778 1~.89! RATO SS GR CSS R~,TC CS£ ~TC 23.$.10 E805~.570 692.S99 1Ec^8.6~0 24.~m0 375~.~24 89g. '.;01 2219 . ~ 7"'~ 1 ~ . ,~ '2 ;;' ** FIL-- FILE N~M_--: P~ SERVICr- NAM=: V,=RSiCN -~ : 1 rj~TE: -55/11/2 MAX RSCO~O LE FILE TYPE: LO PREVIOUS FiLE ** INFORMATIC SS 3 · ,"]= NGT~: 1C24 BYTES NA~E: . NRECORC S TYPE 9 MNEM AP~N~ CN W N FN COUN ST~T LCC FORMAT ** UNITS ENTRY 8LOC~S ENTRY 1 60.0 .liN OES~RiPTION DEPTHS CECREASE FR~FE SPACING- FRA~..E SPACING UNITS 0 D~TUM SPECI; CURVE NAHE COOE CCL 88 LS 68 51 GE 6& MON 68 ISS 88 HSD RiSS 6 TERMIN4TOR LEVEL SP~CING IC~TION BLOCKS STTE,. ~ S,aMPLE UNITS 4 I 3IH 4 I C~S ~ I CPS ~ 1 ~"PS ~ 1 CPS 4 1 C;S ¢ 1 C~S ~ I SU ~. 1 S Z M CURVE REmR NAME CC3E SIZE I I i I I I I i ~ mD 6 ~ 4 GE1 S cS 5KL ~ r S~ ~.~ S G ~': ~ ~ :~ R~TS 6B .. -~. S-~MPLE UNITS I .,:/MN 1 C?S 1 CoS I 1 C~S ' 1 apl 1 SU 1 C. i ENTRY ELOCKS TYPE ENTRY C~TUM SP:CImlCSTICN BLOCKS CURVE REDR NAME CODE SIZE S~MPLE UNITS ~ ii I i i i iii_ COL 68 4 I OIM LS 68 ~ I .CPS G1 68 4 1 CPS S2 68 ~ 1 CPS MON 68 ~ I C~S BKS 68 ~ 1 CPS ISS 68 4 1 CPS HSD 68 4 I SU RBOR 68 4 I C-iM RICS 68 4 I C!M NAME CCi~E SiZE S~PLE SP3 68 4 1 SS 6~ 4 1 GElS 68 4 1 GR 6~ 4 1 ~KL 68 4 1 CSS 68 4 1 SG~ 65 4 1 RATO 08 4 1 RIN 68 4 1 ** D~TA ** DEPTH 11428.C00 FT 3483.251C M CCL 0,000 SPD C.CCO G1 5779,422 GElS 39956,C10 MON 316.968 BKL 389,961 ISS 301489,800 SGMA 15.950 RBOR 1,514 RIN 9,870 LS G2 BKS HSD RIC~ DEPTH 11400.600 FT 347&,727C M CCL 0,000 G1 14~5,168 MON 324,895 .. - ISS 28326~.400 ...:!:' ' - maim. .. . d SPO 13,999 LS GElS 33541,770 G2 BKL 330.131 BKS SGMA 31.482 MSD 1319,868 1099,83C 899.910 C. OZ, 8 30.58C 4C7,22~ 254,884 474,494 0.986 SS GR CSS RATO SS GR USS RATO UNITS F/MN CPS CPS CPS SU CIM 16578,340 178,924 9859.020 12.496 7487,660 156.845 5226.051 18.867 DEPTH 11300.CC0 FT 3444.2476 M CCL 67,500 SPD 14,549 G1 5746.5!2 GElS 92964.0~0 MON 424.346 8KL 2543.757 I$$ 316207. 400 SGMA 21 .CgG REOR I .568 RIN 9.124 LS G2 BKS ~ICS DE,TH 1120e.000 FT 3415.7670 M CCL 0.000 SPD 14.99° G1 8956.473 GElS 119714.80'$ ~ON 52§.~g2 BKL 2445.263 TSS 3539~'~.~~ ~,0 S M,~ 19 91~ RSOR 1 ·538 RIN ¢ DEPTH 11100. C',..,~ T ~CL ~.1-""" qP3 14 9'09 G1 107~0 9'~n GElS 187.~1m 400 .... , ....... uM 21 .C.~~ REOR 1 .466 ~iN ~. 73'2 LS 62 MSm ..<R I C S LS G2 MSD ~ICS DEPTH 1100,9 me,'"' ~T '~'::2 ~,-',70 M . .~ _ ,~, ,./ ~, .,. . .~ ,.., CCL 174..9,C0 S,=D G1 113-~= 3nc GElS 120952; ~,~i w, -.' · ~ ~ON ~31.613 ~KL 3221 ISS 342566.~00 SG.MA 19.5~2 RBOR t ,45~ RIN 8. 5.49 LS G2 =.KS M S g RiCS 10¢00 CC~ FT x~22 ~7C M CCL 39.750 SPS 14. ~¢'P G1 5200.568 GElS 137~49.8C0 MON 541.44& 8KL 21~'2.861 ISS 361481.10~ SGMA 35.747 RBOR I .559 RIN 8.923 LS G2 BKS MS ~ RICS DEPTH 10300.C00 FT 32~1.8470 M I ! i i i I I I I I i I i ' CCL 326.55~ SPD 15.023 G1 4086.04~ GE1 S 1222~2. MON 530.63~ BKL 1~27.111 ISS 347725.40~ SGM~ 36.995 R:SOR I .59~ RIN c.224 LS 62 EKS MSD .~ICS rEPTH 1C740.5C0 FT 3~7~ 711C CCL :::?.~i:~.:_/",:;..::;?.'.~ G 1 MON ISS RBOR 709.500 SmD 14.999 291997 GElS 3319.66~ 45.995 BKL 1529.847 9639.03~ SGMA 607.246 1,80& RIN 6.a48 LS G2 BKS HSD RICS STARTING DEPTH :11428.000 FT ENDING DEPTH :~0740.500 FT 3~83.2613 M 3273.7110 M 1373.$5g 1503.184 2612.4Cl C .779 19.410 2leg .074 2518.754 2712.1.41 0..411 15.79C 2410.74C 27~ 07r 4013.1C7 0.77~ 13.c2~ 2320.110 319~.277 2c9'~ 13.653 =55 928 - 2097.8~2 0.293 1~.321 1275.986 393.579 1835.438 1~..43C 19.998 C .OeO 1719.828 131 .055 24.718 SS GR CSS RATC ~SS C5S ~ATC SS G~ CSS R~TO SS CSS R.&TC SS GR CSS R&TC: SS GR CSS R~TO SS GR CSS RATO 2437~.360 10~0.~09 16291.280 17.~75 .34Z~3.200 ~ ,~ .~ · ~ ,. 22.41~.110 la.2~9 41073.~,C 1 50'~. 71 ~ 2553;.23C 1 ?.024 59762.1 11~1 .7&1 2¢.090.570., 1 7.1,'-, -~,..., 34443.540 885.390 221~8.000 23.92~ 28477.430 743.410 188a7.870 22.229 579.942 831.237 389.961 29.000 ** EiLE TRAILER ~* FiLE NAME: P~SS 3.03 SERVICE NAME: VERSION # : 1 ~=, ~14~ I MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FiLE NANE: *~ FILE HEADER # 4 *~ FiLE NAME: G R .0~ SERVICE NAME: VERSION ~ : q DATE: 55/11/~C MAX RECORD LENGTh: t:]2~ ~YTE.S FILE TYPE: LC ~R~VIOUS ~iLE N&~E: , *~ INFORMATION RECORSS ~* MN EM CO,~ ?: N T S ,:NTRY ~LCCKS TYPE ENTRY CESCmiPTION 11 0 I DEmTHS CECRE~SE 6C.0 FRAME SPACING .lIN FRAME SP~CiNG UNITS 12 M~XZMUM ~RAMES/RECO~D TER~INATO~ -0.500 LEVEL SPACING DATUM SPECI:ICATION BLOCKS CURVE REmR NAME CODE SIZE SfiMPL5 LNiTS COL 68 4 1 3I~ LS 68 & 1 CPS G1 68 ~ 1 CPS G2 68 4 1 CPS MON 68 ~ 1 CPS BKS 68 4 I CPS ISS 68 4 1 CPS MSD 68 4 I SU RBOR 68 4 I DIM RIOS 68 4 I DIM ** FORMAT ** CURVE REPR N4ME CODE SIZE S~MPLE UNITS mmlI iii! IIIml SPD 68 4 1 F/MN SS 6~ 4 1 CPS G~IS 6~ ~ 1 C°S GR 68 ~ 1 ~i BKL ~ 4 1 CPS CSS 68 4 1 SGMA 68 4 1 SU RATO 68 4 1 RiN 68 4 1 DIM ENTRY BLOCKS TYPE 'ENTRY ~ESCRIPTION "' 4 ' I DEPTHS DECREASE 9 ,liN FRAME SPACING UNITS 11 12 M~X!MUM FRAMES/RECORD 0 TERMINATOR -0,500 LEVEL SPACING 10 DATUM SPECIFICaTiON 5LOCKS CURVE REPR CURVE REFR NAME CODE SIZE SAMPLE UNITS NAME CODE SIZE S~MPLE IilI lIIi COL 68 4 1 CiF SP3 ~ ~ 1 LS 6E 4 I CPS SS 58 Z 1 G1 68 ~ 1 CPS GElS 68 ~ 1 02 68 4 1 CPS GR 5~ 4 ' 1 MON &$ ~ 1 CPS 8KL dS 4 1 5KS 68 4 I CPS CSS 63 & 1 ZS.S 6~ ~ 1 ,C°S '.SGY~ 6~ 4 I HSD 68 4 1 SU ~,TO 6.~ ~ 1 R.BOR 68 4 1 CIM RI~ 6~ ~ i RZCS 6~ ~ 1 UNITS F1 MN CPS C:S Su CI ,M Di M DATA SS GR CSS ~. ~, T C. C .GCC 161.758 C · ',30C 0.!74 DEPTH 11~+80.C30 F- .~,~74.727C CCL 3C3.300 SP:] 3~.9~0 LS G1 4.72".5, G~IS 4S1~5o.lC0 02 2. '-,/-, 1 MON 0.012 EKL 212.432 5<S 275.71~ ZSS 21 .O~ SGM~ -1 $3,150 ~.S~ 21 RBOR 0.980 RIN C.COO RiCS 17E.2,~E DEPTH 1130r,,CC 0 FT Z4~,4.247C M CCL O.CO0 SmD 37.996 LS 4C.515 G1 55.1z, 9 GElS 329763.800 G2 66.542 NON 0.308 BKL 3551 .~47 BKS 3248.795 iSS 44.149 SGM~ -~3.g5~ HSD 22.159 RBOR 4.603 RiN O.O00 RiCS C,725 DEPTH 11200.CC, 0 FT 3413.767C M ~CL 01 · MON ISS :~'.--'~!'c-,:-?!:%':.i, R B 0 R · 362.250 SPD 38.123 LS 59.76E 39.226 GElS 250959.500 G2 124,34C 0.547 BKL 2711.201 BKS 2417.964 225.436 SGMA -7.536 HSD 6.8~5 0.62U RIN 0.001 RICS 4.032 DEPTH 11100.C0 limImImmiNmiII .CCL 95.1 G1 128.1 MON 0.3 ISS 113.2 RBOR 0,~ 0 FT 3383. 2870 M ' O~ SPD 38.173 LS 55.056 96 GElS 207991.100 G2 58.413 2~. BKL 643.006 BKS 614.447 21 SGMA 7,370 MSD 15.943 1~ RIN 0.002 RICS 1 .3~6 DEPTH 11000.C0 ' ' ' /-ri.,, . ..... ~1~1 .~ SS OR CSS RATC SS GR CSS RATC SS GR CSS RATO SS GR CSS RATO 122.636 0.118 C.013 117.257 1571.601 .60.924 2.841 61.878 747.272 55.907 0.999 93.962 321.989 82.868 1.760 · . . · G1 87,439 GElS 314406,200 NON O, 6e~3 5KL 288,527 TSS 117,779 SGMA RBOR 1 .COO RiN 0.020 G2 BKS MSD RiOS DEPTm COL O.GCO SPO G1 52.380 GElS MON 0 ,,: x, ~, ~KL ISS 66,55! RBOR 0.957 IO~CO.CCO FT 3322.327C M 3S · 966 LS 2~071_. ~.~4 eO0 G2 11°? 459 5KS -99.c45 MS3 0 on1 ,~IrS DmPTH l O~nn COL 32.250 SPD G1 76.5Cl GElS MON 0.=11 ~K.L i SS 60 · 17';) SGM; REOR 1. C52. ~VN DEPTH COL 1&1 ~.r~ ~ ~ · .., L~ LJ SD~J G1 O.CCO GElS MON 2· COO ~-' "L~ ~, =SS n RBOR 7278.9¢5 ~!N 107`..47 5C"" FT x272 7c?C 33.¢96 LS 1439.,?~a 5KS -3.4.51 MS..,-:. 3. S C C.'" RiOS STARTING O:PTd_. , :11459.0~''~. u-~' FT. ENDING DEPTH :10737.500 ET 35,31.85/-3 3272.7970 46.019 336'886 10.94/-,, 2.1C4 77,846 49 , 112C,'3e9 5¢ I ,113 tc;.gEc C. "" r, C .~5,553 C.*¢C GR CSS R~TC SS GR CSS R,aTC SS GR R~TC. SS G- OSS 2'9!. ~02 55,~1 0.~33 74,150 51S,3~ 59,757 0.~87 675.204 41.;77 C.550 C.OOe C.CCO 11 ** FILE TRAILER FiLE NAME: G R SERVICE NAME: VERSION # : 1 DATE: 85/11/ M~XIMUM LENGTH: 1024 FILE TYPE: LC NEXT FiLE NAME: . ** T~PE TRAILER TAPE NAME: SERVICE NAME: G ~ DATE: ORIGIN 0= DATA: fSYS TAPE CONTZNU~TIO~ # : NEXT TAPE NAffE: COMMENTS: 01 ** REEL TRAILER ** REEL N~ME: SERVICE NAME: BITLiS D~TE . ORIGIN OF DATA: FSYS REEL CCNTINU~TIO~ # : NEXT REEL NAFE: COMMENTS: DRESSE~ REEL HEADER - TAPE HEADER - FILE HEADER - INFORMATION - C~D~T I 01 ATLAS LIS CUSTOMER Tame --- CREAT~-O BY SDS 1 1 . .. PROGRAM .. 2,C DATA - TABLE OUMP - FILE TRAILER - TAPE TRAILER - REEL TRAILER - TOTAL RECORDS: 468 1 1 z+96 12 GRAM: LISCAN RE¥ISION: 5.1 S~mrt of execution: Tue 31 OCT 89 2'16p **** REEL HE~DER **** LIS 89102100 ATLAS 01 LIS ~,U.~TOMER ~OR~'IAT TAPE: PoK 10~' **** TAPE HEADER **** LIS 89/02/00 3402 01 PART NUMBER: WB?QO-OE32 ~.~ FILE 4 HAS Ol== · ~ ~ USION CORRECTED SIGMA FOR RUN I ~ 2' PASS 1.001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : P'RUDHOE BAY : PRUOHOE 8AY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# ON~ DEPTH PER PR~ '~ TAD~ DE~TH U:N~, , ,,~ ~ ~T : ~T 19 CURVES : NAME CODE S~!MPLE~ UNiT BYTES 4 4 4 4 4 9 MON 68 I CTS 10 MSD 68 1 CTS 11 SGMA 68 1 DIM 12: CSS 68 I u"TS I'~ ZSS AR 1 CTS 1~ ~KL 68 1 CTS I~ ~ ~KS 68. I CTS 1 6 RATO 6~ 1 OlFq 17 RICS 68 1 DiM 1 ~ RIN 6~ I DIM 1 ~ RBOR 6-8 I DiM DATA MSB RECORD- (TYPE# uuL GElS SGM~ RATO O) 966 BYTES * SPD G? CSS RICS LS GR _TSS RIN SS MON BKL R~OR 11350,000 5827,545 2,1459'88 558.8740 O0 300,0,'0 98521.44 15,98753 18,80576 12.40470 1363,022 16044,22 6,000000 1360,153 0,0000000 311082,6 5.000000 25606,95 2388,931 160,2670 -1,000000 I 1 300. 000 6323.875 O. 96Z, 9142 0:~30.684 0,0000000 118973,2 2t,30571 23.94882 14,99850 1589,148 19605,17 18,15216 1196.990 2630.299 340435.1 9.575758 28418.52 1783,115 7000,Q30 1.640360. 11250 n~ 962~.676 0.8086413 4828,87! 0.0000000 1037e6.8 1~ 94633 17.87558 14.99850 3139.322 20770.94 14.6~874 1753.183 1668.568 306926.5 9.494316 31476,33 1988,714 4702,172 1,527818 1 I 200. 000 7214.785 0.3063353 0.0000000 10166S.3 19.46053 17,37080 !4,Q9850 2073.368 18475,14 15,50467 1~05.556 548.$752 297205.8 9.758966 27925.48 2019.645 800.6050 1.557412 11150.000 8115,00~ 0,2650222 1244,474 11100.000 8406.738 0.3789353 16~9.412 O,OOOO000 101441,4 19,61343 18,22346 0,0000000 98982.94 19.26781 1~ 78920 14.88930 2298,015 19596,82 14,52406 14.e~985o 241o.913 1953~.54 13.71433 1675.543 56o.1179 289269.6 9.326811 1633.286 ~85.8115 ?~75500.4 9.133101 30464.79 1975.z, 02 1243.703 I .518768 30585.28 2017.345 1209.863 1.498680 11050.000 8056.79? 0,5847983 1450.818 0,0000000 112473,6 20.91959 20,24561 13.99860 2105.Q60 20855.30 15.51032 1592.031 480,3560 313243.1 9.570765 32302.43 1999.107 14~9 1.565174 8395.824 0.330832~ 1497.554 115014,4 19,:~7206 t9,24117 2324.891 21336,32 14.62151 516.8575 322535.2 9.816545 2047.560 1092.7Z7 1.515097 10950,003 767¢ ¢4.~ 0,56223.64 1210,054 0.0000000 1~65,0 26.44077 20.4£76t 14.99850 t56~.249 23069,49 14.76229 1730.150 496,1091 353088,1 9.507805 35140 4~ 1040.789 1 ,583568 10900.000 4170.434 t .2!7751 t438.267 C.O000000 13~585.6 3~.3~380 2~ 4401'~ 14.o9850 4'59. 5549 20898.84 16. ~.~17 1215,831 647,8135 356962,6 9.863493 30884,82 1979,110 1329,952 1,644350 10850.000 $556.$4g 0.3758164 1449.924 0.0000000 121634.1 23.8864E 19.47032 14.99850 1841.450 22614,76 14.47621 183Z.959 565.6394 326654,8 9.392Z81 35742.27 1955,564 1306,459 1.511617 10800.000 1490.126 1.3580'3! 141~.90t O.OOO0000 107248,6 42,89059 26,09145 14.99850 151.4250 15272.33 20.35779 845.3892 575,7290 313077,7 9,9~6813 22030.63 1970.670 1080.447 1,6eo539 10750,000 5~!0.056 0.41~4564 1881.072 0.0000000 118854,6 29.$1407 20,20741 14.99850 94~,5222 19o91.61 17.06885 1534.775 845,7368 343757.1 8,448046 31098.63 2012.130 1733,495 1,56405! TOTAL DATA RECORDS STARTING TAPE DEPTH FiLE TRAILER **** : t04 = 1tx50 0~ ~.~ . ~ ENDING TAPE DEPTH 10730.00 FILE ¢ 2 **** FT,.~,_,.F- HEADER **** PASS 2.002 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAM~ TAPE DEPTH UNIT : FT 19 CURVES : N~ME CODE 1 CCL 68 ~ S~D ~ ~ LS 68 SAMPLE# 1 1 t UNIT VOLT FT ~TS BYTES 4 4 GR MON M SD SGM.~ CS$ BKL BKS R~TO RiCS DATA DEPTH G1 MSD RECORD (Type~ CCL GElS SGMA P&TO 966 BYTES * SPD G2 CSS R!CS LS GR ISS RIN SS MON BKL RBOR 11350,000 7004,574 0.2646445 798,5862 0.0000000 103z, 63.6 21.03940 19,32173 t2,99870 1802.473 15683.38 17.69276 1460.042 46.25658 315270.0 9.757246 28495.69 2064.556 1¢8.3060 1.555188 11300.000 6025.816 0.6464693 6647,000 u. 0000000 110062.3 22.75182 18.78711 12.99870 1542.017 18429.43 19.29720 1370.247 2620.125 329479.1 9.626543 27116.14 1835.401 6919.203 1.651241 112c0.000., 9730.402 0.5124673 4889.246 0.0000000 102716.7 t7.26028 17.55083 13.95700 3244.310 20845,80 14.97043 1893.574 1922.895 310548.4 9.306084 31741.16 1990.598 4777.227 11527381 11200.000 6644.984 0,4018569 1087.t00 0,0000000 92113,38 18.98669 17,84555 13.03440 1970.406 t6898,09 15.80858 1434.744 533.3445 278244.3 9.722538 25636.68 2019.413 899.8691 I .577201 11150.000 849!.270 0.2689456 1197.857 O.O000000 109467.8 19.62059 19.15744 13.39900 2435,392 20883.95 14.39874 1 667.1 89 579.0090 310432.8 9. 244570 32357.63 1995.662 1329.700 1.53902'7 11100,000 9684.414 0,4617117 2001,976 71.99998 117759.2 1~.26810 18.20525 13.39900 2543,561 22~53,55 13.57401 1943.849 854.2534 323649.6 9.218647 35822.95 1998.017 1376.305 1.492366 11050.000 ~865.641 O.O0000OO 118168.5 12.99870 2369.165 1848.844 523.3203 34499.91 1954,90') 11000.000 8615.895 0.4206481 1411.807 0 115617.7 19,98579 19,33011 13.95700 2320.506 21577,11 14.71t49 1669.863 436.4731 331594.7 9.885143 33109.22 2033.403 1428.734 1.532918 10950,000 6642.797 0.5212705 tt01.405 O.O0000OO 128841.8 26.14862 20.38158 13 · 99860 1308.877 2!602.11 1~+.86975 1578.425 492.4153 341941.5 9.643042 32744.85 2001.637 1052.753 1.58,2773 10900.000 3958.581 0.4420?54 1496.416 0.0000000 1'35660.2 38.27022 25.07573 1 ~ 96290 404.3049 20307.71 I 7.2 .81 88 1163.124 661.9695 351627.5 9.993368 30152.19 1991.516 1400.951 1.617521 10850.000 9219.973 0.3306450 1353.655 O.O000u~O 127630.0 23.31564 19.86354 13.59240 2047.202 23916.40 14.48233 1915.252 573.6736 342637.0 9.304953 37577.10 lg70.051 1235.594 1.517520 10500.000 884.109 u.~ 1348.405 0,0000000 116248.3 41, 647~1~ 29.61113 13.99860 260.5649 16746,10 20.50410 840.0999 577.5017 336?36.4 9.911453 24077.89 1991.831 1301.411 1.6,59213 10750.000 2866.355 0.6789882 1843.698 0.0000000 118911.4 a2.12227 t6.96257 13.99860 231.9730 17069.58 lC c9756 932.3650 780.3035 335303.1 9.855392 24607.86 2027.149 169~.080 1.6~9328 TOTAL DATA RECORDS STARTING TAPE.DEPTH FILE TRAILER **** : 104 = 11350.00 ENDING TAPE DEPTH 10730.00 FiL: '~ -.z ***~ FILE ~ADF-R **** PASS 3.003 ln24~ FORMAT RECORD (TYPE~ 64) ON[ DEPTH PER FRAME TAPE DEPTH UNIT : FT 19 CURVES : NAM~ ~'~'~D~- SAMPLe# UNIT 5YT~S * ~ATA DEPTH G1 HSD BKS RECORD (TYPE# CCL GElS SGMA RATO O) 966 BYTES SP~ G2 CSS RIrq LS GR ISS RIN SS MON BKL RBOR 11350.000 7044,?07 0.4900005 746,0371 0,0000000 103071.3 20.56331 19.92015 13.99360 1562.327 18622.83 17,97339 1420.176 46,80670 316749.6 9. ,571 787 28325.62 2033.679 209.1520 1,565497 11300.000 603~, ,056 1 .064761 6779,9~6 0.0000000 114964.0 ~1.72935 19.~6540 13.99860 i532.033 18,991.66 I :S. 75 861 1366.626 2636.717 343379.3 9.403454 27898. r¢5 1831.615 7525.953 1 ,66631Z 11250.000 10355.93 0.3514165 5!7R.738 66.29999 107145.0 17.15283 18.11028 13.99860 3295.871 21772,67 14.81946 1805.545 1896.424 323002.0 9.3,54008 33096.91 1994.944 4568.887 1.528146 11200.003 7895.148 0.37538Z5 t020.751 0.0000000 109031.1 17.65456 14.99550 2255.777 ~0047.75 15.59081 1721.794 521.9956 322537.6 9.715885 30434.76 2019.512 773.9470 1.564578 11150.000 9308.836 0.199394~ 1319.874 0.0000000 t16062,1 20,02631 17,77663 14,99850 2554,582 14.4129.5 1 931 · 1 8'3 561 ,~691 330285.4 9.148191 34:356.09 1972.087 1329.655 1.514580 11100.000 10118.04 0.360453? 1559.72'4 0.0000000 11=197. · 1 18.99019 18.11049 t4 ~344m ~945.455 2 ~ c996.23 t3.70576 t978.981 922.9023 322922.1 9.068317 35814.19 2010.545 1244.138 1.475073 815 ,520 0,4~95~09 1551.747 118555,0 20 85w. ,~1 Z1800.56 1 5 · 496.5564 '~31 26~ ~ 9. 522280 1986.212 1465.459 1 .548419 11000,0uu' .... 3434.176 0,8908, O82 1390,549 0.0000000 113589.4 19.53395 18.75906 1~.99850 2304,569 21185,66 1~.93721 16S4.535 423.9700 327678.8 9.$64305 32608,52 2033.867 1539.263 1,546043 10950.000 7070.570 0.5851167 ~UiJ · 71 0 O.O000OO0 13t177.6 25.64093 19,17384 1466,438 22159.63 15.00215 1739.5D7 4~4,1960 349354.3 9.570356 33552.78 2003.026 1009.256 1,582474 10900,000 3821,435 0,7980031 1535,290 O.O0000OO 132263,3 39,18456 24,58038 14,~9850 366,4719 19750,52 17.21918 1161.674 659,8625 344830.Q 9,709824 29052.78 1989.602 1383.949 1,609451 10550,000 8760,613 0,4367877 1396,800 0.0000000 12419Z.I 24,U3y92 !9,27133 t4.99350 1368,834 23140,89 14,7~618 1877,898 570,1230 337584,8 9.241373 36783.79 1971.857 1279.675 1.513996 10800,000 2515,046 1,0113~.4 1328,~58 0,0000000 111773,3 40.93324 Z8.14114 14.998S0 ~49.3~0 16;333.38 20,64001 828.1230 591,2566 324969.9 9.955315 22887.97 1988.35~ 1169.153 1,659713 10750,000 2917,169 0,4798193 1797,396 0.0000000 117118.4 41,40118 25,84254 14.~9850 27.8.7451 16791,77 19.73354 938.3540 791.8616 331508,3 9.827015 24107.95 2029.429 1700.168 1.662870 TOTAL DATA RECORDS STArTiNG TAPE DEPTH **** FILE TRAILER **** : 104 : 11350,00 ENDIN"~ TAP: DEPTH : 10730.00 FiLE ~ 4 CORR. ,00~ **** ~ILE HEADER **** 1924 COMMENT 'FIRST 'SECOND RECORD SGMA IS S G,~i A TS DIFFUSION CORRErT DIFFUSION CORRECTED AVERAG: AVERAGE SIGMA SIGM~ FROM RUN 1' FROM RUN 2' ONE OEPTH PER :RAME TAPE DEPTH UNIT : r--'T CURVF3 : NAME CODE SAMPLE# SGMA 68 1 UNIT BYTES ~.,M 4 * OATA RECORD (TYPE# DEPTH SOMA 11350.000 14.28152 11300.000 !8,38t01 11250.000 14.51211 11200.000 16,07552 11150,000 16,0'~050 11100.000 17,98535 11050. 000 16,1 2379 11000.000 15.91609 10950.000 23.06541 10900,000 31.73747 10850.000 19.37595 10800.000 33.35167 10750,000 -999.2500 O) 1014 BYTES * SOMA 15.15198 17.93829 13.64147 14.63551 15.95424 17.07z, 52 I=~, . 52452 16.75325 25.50226 40.06387 t8.71257 45.07166 -'920.2500 TOTAL DATA RECORDS : STARTING TAPE DSPTH = FILE TRAILER **** **** TAPE LiS $9t02/0o 3402 01 TRAILER **** 15 1!350.00 ENDING TAPE DEPTH : 10730.00 TOTAL **** REEL RECORDS IN THIS TRA!L~R **** LOGIC~,L TAPE : 344 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 345 TOTAL DECOROS IN THI:S PHYSICAL REEL: 345 End of execUt±on: Tue 31 OCT 89 2:t7o Eiapsed e~iecut£on t~me = I minute ' 41.0 $,e'conds. SYSTEM RETURN CODE = 0 1! 000000": 7777777777 '000000 7777777777 11 000000 7777777777 000000 ?177777777 1111 O0 O0 ' 77 O0 O0 77 1111 O0 O0 77 O0 O0 77 11 O0 0000 77 O0 0000 77 11 O0 0000 77 O0 0000 77 11 O0 O0 O0 77 O0 O0 O0 77 11 O0 O0 O0 77 O0 O0 O0 77 11 0000 O0 77 0000 O0 77 11 0000 O0 77 0000 O0 77 11 O0 O0 77 O0 O0 77 il O0 O0 77 O0 O0 77 111111 000000 77 000000 77 111111 000000 77 000000 77 660666 000000 222222 066666 44 44 060666 000000 222222 006600 44 44 66 O0 O0 22 22 66 44 44 66 O0 O0 22 22 Ob 44 44 66 O0 0000 22 06 44 44 66 O0 0000 22 66 44 44 66666666 O0 O0 O0 22 66666666 4444444444 66666666 O0 O0 O0 22 66606606 4444444494 66 66 0000 O0 22 66 66 44 66 06 0000 O0 22 00 66 44 66 66 O0 O0 22 66 66 44 66 06 O0 O0 22 06 66 44 666006 000000 2222222222 066660 44 000666 000000 2222222222 666666 4~ GGGG H H BBBB PPPP RRRR U U DDDD H H OOO EEEEE G H H B B P P R R U U D D H H O O E G H H B B P P ~ R U O D D H H O 0 E G HHHHH BBBB ..... PPPP RRRR U it D D HHHHH O O EEEE G GGG H H B B P R R O U O D H H 0 0 E G G H H B B P R R U U D D H H O O E GGG H H BB~B P R R UUUUU DDDD H H OOO EEEEE *START* USER PCAL [10707,60264] JOB SHIP SEO. 3762 DATE 17-JUL-80 09:28:19 MONITOR SWS KLIOE37 APR-80. *START* *START* USER PCAL [10707,60264] dOB SHIP 8E~. ]762 DATE 17-jUL-80 09:28:19 MONITOR SWS KLlOE37 APR-BO. *START* SSSSSSSS HH HH IIIII1 SSSSSSSS HH HH IIIIii SS HH ~H II SS HH HH II SS HH HH II SS HH HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH II SS HH HH ii SS HH HH I1 SS HH HH II SS HH HH II SSSSSSSS HH HH Iiiiii SSSSSSSS HH HH Iiiiii PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP TTTTTTTTTT O0000O TTTTTTTT~T 000000 TT OO O0 TT O0 O0 TT O0 O0 TT OO OO TT OO OO TT OO OO TT OO OO TT OO OO TT O0 O0 TT O0 OO TT OOOOOO TT OOO000 *STARTS USER PCAG [10707,60264] JOB SHIP SEO. 3762 DAT~ 17-JUL-80 09:28:19 MONITOR S~S KLIOE~7 APR-80. *START* FILE: DS~B:SHiP.TO<255;[10707.60264] CREATED: 17-jUL-80 08:09:05 PRINTED: 17'JUL-80 09:28:]4 QUEUE SWITCHES: /FILEIPORT /COPiES:I /SPACiNG:i /LIMIT:150 /PORMS:NORMAb SHIPPING INSTRUCTIONS ISSUED 15-JUL-80 14:01 GHB PCCC VENTURA, CALIFORNIA 93003 PCCC j. % V¥ ¥¥ EEEEEEEEEE RRRRRRRR ¥¥ YV ELEEEEEEEE RRRRRRRR YV ¥¥ EE RR RR VV VV EE R~ RR VV VV EE RR RR VV VV EE R~ RR VV VV EEEEEEEE RRRRRRRR VV VV EEEEEEEE RRRRRRRR VV VV EE RH RR VV VV EE RR VV VV EE RR RR VV VV EE RR RR VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR Iiiiii Ii11II II II 1I II Ii 1i ii Ii II II IIiiii IIIIII YY YY YY YY YY YY YY YY 000000 000000 333333 000000 000000 333333 O0 O0 O0 O0 33 33 O0 O0 O0 O0 33 33 O0 0000 O0 0000 33 O0 0000 O0 0000 33 O0 O0 O0 O0 O0 O0 33 O0 O0 O0 O0 O0 O0 33 0000 O0 0000 O0 33 0000 O0 0000 O0 33 O0 O0 O0 O0 33 33 O0 O0 O0 O0 33 33 000000 000000 333333 000000 000000 333333 *START, USER PCA6 [10707 60264] JOB SHIP MONITOR SW$ KLIOE37 APR-80[ *START* f'IhE: DSKH:VERIf~.O03<057>[10707.60264] CREATED: PRINTED: 17-JUL-80 09:28148 QUEUE SWITCHES: /FILE:FORT /COPIES:I /$PACING:I /LIMIT:150 /FORMS:NORMAL ]762 DATE 17-JUL-BO 17-dUb-BO 09:2B:19 09:21:24 SCMLUMB~RGkR COMPUTING CENTER 10707,60264 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: Ol PREVIOUS REEL NAME: COMMENTS: LiS f~ORMAT CUSTOMER TAPE DATE: 80/ 7/15 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: ~0264 DATE: 80/ 7/15 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: 01 PREVIOUS TAPE NAME: COMMENTS: TAPE COMMENTS THE OPEN HOLE DATA WAS DIGITIZED f'ROM bOGS RUN IN MAY UF 1976. THE DIL HAD THE fOLLOWING INFORMATION ON THE HEADING: CSG:I] ]7502696/BTSZ:12.25/FLU1D=LiGNOS/f'LUiD LEV'EL:fULL/DENS=lO.3/ V1SC=4~/PH=il.0/FL=5.0/RM:2.71~68/RMf'~:2.40~64/RMC=].8~68/BHT:i50 PASS THREE Of' THE TUT IS iNVALID f'RUM 11230-11180 DUE TO POWER SURGE. EOF ~ILE READER LENGTH: 62 ~YTES FILE NAME: EDIT .001 MAXIMU~ PHYSICAL RECORD LENGTH: PRE¥1OUS fILE NAME: FILE COMMENTS OPEN HOLE DATA. 1024 BYTES WELL SITE INFORMATION RECORD LENGTH: C[]MPANY: WELL: fl~LD: RANGE: TOWN: SECT ) : · 188 BYTES ATLANTIC RICHFIELD CO. DILLSITE 3-2 PRUDHOE BAY 15E iON NORTH ALASKA DATA ~'ORMAT SPECIFICATION LENGTH: 490 BYTES ENTR~ BLOCKS: 0 SIZE REP CODE ENTRE I 6e 0 i,)ATUM SPECIFICATION BLOCKS: ~NTRY lC TOOL 6VORD# UNITS APl API APl AP1 FILE# 6IZ~ EXP PROC SAM REP DEPT $~i~'T DEPT 8P OIL ILO ibm LLSU DIL GR CNL CALl CNL D~H0 ~"DC NPHI CNL DPHI CNL GR BBC DT BHC ~T 0 0 0 0 0 4 0 0 ! 68 0 0 MV 7 ! 0 0 0 4 0 0 ! 68 0 0 OHMM 7 12 46 0 0 4 0 0 1 68 0 0 OHMM 7 !2 44 O 0 4 0 0 1 68 0 0 OHMM 7 22 8 0 0 4 0 0 I 68 0 0 GAPI 42 31 32 O 0 4 0 0 I 68 0 0 IN ~2 28 1 0 0 4 0 0 i 68 0 0 G/C3 42 44 0 0 0 4 0 0 1 68 0 0 PU 42 68 3 0 0 4 0 0 1 68 0 0 PU 42 68 1! 0 0 4 0 0 1 68 0 0 GAPI 60 31 32 0 0 4 O 0 I 58 0 0 U$/F 60 52 32 0 0 4 0 0 168 O 0 DEPTH 11708.000 11700.000 11600.000 I1500.000 11400.000 1.1300.000 13200.000 11100.000 11000.000 10900.000 10800.000 10700.000 10600.000 10500.000 MN EMONiC SP GR DPHi SP GR DPHI SP GH DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHi SP GR DPHi SP DPHI SP GR DPHI GH OPHI SP GR DPMI SP GR DPttl SP GR DPHI VALUE -29.03! 2.371 1.3.680 -29.031 135.125 5.758 -28.422 85.375 2.520 -91.313 34.375 24.000 -13.906 84.188 3.479 -53.219 36.750 24.719 -44.750 30.828 18.953 -31.438 36.750 19.438 -47.156 28.45] 21.469 -0.047 149.875 0.000 -12.695 96.625 7.078 -10.883 151.125 18.719 -26.000 222.875 14.875 -35.063 142.875 9.594 MNEMONIC ILD CALl GR CALl GR ILD CALl GR CALl GR ILD CALl GR CALl GR ILD CALl GB ILD CALl GR CALl GR ILD CALl GR CALl GR iLO CALl GR 1LD CALl GR ILD CALl GR 'VALUE 5.180 750 5.477 13 172 9.219 1].773 79.500 2 602 12~141 31.578 7.656 13.930 71.000 18.359 12.375 34.188 36.531 12.977 30.594 28.688 12.773 35.969 44.031 13.055 25.797 14.414 15.961 133.125 1.761 14.211 79.75O 3.707 15.289 131.125 3.314 15.289 188.375 2.752 14.703 127.750 ,. ) MNEMONIC ibm DRH[3 DT ILM DRHO DT DRHO DT DT DRHO DT DRHU DT DEMO DT DRHO DT IbM DRHU IbM DRHO DT DT IbM DRRO OT IbM DRHO DT IbM DRRO DT VALUE 5.891 0.089 82.I25 5. 781 109 9.883 0.083 88.125 ].084 0.061 92.563 8.367 0.039 74.8'75 16.594 0.021 102.188 077 87.313 23.359 -0.001 90.938 30.797 0.047 97.750 13.180 0.053 66.438 2,006 0.144 102.188 3.920 0.129 108.625 3.439 0.059 107.000 3.076 0.099 103.375 MNEMONIC bb8U NPHI hhSU NPHI NPHI bL8U NPH! LL8U NPHI bhSU NPHi bhSU NPHI hh8O NPHI LLSU NPHI hbSO NPHI bbSU NPMI bbSO NPHi DLSU NPHI bbSU NPHI VALUE 6.750 0.000 b.750 42.156 10.727 23.734 7.547 25.781 10.531 28.313 18.703 29.875 32.625 20.828 28.125 26.141 43.063 28.906 19.063 27.094 2.b72 39.156 5.859 43.719 5.441 42.750 4.807 37.344 DEPTH 10400.000 10300,000 10200.000 10100.000 IO000.000 9900.000 9800.000 9700.000 9600.000 9500.000 9400,000 9300.000 9200.000 9100.000 MNLMOHIC SP DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHi SP GR DPHi SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPH1 GR DPHI VALUE -22.969 129.750 10.195 -14.516 164.750 8.516 -27.203 182.000 13.195 -38.688 161.250 13.914 -36.875 212.250 13.914 -"26.609 99.56 8.875 -35.063 96.000 9.477 -26.b09 80.000 12.594 -18.750 87.688 17.031 -24.797 98.375 10.680 -29.625 75.875 15.719 -38.094 88.313 13.797 -33.844 79.438 10.555 -28.422 87.125 11,758 MNEMONIC CALl GR ILD CALl GR CALl GR ILD CALl GR ILD CALl GR CALl GR ILD CALl GH ILD CALl GR ILD CALl GR CALl GR CALl GR iLO CALl GR CALl GR ILD CALl GR VALUE 3.707 14.383 112.750 4.992 14.461 139.125 930 148.750 1.665 14.664 142.125 2.160 15.734 169.750 1 896 1§~563 85.188 2.242 15.102 80.375 3.506 15.375 75.563 1.761 14.586 83.375 2.082 16.094 92.938 1.575 15.492 74.375 1.896 15.969 79.750 2.]28 15.617 76.188 2.285 15.734 84.563 MNEMONIC DRHO DT IbM DT DRHO DT DRHO DT ibm OReO DT 1LM DRHO OT DRHO DT ILM DRHO DT IbM DRHO IbM DRHU DT DRHO DT ILM DRHO DT IbM DRHO DT ILM DRHO PT VALUE 3.992 0.019 103-000 0; 45 95. 375 2.508 0.088 103.375 1.827 0.082 113.438 2.285 0.053 101.000 969 :o,o 93.313 2.371 0.141 88.938 3.039 0.039 79.313 1.'194 0.150 107.375 2.160 0.058 92.938 1.696 -0.003 98.188 2.082 0.033 92.125 2.555 0.009 9O.500 2.508 0.074 92.938 MNEMONIC LL8U NPHI LL8U NPHI LL8U NPHI Lb8U NPHI LL8U NPHi 66BU NPHI LLBU NPHI 668U NPHI 66BU NPHI LLBU NPHI 66BU NPHi bbBU NPHI 668U NPHI 668U NPH1 VALUE b.551 35.156 8.984 33.250 3.061 39.875 3.004 39.250 3.824 41.188 2.31b 32.15b 3.0bi 31.563 0.082 25.29'7 2.111 37.094 2.688 31.797 1.819 34.438 2.494 30.828 2.949 31.922 2.895 31.922 DEPTH 9000.000 8900,000 8800.000 8700.000 8600.000 8500.000 8400.000 8300.000 8200.000 8100.000 8000,000 7900,000 7800.000 7700.000 MNkMONIC GR DPHI SP GR DPHI SP GR DPHI SP GR DPHi SP GR DPHI SP GR DPHi SP GR DPHI SP GR DPHI SP GH DPHI DPHI SP GH SP GR DPHi SP GR DPH1 SP GR DPHI VALUE -28.422 83.563 13.438 -26.609 106.125 13.797 -41.125 115.750 12.953 -48.375 112.750 9.953 -47.15b 90.563 10.79:7 -46.563 1.10.938 11.516 -51.40b 101.938 11.398 -56.844 92.375 14.633 -88.875 72.563 18.719 -99,188 67.750 I7.906 -39,906 71.938 15.148 -54.406 59.969 19.953 -50.188 70.750 11.650 -40.500 83.375 13.102 MNEMONIC ILD CALl GR lb[) CALl GR ILD C AL i GR ILD CALl GR 1 LD CALl GH ILD CALl GR ILD CALl GR ILD CALl GR ILD CALl GR CALl ILD CALl GH ILD CALl GH ILD CALl GH ILD CALl VALUE 2.910 16 06 2.160 15.734 99.375 3.254 17 797 953 105.375 2.910 17.953 83.688 3.848 1 953 7 :7so 2.701 17. i]91 86.688 3.135 17.359 82.500 3.377 15.539 69.875 2.416 15.758 b9.250 2.965 14.555 72.875 1.761 13.758 bl.438 3.020 16.031 71.063 2.555 17.953 84.938 MN EMONiC DRHO DT 1LM DRHO DT ibm DRHO DT ILM DRHO DT DRHO DT IbM DRHU DT DRHO DT DRHO DT iLM DRHO DT IbM DRHO DT DRHO DT IL~ DRHO DRHO DT DRHO DT VALUE 3.020 0.082 89.313 2.555 0.008 105.375 3.254 938 314 92.125 2,965 0.058 85.438 3.70'7 0.090 91,125 2.803 0.072 95.750 3.254 0.084 93.938 3.570 0.052 93.500 2.416 0.066 97.375 2.803 0.016 93,938 2.121 0.002 101.375 3.020 0.004 95.938 2.855 0,090 101.188 MNEMONIC Lb8 U NPH1 LLSU NPHi bb8U NPHI LL8U NPHI LL8U NPHI bh8O NPHI LL8U NPH1 bb8O NPHi LL8U NPHI LLSU NPHI bbSU NPHI bb8O NPHI LL80 NPHI bbSU NPHI VALUk 3.824 28.313 3.29"1 34.563 3.617 31.859 3 969 30:172 3.684 32.219 4.195 30.891 3,117 31.500 3.824 32.219 3.017 30.1'72 2.842 29,938 3.017 31.750 3.896 32.344 3.084 33.313 3.234 32.094 DEPTH 7600.000 7500.000 7400.000 7300.000 7200.000 7100.000 7000.000 6900.000 6800.000 6700.000 6600.000 6500.000 6400,000 6300,000 MN SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI GR DPHI SP GB DPH] VALUE -62.281 50.969 14.789 -32.65b 76.750 12.383 -83.438 60.594 19.594 -130 625 21,078 -107.625 52.781 15.898 -105.188 63.594 18.547 -116.125 59.969 13.492 -131.250 36.594 25.047 -107.000 42.594 25.891 -71.938 46.188 21.203 -74.375 56.375 I4.211 -62.875 72.56] 16.984 -85.875 48.594 29.'750 -38.688 65.9]8 21.672 ,MNkMONIC ILD CALl GR 1LD CALl GR. CALf GR iLD CALl GR ILD CALl GR 1LD CALl GR ILO CALl GR iLD CALl GR ILD CALl GR CALl ILD CALl CALl ILD CALl GR ILD CALl GR VALUE 914 60.813 3.707 17.625 71.063 2.285 13.313 57.219 1.383 12.953 49.375 2.160 14.039 51.594 2.508 15.758 60,594 2.855 14.b80 62.969 1.283 12.953 43.781 1.356 13.875 47.375 2.855 14.477 52.188 4.145 17.797 58.781 3.506 17.031 65.938 1.794 17.984 4b.781 3.848 17.516 b3.594 MNEMONIC DRHU OT ibm DRHO OT DRHO DT ibm DRHU DT DRHO DT DRHO DT IbM DRHU DT DRHO DT IbM DRHO DT IbM DRHO DT IbM DRHO DT DRHO DT ibm DRHO DT DRHO DT VALUE 2.910 0.026 93.313 775 o :o o 102.375 2.152 0.158 97.750 1.827 0.058 98.375 2. '701 ; .oo2 .938 3.020 -0.014 101.188 3.b39 -0.004 94.750 1.b35 0.014 100.188 1.729 0.020 102.813 3.193 0.010 90.063 3.992 0.110 107.625 3.920 0.046 103.000 2.lb0 -0.012 124.188 4.066 0.064 99.750 MNEMONIC bbSO NPH1 bbSU NPHI LLSU NPHI LL8U NPHi LLSU NPHi 668U NPHI LLSU NPHi 6bSU NPHI bbSU NPHI b68U NPHI 6LSU NPHI 668U NPHI 6680 NPHI 668U NPHi VAbUE 4.867 30.047 4.043 31.016 5.441 28.719 8.492 27.15b 5.b48 32.813 5.340 31.141 6.313 33.438 4.434 29.688 6.551 33.90b 5.859 32.344 b.313 21.359 5.648 34.15b 4.195 31.141 4.867 34.625 D E P T H 6200.000 6i00.000 6000.000 5900.000 5800.000 5700.000 5600,000 5500.000 5400.000 5300.000 5200,000 5100.000 5000.000 4900.000 MNEMONIC SP GR DPHI SP GH DPHI SP GR DPH1 SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR OPM1 SP GH DPHi SP GR DPHI SP DPHi VALUE -34.469 74.938 17.469 -31.438 74.375 16.984 -47.781 59.969 22.891 -84.063 49.188 30.828 -79.813 60.594 24.203 -4'7.781 65.375 20.469 -53,813 76.188 15.414 -82.813 52.781 27.344 -111.875 40.188 27.938 -82.250 55.781 22.047 -89.5OO 39.594 25,531 -111.250 31.797 33.969 -50.188 69.563 20.828 -38.094 29.984 28.188 MNEMONIC ILD CALI GR ILD CAi, I GR IhD CALl GR ILD CALl GR ILD CAI, I GR CALl GR ILL CALl GR CALl GR CALl GR ILD CALI GR ILD CALl GR ILD CALl GR ILD CALl GR ILL CALl VALUE 3.020 17,953 69,563 3.639 17.906 71.938 2.461 15.273 65.375 1.546 17.828 49.781 1.604 15,398 59.969 3.992 17.750 66.563 3.639 17.984 70.188 2.328 15.516 52.781 2.006 14.836 43.781 2.701 14.914 58.781 2,121 14.117 53.375 1.761 17.953 43.781 3.775 17.547 67.750 2.201 13.477 77.375 MNEMONIC ILM DRHO DT DRMO DT DRHO OT iLM DRHO DT IbM DRHO DT DRHO DT IbM DRHO OT DRHO DT ibm DRHO DT DRHU DT IbM DRHO DT ORMO DT IbM DRHO DT DRHO OT VALUE 3.193 0.104 114.875 3.193 0.092 I09.438 2.508 0.052 100.188 1.933 0.002 122.125 1.827 0.008 107,250 4,223 0.028 102.188 3.639 0.022 104.375 2.650 0.048 118.938 2.461 0.006 115.313 3.707 0.050 106.563 2.201 0,070 119,063 2.285 0.000 121.875 3.848 0.048 102.063 3.193 0.036 113.625 MNEMONIC LLSU NPHI bb80 NPHI LLSU NPHI LLSO NPHi LLSU NPHi LL80 NPHI LL8U NPHI hb8O NPHI LL8U NPHI LL8U NPHI LLSO NPHI LLSO NPH1 bbSO NPHI LL8U NPHI VALUE 3.896 35.594 3.684 41.281 3.969 37.031 4.117 32.813 3.551 31.016 b.195 33.531 4.195 ]8.250 5 051 34:750 b.082 36.313 7.324 30.422 4.04] 30.938 5.543 37.031 5.441 43.094 3.969 34.625 /O D~PTH 4800.000 4700.O00 4600.0O0 ~500.000 4400.000 4300.000 4200.000 4100.000 4000.000 3900.000 3800.000 3700.O00 3600.000 3500.000 MNEMONIC SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP DPHI SP GH DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPHI SP GR DPH! GR DPHI SP GR DPHI VALUE -51,406 30.594 28.063 -92.500 30.594 28.063 -83 438 29~984 28.063 -67.125 29,984 28.188 -108.813 30.594 28-188 -64.063 30.594 28.313 -75.000 30.594 28.313 -90.063 30.594 28.313 -94.938 30.594 28.313 -97.375 30.594 28.313 -71.938 30.594 28.313 -113.063 30.594 28.313 -7b.188 30.594 28.313 -79.188 30.594 28.313 MNEMONIC CALl GR CALl GR CALl GR CALl GR CALl GR ILD CALl GR CALl GR ihD CALl GR CALl GR CALl GR CALl GR iLD CALl GR CALl GR ILD CALl GH VALUE 3.920 13.516 73.750 3.193 13.516 58.I88 4.898 13.516 58.78I 4.547 13.51b 73.188 3.992 13.516 50.375 4.b33 13.516 73.750 6 012 67.188 477 64.188 4.223 13.516 60.594 4.992 13.516 65.375 4.809 13.516 69.563 2.910 13.516 54.594 3.314 13.516 74.938 2.602 13.516 67.188 MNEMONIC I6M DRHO DT 1LM DRHO DT DRHU DT ibm DRHO DT DRHO DT l LM DRHO DT DRMO DT ibm DRHO DT ORHO DRHO DT DRHO DT AbM DRHO OT DRHO DT DRHO DT VALUE 4.145 0.036 118.438 3.775 0.034 119.875 5.4';'7 O.03b 109. 375 4.809 0.036 129.750 4.992 0.038 113.875 4.520 0.038 139,000 6.082 0.040 123.000 b.195 0.040 98.875 4.091 0.038 120.375 5.648 0.038 115.500 4.777 0.038 118.063 3.357 0.038 122.875 3.484 0.038 128.000 3.004 0.038 134.625 MNEMONIC bbSO NPHi LLSU NPHi LLSU NPHI LLSU NPHi LLSU NPHI LLBU NPHI bbSU NPHI hbSU NPHi LLSU NPHi LLBU NPHI NPHI 668U NPHI 668U NPHI 668U NPHi VALUE 4.117 34.625 b.67b 34.625 8.820 34.625 5.754 34.b25 9.500 34.750 5.859 34.750 7.324 34.750 8.336 34.750 "1.891 34.750 8.656 34.750 5.973 34.750 7.324 34.750 5.051 34.750 9.777 34.750 DEPTH 3400.000 3300.000 .]200.000 3100.000 3000.000 2900,000 2800.000 2700.000 2600.000 2596.000 MN EMON1C SP GR DPHI 8P GR DPHI 8P GR DPHI GR DPHI SP GR DPHI MP GR DPHI SP GR DPHI SP GR DPHi SP GR DPH I $P DPH1 VALUE -88.250 30.594 28.313 -75.000 30.594 28.313 -107.625 30.594 28.313 -102.188 30,594 28.313 -64.688 30.594 28.313 -115.500 30.594 28.313 -105.813 30.594 28.313 -9b.750 30.594 28.313 -92.500 29.984 28.313 -999.250 -999.250 -999.250 MNEMONIC ILD CALl GR ILD CALl GR 1LD CALI GR ILD CALl GR ILD CALl GR ILD CALl GR CALl GR CALI GH ILD CALl GR ILD CALl GH VALUE 2.121 13.516 62.375 2.555 13.516 69.563 1.356 13.516 49.188 2.160 13.516 47. 969 2.461 13.516 69.563 1.383 13.516 44.969 1,260 13.516 46.188 2.371 13.516 56.969 1.435 13.516 41.969 -999.250 -999.250 -999.250 MNEMONIC IbM DRHO DT DRHU DT I LM DRHO DT ILM DRHO DT DRHO DT iLM DRHU DT iLM DRHU DT DRHO DT' ILM DRHU DT DRHO DT VALUE; 2.449 0.038 130.250 2.688 0.038 127.063 1.568 0.038 141.875 2.316 0.038 135.125 2.31b 0.038 141.750 1.960 0.038 145.875 1.721 0.038 131.875 2.736 0.038 139.250 2.b37 0.038 57.000 -999.250 -999.250 57.000 MNEMONIC LLSU NPHI LL8U NPHi 6L8U NPHI LL8U NPHI LL8U NPHI bb8U NPHI bb8U NPHI LL8U NPHI LL8U NPHI LL8U NPHI VALUE 4.117 34.750 3.754 34.750 3.b17 34.750 %.b91 34.750 3.0bl 34.750 4.434 34.750 750 4.355 3~. 750 1.165 34.750 -999.250 -999.250 SU~AR~ O~~ DATA NUMB£~ O~ ~ECURDS: 868 LENGT~ 0~' RECORDS: 1014 BY'TES LENGTH O~~ LAST RECORD: 870 BYTES FILE TRAILER LENGTH: 62 B~TES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECURD LENGTH: NEXT ~iLE NAME: 1024 BYTE6 FILE HEADER LENGTH: 62 BYTES FILE NAME: EDiT .002 MAXIMUM PHYS1CAL RECORD LENGTH: PR~V1UUS FILE NAME: FILE COMMENTS PASS ONE TDT. 1024 BYTES WELL SITE INFORMATION RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECTION: COUNTY: STATE: 188 BYTES ATLANTIC RICHFIELD CO. DILLSITE 3-2 PRUDHOE BAY 15E 10N 11 NORTH SLOPE ALASKA DATA ~ORMAT SPECiFICATiON LENGTH: 450 BYTES ENTRY BLOCKS: 0 SIZE] REP CODE ENTRY ! 66 0 DATOM SPECIF ICATIUN BDOCRS; ENTRY 1 2 4 5 7 8 9 10 11 lC TOOb SVORD# UNITS AP1 API AP1 APl Flbk# 6IZ DEPT GR TOT TAU TDT THAT TDT SIGM TDT NITD TDT N2TD TDT N3TD ~DT F1TD TDT P2TD TDT F3TD TDT ~ EXP PROC FT 0 0 0 0 0 4 0 0 GAPI 51 31 32 0 0 4 0 0 US 51 41 1 0 0 4 0 0 C/C 51 42 I 0 0 4 0 0 CO 51 40 I 0 0 4 0 0 CPS 51 39 1 0 0 4 0 0 CPS 51 39 2 0 0 4 0 0 CPS 5I 39 ] 0 0 4 0 0 CPS 51 39 1 0 0 4 0 0 CPS 51 39 2 0 0 4 0 0 CPS 51 39 3 o 0 4 0 0 SAM REP DEPT SHIFT I 08 0 0 I b8 0 0 1 68 0 0 1 68 0 0 I 68 0 0 I /)8 0 0 1 b8 0 0 1 68 0 0 I 68 0 0 I 08 0 0 1 68 0 o DEPTH 11595.000 11500,000 11400.000 11.300.000 11200,000 11100.000 11000.000 10900.000 10800.000 10790.000 MNE~M[IN lC GR NITD ~'2TD GR NITD ~'2TD GR N1TD F2TD GR NITD f'2TD GR N1TD F2TD GR N1TD F2TD GR NITD ~2TD GR NITD F2TD GR N1TD F2TD GR N1TD ~2TD VALUE -999.000 -999.000 -999.000 31.800 970.854 142.714 50.400 2134.673 304.523 32.700 1234.171 215.075 20.600 767.839 144.724 30.000 2038.191 335,678 19.900 1750.754 257.286 76.900 2603.015 315.578 b3.200 2158.794 240.201 0,300 2.010 1.005 MN EMON lC TAU N2TD ~3TD TAU N2TD F3TD TAU N2TD P-3TD TAU N2TD P3TD TALl N2TD F3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD ~3TD TAU N2TD F3TD TAU N2TD P'3TD VALUE -999.000 -999.000 -999.000 237.503 623,115 47.236 90 691 1270:352 123.61:8 214.135 848.241 79. 397 .884 66.332 187 973 1254:271 114.573 218.961 1101,507 104.523 129.045 1583.919 130.653 129.045 1380.904 130.653 -4.052 0.000 0.000 MNEMONIC TRA~ NBTD TRAT N3TD TRAT N ,]TO TRAT N3TD TRAT N3TD TRAT N3TD TRAT N 3 TD TRAT N 3TD TRA'I' N3TD TRAT N3TD VALUE -999.000 -999.000 2.825 297.487 4.065 470.352 3.070 40b.030 2.370 410,050 3.220 522.613 3.145 534.b73 3.885 590.955 4.625 592.965 0.025 4.020 MNEMON lC SiGM F1TD SlGM F1TD $IGM 6lTD 61GM F1TD 61GM F1 'I'D SIGM F1TD F1TO $iGM F1TD SIGM F1TD S1G~ FITO VAbUE -999.000 -999,000 19.225 215.075 49.875 402.010 21.475 283.417 15.b50 188.945 24.200 484.422 20.b50 359.799 35.250 499.497 35.250 367.839 0.375 2.010 SUMMARY OF DATA R~CURDS NUMBER [JF RECORDS: 71 LENGTh Of' RECORDS: 1018 BYTES LENGTH Of' LAST RECORD: 50 BYTES FILE TRAILER LENGTH: 62 BYTES f'ILE NAME: EDiT .002 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~'ILE NAME: 1024 B~TE$ EOf FILE HEADER LENGTH: 62 BYTES ~'ILE NAME: EDIT .003 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: FILE COMMENTS PASS TWO AND PASS THREE OF THE TOT. 1024 BYTES WELL SITE INFORMATI[IN RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECTION: COUNTY: STATE: 188 BYTES ATLANTIC RICHf'IELD CO. DILLSITE PRUDH.OE BAY 15E ION NORTH SLOPE ALASKA DATA f~ORMAT SPECIf'ICATION LENGTH: 850 BYTES ~NTRY BLOCKS: TYPE 0 SiZE REP CODE ENTRY ! 66 0 DATUM SPECli~'ICATIUN {5LUCi{S: ENTR~ IC T.OOh 1 DEPT 2 GR TDT TAU TDT 4 TRAT TDT 5 S1GM TDT 6 N1TD TDT 7 N2TD TDT 8 N3TD TDT 9 F1TD TDT F2TD TDT 11 ~3TD TDT 12 GR TDT TAU TDT 14 TRAT TDT 15 SiGM TDT 16 N1TD TDT 1.7 N2TD TDT 18 N3TD TDT 19 f'ITD TDT 20 F2TD TDT 21. F3TD TDT SVORD~ UNITS API AP1 AP1 AP1 F1LE$ SIZE EXP PROC SAM REP DEPf SHIFT FT 0 0 0 0 0 4 0 0 GAPI 51 31 32 0 0 6 0 0 US 51 41 1 0 0 4 0 0 C/C 51 42 1 0 0 4 0 0 CU 51 40 1 0 0 4 0 0 CPS 51 39 1 O 0 4 0 0 CPS 51 ]9 2 0 0 4 0 0 CPS 51 ]9 3 0 0 4 0 O CPS 51 ]9 1 0 0 4 0 0 CPS 51 39 2 0 0 4 0 0 CPS 51 39 3 0 0 4 0 0 GAPI 51 31 32 0 0 4 0 0 US 51 41 1 0 0 4 0 0 C/C ~51 42 1 0 0 4 0 0 CU 51 40 1 0 0 4 0 0 CPS 51 39 1 O O 4 O 0 CPS 51 39 2 0 0 4 0 0 CPS 51 39 3 0 0 4 0 0 CPS 51 39 1 0 0 4 0 0 CPS 51 ~9 2 0 0 4 0 0 CPS 51 39 3 0 0 4 0 0 I 68 0 0 I 68 0 0 1 68 0 0 I 68 0 0 I 68 0 0 1 68 0 0 1 68 0 0 I 68 0 0 1 68 0 0 1 68 0 0 1 68 0 0 I 68 0 0 1 68 0 0 1 68 0 0 1 68 0 0 I 68 0 0 1 68 0 0 1 68 0 0 1 68 0 0 1 68 0 0 1 68 0 0 DEPTH 11595.000 11500.000 11400.000 11300,000 11200.000 11 100.000 11000,000 10900.000 10800.000 MN EMONIC GR NITD F2TD TRAT N3TD GR NITD P'2TD TRAT GR N1TD P2TD TRAT NSTD GR NITD F2TD TRAT NSTD GR NITD F2TD TRAT N3TD GR N1TO TRAT NSTD GR NITD F2TD TRAT NSTD GR N1TD F2TD TRAT NSTD GR N1TD F2TD TRAT NSTD VALUE MNEMONIC VAbUE 0.200 TAU -4.052 0.000 N2TD -2.010 0.000 F3TD 0.000 -999.000 SIGM -999.000 -999.000 F1TD -999.000 28.900 TAU 239.281 994.975 N2TD 735.678 145 729 ~3TD 60'302 2~850 SIGN 18.300 607.035 F1TD 215,075 56.300 TAU 90.945 1973,869 N2TD 1224.121 280.402 ~3TD 126,633 4.400 SiGM 47.725 703.518 F1TD 386.935 32.900 TAU 223,787 115].769 N2TD 834.171 190.955 F3TD 90.452 2.960 SIGM 19.200 619,095 f'ITD 229,146 23.600 TAU 262,395 980.904 N2TD 777,889 168,844 F3TD 76,]82 1.700 SIGM 11.750 387.940 ~ITD 261.307 31,500 TAU 188.227 2060.301 N2TD 1350.754 340.703 F3TD 127,638 ].030 SIGM 23.800 711.558 FITD 429.146 26.000 TAU 232.423 1461.306 N2TD 1045.226 231.156 f3TD 116.583 2,905 SIGH 20.250 683.417 FITD 358.794 85,200 TAU 135.141 2450.251 N2TD 1475.377 293.467 ~3TD 126.633 4.200 SIGH 33.525 753.769 ~ITD 48.3.417 63.400 TAU 139.459 2122.613 N2TD 1382,915 236.181 FSTD 116.583 4.380 SIGM 32,725 751.759 f'ITD 376.884 MNEMON1C TRAT N3TD GR N1TD ~2TD TRAT N3TD GR NITD F2TD TRAT N]TD GR NITD FRTD TRAT N3TD GR N1TD ~2TO VALU~ MNEMONIC -0.0iO SIGH 0.000 F1TD -999.000 TAU -999 000 N2TD -999:000 F3TD 2.755 SIGH 542.714 FITD 36.000 TAU 962.814 N2TD 154,774 F3TD 4,295 SIGH 641.206 F1TO 55,900 TAU 2014.070 N2TO 311.558 F3TD 3 445 SI:GM 574:874 F1TD 33,100 TAU 1093.467 N2TD 159.799 FSTO VALUE 0,000 2.010 -999,000 -999.000 -999,000 19.000 219.095 247,663 739.698 72.362 49,250 351.759 93,485 1332.663 134.673 20,200 240,201 238.773 880.402 88,442 TR.AT 2.560 SIGM 17,450 N]TD 582.915 F1TD 255.176 GR 34,400 TAU 391.428 N1TD 689.447 N2TD 317.588 ~'2TD 139.698 ~STD i26.633 3.265 8IGM 023.115 f'ITD 35,200 TAU 1877.387 N2TD 317.588 F3TD 2.940 SIGH 629.146 F1TD 24.900 TAU 1670. N2TD 3.845 SIGH 671,357 FIIO 89,300 TAU 2568.844 N2TD 304.523 FSTD TRAT N3TD GR N{TD F2TD TRAT N3TD GR N1TD F2TD TRAT NSTD GR NITD ~'2TD TRAT NSTO GR NITD ~2TD 4.215 SIGH 645.226 F1TO 55.700 TAU 2301.507 N2TD 249,246 f'3TO 24.175 440.201 191.529 127b,382 13b.b83 19.725 309.548 223.279 1i37.b88 11b.583 33.375 481.407 134.379 lb32.161 133.668 32.475 360.804 137.681 1497.487 129.648 DEPTH 10790.000 MNEM[]N lC GR N1TD F2TD TRA T N3TD VALUE 0.300 2.010 1.005 0.060 2.010 MNEMDNIC TAU N2TD ~;3TD $IGM FITD VALUE 2.010 I. 005 0.475 4.020 MNEMONIC TRAT GR NITD ~2TD VALUE 0.010 0.000 0.400 4.020 0.000 MNEMONI. C F1TD TAU N2TD VALUE 0.425 3.015 '4-052 2.010 0.000 SUMMARY OF DATA RECORDS NUMBER (~ RECORDS: 1,]5 LENGTH OF RECORDS: 1014 BYTES LENGTH OF' LAST RECORD: 258 BYTES F'iLE TRAiLEB LENGTH: 62 BYTES FILE NAME: EDIT .003 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~'ILE NAME: 1024 BYTES EOF ~'ILE HEADER LENGIH: ~2 BYTES FILE NAME: EDiT .004 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: FILE COMMENTS PASS 1024 BYTES WELL SITE IN~'ORMATiUN RECORD LENGTH: COMPANY: WELL: F'IELD: RANGE: TOWN: SECT1ON: COUNTY: STATE: 188 BYTES ATLANTIC RICHFIELD CO. DILLSITE ~-2 PRUDHOE BAY 11 NORTH SLOPE ALASKA DATA FORMAT SPECIFICATIUN LENGTH: 450 B'YTES ENTRY BLOCKS: T 2 PE 0 SIZE REP CODE ENTRX 1 66 0 DATUM 8PECIf'ICATION BhOCKS: ENTRY 1 2 5 6 7 8 9 10 11. lC rOOb SVORD# UNITS DEPT GR TDT TAU TDT TRAT TDT $IGM TOT N1TD TOT N2TD TOT N3TD TDT P1TD TOT [2TD TOT ~'3TO TDT FT GAPI US C/C CO CPS CPS CPS CPS CPS CPS AP1 0 51 51 51 51 51 51 51 51 51 51 AP1 0 31 41 42 40 39 39 39 39 39 39 AP1 0 32 1 1 1 1 APl 0 o 0 0 0 o 2 0 ] 0 I O 2 O 3 0 Flbg~ EXP PROC SAM REP DEPT SHIFT 4 0 0 1 68 0 0 4 0 0 I 68 0 0 4 0 0 I b8 0 0 4 0 0 I 08 0 0 4 0 0 1 68 0 0 4 0 0 I 68 o o 4 0 0 1 ~8 0 0 4 0 0 I b8 0 0 4 0 0 1 68 0 0 ~ 0 0 1 68 0 o 4 0 0 1 68 0 0 DEPTH 11595,000 11500,000 11.400,000 11300,000 11200.000 11100,000 11000o000 10900.000 10800,0O0 10790o000 MN EM[)NIC NITD P 2TD GR NITD F2TD GR N1TD F2TD GR N1TD ~2TD GR N1TD F2TD GR N1TD ~'2TD GR NITD ~'~2TD GR N1TD F2TD GR N1TD F2TD GR N1TD f~2TO VALUE 0,000 2.010 1.005 26,000 iO53,266 163,819 59,600 2110,553 314.573 41.600 1324.623 235.176 27.400 816.080 150.754 32.200 2046,231 321,608 23.400 1497.487 244.221 88,500 2562,814 290.452 67.500 2259.296 243.216 0,500 10,050 2,010 MNEMON lC TAU N2TD FSTD TAU N2TD TAU N2TD F3TD N2TD FSTD TAU N2TD F3TD TAU N2TD FSTD TAU N2TD ~'STD TAU N2TD f'STD TAt] N2TD F3TD TAU N2TD FSTD VALUE -4.306 0.000 I .005 224.041 721.608 52,261 94.501 1290.452 130.653 206.007 918.593 94.472 288.049 607.035 65.3,27 190.259 1208.040 110.553 231.915 920.603 103,518 133.871 1481.407 110,553 134.633 1394.975 1.10,553 -4,052 6,030 1.O05 MNEMONIC TRAT NSTD iR,AT NSTD TRA~£ N3TD TRAT N3TD TRAT N3TD TRAT N3TD ' ' NSTD TRAT N3TD TRAT NSTD TRAT NSTD VALUE 0.000 4.020 2.850 341.708 4.540 486.432 3.085 438.191 141 3.090 402.010 2.985 397.990 3.965 458.291 4,185 500.503 0.025 4.020 MNEMUNIC $IGM F1TD $1GM flTO SIGM F1TD 8IGM El'rD $IGM F1TD SIGM SIGM F1TD SIGM F1TD $1GM F1TO $IGM flTD VALUE 2.400 3.015 20.500 225.120 47.550 386.935 22.150 309.548 15.775 194.975 24.000 474.372 19.650 358.794 33.850 483.41'7 33.750 397.990 0.900 5.025 SUMMARY Of' DATA RECORDS NUMBER OF RECORDS: 71 LENGTH OF RECORDS: 1,018 BYTES LENGTH OF LAST RECORD: 50 BYTES fILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT ,004 MAXIMUM PHYSICAL RECORD LENGTH: NEXT FILE NAME: 1024 BYTES EOF ~iLE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .005 MAXIMUM PHYSICAL RECURD LENGTH: PREV1UU$ FiLE NAME: ~'iLE COMMENTS PASS FIVE AND PASS SlX, 1024 BYTES WELL SITE INFORMATION RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECTION: COUNT~: STATE: 188 BYTES ATLANTIC RICHFIELD CO. DIDLSITE 3-2 PRUDHOE BAY 15E 1ON 1! NORTH SLOPE ALASKA DATA fOI~I~AT SPECIFICATION LENGTH: 850 BYTES ENTRY BLOCKS: IYPE 0 SIZE REP CUDE ENTRY 1 6~ 0 DATUM SPECiFiCATICii\{ BLOCKS: ENTRY lC TOOL SVOI~,D# UNi,rs AP1 API AP1 AP1 FIL~:~ 6IZ~: EXP PROC SAM HEP DEPT SHIFT ! DEPT 2 GR TDT GAPI ,] TAU TDT US 4 TRAT TDT C/C 5 $1GM TDT CU 6 NITD ~DT CPS '? N2TD TDT CPS 8 N3TD TDT CPS 9 ~ITD TDT CPS 10 ~:2TD TDT CPS I1 F]TD TDT CPS 12 G~ TDT GAPi 1] TAU TDT US 14 TRAT TDT C/C 15 61GM TDT CU 16 NITD TDT CPS 17 N2TD TDT CPS 18 N3TD TDT CPS 19 ~'ITD TDT CPS 20 F2TD TDT CPS 21 F3TD TDT CPS 0 0 0 0 0 4 0 0 I 58 0 0 51 31 32 0 0 4 0 0 1 68 0 0 51 41 i 0 0 4 0 0 I 68 0 0 51. 42 1 0 0 4 0 0 i 68 0 0 51 40 I 0 0 4 0 0 1 68 0 0 51 39 1 0 0 ~ 0 0 1 68 0 0 51 39 2 0 0 4 0 0 1 68 0 0 51 39 3 0 0 4 0 0 I b8 0 0 51 39 I 0 0 4 0 0 1 68 0 0 51 ]9 2 0 0 4 0 0 I 68 0 0 51 ~9 3 0 0 4 0 0 I 68 0 0 51 ]1 32 0 0 4 0 0 1 68 0 0 51 41 1 0 0 4 0 0 1 68 0 0 51 42 I 0 0 4 0 0 I 68 0 0 51 40 1 0 0 4 0 0 1 68 0 0 51 39 1 0 0 4 0 0 1 68 0 0 51 39 2 0 0 4 0 0 1 68 0 0 51 39 3 0 0 4 0 0 1 68 0 0 51 39 1 0 0 4 0 0 1 68 0 0 51 ~9 2 0 0 4 0 0 I 68 0 0 51 39 3 0 0 4 0 0 1 b8 0 0 DEPTH 11595.000 11500.000 11400.000 11300.000 11.200.000 11100.000 11000.000 10900.000 10800.000 EMt]N lC GR NITD P2TD TRAT NBTD GR N1TD F2TD TRAT NSTD GR NITO F2TD TRAT N3TD GR NIT0 F2TD TRAT NSTD GR NITD F2TD TRAT NSTD GR N1TD F2TD TRAT N3TD GR N1TD F2TD TRAT NSTD N1TD f 2TD TRA'I N]TO GR N1TD ~2TD TRAT NSTO VALUE -999.000 -999.000 -999.000 -999.000 -999.000 28.900 964.824 134.673 2.740 448.241 55.200 1925.628 289.447 4.335 558.794 37.800 1153.769 210.050 3.095 490.452 30.900 974.874 169.849 2.810 508.54] 37.800 1903.518 338.693 3.170 619.095 28.800 I692.462 261.307 3.085 598.995 90.000 2761.809 313.568 4.085 671.357 67.500 2301.507 256.281 4.345 659.296 MNEMONIC TAU N2TD FSTD SIGM F1TD TAU N2TD ~STD S1GM FITD TAU N2TD [;STD S1GM [;lTD TAU N2TD f*3TD SIGM f~ITD TAU N2TD SIGM F1TD TAU N2TD P3TD $IGM F1TD TAU N2TD FSTD SIGM f-lTD TAU N2TD 8IGM TAU N2TD ~STD 6IGM F1TD VALUE -999 000 -999!000 -999 000 2999.000 999.000 240.043 655.276 48.241 19.650 227.136 93.739 1202.010 118'593 47.225 412.060 223-025 741.708 76.382 21.275 242.211 262.395 697.487 68.342 18.125 234.171 193 053 1195~980 114.573 25.425 496.482 216 421 1109~548 108.543 20.725 339.698 131.077 1640.201 130.653 35.050 496.482 132.347 1429.146 118.593 33.675 400.000 MNEMONIC TRAT N]TD GR NITD F2TD TRAT N]TD GR N1TD ~2TD TRAT N3TO GR N~TD ~ TD TRAT N]TD OR N1TD P'2TD TRAT N3TO GR NITD TRAT N3TD GR N1TD P2TD TRAT N]TD GR N1TD P2TD TRAT NSTD GR N1TD f2TO TRAT NSTD GR N1TD P2TD VALUE -999.000 -999.000 -999,000 -999.000 -999.000 3.050 353.'769 31.000 1039.196 161.809 4.090 478.392 58.800 2008.040 334.673 MNEMONIC 'VALUE 8iGM -999.000 FITD -999.000 TAU -999.000 N2TD -999.000 FSTD -999.000 SIGM 18.925 F1TO 196.985 TAU 231.153 N2TO 733.668 F]TD 5b.281 $IGM 48.325 P'ITD 385.930 TAU 94.501 N2TD 1210.050 F]TO 150.754 2.650 SIGM 20.200 440.201 FITD 272.362 39.400 TAU 216.675 1139.698 N2TD 844.221 190.955 F3TO 88.442 2.~70 448. 41 30.000 986.935 170.854 2.915 540.703 37.300 2205.025 384.925 3,1bO 532.663 31.300 1604.020 241.206 4.070 615.075 94.500 2647.236 297.487 4.325 603.015 72.300 2237.186 242.211 SIGM 17.350 F1TD 228.141 TAU 252.997 N2TO 767.839 ~STD 82.412 SlGM 23.550 ['lTD 480.402 TAU 178.575 N2TD 13~4.824 ~'STD 14/.739 SIGM 21.125 F1TD 355.779 TAU 219.977 N2TD 1089.447 F3TD 111.558 SIGM 34.425 F1TO 505.528 TAU 129.299 N2TD 16b8.342 FSTD 135.b78 SIG~ 34.050 F1TD 402.010 IAU 134.125 N2TD 1411.055 F3TD 110.553 DEPTh 10790.000 MNEMONIC GR N1TD F2TD TRAT N3TD VALUE 0.700 12.060 2.010 0.000 -4.020 MNEMONIC TAU N2TD F3TD SIGM FiTD VALUE -4.052 8.040 1.005 0.000 -2.010 MNEMDNIC TRAT N]TD GR NITD P2TD VALUE 0.065 4.020 0.000 -4.020 -2.010 MN~EM ON lC $1GM Fl'I'D N 2 TD F]TD VALUE I .02,5 5.025 -3.036 -~.020 -2.010 SUMMAR~¥ OF DATA RECORDS NUMBER OF RECORDS: 135 LENGIB 0~' RECORDS: 1014 BYTES LENGTH OF LAST RECORD: 258 BYTES flUE TRAILER LENGTH: 62 BYTES FiLE NAME: EDiT .005 MAX/MUM PHYSICAL RECORD LENGTH: NEXT ~iLE NAME: EOF TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 60264 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: NEXT TAPE NAME: COMMENTS: 1024 BYTES DATE: 80/ 7/15
