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Home My WebLink About180-0702024-1008_Incident_PBU_17-02_Flowline_Rupture_jh Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-8-2024 P. I. Supervisor FROM: Josh Hunt SUBJECT: Ruptured Flowline Petroleum Inspector PBU 17-02 PTD 1800700 Hilcorp North Slope LLC 10/8/2024: I traveled to Prudhoe Bay Unit Drill Site 17 to talk with the operator about the incident. I met with Hilcorp operator Tim Phillips and went over what happened. He told me that on 10/2/2024 at around 09:00 their main water injection facility went down due to an unknown cause. This caused the water tanks to fill up very fast, which led to shutting down several pads going to that facility including Drill Site 17, which led to the well flowlines pressuring up. When the flowline on PBU 17-02 reached about 1300 psi it ruptured and caused a complete separation of the flowline; Mr. Phillips stated that in the past the line has held 2000 psi without incident. The pipe failure resulted in roughly 30 feet of separation between the flowline ends and bent two of the heavy-duty flowline vertical support members (VSM)’s over at a 45-degree angle. They reported to me that the estimated volumes of the spill were 100 gallons of oil, 800 gallons of produced water, and 2 gallons of corrosion inhibitor. ACS was on location and actively cleaning the spill during my visit. As of right now the half of DS17 that Well 02 is located is completely shut down and isolated until the VSM’s can be fixed to support all the other associated lines; the other half of DS17 is online. Hilcorp put together hard line from Well 17-02 over to Well 17- 03A. Once they get the VSM’s fixed they plan to bring that half of the pad back on. Their plan is to leave Well 17-03A shut in, flow across the tree and use its flowline for Well 02. There is a spot on the hard line for them to install a low-pressure pilot for the surface safety valve, but they haven’t got that far yet. The root cause of this failure is external corrosion caused by a small leak in the insulation which held water against the pipe and eventually rusted through the galvanized pipe around the insulation. Attachments: 11 Pictures; PBU DS17 Pad Map 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.09 11:12:32 -08'00' 2024-1008_Incident_PBU_17-02_Flowline_Rupture_jh Page 2 of 4 PBU 17-02 Flowline Rupture Photos by AOGCC Inspector J. Hunt 10/8/2024 Flowline on the ground behind DS 17-2. Hard line going from well #2 to well #3. This is the fitting for the pilot once they get going. 2024-1008_Incident_PBU_17-02_Flowline_Rupture_jh Page 3 of 4 Corrosion on the bottom of the ruptured flowline. Looking at the end of the ruptured flowline. The other end of the flowline pushed back 30’. The bottom of the galvanized pipe which covers the line. 2024-1008_Incident_PBU_17-02_Flowline_Rupture_jh Page 4 of 4 One of the bent VSM’s (cut off already) Side of the road covered in oil. (road was cleaned) Showing whats left of the release on top of the ice. "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/"/"" " " " # # # # # "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ "/ 16 15 20 21 7 8 9 10 12 13 14 1 2 5 6 11 193 4 22 1265'1245'60'Enter/Exit 830' Gravel Removed from Tundra Gravel Removed from Tundra 200' 215' 160' 155'60'4971 4904 4901 4902 WELL WELL INJECTOR DATE :MAP DATE : 2015SCALE : 1" = 200 'PBU - DS 17 bs14495.mxd 6/30/2016 For current Well and Service information please see Atlas: http://alaska-gis.bpweb.bp.com ! S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, October 07, 2015 7:44 AM To: AK, OPS FS2 OSM; AK, OPS FS2 Field OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr; Drotar, Mark; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Stechauner, Bernhard Subject: OPERABLE: Producer 17-02 (PTD#1800700) TIFL Passed All, Producer 17-02 (PTD#1800700) passed a warm TIFL on October 03, 2015 confirming two competent barriers in the wellbore. The well is reclassified as Operable. Plan Forward: 1. Downhole Diagnostics: Cold TIFL—FAILED 09/22/15 2. Downhole Diagnostics: Warm TIFL—PASSED 10/03/15 3. Operations: Return well to production as needed Please call with any questions or concerns. Thank you, SCD AUG 0 4 2016, Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com Fro • AK, D&C Well Integrity Coordinator Sent: Tu y, September 22, 2015 6:51 PM To: AK, OPS FS2'QSM; AK, OPS FS2 Field OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline 0.; .tions Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr, : e - Mark; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti 3; Ste :. '-r Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C We ;. ity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spe - • 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION 17-02 (PTD #1800700) Sustained Inner An . Casing Pressure over MOASP All, 0 11111/ 0 ■ 4 S T co co O el < � N N E E 0 0 U §N 11�'11� st co .12g2'1 0,'7 co 10.g64- '..,..r & 7 -O QOcam `" IO t c & 0)"6 ,0, 08 U 0)d y 0�3t U !n 0 Q Q(I Q s .2 -- 03 E 0 N ccoo A c1 ° 6' 0.Is o _ 0 Z U 0 N N CL7 LO.1 m Q �7 go 7 7 7 7 7 >>>7 >>7 7 7 7 7 7 7 7 7 7> 0 corn oo c Q Q Q n • a co a a Q�:2?Q Q C< N N N N CO N 0 N N N N 1-CO M M W N 0' LIO Z . f ° 0 ° Q cc W U a O -J U ? W 0 I i 2 Z0 C7 C, 0 0 0 OJ U I otf e6 e8 = Z Z II- I~i LL0 a1- 1-U. 0 IC Z O 0 00 pp o> w 30 e- IIJ 1/1 3 Way y 0 0 w• 000m=ma00=-m0_I=re2=001-Q a l aaaaamawwwmrcaaamawmaacnw a___ayaU__v�aa_x0m1-00Z z gooo�.-oo0S.-ooh- - ooo � Uet o o 0990 CD 999'9999999999499QQ99Q m y -) ZoCC� �F. '9EaY �� a coaiaF.oe0a0 ; � vi030/ 0.5 z m°mmmm''mmmmmm'' 0mmmMmaammmMa N U) o Z a, ILI -1 CO.1. 0 c w 7 N O N 0I• !i 01001.x 1-°16 UY ^63aaa`-2 , :i> �a NNaaae4I c c O o. E )d M N Q C N w ° 13 m NuZw W6. wwO dmdo QrQQ STATE OF ALASKA ~, ALA IL AND GAS CONSERVATION COM ON ~~~~~~~® REPOOF SUNDRY WELL OPE NS O MAR 2 G 2008 1. Operations Performed: ^ ® ~t~,~, ~ & G~ ~8, ~~ Abandon RepairWell ^ Plug Perforations ^ Stimulate Re-Ent~~SLSOgn~ed e I II~~10TTddyyee ®Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 180-070 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20486-00-00 7. KB Elevation (ft): 70, 9. Well Name and Number: PBU 17-02 - 8. Property Designation: ~ j:3~ ',~ 10. Field /Pool(s): ADL ~~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary ~~ Total depth: measured 11375 - feet true vertical 9567 feet Plugs (measured) N/A Effective depth: measured 11304 feet Junk (measured) N/A true vertical 9504 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2676' 13-3/8" 2676' 2676' 4930 2670 Intermediate Production 11348' 9-5/8" 11348' 9543' 6870 4760 Liner ~'~ APR ~ 4 200 Perforation Depth MD (ft): 10512' - 10784' Perforation Depth TVD (ft): 8818' - 9051' 4-1/2", 12.6#, 13Cr-80 10313' Tubing Size (size, grade, and measured depth): .r,_1 i2" 17# i _Rn Packers and SSSV (type and measured depth): 9-5/8" x 4-1l2" BKR S-3 10225' 9-5/8" x 5-1/2" BKR SAB 10336' 12. timulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 10145'. Cut and pull 9-5/8" casi ng from 1900'. Run 9-5/8" (47#, L-80, TC-II) tieback to surface. Cement w/ 130 bbls Class 'G' w/ Gas-Blok 730 cu ft / 624 sx . Clean out and run new Chrome tubin to 10313'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 10 235 Subsequent to operation: 820 905 2998 1652 317 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564-4387 308-007 Printed Name Sondra Stewman Title Drilling Technologist II~~zz Prepared By Name/Number: 5"®~ °~ Sign ure M_ Phone 564-4750 Date UJ - Sondra Stewman 564-4750 UC)I'1 Form 10-404~~ised 04/2006 ~~~3X3/~ ~ ~ ~ ~~- ~~"` ~~ Submit Original Only TREE _ FMC GEN 2 WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV 70' BF. ELEV = KOP = 3100' Max Angle = 46 @ 6200' Datum MD = 10573' Datum TV D = 8800' SS L9-518" CSG, 47#, L-80, ID = 8.681" ~-j 1903 13-3/8" CSG, 72#, L-80, ID = 12.347" 2676' irlimt.l;Ill ID = X-Nipple @ 2090' = 3.813" ID 17-02 Q' ~-~ Csment to surface 4-1/2'° X NIP; 1D = 3.813" CHAS I IFTMANDRFLS ST MD TV D DEV TYPE V LV LATCH PORT DATE 5 3041 3040 9 MMG DOME RKP 16 03104!08 4 5134 4791 44 MMG SO RK 24 03!0410$ 3 6849 5999 45 Fu1tv1G DIt~tY RK 0 02126!08 2 8482 7195 40 MMG DMY RK 0 02126/08 1 9862 8281 37 MMG DMY RK 0 02126/08 1(}1 ~~,' --~ 4-1 /2° X NIF~PLE, ID = 3.813" 14225' 9-518" X 4-1'2" BKR S-3 PKR, ID = x.xx° 10259' 4-112" X NIPPLE, ID = 3.813" ~ 4-112" TBG; 12.6#, 13Cr-80:.0154 bpf; ID = 3.958" ~ 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ PERFORATION SUMMARY REF LOG: BRCS ON 07/31/80 ANGLE AT TOP PERF: 33 @ 10512' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 0.2 10512 - 10522 O 03/28/91 4" 8 10632 - 10642 O 06/10/81 4" 8 10651 - 10656 O 04/29!88 4" 12 10668 - 10678 O 04/29/88 4" 8 10684 - 10714 O 04/29/88 4" 8 10728 - 10748 O 04/29/88 4" 8 10764 - 10784 O 04/29/88 PBTD -j 11304, 9-5/8" CSG, 47#, L-80, ID = 8.681" 11348' TD 11375' 1Q31' -'~4-112" TUBING TAIL WLEG 10336' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.750" 10390' 1 5-1/2" CAMCO LAND NIP, ID = 4.44" 10393' -j 5-1/2" BAKER SHEAROUT SUB 10384' ELMD TT LOGGED 09/01!80 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/05/80 ORIGINAL COMPLETION 02/25108 D16 RWO 03/09/08 KSB/PJC GLV C/O (03/04/08) PRUDHOE BAY UNIT WELL: 17-02 PERMfT No: 1800700 API No: 50-029-20486-00 SEC 22, TI1 N, R15E, 4308.55 FEL & 1317.94 FNL BP Exploration (Alaska) • • BP EXPLORATION Operations Summary Report Page 1 of 15 ~ Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task I Code NPT Phase ~; Description of Operations 2/13/2008 21:00 - 22:00 1.00 MOB P 22:00 - 00:00 2.00 RIGD P 2/14/2008 00:00 - 03:30 3.50 RIGD P 03:30 - 17:00 I 13.50 I MOB I P 17:00 - 18:00 1.00 RIGU P 18:00 - 18:30 0.50 RIGU P 18:30 - 19:30 1.00 MOB P 19:30 - 20:30 I 1.001 RIGU I P 20:30 - 21:00 I 0.501 RIGU I P 21:00-22:30 1,50RIGU ~P 22:30 - 00:00 1.50 RIGU P 2/15/2008 00:00 - 00:30 0.50 WHSUR P 00:30 - 03:00 2.50 WHSUR P 03:00 - 03:30 0.50 WHSUR P 03:30 - 04:00 0.50 WHSUR P 04:00 - 04:30 0.50 ~ W HSU R P 04:30 - 07:30 3.00 WHSUR P 07:30 - 09:00 1.50 WHSUR P 09:00 - 10:00 1.00 WHSUR P 10:00 - 12:30 2.50 WHSUR P PRE PJSM. Jack up rig and move off F-17A. Spot rig to UD derrick. PRE Continue R/D rig floor and prepare to lay down derrick. PRE Continue R/D. Place Rig Mats over buried electrical cables. Remove BOPE from cellar and secure on stand. Install rear booster wheels. PJSM, cover rig move operations. PRE Start rig move from F-Pad. Make GC1 at 0700-hrs; Putuligayuk River at 0930-hrs; West Guard Shack at 1245-hours. At 1300-hours, called AOGCC with 24-hour notification of impending initial ROPE test. 1330-hours, John Crisp acknowledged, but said he would check back with us tomorrow morning. Rig crossed the Sag River at 1600-hours. On DS 17 at 1700-hours. PRE PJSM. Position rig and remove rear booster wheels. PRE Remove BOPE from moving stand and place on BOP rack in cellar. PRE Lay herculite over DS 17-02 rig location and place rig mats in position. Inspect draw works before attempting to raise derrick. PRE PJSM covering raising derrick procedures. Inspect all components to raise derrick and go through check list. Raise derrick. Secure derrick, install derrick torque tube pins. R/U floor tuggers. PRE Inspect around well. Check for pressure on wellhead and tree (no pressure). Move and spot rig over DS 17-02. Shim and level rig. PRE Spot slop tank in position. Load pits with seawater. R/U circulating manifold in cellar. Bridle down derrick. R/U mud manifold on rig floor. Hook up and open OA to slop tank (0 psi on OA). Accept riq at 22:30, Feb 14, 2008. PRE Hang bridle lines in derrick. R/U compensator on top drive. R/U mud lines on floor. DECOMP R/U DSM lubricator and equipment. Test lubricatorto 500 psi,_ good test. DECOMP RIH and attempt to pull BPV without success. Rebuild retrieving tool. Re-run and attempt to pull BPV without success. Apply steam to wellhead, suspect ice build up on BPV. Rebuild retrieving tool. Re-run and pull BPV from tubing s ool. UD BPV. DECOMP R/D DSM lubricator and equipment. Clear rig floor. DECOMP Finish R/U pump #2 pump module. Fill lines and test circulating system to 3500 psi, good test. R/U to reverse circulate. DECOMP Displace well to seawater by reverse circulating at 6 bpm with 350 psi. Pumped 38 bbls to get returns. Pumped 75 bbls to clear diesel from tubing. DECOMP R/U and pump down tubing surface to surface at 6 bpm with 350 psi. DECOMP FMC made three attempts to install the BPV. John Crisp, AOGCC, called and waive State's witness of BOPE tests. DECOMP Pressure test BPV from below at 1.500-nsi for 3n charted .min tes. Good test. DECOMP PJSM. N/D tree and adaptor Flange. Transfer tree outside the • BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: D F T H T k d h i T D f ate rom - ours as e NP escript on o I Co P ase Operations o ~ 2/1512008 _ 10:00 - 12:30 2.50 WHSUR _ P DECOMP - - - - - cellar. 12:30 - 16:00 3.50 BOPSU P DECOMP Install test dart in BPV. PJSM N/U BOPE. 16:00 - 18:30 2.50 WHSUR N SFAL DECOMP The test dart won't hold from the top, but the BPV holds from underneath. FMC rounding up parts to repair the test dart. P/U landing joint with XO, retrieve dart for repairs to ball and seat in dart. Repairs were made to test dart and the dart was replaced into the BPV. 18:30 - 22:00 3.50 BOPSU N SFAL DECOMP Attempt to get a high and low pressure test gave the same results as before, good high pressure test and unsuccessful low pressure test. The lock down screws were ran in to make sure the tubing hanger was secured properly in the wellhead. Install a high pressure bleeder in the test port on tubing spool between the tubing hanger's primary and secondary packoffs. Attempt to pressure upon the hanger's primary packoff from above was made and a steady leak was observed from the bleeder. The stream of seawater increased proportionally with the more pressure applied from above. The high pressure bleeder was removed from test port and a high pressure test indicated the secondary packoff was holding with high pressure, but still would not hold at low pressure. 22:00 - 22:30 0.50 BOPSU N SFAL DECOMP Consult town with situation and possible options. 22:30 - 23:00 0.50 BOPSU N SFAL DECOMP Apply pressure test from the IA with the 4" test joint in the pipe rams. This tested the hanger secondary packoff from below, the Baker IBP, and the ISA BPV. The test was staged up from 500 to 1000 and to 1500 psi. All tests were held for 5-10 charted minutes and proved good on the chart. The bleeder on the test joint was opened and showed some fluid getting above the hanger. This test was again preformed with the high pressure bleeder in the test port. Small amounts of seawater were observed getting by the secondary packoff and the charted results were the same. 23:00 - 00:00 1.00 BOPSU N SFAL DECOMP Consulted town rig team of situations and options. Squeezing in emergency packing was discussed, but disregarded due to the type of wellhead and hanger. RIH w/ a WRP was disregarded due to the hanger primary and secondary packoff leaking. Hanging the tubing string off on a storm packer seemed to be the most justifiable option. John Crisp with AOGCC was contacted. After explaining the situation and possibilities, John Crisp gave the OK to proceed with the plan forward of ullin han er and han tubin from storm acker and test BOPE. 2/16/2008 00:00 - 02:00 2.00 BOPSU N SFAL DECOMP Contact HES for running storm packer, DSM to pull BPV, and FMC to pull hanger from tubing spool. R/U and test pipe rams. Test to 3500 psi, good test. Test annular preventer, HCR choke, and manual choke with pipe rams shut to 250 psi low pressure and 3500 psi high pressure. Hold tests for 5 charted minutes, good tests. 02:00 - 03:00 1.00 BOPSU N SFAL DECOMP R/D testing equipment and blow down lines. Pull and UD test joint. 03:00 - 03:30 0.50 BOPSU N SFAL DECOMP M/U BPV blanking plug pulling tool to landing joint. RIH and engage blanking plug. Release from BPV and POOH. 03:30 - 05:00 1.50 BOPSU N SFAL DECOMP P/U DSM tools and lubricator to rig floor. R/U DSM lubricator and extension. RIH and secure with annular preventor. Test Printed: 3/12/2008 11:43:35 AM • BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Welf Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase j Description of Operations 2/16/2008 03:30 - 05:00 1.50 BOPSU N SFAL DECOMP lubricator. 05:00 - 06:30 1.50 BOPSU N SFAL DECOMP Pull BPV. No pressure under BPV. POOH with BPV and UD. P/U landing joint, M/U to XO, RIH and engage in hanger. 06:30 - 10:30 4.00 BOPSU N SFAL DECOMP BOLDS. Find one gland nut with no threads. Apparently damaged the last time the LDS and gland nuts were function tested. Wait on repair parts and thread chaser from FMC. Run thread chaser into spool. Install new gland nut and LDS. 10:30 - 11:00 0.50 PULL N SFAL DECOMP M(U Landing joint to Top Drive. P(U on landing joint and hanger pulls free at 240K-Ibs, drops back to 185K-Ibs. Continue pulling slowly and and tubing pulls free at 220K-Ibs, drops back to 215K-Ibs. 11:00 - 11:30 0.50 PULL N SFAL DECOMP B/O and UD Hanger, XO and Landing Joint. Bring up spooler and connect control lines to spooler. 11:30 - 12:00 0.50 PULL P DECOMP POH and UD three joints of 5-i/2" tubing. 12:00 - 13:00 1.00 DHB P DECOMP P/U Halliburton RTTS and RIH and set 1-joint of DP below Rig Floor. Floorhand opened HCR valve before the Choke manifold was fully bled off. About 2-gallons of seawater sprayed up the side of the Drill Pipe and escaped onto the Rig Floor through the split in the rubber hole cover. No one was in the path of the spray which covered the lower part of the A-leg on the Off Driller side. A safety meeting was held immediately to discuss the event. All the fluid was contained in the immediate area of the rotary table. ADW Wells Workover Supt was contacted as well as the Doyon Anchorage based drilling manager. The A-leg was promptly cleaned up. 13:00 - 14:30 1.50 BOPSU P DECOMP R/U for BOPE test. John Crisp, AOGCC, had earlier declined to witness the BOPE test. 14:30 - 18:00 3.50 BOPSU P DECOMP Test BOPE to 250-psi low and 3.500- si hioh using 4" and 5-1/2" test joints. All tests were good. 18:00 - 18:30 0.50 DHB P DECOMP R/U HES RTTS retrieving tool and RIH. Engage and relax RTTS. POOH and UD RTTS. 18:30 - 20:00 1.50 PULL P DECOMP R/U and CBU at 10 bpm with 1060 psi. Bottoms up was clean without any problems. Small amounts of residual crude oil still in returns. 20:00 - 00:00 4.00 PULL P DECOMP POOH and UD 5-1/2", 17#, L-80 tubing from 10,040' to 7016'. Recovered 1 SSSV and 27 stainless steel bands with control line. 2/17/2008 00:00 - 02:30 2.50 PULL P DECOMP Continue to POOH and UD 5-1/2", 17#, L-80 tubing from 7016' to 4280'. Condition of pipe is good with some internal pitting and corrosion. Threads are in OK shape. 02:30 - 03:00 0.50 PULL P DECOMP Service rig and top drive. Slight damage noticed to wear plate on elevators. Change out tubing elevators. 03:00 - 07:00 4.00 PULL P DECOMP Continue to POOH and UD 5-1/2", 17#, L-80 tubing from 4280'. Condition of pipe is fair with some interal pitting and corrosion. Threads are in OK shape. Total recovery from well- 231 full joints of 5-1/2" tubing, 1 cut joint of tubing at 19.12', 12 GLM with handling pups, 1 SSSV and control line, and 27 stainless steel bands. 07:00 - 07:30 0.50 PULL P DECOMP Clear and clean rig floor. 07:30 - 08:00 0.50 EVAL P DECOMP P/U landing joint. M/U to wear ring and set in tubing spool. 08:00 - 09:30 1.50 EVAL P DECOMP PJSM with SWS E-liners. Discuss R/U operations and procedures. Discuss safety expectations while working on Printed: 3/12/2008 11:43:35 AM r • BP EXPLORATION Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date 'From - To Hours. Task ~ Code' NPT 2/17/2008 08:00 - 09:30 1.50 EVAL P 09:30 - 11:30 2.00 EVAL P 11:30 - 12:00 0.50 EVAL P 12:00 - 14:00 2.00 CLEAN P 14:00 - 23:00 I 9.00 I CLEAN I P 23:00 - 00:00 I 1.001 CLEAN i P 2/18/2008 100:00 - 01:30 ~ 1.50 CLEAN ~ P 01:30 - 02:30 I 1.001 CLEAN I P 02:30 - 07:30 I 5.001 CLEAN I P 07:30 - 13:30 I 6.001 DHB I P 13:30 - 15:00 I 1.50 I DHB I P Page 4 of 15 ~ Spud Date: 7/17/1980 Start: 2/1 /2008 End: 2/27/2008 Rig Release: 2/27/2008 Rig Number: Phase Description of Operations DECOMP Doyon 16. R/U SWS with line wiper. DECOMP RIH with USIT ultrasonic imaging logging tool to 3100'. Log to surface in cement evaluation mode looking for the top of cement in the 13-3/8" x 9-5/8" annulus. Evaluate results. Top of cement at 1960'. DECOMP R/D SWS and move equipment off rig floor. DECOMP Gather and M/U Baker fishing tools for BHA #1. Consisting of 8-1/2" used bit, 9-5/8" scraper, (2) 7" boot baskets, bit sub, bumper sub, jars, x/o sub, (9) 6-1/4" drill collars, and x/o sub to HT-38 drill pipe. Total length of BHA #1- 315.51' DECOMP P/U 310 joints of 4" HT-38 drill pipe from pipe shed and RIH with BHA #1 to 10,129'. DECOMP Establish parameters of Up Wt- 205,000 Ibs; Down Wt- 157,000Ibs; Rotating Wt- 175,000 Ibs at 50 rpm with 5500 ft-Ibs free torque; Pump Pressure- 510 psi at 5 bpm. Establish SPR. Tag top of 5-1/2" tubing at 10,144'. Reciprocate scraper multiple times from 10,142' to 10,085'. Pump 20 bbl high viscosity sweep at 10 bpm with 1720 psi. DECOMP Pump 20 bbl high viscosity sweep at 10 bpm with 1720 psi. Worked boot baskets through sweep. Sweep did not bring any extra cutting or solids to surface. No losses. Montitor well. DECOMP PJSM. Slip and cut 85' of drill line. Inspect dynomatic linkage, service top drive. DECOMP POOH with scraper. Stand back 4" HT-38 drill pipe in derrick. Work scraper from 1960' to 2050'. Continue POH and S/B DP. B/O and L/D Scraper and Junk Baskets. Junk baskets contained less than one cup of scrap metal. DECOMP P/U Halliburton RBP and RIH to 10,121'. M/U to Top Drive and continue.F31.H_to met BP at 10.130', center of element. DECOMP Pressure test 9-5/8" casing. Find several Casing Head LDS slightly weeping fluid. Bleed off pressure and tighten gland nuts. Pressure test casing to 3 50 -; ~~ any rarnrri nn chart fnr 15:00 - 18:30 18:30 - 19:00 3.50 0.50 DHB DHB P P DECOMP DECOMP Release RBP and POH to set RBP at 2000'. Stand back 4" HT-38 drill pipe in derrick. Establish parameters of Up Wt- 69,000 lbs; Down Wt- 71,000 lbs. Set HES RBP at 2000' center of elements and 1993' too of tool. Unsting from RBP and POOH 1 stand of drill pipe. R/U sand hopper and dump 32-bags (1600-Ibs) of 20-40 River sand for 36' of coverage to 1957'. 19:00 - 19:30 0.50 DHB P DECOMP R/U sand hopper and dump 32-bags (1600-Ibs) of 20-40 River sand. 19:30 - 20:30 1.00 DHB P DECOMP Clear sand from drill string by pumping 1 drill string volume at 1 bpm with 50 psi. Allow sand to settle for 30 minutes. RIH and tag top of sand at 1975'. 20:30 - 21:30 1.00 ZONISO P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 21:30 - 22:30 1.00 CASE P DECOMP P/U BHA #2 consisting of 8-1/4" OD multi string cutter, x/o sub, 8-1/2" stabilizer, x/o sub to 4" HT-38 drill pipe. 22:30 - 23:30 1.00 CASE P DECOMP RIH with BHA #2 on 4" HT-38 drill pipe from derrick. 23:30 - 00:00 0.50 FISH P DECOMP Establish CSG cutting parameters of Up Wt- 65,000 Ibs; Down Wt- 70,000 Ibs; Rotating Wt- 70,000 Ibs at 65 rpm with 2500 ft-Ibs free torque; Pump Rate at 5.5 bpm with 530 psi. R/U rig floor cutting casing and circulating out arctic pac. R/U to arctic Printed: 3/12/2008 11:43:35 AM • • BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: i ~ Date From - To ~ Hours Task ..Code NPT Phase ~ Description of Operations 1 2/18/2008 23:30 - 00:00 0.50 FISH P DECOMP pac tank. Locate casing collars at 1923' and 1880'. P/U and s of casin cutter at 1900'. 2/19/2008 00:00 - 01:30 1.50 CASE P DECOMP Continue to R/U to tiger tank from OA. R/U LRHOS and pressure test lines. Spot vac trucks. 01:30 - 02:00 0.50 CASE P DECOMP Hold PJSM with CH2MHILL support crew, LRHOS, and rig crew. Discuss upcoming arctic pac clean out operation and possible hazards. Assigned each person's assignments and responsibilities. 02:00 - 02:30 0.50 CASE P DECOMP Open OA to tiger tank and start cutting casing at 65 rpm and 3000 ft-Ibs torque pumping at 4 bpm with 330 psi. Increase pump pressure to 530 psi with 5 bpm. Increase pump pressure to 720 psi at 6 bpm. Torque increased to 4000 ft-Ibs before spiking to 7000 ft-Ibs. Pump pressure dropped to 600 psi and rate increased to 6.3 bpm, flow was also spotted coming from OA to tiger tank. Continue cutting for 1 more minute. Total time actual cutting- 9 minutes. 02:30 - 04:00 1.50 CASE P DECOMP Shut down cutting operations. Shut OA to take returns up IA. Bring LRHOS on line pumping at 2 bpm with 300 psi. Pump 21-Bbls and spot hot diesel at bit. Shut in annular and open OA to tiger tank. Continue pumping with LRHOS at 2-Bbls with 300 psi. Pump a total 111-Bbls of diesel. Turn over to rig pump and line to pump hot seawater treated with SafeSurf O at 5 bpm with 220 psi. Spot seawater at bit. Shut down pumps. 04:00 - 05:00 1.00 CASE P DECOMP Allow hot diesel to soak thoughout OA for 1 hour. 05:00 - 06:30 1.50 CASE P DECOMP Continue to circulate at 6 bpm with 650 psi. Finish pumping a total of 200-Bbls of treated seawater. Chase with clean seawater. The returns from the circulation contained 40% diesel, 50% crude oil, and 10% Arctic Pack, but the fluid had no higher viscosity than crude oil. 06:30 - 07:00 0.50 CASE P DECOMP POH and S/B DP in Derrick. 07:00 - 08:30 1.50 CASE P DECOMP B/O and L/D Multi-string Cutter and stabilizer. 08:30 - 09:00 0.50 CASE P DECOMP Pull wear ring. 09:00 - 10:00 1.00 CASE P DECOMP M/U and engage spear and BOLDS on casing head. 10:00 - 10:30 0.50 CASE P DECOMP Pull Hanger to floor with 120K-Ibs. R/U 9-5/8" casing handling e ui ment. 10:30 - 11:00 0.50 CASE P DECOMP Release and L/D spear. B/O Pup and Hanger. 11:00 - 15:30 4.50 CASE P DECOMP POOH and L/D 9-5/8" BTC Cs .Casing in good condition. Recovered 44 full joints plus 20.76' cut joint. Recovered 10 Bow Spring Centrilizers. 15:30 - 17:00 1.50 CASE P DECOMP Clean and Clear Rig Floor. Rig Down Csg Handling Equipment. P/U and B/O Spear, L/D Same. 17:00 - 18:00 1.00 CASE P DECOMP M/U 9-5/8" Dress Off BHA. 12"x 9-5/8" Dress Off Shoe, 11-3/4" Extension, 11-3/4" Boot Basket, 13-5/8" CSG Scraper, Bumper Sub, Jars, (9) 6-1/4" DC's. Total Length = 321.16' 18:00 - 19:30 1.50 CASE P DECOMP RIH with Dress Off BHA on 4" HT-38 drill pipe from derrick to 1839'. 19:30 - 20:00 0.50 CASE P DECOMP Establish Parameters of Up Wt- 87,000 Ibs; Down Wt- 87,000 Ibs; Rotating Wt- 85,000 Ibs at 60 rpm with 3000 ft-Ibs free torque; Pump Pressure- 120 psi at 5 bpm. Continue RIH and tag top of CSG Stub at 1900'. Dress off top of CSG at 80 rpm and 4500 ft-Ibs torque. Increased pump rate to 10 bpm with 450 psi. Dress over 5' of CSG Stub to 1905'. Top of CSG stub at 1900'. Printed: 3/12/2008 11:43:35 AM • • BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To !Hours Task Code NPT Phase ~ Description of Operations 2/19(2008 20:00 - 21:00 1.00 CASE P DECOMP Pump 20-Bbl high visc sweep and follow by displacing to new seawater at 8 bpm and 320 psi. Monitor well. 21:00 - 22:00 1.00 CASE P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 22:00 - 23:00 1.00 CASE P DECOMP POOH with BHA #4. Stand back 3 stands of 6-1/4" drill collars. L/D Dress Off Assembly. 23:00 - 00:00 1.00 CASE P DECOMP Gather and R/U 9-5/8" CSG equipment. Discuss with town engineer not changing out the pipe rams to 9-5/8" due to the tested lower barrier at 10,316'. Current configuration is acceptable. 2/20/2008 00:00 - 01:30 1.50 CASE P DECOMP Continue to gather and R/U 9-5/8" CSG equipment. Hold PJSM with Rig Crew and CSG Crew. Discuss procedures for running 9-5/8" Hydril 563 CSG and discuss risks assocated with heavy pipe in pipe shed and on rig floor. Discuss risks associated with heavy duty tongs. 01:30 - 04:30 3.00 CASE P DECOMP P/U ES Cementer and Baker Packer Type Casing Patch Assembly. Inspect by Baker and HES Techs. Each connection from the top of the ES Cementer to the screw in sub was Baker Locked. RIH with 9-5/8", 47#, L-80, Hydril 563 Casing with 1 free floating straight vane centralizer per joint. Used Jet Lube Seal Guard thread compound and torque turned each connection to 15,800 ft-Ibs. Stabing guide used on each joint. 04:30 - 06:00 1.50 CASE P DECOMP M/U CMT cross over head (Hyd 563 pin x BTC box) to last joint of CSG (#50) while in V door. P/U joint #50 and M(U in string. Establish parameters of Up Wt- 125,000 Ibs; Down Wt- 125,000Ibs. Tag CSG stump at 1900'. 06:00 - 06:30 0.50 CASE P DECOMP S/O Down to Casing Stump and Tag at 1900'. Slowly rotate to the right and work down over Casing Stump. Stack Up to 50,000 Ibs on Casing. Swallow Casing Stub fully to 1903'. P/U to 300,000 Ibs (175,000 Ibs over) to confirm atch is en a ed. S/O to 230,000 Ibs _100,000 Ibs over) and hold for cement 'ob. 06:30 - 07:30 1.00 CASE P DECOMP R/U Pressure Test Lines and Chart. Pressure up to 2000 psi on Casing and shut-in. Chart Pressure for :~n mine at ~nnn si. Good Test. Continue to pressure up on casing to shear ES Cementer. Required 2950 psi to open ES Cementer. Once Cementer Open, circulate 50 bbls at 4.7 bpm and 200 psi. 07:30 - 08:00 0.50 CASE P DECOMP PJSM with Rig Crew, Vac Truck Drivers, Dowell Cmtrs, and Mud Engineer on Safety and Procedures for Cmt Job. 08:00 - 09:00 1.00 CASE P TIEB1 Dowell batch up mixers. Pressure Test Lines to 4850 psi with Dowell. Come on line with cement at 5 bpm and 800 psi. Pump 130 bbls of 15.8 ppg Class G Cement with Gas Block Additive. Final Pump pressure = 5 bpm and 700 psi. 09:00 - 10:00 1.00 CASE P TIE61 Down on Cement Pumps and Open Up Cement Head to Closing Plug. Kick Plug Out w/ 5 bbls from Dowell. Bring On Rig Pumps and Displace Cement at 5-6 bpm with 250 psi. Caught Up to cement at 60 bbls of Displacement. Open OA Vavle and Close Bag. Pump returns through OA valve Outside at 5 bbls per min and 800 psi. Cement Returns seen at slop tank at 116 bbls of displacement. At 127 bbls of displacement slowed pumps to 2.0 bpm and 700 psi. Bump Plug at 139 bbls at 2.0 bpm and 850 psi. Continued to Printed: 3/12/2008 11:43:35 AM ~ i BP EXPLORAT{ON Operations Summary Report Page 7 of 15 ~ Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/20/2008 09:00 - 10:00 1.00 CASE I P 10:00 - 10:30 I 0.501 CASE P 10:30 - 12:00 1.50 BOPSUF~ P 12:00 - 14:00 2.00 WHSUR P 14:00 - 15:00 I 1.001 WHSUR I P 15:00 - 16:00 I 1.001 WHSUR I P 16:00 - 17:00 1.00 WHSUR P 17:00 - 18:00 1.00 WHSUR P 18:00 - 19:30 1.50 WHSUR P 19:30 - 20:30 1.00 WHSUR P 20:30 - 21:00 0.501 CASE I P 21:00 - 22:00 I 1.001 CASE P 22:00 - 00:00 I 2.001 CASE I P 2/21/2008 100:00 - 00:30 0.501 CASE P 00:30 - 01:00 0.50 CASE P 01:00 - 02:00 1.00 CASE P 02:00 - 03:00 1.00 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 04:30 I 1.001 CASE I P 04:30 - 05:00 I 0.50 I CLEAN I P TIE61 pressure up to 1760 psi and close ES Cementer. Pressure up further to 2000 psi and Hold for 5 minutes as per HES Rep. Bleed Down Pressure and Check for Flow back up casing. plo-Flow ES Cementer Holding. CIP at 09:33hrs TIE61 Clean up after Cement Job. Flush BOP Stack and lines with Citric Acid Solution. Sent to slop tank to lower pH in Cement rinse trucks. TIEB1 N/D and split Casing Spool and Tubing Spool. WHDTRE Set emergency slips with 100,000 Ibs overpull on Casing Strin°• Slack off 100,000 Ibs over pull to fully set emergency slips. R/U Wachs cutter and cut 9-5/8" Casing Stub as per FMC Tech. Clean up area. WHDTRE Separate Tubing Spool from BOPE Stack. Stand BOPE Stack on BOP stand. Set old FMC 13-5/8" x 13-5/8" Tubing Spool to the side. WHDTRE Prepare wellhead for installation. Install new 9-5/8" standardized primary pack off in wellhead. WHDTRE Install and N/U new FMC 13-5/8" x 13-5/8" 5M Tubing Spool. WHDTRE R/U FMC and test Tubing Spool and Pack off to 3800 psi for 30 minutes. WHDTRE Set BOPE on Wellhead. N/U BOPE. WHDTRE P/U and install Test Plu .Perform bod test on Wellhead x BOPE flange to 250 psi low pressure and 3500 high pressure. ach~est held for 5 charted minutes, Good test. Pull Test Plug and install Wear Ring. TIEBi P/U BHA #5 consisting of 8-1/2" Bit, (2) 7" Boot Baskets, Bit Sub, Bumper Sub, Jars, X10 Sub, 3 stands of 6-1/4" Drill Collars from Derrick, X/O Sub to 4" HT-38 Drill Pipe. Total length of BHA #5- 312.14' TIEB1 RIH with drill out assembly on 4" HT-38 Drill Pipe from Derrick to 1829'. Received confirmation of UCA of 500 psi at 21:45 hrs. TIEB1 Establish drill out parameters of Up Wt- 85,000 Ibs; Down Wt- 85,000Ibs; Rotating Wt- 85,000 Ibs at 80 rpm with 2000 ft-Ibs free torque; Pump Pressure- 490 psi at 10 bpm. Continue washing in hole through Gement Stringers from 1870' to the top of the ES Cementer at 1891'. Start drilling on ES Cementer at 22:30 hrs with 5000 to 10,000 Ibs WOB at 80 rpm with 3500 ft-Ibs torque. Drill through ES Cementer and Cement (1896') at 23:15 hrs. TIE61 Drill through ES Cementer and Cement. Continue reaming to the top of Sand at 1975' with 60 rpm and 4000 ft-Ibs torque at 10 bpm with 500 psi. Wash through sand to 1980'. TIEB1 Pump 20-Bbl high visc sweep at 10 bpm with 380 psi. Noticable increase in sand at surface in sweep. TIE61 Slip and Cut 85' of Drill Line. Monitor well. TIE61 POOH standing back 4" HT-38 Drill Pipe in derrick. TIE61 POOH with BHA #5 standing back 3 stands of Drill Collars in Derrick. Boot Baskets contained a total of 1 gallon of Cement, Metal, and Sand. TIE61 R/U and to test Casing. Close Blind Rams and test Casing to 3500 si. Hold test for 30 charted minutes. Good Test. CLEAN M/U BHA #6 consisting of RCJB, 9-5/8" CSG Scraper, Bit Sub Printed: 3/12/2008 11:43:35 AM • • BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ~ Code NPT Phase I Description of Operations 2/21/2008 04:30 - 05:00 0.50 CLEAN P CLEAN Bumper Sub, Jars, X/O Sub, 3 stands of 6-1/4" Drill Collars from Derrick, and XJO Sub to HT-38 Drill Pipe. Total length of BHA #6- 312.03' 05:00 - 06:00 1.00 CLEAN P CLEAN RIH with BHA #6 on 4" HT-38 Drill Pipe from Derrick to top of sand. 06:00 - 06:30 0.50 CLEAN P CLEAN Displace to clean Seawater. 06:30 - 07:00 0.50 CLEAN P CLEAN Establish Parameters. Tag Sand at 1977' pumping 6 bpm at 180 psi. Rotate at 40 rpm's. Wash and Rotate Down to 1985'. 07:00 - 08:00 1.00 CLEAN P CLEAN B/O and Blow Down Top Drive. POOH with RCJB, Stand Back DP. CLean Out RCJB. Boot Basket Contained fine cement and sand. Reverse Basket Had 3 golf ball size chunks of Aluminum. 08:00 - 09:00 1.00 CLEAN P CLEAN Redress RCJB Basket. RIH with RCJB with DC's on 4" DP from Derrick. 09:00 - 09:30 0.50 CLEAN P CLEAN Establish Parameters. Circulate at 6 bpm and 180 psi, rotate at 40 rpm's. Tag Sand at 1985'. Rotate and Wash Down to 1989'. 09:30 - 10:30 1.00 CLEAN P CLEAN B/O and Blow Down Top Drive. POOH and Stand Back 4" DP. Clean Out Boot Baskets and RCJB. Boot Baskets Contained 2 cups worth of 1"diameter aluminum pieces plus chunks of cement. Reverse basket contained 3 golf ball size chunks of aluminum as before. 10:30 - 12:00 1.50 CLEAN P CLEAN B/O Reverse Basket and Boot Baskets, UD Same. CLean and Clear Rig Floor. 12:00 - 13:00 1.00 CLEAN P CLEAN M/U HES RBP Retrival Tool and RIH on 4" DP. 13:00 - 13:30 0.50 CLEAN P CLEAN Tag Up at 1990'. M/U Top Drive. Establish Circulation. Pump 20 bbl High Visc Sweep. Bring Pumps Up to 12 bpm and 1200 psi. Wash Down and Latch into RBP at 1993. Sweep brought back lots of small cement pieces, some rubber and sand. 13:30 - 14:00 0.50 CLEAN P CLEAN Make 1/2 Rotation on Pipe and P/U to 15,000 Ibs over string wt to Unseat RBP. Bring on pumps and CBU at 6 bpms at 300 psi. POOH to confirm free and then RIH Past Setting Depth to confirm RBP on the hook. 14:00 - 15:00 1.00 CLEAN P CLEAN POOH and Stand Back DP. L/D HES RBP and Tool. 15:00 - 15:30 0.50 CLEAN P CLEAN P/U 5-1/2" Type D Spear BHA #8 consisting of Spear, X/O Sub, Bit Sub, Bumper Sub, Jars, X/O Sub, 3 Stands of 6-1/4" Drill Collars from Derrick, X/O Sub, Intensifier Jars, Pump Out Sub, X/O to 4" HT-38 Drill Pipe. Total length of BHA #8- 327.64' 15:30 - 19:30 4.00 CLEAN P CLEAN RIH with Type D Spear Assembly on 4" HT-38 Drill Pipe from derrick to 10,109'. 19:30 - 21:00 1.50 CLEAN P CLEAN Establish SPR and fishing parameters of Up Wt- 205,000 Ibs; Down Wt- 160,000 Ibs; Rotating Wt-180,000 Ibs at 40 rpm with 5000 ft-Ibs free torque; Pump Rate- 4 bpm with 510 psi. Rotate right 5 round to break over torque at 5000 ft-Ibs; set torque limit at 12,000 ft-Ibs. Continue RIH and tag top of tubing stub at 10,145'. Continue RIH 5' into tubing stub and bottom out on spear stop ring to a total depth of 10,151'. P/U to 215,000 Ibs (10,000 Ibs overpull) to confirm engagement with tubing stub. Slack off to 190,000 Ibs (10,000 Ibs overpull with rotation). Start right hand rotation while maintaining 190,000 Ibs, 14 total Printed: 3/12/2008 11:43:35 AM C: • BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date j From - To Hours Task Code ~ NPT Phase Description of Operations 2/21/2008 19:30 - 21:00 1.50 CLEAN P CLEAN rounds to the right before stalling out with 12,000 ft-Ibs. Work torque down to spear by slacking off to 180,000 Ibs. Release torque and pulled to 215,000 Ibs. Slack down to 190,000 Ibs. Put 14 total rounds to the ri ht and noticed first si ns of releasin K-Anchor. Continue rotating to the right while maintaining 10,000 Ibs overpull, 190,000 Ibs total causing top drive to stall out with 12,000 ft-Ibs torque. Release torque and working spear down to 150,000 Ibs and up to 220,000 Ibs. Slack off to 170,000 Ibs, put right hand torque in work string while lifting to 190,000 Ibs, signs of K-Anchor releasing by continue to turn to the right with normal free torque of 5000 ft-Ibs. Pull 10' without any excess weight on weight indicator and no fluid losses. Attempt 3 times to reengage K-Anchor each time losing 1.5' of hole and gaining 90 psi increase in pump pressure at 2.5 bpm with 10,000 Ibs set on stub. P/U 10' without any noticeable overpull each time. POOH to 10,109'. Monitor well. Well stable with no losses. 21:00 - 23:30 2.50 CLEAN P CLEAN CBU at 9 bpm with 2360 psi. Gas and crude in returns at bottoms up. Continue to circulate and allow returns to clean up of gas. Stop and monitor well. Sufficient amount of crude breaking out at surface. Strap pits and continue circulating one more bottoms up. Monitor well. Well lost 2-Bbls during last CBU. 23:30 - 00:00 0.50 CLEAN P CLEAN Service rig and change out rig crew while monitoring well. '2/22/2008 00:00 - 03:00 3.00 CLEAN P CLEAN POOH with Spear Assembly. Stand back 4" HT-38 Drill Pipe in Derrick. 03:00 - 04:00 1.00 CLEAN P CLEAN POOH with BHA #8 standing back 3 stands of 6-1/4" Drill Collars. No Recovery. Type D Spear Dog Stop rolled through divider to separate Right Hand Set and Left Hand Set. ,Spear dams ed be and reuse. 04:00 - 05:00 1.00 CLEAN P CLEAN Assess damage and consult town engineer. Decision made to RIH with ITCO Spear. 05:00 - 06:00 1.00 CLEAN P CLEAN Send for new ITCO Spear. Clear and Clean Rig Floor. 06:00 - 06:30 0.50 CLEAN P CLEAN M/U BHA with ITCO Spear with Double Grapple, Bumper Sub, Jars, DC's, Intensifier, Pump Out Sub, Total Length = 327.6 ft 06:30 - 09:30 3.00 CLEAN P CLEAN RIH with ITCO Spear BHA on DP to Top of Fish. Contact state at 07:20 hrs with 24 hr notice on testing BOP's. 09:30 - 10:00 0.50 CLEAN P CLEAN Establish Parameters. P/U Wt = 210,000, S/O Wt = 155,000, Rot Wt= 184,000, Pump Rate = 2.7 bpm at 120 psi. Free Torque = 5000 ft-Ibs at 30 rpm's. S/O and Enaaae Grapple it top of fish at 10144' and continue to S/O another -8' to No Go. Pump pressure Climbed rapidly once No-Go'd. P/U 20,000 Ibs over string wt and confirm latched up, let Jars bleed off. Attempt to Rotate Out K-Anchor with 14 right hand roations. P/U and No Over Pull. S/O and Engage Fish again, pump pressure climbing. Can not P/U on Fish-Spear Backed Out of Fish an in release position now. Make 3 left hand rotations and engage fish again. P/U with 20,000 Ibs over string wt. 10:00 - 18:00 8.00 CLEAN P CLEAN Attem t to 'ar fish loose. Drop bar for Pump Out Sub. Begin Jarring at 40,000 Ibs over with straight pulls to 65,000 Ibs over. Work up to 140,000 Ibs jarring and 190,000 Ibs over straight Printed: 3/12/2008 11:43:35 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Event Name: WORKOVER Start: 2/1/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code~PT Phase -1- -- __. 2/22/2008 10:00 - 18:00 8.00 CLEAN P ~ ~ CLEAN 18:00 - 23:30 I 5.501 CLEAN I P 23:30 - 00:00 0.50 CLEAN P 2/23/2008 00:00 - 03:00 3.00 CLEAN P 03:00 - 04:00 I 1.00 CLEAN ~ P 04:00 - 05:00 I 1.001 CLEAN I P 05:00 - 05:30 0.50 CLEAN P 05:30 - 09:00 3.50 CLEAN P 09:00 - 10:00 I 1.001 CLEAN I P 10:00 - 10:30 I 0.501 CLEAN I P 10:30 - 12:00 I 1.501 CLEAN I P 12:00 - 17;00 5.00 CLEAN P 17:00 - 17:30 0.50 CLEAN P 17:30 - 19:00 I 1.501 CLEAN I P 19:00 - 21:30 I 2.501 CLEAN I P Page 10 of 15 Spud Date: 7/17/1980 End: 2/27/2008 Description of Operations pulls. Fish moving slowly. Making - 1 ft an hour jarring. Made a total of 12' puling fish. Continue to iar on tubing stub. Hit jars with 350,000 Ibs up wt (140,000 Ibs overpull). P/U to 400,000 Ibs straight pull and hold. Slack off to 140,000 Ibs to cock jars. Repeat several cycles without making any new footage. Pull a total of 12'. At 23:00 hrs, attempt to use bumper sub to nudge down on tubing stub. Lost most of the overpull on fish. Made 3 attempts to get new hold with grapple without success. First attempt, 20,000 Ibs overpull before grapple slipped free, second attempt, reset spear to the left, pick up 10,000 Ibs overpull before grapple pulled free, third attempt, no overpull before grapple appeared to slipped out. Consult town, decision to POOH and change out grapple. Total jarring time- 11 hrs. No losses or gas observed during the jarring operation. R/U to POOH, pump dry job, blow down top drive. POOH with spear assembly. Stand back 4" HT-38 drill pipe in derrick. CLEAN CLEAN CLEAN At 02:16, Contact AOGCC Chuck Scheve to~ive 2 hour notice of BOPE test. AOGCC waived witness to BOPE test by Chuck Scheve. CLEAN POOH with BHA #8. Stand back 3 stands of 6-1/4" drill collars in derrick. L/D jar assembly. Recovered 20.20' of 5-1/2" tubing cut off joint and 15.10' pup joint. Total length of recovery- 35.30'. Pup joint broke free on the pin end leaving the threads downhole in the top of the Camco Sliding Sieeve. Condition of tbg recovered was good with only very slight external corrosion on body of pup joint. CLEAN Clear and clean rig floor. R/U to test ROPE. Pull wear ring and set test plug. CLEAN R/U to test BOPE. Pull wear ring and set test plug. CLEAN Test BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 charted minutes. AOGCC Chuck Scheve waived witness of test. Test witnessed by Doyon Toolpusher and BPX WSL. CLEAN Blow Down and Rig Down BOP Test Equipment. Pull Test Plug and Set Wear Ring. CLEAN Gather Components for BHA. Load Wash Pipe in Shed and Strap. CLEAN P/U and M/U BHA #10. 8-1/2"x 7-1/4" Mill Shoe, 6 jts of 8-1/8" Wash Pipe, Triple Connect Sub, Double Pin XO, (2) 7" Boot Baskets, Float Sub, Bumper Sub, Jars, XO, (9) 6-1/4" DC's, XO. Total Length = 498.0 ft CLEAN RIH with Wash Pipe BHA with in two stands of Top of Fish. Break Circ every 30 Stands. CLEAN PJSM with rig crew on slipping and cutting operations. Review Procedures and Hazards. CLEAN Slip and Cut 80' of 1-1/4" Drilling Line. Service rig, inspect savor sub. CLEAN Continue to RIH to 10,091'. Establish Parameters of Up Wt- 200,000Ibs; Down Wt- 154,000 Ibs; Rotating Wt- 176,000 Ibs at 40 rpm with 7000 ft-Ibs free torque. Pump Rate 10 bpm with Printed: 3/12/2008 11:43:35 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Event Name: WORKOVER Start: 2/1/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date I From - To Hours Task Code I NPT ~ Phase Page 11 of 15 Spud Date: 7/17!1980 End: 2/27/2008 Description of Operations 2/23!2008 19:00 - 21:30 2.50 CLEAN P CLEAN 1960 psi. Decrease pump rate to 8 bpm with 1230 psi. Continue RIH to fish at 10 167'. Pump high visc sweep. Wash and ream to 10,186 at 40 rpm with 7000 ft-Ibs and 8 bpm with 1230 psi, no WOB. Make connection and continue washing and reaming with 500 to 2000 Ibs WOB. Start taking weight at 10,240'. Keep 4000 Ibs WOB and torque increased to 9000 ft-Ibs. Continue washing and reaming to 10,279'. Pump 2nd high visc sweep and circulate up hole. Make connections and continue washing and reaming. ~a too of PBR barrel at 10,294'. Pump pressure increased to 1260 psi, torque up to 10,000 to 12,000 ft-Ibs at 40 rpm. Continue to wash and ream over PBR to to of PKR at 10 318'. 21:30 - 23:30 2.00 CLEAN P CLEAN Pump 2 high visc sweeps back to back at 11.5 bpm with 2500 psi. Sweeps brought an increase in Sand, Frac Sand, and fine metal shavings. R/U to POOH. Pump dry job. 23:30 - 00:00 0.50 CLEAN P CLEAN POOH with Washpipe Assembly. Stand back 4" HT-38 Drill Pipe in Derrick. 2/24/2008 00:00 - 02:00 2.00 CLEAN P CLEAN Continue POOH with Washpipe Assembly. Stand back 4" HT-38 Drill Pipe in Derrick. 02:00 - 03:00 1.00 CLEAN P CLEAN POOH with BHA #10. Stand back 3 stands of 6-1/4" Drill Collars. L/D 6 joint of Washpipe. Recovered 3 gallons of Frac Sand and Metal in Boot Baskets. 03:00 - 03:30 0.50 CLEAN P CLEAN Clear and clean rig floor. P/U Baker Overshot and Grapple. 03:30 - 04:30 1.00 CLEAN P CLEAN M/U BHA #11 (Overshot and Grapple Assembly) consisting of 8-3/8" Overshot Guide and Extension, Overshot with 6.5" spiral Grapple and Control, Bumper Sub, Jars, X/O Sub, 3 stands of 6-1/4" Drill Collars from Derrick, X/O Sub, 6-1/4" Intensifier Jars, Pump Out Sub, X/O Sub to HT-38 Drill Pipe. Total length of BHA #11- 322.14' 04:30 - 07:30 3.00 CLEAN P CLEAN RIH with Overshot and Granule Assembly on 4" HT-38 Drill Pipe from Derrick. 07:30 - 08:30 1.00 CLEAN P CLEAN PJSM, cover what is going to be done when fish is pulled free and handling fluids. Take initial parameters. Up Wt = 200,000 Ibs Dw Wt = 160,000 Ibs Rot Wt =182,000 Ibs with 6,000 ft Ibs free torque at 40 rpm's. S/O and See to Continue to Slack Off another 15 ft and Stack 30,000 Ibs down on fish. Pump Pressure increased from 280 psi to 550 psi at 2.8 bpm. P/U and see over pull. Pull Up to 50,000 Ibs over and let jars go off. Straight Pull to 75,000 Ibs over. Fish Not Moving. S/O again to 30,000 Ibs down to re-set jars. P/U to 75,000 Ibs over and let jars go off, then P/U to 110,000 Ibs over. Fish Moving Up Hole. Draq Fish -10 ft and Fish Popped Free. Lost all 08:30 - 11:00 2.50 CLEAN P CLEAN Attempt to Establish Circulation. Pump Down Drill String and Down Annulus at 12-13 bpm with 40 psi on pump. Feed Well -400 bbls in 30 mins. Send Vac Truck for more SW and call out another SW Truck. Back down on rate down to 3 bpm for another 100 bbls and then to 1 bpm for another 100 bls while waiting for more fluid to arrive on location. 11:00 - 12:00 1.00 CLEAN P CLEAN Sw Truck arrived on location. Take on fluid and continue to feed well at 1 bpm. Shut-Down fluid for -10 mins and have Printed: 3/12/2008 11:43:35 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Event Name: WORKOVER Start: 2/1/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: i Date i From - To Hours ~ Task Code i NPT Phase 2/24/2008 11:00 - 12:00 1.00 CLEAN P CLEAN 12:00 - 16:00 4.00 CLEAN P CLEAN 16:00 - 16:30 0.50 CLEAN P CLEAN 16:30 - 20:00 3.50 CLEAN P CLEAN 20:00 - 20:30 0.50 CLEAN P CLEAN 20:30 - 21:00 0.50 CLEAN P CLEAN 21:00 - 21:30 0.50 CLEAN P CLEAN 21:30 - 00:00 2.50 CLEAN P CLEAN 2/25/2008 00:00 - 01:00 1.00 CLEAN P CLEAN 01:00 - 01:30 0.50 CLEAN P CLEAN 01:30 - 02:30 1.00 CLEAN P CLEAN 02:30 - 11:00 8.50 CLEAN P CLEAN 11:00 - 12:30 1.50 CLEAN P CLEAN 12:30 - 13:00 0.50 CLEAN P CLEAN 13:00 - 14:30 1.50 CLEAN P CLEAN 14:30 - 00:00 9.50 CLEAN P CLEAN Page 12 of 15 Spud Date: 7/17/1980 End: 2/27/2008 Description of Operations DHD take fluid level shot at 11:30 hrs. Fluid Level at -1230 ft. Continue to feed fluid at 1 bpm for another half hour. Shut- down and take another fluid level shot. Fluid level again at -1230 ft. Set hole fill to -1.5 bpm and POOH with Fish. Stand Back Drill Collars. Hold PJSM on handling Fish, go over procedures for punching and possible trapped pressure. POOH and Disengage Overshot from Sliding Sleeve. L/D Jars, Bumper, and Overshot. Punch above and below every connection. L/D Sliding Sleeve and top 15 ft Pup Joint. Punch Top Full Joint of 5-1/2" Tbg above and below tbg patch and below connection with lower joint. Clearly saw two pickle size holes that tbg patch covered which were 16.6' from the box end of the top full joint. When Punch 5-1/2" tbg leaked out brown slurry mixture that looked to be crude, sand, scale, and cement. Very slow to leak out of pipe, not under pressure. Continue to L/D Lower Full Joint, Pup Jt and Seals. Same brown slurry seen. Seals measured out at 6-1/8" OD and 17.45 ft long. Bottom of the IBP element was 5.8' ft from bottom of Seals. Total length of recovery- 134.64'. Clear and clean rig floor. P/U overshot BHA. Break and L/D BHA #11. P/U BHA #12 (Cleanout/Drift Assembly) consisting of 6' Bit, Bit Sub, X/O Sub, 1 joint of 4' HT-38 Drill Pipe, 2 X/O Subs, 9-5/8' Scraper, (2) 7" Boot Baskets, Bit Sub, Bumper Sub, Jars, X/O Sub, 3 stands of 6-1/4" Drill Collars, X/O Sub back to 4" HT-38 Drill Pipe. Total length of BHA #12- 354.20' RIH with Cleanout Assembly on 4" HT-38 Drill Pipe from derrick. Shot fluid level on Annulus at 1200' at 23:00 hr¢ while using continuous hole fill at 60 bgh. Increase continuous hole ill to 90 bph. Will shoot fluid level again at 05:00 hrs. Continue RIH with Cleanout Assembly on 4" HT-38 Drill Pipe from Derrick to 10,231'. Establish parameters of Up Wt- 230,000 Ibs; Down Wt- 150,000Ibs; Rotating Wt- 190,000 Ibs at 50 rpm with 10,000 ft-Ibs free torque; Pump pressure- 60 psi at 6 bpm. Ease down and tag top of PBR at 10,296'. P/U 5' and rotate at 15 rpm with 7000 ft-Ibs free torque. Ease into PBR and continue down. Tag bottom of PBR at 10,314'. Repeat procedure and P/U out of PBR. Run Scraper 4 times over from 10,231' to 10,274' Attempt to reverse circulate bottoms up at 8 bpm 160 psi. Pumped 200-Bbls and could not get returns. Shut down pumps. Continue to add fluid to annulus at 90 bph. PJSM. POOH and L/D 4" HT-38 Drill Pipe. Shot fluid level in annulus at 05:00 hrs. Level again at 1200'. Continue to use continuous hole fill at 90 bph. POOH with BHA 12. UD (9) 6-1/4" Drill Collars. L/D Jars, Bumper Sub, X/O Subs, Scraper, and Bit. Clear and clean rig floor. Pull Wear Ring. P/U Doyon Torque Turn equipment with compensator. R/U Floor Valve for tubing. Check tubing and jewelry before RIH. P/U and RIH with 4-1/2", 12.6#, 13Cr80 Vam Top tubing with Printed: 3/12/2008 11:43:35 AM -~ • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 17-02 17-02 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/1 /2008 Rig Release: 2/27/2008 Rig Number: Page 13 of 15 Spud Date: 7/17/1980 End: 2/27/2008 Date From - To Hours Task Code I NPT I Phase 12/25/2008 14:30 - 00:00 9.50 CLEAN I P 2/26/2008 00:00 - 03:00 3.00 RU 03:00 - 04:00 1.00 RU 04:00 - 04:30 I 0.50 04:30 - 05:00 05:00 - 10:00 10:00- 11:30 11:30 - 13:00 13:00 - 15:30 Description of Operations CLEAN 4-1/2" WLEG and Baker S-3 PKR. All tubing and jewelry was drifted before RIH. All connections were started by hand with compensator and torqued to 4440 ft-Ibs with Doyon Torque Turn equipment. All threads were lightly doped with Jet Lube Seal Guard thread compound. Stabbing guide was used on all connections. Baker-Loc used on all joint below Baker S-3 PKR. RUNCMP Continue to P/U and RIH with 4-1/2", 12.6#, 13Cr80 Vam Top tubing to 10,293'. All connections were started by hand with compensator and torqued to 4440 ft-Ibs with Doyon Torque Turn equipment. All threads were lightly doped with Jet Lube Seal Guard thread compound. Stabbing guide was used on all connections. RUNCMP Establish parameters of Up Wt- 160,000 Ibs and Down Wt- 126,000Ibs. M/U joint # 238 in string. Ease in hole to top of PBR. Did not detect PBR. Continue easing into PBR. Bottom out WLEG on bottom of PBR at 10 320'. S/O 3000 Ibs on H to 10,293' and rotate tubing string 1/2 turn and work torque to WLEG. Sting back into PBR and tag bottom of PBR at 10,320'. P/U out of PBR. Sting back into PBR once more. Bottom out at 10,320' with 3000 Ibs on WLEG. P/U to neutral weight and an additional 2 ft. Figure space out. Break out joints #237 and #236. P/U 38.88' of space out pups. P/U joint #236. P/U landing joint and M/U to tubing hanger. M/U into completion. Blank unused ports and prep to RIH. RUNCMP RIH with tubing hanger and land completion at 10,314'. RILDS. 0.50 BUNCO RUNCMP R/U to reverse circulate hot seawater and hot corrosion inhibited seawater. 5.00 BUNCO RUNCMP PJSM with rig crew and CH2MHILL vac truck drivers. Discuss pumping operations and procedures. Reverse Circulate 200 bbls of 140 deg F Seawater and 560 bbls of 140 deg F Seawater with corrosion inhibitor at 3 bpm with 40 psi. No returns to surface. 1.50 BUNCO RUNCMP Drop Sall and Rod. Chase Rod down with 17 bbls of Seawater at 2.5 bpm and 40 psi. Pressure Up on Tubing and Set Packer with 3500 psi. Fill back IA with 35_bb_Is~Seawater. 1.50 BUNCO RUNCMP Bleed Tb Pressure to 1500 si and Pressure U on Annulus tn,_3y(l nsi AttPmnt to nrassura Tact Praccura Rlaaric rin~~%n uickl Pressure Up threee times in attempt to test, loosing -500 psi in 3 mins.. Bleed Down Annulus Pressure and then Bring Back Up to 3500 psi. Pressure Bleeds off at slower rate, Loosing -- 500 psi in 7 mins. Pressure Up again and attempt pressure test. Bleed Off Annulus third time and pressure up ~0 3500 psi. Saw crude in returns when bleeding off annulus. Still Loosin at ood rate. Blee s o 0 psi in -~0 mins. Pressure Test Showing Improvement over three different tries. Consult Town. 2.50 BUNCO RUNCMP Bleed Down Annulus and Tbg Pressure. Line Up on Tbg and Pressure U to 4500 si to insure packer is set fully. Hold Pressure for 15 mins. Lost -100 psi in 15 mins ut leveling off Printed: 3/12/2008 11:43:35 AM • BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 2(26!2008 13:00 - 15:30 2.50 BUNCO RUNCMP 15:30 - 19:30 4.00 BUNCO RUNCMP 19:30 - 22:00 2.50 BUNCO WAIT RUNCMP 22:00 - 00:00 2.00 BUNCO RUNCMP for Vast 5 mins. Bleed down tbg pressure to 1800 psi. Line Up on Annulus and Pressure Up to 3500 psi. Lost -150 psi in 10mins. Bump Pressure Up to 3500 psi, lost approximately the same amount again. Bleed Annulus all the way down to zero and bring back to 3500 psi. Let test run out, lost - 525 psi in first 25 mins and -800 psi in 50 mins. Getting close to leveling out after 50 mins. Bleed off Annulus and Tbg to zero psi. See crude in returns when bleeding off tubing,. Line up on both at same time an pressure up to 3500 psi. Annulus Lost - S00 psi in 1 hr, tubing pressure test lost minimal amount. Bump Annulus back up to 3500 psi and holding waiting of truck of Seawater. Tbg pressure holding steady at 3400 psi and Annulus Flat Lining at 2600 psi. Pressure up on Annulus to 3,500 psi, bled down 300 psi in 20 minutes. Wait on Seawater Truck to arrive on location. Called on status of truck at 20:00 hrs, told have no record of truck being ordered. Called back after 10 mins of converstation and said truck had "Pony Motor" go down at SIP and was now up and running. Estimated truck to be on location at 21:30 hrs. CH2M Hi11 trucks arrived on location at 22:00 hrs Bleed down Tubing to 1,200 psi and shear out valve in top GLM, Pumped down tubing and take returns through annulus, at 4 bpm with 320 psi, Crude returns seen at surface with a max of combustable gas level of 40% for the first 40 bbls of retums. The next 90 bbls of sea water was mixed with crude oil, the following 150 bbls cleaned up. Crude was seen in the last 20 bbls to surface. 2/27/2008 00:00.- 01:30 1.50 BUNCO RUNCMP CMIT on Tubing and Annulus bleed down from 3,500 to to 3,300 in 20 minutes,After 1.5 hrs it leveled off at 3,000 psi for 30 minutes. 01:30 - 03:00 1.50 BUNCO RUNCMP Circulated out Clean Sea Water to Shear Valve at 4 bpm with 400 psi, Crude oil was comingled with sea water. while waiting on FMC. 03:00 - 04:30 1.50 BUNCO RUNCMP /~ anriing jt sat TW with FM rPnrPSPntitive. P/U landing jt and pressure tested TWC to 1,500 psi from below for 30 mins and 3,500 psi from above for 10 mins. Good Test, R/D and blow down surface lines. 04:30 - 07:30 3.00 BUNCO RUNCMP Remove Blind Rams from Stack and Nipple down BOPE. 07:30 - 09:00 1.50 WHSUR P RUNCMP N/U FMC 13-5/8" x 4-1/16" 5M Adapter Flange. 09:00 - 10:00 1.00 WHSUR P RUNCMP 13/U Test Equipment and Pressure Test Adapter to 5000 psi for 30 mins. 10:00 - 11:00 1.00 WHSUR P RUNCMP N/U New CIW 4-1/2" Tree. 11:00 - 12:30 1.50 WHSUR P RUNCMP Pressure Test Tree to 5000 psi for 30 mins on chart with diesel. 12:30 - 13:30 1.00 WHSUR P RUNCMP P/U DSM Lubricator, M/U to Tree and Pressure Test to 1000 psi for 10 mins. Pull TWC, found 300 psi on tbg. 13:30 - 14:30 1.00 WHSUR P RUNCMP PJSM with Little Red. R/U Little Red and Pressure Test to 3000 psi. Pump 160 bbls of Freeze Protect at 4 bpm. and 800 psi. 14:30 - 16:00 1.50 WHSUR P RUNCMP Line up hoses and U-Tube Freeze Protect. After 1 hr, Pressure on Tbg 975 psi and IA 625 psi. After 1.5 hr, Pressure on Tbg 950 psi and IA 650 psi. Printed: 3!12!2068 11:43:35 AM • • BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: 17-02 Common Well Name: 17-02 Spud Date: 7/17/1980 Event Name: WORKOVER Start: 2/1/2008 End: 2/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/27/2008 Rig Name: DOYON 16 Rig Number: i ~ ' Date ~ From - To Hours Task Code NPT i ' Phase Description of Operations 2/27/2008 16:00 - 16:30 0.50 WHSUR P RUNCMP Shut-In Tree Valves and Bleed Down Lines. B/O Line to Tree Cap. 16:30 - 17:00 0.50 WHSUR P RUNCMP P/U DSM Lubricator. Pressure Test Lubricator on Tree with Diesel to 1500 psi for 10 mins. Set Cameron Style BPV. Pull and L/D Lubricator. 17:00 - 17:30 0.50 WHSUR P RUNCMP Install Tree Cap and Gauge. Open Up to Little Red and pressure up under BPV to 1500 psi for 10 mins. Good Test. 17:30 - 18:00 0.50 WHSUR P RUNCMP Bleed Down and Drains lines. R/D Little Red. 18:00 - 19:00 1.00 WHSUR P RUNCMP Remove Double annulus valve, remove slop tank, bridle up. Rig Released at 19:00 hrs on 2/27/2008 Printed: 3/12/2008 11:43:35 AM 02/28/08 NO. 4612 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Aurora,GNI,Pt.Mac,Milne Pt,Endicott Wpll .Inh it t ~n noac.i.,rinn n~ro cxi c„i,,. en 15-25A 12014000 LDL / -~0 '~+ 02/20/08 1 1 A-12A 11963077 MCNL sr 3 01/19/08 1 1 GNI-04 12031448 TEMP SURVEY (REVISED) ~- ~ (~ 01/22/08 1 1 P2-32 11968730 USIT - '- ~- 02/13/08 1 1 17-02 11996384 _ USIT /~Q - ~' 02177108 1 1 Y-07A 11962781 SCMT '}-1 Q ~ 02/03/08 1 1 P2-58 12031456 USIT /9D - ~~ 02/25/08 1 1 MPH-12 12005205 MEM INJ PROFILE ~ _ (~'}~ tt '3 02/15/08 1 1 4-14/R-34 11975755 USIT V=e ~ 02/25/08 1 1 S-126 11968731 JEWELRY/PERF/SBHP '~- ~ ~ 02115/08 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ~A ~ ~ ~~U~ Petrotechnical Data Center LR2-1 ~~~ MAR L 900 E. Benson Blvd. °° Anchorage, Alaska 99508 Date Delivered: j /j r'~~> t"± ;1 ~`,~~f~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth j Received by: Iy • • ,i,~i~, r , Doyon 16 BPV, TBG HGR issue. • Page 1 of 1 Regg, James B (DOA) From: Mabeus, Rodney E (M-I) [mabere@BP.com] Sent: Saturday, February 16, 2008 6:24 AM To: jim.reg@alaska.gov; DOA AOGCC Prudhoe Bay; Fleckenstein, Robert J (DOA) Cc: Willingham, James M (ASRC ENERGY SERVICES); Reem, David C; Rossberg, R Steven; West, Howard J; McLaughlin, Sean M Subject: Doyon 16 BPV, TBG HGR issue Attachments: RTTS.doc Gentlemen, As requested by John Crisp, here is the sequence and events around the BOP test 2-16-2008. Rodney Mabeus/Mike Rooney WSL Doyon 16 «RTTS.doc» D~~ 1?-~ 2-- a-l3~ ~NE~ FEB ~ 5 200 i w.. ._ ,_..... ... __ .. .... 2/22/2008 • . p DS 17-02 Doyon 16 2/15/2008 18:00 to 23:00 Hours ~~. ~~~ As requested by AOGCC inspector John Crisp, the following operations were documented to be sent to AOGCC. These events led to the request to pull the tubing hanger, 3 joints of tubing, RIH and hang the tubing string from a storm packer, set a test plug, and test BOPE. The Work over Fluid is 8.5 ppg Seawater. The 5-1/2" tubing was Power Jet Cut 2-1-2008 at 10,160' MD. A Baker 2.5" 1BP was set 1-30-2008 and tested to 3,000-psi at 10,316' E-line MD. t) ISA BPV was set in 5-1/8" FMC Tree. 2) BPV was tested to 1500 psi from below through the IA. This tested the BPV (which was also visually observe), and the Baker IBP set at 10,316' to Facture Gradient. It also tested the integrity of the well bore and 9-5/8 x 5- 1/2" Baker SAB Packer. This hydraulically proved isolation of the well bore from the production zone. 3) 'The tree was N/D, the blanking plug was installed, and BOPE were N/U. 4) °fhe 4" test joint with doughnut was picked up and RIH. 5) An attempt to get a low pressure test to 250 psi was unsuccessful. An attempt to get high pressure test to 3500 psi appeared to be a good test. Another attempt was made to achieve the low pressure test, but again without success. 6) The blanking plug was POOH, rebuilt, and re-installed. 7) High and low pressure tests gave the same results as before: a good high pressure test and an unsuccessful low pressure test. 8) The lockdown screws were run in to make sure the tubing hanger was secured properly in the wellhead. 9) A high pressure bleeder was installed in the test port on the tubing spool between the tubing hanger's primary and secondary packoffs. 1 tl) 'The hanger's primary packoff was pressure tested from above, and a steady leak was observed from the bleeder. 'The stream of seawater increased proportionally with pressure applied from above. The high pressure bleeder was removed from the test port and a high pressure test indicated the secondary packoff was holding with high pressure, but still would not hold at low pressure. 11) Pressure was applied from the IA, and the 4" test joint was installed in the pipe rams. This tested the hanger secondary packoff from below, the Baker IBP, and the ISA BPV. The test was staged up from 500 to 1000 and to 1500 psi. All tests were held for 10 charted minutes and proved good on the chart. The bleeder on the test joint was opened and showed some fluid getting above the hanger. The test was repeated with the high pressure bleeder open in the test port. Small amounts of seawater were observed getting by the secondary packoff and the charted results were the same as the previous test. 12) Doyon 16 rig team consulted David Reem and Jim Willingham, Anchorage ADW. Squeezing in emergency packing was discussed, but disregarded due to the type of wellhead and hanger. RIH with a WRP was disregarded due to the hanger primary and secondary packoff leaking. Hanging the tubing string off a storm packer was the most feasible option. 3) John Crisp with AOGCC was contacted by Rodney Mabeus, WSL Doyon 16. John Crisp gave the OK to proceed with the plan forward as followed: ~~ • Perform a visual test of the pipe rams and annular preventer. • R/U DSM lubricator and pull BPV. • RIH with landing joint and pull tubing hanger to rig floor. • Monitor well. • POOH with 3 joints of 5-1/2" tubing. L/D tubing. • P/U HES Storm Packer. RIH and set below wellhead. • POOH w/ drill pipe, set test plug, and test BOPE. Jim Willingham notified Steve Rossberg of the situation. With Steve Rossberg's OK, Doyon 16 proceeded as planned. STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report ~ ~ z~2~~~~ Submit to: itxl_r~;~~~;;_~~si~.~_~@,~~ `\~ do~a.ao.,cc. ru~iE;;~n.ba3'~~:iaska.guv boE~.fP~,ke:~sfiei3~t~~aia~~k.~.c3~+~t Contractor: Doyon Rig No.: 16 DATE: 2!16/2008 Rig Rep.: A. Honea / J. Hansen Rig Phone: 659-4169 Rig Fax: 659-4163 Operator: BPX Op. Phone: 659-4168 Op. Fax: 659-4163 Rep.: M. Rooney Field/Unit & Well No.: PBU 17-02 PTD # 1800700 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/ 3500 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Workover: X Weekly: Annular: 250/ 3500 Explor.: Bi-Weekly Valves: 250/ 3500 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Quantity Size Test Result Annular Preventer 1 13-318" P Pipe Rams 0 NA NA Lower Pipe Rams 1 3-112"x6" P Blind Rams 1 13-3/8" P Choke Ln. Valves 1 3-1/8" P HCR Valves 2 3-1/8" P Kill Line Valves 1 3-1/8" P Check Valve 0 NA NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: Quantity Test R No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure T est F System Pressure 3000 P Pressure After Closure 1900 P 200 psi Attained 14.5-sec P Full Pressure Attained 1-min 9-sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 5 @ 2025psi Test Results Number of Failures: 0 Test Time: 3.5 Hours Components tested All Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: "i::-:.reg ~aiaska. ov Remarks: AOGCC granted a variance to pull the hanger to the floor, RIH and set an RTTS, then use a blanking plug to facilitate testing the BOPE. This variance was granted after several attempts with ISA BPV proved that 24 HOUR NOTICE GIVEN YES X NO Date 02/14!08 Time Test start 14:30-hrs Finish BOP Test (for rigs) BFL 11/14/07 13:30:00 PM By John Witness M. S. 200 8-0216_60 P_D oy on 16_P B U_ 17-02.x1s • r"" 0..J .~., ~ ~ ~ ~ ~ f~ 6 H ~ C~ .J1 LLL 111 j SARAH l PAL N, GOVERNOR AL1lSSA OIL A1~TD GAS 333 W. 7thAVENUE, SUITE 100 COI~TSER`QATIOI~T COI~II-IISSIOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 ~~'~~ ~~~ ~` ~ 200 .~`~ d Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-02 ~C~b Sundry Number: 308-007 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. DATED this ~5da of Janu , 2008 Y az'y Encl. Sincerely, \~~~ ~~~ ~S~ " - STATE OF ALASKA ~J »O~ ALAS OIL AND GAS CONSERVATION COMMfSSION p~ APPLICATION FOUR SUNDRY APPROVAL~~~~,~Q~ ~ U 20Q~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforat Ti nsi / ~11a~ca iC ~"~aa~s`~'ons, ~r> mis~;~r~ ,~, ~ „(yyLle! Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate Uu Re-Entejnuseefad~ed e A ~nD (J('I ' ^ Change Approved Program II Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 180-070 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20486-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 17-02 , Spacing Exception Required? ^ Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028334 A.~04,?~3r 70'' Prudhoe Bay Field / Prudhoe Bay Poot 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11375 - 9567 - 11304 9504 None None Casin Len th Size MD TVD Burst Colla se Structural and for 11 20" 110' 110' 1530 520 Surface 2676' 13-3/8" 2676' 2676' 4930 2670 Intermediate Prod i n 1134 ' 9-5/8" 11348' 9543' 870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10512' - 10784' 8818' - 9051' S-1/2", 17# L-80 10394' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 10336' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 15, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Davi eem Title Engineering Team Leader 1 Prepared By Name/Number: Signature Phone 564-5743 Date ~ -. Terrie Hubble, 564-4628 Commission. Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity (~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: `~ J~OQ ~\ ~.~.)~ -~-S"~ Subsequent Form Required: ~~~--\ APPROVED BY ~ ~ ~i0 A roved B : M ER THE COMMISSION Date Form 10-403 Revised 06/2006 `~~ I ~ ~ ~ Submit In Duplicate _ ~ ~~. ,~~~ ~ ~ 200 ~ R l G • by G r imy 17-02 Rig Workover • Scope of Work: Cut, Pull, Replace 5-1 /2" L-80 completion with 4-1/2" Chrome tubing, Run a USIT to evaluate TOC and 9-5/8" corrosion. Cut, Pull, Replace 9-5/8" casing and cement to surface. MASP: 2388 psi Well Type: Producer Estimated Start Date: February 15, 2008 Pre-Rig Work Request: O 1 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. E 2 Set QuickDriN plug in middle of 15' pup joint below the sliding sleeve at 10210'. (Ref: 8/4180 tubin summar F 3 CMIT-TxIA to 3000 E 4 Jet cut @ 10140', in the middle of the 1S full joint above the sliding sleeve. (Ref: 8/4/80 tubing summa F 5 Circulate/bullhead SW thru the cut leavin a diesel ca .Bleed WHP's to 0 si. W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid with sea water through the cut. 2. Pull and LD 5-1/2" tubing string. 3. RIH with 9-5/8" casing scraper to RBP setting depth of 2300'. 4. Run USIT to determine TOC and evaluate corrosion in the 9-5/8" casing. 5. Use a RTTS to test casing below the proposed 9-5/8" cut depth of 2100' (confirm with USIT data). 6. Set 9-5/8" RBP at 2300' 7. Cut, pull, replace 9-5/8" casing and cement to surface. 8. Test well to 3500 psi. 9. Drill out landing collar and cleanout 10. Pull 9-5/8" RBP 11. Pull tubing stub, sliding sleeve, and PBR from packer. 12. Run polish mill and 9-518" scraper 13. Run new 4-1/2" Chrome tubing completion with packer at 10130' MD. 14. Displace the IA to packer fluid and set the packer. 15. Test Tubing & IA to 3500. psi. Freeze protect to 2200' MD. 16. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = FMC GEN 2 W0.LHEAD= FMC ACTUATOR = AXELSON KB. 0.EV = 70' BF. ELEV = KOP = 3100' Max Angle = 42 @ 6200' Datum MD = 10573' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-( 2676' Minimum ID = 3.0" @10223' 5-112" TBG PATCH PERFORATION SUMMARY REF LOG: BRCS ON 07/31/80 ANGLE AT TOP PERF: 33 @ 10512' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OpnlSgz DATE 3-318" 0.2 10512 - 10522 O 03/28/91 4" 8 10632 - 10642 O 06/10/81 4" 8 10651 - 10656 O 04!29/88 4" 12 10668 - 10678 O 04(29{88 4" 8 10684 - 10714 O 04/29!88 4" 8 10728 - 10748 O 04!29/88 4" 8 10764 - 10784 O 04/29/88 i 5-112" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" 10394' PBTD -~ 11304, 9-5/8" CSG, 47#, L-80, ID = 8.681 " 1 ~ 348' (~ 11375' 17-02 2136' -1 TOP OF CEMEM ® 2197' 5-112" CAMCO BAL-O SSSV Nom, ID= 4.56 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3777 3736 14 D MY RK STRIPP ED LAT CH 2 6891 6029 45 MMG DOME RK 16 05/13/06 3 8272 7035 41 MMG DMY RK 0 08/30/05 4 8385 7121 41 MMG DMY RK 0 5 8840 7472 39 MMG DMY RK 0 6 8953 7560 38 MMG SO RK 22 05/13/06 7 9234 7783 37 MMG DMY RK 0 8 9343 7870 37 MMG DMY RK 0 9 9585 8062 38 MMG DMY RK 0 10 9697 8150 38 MMG DMY RK 0 11 9977 8374 37 MMG DMY RK 0 12 10089 8465 36 MMG DMY RK 0 I ( 10197' 5-1/2" CAMCO DB-1 SLIDING SLV 10223' S-1/2" TBG PATCH, ID = 3.0" (SET 11/02/91) 10304' 5-112" BOT PBR ASSY, ID = 4.750" 10336' I'-I 9-5/8" X 5-112" BAKER SAB PKR, ID = 4.750" 10390' I-{ 5-1/2" CAMCO LAND NIP, ID = 4.44" 10393' -~5-1/2" BAKER SHEAROUT SUB 10384" ELMD TT LOGGED 09/01/80 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/05/80 ORIGINAL COMPLETION 06/27(06 COM/PAG WAIVER SAFETY NOTE (06/02106) 10/16/02 JRGKK WAIVER SAFETY NOTE 11/16/05 KSB/PJC GLV GO 04127!06 DPS/PJC OA DOWNSOUEEZE 05/03!06 ? / PJG OA DWN SOZ CORRECTION 05/19/06 KSB/TLH GLV GO (05/13/06) PRUDHOE BAY UNff WELL: 17-02 PERMIT No: 1800700 API No: 50-029-20486-00 SEC 22, TI1 N, R15E, 4308.55 F0. & 1317.94 FNL BP Exploration (Alaska) TREE ~ FMC GEN 2 WELLHEAD= FMC ACTUATOR= AXf3SON KB. ELEV = 70' BF. ELEV KOP = 3100' Max Angle = 46 @ 6200' Datum MD = 10573' Datum TV D = 8800' SS • ~ ~ -0 ~ SAF NOTES: proposed RWO 0' Cement to surface 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = PEF2FORATION SUMMARY REF LOG: BRCS ON 07/31/80 ANGLE AT TOP PERF: 33 @ 10512' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 0.2 10512 - 10522 O 03/28/91 4" 8 10632 - 10642 O 06/10/81 4" 8 10651 - 10656 O 04/29/88 4" 12 10668 - 10678 O 04/29/88 4" 8 10684 - 10714 O 04/29/88 4" 8 10728 - 10748 O 04/29/88 4" 8 10764 - 10784 O 04/29/88 14-1/2" TBG, 12.6#, 1361--80, .0154 bpf, ID = 3.958' I 15-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" I PBTD 9-5/8" CSG, 47#, L-80, ID = 8.681" I 11375' I 14-1l2" X NIP, ID= 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3033 3000 4 5154 4750 3 6852 6000 2 8487 7200 1 9885 830 10110' ~4-1/2" X Nipple, ID = 3.813" 10130' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = x.xx" 10150' 4-1/2" X IY~pple, ID = 3.813" 19-518" X 5-1/2" BKR SAB PKR, ID = 4.750" 10390' I--i 5-1/2" CAMCO LAND NIP, ID = 4.44" 10393, ~~ 5-1/2" BAKER SHEAROUT SUB 10384" ELMD TT LOGGED 09/01/80 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/05/80 ORIGINAL COMPLETION 05/09/07 SWGPAG GLV GO 04/27/06 DPS/PJC OA DOWNSOUEEZE 05/30/07 TO/TLH MAX DEV CORRECTION 05/03/06 ? /PJC OA DWN SOZ CORRECTION 7/24/2007 KSB/SV GLV GO 06/27/06 CONVPA WANER SAFETY NOTE (06/02/06) 08/11/07 JLJ/PJC PULLED PATCH @ 8925' 04/07/07 RCT/PA GLV GO (04/04/07) 04/07/07 TEUPAG SET WFD TBG PATCH @ 8925-60' PRUDHOE BAY UNfr WELL: 17-02 PERMfT No: 1800700 AR No: 50-029-20486-00 SEC 22, TI1 N, R15E, 4308.55 FEL 8 1317.94 FNL BP 6cploration (Alaska) 17-02 (PTD # 1800700) Internal ~ver Cancellation Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Wel{ Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) _ Sent: Tuesday, December 11, 2007 9:59 AM ~~~~ ~ t ~ ({ ~'~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Colbert, Chris M Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Holt, Ryan P (ASRC); Dube, Anna T Subject: 17-02 (PTD #1800700) Internal Waiver Cancellation All, ~ An internal waiver was issued for TxIA communication on well 17-02 (PTD #1800700) on 06/27/06. However, the well is currently shut-in and there are no plans to return the well to production before 12/31/07. The well is planned for a RWO in `~ spring 2008. Therefore, the waiver is cancelled. ~• The well has been reclassified as Not Operable. Please remove the waivered wells signs and the laminated copy of the waiver from the wellhouse. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~ JAN ~ 208 12/18/2007 ScblulDblPgep ro û - O-::;-C) RECEJVEe) 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL. 3 0 ZOO? Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 l\Iæka Oil & Gas Cons. CommissiQn Anchorage SCANNED AUG 0 1 2007 Field: Prudhoe Bay Endicott Well Job# Loa Description Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07111/07 1 X·19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-308 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: gCP · ~ I STATE OF ALASKA . ~....r¿)-~~ ALA A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Convnission o Stimulate 0 Other 0 WfØ:ch o Waiver 0 Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 180-0700 r Kt:.\"'CI V a...U APR 2 6 Z007 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull TubingD Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service 6. API Number: 50-029-20486-00-00 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 70 KB ( PBU 17-02" ADLO-028331 / 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool / 8. Property Designation: Total Depth measured true vertical 11375 i 9567 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 11304 { feet true vertical 9504 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 30 - 110 30 - 110 1530 520 SURFACE 2647 13-3/8" 72# L-80 29 2676 29 - 2675.72 4930 2670 PRODUCTION 11320 9-5/8" 47# L-80 28 - 11348 28 - 9543.2 6870 4760 stAANED MAY 02 2007 Perforation depth: Measured depth: 10512' - 10784' True Vertical depth: 8813' - 9051' - - - - Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 26 - 10394 Packers and SSSV (type and measured depth) 5-1/2" BOT PBR Assembly 5-1/2" Baker SAB Packer o o 10304 10336 o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 845 shut in Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 6311 5535 0 o 0 0 15. Well Class after proposed work: Exploratory Development r;¡' 16. Well Status after proposed work: Oil r;¡ Gas WAG Tubing pressure 384 o 13. Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ W OS PL Contact Gary Preble Signature Data Management Engineer Printed Name 564-4944 Date 4/19/2007 07":> Submit Original Only . . ,¥ 17 -02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***WELL FLOWING ON ARRIVAL *** (pre patch) SET 5.5" SLIP STOP CATCHER SUB @ 7003' SLM. RIH W/4.5" OM-1 W/EXT FINGER TO STA #2. ***CONT ON 04/04/07 WSR*** ***CONT FROM 04/03/07 WSR*** (pre tbg patch)) PULLED 1.5" LGLV 16/64" PORT SIZE (RK) FROM STA #2 6891' MD. SET 1.5" DGLV (RK) IN STA #26891' MD. PULLED SLIP STOP CATCHER SUB FROM 9003' SLM. ***WELL FLOWING ON DEPARTURE*** NOTE: USED CLOCK SET @ 9:00 TO SET DGL V. _rrrm_'''m''',_, _rrn_A_'_~~~ 4/6/2007 T/I/O=950/1860/520 Temp=S/1 Assist E-line (Restore Tubing Integrity) --- Job In Progress--- see following WSR for story *******WSR Continued to 04-07- 07******* FLUIDS PUMPED BBLS 68 60/40 Meth 300 1 % KCL 1 Diesel 369 Total e e pròil- IW-or-¡O Notice of Waivered Well WELL: 17 -02 WELL TYPE: Producer - Gas lift DA TE: 06-02-06 Production Data: 06/02/06: 549 BOPD, 2,217 BWPD, 4.7 MM GL Rate, 8.6 M GaR. Pressures: Flowing 81 Tubing 350 psi 1960 psi 9-5/8" ANN 1270 psi 1900 psi 13-3/8" ANN 790 psi 450 psi REASON FOR NOTICE: TxlA Communication COMMUNICA TION DEMONSTRATED BY: · TIFL Failed - 09/02/05. PRODUCTION CASING INTEGRITY DEMONSTRATED BY: · CMIT-TxIA Passed to 3000 psi -12/15/05. TUBING LEAK IS DEMONSTRATED MANAGEABLE BY: · NFT-IA Passed, final gas rate 144 scfph @ 1 psi - OS/21/06. SURFACE CASING INTEGRITY DEMONSTRATED BY: · MIT-OA Passed to 2400 psi - 04/30/06. IMPORTANT CONSIDERATIONS I COMMENTS: · 2 levels of protection are the production and surface casings have been tested to at least 1.2 times the operating . pressure limits. PLAN OF ACTION: Any deviation from this waiver must be pre-approved by the Wells Group and the Operations Manager. · Monitor well head pressures and log daily. · Perform the following waiver compliance testing: · Annually demonstrate production casing integrity. · Annually demonstrate surface casing integrity. · Annually demonstrate the tubing leak is manageable. Operating limits Max lAP = 2000 psi Max OAP = 1000 psi )Inna Ðu6e Well Integrity Coordinator I am approving this document 2006.06.08 13:34:31 -08'00' Date I,' Digitally signed by Olsen, Clark A Olsen Clark 1\i..DN:CN=Olsen,ClarkA , 17\::R~on: I am approving this document ,/ Date: 2006.06.08 17:04:53 -08'00' Well Operations Supervisor Date Rhoads, Christopher A , Digitally signed by Rhoads, Christopher A À DN: CN = Rhoads, Christopher A " \R:eason: I am approving this document Ðatä:c:2006.06.1114:13:56-OS'00' Area Manager Date Well Operations Manager Date Operations Manager Digitally signed by Kurz, John ,', DN: CN = Kurz, John 'RElason: I am approving this document Date: 2006.06.27 16:02:06 -08'00' Date R b R St ..i: ....Di9itally signed by Rossberg, R Steven ass erg even DN: CN = Rossberg, R Steven , ,/.,,~:R~on: I am approving this document Date: 2006.06.08 17:02:34 -OS'OO' Kurz, John Distribution: DS I Pad Operator DS I Pad Engineer WOE WI Status: Normal Status: > 10/12/94: MITOA Failed: 2.3 bpm @ 570 psi. > 10/26/94: IAxOA PPPOT Passed. > 12/30/97: OA @ 420 psi & OA FL @ 130'. > 06/23/98: OA FL @ 125', 500 psi > 08/04/98: OA FL @ 132', 520 psi > 04/03/99: OA FL @ 130', 580 psi > 10/27/01: TIFL Failed > 11/08/01: SL CO'ed OGLV > 11/20/01: Re-TIFL Failed > 10/12/02: PPPOT-T Passed > 10/15/02: NFT Passed > 09/21/03: NFT Passed 248 cfph @ 2 psi > 08/29/04: NFT Passed 390 cfph @ 2 psi > 09/03/04: MITOA Passed to 2400 psi > 06/21/05: MITOA Failed to 2400 psi. LLR of 1 bbls @ 1100 psi. > 06/27/05: Waiver canceled for TxlA comm > 07/16/05: Bled IA 2300> 460 psi in 4.5 hours (TP dropped 250 psi). AL valve frosted over > 07/16/05: IA FTS during bleed (Failed NFT) > 07/19/05: lAP increased 280 psi in 2 days (to 800 psi) and 0 psi in final day, AL spool has 1100 psi on it > 08/29/05: Caliper Tbg: 237 jts 0-40%, 29 jts 40-85% > 08/30/05: Set DGL V's in Sta #2 and #3 > 09/02/05: TIFL Failed > 09/23/05: LLR < 4.5 bpm @ 1500 psi > 10/17/05: Sensa LDL, GLM #6 leaking. > 11/16/05: Set DGL V w/ext pkg in Sta #6 > 11/28/05: Set TIP @ 10197' (SS) > 12/15/05: CMIT-TxIA Passed to 3000 psi, lAP came up while pumping down Tbg > 12/29/05: MITOA Failed - 2.2 bpm @ 920 psi > 01/16/06: Depress'd OA FL within 426' of shoe > 04/26/06: OA downsqueeze, 29 bbls cement > 04/30/06: MITOA passed to 2400# > 05/14/06: LGLVs sta#2 & 6 > 05/15/06: Pulled TIP > OS/21/06: NFT-IA Passed -144 scth - 1psi Comment T/IIO = 200/200Nac. Open (cold). NFT PASSED - IA & OA FL (post-POP/for waiver). IA FL @ 2524', FL inflowed 956' overnight, OA FL near surface. TBGP decreased 20 psi, lAP increased 70 psi overnight. Lateral valve behind wellhouse leaks-by (frosted-up), pad operator shut-in gas in manifold building today. Bleed lAP to UIT # 071 to 5 psi (2.5 hrs), IA FL @ 1842', CFH = (564). Shut-in wing valve and begin NFT. 1st hr bleed = 2 psi, (240 CFH). 2nd hr bleed = 1 psi, (174 CFH). 3 rd hr bleed = 1 psi, (144 CFH). Final WHPs = 200/1Nac. T/I/O = 350/1270/790. Hot. NFT IA & OA FL (post POP/ for waiver). IA FL @ 8953' (Sta # 6, SaG LV) 392 bbls, OA FL @ Surface. Shut-in AL at lateral valve and begin lAP bleed down flowline to CLP 220 psi (4 hrs). Continue bleed to UIT # 071 (30 min). RDMO. IA FL @ 3480', Final WHPs = 220/130Nac. Continue NFT tommorrow, left well open. *** CONTINUE JOB FROM 05-14-06 *** (ANN COMM MIT'S ) BAILED PARAFFIN FROM TOP OF DBP PLUG PULLED 51/2" DB PLUG BODY FROM 10171' SLM *** LEFT WELL SHUT-IN TURNED OVER TO DSO *** *** JOB CONTINUED FROM 5-13-06 *** ( POST ANN COMM MIT'S ) SET 1.5" S/O DUAL CHECK IN STA # 6 UNABLE TO LATCH PLUG 4" LIB NO IMPRESSION 2.25" BAILER TO 10167' SLM RECOVER HEAVY ASPHALTINE 4.5" GAUGE Page 1 of 6 Well Integrity History Type: PAL Problem: TxlA comm DGL V in sta #1 has broken latch RKP equalizing valve in sta #12 (RKP valves are difficult to pull, and have a tendency to break) Drilling file verifies SC is 13 3/8", 72#,L-80 Permanent Patch in hole (below all GLM's at 10223) Date 5/21/2006 5/20/2006 5/15/2006 5/14/2006 61812006 e Well 17-02 e 6/8/2006 Planned Action: Obj: Waiver for TxlA comm 1, FB: CMIT-TxIA to 3000 psi - PASSED, MITOA - FAILED 2. FB: OA dwn sqz - DONE 3. FB: MITOA to 2400 psi - PASSED 4. SL: Set LGLVs, pull TIP - DONE 5, DHD: POP, NFT-IA - PASSED 6. WA V: Obtain TxlA waiver - Drafted for review e e Date -~-~.._-~--..~- ..~--~----~---~-,--- 5/13/2006 5/12/2006 5/11/2006 5/9/2006 4/30/2006 4/26/2006 4/26/2006 1/17/2006 1/16/2006 1/15/2006 1/10/2006 12/29/2005 12/15/2005 12/11/2005 11/29/2005 11/28/2005 11/28/2005 11/27/2005 11/27/2005 11/20/2005 6/8/2006 Comment RUN TO 10170' SLM BAILER RUNS FULL -OF ASPHAL TINE ***CONTINUE JOB ON 5-15-06*** *** CONTINUE JOB FROM 5-12-06 *** (POST ANN COM MIT'S ) UNABLE TO PULL STA # 5 DUE TO POSSIBLY ROUNDED OFF FISHING NECK, VERIFIED DGLV IN STA#5 PULLED DGLV's STA #6 @ 9828' SLM & STA # 2. SET LGLV STA # 2 @ 6877' SLM NOTE: STA # 2 @ 9:00 POSITION. USED D-CENTRALlZER & COLCK CONTINUED JOB ON 5-14-06 SEE WSR *** CONTINUE FROM 5-11-06 (POST ANN COMM MIT'S) ATIEMPTING TO PULL DGLV FROM STA # 5 MANDREL @ 9 a-CLOCK P~S, CONTINUE JOB ON 5-13-06 SEE WSR *** WELL SHUT IN PRIOR TO ARRIVAL *** (POST ANN COM) PULLED PRONG FROM TIP ATIEMPTING TO PULL DGLV FROM STA # 5 CONTINUE JOB ON 5-12-06 SEE WSR T/I/O= SSV/950/90. Temp= SI. OA FL (post OA down squeeze), OA FL @ surface. T/I/O=SSV/920/0 MIT OA PASSED @ 2400 psi, (Shut In)(Post OA Down SQZ) OA pressured up w/5.3 bbls Diesel pumped. 1 st test OA lost 30 psi in 15 min. w/ total loss of 300 psi in 30 min. 2nd test OA lost 90 psi in 15 min. w/ total of 140 psi in 30 min. Final WHP's=SSV/920/0 OA down squeeze. Pumped 10 bbls methanol to establish injection, 10 bbls DS CW 100, 250 bbls fresh water OA flush, 5 bbls spacer, 29 bbls of 15.7 ppg Arctic Set 1 cement, 5 bbls fresh flush, displace with 119 bbls cude, Estimated cement top @ 2136' (540' above shoe). Monitor OA pressure for 30 minutes post. Notify pad operaror. T/I/0=UK/1000/0 Assist schlumberger with OA cement squeeze, Pumped 119.4 bbls crude to spot cement & freeze protect OA. FWHP's=UK/1000/0 T/I/O = SSV/870/420, Temp = SI. Monitor (post OA depress). lAP decreased 10 psi overnight. OAP increased 50 psi overnight. T/I/0=SSV/880/600. OA FL Depress (Pre dwn sqz) DNE 1500 psi per WOS. OA FL @ 492'. Pressurized OA to 1500 psi in 200 psi increments. OA FL fell to 2250' (131 bbls). OAP decreased to 1400 psi in 30 minutes. Pressured back up to 1500 psi. Monitored 30 minutes. OAP decreased to 1400 psi. OA FL remained at 2250 psi. Bled OAP to 370 psi in 1.5 hours. OA FL inflowed to 1380'. Final WHP's=ssv/880/ 370 T/I/0=SSV/880/210. SI. OA FL Depress (Pre dwn sqz) DNE 1000 psi. OA FL @ near surface. Pressurized OA to 1000 psi. OA FL fell to 240' (14 bbls). Monitored 30 minutes. OAP decreased to 840 psi. OA FL @ 324' (19 bbls). Final WHP's=SSV/880/840 TI0=SSV/880/200, temp=SI. OA FL @ near surface. Pre-OA Down-Squeeze. T/I/O=700/880/350 Mit OA @ 3000 psi (FAILED) Established LLR of 2.2 bpm @ 920 psi. (well shut-in) (Evalulate for waiver) Pumped 10 bbls diesel pressure @ 1700 psi pressure broke. Established LLR of 2.2 bpm @ 920 psi. Pumped 14 bbls diesel @ rate. Bleed down pressure. Final WHP's=700/880/300 T/I/0=700/670/400 CMIT Tx IA to 3000 psi. PASSED (Eval for waiver or secure) Pumped 3 bbls neat meth and 86 bbls crude down TBG to pressure up to 3000 psi. lAP came up rapidly while pumping down tubing, 3rd test T/llost 40/20 psi in 15 min, Lost 20/20 psi in 2nd 15 min,Passed per PE, Bleed WHP's, Flowline frozen Final WHP's=650/840/460 T/I/0=1110/480/380. Temp=SI. Bleed Tubing <500 psi (pre-MITIA), T & IA FL's. T FL @ 2385' (between SSSV & sta #1) (OGLV @ sta #3) (55 bbls). IA FL @ 612' (above SSSV) (27 bbls). Bled TP from 1110 psi to 370 psi in 1 hour, 35 minutes (fluid to surface). TP increased 10 psi during 30 minute monitor (RD). Final T/I/O=380/41 0/370. *** CONTINUED FROM 11-28-05*** BLED TUBING PRESSURE FROM 1340 PSI DOWN TO 1040 PSI HELD FOR 30 MINUTES GOOD TEST ON PLUG ***WELL LEFT S/I, DSO NOTIFIED*** *** CONTINUED FROM 11-27-05*** PULLED WHIDDON CATCHER BLEEDING DOWN IA LRS PUMPED 45 BBLS CRUDE DOWN TUBING, RUN 5.5" BLB, AND 4" GAUGE RING RUN 5.5" DBP CAMCO PLUG W/4,51" PACKING SET @ 10171' SLM IN SILDING SLEEVE NIPPLE PROFILE RUN 74" PRONG W/1 3/4" FN SET @ 10165' SLM ***CONTINUE JOB ON 11-29-05*** T/I/O=1500/450/400 Assist SSL (gas-lift maintenance) Pumped 45 bbls crude. Final WHP's=1200/500/400 ***WELL SiaN ARRIVAL*** BLEEDING DOWN fA SET 5.5" WHIDDON CATCHER SUB @ 10183' SLM ***CONTINUE ON 11-28-05*** T/I/0=1500/520/410. SI. TBG & IA FL (for W/L). TBG FL @ 4006' (92 bbls), IA FL @ 750' (33 bbls). T/I/O = 1510/360/390. Temp = SI. No change in WHPs since yesterday. ----- Page 2 of6 Date 11/19/2005 11/17/2005 11/16/2005 11/16/2005 11/16/2005 11/16/2005 11/15/2005 10/18/2005 10/17/2005 10/17/2005 10/16/2005 9/23/2005 9/20/2005 9/11/2005 9/3/2005 9/2/2005 8/30/2005 8/29/2005 8/28/2005 8/17/2005 7/19/2005 7/18/2005 6/8/2006 e e ~.~--~----~-~- ~--,-~ Comment DUO =1510/360/390, SI. IA FL @ Surface, TBG FL @ 3777' (Sta # 1). Monitor 1 hr, no change in FLs or WHPs. Note: AL Spool disconnected. ***JOB CONTINUED FROM 11-16-05*** PULL CATCHER. ***JOB COMPLETED, WELL LEFT SHUT IN*** ***JOB CONTINUED FRaN 11-15-05*** SET SLIP STOP CATCHER. LRS PUMPED A TOTAL OF 170 BBLS OF CRUDE DOWN TBG. C/O STA#6 W/1.5" DGLVW/ EXT. PACKING. ***JOB CONTINUED ON 11-17-05*** T/I/O 1750/340/400 Assist Slickline (Secure Well) Load tbg w/1 00 bbls of crude. RDMO Final WHP"s 1160/610/420 TI0=1700/380/420, temp=SI. TBG & IA FLs @ surface (for SL), TI0=2150/200/400 LOAD TBG EVAL FOR WAIVER OR SECURE PUMPED 70 BBLS OF 75* CRUDE DOWN TBG FWHP=1660/540/430 ***WELL S/I ON ARRIVAL*** SET CATCHER @ 8990' SLM. PULLED CATCHER FOR FLUID LEVEL SHOT. ***JOB CONTINUED ON 11-16-05*** ***JOB CONTINUED FROM 10-17-05*** LOGGED TUBING FROM 8915' SLM TO SURFACE. ***WELL LEFT SHUT IN*** ***WELL S/I ON ARRIVAL *** (Sensa LDL) STOPPED TOOLS @ 10452' STM. LOGGING ON SENSA LINE, LOGGED IN PROGRESS. ***JOB CONTINUED ON 10-18-05*** T/I/O 2150/1000/440 Assist Slickline- Leak Detection Log [Eval for Waiver or Secure] PUMPED 537 BBLS OF 125* CRUDE DOWN IA FWHP=2250/160/650 ***WELL SiaN ARRIVAL***(PRE-SENSA LDL) TAG BOTIOM @ 10687' SLM W/2.8" CENT & SAMPLE BAILER ***GIVE WELL BACK TO DSO, LEAVE SI*** T/I/O = 2060/1500/500 Preform LLR on IA to 2500 psi., IA pressure started at 1500 psi. after pumping 533 bbls of crude ,the pressure continually decreased to 450 psi. Final WHP= 2300/440/640. LLR-IA 2500 PSI EVAL FOR WAIVER OR SECURE JOB POST PONED AL LINE NEEDS TO BE RIGGED OFF T/1I0=1980/131 0/450. Temp=SI. T & IA FL's. (For LDL.) T FL @ 7875' (183 bbls). IA FL @ 3660' (160 bbls). TP increased 60 psi, lAP increased 600 psi since TIFL on 9-3-05, T/I/O= 1920/710/450. Temp= SI. WHP's post- TIFL, (post-DGL V, eval for waiver). TBG pressure decreased 40 psi. lAP increased 230 psi overnight. OAP no change. AIL line SI at lateral valve, (still frosted), Called grease crew to service. T/I/0=1960/1900/450. Temp=SI. re-TIFL-(FAILED) post DGLV. (Eval for waiver.) AIL is SI at lateral. IA FL @ 7665' between sta 2,3 (336 bbls). Bled lAP from 1900 psi to 450 psi in 4 hours 45 min, FTS end IA bleed. During IA bleed, AIL lateral frosted up. OAP increased 10 psi. Monitored for 30 min, IA FL remained at surface, lAP increased 30 psi, OAP decreased 10 psi. Flowline is still freeze protected. Notified DSO not to POP. Final WHP's = 1960/480/450. ***JOB CONTINUED ON 8-30-05*** SET 1.5" DGLVW/IN STA#3@8261'SLM. PULLED 5-1/2" C-SUB@ 10165' SLM. ***WELL LEFT SHUT IN & DSO NOTIFIED*** *** JOB CONTINUED FROM 8-28-05*** RIH W/2.75" SWAGE, TEL & S. BAILER. TAG T.D @ 10718' ELM. S. BAILER EMPTY. CALIPER TUBING FROM 10410' SLM TO SURFACE. PDS HAS DATA. SET 5-1/2" WHIDDON CATCHER SUB @ 10,163, PULLED 1-1/2" OGLV FROM STA #3 - 8255' SLM & LGLV FROM STA #2 - 6868' SLM. SET DGL V LATCH IN ST A # 2. JOB I N PROGRESS. ***CONTINUED ON 8-30-05 WSR*** ***WELL SHUT IN ON ARRIVAL*** RIH W/2.75" G. RING. JOB IN PROGRESS *** CONTINUED ON 8-29-05 WSR*** ***WELL SiaN ARRIVAL*** (SBHPS) DRIFTAND TAG W/ PETRADAT GAUGES, STOPS @ 10,573, AND 10,690, TAG @ 10,721' MD ***Return well to DSO*** T/I/O = 1950/800/370, Temp = SI. MonitorWHP's post IA bleed (Eval high lAP, DSO call in) Day 3. AL lateral line shut and still frosted over, AL line @ 1100 psi. **Note** Integral on companion. T/I/0=SSV/800/370. Temp=SI. WHP's post-IA bleed. (Eval high lAP, DSO call in.) Day 2. lAP increased Page 3 of 6 ~..~--- Date 7/17/2005 7/16/2005 6/22/2005 6/21/2005 6/19/2005 4/1/2005 9/3/2004 8/29/2004 9/21/2003 3/4/2003 10/27/2002 10/15/2002 10/15/2002 10/12/2002 8/11/2002 12/5/2001 12/5/2001 11/20/2001 11/20/2001 11/18/2001 11/13/2001 11/9/2001 11/8/2001 6/8/2006 e e _._---~- .._-~ Comment -150 psi. SSV SI, unable to get TP. AIL lateral SI, still frosting, IA casing valve SI to isolate AIL. AlL@980 psi. T/I/0=340/650/370 Temp=SI WHP's post-IA bleed (eval high lAP, DSO call-in). TBG pressure decreased 1710 psi, lAP increased 130psi, and OAP decreased 40 psi (Post IA bleed). AI line shut in. AI line pressure was 840 psi. IA valve shut. **Note frosting on IA valve**, (No IA companion valve. No OA companion valve), T/I/0=2300/2300/410. Temp=SI. IA FL, Bleed lAP < 300 psi. (Eval high lAP, DSO call in.) AIL SI at lateral, single IA casing valve attached, IA FL @ 10336', 95/8 x 51/2 packer, no fluid in lA, (453 bbls). Bled lAP from 2300 psi to 460 psi in 4.5 hours. During IA bleed, TP tracked lAP down to 2050 psi, TP held 2050 psi through rest of IA bleed. Frosting of AIL lateral valve occurred once lAP dropped below 600 psi, had grease crew service the AIL lateral valve. Once lAP reached 460 psi fluids came to surface, crude returns, end IA bleed. AIL lateral valve did not appear to be holding, and developed an external leak, notified DSO of status. Monitored for 30 mins, lAP increased 70 psi. Final WHP's 2050/520/410. T/I/0=1900/1930/220. Temp=SI. Monitor WHP's (post-MITOA). T/I/O = 260/1720/800 ,MIT-OA to 2400 psi {FAILED}. Pumped 8 bbls to achieve test pressure = 260/1720/2400. Pressures @ 15 min.= 260/1720/2360. Pressures @ 30 min.=260/1720/760. Established a LLR of 1 bpm @ 1100 psi for 20 bbls. Final WH P 260/1720/760 T/I/O=270/1500/530. Temp=SI. OA FL. (Pre MITOA). OA FL @ 120' (7 bbls). T/I/0=250/1500/600, Temp=WARM, OA FL (OA FL Project). OA FL @ 72' (4 bbls). TI0=240/1620/450 MITOA PASSED @ 2400 PSI. (Well Flowing on Arrival)(Waiver Compliance) Install Integral Flange. OA Pressured up w/14.8 bbls Diesel Pumped. OA Lost 50 psi in 15 min. w/ Total Loss of 50 psi in 30 min. Integral Removed, Original Flange Installed and PTd to 1600 psi. Final WHP's= 240/1620/450 TIO= 240/1600/420. NFT-IA PASSED gas rate = 390 cth @ 2 psi. (forW/C) Well flowing with AIL. Initial IA FL @ 8335' sta 4 (370 bbls), OA FL @ 216' (13 bbls). Bled lAP down from 1540 psi to 9 psi in 5 hrs. IA FL in flowed 6500', switch to tank continue to bleed lAP to 10 psi. SI wing start NFT. NFT-IA Passed with an initial gas rate of 870 cfph @ 9 psi and a final gas rate of 390 cfph @ 2 psi. Final WHP's= 320/4/340 ** DSO to B.O.L. ** T/I/O= 220/1540/420. NFT PASSED (for W/C) Well flowing with AIL. InitiallA FL @ 8335' (between sta's #9 & #10). Bled lAP down from 1540 psi to 7 psi in 5 hrs and 30 minutes. NFT PASSED with an initial gas rate of 870 cth @ 7 psi and a final gas rate of 248 cth @ 2 psi. Final WHP's= 720/2/340 T/I/O = 380/1620/440. IA FL for GLE. IA FL @ 8840' (station # 5). T/I/0=250/1760/360 (Waiver Com.) OA FL @ 156', T/I/O = 280/60/300. NFT-IA PASSED. (For WC). Continued from night shift. Bled IA from 60 psi to 8 psi. SI well and started NFT, Initial gas rate of 600 scf/hr at 7 psi. Started 3 hour test. Final gas rate of 435 scf/ph at 4 psi. Final WHP's = 270/4/300. DSO will BOL with AL later. T/IIO=400/1740/340. TIFL FAILED (Prep for NFT, WC). Left well flowing. InitiallA FL @ 8517' (between Sta 4 and 5). Bled IA from 1740 psi to 240 psi in 4 hours. IA inflowed 6057' or 265 bbls. C/O with day crew. Final WHP=300/240/300. TII/O = 300/1720/350. PPPOT-T PASSED. (OA waiver eval) Tightened LDS to 450ftllbs. Pressured void to 5000psi. Test void lost Opsi in 30 min. PPPOT-IC PASSED. Pressured void to 3200psi. Test void lost 100psi in 30 min. T/I/O = 280/1810/400. Temp = Hot. IA FL @ 8255' (Sta # 3). (IA FL for GLE). GLR = 4.53 mmcf. BLED IA FROM 1780 PSI TO 270 PSI IN 8 HOURS [Ann Comm] T/IIO = SI/1780/150. Bleed IA (pre-SSV repair). Bled IA from 1780 psi to 270 psi in 8 hours. RE-TIFL (FAILED) [Ann Comm] T/I/O = 300/1550/300 Re-TIFL FAILED (post OGLV change out). Shut in well stack out TBG. InitiallA FL @ sta # 6 8953'. Bled IA from 1850 psi to 680 psi in 2 hours. IA FL rose from 8953' to 2400'. Monitor IA pressure for 1 hour, IA pressure increased to 750 psi, IA FL @ 4450'. Final WHP's = 1750/750/260 P.O.P. T/I/O = 300/1560/300 Attempted TIFL. Shut in wing, stack out well, put gauge on tree cap, open swab, O-ring blew out - closed swab and master, neither valve is holding, call grease crew. Grease swab and master valves, replace o-ring on tree cap, install tree cap and pressure test o-ring. a-ring blew out again, closed swab and master, bleed down tree cap. Need to replace tree cap bonnet. T/I/O = 320/1760/300 IA FL at 8953' (St #6) GLR= 2.85 mmcf. For GLE. T/I/O = 260/1700/300, IA FL @ 6000' for GLE. RAN 4 1/2" OM-1 (L T) W/ EXTENDED FINGER & 7" EXT W/1 5/8" JDS TO GLM # 2 @ 6873' SLM & PULL LGLV, RAN SAME W/1 1/2" RK LGLV & SET IN GLM # 2 @ 6873' SLM, RAN SAME W/1 1/2" RK OGLV & Page 4 of 6 e e Date ._~---~--- ~~-,-- 11/8/2001 11m2001 10/27/2001 10/27/2001 10/23/2001 9/23/2000 7/6/2000 4/3/1999 8/4/1998 7/22/1998 6/23/1998 5/14/1998 12/30/1997 9/19/1997 5/9/1997 4/30/1997 11/6/1996 10/19/1996 9/19/1996 8/13/1996 4/16/1996 10/8/1995 10/26/1994 10/12/1994 3/29/1994 11/8/1991 11m1991 11/5/1991 11/3/1991 11/2/1991 10/25/1991 10/23/1991 9/19/1991 7/26/1991 6/8/2006 Comment SET IN GLM # 3 @ 8255' SLM, RAN 5 1/2" OM-1 ST W/3' STEM & 4.5 SWAGE ABOVE & SET DGLV IN~ GLM# 6 @ 8927' SLM, PULL WHIDDON CATCHER SUB @ 10,161' SLM, RIG DOWN, TURN WELL OVER TO PRODUCTION. SL CO'ed OGLV SET CATCHER SUB, PULLED 32/64" OGLV FROM GLM #6, PULLED LGLV FROM GLM # 3 @ 8255' SLM, CaNT' ON 11-08-2001 WSR. WELL SHUT-IN, JOB IN PROGRESS. T/I/O = 300/1550/280 TIFL FAILED (DSO called); bled IA from 1550 psi to 340 psi in 2.5 hrs. InitiallA FL at 8630' (between St #4 & St #5). IA FL rose from 8630' to 3770' (inflowed 213 bbls). Shut in bleed and IA pressure increased from 340 psi to 360 psi in 30 mins. Final SI TBG pressure was 1200 psi. Well is BOL with AIL. Final WHP's = 1000/600/280 TIFL FAILED (FOR DSO) [Ann Comm, TIFL) T/I/O = 310/1580/380 IA FL at 8953' (St #6). For DSO (well slugging). RAN PPROF W/ DEFT, GLS CANCELLED DUE TO SLUGGING, TAGGED TD @1071O. SPLITS: 10684-1071417%,10668-106787%,10651-10656 41%,10632-1064235%,10512-10522 <1%. COMPLETED STATIC PRESS SURVEY, PRESS@10632= 3203.7 PSIA, @10514= 3161.3 PSIA T/I/O = 220/1560/580 OA FL at 130'. Monitor OA FL & press. Possible OA down squeeze (DHD work list). T/I/O = 260/1500/520 OA FL at 132'. T/I/O=280/1410/500 IA FL @ 8953' (OGLV). (FE). T/I/O = 280/1520/500 OA FL @ 125'. AD40: OA has remained stable for two months. T/I/O = 220/1420/420 OA FL at 130'. T/I/O=300/1400/400 OA FL @ 130'. T/I/0=300/1450/380 OA FL @ 120' (7 bbls). T/I/0=280/1460/360: OA FL @ 110' (6.5 BBLs). T/I/0=240/1560/350. OA FL @ 90'. T/I/0=280/1570/380 OA FL @ 100'. TII/O=300/1800/400 OA FL @ 100'. and appears stable. T/I/0=260/1750/400 OA FL @ 100' . OA Pressure Stable. T/I/0=300/1750/350. Monitor WHP's. OA pressure continues to remain at 350 for 3 months. T/I/0=300/1500/400, Monitor WHPs. T/I/0=250/2000/450. IA x OA PPPOT PASSED. Pressured to 2000 psi: +10 psi in 30 min. Failed 1st test [-150 psi in 15 minI. Tightened lockdown screws and gland nuts. Flushed through w/ clean hydraulic fluid and tested again. Final WHP:250/2000/450 T/I/O=280/1990/680, well on AIL. MIT-OA FAILED, The LLRT is 2.3 bpm @ 570 psi. Pumped total of 13 bbl of diesel + 8 bbls of Meth. Final Press: 280/1990/140. T/I/0=350/1700nOO, well on AIL. East of Sag Screening TIFL PASSED. The IA FL remained @ 9343'(orifice), bled IA press from 1800 to 180 psi. Completed a post-patch TIFL - PASSED. Bled IA from 1400# to 200#. IA FL @ 6890. Fluid did not move after blowing down the 9-5/8" casing. No further ACevaluation required. RU for TIFL (incomplete). IA FL @ 6890' just below orifice at 6973'. Plan to do TIFL tomorrow. T/I/O=1500/1750/350 psi. IA @ 6900'. No change since yesterday. T/I/0=1500/1750/350 psi. IA FL @ 6900'. Patch installed across Station #2 (6891 '). 11/2/91. TIFL scheduled, WL set Tbg patch. Post patch installation TIFL has been scheduled. Patch procedure has been requested from engineering. Review of recent TIFL data indicates well is capable of flow to surface via hole in Tbg @ - 10,233. Per discussion with surveillance engineering, well is anattractive sidetrack candidate. The sidetrack evaluation is continuing. At this time it is recommended to install a patch across the previously identified hole in the Tbg. Oil rate impact of 1900 bopd if well is shut-in. Completed TIFL for RWO screening purposes. Well is operating at the orifice (6900'). IA FL moved uphole 5200'(from 6900' to 1700') during the 2.5 hourtest. 9-5/8" was blown down to commonline pressure. Results under review. Reviewed recent annular communication history. Well is currently operating within the standard PBay guidelines. Source of Tbg x IA communication will not allowsustained flow to surface via the 9-518" casing at Page 5 ot6 e e Date -- 7/25/1991 7/22/1991 5/18/1991 5/16/1991 5/11/1991 5/8/1991 5/3/1991 5/2/1991 6/8/2006 .~-----~._- Comment this time. Noadditional AC eval required at this time. DS Operator to notify when well operates outside standard Prudhoe Bay guidelines. Completed TIFL to surface tank. Well is not capable of sustained flow to surface via IA at this time, Bled IA from 1680 psi to 0 psi in 3.5 hours, Fluid level moved uphole from 6891' to 492', T/I/O=(350/1600/450 psi). Completed TIFL to flowline. Initial IA FL @ 7139' (below orif @ 6891')\ IA pressure @ 1600 psi. After 7-1/2 hours, IA FL @1645'\ IA pressure @ 340 psi. Recommend using upright tank and re-testing well to atmosphere. LDL. Ran spinner/temp down tbg while pumping down 9-5/8" at 0,3 BPM at 2400 psi. Both tools located hole at 10233' in middle of joint below sliding sieve. Goodlocation to patch. No other indications of leaks. Inflatable BP in TI, Pressured tbg to 2000 psi and 9-5/8" rose to 1200. Pressured 9-5/8" to 2000 and tbg rose to 1800, Both equalized. Tbg X 9 leak both ways. No leak to formation indicated. Will run LDL. Recommend to change out #2 OGL V to dummy and run TI plug. Then rerun LDL. Ran LDL. Could not find tbg,leak while injecting down tubing. TX9 annulus pressure incr. from 200 to 875 psi in 12 minutes when annulus shutin. Tbg and annulusequalized when injection stopped. (Small leak, 0.15 BPM, was present in TX9 annulus during 5/4/91 Frac.) Small tbg. leak also appears to be present. Plan to set plugin TI and retest. Performed Tbg Injectivity test to observe IA pressure behavior during simulated frac operations, At a maximum injection pressure of 700psi, there was no evidence of Tbg x IA communication. During the tubing injectivity test, the IA pressure continued to decline. The 9- 5/8"annulus went on vacuum during the test. Per discussion with CPFIWSW, it is recommended to run a plug in the Tbg Tail and perform a combination Tbg/Casing MIT-To evaluate 9- 5/8" casing integrity. Notified unable to MIT 9-5/8" casing during frac prep operations. Page 6 of 6 TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum NO = FMC GEN 2 FMC AXELSON 70' 3100' 42 @ 6200' 10573' 8800' SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" Minimum ID = 3.0" @1 0223 5-1/2" TBG PATCH e 17-02 S OTES: ***T X IA COMM. OPERATING PRES RE OF THE 13-3/S" ANNULUS MUST NOT EXCEED 1 000 PSI (10/16/02 W AIVER)*** p 2136' H TOP OF CEMENT I )< . X 1-15-1/2" CAMCO BAL-O SSSV NIP, 10= 4.56 I X X. I 2197' X X GAS LIFT r.,1ANORELS X ST MO ND DEV TYÆ VLV LATCH PORT DATE H 2676' ---.J ~.. 1 3777 3736 14 DMY RK STRIPPED LATCH 2 6891 6029 45 MMG DOME RK 16 05/13/06 3 8272 7035 41 MMG OMY RK 0 08/30/05 4 8385 7121 41 Ml\¡1G Dlvrv RK 0 5 8840 7472 39 MMG OMY RK 0 U 6 8953 7560 38 Ml\¡1G SO RK 22 05/13/06 7 9234 7783 37 MMG OMY RK 0 8 9343 7870 37 MMG OMY RK 0 . 9 9585 8062 38 MMG OMY RK 0 10 9697 8150 38 MMG OMY RK 0 11 9977 8374 37 MMG OMY RK 0 12 10089 8465 36 MMG OMY RK 0 I I I 10197' H 5-1/2" CA MCO OB-1 SLIDING SL V I II II I 10223' 1--15-1/2" TBG PA TCH, 10 =' 3.0" (SET 11/02/91) I I 10304' H 5-1/2" BOT PBR ASSY, 10 = 4.750" I 12' al perf data Cg ~ I 10336' 1-19-5/8" X 5-1/2" BAKER SAB PKR, If):: 4.750" I z DATE .::::,. 03/28/91 06/10/81 04/29/88 I . 10390' 1-15-1/2" CAMeO LAND NIP, 10:: 4.44" I 04129188 . 04/29/88 04/29/88 04/29/88 2" H 10394' 1- '--, I 10393' 1-15-1/2" BAKER SHEAROUT SUB I I 10384" H ELMO TT LOGGBJ 09/01/80 I 11304' I 11348' I 11375' ÆRFORA 110N SUMMARY REF LOG: BHCS ON 07/31/80 ANGLE AT TOP ÆRF: 33 @ 105 Note: Refer to Production DB for historic SIZE SPF INTERVAL Opn/Sq 3-3/8" 0.2 10512 - 10522 0 4" 8 10632 - 10642 0 4" 8 10651 - 10656 0 4" 12 10668 -10678 0 4" 8 10684 - 10714 0 4" 8 10728 - 10748 0 4" 8 10764 - 10784 0 , 5-1/2" TBG-IPG, 17#, L-80, .0232 bpf, 10:: 4.89 DATE 08/05/80 10/16/02 11/16/05 04/27/06 05/03/06 05/19/06 I PBTD I 9-5/8" CSG, 47#, L-80, 10:: 8.681" REV BY COMMENTS ORIGINAL COMPLETION JRClKK WAWER SAFETY NOTE KSB/PJC GL V C/O DPS/PJC OA OOWNSQUEEZE ? / PJC OA OWN SQZ CORRECTION KSBITLH GLV C/O (05/13/06) ~ DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 17-02 ÆRMIT No: "1800700 API No: 50-029-20486-00 SEC22, 111N, R15E, 4308.55 FEL & 1317.94 FNL BP Exploration (Alaska) SCblumberger RECEIVED Alaska Data & ConSulting Services 2525 Gambel/ Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUN 0 8 2006 06/01/06 .~ ' -"1 ì (~"''' (,,-¡¡S Ccmrm . .....~I...I""'-""'>""". · '~tV"IJ"e . ." .. C;~'.h ·..r."''''-l'''':' ., '¡': ¡_ '''~~it:.' . ~~N\i; ...- NO. 3828 ¿, C;' .i (~ o Cornpany: State of Alaska Alaska Oil & Gas Cons Cornrn Attn: Helen Warrnan 333 West 7th Ave, Suite 100 Anchorage, AK 99501.,..... . (J 7 0 Field; Prudhoe Bay t ß Ó CI CD Well Job# log escríDtion ate o or I P2=Z-2 "1 ? - (j¿,A" 1113674.4 lG[S" 11/13/05 1 11'2-16 I ~ ~ - 1::J~ 1 ~058238 WFL 087fši0s- 1 P2-36 Cj'f - I G:,() N/A lDl 07/13/05 1 P2-50B ¡ '1,'\- - O~(~ N/A LOl 07/16/05 1 16-03 ¡~!-('i! 11076454 INJECTION PROFILE 07/28/05 1 1'2-36 I tí 1- - h?(:;. 11051061 GLS/lOL 06/15/05 1 4.18/5-30 ¡Lr;.:" - Ii 6 10564459 PSP GlS 04/18/03 1 1·33 B/l-24 L cr <ir - ;5 -<Ç;')_ 10889175 SCMT 10/12/04 1 04-41A c1-} -.(y,,- <) N/A lOL 07/18/05 1 15-09A C; 3 - I.~~ N/A OIL PHASE BOTTOM HOLE SAMPLE 02/02/05 1 09·17 -::t--'7- - t'.;'" í":? 11076460 INJECTION PROFilE 08/18/05 1 16-09A ICJ 1 - {),-:::' L7{ 11051089 PRODUCT/ON LOG W/OEFT 08/18/05 1 16·11 í~-"-II'Y 11058249 LOL 09/14/05 1 17-02 I Jt6 (~ - D7-Ö N/A SENSA MEMORY LOL 10/17/05 1 NI(-38A /:5(-y -fJ.:/; 10687734 MDT 02/27/05 1 R'35 ic,'~-l(r 11212863 USIT OS/26/06 1 0-o9A 1 Cie; _ 0; <, 11221576 USIT OS/27/06 1 L5-16 ; ";,C1- - n I':; . 11212864 USIT OS/28106 1 K-08A ::) ('\;~ .. ! 4r.'J 11054182 MCNL .# i:-=<,-,-/'q ~ 06/06/05 1 1 H-04A '>'..,;;¡ '- I (,r ( 10715365 MCNl #. (:~ </'7 ";> 11/27/03 1 1 - o BL e e Petro technical Data Center LR2-1 900 E. Benson Blvd. AnChorage, Alaska 99508 I' /\ ^ // ! " (Q , (/ ~v'V Alaska Data & ConSulting Services 2525 Gambell Street, Suite 400 AnChorage, AK 99503-2838 A TIN: Beth ) ) FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL Al\ID GAS CONSERVATION CO.M1tDSSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay, 17-02 Sundry Number: 306-023 ':-'{;" ",11 bn-'q~:If'11 J n ß) '11 20nt:: ,,~~..;lt,t~1 \,~~" ' , b',~N &Ii ij~..:!Jt!! c(D \~r{) or Dear Ms. Julian: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ Daniel T. Seamount Jr. Commissioner DATED this2 o day of January, 2006 Enc!. / 1. Type of Request: C/lI (---18--oç" '\ STATE OF ALASKA '\ ALA, fA OIL AND GAS CONSERVATION COMMI..... _, ,bN APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development ~ RE~V~fr°(ø .IAN 1 R 2006 Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Suspend U Repair well 0 ./ Pull Tubing D Perforate U ^Iosko QjL1~ Cons. co.~ Stimulate D Time Extensio~~horage Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 180-0700 .,./ Stratigraphic 0 Service 0 6. API Number: 50-029-20486-00-00 ./ 9. Well Name and Number: 70 KB 17 -02 ,/ 8. Property Designation: ADL-028331 11. Total Depth MD (ft): 11375 Total Depth TVD (ft): 9567 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11304 9504.42 None Junk (measured): None Collapse 520 2670 4760 Casing Length Size MD / TVD Burst Conductor 80 20" 94# H-40 30 11 0 30 110 1530 Surface 2647 13-3/8" 72# L-80 29 2676 29 2676 4930 Production 11320 9-5/8" 47# L-80 28 11348 28 9543 6870 Perforation Depth MD (ft): 10512 - 10784 ~ Perforation Depth TVD (ft): 8818.33 - 9050.5 Tubing Size: 5-1/2" 17# / Tubing Grade: L-80 Tubing MD (ft): 26 - 10394 Packers and SSSV Type: 5-1/2" BOT PBR Assembly 5-1/2" Baker SAB Packer Packers and SSSV MD (ft): 10304 10336 ,,/ 12. Attachments: Descriptive SummaryofProposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for r7- Commencing Operations: 1/27 006 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify thaÌìhe foregoing is true and correct to the best of my knowledge. Printed Na~ JennNr Julian Title Wells Engineer Signature \.'C' ". ~ . ~(. ~ Phone 564-5663 ~ ~ COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory 0 Development ~ / Service 0 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Contact Prepared by Sharmaine Vestal 564-4424 Jennifer Julian Date 1/13/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number::3()U - Od3 Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: RBDMS BFl JAN 1 9 2006 Subsequent Form Required: \ 0 - 4- 0 4 Approved by: Orf~j,,.,~~ ~.....~" ~ ~ t,,;,"" ""...J .;)~:¡I,G.",. c,;)] D,;'\~ j S2;i~J\QOUNT COMMISSIONER APPROVED BY THE COMMISSION Date: ,~~O ~OLQ Form 10-403 Revised 7/2005 OR'G\{'~AL Submit in Duplicate brJ "-~·_'·ø- . . .. ... ø. .'. -".,-- ) ) To: J. Bixbyl D. Cismoski Well Operations Team Leader Date: January 11, 2006 From: Janet Sack, Design Engineer July 5, 2005 Revised by Jessica Pedota, January 11,2006 Subject: 17-02 OA Cement DownsQueeze Procedure PBD17WL02-N Est. Cost: $22M lOR: 400 BOPD Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 DHD Depress OA FL wI AL / 2 F OA cement downsqueeze 3 F MIT OA cement downsqueeze 2400 after WOC /'" 4 WAV Write up Waiver for TxlA 17-02 is a PAL with T x IA communication. On 06/21/05, this well failed an MITOA and the waiver for T x IA communication was canceled on 06/27/05. The T x IA was not fixed with extended packing in the leaking GL V and the caliper does not look promising for a TxlA repair. MIT-OA failed on 12/29/05 with a LLR of 2.2 bpm at 920 psi. An OA downsqueeze is recommended so a waiver can be pursued. A waiver will require /'"~. annual testing of the production casing as the primary barrier (CMIT-TxIA passed to 3000 psi on 12/15/05) and surface casing as the secondary barrier surface casing. This program is designed to depress FL wI AL to determine leak depth. Following the fluid depress, pump a column of cement from the shoe to approximately 500' above the shoe. 4.0 5.0 The procedure includes the following major steps: 1. DHD Depress OA FL wI AL. 2. DHD Shoot fluid levels and record WHP's. 3. DHD Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. OA Downsqueeze M IT OA after waiting on cement. ../ If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (W), 274-0929 (H), or 240-8037 (C). cc: w/a: Well File ) ) JOB PLANNING DETAILS: 12/12/2005: MIT-OA failed with a LLR of 2.2 bpm at 920 psi. Well has TxlA communication. OA= 13-3/8" 72# L-80 IA= 9-5/8" 47# L-80 Shoe at 2676' OAxlA Annular Capacity=.0581 bbls/ft Volume to shoe = 156 bbls 500' of cement = 29 bbls Displacement= 156 -5 (H?O spacer) - 29 (cement) - 5 (H20 flush) = 117 bbls Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 400 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 117 bbls at 30-60 degree F .-/ Crude: (volume needed to load OA) DSCW101: 10bbls Arctic Set 1 Cement (15.7 ppg): 29 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): DHD/FB: 1. Depress OA FL w/ AL. 2. Shoot FLs and record WHPs. 3. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. 4. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping 1. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 2. If well has IA x OA communication (well has not shown this communication to date), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a LRS or pump. ) ) 3. Flood lines with warm fresh water and pressure test lines to 3000 psi. 4. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent /" times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW101 surfactant (optional) c. -250 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 29 barrels of 15.7 ppg Arctic Set 1 cement f. 5 bbls of ~Sh water flush g. 117 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 1 07 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 5. Shut down pumps and leave the well SI. Please DO NOT try to achieve a /' SQueeze or to build SQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 6. Notify the Pad Operator prior to leaving location that the OA may be subject to /' rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post SQueeze: FB: 7. MIT-OA to 2400 psi. 8. Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. TREE = WELLHEAD = ACTUATOR = ELEV = BF. ELEV = KOP= .~,~_~ Angle = Datum MD = Datum TVD = FMC GEN 2 FMC AXELSON 70' ) -----.----.- 3100' 42 @ 6200' 10573' 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2676' Minimum ID = 3.0" @1 0223' 5-1/2" TBG PATCH PERFORA TION SUMMARY REF LOG: BHCS ON 07/31/80 ANGLE AT TOP PERF: 33 @ 10512' Note: Refer to Production DB 'for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 0.2 10512-10522 0 03/28/91 4" 8 10632-10642 0 06/10/81 4" 8 1 0651-1 0656 0 04/29/88 4" 12 10668-10678 0 04/29/88 4" 8 10684-10714 0 04/29/88 4" 8 10728-10748 0 04/29/88 4" 8 10764-10784 0 04/29/88 ~ 17 -02 o L I I ..... '" z :8: I I 5-1/2" TBG-IPC, 17#, L-80, 0,0232 bpf, 10 = 4,892" 1-1 10394' r--~ DA TE REV BY COMMENTS 08/30/05 DTRlPJC GL V C/O 11/16/05 KSB/PJC GL V C/O I PBTD 1-1 11304' 9-5/8" CSG, 47#. L-80, 10 = 8.681" 1-1 11348' ~-1 11375' DATE 08/05/80 11/30/00 02/27/01 07/14/01 10/16/02 REV BY COMMENTS ORIGINAL COMPLETION SIS-MWH CONVERTED TO CANVAS SIS-LG FINAL RN/TP CORRECTIONS JRC/KK WAIVER SAFETY NOTE .. SAÆ, hTES: ***T X IA COMM. OPERATING PRESSURE OFTHE 13-3/8" ANNULUS MUST NOT EXCEED 1000 PSI (10/16/02 W AIVER)*** 2197' 1-1 5-1/2" CAMCO BAL-O SSSV NIP, 10= 4.56 IlL GAS LIFT MANDRELS ST MD TVD DE\! TYPE I VLV I LATCH PORT DATE 1 3777 3736 14 RK HAS BROKEN LA TCH 2 6891 6029 45 MMG DMY RK 0 08/30/05 3 8272 7035 41 MMG DMY RK 0 08/30/05 4 8385 7121 41 MMG DMY RK 0 5 8840 7472 39 MMG DMY RK 0 6 8953 7560 38 MMG kDMY RK 0 11/16/05 7 9234 7783 37 MMG DMY RK 0 8 9343 7870 37 MMG DMY RK 0 9 9585 8062 38 MMG DMY RK 0 10 9697 8150 38 MMG OMY RK 0 11 9977 8374 37 MMG DMY RK 0 12 10089 8465 36 MMG RKED RKP " EXTENDED PA CKING 10197' 1-1 5-1/2" CAMCO DB-1 SLIDING SLvl 10223' 1-1 5-1/2" TBG PATCH, 10 = 3.0" (SET 11/02/91) 10304' 1-1 5-1/2" BOT PBRASSY, 10 = 4,750" I 10336' 1-1 9-5/8" X 5-1/2" BAKER SAB PKR, 10 = 4,750" I 10390' l-l 5-1/2" CAMCO LAND NIP, 10 = 4.44" 10393' 1--1 5-1/2" BAKER SHEAROUT SUB 10384" 1-1 ELMD TT LOGGED 09/01/80 PRUDHOE BA Y UNIT WELL: 17-02 PERMIT No: 1':1800700 API No: 50-029-20486-00 SEC 22, TI1N, R15E, 4308.55 FEL & 1317.94 FNL BP Exploration (Alaska) · (( ~~. 'í? /8 \ rc;r:»t. i ¡.~ '\ . I ¡, I- ~ ~ ¡ I ¡ f I ( [ ) u/j(·J i-6 ) mll ~ . \ ii Æ!:· '(~ í~// . Ii! I ! 8/, 'I. ¡ !. "ð! 1 I, i\ U Ii' / /8i ~ : I r I ,,I,., r ,1\ 'Ie'il' ,!II !' ,i I' \ . . ' ". i· ~! \ \.llJ i: I/~ lb~ ® U' /Fù ) AlASKA OIL AM) GAS CONSERVATION COMMISSION / / FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 l~Ó -'ffr* {J Re: Prudhoe Bay 17-02 Sundry Number: 305-191 SCANNED JUt. 2. 0 2005 Dear Ms. Julian: 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. Please provide at least twenty-four (24) hours 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 follow' the date of this letter, or the next working day if the 23rd day falls a/holiday or weekend. A person may not appeal a Commission de cis: n t Superior Court unless rehearing has been requested. DATED this/~ay of July, 2005 Encl. ) ) July 13, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RECEIVED JUL 1 3 2005 Alaska Oil & Gas Cons. Commission Anchorage RE: Sundry Notice for 17-02 OA Downsqueeze BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain a production waiver for well 17-02. Step 1 2 3 Type DHD F F P roced u re Depress OA FL w/ AL OA cement down squeeze /" MIT OA cement downsqueeze after WOC ~ Well, 17-02 is a PAL with TxlA communication. On 06/21/05 it failed an MITOA to 2400 psi with a LLR of 1 bbls. @ 1100 psi. The waiver for TxlA communication was canceled on 06/27/05. /' The procedure includes the following major steps: 1. DHD 2. DHD 3. DHD 4. 0 5. 0 Depress OA FL w/ AL. Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. OA Downsqueeze , MIT OA after waiting on cement. /' This program is designed to depress FL w/ AL to determine leak depth. Following this, pump a column of cement from the shoe to approximately 500' above the shoe. Please contact Jennifer Julian at 564-5663 (H) 274-0929, (Cell) 240-8037 with any questions. Sincerely, <2Q;~~~ (¡nnifer Julian Wells Engineer ORIG!NAL 7f ~tt 1/t4-1 u't OZ:;7-'~~(-f' RECE\Vt ) STATE OF ALASKA) 7..005 ALASKA 'OIL AND GAS CONSERVATION COMMISSION JUL 13 APPLICATION FOR SUNDRY APPIiW~as Cons. Commission 20 AAC 25.280 Anchotage Stratigraphic D Service D 9. Well Name and Number: 17-02 / 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11304 9434.4 Size MD TVD 1. Type of Request: Abandon D Suspend D Alter Casing D Repair Well I!I Change Approved Program D Pull Tubing D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 70.00 KB 8. Property Designation: ADL-028331 11. Present Total Depth MD (ft): 11375 Casing Total Depth TVD (ft): 9567.0 Length CONDUCTOR SURFACE PRODUCTION 80 2647 11320 20" 94# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 /' Perforation Depth TVD (ft): 8818 - 8827.0 8920 - 8928.7 8936 - 8940.6 8951 - 8959.4 8965 - 8990.3 9002 - 9019.5 9033 - 9050.5 Perforation Depth MD (ft): 10512 - 10522 10632 10642 10651 10656 10668 10678 10684 10714 10728 10748 10764 10784 Packers and SSSV Type: 5-1/2" BOT PBR Assembly 5-1/2" Baker SAB Packer 5-1/2" Cameo BAL-O SSV Nipple 12. Attachments: Description Summary of Proposal ŒJ Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: July 27, 2005 Date: / Operation Shutdown Plug Perforations Perforate New Pool 4. Current Well Class: D D D Other D PerforateD Waiver D StimulateD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 180-0700 . /' / Development Œ] Exploratory D 6. API Number / 50-029-20486-00-00 Plugs (md): None Burst Junk (md): None Collapse top 30 29 28 bottom top 110 30.0 2676 29.0 11348 28.0 bottom 110.0 2675.7 9543.2 520 2670 4760 1530 4930 6870 Tubing Size: 5-1/2" 5-1/2" Tubing Grade: Tubing MD (ft): 17 # L-80 IPC 26 Patch 10223 10394 10248 Packers and SSSV MD (ft): 10304 10336 2197 13. Well Class after proposed work: Exploratory D DevelopmentŒ] 15. Well Status after proposed work: Oil ŒJ / GasD PluggedD WAG D GINJD /' Service D Abandoned D 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Jennifer Julian Printed Name Signature (\ Jennifc:r .JUlifffi\~ ~ OJV'\/'Yw p \.., C V Title Phone Wells Engineer 564-5663 7/13/05 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Ie - 404 · FL Sundry Number: .3t;:s- "'f f I Mechanciallntegrity Test ~ Location Clearance D OR\G\NAL RBDMS BFL .ILJL 1 9 701:05 / BY ORDER OF THE COMMISSION Date: 1þb5 SUBMIT IN DuL~:TE ) " TREE = WELLHEAD = 'ÄCTÜÄi'ÖR';' kä~EiE\i;;;" BF. a.EV = KOP = 3100' rv'ax Angle = 42 @ 6200' 'õatuñî"Mõ-;;;"'-"'W~'^""^-1"Õ573;' ''ì5àiUmTvÖ-;''W^'^^ssô6ì§,s FMC G8\J 2 FMC AxËLšON .. ·····""70; 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2676' ~ Minimum ID = 3.0" @1 02231 5-1/2" TBG PATCH PERFORATION SUMMARY REF LOG: BHCS ON 07/31/80 ANGLEATTOP ÆRF: 33 @ 10512' I\bte: Refer to Production DB for historical perf data SIZ E SPF INTER\! AL Opn/Sqz DA TE 3-3/8" 0.2 10512-10522 0 03/28/91 4" 8 1 0632-1 0642 0 06/10/81 4" 8 10651-10656 0 04/29/88 4" 12 10668-10678 0 04/29/88 4" 8 10684-10714 0 04/29/88 4" 8 10728-10748 0 04/29/88 4" 8 10764-10784 0 04/29/88 17-02 f) L I I II ..' ) /' SAFETY NOTES:***T X IACOMM. OPERATING PRESSURE OF THE 13-3/8" ANNULUS MUST NOT EXCEED 1000 PSI (10/16102 W AlVER)*** 2197 1-1 5-1/2" CAI\ICO BAL-O SSSV NIP, ID= 4.56 GAS LIFT MANDRa.S STA MD lVD DEV TYÆ LATCH VLV ~ 1 3777 3736 14 Mtv1G RK 2 6891 6029 45 Mtv1G RK 3 8272 7035 41 Mtv1G RK 4 8385 7121 41 Mtv1G RK 5 8840 7472 39 Mtv1G RK 6 8953 7560 38 Mtv1G RK 7 9234 7783 37 Mtv1G RK 8 9343 7870 37 Mtv1G RK 9 9585 8062 38 Mtv1G RK 10 9697 8150 38 Mtv1G RK 11 9977 8374 37 Mtv1G RK 12 10089 8465 36 Mtv1G RKP 10197 1-1 5-1/2" CAI\ICO DB-1 SLIDING SLvl 10223' l-i 5-1/2" lBG PA TCH, 10 = 3.0" (SEr 11/02/91) 10304' 1-1 5-1/2" BOT FBRASSY, ID= 4.750" 1 z ~ 10336' 1-1 9-5/8" X 5-1/2" BAKERSAB FKR, ID =4.750" 1 I . 1 10390' 1-1 5-1/2" CAMCO LAND NP, ID = 4.44" 5-1/2" lBG-IPC, 17#, L-80, 0.0232 bpf, ID=4.892" 1-1 10394' ~ 1 PBTD 1-1 11304' 9-5/8" CSG, 47#, L-80, D = 8.681" 1-1 11348' [lQ]-I 11375' DA lE REV BY CO Mv18\JTS 08105/80 ORlGINA L COMPLETON 11/30/00 SIS-MWI- CONVERlEDTO CAN\! AS 02/27/01 SIS-LG FINAL 07/14/01 RN/lP CORRECTIONS 10/16/02 JRC/KK WArvER SAFETY NOTE J I( x x ..x .- .. -II( [ p; I DA TE REV BY COMtvENTS 10393' 10384" 5-1/2" BAKER SHEAROUT SLE a.MD TT LOGGED 09/01/80 PRLDI-DE BAY lJ'J1T WELL: 17-02 PERMIT' I\b: 1800700 AR No: 50-029-20486-00 SEC 22, TtI N, R15E, 4308.55 Fa. & 1317,94 FNL BP Exploration (Alaska) FW: 17-02 Cancel waiver , Subject: FW: 17-02 Cancel waiver From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 26 Jun 2005 16:28:44-0800 To.: "Rossberg,R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Phillips, Patti J" <phillpj l@BP.com>, jin1_regg@admin.state.ak.us, winton_aubert@admin.state.ak.us, "GPB, FS2/COTU Area Mgr" <GPBFS2TL@HP~com>,."GPB, Wells Opt Eng~'.<GPBWel1s0ptEng@BP.com>, "OPB, Optimization Engr" <GPBOptimizationEngr@BP~cQm>, "OPB, FS2 DS·Ops Lead" <GPBFS2DSOpsLead@BP.com> cc: "Dube, Anna T" <Anna.Dube@BP.com>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com>, "Holt, Ryan P (VECO)"<Ryan.Ho1t@BP.com>, "Mielke, Robert L." <robert.mielke@BP.com> ) PTty#- (C(;o -~~t Hello all. Well 17 -02 failed recent waiver compliance testing. The well has been 81 and classified as a Trouble well. We're working with the Anchorage PE to evaluate remediation options. Please call if you have any questions. Joe 1-907-659-51 02 From: Holt, Ryan P (VECO) Sent: Sunday, June 26, 2005 3:52 PM "' To: NSU, ADW Well Integrity Engineer SCANNED JUL 2 220m) Subject: 17-02 Cancel waiver t ~:(I~()7:Ð Hello Joe, Well 17-02 has been classified as a Trouble well and the waiver has been canceled. 17-02 recently failed a MIT-OA for waiver compliance and will either need TxlA communication repaired or a OA downsqueeze I passing MIT-OA and a new waiver issued. Please contact Joe Anders or Donald Reeves at x51 02 with any questions. Ryan .Holt Well Integrity Tech. Pager 4236-786 Office 659-5524 l-ô,t ~lcA~t-~ R.¿cûv~ PvhlL~~ f-h s~~~ ~~yt,*,~\ ùK. (!?!:>I) Gc<s (J..{cF.) Mtt....¡ ?iJ)ç ,~f) l õ-'~ç /~kv-c '" Vb ç 11,(,30 L(D3Z, , z~ ò ~ q 2,,=- I I 7 (., '3b¡ (;["0 2. (M;;..\...Ì€r- (.h.b \ ) C¡z- 5"70 I 10, ~t¿ 7 10(, Cf31 / ])C1 ~ 3( ]0 13¡qq4 3\ 1 of 1 ~~1~ 7(1~'DS- 7/13/20059:51 AM t /$oo?oo MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~t~ DATE: Commissioner December 15, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 17 Friday, December 15~ 2000: I traveled to BPX's Drill Site 17 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 15 wells and 30 components with one failure. The Surface Safety Valve on Well 17-4 Failed to close on its initial test. After this valve was serviced and the hyd lines flushed it operated properly and passed the retest. Mark Womble performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the wellhouses on this location while witnessing SVS tests. All the wellhouses and associated equipment appeared clean and in good condition Summary: I witnessed SVS testing at BPX's PBU Drill Site 17. PBU DS17, 15 wells 30 components 1 failure 3.3% failure rate 19 Wellhouse inspections Attachment: SVS PBU DS17 12-15-00 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential ( Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ,BPX Operator Rep: Mark Womble AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / DS 17 Separator psi: LPS 165 Date: 12/15/00 lIPS Well Permit Separ Set L~ Test Test Tat Date Oil, WAG, G~J, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE 17-01 1800550 165: 150 130 P P 17-02 ~~00 165 150 100 P P 17-03A 1972160 165 150 110 P P 17-04A 1960500 165 150 120 P 5 12/15/00 17-05 1800960 165 150 110 P P 17-06 1801320 17-07 1810660 165 150 140 P P 17-08 18107401 17-09 1810900 165 156 100 P P 17-10A 1991100 17-11 1842440 165 150 120 P P 17-12 1842450 165 150 120 P P 17-13 1841790 165 15~ 110 P P 17-14 1841660 165 150 140 P P OIL 17-15A 1991310 17-16 1920910 165 1501 130 P P 17-19A 1970550 165 150 130 P P OIL 17-20 1921150 165 150 120 P P ,,,, 17-21 1921250 165 150 130 P P Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.3% fflgo var Remarks: Surface Safety on 17-4 failed to close, it was serviced and retested. 12/19/00 Page 1 of 1 SVS PBU DS17 12-15-00 CS.xls GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 9174 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/5/95 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar Floppy Disk D.S. 3-13 -7 ~7/ INJEC PROFILE (12-4-94) 1 1 ~'1 D.S. 3-14 '7C/~ ~-- BACK-OFF RECORD (12-3-94) 1 1 ID.S. 9-5A ~~C~ STATIC BHP SURVEY (12-9-94) - 1 1 D.S. 11-24A c~ .~-':~2-O(-~ PROD PROFILE (12-6-94) I .1 D.S. 14-9B ~1~:~--'~ O~L~ PROD PROFILE (12-8-94) I 1 D.S. 14-24 "~..,"~- ~C~ PERF RECORD (12-6-94) I 1 D.S. 14-35 · <~'~--I L~.~. PROD PROFILE (12-7'94) 1 1 D.S. 16-20 ~ "~"'---~-~.- ~'- PROD PROFILE (12-6-94) I 1 D.S. 17-2 ~" C~ (~ STATIC BH PRESS SURVEY (12-10-94) I 1 , Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE:~ 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 j 1-06 1-11 1-25 1-29 1-30 3-02 3-19 4-36 4-41 5-11 9-15 9-18 9-25 11-35 11-36 13-31 13-35 14-03 14-03 16-23 16-23 17-02 18-02 18-04 18-19 Log Date (M-D-Y) 6-13-94 6-13-94 6-14-94 6-10-94 I / Perf Record ' 6-14-94 i"" Bual Burst 6-08-94 j/ CNL 6-07-94 ix Tubing Cutter 6-05-94 i/ Perf Record 6-11-94 !" Perf Record 6-12-94 ,,/Cutter Record 6-11-94 ~' Dual Burst 6-13-94 / Inj Pmf 6-14-94 ,/ Inj Pmf · / inj Pmf / Perf Record 6-14-94 6-11-94 6-07-94 6-09 -94 6-09-94 6-15-94 6-15-94 6-13-94 6-10-94 6-6-94 6-12-94 6-12-94 6-10-94 Tool Type j Run,~ I Contractor Scale Dual Burst { 1, 5" Sch Dual Burst ! 1, 5" Sch Perf Record [ 1 5" .,,, ~' Perf Record ~' Perf Record /" Perf ReFord f Prod Log Dual Burst Leak Detection 'J Alpha Tubing f Prod Pmf / Perf Record ~ Dual Burst 1 5" I 5" 1 5" 1 5" 1 5" 1 5" I 5" 1,5" 1 5" 1 5" I 5" I 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1&5" 1, 5" 1, 5" .-'Leak Detection j 1, 1" & 5" Sch ISch Sch Sch , Sch I Sch Sch ' Sch Sch Sch Sch Sch .., Sch I Sch Sch , Sch Sch Sch Sch Sch Sch Sch Sch i * The correct APl # 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 AlasKa, Inc. I$ a Sul~sldlary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage. Alaska 99510 DATE: 11-3-92 REFERENCE: ARCO CASED HOLE FINALS 10-3-92 Prod Profile Run 1. ~' Camco 9-28-02 Leak Detect (Flexstak) Run 1. [~' Camco 9-14-92 InJ Profile Run 1. [~' Camco 9-20-02 InJ Profile Run 1. [~' Camco 10-2-02 Prod-InJ (Flexstak) Run 1. [~' Camco 9-19-92 Leak D~tect Run 1, 8~' Camco 9-26-92 GR/Collar Run 1, [~' Camco 9-27-92 GR/Collar Run 1, [~' Camco 9-25-92 Prod Profile Run 1. [~' Camco 9-14-92 Prod Profile Run 1, [~' Camco 10-2-92 InJ Profile Run 1, 8~' Camco 9-4-92 Prod Profile Run 1. [~' Camco 10-4-92 InJ Profile Run 1, [~' Camco 9-26-92 Prod Profile Run 1, ~' Camco 9-26-92 GR/Collar Run 1. [~' Camco 10-5-92 InJ Profile/PITS Run 1, [~' Camco 0-27-92 InJ Proffie Run 1, ~' Camco 9-19-02 Leak I~tect Run 1, [~' Camco 0-27-02 Prod Profile Run 1, [~' Camco 10-4-92 InJ/Shut-ln Temp Run 1, [~' Camco 10-2-92 InJ Profile Run 1. [~' Camco 10-3-92 InJ Profile (Flexstak) Run 1, ~' Camco 10-1-03 , InJ Profile Run 1, [~' Camco 9-15-02 InJ PrOfile Run 1, [~' Camco 9-17-92 Prod Profile (Flexstak) Run 1. [~' Camco 10-1-92 Prod Profile Run 1. [~' Camco 9-28-92 GR/Collar Run 1, [~' Camco 9-28-92 Prod Profile Run 1, [~' Camco 9-15-92 Prod Profile Run 1, ~' Camco 10-1-92 Prod Profile Run 1, [~' Camco Please sign and returnee at~~ copy as receipt of CEIVED // ~ / ~ .... ,A/as,"- &1993 ~ve A Nice ~I / ~ Oil Gas Cons. Commission ~n~ W~ce APPROVED ,~ AT0-1529 ~s~ ~224~-~ ..... # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL FILES # BPX # STATE OF ALAS~ ARCO ALASKA, INC. F'.O. BOX t00360 ANCHORAGE, ALASKA DATE t2-3t-91 REI--ERENCE' ARCO CASED HOLE FINALS t~-28 t-tt-~ ~ LEAK Q~rECT 4-3 ~-~-9~ ~ PROD PROFILE 4-~4 ~-3~-9~ ~ LEAK DETECT 4-~4 ~-8-9~ LEAK ~ETECT ~~ 4-27 ~-~-9~ ~ INJ PROFILE 5-~ ~, ~e-~-~ ~ P~o~ P~OF~LE ~7-2 ~ ~-2-9~ ~ CCL TIE-IN TUBING PATCH RUN t, RUN t, 5' RUN RUN t, 2"&5" RUN t, 5" RUN ~, 5' RUN RUN RUN t, 2' RUN RUN PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA. RECEIVED BY ____~__ __~_' HAVE A NICE DAY! $ONYA WALLACE AT0-1529 AF'F'NUVED ~_~~ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO _, I--I ~"1 L. LJ Cr-.irlL 0 CAr'iL, O CAMCO CAF~CO DISTRIBUTION $ CENi-K'AL P/LES $ CHEVRON D & M T~ EXI'EN$ION EXPL. ORATION · ' EXXON MARATHON · ..'"' MOBIL PHILLIPS F'B WELL FILE"' R & D BF'X STATE OF ALASKA TEXACO * THE CORRECT API~ FOR t7-2 I$ 5~-029-28486~ RECEIVED ,JAN 1 0 199~ Alaska Oil & G~s Cons. Commission Anchorage 1. Operations performed: operat~n shutdown Stimulate ~ PluggIng ---- Pull ruling Alter casIng Repair well STATE OF ALASKA ALASKA( '_ AND GAS CONSERVATION C(][r ,41SSION REPORT 'UF SUNDRY WELL OPERATIC[ ...I Perforate 5. Type of Well Development X~ Explorat~'y -- Stratigraphy= 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2722' FNL, 499' FWL, Sec. 22, T11N, R15E, UM At top of productive interval 1505' FNL, 1289' FWL, Sec. 21, T11N, R15E, UM At effective depth At total depth 1323' FNL, 965' FWL, Sec. 21, T11N, R15E, UM 11375 feet Plugs(measured) 9566 feet 12. Present well condition summary Total depth: measured true vertical Olher X 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property PnJdhoe Bay Unit 8. Well number 17-2 9. Permit number/approval number 80-70 ,, 10. APl number 50 - 029-2O486 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured true vertical 11304 feet 9503 feet Junk(measured) Casing Length Conductor 110' Surface 2608' Production 11278' Size Cemented Measured depth True vertical depth 20: 250 sx PF II 110' 110' 13-3/8" 1908 sx Fondu 8, 400 sx PF ii 2678' 2678' 9-5/8" 1300 sx Cl "G" 11348' 9542' Perforation depth: measured 10512-10522'; 10632-10642'; 10651-10656'; 10668-10678'; 10684-10714'; 10728-10748'; 10764-10784' true vertical 8817-8826'; 8919-8927'; 8935-8939'; 8949-8958'; 8963-8989'; 9002-9010'; 9033-9050' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 10394' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 10336' MD; 5-1/2", 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. 14. N OV 2 5 1991 Alaska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3046 5117 2869 -- 327 Subsequent to operation 2898 4576 6864 -- 330 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~.. Oil ~ Gas m Suspended Service , , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic, lned Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 778/6 MRM/SLW cc: SW, JWP SUBMIT IN DUPLICATE ( 17-02 ( DESCRIPTION OF WORK COMPLETED PERFORATING, FRACTURE TREATMENT OF SAG/Z4, & TUBING PATCH INSTALLATION 3/28191: Added perforations: 10512 - 105PP' MD (Sag) Ref. Log: BHCS 7/31/80. 4125/91: RIH w/CT to tag bottom & pumped 105 bbls of gelled sand slurry, containing a total of 12400 lbs of 20/40 mesh sand, 1600 lbs of 100 mesh sand, & 1600 lbs of silica flour, to place a pre-frac sand 4126191: RIH & tagged top of the sand plug at 10772' MD. 4128/91: RIH w/CT & pumped additional gelled sand slurry, containing a total of 3000 lbs of 20/40 mesh sand, and 200 lbs of 100 mesh sand, to raise the top of the sand plug. Perforation intervals partly covered or isolated by the sand plug, located at: 10684 - 10714' MD (Z4) 10728 - 10748' MD (Z4) 10764 - 10784' MD (Z4) Ref. Log: BHCS 7/31/80. 4/29/91: RIH & tagged top of the sand plug at 10703' MD. 514191: MIRU & PT equipment to 9400 psi. Pumped a Hydraulic Fracture Treatment, using 12/18 mesh proppant, through the open perforations located above the sand plug at: 10512 - 10522' MD (Sag) 10632 - 10642' MD (Z4) 10651 - 10656' MD (Z4) 10668 - 10678' MD (Z4) 10684 - 10714' MD (Z4: Ref. Log: BHCS 7/31/80. partly covered w/sand) Pumped: a) 281 bbls 50# Pre Pad followed by b) Shutdown. ISIP @ 2020. Resumed pumping: c) 2470 bbls 50# Crosslinked Pad, @ 56 bpm, followed by d) 1292 bbls Cross Linked Slurry, w/proppant concentrations @ 2 - 12 ppg, followed by e) 247 bbls Flush, followed by f) Shutdown. Placed a total of 312,900 lbs of proppant into the formation. 713191: Performed wellbore proppant fill cleanout to 10850' MD. 1015191: Pumped scale inhibition treatment. 1112191: Rigged down. Flowed well. RECEIVED N OV 2 5 1991 Alaska 0il & Gas Cons. C0mmissio~ Anchorage RIH w/3.00" ID tubing patch & set patch at 10226 - 10247' MD (seal to seal), across hole located at +/- 10235' MD. Rigged down. Placed well on production & obtained a valid production test. ARCO ALASKA, INC. P.O. BOX tOOSSO- ANCHORAGE, ALASKA 995t0 DATE: REFER'ENCE · - - t3-2A-- i4-t7 -t 4-2t 6-t 3-9~ ARCO CASED HOLE FINALS 6-i-9i COLLAR-F'ERF 6-2-91 ..... COLLAR-PER~-- ...... 5-i6-9i ~' INJ PROF. 5-t6-9t -,----INJ PROF'. 4-25 5-t 6-9 4-~6 .... 5-t6-9 5-f5 5-i ?-9 6--~-t -- -5-23-9 6-00 5-23-9 6-24--- 5-~ 9-9 7-.2 -- 5-8-9t 7---2 -5.-- ~ 8-9 7.-f t ' 5-27-? JUN 1 1 19-91 - ~ '-:.~- .......... Alaska 0il & Gas Cans. Commission - - An~horalte RUN ~ o 5; · ATLAS INJ PROF-GR'. -~-ZNJ_PROF-- PROD PROF ...... INJ PROF, .......... PROD F'ROF PROD F'RO~-- ~'.LEAK DETEL~I'.~' ,. t-,~,~-LEAK--DE~EC~J~Z~.- LEAK DETECT'" PLEASE SIGN AND RETURN THE ATTACHED COF'~ RECEIVED BY ~__~~~~- - -i-. ---RUN -t, -5"- - A:fLA$ ' ;??" RUN t , 5 · CAMCO ............. RUN--t , -5' ......... CAMCO -~.- RUN t , 5 · CAMCO RUN -t ~ -5" ..... -CAMCO - ~ ' RUN t~ ~ ~ CAMCO .............. RUN t , - 5' .CAMCO RUN t, 5 ~ CA~CO -RUN .-t ~ . -.~.~.':-~'~-' RUN t ,'; 2" ":'; :;' ~:,/~CAMCO ?;:.' . RUN i ,- 5" .... '~':~ ..... ~;. .:.RUN -t ,_5 ~.:]~Z'~-~CAMCO . . .~ 7'Z? RUN t ,. 5" 'TZt~]~;'CAHCO OF DATA. ;.,~,.., ? . AS RECEIPT HAVE A NICE DAY.. ....... DIStRIBUtION ........ '~ ....- . ..... , ~ . CENTRAL--EILES ........ ~ PHILLIP~ ' ' - _ CHEVRON PB WELL'FILES D&M .......................... R&D EXTENSION EXPLORATION ~ ~ BF'X EXXON ' --,-~ ~ $1'ATE.~.ALASKA- MARATHON TEXACO MOBIL / 991 c.~Cons.. . . __ ge Commission ;~NCHORACE, HL.H$1<A DATE. 4- 4-9t RI£FERENCE' FtRCO CASED HOLE FINALS' I --.S, 1,.,- '~ '_,z--90 F'ERF RECORD t -5 I 2-I 6-90 F'ERF RIECOF,.'D 2- t 3 t 0- 2-,;-90 r'EF,:F R. ECORD 7.~-,~ 3 -3 t -9 t Ct)L.L. AR/F'IEI-~F Z,- ":: 3-- 30-9 t t..OL. LAR/F'E-F,:F ,.'l - ¥ 3 -29--9 i L.t)k L A R / I-' E I.< F -z, -:'2 3 ','--91 L. OI.I.dR/F'F...RF 3-25 .'l- ,'iu--9i - COLLAF,:/F-'EF(F . , " , ¢~ _. C/ , .,, .',c, .~ , ,.. , t COL..LAF~/I E.F:F · ! ' ', # "1 ~' 5~---5 I ,,¢-2 ;-. 9¢,~ PI:.~F<F RECUI-,D t I .-28 t 0 .8-.90 ~"E'RF' RFi:COr<D t 2-t t 2-29-.9~...) F'I::.I-,'F F,~[...COI;,'D t 2-31 i 'i .. 28-90 I-"I:i.F;,'F RECORD J :~;.-~ .4 t 0 -25--90 F'ERI:" RECORD t 4--3~ -:- ~,-o,~ I:-' I:.- I:,,' F "" !:,, E:. C 0 R D I 5-4 t 2-2-90 GAMMA RAY i 5-4 J 2-2-90 PI:...RF F<rr. CORD JS-JJ ~0..-25-9() PERK RECORD 'i 5-2J J ~,-')-'>9-9e I-I:.:.F,,F RECORD 'i 6-9 3-2 7--9 'i. CC[. - ........ ~ ?-2 3-28-9i COLLAR/F'ERF - I<UN I-,' U N RI.IN RUN I..,' L~ r,J I,'lJN I<lJN r.'L~iJ RUN I',.' ~J N RUN I,:tJN RUN r<UN RUN F<UN -- RUN RUN - RUN RUN F'I_EASE ,;I(;N AND I,,'ETURN YHE A¥'rACHED COF'¥ AS RECEIPT I,.I':.CEIVED BY _ IIAVE A NICE DAY! .... AF'F'ROV~ [RAN&' ;'S'HARON WILSON AT0-t529 .~:,,,~ D~IRIBUTION .......... ........ -- ~ EXTENSION EXF~LORATION - ~ EXXON UF DA1 A, · "' F'FIiLLI F'S F'B ~ELL EILES R&D , ~-.. BF'X RECEIVED ~ STALE OF ALASKA,'APR 9 1~/! MARATHON ........................... :i:EXACO , _ ...... Alaska Oil & ~as Cons COt.mission M o rJ I L ., Anchota9e AI;'C.O ~kLA£1, A, If'~,C F' O, BOx, 1-}03o0 A¢CI4OF'AC_,.E, ALA,~kA ( 995 I '.'} ._,A,.,ED HOLE FINAL F':-ZFERENCE ARCO P' "' ' "z-1 "" i -)-WU-de M1 iNJEC;TIOr.~ 5-"5 1 2-30-8¢ CEF Rbr,~ 1 , 5 ,....;- i-8-c;',',.) COLLAR/F'ERF f,'tJt',~ ~, _- ?_~, i,-~__,_,-)-;, _,.,Ro; F'R 00 U C T I )] N_ I-' ~,' U F [ L E I.,' m i N_ 1., :':.. 7-* 3 t '~-2'7 -8",--' :~-r.'iNNr. R. 'Fl: .~ .,.,.. , m, , ~ -i 5 1 2-'£-"'-8'.~ NOI,..:E T'EhF' !-:Ur,, ~ , " '2-29 i-7-¢,'C: COL. LAh./F'ERF ,,:UN ') , "/_' 2-3') 1 2-2'~-89 F'ROC, UCTION F'F:f3~: FL.E l.,.:uf'.J "'=: - 1 i 1 '-'- 1 8-89 u .JLLr-~R ktJl'J 5:- -t 3 t -9--90 COLL¢,F,'/F:'r::F,:I' I;;Ur,.) 1 , 5 5-'-"t,_ *, ..~-.3i -89 F'F,'ODUCT l: ON I:-'R'OF [LE RLIN 7-2 ~ 2-%0-8';' F'F,'ODUCTrON F'RuFILE/P[ ¥$ F.:UN '2, 5 F'I_E-'A,:E ~iGN AND RETURN THE ~'~TIAL, I-tEL, COF'Y A~. F,'E.,EIF'T OF DATA RECEIVED BY _ H¢--,VE A NICE D £ALI_Y HOFF'EC'K ATO- ~ 529 DISTRIBUI' ION CENTRAL FILES ~ PHIl_LIPS CHEVRON F:'B WELL F ILE£' D & M R & D EXTEN£ION EXF'LORA'fION ~ BF'× EXXON ~ $IAiE OF ~'~L~SK'A HAR~THON "-,,.TEXACO HOBIL ,~,AKtLIJ ,~ FI_A,',' q FL.~4,. C~4¢~C0 CAMCO ARCO Alaska, Inc~~ Prudhoe B~ ,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 3, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-2, Approval No. 9-741 Dear Mr. Chatterton: / Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/TPA/jp Attachment J. Gruber, ATO-1478 PI(DS 17-2) W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany AR3B--6132-C STATE OF ALASKA ALASK~,-~IL AND GAS CONSERVATION C.__/ 4MISSIOI~ p I ~ I IV ~ REPOR'F .JF SUNDRY WELL OP, RATIONS ' 1. Operations performed: or.am ~hut~m --- SamuU X mu~g --.- Perk.~ --- 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2722' FNL, 499' FWL, Sec. 22, T11N, R15E, UM At top of productive interval 1505' FNL, 1289' FWL, Sec. 21, TllN, R15E, UM At effective depth Alter casino ,---. Repair woll 5. Type of Well Exploratory Se~Hce At total depth 1323' FNL, 965' FWL, Sec. 21, T11N, R15E, UM 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Pmdhoe Bay Unit 8. Well number 17-2 9. Permit number/approval number 80-70/9-741 10. APl number 50 - 029-20486 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11375 feet Plugs(measured) 9566 feet Effective depth: measured true vertical 11304 feet 9503 feet Junk(measured) Casing Length Conductor 110' Surface 2608' Production 11278' Size Cemented Measured depth True vertical depth 20" 250 Sx PF II 110' 110' 13-3/8" 1908 sx Fondu & 400 sx PF II 2678' 2678' 9-5/8" 1300 sx Cl 'G' 11348' 9542' Perforation depth: measured 10632-10642'; 10651-10656'; 10668-10678'; 10684-10714'; 10728-10748'; 10764-10784' true vertical 8919-8927'; 8935-8939'; 8949-8958'; 8963-8989'; 9002-9010'; 9033-9050' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 10394' MD Packers and SSSV ,type and measured depth, Baker SAB packer @ 10336' MD: 5-1j~"~j~:)lB~a~-~V @ 2197' MD II- i",.1~ I.- i ti Fl l 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attachment Treatment description including volumes used and final pressure JAN -9]990 Alaska 011 & Gas Cons. Gclmfftissll~ Annlmmm~ Reoresentative Daily Averaae Production or Injection Data ....... '- OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1148 4233 1309 Tubing Pressure 250 Subsequent to operation 2737 6042 5142 15. Attachments Copies of Logs and Surveys run x Daily Report of Well Operations ,, x 16. Status of well classification as: Oil x.~_ Gas__ Suspended.__ Service 287 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed..,~~,~~,~t~ ~ T~tle Operations Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Drill Site 17-2 Description of Work Performed TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: Ivishak Fracture Treatment To Stimulate the Zone 4 Interval 10632-10642', 10651-10656, 10728-10748' MD (Ref. BHCS Nov. I to Nov. 18, 1989 10668-10678', 10684-10714 and 7/31/80) 1. Pumped a sand dump treatment to cover bottom perforations. Estimated sand top was 10756' MD. 2. MIRU wireline. Tagged sand top at 10758' MD. 3. Pulled live GLVs and replaced with dummy GLVs. Pressure tested 5-1/2 x 9-5/8" annulus to 3000 psig. 4. MIRU fracturing equipment. 5. Pumped propped fracture treatment for Zone 4 Ivishak interval using gelled water and 16-20 mesh Carbolite proppant at 45 bpm. a. 103 bbls Formation breakdown and shutdown for ISlP. b. 1204 bbls Cross-linked Pad c. 455 bbls Slurry at 2-9.5 PPG (93,000# of proppant was pumped into the well and 86,000# was placed into the formation) d. 255 bbls Gel flush 6. Removed proppant from wellbore. 7. MIRU wireline. Pulled DGLVs and replace with LGLVs. 8. Opened well to flow, gradually increased rate. Obtained valid well test. RECEIVED JAN - 9 1990 8[ Gas Cons. Anchorage ! ARCO Alaska, Inc. I, Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 21, 1989 C. V. "Chat" Chattedon Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-2, Permit No. 80-70 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/MDR/jp Attachment J. Gruber, ATO-1478 PI(DS 17-2)W1-3 RECEIVED AUG 2 21989 Alaska Oil & Gas Cons. Commisslon Anchorage ARCO Alaska, Inc ,s a Subsmdlary of AtlantmcR;chfmeldCompany AR3B--6132-C; STATE OF ALASKA ALASK,~( .L AND GAS CONSERVATION C~r APPLICAI'ION FOR SUNDRY Ar- 'MISSION Ft RI6 IN A L ,-'ROVALS' 1. Type of Request: Abandon Suspend Opera,on shutdown Alter casing Repair well Plugging Change approved program 'Pull tubing Vanance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X... Exploratory · ,, Strat~graph~ .,, Service 4. Location of well at surface 2722' FNL, 499' FWL, Sec. 22, T11N, R15E, UM At top of productive ~nterval 1505' FNL, 1289' FWL, Sec. 21, T11N, R15E, UM At effective depth At total depth 1323' FNL, 965' FWL, Sec. 21, T11N, R15E, UM Re-enter suspended well .... Time extension Sl]rnulate X ..... Perforate Other 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-2 9. Permit number 80-70 10. APl number 50 - 029-20486 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11375 feet 9566 feet Effective depth: measured 11304 feet true vertical 9503 feet Casing Length Size Conductor 110' 20" Su dace 2608' 13-3/8" Production 11278' 9-5/8" Plugs(measured) RECEIVED AUG 2 2 Ig89 Junk(measured) Jt, JasJfa 0JJ & Gas Cons. Commission Cemented M~asu~C~ True vertical depth 250 Sx PF II 110' 110' 1908 sx Fondu & 400 sx PF II 2678' 2678' 1300 sx CI 'G' 11348' 9542' Perforation depth: measured 10632-10642'; 10651-10656'; 10668-10678'; 10684-10714'; 10728-10748'; 10764-10784' true vertical 8919-8927'; 8935-8939'; 8949-8958'; 8963-8989'; 9002-9010'; 9033-9050' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10394' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 10336' MD; 5-1/2" Camco Bal-0 SSSV @ 2197' MD 13. Attachments Description summary of proposal Detailed operations program BOP sketch x 14. Estimated date for commencing operation September 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Sig ned 2.~_~..~~t.~__.....--~ Title Operations Engineering Manager 15. Status of well classification as: Oil x Gas Suspended Date FOR COMMI~SION URIE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMUT, Approved by order of the Commissioner Commissioner I^..r°w'"°- Approved Copy Returned Date ~ ~,~'B '~ ,, Form 10-403 Rev 06/15/88 163 M. D. Ruatto, 265-6941 SUBMIT IN TRIPLICATE DS 17-2 Ivishak Formation Hydraulic Fracture Treatment Preliminary Procedure · . . . 1 . e . Place sand fill in wellbore to +_ 10754' MD. Tag sand fill to verify depth· Pull gas lift valves and replace with dummy valves. Pressure test tubing/casing annulus. MIRU fracturing equipment. Pump propped fracture treatment at 40-45 BPM into the perforation intervals (10632'-10748' MD). Fracturing fluid will be 50 lb. gelled water with borate cross-linker and approximately 44,000 lb. of 16/20 mesh proppant. The pump schedule is outlined below. Stage Number Volume 1 900 bbl 2 40 bbl 3 40 bbl 4 45 bbl 5 50 bbl 6 35 bbl 7 250 bbl Clean out sand fill to PBTD. Fluid cross-linked water pad 2 ppg in cross-linked water 4 ppg in cross-linked water 6 ppg in cross-linked water 8 ppg in cross-linked water 10 ppg in cross-linked water gelled water flush Open well to flow, gradually increasing the drawdown to allow proper fracture healing. Test well. Install gas lift valves. R E C ~ IV ~ O ,AUG 2 1989 Aaska Oil & Gas Cons. Commission 6 5 4 3 2 COILED TUBING UNIT BOP EGIU ! PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAU$ 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~)00 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 2 H]REL]NE BOP EOUIPMENT 1. 5000 PSI 7" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIR£LIN[ RAUS (VARIABLE SIZE) · 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF BOX ~ oO,'~A¢ ~,NCHORAGE, ¢H_A~KA [~¢~TE · 5-'i ~ -RR _ 'I--R 4-."4,-R:~. t~,1-11 ! AR/PFRFnf4'ATIRN -?? 4- .? ~.,-RP, CMl '"4- ?-7 4- .o-RR P. AI ! .'K-?7 4-4-gg Df]I! ¢~!;.' 4,-t ~-?~-g,q PAll ¢~K'/PFRF FII:;'~TTI3N ~-*O 4- ~"~- _,~,z:,, F' ?.J I · ~- '~g;'-f:~fl I:fll ! ,%r;'/Iz'r-'i:;."F'f'1RAT ,rFlkl 7-% 4--'-)')-f-':[',~ ¢'Fll I ,~I:,' .." PI: i-;.'r"Fll;'ATTR."-.I R-,ct 4_'-,~,. _RR pill I ¢,1;,/F, FPl- F!RAT ,r ~IH P I.,.IT~i,I?- i 4- o: -.F~.;:~ F'fll !:'1 FF>,,'Z'..F .*:.' !' fi,.N ANT)I'! II:;:H T1 R'I:I~F T ',,! F DRY HAVF A NICF DAY' TRAN~ ~ AF'F'RF)VFD I AR/F'FI;,'I-'f'IR¢~T'TFI!,.! F,'!lk; i ct., Ti~,F:14t" :ill :" . .7 ' . _ DT£TRTRIITTRN ~~ F~NN MARATHRN ~. MnBIl_ ~ PHTII TP,~' F'R WFLI FTi R t,, D ~ TFX~I':,n ARCO ALA£KA, P. 0. I~OX ANCHORAGE, ALASKA DATE: 2-~&-SR REFERENCE: ARCO CASED HOLE FINAl. t -4 t -22-88 t-t 3 t-22-8R ~-t 6 ~-2~-R8 ~-~ 9 t -?O-RR ~ -23 t -28-88 ~ -23 t -24-88 4-7 2-4-88 4- f R 2-~-B8 4-22 ~ -29-88 7-~ ~ 2-~-88 9-~4 ~ -25-88 ~ ~-~ 8 ~-g8-R8 4 ~-~ ~ -24-88 ~ 3-5 ~ -23-RR ~3-~7 ~-23-88 ~ 3-28 ~ -22-8~ ~ 4-22 ~ -27-88 t &-2 t -25-8R ~ 6-5 ~ -28-88 ~ 6-~ 9 2-t -88 ~ 7-8 ~ -25-88 ~7-~e ~ -25-88 PR,PRFLE/FM/TP/FD/W RLIN ~, 5" FLOWMETER RIIN PRD.PRFLE/FM/TP/FD/W RIIN ~, 5" PRD.PRFLE/HPFM/TFMP/DFN RUN PRD~PRFLE/HPFM/TEHP/DEN/WHIIT RUN t, 5" PTTE/TFMP RIIN PITE/GR/TEMP RIIN PITE RUN 7, PIT~/TEMP RIJN ~, 5" PIT£ RLIN 7, FLOWMETER RUN PIT~/TEMP RUN ~, 5" PRD.PRFLE/HPFM/WH[IT RUN ~, 5' PRD,PRFL. E/HPFM/WHtlT/~R RUN GAMMA RAY RUN t, 5" PRn. PRFLE/HPFM RUN PRD,PRFLE/$PIN/TEMP/WHUT RUN IN,J~PRFLE/FM/TP RUN t, 5' INJ.PRFLE/HPFM/TEMP RIIN t, 5" PTT$/TEMP RUN PRODUCTION PROFILE RUN t, 5" PRD.PRFL. E/$PIN/TEMP/GR/WHUT RLIN t, 5" PRD~PRFLE/HPFM/GR/WHUT RUN INJ~PRFLE/HPFM RUN INJ,PRFLE/HPFM RIJN t, 5" PLEA£E $I~N ANn RETUR~ THE,~I~I~TTAC, VHEn COPY A,~ R,~j:PT O~ nAT RECEIVED BY HA VE N I AT0-t52~ A · TRAN,~ ~88i 05 /~i APPROVED. l~_ DT£TRIBllTTON ~..- CENTRAl_ FILE£ '='... PHTI_I_IP,~ · ..'"' CHEVRON PR WELL F T l F,~ D & M R & D ~ EXTENSION EXPL ORATION Q SAPC ~- EXXON ~ ,~TATE OF AL.A£KA MARATHON ~ TEXACO MOBIl_ ~r ~AMCO ~AMCO hAMan CAMCn CAMCn CAMCO ~AMC~ CAMCO nAMCn CAMCO ~AMCn CAMCO CAMCO CAMCO CAH~O CAMCO ~AMCO CAMC~ CAMCO CAMCO CAMCO DATE: REFERENCE: ARCO PRESSURE DATA PLEA£E £IGN AND BHP-PRF$$IJRE BIIII_DIIF' BHP-ETATTC GRADTENT BHP-ETATIC GRADTFNT BHP-~TATTC ~RADIFNT BHP-£TATIC GRADIENT BHP-FLOWTN~ ~RADTFNT BHP-FI..OWTN~ GRADTENT BHP-FLOWTN~ GRADIENT BHP-ETATTC G~ADTFNT RETURN THE'ATTACHED RFCFTPT OF DATA, CAMCO CAMCn CAMCO RAMCO RAMCO RAMCO RAMCG RECEIVED BY___ HAVE A NICE DAY' PEGGY BENNETT AT0-t529 TRAN~ ..-88t APPROVED DT£TRIBIITTON CFNTRAL F I I_E,~ CHFVRON ~,.- O & M EXTENSION FXPL[3RATION ~' ~XXON MARATHON '"-.- MOBIl. ARCO ALASKA, INC. ( ANCHORAGE~ Al ASkA ~0 DATE: 2-t ~-RR REFERENCE: ARCO CASED HOLE FTNAI. PR,PRFLF/FM/TP/FD/M F[OMMFTER PRD.PRFLE/FM/TP/FD/M ~_-~-20-BR ~-~ 1-2G-R8 '-29-88 -5-8R 4-23-8R t-3~-AR t-24-88 ~~J~ 4-23-8R t-22-88 ~-~~t-27-88 .~-~/t -3~ -88 ~_ f ?-~ J t -25-B8 PRD.PRFLE/HPFM/TFHP/DFN RIIN t, %' PRD~PRFLF/HPFM/TEMP/DFN/MHIIT RUN t, ..5' PTT.~/TFHP RIIN t , "~' PIT2/CR/TEMP RIIN 9, ~' P]TE PIT$/TEMP PffT$ FLOWM£TER PITE/TEMP PRO PRFLE/HPFH/WHL~oiI&G~ Cons. CoB~sC[~RIJN PRD~PRFL. E/HPFM/W~[~?~R ~chom~e RUN GAMMA RAY RUN t,, ~m RUN t , 5' RUN t ~ 5 · RUN t , 5' RUN t , 5' ~tJN ~, 5' RUN t , ~ ' RLIN t , 5' RUN t , ~" RUN ~ , 5' PRD,PRFLE/HPFM PRD.PRFLE/$PIN/TEMP/WHUT INJ,PRFLE/FM/TP INJ.PRFLE/HPFM/TEMP PIT$/TEMP PRODUCTION PROFILE rRD.PRFi.F/$PIN/TCHF'/~/~HUT PRD~PRFLE/HPFH/GR/WHUT INJ.PRFLE/HPFH INJ.PRFLE/HPFM CAM~n CAMCO CAMCO CAM~O ~AMCn CAMCO nAMcn CAM~O CAM~n CAM~O CAM~O CAMCO CAMCO CAMCO CAMC~ CAMCO CAHCO PLEA£E SIGN AND RETURN THE ATTACHED COPY A£ RECE RECEIVED BY HAVE A NICE BENNET PEGGY ATD-t 529 TRAMS ~88405 APPROVED DTSTRIBLI ZON ! CENTRAL FILEE CHEVRON D & M EXTEN2ION EXPL ORATION EXXON MARATHON MOBIL iq/O cuO .---- oivLT' PH![.I_I_ [P~ PR bIELL FTL R SAPn 2TATE OF TEXACO AL. AS1 ARCO Alaska, Inql~'* Prudhoe B,~y ,~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 1, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-2 Permit No. 7-498 Dear Mr. Chatterton: Attached is the Report of Sundry Well formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp At t a chment cc: Standard Alaska Production Company Pi(DS 17-2)W1-3 Operations detailing work per- WELL S / 119 ARCO Alaska, Inc is a Subsidiary of Atlant,cR,chf,eldCompany AR3B--6132-C i STATE OF ALASKA ~ AL .,A OIL AND GAS CONSERVATION CO .ISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed' Operation shutdown [] Stimulate'j~ Plugging ~ Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Ala s]~q: The. 3 Address P.O. Box 100360~ Anchorafie~ AK 99510 4 Locahon of well at surface 2722' FNL, 499' FWL, Sec. 22, TllN, R15E, UM At top of productive ~nterval 1505' FNL, 1289' FWL, Sec. 21, TllN, R15E, UM At effechve depth At total depth 1323' FNL, 965' FWL, Sec. 21~ TllN, R15E, UM 11 Present well cond~bon summary Total depth measured 11375 feet true vertical 9566 feet Plugs (measured) 5 Datum elevation (DF or KB) 70 ' RKB Feet 6 Unit or Property name Prudhoe Bay Unit 7 Well number 17-2 50-- 029-20486 10. Pool Prudhoe Bay Oil Pool Effective depth measured 11304 feet true vertical 9503 feet Junk (measured) Casing Length S~ze Cemented Structural Conductor 110' 20" 250 Sx Surface 2678' 13-3/8" 2308 S× Intermediate Produchon 11348' 9-5/8" 1300 Sx L~ner Perforahon depth: measured 10632-10642', 10651-10656', 10668-10678' true verhcal 8919-8927', 8935-8939', 8949-8958', 8963-8989' Tubing (s~ze, grade and measured depth) 5½", 17#, L-80, PC tubing @ 10394' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 10336' MD_.' Camco Bal-O SSSV 0 2197' 12. St~mulahon or cement squeeze summary Measured depth ~ue Verhcaldepth 110' 110' 2678' 2678' 11348' 9542' , 10684-10714', 10728-10748' , 9002-9010' Intervals treated (measured) Treatment descnphon including volumes used and final pressure Attached , 10764-10784' , 9033-9050' SEP ¢, "",, Alas~ Oil l Gas Cons. Commission Anchorage 13 Prior to well operation Subsequent to operahon Representative Daily Average Produchon or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2700 2160 150 -- 3830 3200 575 Tubing Pressure 230 230 14 Attachments Da~ly Report of Well Operahons'~ Cop~es of Logs and Surveys Run [] 15. I hereby certify that the forego,rig ,s true and correct to the best of my knowledge ~<~ - ~7x--oC'~ Title Operations Engineering Manager Date Form 10-404 Rev 12-1-85 Submit in Duplicate WELLS/Il9 J. M. Vitucci, ATO-1508, 265-6358 DRILL SITE 17-02 AMINE PHOSPHONATE SCALE INHIBITION TREATMENT TREATMENT DATE: 8/13/87 I o , o ° o Obtained a valid well test. Fluid packed the 5-1/2" x 9-5/8" annulus with crude. MIRU pump trucks and transports. Pump the following fluids: A, B. C. D. E. 48 bbls. of EDTA with additives 77 bbls. of selected scale inhibitor blend 425 bbls. of diesel 250 bbls. of dead crude 5 bbls. of diesel Shut in well for 12 hrs. RD and released equipment. Obtained a valid well test. A( STATE OF ALASKA I~ AL ..A OIL AND GAS CONSERVATION CO ..,~SSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request. Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] T~me extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2 Name of Operator ARC~ Aln.~kn_ Tnt., 3 Address P.O. Box 100360, AnchoraAe, AK 99510 4 Locahon of well at surface 2722' FNL, 499' FWL, Sec. 22, TllN, R15E, UM At top of productive ~nterval 1505' FNL, 1289' FWL, Sec. 21, TllN, R15E, UM At effective depth At total depth 1323' FNL, 965' FWL, Sec. 21, TllN, R15E, UM 11 Present well cond~hon summary Total depth- measured 11375 feet true vertical 9566 feet Plugs (measured) 5. Datum elevation (DF or KB) 70' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 17-2 8 Permit number 80-70 9. APl number 50-- 029-20/+86 10 Pool Prudhoe Bay Oil Pool Effective depth, measured 11304 feet true vertical feet 9503 Casing Length S~ze Conductor 110 ' Surface 2678' Ir;,tcrm,,cdi~tc Production 11348 ' L~ner Perforahon depth measured Junk (measured) Cemented Measured depth WueVerhcaldepth 20" 250 Sx 110' 110' 13-3/8" 2308 Sx 2678' 2678' 9-5/8" 1300 Sx 11348' 9542' 10632-10642', 10651-10656', 10668-10678', 10684-10714', true verhcal 8919-8927', 8935-8939', 8949-8958', 8963-8989', 9002-9010', 9033-9050' Tubing (size, grade and measured depth) 5½", 17#, L-80, PC tubing @ 10394' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 10336' MD; Camco Bal-0 SSSV @ 2197' 10728-10748', 10764-10784' 12 Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13 Estimated date for commencing operation 14. If proposal was verbally approved September 1987 Name of approver Date approved 15 I hereby/~ertify that~t4~e fj~reg~l~g ~s true and correct to the best of my knowledge SignedI1~,~~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 N°tify c°mmissi°n s° representative may witness I Appr°val N° ~ J ~TZ ~ [] Plug ~ntegnty [] BOP Test [] Location clearance _ _ by order of ~ Comm,ss,oner the comm,ss,on Date ~ ~"~---~'---~ ~ J. M. Vitucci, ATU-lbU~, Zbb-bi~b~ Submit in triplicate~ DRILL SITE 17-02 AMINE PHOSPHONATE SCALE INHIBITION TREATMENT I o . . o Obtain a valid well test. Fluid pack the 5-1/2" x 9-5/8" annulus with crude. MIRU pump trucks and transports. Pump the following fluids: Ao B. C. D. E. 48 bbls. of EDTA with additives 77 bbls. of selected scale inhibitor blend 425 bbls. of diesel 250 bbls. of dead crude 5 bbls. of diesel Shut in well for 12 hrs. RD and release equipment. 10. Obtain a valid well test. RECEIVED Alaska 0il & Gas Cons. Commissio Anchorage ! ARCO Alaska, Inc% Post Ofhce Box 100360 Anchorage Alaska 99510 Telephone 907 276 1215 r Date: April 23, 1985 Reference: ARCO Pressure 12-26 ~/ PBU 16-9 f 16-14 17-1/ 17-2j 18-3 / 4-3-85 DA Gradient Survey Gradient Survey Gradient Survey Gradient Survey Gradient Survey PBU Surveys 4-4-85 Camco 4-4-85 Camco 4-6-85 Camco 4-6-85 Camco 4-7-85 Camco 1-9/10-85 DA F~gn and return the Received by Pam Lambert ATO 1429C Trans 079 attached copy as recipt of data. t,~,]~. Gomm~ss~on Anchorage Chevron ~& M Exp1. Services Ext. Exploration ~xxon Marathon Mobil E & P l~'Well Files ~f& D $~hio S~s~e of Alaska ~e.xaco ARCO Alaska, Ir~ Post Offlc",= dox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 13, 1984 Mr. Harold Hedlund State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 17-2 Dear Harold, The DS 17-2 Well Completion Report, dated September 22, 1980, incorrectly lists the ADL number as 28334. The correct lease designation for this well is ADL 28331. Also, the township should be TION for all locations of this well (surface, TD and top of the producing interval). Please make these changes to your records/files. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L04 xc' K. McFarland, ATO 1429 P. T. Willman, ATO 1069 Well File RECEIVED DEC 1 Anchorage ARCO Alaska, Inc is a Subsidiary of AtlanhcR~chf~eldCompany ARCO Alaska, (' Post Ofhce Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 9, 1984 Reference: ARCO Cascd Hole Finals D.S. 3-12 5-27-84 D.S. 6-14 6-13-84 D.S. 13-9 5-18-84 D.S. 17-2 5-23-84 Collar/Pcrf Log CPL/TDT-M w/listing PLS/Tracer & Diff Temp Collar/Perf Log Run 1 5" GO 5" Sch Run 1 5" DA Run 1 5" GO P~~lease sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO-1429F Trans. #247 DISTRIBUTION ~hevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc.( Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 9, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 17-1 DS 17-2 DS 17-5 DS 17-7 DS 17-9 Permit No. 80-55 Permit No. 80-70 Permit No. 80-96 Permit No. 81-66 Permit No. 81-90 Enclosed are the Completion Reports for work done on the above mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Enclosures SOHIO Alaska Petroleum Co. File P1 (DS 17-1)W4-3 File Pi(DS 17-2)W4-3 File Pi(DS 17-5)W4-3 File Pl (DS 17-7)W4-3 File P1 (DS 17-9)W4-3 RECEIVED J U L 1 6 ]984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc Is · Subsidiary of Atl,,ntlcRIchfleldComp~ny STATE OF ALASKA /"JZ~ ' / ALASK,~, ~IL AND GAS CONSERVATION CI ,IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1 Status of Well Class~hcanon of Serwce Well OIL ~[ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Thc. 80-70 3 Address 8 APl Number .... P.O. Box 100360, Anchorage, Alaska 99510 50-029-20486 4 Location of well at surface 9 Unit or Lease Name 2722' FNL, 499' FWL, Sec 22, TllN, R15E, UM Prudhoe Bay Unit At TopProducmg Interval 10 Well Number 1505' FNL, 1289' FWL, Sec 21, TI]N, R15E, UM DS 17-2 At Total Depth 11 F~eldand Pool 1323' FNL, 965' FWL, Sec 21, TllN, R15E, UM Prudhoe Bay Field 5 Elevation ,n feet (,nd~cate KB, DF, etc ) 6 Lease Demgnatmn and Serial No Prudhoe Bay Oil Pool 70' RKB ADL 28334 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband 15 Water Depth, ~f offshore 116 No of Completions 7/17/80 7/31/80 8/5/80 feet MSLI Single. 17 Total Depth (MD+TVD) !18 Plug Back Depth (MD+TVD) 19 D~recnonal Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11375'MD- 9566'TVD l1304'MD - 9503'TVD YES~]~ NO [] feet MD 22 Type Electmc or Other Logs Run DIL/SP/BHCS/GR FDC/CNL/GR/CAL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEIWT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# Weld H-40 Surf. 110' 32" 250 sx Permafrnst II tn .~1 1'¢~ 13-3/8" 72~A Butt L-80 Surf. 2676' 17%" 1908 sx Fondu olus 400 sx Permafrost TI 9-5/8" 47# Butt L-80 & Surf. 11348' 12~" 1300 sx Class G cmt RS95 24 Perforations open to Producnon (MD+TVD of Top and Bottom and 25 TUBING RECORD ~nterval, s~ze and number) *New Perfs w/4spf SIZE DEPTH SET (MD) PACKER sET (MD) 10632 - 10642'MD (10') 8920 - 9049'TVD 5%" 1039Z~' 10~a9' 10651- 10656'MD (5') 10668 - 10678'MD (10') 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10684 - 10694'MD (10') DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *10728 - 10748'MD (20') N/A *10764 - 10784'MD (20') 27 PRODUCTION TEST , , Date F~rst Producuon I Method of Operauon (Flowing, gas I~ft, etc ) 6/9/81I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/22/84 6.2 TEST PERIOD I1~ 790.5 552.6 O 69 699 FIowTub~ng Cas~ngPressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 547 24-HOUR RATE ~I~ 3060 2139 0 26.2 28 CORE DATA Br~efdescmpt~onof I~thology, poros~ty, fractures, apparent d~ps and presence of o~l, gasorwater Subm~tcorech~ps N/A RECEIVED JUL 1 61 84 Alaska Oil & ~as Con~ ~._ Form 10-407 Rev 7-1-80 CONTINUED ON REVERSE SIDE AnChorage Submit, ..... c te 29 3O GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and grav,ty. MEAS DEPTH TRUEVERT DEPTH GOR, and t~me of each phase Top Sadlerochit 10619' 8909' N/A O/W Contact 10846' 9104' Base Sadlerochit 11248' 9455' 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned. . .... T,tle Regional En~tna~r _ Date 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 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none".. Form 10-407 ! ARCO Alaska, Inc. ~ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 25, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 17-1 DS 17-2 DS 17-5 DS 17-7 DS 17-9 Permit No. 80-55 Permit No. 80-70 Permit No. 80-96 Permit No. 81-66 Permit No. 81-90 Attached are "Subsequent Report" Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File Pi(DS 17-1)W1-3 PI(DS 17-2)Wl-3 P1 (DS 17-5)Wl-3 Pi(DS 17-7)Wl-3 PI(DS 17-9)Wl-3 RECEIVED JUN2 8 :] 184 Alaska 0jJ & Gas Cons. Commission Anchorage ARCO Alaska, Inc Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA(' L AND GAS CONSERVATION C({~ ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WE LLM~ 2 Name of Operator ARCO Alaska, Inc. 3 Address P.O. Box 100360, Anchorage, Alaska 99510 4 Locat,on of Well (Surface) 2722' FNL, 499' FWL, Sec. 22, TllN, R15E, UM (Producing Interval) 1505' FNL, 1289' FWL, Sec. 21, TllN, R15E, UM (Total Depth) 1323' FNL, 965' FWL, Sec. 21, TllN, R15E, UM 5 Elevatmon ,n feet (md~cate I<B. DF. etc ) I 6 Lease Des~gnatmon and Serial No 70' RKB I ADL 28334 12 7 Permmt No 80-70 8 APl Number 50- 029-20486 9 Umt or Lease Name Prudhoe Bay Unit 10 Well Number DS 17-2 OTHER [] 11 Fmeld and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tr~plmcate) (Submmt ~n Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casmng [] St,mulate [] Abandon [] Snmulatmon [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Reportmuluplecompleuonson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, mcludmng estmmated date of starting any proposed work. for Abandonment see 20 AAC 25 105-170) Began perforating operation 5/23/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 10728 - 10748' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 10764 - 10784' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 7/31/80 RECEIVED JUN2 819114 Alaska 0il & Gas Cons, C0mmlssion 14 I hereby c. Art~fy that t_he foregoing ~s true and correct to the best of my knowledge Smgned ....... / T,tle Regional Engineer The space below for Corem,ss,on use Condmuons of Approval. ~f any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Subm,t "lntentmons" mn Triplicate and "Subsequent Reports" ,n Duplmcate ARCO Alaska, In4 Prudhoe Bay r.:ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 2, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 17-1 DS 17-2 DS 17-5 DS 17-7 DS 17-9 Permit No. 80-55 Permit No. 80-70 Permit No. 80-96 Permit No. 81-66 Permit No. 81-90 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File PI(DS 17-1)W1-3 Pi(DS 17-2)W1-3 Pi(DS 17-5)W1-3 Pi(DS 17-7)W1-3 PI(DS 17-9)W1-3 ARCO Alaska, Inc Is a Subsidiary of AtlantlcRIchfleldCompany RECEIVED Alaska Oil & Gas Cons. Commission A~,$:r,,.:,~ ago STATE OF ALASKA ALASK( .)IL AND GAS CONSERVATION ~' MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL~ OTHER [] 2 Name of Operator 7 Permit No ARCO Alaska, Inc. 80-70 3 Address 8 APINumber P.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20486 4 LocatIon of Well 2722' FNL, 499' FWL, Sec. 1505' FNL, 1289' FWL, Sec. 1323' FNL, 965' FWL, Sec. 5 Elevation in feet (indicate KB, DF, etc ) 70' RKB 22, TllN, R15E, UM 12 21, TllN, R15E, UM 21, TllN, R15E, UM I 6 Lease Designation and Serial No ADL 28334 9 Unit or Lease Name Prudhoe Bay Unit 10 Well Number DS 17-2 11 F~eld and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit .n Triplicate) (Submit m Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Snmulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Reportmult~plecomplenonson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Describe Proposed or Completed Operanons (Clearly state ali pertinent detads and g~ve pertinent dates, including esumated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc. proposes to add perforations on DS 17-2 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 operation. Proposed Perforation Intervals: 10728-10748' MD 10764-10784' MD Ref: BHCS 7/13/80 Subsequent Work Reported 14 I hereby certify that the fore, going ~s true and correct to the best of my knowledge Signed ...... T~tle Regional Engineer The space below for Commission use Date Conditions of Approval, ~f any Approved Capy BY LO#NIE C. $1~Illi By Order of Approved by. COMMISSIONER the Commms~on Submit "Intentions" ~rfTr~pl~cate Form 10-403 Rev 7-1-80 and "Subsequent Reports" ~r~ Duphcate Anchorage. ,Alaska 9g5~0 'T'el~lghone '2-0'~ ,'7 ~637 May 3, 1982 Reference: ARCO PRESSURE DATA D.S. 17-5 3-16/17-82 D.S.17-1 3/7/82 " DS..2-11 2-14/15-82 " D.S.7-11 10/23/81 " D.S.2-2 2/13/82 " D. S. 2-5 2-3/4-82 " iI Pressure Survey ijj~'~ ......lO/11/81 /Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 141 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON uti & Gas Cons. Commission Anchomg~ ¢ ARCO' ,.,~1 and Gas Company Norq~ Alaska D~stnct Pos~ O~I~ce 6ox Anchorage. A',~ska %510 Telephone 207 277 5637 Jerry A Rochon DIstr,ct Operahons Eng;neer November 6, 1981 Reference: ARCO CASED HOLE FINALS D.S.7-3 10/15/81 CNL Run 2 5" .**'~..S.17-2 ~" 10/11/81 EPL Run 1 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Trasnmittal ~ DIS[RIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ~'..~ ~--~. ~, D & M SOHIO , "',- ~ GEOLOGY MARATHON x.. STATE OF ALASKA CHEVRON ,"?" ,~ ARCO Alaska, Inc Post OfhcrJ x Ancho,'ag", Telephone on7 277 5637 October 28, 1981 Mr. Jim Trimble State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Subject: Sub-Surface Safety Valve Setting Attached please find the Sub-Surface Safety Valve (SSSV) setting depths for the wells mentioned in our 10/22/81 phone conversation. Please note that all measurements are measured depths. If we can be of any help in the future do not hesitate to call. Si nc e rel y, Graham A1 vord Associate Engineer GA: 1 tc Attachment 17-1 17-2 17-3 17-5 17-6 16-1 ( ( Sub-Surface Safety Valve, Setting Depth Measured Depth (MD) ft. 2162 2204 2167 2127 2130 2127 ARCO Alaska, Inc.!~ North Slope ~ act Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon D~stnct Operahons EngIneer October 12, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: D.S. 16-1 Permit No. 80-136 D.S. 16-2 Permit No. 80-150 D.S. 16-8 Permit No. 80-02 D.S. 16-9 Permit No. 81-19 D.S. 16-10 Permit No. 80-04 D.S. 16-11 Permit No. 80-118 D.S. 16-16 Permit No. 80-127 D.S. 17-1 Permit No. 80-55 D.S. 17-2 Permit No. 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Dear Mr. Hamilton: Enclosed are our Completion Reports for the above-mentioned wells. Very truly your~/ /~,/~. A. Rochon JAR: DAH: adri Attachments ECEIYEO OCT 2 0 I98! Ala~<a Oi~ & Gas Cons. Commfs,~for~ a~chorag~ ARCO Alaska, Inc is a subsidiary of Atlanl~cRIchhetdCompany ALASKA[.,_ AND GAS CONSERVATION C(~ MISSION 'wELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class~f,cat~on of Service Well O~-~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 80-70 3 Address 8 APl Number P. O. Box 360, Anchorage, Alaska 99510 5o-029-20486 4 Location of well at surface 9 Unit or Lease Name 2722' FNL, 499' FWL, Sec. 22, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10 Well Number 1505' FNL, 1289' FWL, Sec. 21, TllN, R15E, UM D.S. 17-2 At Total Depth 11 Field and Pool 1323' FNL, 965' FWL, Sec. 21, TllN, R15E, UM Prudhoe Bay Field 5 Elevat,on m feet (,nd~cate KB. DF. etc ) [ 6 Lease Des,gnat,on and Ser,al No Prudhoe Oil Pool 70' RKBI~ ADL 28334 12 Date Spudded 13 Date T D Reached 14 Date Comp . Susp or Aband I 15 Water Depth. ,f offshore 116 No of Complet,ons 7-17-80 7-31-80 8-5-80I feet MSLI Single 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 D,rect,onalSurvey i 20 Depth where SSSV set I 21 Th,ckness of Permafrost 11375 'MD 9566' T~rD 11304' MD 9503' rV~s KK NO []I feet MDI 22 Type Electric or Other Logs Run DIL/SP/BHCS/GR FDC/CNL/GR/CAL 23 CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94,Welde( H-40 sLlrface~ 110' 32" 250 sx Permafrost I'. to surface 13-3/8" 72, Butt L-80 stlrface 2676' 17 1/2" 1908 sx Fondu plus .00 sx Permafrost 9-5/8" 47, Butt L-80 & stlrfa_ce 11348' 12 1/4" 1300 sx Class G cmt RS95 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD ~nterval. s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) ,,, 10632-10642' M.D. 5 1/2'' 10394, 10342' 10651-10656' M.D. 10668-10678' M.D. 26 ACID. FRACTURE, CEMENT SQUEEZE, ETC 10684-10694' M.D. D.EPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9739' T.V.D.-9796' T.V.D. ~/A 27 PRODUCTION TEST Date F~rst Producnon I Method of Operation (Flowing, gas I~ft, etc ) 6-9-81 I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 8-10-81 12.3 TESTPERIOD I~ 835 708 0 39I 847 , Flow,Tubing Casing Pressure CALCULATED.,~ OIL-BDt GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 955 24-HOUR RATE ~ 1630 1381 0 26.2 28 CORE DATA Bnefdescnpt~onof I~thology, poros~ty, fractures, apparent d~ps and presence of od, gasorwater Subm~tcorech~ps RECEIVED OCT 2 0 ~ol~ 0il & Gas Cons, Commis~.;~n Form 10-407 Submit ~n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE ., 29 3O GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and t,me of each phase T. Sadlerochit 10620' 8909' N/A B. Sadlerochit 11248' 9454' 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ,/z~~ _~~ T,tleDistrict Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. North Slope rlct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operahons Engineer July 27, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: D.S. 17-1 Permit No. 80-55 D.S. 17-~ Permit No. 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Dear Mr. Hamilton: Enclosed are our Sundry Notices of work completed o~ the above- mentioned wells. Very_truly yours, ~I. ~. Rochon JAR:DAH:adri Attachments RECEIVED JUL 9 1981 Alaska 0il & ,.~., ARCO Alaska, Inc is a subsidiary of AtlarlllcRichlteldCompany STATE OF ALASKA O~ ALASKA ,L AND GAS CONSERVATION C ,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator 7 Permit No ARCO Alaska Inc. 80-70 3 Address 8. APl Number P.O. Box 360 Anchorage, Alaska 99510 50- 029-20486 4 Location of Well 2722' FNL, 499' FWL, 5 Elevation in feet (indicate KB, DF, etc ) 70 KB 12 Sec. 22, T10N, R15E, UM Lease Designation and Serial No ADL 28334 9. Unit or Lease Name Prudhoe Bay Unit 10 Well Number 17-2 11 F~eld and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropmate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF: (Submit ~n Tmpl~cate) (Submit in Duplmate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [~ Stimulate [] Abandon [] Stimulation [] Abandonment I'~ Repair Well [] Change Plans [] Repairs Made [] Other ~ Pull Tubing [] Other [] Pulhng Tubing [] (Note Report muluple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13. Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, includ~ng estimated date of start,ng any proposed work, for Abandonment see 20 AAC 25 105-170) Began perf operation 6/9/81. Tst tbg & annulus. Tst tree. NU & tst perf equipment. NU & test w/BOP & lubricator. Run 4" dummy gun. Perf ~694:2j_~. Unload well to tank. Flow to flow station. Perf. ~94.1 4 spf. perf ~ 4 spf. perf j_065~L-5_~_4 spf. ?erf ~0632-~_~4 spf. Reperf 10694-714 4 spf. Reperf 10668-78 4 spf. Reperf 10651-56 4 spf. (misfired). Reperf 10632-42 4 spf. ND perforating unit. RU wireline unit. Test wireline BOP & lubricator. Record static BHP. RD wireline unit. Secure well, 6/10/81. Installed SSSV 6-]3-8]. RECEIVFD JUL ,3 IgC! Alaaka 01t & ~s , 14 I hereby.ee?'~l~y that the_forego~ng/~'true and correct to the best of my knowledge The space ~el?~ for Commission use Condit~ong~d~ Approval, If any Date By Order of Approved by COMMISSIONER the Commmslon Date Form 10-403 Rev 7-1-80 Submit "lntentlons" in Trtphcate and "Subsequent Reports" tn Duphcate ARCO Od and Gas,~ompany North Ala sk~, ~stnct Post Oil,ce Box 350 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A Rochon DIstrict Operahons Engineer June 29, 1981 Reference: ARCO PRESSURE DATA D.S.17-3 D.S. 17-6 6/L1/81 6/12/81 6/10/81 Pressure Survey Pressure Survey Pressure Survey Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #389 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA MOBIL ' GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO OH and C, as Company ~s a O~v,slon ol AllanhcRichl~elcICompany ARCO Alaska, Inc_ Norlh Slop( strict Post Ofhce ~Jox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A Rochon D~strlct Operahons Engineer April 30, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: D.S. 17-1 Permit No. 80-55 D.S. 17-2 Permit No. 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-4 Permit No. 80-85 D.S. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Enclosed are our Sundry Notices detailing the work to be done on the above mentioned wells. Very truly yours, z~. District Operations Engineer JAR/HFB/kam Enclosures RECEIVED MAY - 6 1981 Alaska 0il & Gas Cons. Commission Anch0raga ARCO Alaska Inc ~s a subsidiary of A|lanhcRIchfleldCompany · STATE OF ALASKA CC ALASK~ ~,IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7. Permit No. ARCO Alaska 80-~0 3 Address 8. APl Number ?. 0. Sox 360 Anchora§e, AK 99510 50-029-20486 4. Location of Well 2722' FNL, 499' FWL, Sec. 22, T10N, R15E, UM 5 Elevation in feet (indicate KB, DF, etc ) 70 KS 6 Lease Designation and Serial No ADL 28334 9. Untt or Lease Name Prudhoe Bav Unit 10. Well Number 17-2 11. F~eld and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF: (Submit m Trtphcate) (Submtt m Duplicate) Perforate [~ Alter Castng [] Perforat,ons I-'] Altering Castng [] Stimulate [] Abandon [] Stimulation r-I Abandonment [] Repmr Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Report mult,ple completions on Form 10-407 w~th a submttted Form 10-407 for each completion ) 13. Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve perttnent dates, tncludtng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating the well will be flowed to the flow station for clean up and production. Should additional drawdown be necessary to unload the wells it may be flowed to a tank for initial clean up. The perforated intervals will be given in the subsequent report. Ail wireline work will be done through a 5000psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean up operation. RECEIVED MAY - 6 ] 9 ~- ~ ~o, ~ ~aska 0]] & Gas Cons. C0mn~sm0n Anchorage 14 I hereby cert,fy that the foregoing is tr~e~nd correct to the best of my knowledge S,gned//~~ ~ T,tle District Operations Engineer Date The space bettor Corniness,on use 4-30-81 Conditions of Approval, if any Approved by Approved opy Returned By Order of COMMISSIONER the Comm,sston Form 10-403 Rev 7-1-80 Submit "lntentton$" tn Trtphcate and "Subsequent Reports" tn Duphcate ARL.,O k)~i and Gas Company North Alaska DIstnct Post Ofhcfl~' x 360 Anchorage; ,~aska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 7, 1980 Reference: ARCO Magnetic Tapes O.S. 17-3 10/14/80 D.S. 14-2 10/16/80 D. O/22/80 D.S. 13-4 10/9/80 Log & Int. #CN-10278-11850 " " CN/MS 10500-11400 " " CN/MS 10000-1]_310 " " C/O Log 9100-9834 as'~ sign and return the attached copy as receipt of data. Mary F. Keilis North Engineering Transmittal #783 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON .. R.E £ I D Alaska 0il & G~s Corm. Commission Anchorage ARCO Oil and Gas Company is a Division O! AtlantlcRichfteldCompany ARCO Oil and Gas Company Norlh Alas( '}istnct Post Ofhce ,.,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon Distr~ct Operahons Engineer October 14, 1980 Reference: ARCO Cased Hole Finals D.S. 17-2 8/30/80 CNL Run 1 5" p.s. 17-2 8/4/8o CB~,/VD~, Run I 5" Pleasesign and return the attached copy as receipt of data. Mary Kellis North Engineering TRANSMITTAL # 699 _..j.j"coM'~ J COMM J .C. OMM RES ENG 1 ENG J 2 ENG __J3 ENG 4 ENG t,,,,J- 1 GEOL' -'-'j-STAT 'I/E~ ~ STAT TE~-- 1 ~CONFER: 'FILF:' _ DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company es a Division o! AtlanhcRichfleldCompany ARCOO~Iand Ga.~, ~mpany A:;.SI,J L;' ~,', Po.-.t 0',',, ~ :-' , . Septe,mber 24, 1980 Mr. Hoyle Ha,mi lton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- As-Built Survey Plats ,' [ 4 ENO" ', STAT TEC ~ STAT TEC ,_ C,~NsrF<: Ft', F,, Dear Sir' In an effort to insure that your files are co,replete, we have attached copies of our well location as-built survey plats for all wells permitted thus far ~n 1980, excluding those included in our original drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments 16115 ~: ~~ ZTZl.77 I I HEREBY CERTIFY THAT ! PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT ~.s. ~7 - conductors ] ~,~u ~ ~u,~ su~vE~ ~ ~ ~E, ~S-~U,~ ~OC~,O~S ~,LS ~E CO~EC~, ~S 0~: DATE STAT~ ,~A.~ kA~ ; ~0.; l. Y = 592779~.39~ h. Y = x = 7o8786.75~ x = 7o87o2.5~6 ~~~. LAT = 70o~2'21 8~6" LAT = 70°12'25 308" ~ . . ~% ........ ~.~- LONG = ]~8°]8'59.678'' LONG = lh8°l~'Ol.Shl'' ~&~.- & 2. Y = 59279]0.~6 5. Y = 5928260.936 g*/49~ ~ X.= 708758.898 X = 70867~.050~'~~~ ....... LAT = 70°~'22.99F" LA~ = 70°~2'~.~" ~ X = 708730.87] X = 7086~.~62 LAT = 70°]2'2~.]~]'' LAT = 70°]21 27.6~]~l LONG = ]~8°]9'0].]]3" LONG = ~8°19'03.331'~ II I III I I I II L I I I I I I~1 I I AtlanticRichfieldCompany ~ ~DATE. DRAWING ~o: NORTH AMERICAN PRODUCING DIVISION ~'~-~O ALASKA DISTRICT- PRUDHOE BAY I IIII ~11 II III i i i i I i ..... ARC(~ Oil and Ga~' ,mpany Alaska D~stnc[ Post Ofhce Box 360 Anchorage Alaska 99510 Telephone 907 277 5637 September 19, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 6-16 (Permit no. 80-33) DS 17-2 (Permit no. 80-70) Kuparuk E-5 (Permit no. 80-58) Dear Sir' Enclosed please find our Completion Reports, for the subject wells, including individual drilling histories and gyroscopic surveys. Updated reports will be filed as soon as perfor- ating is completed and production test data becomes available. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures ARCO OH and Gas Company Js a g~vtston of A'~JanhcR~chf~e~dCor'n',;,~'aY Form · STATE OF ALASKA (see other in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* 'la TYPE OF WELL WEL I~.IOILLr~ GAS r-'] DRYI-'-]t_J Other WELLI I b TYPE OF COMPLETION NEW WORK DEEP- r~] PLUG DIFF WELL[X-] OvER E~ EN I I BACK[--] RESER E~ Other 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360, Anchoraqe~ AK 99510 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 10 ~ g~/~ 2722' FNL, 499' FWL, Sec. 22, T~xl'N, R15E, UM At top prod interval reported below 1505' FNL, 1289' FWL, Sec. 21, T~N, R15E, UM At total depth 1323' FNL, 965' FWL, Sec, 21, T~I~N, R15E, ug ORIGINAL 5 APl NUMERICAL CODE 50-029-20486 6 LEASE DESIGNATION AND SERIAL NO ADL 283S~L I 7 IF INDIAN, ALLO17EE OR TRIBE NAME UNIT, FARM OR LEASE NAME Prudhoe Bay Unit W [dL'[. NO -'~ DS 17-2/ '0'-Frlc'-LD AND POOL, OR WILDCAT Prudhoe Bay Fiel d, Prudhoe Oi 1 Pool 11 SEC,T,R,M,(BOTTOMHOLE OBJECTIVE) Sec. 21, T10N, R15E, UM 12 PERMIT NO 80-70 18 TOTAL DEPTH, MD & TVD 119 PLUG BACK MD & TVDJ20 ,. 0OM....OW 'l;j, R ~Tf~ Y TOOLS INTERVALS DRILLED BY CABLE TOOLS 11375' MD 9566' TVDlll~§[~' gD 9503' TV~) single 22 PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* 23 WAS DIRECTIONAL TOP Sadlerochit 10620' gD 8909' TVD SURVEYMADE Base Sadlerochit 11248' MD 9454' TVD yes 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHCS/GR, FDC/CNL/GR/CAL 25 CASING SIZE I WEIGHT, LB/FT 20" [94, welded 13-3/8" 72~ BUTT 9-5/8" 47, BUTT CASING RECORD (Report all strings set In well) GRADE J DEPTH SET (MD) J HOLE SIZE H40 J 110 I 32" 250 k80 I 2676 17~" 1908 LB0 &l 11348 12¼" 1300 IRS95 I 26 LINER RECORD SIZE TOP (MD) I BOTTOM (MD) SACKS CEMENT* n/a 28 PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) n/a CEMENTING RECORD I AMOUNT PULLED sx Pemafr0st II t0~surface sx Fondu plus 400 s~ Permafrost 1I sx Class G cmt / / 27 TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) 5~" 10394 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC PACKER SET (MD) 10342 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 30 DATE FIRST PRODUCTION n/a TEST PERIOD 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc ) PRODUCTION J WELL STATUS (Producing or shut-in) I IWATER-BBL IGAs-OIL RATIO ~ WATE~-~BL J OIL GRAVITY-APl (CORR) I ITEST WITNESSED BY JPRODUCTION METHOD (Flowing, gas hft, pumping--size and type of pump) 32 LIST OF ATTACHMENTS Drilling History and Gyroscopic Survey O I L-BB L GAS-MCF GAS--MCF 33 I hereby certify that the foregoing an~ attached~i~nformatlon is complete and correct as determined from all available records SIGNED · ' · (See instructions and Spaces for Additional Data on Reverse Side) · DATE~"/g:~~ ~Z. 1980 INSTRUCTIONS General' Th~s form is designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n 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 th~s 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) (~f any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately ~dentified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for thIs well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on thIs form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME ~tC~. MEAS. DEPTH TRUE VERT DEPT TOP Sad] erochi ]0620' 8909' Base Sad]erochi ]]248' 9454' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER Drilling History DS 17-2 (-22-11-15) API NO. 50-029-20486, Permit NO. 80-70 Spudded Well @ 2100 hrs, 7/17/80. Drilled and surveyed 17½" .directi6nal hole to~2715'. Ran 67 joints 13-3/8" 72# L80 Butt csg and landed at 2676'. Cmtd csg w/1908 sx Fondu cmt follov~ed by 400 sx Permafrost II cmt. ND 20" riser, set packoff and test w/2000 psi. NU BOPE and test same. Drill- out csg plus 10' new 12¼" hole. Run leakoff test to 12.0 ppg EMW. Drill and survey 12¼" directional hole to 11375' w/no problems. Ran DIL/SP/BHCS/GR and FDC/CNL/GR/CAL loas. Ran 9-5/8" 47# L80/RS95 csg and landed at 11348'. Cmtd csg w/1300 sx Class G cmt. Install packoff and test w/5000 psi. Clean out csg to 11304'. Displace well to NaC1 Down- squeeze 300 sx Permafrost "C" cmt followed by 1~8 '~6i-~ Arctic Pac fluid down 9-5/8" x 13-3/8" annulus. Ran 5½" 17# L80 LT&C tbg w/accessories. Land tbg w/tail @ 10394', pkr @ 10342. ND BOPE, NU tree and test w/5000 psi. Dis- place well to diesel. Set pkr and press test tbg and 9-5/8" x 5½" annulus. Rig lines to begin long term test. RREL @ 0730 Hrs, 8/5/80. ARCO Oil and Gas Company 'l"~-k'~ [', ~",,.' -',' ' 0",',. ' L~x September 19, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ___ CON F'- R FltF. Subject: DS 6-16 (Permit no. 80-33) DS 17-2 (Permit no. 80-70) Kuparuk E-5 (Permit no. 80-58) Dear Si r' Enclosed please find our Completion Reports, for the subject wells, including individual drilling histories and gyroscopic surveys. Updated reports will be filed as soon as perfor- ating is completed and production test data becomes available. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures CO,qPLLTi©'~ NEP,~R¥ ARCO OIL ',1, GAS GYROSCOPIC SdkVEY ',~ADIUS C,k CLI,~VATU~.E iLTiiO~ OI OPLF;A F{;~-A II~K AF f- LmF E',ACtt SURVEY DATE CO,';PUTAT I 31 AUG 80 WELL DS 17-2 K tS ELF_¥ 70. FI. JOB (DUSS-16ob3) RECORD OF SURVEY ALL CALCUL,,TIOi~S Pkl4FO,,<,q[:u i~JY I b ¢i LLECTROF,iIC CO~,PUTE,~, 1 RUE ?IE/~S, D,=IFT Vk,~TiCAL .SOB DRIFT TOTAL COORDINATES C L 0 DhPTH A,,,,: L a DEHTH SLA DIkcC D I STAt~CC D ,~', DEG · IR Ii-,'-~ UiN S U R E 5 Ap~GLL 0 'J 0 O.~;O -70.00 N O.OOE 0.00 S 0.00 100 u 12 99.99 29.99 S 6.805 0.00 N 0.11 2u0 0 U 1~9.99 12b.99 S 6.90W 0.30 S 0.11 3Uu 0 i7 299.vq 220.9¥ Sll.60E 0.70 $ 0,13 400 () lb 3~,99 329.~9 S53.00E 1.11 S 0.~9 500 0 4~ q99.99 429.99 N~4.90E 1.05 S 1.25 600 () 41 599.98 529-98 .~46.10E 0.13 S 2-1~ 700 () 33 099.97 629.97 1'~40.90E 0.64 N 2,95 mO0 0 20 799.97 729.97 N41.40E 1.23 N 3.44 900 0 24 d99.97 829.97 S85.00H 1.47 I~ 4.03 1000 0 19 999.~27 929.97 ~478.6UL 1.50 N 4.65 1100 0 10 1C99.96 lo29.96 S63.30E 1.44 N 5.08 1200 U 17 119~.96 1129.96 S74.80E 1.29 N 5.47 1300 0 13 1299.9~ 1249.96 S 3.40E 0.96 N D.74 1400 u 40 13q9.~6 1329.96 S 2.70E 0.17 N 5.78 1500 1 6 1,99.95 i429.95 S15.70E 1.36 S 6.03 1600 I 23 15')9.~J2 1529.92 S28.50E 3.39 S b.86 1700 "0 45 1699.90 16~9.90 SSO.BOE 4.82 S ~.05 1800 0 51 1799.89 1729.39 $22.30E 5.94 S 8.87 1900 1 2 lb9~.o6 1329.08 S52.90E 7.25 S 9.88 2000 1 35 1999.d5 1929.85 So2.3CE b.12 S li.99 2100 1 35 2099.U1 2029.81 NSB.TOE 8.15 S 1,.77 2200 1 3u 2199.78 2129.78 NS1.80E 7.81 S 17.4D 2300 1 19 2299.75 ~z29.75 S80.70E 7.83 S 19.91 2400 1 11 2399.72 2329.72 S55.80E 8.6~ S 21.94 u.O0 S 0 0 O 0.71 S iu ~1 42 i.18 S 19 t7 5o 1.63 S 49 51 P9 2.19 S 86 21 b8 3.00 lq 77 34 51 3.&6 .~ 70 15 41 ~,29 N 69 57 5.28 N 74 5 13 5.62 N 76 38 30 b.b2 t~ 80 Zd 5u 5.79 14 08 18 37 6.19 S 7/ i4 13 7.65 S o5 4i i1 9.38 S 59 g 48 10.68 ~ 56 11 12.25 S 53 44 i4 14.4~ S 55 54 17 i6.~7 S 61 6 i 19.12 S 65 p~ 21.40 S 68 31 25.58 S 68 29 U.OUO 0.200 0.040 0.140 0.120 0.~00 U.uSO 0.080 0.140 0.120 0.070 0.4bO 0.,3o 0.290 0.650 O.110 0.190 O.b50 0.015 0.080 0.190 0.120 ~; I 5TA,~C~a O.GO -O.tO -O.di -O.bb -0.74 -2.10 -~.b4 -~.83 -3.51 -3.80 14.30 -4.72 -D.40 -9.20 -il.7J -1~.02 -16.64 -i9.00 -21.39 -~J.57 ARCO DS 11-2 GYROSCOPIC SU,<VLY JO[~ NO. ~0SS-16653 31 AUG 80 RECORD OF SURVEY ALL CALCULATIur, S Pb-I,~FOR.~';EL~ P,Y I 6 ,4 EI_ECTRONZC CO,,~POTLR , ,;EAS. DEPTFt T R LJ F IFT V~ x'FICAL SUB DRIFT S[.r DLPTrt SLA PI,kEC ,,, DEG, vSOu C 2700 O 3J 2ROO 2900 b 31uO 8 46 3200 11 3300 3400 1~ 10 35O0 21 32 3600 2 3700 24 47 3000 26 55 3900 28 48 4000 3J 5~ 4100 33 23 200 35 20 300 3b 2o 4400 ~5C0 62 24 4600 ~700 43 1') 6800 43 39 ~900 43 5000 5100 5200 43 5300 44 9 £499.'11 =429.71 S59.00[ gb)v. To zb~9.70 So6.1oE 2699.7D ~6~9.70 2 [99.60 ~729.66 2~99.40 2629.40 ~b2.10~ 299~.00 2920.60 ,u27.6U~ 309 /.41 5~27.41 3]qS.b3 3125.83 329~.27 3223.2 ~ 33~3.97 5318.97 ,~70.40W 34~2.72 ~4t2.72 ,'~79.60~ 357b.24 3505.24 3606.~¢ 3596.64 NSO.IOW 3756.62 ¢066.62 3645.02 ;775.02 :'~79.70W 3931-70 J861,70 4o16.33 ~946.35 ~t79.8uW 4u')~.d T ~028.b7 N79.40W 41Th.d4 4108.b4 :~79.7UW 425b.61 41o5.61 N79.60W 433~.u9 426d.09 ~79.60W 44~b,46 4333,40 N79,80~ 4476.32 44o6.32 4548,8b ~+4'[8 · 86 1479,8GW 4621,32 4551.32 409~.03 46Z').63 F~79,70W 4765.72 4695.72 N78.50W 4~57.o3 4767.85 i~77.80W 4909.7~ ~839.7~ N77.50~.~ TOTAL COORDINATES 9-5P S 23. 10.16 S 24. 10.79 S 25. lZ.iO $ 23. 7.97 S 16. 1.b7 N 10. 12.49 fL Ge 17.39 iN 16. 19-74 Ii 39. 26.94 '< 67. 35.93 N 42.46 N 138 · 49.26 N 178. 56.90 N 221. 65.26 i~ 267. 74.34 ~.; 316. 84.01 N 368. 94.20 N 423. 105.o8 h 483. 116.59 I,~ 546. 128.64 N 611. 14o.79 N 678. 152.68 N 745. 164.63 I~ 813. 176.54 N 881. 188.54 ~ 949e 201.64 N 1017. 215.87 N 1085. 230.73 ," 1153. C L 0 $ U r< b 5 ,, DISTANCE ANGLL DOG LbO ,SEVEr~ I TY DLG/iOOFT 25.30 S 67 43 41 E u.390 26.55 S 67 29 13 E 0.1¥0 27.47 $ 66 52 ~. i 0.110 Zo.82 S 03 10 47 E k.OOg 19.95 S 06 26 b E iu.4~ 12.49 ~q u ~6 g~ ¢. U./63 g4.28 N 44 1~ 50 , Z.996 43.9o ,~ 63 1~ 40 v, 2.079 '/2.40 ~Q 68 9 iO ¢~ 4.o06 106.99 N 70 Z2 24 W 2.0d4 144.53 ~ 72 b4 b7 ~ 1.~lu 1~4.83 N 74 3g 34 .m 1.742 a2b.2W ~'~ 75 33 D3 W 2.122 274.92 ~ 76 16 2 '~ 1.890 324.70 377,92 N 77 9 434.32 il 77 2fl 24 W 1.95~ 494,30 ,~ 77 43 31 ~, 3.102 55u.35 ~ 77 56 .6 cV 2,~00 haP.b3 N 78 7 Z~ W 1.230 o92.95 N 78 16 38 w 0,070 701.4Z N 78 25 ~0 w 0.2o0 83u.g3 ~ 78 33 44 'w 0.381 899.13 I'q '/8 40 ~q W 0.303 90b.18 N 78 46 14 w 0.52b lo37.48 11o6.76 l'~ 1i76.24 ~ 78 41 14 W 0.307 oECTIO~ i51 -zS.g7 -Z7.42 -19.90 -9.19 4.32 21.7c ~3,0i /2.34 104,37 ~7,4~ 27J,53 322,70 431.i0 490.58 619.P0 82Z.02 ~U9.99 1~26.6~ lO95.3o £16q.25 ARCO OS IV-2 CYRObCuPIC SUF, VEY ,JOB NO. iJ0SS--i6653 31 ~UG 80 RLCOI<D OF SOt-,VE¥ AL[. CALCULATIOP~S P~f-<F(,R,,,LL. BY I ~ .,, ELECFRONIC CG~t;UIEt,, ~)EPT~I ~,,,,,,,,,~ 4. C 0 550(....' 560(~ b/00 590O 6oO0 6100 62 O0 64 O0 6500 6600 6700 6BOO 6900 ~.,7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 TPUE O~..IFT V~. ,-~TICAL SUb DRIFT ,~,,' ,,L Lr- I..¢L i~' T t t SEa D II':EC D : DEG · 44 33 4981,23 4911,23 N77,OOW 44 al 5~;54.41 ',952.41 ,'~77,30W ~+5 5 5123.25 p()53.~5 ;',,77.3 Or, qb 13 b193.75 bi~3.75 ¢~77. lOW ~5 41 5253,d9 5193-8~ N76.00W 45 37 5333.79 ~263,79 N76.30¢; 45 4o 540~,63 9353,63 ;'476,8 OW 46 4 5473, 1W 5403,19 1~75,6UW 46 ~ 554~.bl 5472,51 1~75.60v.' 45 42 ?~12.d6 p542,06 fN 75 · 30,,N 45 36 5681.W5 5611,95 N75.30w 45 9 5752. 19 56o2.19 N75.90W 45 3 5822.76 5752,76 ~75.3UW ~4 D8 5~03e45 582Je45 ~75,30v~ 45 17 5963, PB b695.'~8 .~75,20~'~ 44 5o 6034.60 5904.60 .475,50W 44 26 6105,74 &035,74 N'/5,20W 44 26 6177,13 6107.13 N75,40cv 44 18 624B,60 6178,60 2~75,40e~ G4 2 63Z(~.32 6250.32 N75.lOW ~4 ll b392,10 6322,1C ~;74.6GW 43 z~7 6~64,04 63q4,O4 ~.475 · 2 O~ 43 26 6536.43 64~6,45 N74. dOv~ 43 15 6609. 1~ 6539,1~ ~-/5,40W 42 53 6682,18 ~612,18 N75,00W 42 2U 675b-TV 6685.77 N75.40W 41 b3 6629.V5 67D9,95 f'~75.20W 41 6 6904.b4 6834,84 .~74,50~ 41 2 6~)80,23 6910,23 ,~74,7OW TOTAL COOr.,O I NAI Lb 246,16 ,~ 1221,58 261.78 N 1290,07 277.~0 ~ 1358,9~ 293.0i ?~ 1428.07 309,59 [( 149~,3W ~26.71 N 1566.cb 360,49 N 1706,21 378,30 ~ 1776.05 396,22 I~ 1845,63 414,37 N 191~.80 432.G8 N 1983,75 449,69 ~i 2052,37 467-64 N 2120,79 485,69 N 2189,34 bOZ.O0 N 225f,8~ 521,37 N 2~25,83 539,14 N 2393.57 556,77 Iq 2461,25 ~74,52 N 2D28,65 59g,71 N 2595,~ 610,80 N 2662,90 62U,66 N 2729.55 646,31 tl 2795,89 6~3,76 N 2861,93 681,06 a 2927,39 690,08 N 2992,J6 715,39 l~ 3056,22 73g,84 ,N 3119,56 C L O S U k ~ b OI S'FAi~CE a~kGLE O M DOO LbG bgVmlxlTY DLG/iOOPI 12,0.1~+ i316.30 t': 78 31 .z+ W lbdO.Wo ,~ 75 27 59 W 1529,06 1600,53 N 7U 13 17 ~' 1672,07 N 78 9 0 1743,88 N 1815,0~ 1d07,68 N 77 1w59.13 i"~ 77 47 gu W Z030,26 N 77 42 4~ W 0,197 0,410 0,165 0,/27 0.16~ 0.o91 u.12b O,loO 0,54~ 0,~17 O,O60 0,324 0,474 0,426 0,140 o,~gd O.~SO 0,484 0.398 0,340 0,40~ 0.b89 O.d~7 0,111 baC'I'IOtl 1~03,4o 137m,54 i-43,97 io57,19 i800,~+6 1872,03 i94~,30 ZOl4,2U 2084.70 2155,25 ZZ9o,44 g~66,47 k*36.k5 2505,93 ZP75,39 ZO44eUO 2114,06 2782,~4 29~9,34 ~9~6.b2 5119.7g ARC~ ~S 17-2 GYI~OSCUP I C. SUr,'v~Y JOB .4',.,' · Rtz. CURD OF SUI',:VE'Y ALL CALCLiL;,TiO~S PFF, POr<;.~LO tOY I u ~,1 ELECTRONIC COr'.PUTEi~ ,.,EA S. DEPTH [, B300 qO 39 ~..,o400 40 25 8500 ,.0 26 8600 _~9 8700 8oC)O 9bO0 B7 50 91o0 b~ 24 92 () 0 '¢ '/ ] 9400 3 f 20 9600 9700 9.800 b7 1 9900 3OuO ob 34 ~OlOO 34 51 10200 33 41 10300 ~3 44 104OO 32 10500 10600 51 45 10700 31 1 10800 30 11 10900 11000 29 b7 11100 2~~ 49 T,~UE VL.~,TICAL SU~ DRIFT TOTAL COOkDINATES C L ,.) D._,' T t~ ,Ur A D IkLC mi STA~CE [)lzO . 7.;55.07 o9~55.87 ,N73.90w [50.54 N 3182.53 7131,87 7061.87 ~474.9OW 768.02 t,; 3245.13 '/~_o 7.99 '/1~7.99 ~75. low 784.U0 ;,t 3307.77 72H4.45 '/~[i4..5 N74.10¢~ g01.92 ,~ 7361.73 7291.73 r474.6uw 819.0~ N 3431.01 7qbg.4d 7369.4o ~75.00W 835.53 N 3491.71 7517. /1 7447.71 N74.70W 851.81 N 3551.83 7596.56 7526.56 ¢474.SOW 867.98 N 3611.17 /075.76 '/6Ob.V6 ,~75.4o'~ 883.68 ,'4 367o.15 7755.4,5 7~85.40 ~.,75 · 00¢~ 899.13 N 372b.64 7c35.2Z 7765.2Z t4-13.00,, 915.73 ,N 3786.53 79]4.88 7844.88 N72. !0~¢ 933.86 14 3844.2d 7994.10 7924.10 ~71.30w 953.02 N 3902.1~ 8072.d8 oo02.88 N69.70W 973.58 d 3960.20 8151.67 b081.67 ,468.60. 995.50 ¢~ 4017.75 82'3(). 9~ &160.98 N67.40¢~ 1018.32 7'1 4074.22 8~10.98 8240.W8 ~66.90~] 1041.01 ,",, 4129.51 8391.o2 832i.82 N66.20~ 1065.04 N 4183.51 847~.52 0403.52 ,466.00w 1088.40 N 4236.23 8556.14 8486.14 ,~65.30W 11i1.~2 N 4287.5~ 8639,32 5569.32 ~64.00w 1135.39 [~ 4357.71 9722.97 d652.97 ,~62.50w 116L:.06 :t 43d6.65 8b~7.i7 ,m737.17 [~60.50'~, 1185.79 '~ 4434.0~ ~o91.~3 ¢.b21.83 N61.40~ 1211.64 N 4480.58 8977.19 6907.19 1~61.40v, 1236.57 ii 4526.31 906~.26 8993.26 NOi.iOW 1261.06 N 4570.94 9149.86 907~. 86 N59.70~,~ 1285.76 N 4614.43 q2~6.70 9166.70 N60.20W 1310.59 N 4657.35 9523.97 ~253.97 ,,;60.9OW 1334.59 ;,~ 4699. bO S U k E S A,',~G LL D JZ69.03 ~'~ 3334.78 iq 76 41 5 ~40~.~1 ,~ 7b 36 5Z W ~527.fl2 d 76 34 2~ W 3590.29 565~.b4 37i4.Ug 3175.05 ,'~ 76 g'/ 44 W ~035,52 r~ 7o 26 32 ;895.69 ,. 76 24 10 w ~956.01 4015.84 N 70 16 30 W .078.12 N 76 11 17 ~139.24 i'~ 76 4199.56 425b.85 4373.82 a~29,31 N 75 27 5~ W 4483.85 4537.45 N 79 11 i3 w -+589.86 ~, 75 i 40 W 464i.51 ~b9~.i~ N 74 43 11 W 47.1. ~1 .790.21 483b.24 4865.68 ~ 74 8 50 w DOG LEG SEVtzR I TY DEG/1GoFT 0.484 0.0~o 0.d63 0.159 0.917 0.484 0.4i~ 0.72! 0.440 0.019 0.67Z O.b12 0.801 0.674 0.909 0.[23 0.~03 1.110 b.601 0,o3o 0.833 0.~00 0.243 0.u07 bbCTiO,~ oI~TA;~C= 3Z~0.52 3315.37 3P07.62 3632.44 3754.63 3d7b.Oa ~119.60 ~240.34 4299.07 4356.D7 4.6'7.91 4522-2[ 4~28.0~ 4079e40 4729.7i 477~.~D AP, Cu ~5 1 /-2_ GYROSCOPIC SUI<VEY JOB NO. 150bS-16663 AUG bO I<LCORD ALL CALCLli. A T I &,,~$ T ,,,EAS · ~)1, ! [-- T VL .'~T I C~L L) ~', L~P, ! F T L,Je TuTAL CuuKDINAT~$ %~1200 ZY. 2,q 9411.72 93,+1.72 ,<60.60v, 1358.02 N 4741.69 L' 11;750 2~~, 11 0455.73 93~5.73 ,~60,70w i369.65 ;'~ 4762.3o ~, 11575 gb 11 9565.90 ~495.~3u 7q60.7o'~ 1398.56 ~ 4b13.d9 ,~' d, OTTO'.I ~-t~JLt.- CL(;SUR[:. 5012.94 FEET AT ~l 73 48 0 W C L O S U R E ~ D ]' ST A,,,C E ANGLb. L) N S 4932.35 ~ 74 1 b ~ ,+955.42 N lb 57 17 W 501Z.9~ ,~ 73 4~ u ~ DOG LEa SEVEI~IT¥ LJEG/iuOF'[ 0.366 0.~42 b~CTiO,~ 49g>,04 4946.42 sperr j-sun d. A Fouch~ President Mr. Bob Hines Arco Oil & Gas P. O. Box 360 Anchorage, Alaska 99510 September 3, 1980 Re: Our Boss Gyroscopic Survey Job No. Boss-16653 Well 17-2 (SEC22 T10N R15E) Prudhoe Bay Field North Slope, Alaska Date of Survey: August 31, 1980 Operator: Kirk Afflerbach Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclosures ARCO P.% 1-,'-Z GYF, O.SCOPIC .SU,-<VLY JOE INTF.xPOLAiL') T~UL VEkTIC,~L L3. EP'FHS, COO,*~OIt~ATE5 AND CLOSU~L3 Fo~~, GIVE,4 DEPTt-t$ CODE ,- -,\SU~i.D v E,<l' I C,~L ;4A' ~t_- ,~[ I--,T I ~ ~,~:_ F' 1 Pt 1~~ T,,'.,L (..b,Ji~,D I NATES C L U 3 d r< E u I ,S TA ~,~ C L AliG L r:. AUG 80 $ t.:. A TOP SAL) 1062u 8900.85 121o.73 I'4 4489.76 !~,ASF- SAi) 1124~: 94pS.9f 1369.41 i~ 476i.42 PLOG r~ACA* 113C4 9503.33 i302.41 N 4'/84.47 -q 11375 9505.90 139d.56 N 4b13.89 4651.71 'N '14 50 13 W b~38.ob ,+954.43 N f3 57 15 w 9~83.97 5012.9~ ,i 73 48 0 W ~495.90 *WIRELINE DEPTH ARCO 17- 2 LFP TI~t OTHLR DAT,-, (¢'¥'I~OSCuP I C SUI-,'VEY FO.t &VLI-~Y LVkt4 100 JL.,B FEET OF SUb SEA DEPTH. 3i AdO 8O ]7<) ? '! () ~7d a ,47 o 77 F, 970 1o 11 '/o 1/ 1570 1 ~70 1~70 16/0 1'770 lr7~ 197~) 217& 2270 2370 2470 267.) 2770 ~70 2~7l 3072 317~ 327~ 3380 3486 TRuE VL[:T I CAL ut. PT,-~ 170. 270 · 37G. 470 · 570. 670. 770. 870. 1,: /O. 1170. 1~:';'C · 1.3 1470. 1570. 1570. ]77o. 157C. 1970. 207d. 217C. 2270, 2370. 2470, 257G, 2670. 2770, 2~7G, 2970. Jb ~b 3170. 3270. 3370, 3470. 3570, SU3 3LA 1 O0 200 400 5 O0 70,. U L, .) ] 1400 1500 i 600 176U 1 1900 2OOO 2100 22D~, 2300 24 GO 2500 2600 27~ 2tGO 2900 3C(,u 3 1 o 0 3200 ~300 3400 3560 >tD-TVD D I F k Lfx ii,~C L 0 0 0 0 0 0 O 0 0 ,3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 i 2 3 6 9 16 24 VL:~ f I CAL COqR, LC T ION I OTAL COOr'c,D INA TE.$ 0,21 O 0,12 O,p4 S O,11 1.oO S 0.27 1,19 o 0,91 0,39 S 1.90 o-4Z ;~ 2.72 $.U6 :~ 3.30 1.45 N 3.61 i.47 ,'~ 4.4~ 1.49 & 4.97 1.3~ .~ 5,31 1.09 ;4 b,70 u,bu Il 5.70 u.u2 S 5.90 2.74 b 6,52 4.~4 S 7.0~ 5-55 ~ 8.6~ 0.88 S 9.47 7.v3 S 11.2~ o.21S 13.9z 7.90 5 16.65 7.7~ S 19,20 8.33 S 21,37 g,35 $ 23.01 10.02 b 24.21 10,57 b 25,09 1i.94 S Z4.79 9.54 S 20.43 1.94 S 12.64 lu.ll g 3.42 16.~o ,N 11.~7 19,03 N 33,48 25.17 m 61.05 3b.17 N 95.69 42.43 N 13b.76 ARCO F~S i7-2 L) A l A GYROSCOP I CZ SUi~VEY JOB NO. F~ET OF 60S$-166~3 SUb SLA O~Pln. 31 AUG 80 /-% L.~'[ i~ TI; 3704 392 ') 4045 4165 42~9 441q 4691 4967 5]06 5344 ~525 5666 5809 6G'~ 5 6239 ~3~3 6525 0667 6~05 o950 7D90 7230 7369 7508 7646 77~.3 7~19 8O53 8186 8318 T-<bl- VLI<TICAL ,~L~ 'Iii 367G. 3770. 3970. 4076, 4170, 4~70, 4370, 4470. 4570. 4670, 4770, 4670, 4970° 5070, 5176. 5270, 5370, 5470° 5570, ~6/0. 5770, 5870. 5970, 6070, 6170. 62'10. 6370. 6470. 6S70o 6670. 6770. 6970. '1070, SU~-, 36ou 37 u 0 3800 39 C, u ~+OCb 4100 ~+230 43C0 4403 450(; 4600 47 0 0 46 O0 490U 5 5260 53 O 0 54O0 5500 5600 5700 5~00 5900 6000 6100 6200 o 300 6400 6500 6603 67C0 6800 6900 7000 tID-TVO 33 45 58 74 94 118 149 164 221 259 297 335 374 414 454 496 539 5Sl 625 669 713 755 797 8dO 919 960 1038 1076 1113 1149 1183 1216 1248 V FRT I CAL COIiRLCT ION 9 12 13 16 20 24 31 35 37 38 3~ 39 40 4O 42 43 42 44 44 44 42 42 41 42 39 41 39 39 38 37 36 34 32 TOFAL COORD INAI'E$ 49.53 ~o.£1 Or.gZ N 280,72 7g.d3 ;~, 339.17 95.94 N 404.16 104.32 N 4 11d,99 135.62 ~ 047.56 15k,l~ 160,40 184.~3 ,'~ 927.09 202.49 222.73 243,93 ;4 1210,57 26),70 ~'~ 1307.05 287.02 ~q l~O~. 50 311.10 N 1503.~6 335.~7 ,~ 1602. 17 30U,41 l~ 1702.50 385.56 4i1,5V N 1902.89 436,60 461.93 ~ 2098.03 4~7.16 ~ 2194.~3 512.6~ ,~ 2291.71 537.68 N 2386.69 562.17 N 24~1.39 567,22 ;~ 2574.94 612.24 I'~ 2068.25 637.25 N 2759.96 660.99 684.37 N 2939.74 707.35 N 3026.25 730.97 1~ 3110.53 753.95 ARCO DS ~,"EASU[~LD 17-2 DjP Tt-I A ~,,i D L, ATA GYt(OSCuP I C f-,U~ ~VE P,Y SURVEY EVEi~ 100 JOB FEET OF 60SS-16623 SUB ,bLA DLMTH, AUC 8O [4EASUR EO D k P T d TRdE VERTICAL DL P SUB St_iA MD-I vD DIFFERENCE VERTICAL CURRLC'F ION TuTAL COO,aD Ip~ATES 8581 8710 0966 9~9o, 9343 9469 ')596 9729 ~84c) 09-/3 10096 1021 -/ 10337 1,.)4b 6 10692 10Rd8 10923 11038 ]1152 11266 7170 7270 7370 7470 7~ /0 767 (l 77 lO 7670 7970 8O70 o170 o 27 0 83-/0 6470 8570 8070 8 7'/0 bfl7O 8970 9370 9170 9270 9370 9470 7100 7200 7300 7400 750O 7603 /700 7 ~ 00 7900 bO00 ~lOo ~200 8300 ~400 8500 8~00 8700 ~00 89{)0 9000 9100 9200 9300 9400 12UO 1311 1340 1369 1396 1423 1448 1473 1499 1526 1553 15'19 1603 1626 1646 1667 1686 17o4 1722 1738 1753 1768 178Z 1796 3Z 31 29 29 2'7 27 25 25 2~ 27 27 26 24 23 20 21 19 18 16 15 15 14 14 77o,U2 198,69 820.76 641,93 26~.00 683,15 901.97 923.41. 947.09 973.20 iGOr.80 i029,93 1059.1~ 1087,4~ 1115.54 114~.4g 1174.~7 1205.31 i291.63 1319.94 1347.09 1373,43 3276.33 3358.15 3437.06 3515.29 3590,8~ 3665 · 72 3739,10 3811,3i 3684,09 3957e70 4030.80 4i01.26 4168.88 4253,93 4295.91 4355,94 4413,i3 4468,37 4522,33 4574,36 46'/3,53 4721.50 4768,92 ARCO 1 7-2 GYROSCOPIC SURVEY JO~ NO, ~30SS-166 5B AUG 80 I NT ERPL)LA TF D MFASURED DEPTH 1000 2 3000 4000 5.9o0 6,000 7O00 6000 gm.hO 1 ()O0.fl 11000 VALUES FOR TRLJF VERTICA [)EP EVLN 1000 L SUB SEA 999. 929. 1999. 1929. 2998. 2928. 3931. 3861. 4693. 4623. 54C3. 5333. 6105. 6035. 6829. 6759. 7596. 7526. 8391. 8321, 9236. 9166. FEET OF MEASURED DEPTH. TOTAL COORDINATES 1.50 N 4.65 E 8,13 S 11,96 E 1.60 N 10,39 E 74,77 N 315,98 W 189.13 N 949.53 W 344,02 N 1636.26 W 521,78 N 2325.70 W 698.41 N 2992.16 W 868.76 N 3610,94 W 1065,55 N 4183.27 W 1310.92 N 4657.14 W 4OO 6~ 1600 2000 2400 - 2800 - 3200 SURFACE LOCATION IS 2722' SNL~ 499' EWL~ SEC. 22 T I0 N~ R 15 E~ U.M. VERTICAL SECTION ARCO OIL &GAS DRILL SITE 17-2 RADIUS OF CURVATURE GYROSCOPIC SCALE: I" = I000~ SEPT. 8~ 1980 ALL DEPTHS SHOWN ARE TVD :5600 ~r 4400 ~ 5~00~ 5600 60~00 ~ TVD= 9566' TMD = 11~$75' HORIZONTAL VIEW ARCO OIL I~ GAS DRILL SITE 17-2 RADIUS OF CURVATURE GYROSCOPIC SCALE: I" = I000' SEPT. 8~ 1980 T ION~ R 15E~ UM 16 I 15 21 TVD = 9566~ TMD= 11~$75' ALL DEPTHS SHOWN ARE TVD , 4 ¢ A PETROLANE ~PANY REPORT of SUB-SURF,4CE DIREC TiONA L SURVEY ARCO 0il & Gas COMPANY D.S. 17, Well #2 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY DATE A780D0426 Directional Single Shot 8-2-80 SURVEY BY George Wainscoat, Jerry Cook OFFICE Alaska I'RUDNOt' PAY, ~ORIH S[OP~, At P, SkA ~':)b, 0-1].~75h!~, DRILLER: WAIN$COA'~/COOK JOB NO: A7:-~0I~0426 VERilt~AL SECTION CALCULATED IN PLANE" OF' DIRECTION: RECOND OF SURVEY RADIUS OF CURVATURE METHUD A tJ I ~ WLLL BAY, NO; '2 NORIFI St ~F'E, ,E?,SLIR[ II [If,']F F fIISF'] tl ANbL L'. ILE. 1 LI t~ O. 0 0 603. 0 SO 941. 0 0 1429. 1 0 '40. 1 15 _700. 0 45 2816. 1 SO 2878. 4 S0 2940. 5 lb 3002. 7 10 3095. 9 30 3127..-,° 45 3109. J 0 45 -.~ .) ~: O~.J1, 1~- ,-'-zO 3313. 14 SO ~3S44. 14 15 337o. 15 45 x407. 1 / ,30 ~_, 37. 1~~ 30 346~. '21 0 4013. 32 0 4106. 3'; 15 -1199. 36 0 4292. 39 0 --4385. ,12 0 I,R]'F T COURSe. D]RLCTION LENG1 II l-EEl 0 O. N 11 P 603. 0 3'/8~.. S 12 W 488. S 53 I' 1211. S 27 E 110. N 44 W N 72 I,.J 62. N 51 W 62. N 29 W 62. T h'lJL VE i',,'i 1 DE F'i I'[.L 0 602 940 1428 2639 2749 2815 2877 29,39 3001 N 49 W 93. 3093 N 59 W 32. 31"4 N 74 W 62. 3185 S U8 W 62. 3246 N 85 W 62. 3306 N 7/ W Sl. 3330 N 74 W 3'2, 3S67 N 72 W ,~1. 3397 N 69 W 30. 342~' N 73 W SI. dqS~ 80 W 79. 3628 PO W 92. 361 -d UO W 94. 55697 77 W 92. 3779 3'9 W '?,1. 3~62 N 77 W 9,;. 3942 N /9 W 93. 4020 N v9 W 93. 4096 N ,-'? W 93. 41/0 N /'9 W 9~. 4241 C. AL VERTICAL SUBSF. A H S[.[,l J'ON TVII 'r F LET F'E ET .00 .99 .99 .96 . 73 .71 .70 .61 .38 .01 R E C T A N G U L. A R C L C 0 0 R 0 I N A T E S E~ISTANCE FEET .... FEET 0.00 -70.00 0.39 532.99 .... 2. 0.61 870.99 4. 0.05 1358.96 O. -14.43 2569.73 -2t. -16.07 °679.71 -15.56 2/45.70 23, -1'2.42 2807.61 21. -7.24 2~69.~8 19. -1.46 293l.ol ..... 13. 0 S LI R E DOGLEG OIREuTION SEVERIT D M DGt 100F -' O0 0.00 0.00 0 0 0.00 58 N- -- 0.50 E 2.o3 N 11 0 E 0.08 05 N 0,78 E 4.11 N 11 0 E 0.15 13 S 0.10 W 0.17 S 37 32 W 0.20 24-S ........ 7,-79-E .......... 22,62- -S- 20 ~"- 9 ~E O. 10 .01 10.o:5,..,.-~ 0-~ -~.,~. O1 .61 14.89 ,j' 3o,54.61 .... O. .71 o~- . ..0°353 3115.71 · 44 37,48 3176.44 5. · 72 51.23~ 3236.72 .75 58.79 J266.75 6. .66 67.04 ~ ~,,, .06 · 36 75.90 3327.36 11 · · 81 85.40 ~ ,.~o~ .81 14. · 89- ~ 96.15 ~ 3389.89 ....... I8'~ 70 S 9.01 E 24.42 S 21 40 E 0.60 27S .......... 8.28-E 24.65 -S 19 38 E 3.38 u~ S 5.56 E ~-.,2 S 14 29 E 5.25 02 %; 0.95 E 19.04 S 2 52 E 3.10 88--S ............. 3:36 W- -14.28 -S 13 37~W-~4.98 41S 11.84 W 12.52 S 73 57 W 3.92 43,:S , 15.94 W 15.95 -S-88 28-W 5.47 75,./N ~25.54 W ~o.~ 82 N 81 39 W 5.19 26 N' , ;37.89 W 38.26 N 82 5 W 6.46 64' N ...... 52.35 W 52.A'~ :; --,1, ~,, -N-83 ~1 W~ 16 85 N 92 N 51N 59.95 W 60.3'; N 85 2'9 W 6.45 oi.96 W -68.~'=,- 8*'~ - ' c,,. N ,,_ 31 W t-,.TM..,~ 76.-14 W 77.31 N 81 26 LO 5.94 85.4:2 W 86.67 N 80 1~ W 7.38 97.27'-N~79~t4'W-- 0.58 18-N ............ 95i56"W ..... 125,24 55 -~ iol. 60 3542 . ' .59 201.51 3o27. S9 38. .54 242.52 3709.54 46. .05 2'87.16 5792.05 56. O1N 124.01W 126.50 N 78 36 W 3.79 41N loO.St~W--- 163.$6---N 78 55 W .... 2.45 44 N 2~0.16 W 203.82 N 79 8 W 1.60 70 N 240.74 W 245.22 N 79 1W 1.83 Oo N - -284.78-W- 290.24 -N 78 52 W 3.10 ,61 335.15 3872.61 .,. u 385.53 3750.'.30 .56' 438.45 4026.,.o~ .55 494.44 4100.3,7, .04 -~ 554.17 417t.04 66. 76. 86. '27. 109. 12 N 332.13 W 338. 69 N ........ 581.83~W .... 389, 90 N 434.36 W 44'' 70 N 489.9S W 499. 22-N .... 549,2t W --559, 65 N 78 44 W 2.39 46 N 78 39 W 2.69 97 ?4 78 41W 1.88 57 N 78 43 W 3.25 90 ...... N 78 45~W~- 3.23 RCL) OIL GAS NOR11--t SL OI-'E ~ A L. A SI',. A CORF'UTATION PAGE NO. 2 ---tIME DAYE - 08 ** 35: 05 25-AUG-80 IEASURFI; DRTF f I'~I~II- 1 DLI-"I'I-i ANGL. f. D] I-<[.L, TION F t-. L 1" I~ ~'1 D 4485, ,13 i5 .,)21, 44 30 ~'14, 45 0 6020, 46 0 '26, 45 1~' ~..,. 6838, 4b '15 7340, 44 45 7039, 43 0 8090. 42 0 8385,- 4] 0 8084. 38 15 ~10t. 37 0 9422. 27 jO 9790. 38 0 10424. 33 30 N / &~ W N 78 W- 76 W N 73 W N 72 W 72 W N 73 W N 7] W N 7'.' W N 72 W N 72 ~ 72 N 66 N z o N 5~ 10924, 30 15 N 56 1]].73, 29 0 N 54 1 ~ 275, 29 0 N 52 CL USURF TRLIE COURSE VERTICAL VERr]CAL SUBSE. A LENGTH DJ_I-' Tl-I SE-CI ION TVIJ FE~ F £. [-:_ T Fl-_El FEE]' 100. ~6. 474, 506, 312, 502, 499. 251. -295, 4314.62 621.23 4244.62 4700.99-- 989.53 4630.99 5073.83 1356.74 5003.83 5406.06 1693.95 5336.06 5759.93 2055,41 5689,93 A N G U L A R C L. 0 S U R E. DOGLEG D 1N A T E S DISTANCE DIRECTION SEVERIT'~ FEET ...... FEET D M DG/IOOF] 122.72 N 615.57 W 627.68 N 78 44 W 1.42 -199.96--N- -978.94 W-- 999.15- N 78 27 W 0.23 283.09 N 1339.05 W 1368.64 N 78 4 W 0.28 373.43 N 1664.79 W 1706.16 N 77 21W 0.50 -~-482~.-t~9-t4~2009.73-W--2066..77 .... N-76-30-W .... 0.20 t:' 1 NAL 499, 217, 321, 368, 634. W 500. W 249. W 5978,62 2277,88 5908,62 633P,03~. 2634,17 676~_ =,03 6691,72 2979.87 6621.72 6876.77 3149.41 6806.77 7097.71- 3344.81 ...... 7027.71 550.96 N '-'")°1 , 38 W 2288 658,16---N ...... 2561,39-~W -2644 765.03 N 2890,28 W 2989 818.83 N 305],08 W 3159. 879.2a,-N ....... -~236.99 W 33~4., 7482.02 3662.92 7,112.02 977.57 N 3539.63 W 2'653.89 3795.35 . 758~.~.89' 1018 51 N.~ 3665.61 W 7909,40' '-3989 ;'~48 '" 783,-- · 4b ~ .ZOeS~ f6T~TN ...... ~3846.92 W o ~c,,~ 37 4213.'28~ ' ~. 8130. ~7 1186.84~ N 4049.37 W 8714· 78 ~-4524 · 53' ...... 8644.78 ..~('~8'~',-~,, 9'~" f.J .4~63 ,16 W 9139 S2 4828 92 9069,$2 1.~4,34 N 4~79,4t W 9355.77 4947,52 9285.77 1604.94 N--4680.2~4 W 9444.98 4994.68 9374.98 1634.69 N 4719.72 W 68 N 76 4 W 0,16 60 -N-75-35.-W~-0.24 82 N 75 10 W 0,45 05 N 74 59 W 0,48 27---N~74 48-W .... 0,34 3672.14 N 74 34 W 0.55 3804.48- N-74 -28 W - 0.58 3997.85 N 74 12 W 1.14 4219.72 N 73 40 W 0.68 4577,08~-N~72~25 W- 1,02 4829,62 N 71 2q W 0,68 4947.7o N 71 4 W- 0.64 4994.79 N 70 54 W 0.95 RECTI ON STANCE N 70 DEGS 53 MINS 47 SECS W 4994.79 FEET spepp -sun J. A. Fouch~ President Mr. Bob Hines Arco Oil & Gas P. O. Box 360 Anchorage, Alaska 99510 September 3, 1980 Re: Our Boss Gyroscopic Survey Job No. Boss-16653 Well 17-2 (SEC22 TION R15E) Prudhoe Bay Field North Slope, Alaska Date of Survey: August 31, 1980 Operator: Kirk Afflerbach Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclosures CO,nPLETIQ ~ kKP,.)2.[ ARCO OIL & CAS GY,~OSCC,[~ I C SdI, ViZY RADIUS OF CUIxVATLJ~E ILTt~uu OF SURVEY DATE CQ,'~PU FAT I Uh AL;_ RECORD OF CALCUL~-~TIO,,~S [-~k_~qFO,,,,l[.U l-JY SURVEY I b MEAS, DEP TH :.) 1,-, VL ~,T iCAL DEPTH 0 100 d 12 99.99 200 300 0 17 299.~q 400 ~) 16 39-~. 99 500 0 4b 499,99 600 0 41 599.98 700 O 33 o99,97 o00 C,, 20 799,97 900 0 24 dv9,97 1000 1100 0 10 1099,96 ~"~ 12 O0 0 17 119~,96 1300 0 13 1299,96 1400 0 40 13q9-')6 1500 1 6 1600 ] 23 1700 0 4b 1699.~0 ldO0 0 51 1 ~99.89 1900 1 ? 1U99.08 2000 1 35 199-~. d5 2100 1 35 2099.81 2200 I 3U 2199.78 2300 1 19 22:)9.75 2400 1 11 2399.72 · DRIFT D Il,cC DEG. -7o.00 ;40.OOE z9.99 S 6.8GE 1~.99 $ 6.90W 229.95 Sll.60E 329-99 S53.00E 429,99 N44,90b 529,98 N46.10E 6Z9,97 N40,90E 729.97 N41.40E 929.97 i~78,6CL 1029.96 $63-30E 1129-96 $74-80E 12g9,96 $ 3,40E i329.96 S 2.70E i429,95 1529.92 S28.50E 1629-90 S50.80E 1729.89 S22,30E 1829.88 S52,90E 1929.85 S~2,30E 2029,81 ig83.?OE 2129.78 NS1.80E Z229.75 S80.70E 2329.72 $~.8~E 31 AUG 80 wELL DS 17-2 K B ELbV 70. FI. JO~ (bOSS-16653) LLECTRONIC COP,PUTL~x TO~\L COORDINATES O.O0 5 0.00 ~ 0.00 f4 0.1~ E 0.30 S 0,11 F 0.70 $ 0.13 E 1.Il $ 0.~9 E ~.05 $ 1.25 L 0,13 S 2,18 E 0.64 N 2.95 h 1.23 N 3.44 E 1.47 I~ 4.03 E 1.50 ii 4.65 g 1.44 N 5.08 E 1.29 N 5.47 L 0.96 IN 5.74 ~ 0.17 N 5,78 E 1,~6 S 6.03 E 3.39 S 6.66 E 4.82 $ 8.05 E 5,94 S 8,87 E 7.25 S 9.88 E b.12 $ li,99 E 8.15 $ 1~,77 ~ 7.8i S 17.4D h 7.83 S 19.91 E 8.64 S 21.94 E C L O U I STA~C~: O,11 0.32 o.71 1.18 i,63 2,19 3,00 3,00 ~+,29 b.Zfl 5.62 5,82 5.79 6.19 7,65 9,38 10,68 12.25 i4,4~ i6.~7 19.12 21.40 U R E S AI'~GLr D N~ S S 0 0 0 A t'~ 86 36 0 m $ 20 31 35 E S lo 31 42 E S 19 t7 50 b 54951 ;9 b 5 86 21 58 E S 68 29 3b E DOG LEG 5bVERITY JEo/iOOFT O.OOO 0.200 O,040 0,540 0,120 0.140 O-gOO O.ubO 0,080 o.120 O.uTO 0.4bO O.43U 0,650 0.110 0.190 O.bSO U.Ol~ 0.080 0.190 S~CTIOm DISI'A,~C~ O.CO -o.10 -O.gi -0.35 -0.74 -t.53 -2.10 -4,b4 -2,83 -3,31 -3.8b -4,3U -4,72 -b.09 -P.40 -9,20 -lO,3P -11.7J -1~.02 -16.64 -19.06 -Z1,39 -z3,57 ARCO DS 1 1-2 GYROSCOP!C SU,~VLY JOB NO. 60SS-16653 31 AUG 80 RECORD OF SURVEY ALL CALCULATIu~'~$ PERFOI<NEL~ BY I B ,v, ELECTRONIC COhIPUTLR T R LJ["- ,',EAS. t),..~IFT VI ~<TICAL DEPTt~ A[...S L L :.., L k IVI $UR. DRIFT SuA D I ,iEC DCG. 2_500 u 40 ~_499. '/1 ,- 4Z9.71 S59.00E ~,,...Z 600 0 37 zb';v.7u 25,:9.7o S66. IuE 27~0 0 ~ J 2699.-/U ~6J9.70 S33.3uE 2~(JO ~ 29 2 /9~.OO ~7~9.E, 6 2900 5 ~1 2899.40 2629.40 ,~2 · lO,'~ 3000 ~ 52 2998.60 2926.60 31UO ~ 46 309l.~1 ~u27.41 ,q6u.lO~ 3200 11 33 31q5.b3 3125.83 N87.30~v 3JO0 14 24 3293.27 52~.27 ;~80.70v~ 3400 19 10 33':3.97 5318.97 3500 21 32 3402.72 ~4i2.72 N79.6Ow 3600 23 ~ 357b.2~ 3505.24 ;~80.60W 3700 24 47 3666.~4 3596.64 NBO.iOW 3800 26 55 3756.&2 5OW6.&2 N79.Tuk, 3900 28 48 3045.02 3775.02 N79.TOW 4woo 30 5V 3931.70 ~861.70 4100 33 23 4~16.33 ~V46.33 1~79.80W '+200 35 20 z+ug~.~ ~02~.87 N79.4OW ~4300 38 2o 417h.84 4108.84 7~79.70W 4400 41 14 4255.61 4165.61 4500 ~2 28 433~,.09 426~.09 ;~79.60W 4600 ~+3 t~ 4403.46 4333.40 N79,80W 4700 43 19 4476. 32 4406.32 4900 43 2~ 4621.32 4551.32 5000 4D 54 4093,03 4643.63 N79.7OW 5100 4S 49 4765.72 4695,72 N78,50v~ 5200 43 53 4837.03 4767,83 ~477.80W TOTAL COORD INATEb 9.59 S 23.4~ L 10.16 b 24.52 E 10.7') S 25.26 E lZ.iO S 23.93 E 7.97 S 18.29 E 1.57 ;,~ 10.31 E 12.49 I( 0.16 17,39 ~ 16,94 w 19.74' i~ 39,27 26.94 N 67.20 '~ 3D.93 N 100.77 W 42.46 N 138.16 49.26 N 178,14 56.90 N 221.08 W 65.26 ~ 267.07 74.34 N 316.0b W 84.01 N 368.46 94.20 N 423,98 105.o8 N 483.00 w tlb.59 N 546.02 W 128,64 N 611.65 14o,79 N 678.50 152.68 N 745.96 ',,~ 164.03 ~x~ 813.74 176.54 N 881.62 W 16~.54 ~ 949.65 201.64 N 1017.69 215.87 N 1065.50 230.7~ ,,, 1153.39 C L u S U F< L S P I STANCE ANGLL. D ;.1 z5,30 S 67 43 47 E 26.55 S 67 29 13 Z7,47 6 66 52 = E /0.82 S 03 10 47 E 19,95 S ~6 26 b E 12.49 N u 24.28 43.~0 72,40 106,99 1,4,5j 104.83 N 74 32 34 W Z2b,29 ~'~ 75 33 b~ W 274.92 324.~0 ~ 7o 4P 47 W 3[7.92 N 77 9 434.32 ~ 77 28 24 W 494.30 550.33 695,03 N 78 7 Z~ W o92,95 N 7~ 701,42 N 78 2~ 50 W 83~,23 N 78 33 44 W 899,13 ~q f6 40 3~ W 90b,18 1037,48 ~ 78 47 33 W 1106,76 ;'~ 7~ 4~ 9 W 1~76,24 N 78 41 14 W DOG L ~G SEVERITY DLG/iOOFT u.390 O.lWO u-llO 2.002 3.040 u. 163 2.996 2,o79 4.886 2.od4 1.~1~ 1 · 742 2,i22 1.690 2,i83 2 1.95~ 3.102 2.~00 1.230 O,O-l~ 0,268 0,381 0.303 0.526 U,~82 0.344 0.30'/ olEC T I Ol,,l -a5,~7 -Z7.42 -19.90 -9.1W 4.32 /2.3~ ~g7,40 27J,53 322.70 mf5,37 490.58 619.D0 822.02 089.99 958.11 1026.63 lo95.3o 1164.25 ARC() ,r CYRO$CUP TC SUI<VLY JOB ~.0SS-166~;3 31 ~UG 8O RE. COIxD OF SURVEY ALL. CALCULATIOP~S PERFORi,,LD BY I 15 ,. ELECTRONIC CG~,IPUIEK ~5400 44 33 5500 44 41 56.90 ~b 5 5/00 ab 5dO0 45 5900 45 6000 45 610 (; 6200 63u0 45 42 6400 45 36 6500 4~ 9 6600 45 3 6700 6BO0 45 6900 44 ~000 44 26 100 44 26 7200 44 7300 44 7400 44 11 7500 43 47 7600 43 26 7700 ~3 15 7800 42 53 7900 42 20 8000 41 b3 8100 41 6 8200 41 2 TPU,: Vc~xTICAL SLIb DRIFT TOTAL COOrxDINAIE5 C L L;Li;Tti SEA D~G. 4981,23 4911-23 N 77.00~'~ 246,16 ,~ 1221,5.4 505Z.41 ~+982.41 ?~77.30W 261.78 N 1290,07 b125,25 P055.25 N77.30~'. 277.30 ~ 1358,9Z 5193,75 D123.75 1'~77, lOW 293,01 ~ 1428.07 5263,B9 5193.8U ~76,00W 309,59 5333. ~ ~263,79 N76.30W 326.71 N 5403,63 933b,63 N76,80W 345,~6 N 1636,~4 5473.1W 5403,19 ~75,60W 360,49 554Z,51 5472,51 ~75,80v.' 378.30 ~ 1776.05 b~12,06 >5~2.06 ~75 · 30'.~ 396,22 I~ 1845,63 56ql.95 5611.95 N75 · 30'.'~ ~14,37 N 191~.80 5752.19 56o2.19 N75.90W 432,06 N 1983,75 5822,76 575~,76 ~75,3O'W 449,69 589J,45 5823.45 ~75.30~ 46Y,64 5~63, ~8 5693.98 .~75,20~'~ 485,69 6o3~.60 5904.60 .~75.50W bOS.O0 N 225~,84 6105,74 6035,74 N75,2OW 521,37 6177,13 6107.13 N75,40~ 53~,14 6Z48,60 6178,60 N75,40~ 556,77 6520.32 6250,32 N75,lOW 574,52 N 2528,6b 6392.10 6322,10 ;~74.60W 59Z,71 N 2595,U4 6~64,o4 63a4,04 ;'~ 5,20W 610,8u N 2662,gU 6536,43 o4~6,43 N74.UOW 628,66 N 2729,55 6609.14 653W,1~ ~75,40W 646,31 6682.18 6612,18 N75,00~ 663-76 N 2861,93 6755.77 6685.77 N75.40W 681,06 6B29,95 6759,95 F. 75,20W 698.08 6904,84 o834,8g N74.50~ 715.39 6980,23 6910.23 :~74.70W 73Z.b4 :~ 3119,56 ,~NGLE D M 12,0.1, N 78 36 24 ~ 1316,36 al 7B 31 ~+4 W 1457.8~ N 7b 24 17 ~ 1529,06 r~ ~8 19 6 ~ 16~0.53 N Y~ lB 17 ~ 1672,07 N 78 9 0 w 1743,88 N 7U 4 10 ~. 181b,~9 ,q 77 DB $2 ~ 1867.68 N 77 53 0 ~ 1959,13 N 77 47 gu W 4030,L6 :~ 77 42 4~+ W' 21ol.06 N 77 30 ~8 W Z171,74 N 77 33 D3 w 2Z4/,57 ~ 77 29 30 W Z~13.3Z 1~ 77 25 34 W 2383,55 N 77 21 b~ W 2453,54 Iq 77 tS 21 W 2523,44 ,'~ 77 15 11 W ZP93,09 1'4 77 11 58 W LEG i TY DEG/iOOPI 0,470 0,197 0,410 0-£65 0,~27 O.16S 0,091 O.12b u. DU9 O.luO 0,542 O,J17 0.324 0.474 0,426 0,140 0,140 0.~9~ 0.~80 0,484 0.39~ 0,340 0,40~ 0.~89 0,45~ 0.837 O.11i b,-'CT IO~ 1~03.4o 137~,b4 1-43 · 9 7 1657,19 17g~.6~ 1800,46 1872.03 Z014,20 2155.25 2g90,44 ~366,47 JO44. ~0 2714,06 2782.84 ~ 1 · 27 Z~19,34 ggo6.b2 3053.6~ 31i9.7g 31b~.26 ARCo GYI~OSCU~-~IC SLJ,=~,LY Jvb 14,,.,' · ~50ob-16653 AdG 80 RLCuI(D OF ..qURVEY A[.L CALCULATIOI,S PFi~,kOlx,.,t_O I]Y I d ,4 ELECTRO~,IIC COMPUTER ~.,E/~S. u,,.IFr DEP Trt A, [., VLRTICAL $U8 DRIFT TOTAL COORDINATES C L d DL,=TH ,b~_ A D I RFC u, I STA~NC E [)EG · 8.300 4<5 39 7055.07 '~.~SaO0 40 25 7131.8Z RbOO '.U 2& 7207.99 8000 bTuO 'SH 5~ 756].73 b~O0 9wOO 91oo 9200 37 ] 7755.4.) 9300 9400 9500 37 52 7994.10 9600 9700 J 1 5] 81bl.67 9800 37 11 8c30.9d 9900 0000 ~5 54 8391.U2 OlOO 34 51 8473.52 10200 ~3 41 8056.14 10500 33 44 0659.32 10400 32 4~ q722.97 10500 32 33 8b07.i7 10600 31 45 8~91.~3 10700 bl 1 8977. 19 10800 30 11 906~.26 10900 29 49 9149.06 11000 29 11100 2e 49 9523.97 5985.87 N73.qOw /50.54 N 3182.53 7061.87 ~74.9u~' 768.02 51>7.99 r~75. lOW 'lc:4.80 N 3307,77 '/2i4.~5 N74. low 801.92 N 3369.91 /291.73 .~74.6ow' 819.0~+ ~.~ 3431.01 7369.40 ~.~75. OO~ 83b,53 N 3491,71 -~447.71 [~14.70W 851.81 7526.56 F474.8 o~, 867.98 -/60b,76 N75,4u'~ 883.68 7085.40 i',:7 5 · O 0¢~ ~99.13 N 3725.64 7 7(05.2Z ~73.0U~. 915.73 N 3786.53 7844.88 N72.10w 933.86 ~'~ 3844.20 7924.10 1~71.30w 953.02 oo02.B~ N69.70w 973.D8 80~t.67 N68.60v, 99p.50 6160.98 N67.40.'~ 1018.32 ~240.~8 N66.90W 104i.ol o32i.82 N66.20~. 1065.0g N 4163.51 0403.52 .~66.00w 1088.43 ~486.14 li65.3uW 1ii1.~2 N 4287.5~ 8569.32 ~{64.00w 1135.59 N 4337.71 o652.97 ,q62.50w 116C.06 ;~737.17 .160.50~ 1185.79 c821.83 N61.40w 1211.64 6907.19 No 1 · 40~.~ 1236.57 I.~ 4526.31 8993.26 N61. i0~ 1261.06 N 5079.86 N59.70~¥ 1285.76 N 4614.43 ~ 166.70 N60.20¢.' 1310.59 N 4657.35 ~253.97 ..~60.gGw 1534.59 $ U R E 5 A,,~GLE D *139.24 i, 76 5 1W 4199.56 N 75 58 0 ~ 4255.85 N 75 DO 35 w 4~29.31 N 75 27 5g W 4485.85 N 75 19 b4 ~ 0537.45 N 75 11 i3 w 4589.86 t, 75 i 40 W 464i.51 ~ 74 52 4 ~ 409~.i8 N 74 43 11 W 4~1.71 ~ 74 ~4 3P ~ '+7W0.21 N 74 25 48 W 4838.24 N 74 16 59 ~ 4805.68 0~ 74 8 50 ~ DOG LEG SgVkk I TY DEG/1OOFT 0.510 0.4~4 O.w~o 0.159 0.917 0.484 O.4iO 0.727 0.440 0.019 0.672 0.512 0-801 0.674 0.989 O. /23 1.180 0.,+03 1.110 0,601 0.o3~ 0.740 0,833 O.bO0 0.243 5bCTiON oI~TA[~Ct 3~44.30 3PU7.62 5o9~.7U 3754.63 3014.91 387b.Oz 3996.4b 4028°04 ~llW.80 41~0~ ~240.34 4299.07 4356.27 4412.6~ 4522.2! 4~g8,03 4079,46 4729,71 477~,95 4dgT,6W GYRuSCOPIC 5UNVLY ,JOB hO, 15055-166 63 51 AUG bO I4LCORD Ok 5U,xVEY ALL CALCLJLATIo,~S PCRFO~4,,,z¢ BY ! 6 ,.: LL~CTRUI4IC CO:~PUTu,~ T,~UC i,,EAS. ~)i- I FT VLmT ICAL [.EPTtt A,,t~L~_ ~.Li'Trt DR IFT ~ · TOTAL C~)ui<DIKATES · ,~1200 /F, 2,q 9411.72 93~+i.72 ,'~'60.60v, 1358.02 ;N 4741.69 l12bO 28 11 9~b5.73 q3~5.73 ,~60.70v, 1369.65 N 4762.30 11375 2~, 11 9565.~,0 ~95.V~ N60.TG,~, 139b.56 ~ ~13.d9 BOTTOM ~Lt. CI, u,SUR,[- 5o12.94 FEET AT ~,~ 73 48 0 W C L c~ .S U R E ~ U i ST A,,,C E Ai~ G L b_ 4932.33 ;N 74 1 b w N95b.42 ,i /m 57 iF W bOtZ.94 ,N 73 46 u DOG LEG SEVEklT~ 0.36b 0.b42 ~.uuO ARCO t'~.~ 17-2 GYROSCOPIC SURVP_F JOtS NO. F$0S5-10653 INTi,~P,,}LATL,) T,~U~: VEi-,TiC~-NL DEP'FF~S~ COO,-~DINATE$ AND CLOSU~LS FO~,~ GIVEN DEFT[IS l'r~U b. CUL)E ,-' i ,,\.S U,( [': ¢ v E,,, T ~ C,,,L ;4A ~E D, L I..- T t I S'LPTH l',..,, T i\L CUd,~C I NATES u ~ S TA t~ C r.... ANG L r:.. AUG 80 SbA TOP SALJ 1062U &90o.65 121(o.73 I'4 4489.76 HASF S**l} 1l¢4~; 9423.97 1369.41 ['~ 4761.42 PLUG F~ACK* 11304 9503.33 i3o2.41 N 4784.47 TD 11375 9505.90 i39d.56 N 4~13.89 4651.71 ,+954.43 ~ F3 57 15 ~ 9383.97 5ulZ.~ N 73 48 0 W v495.90 *WIRELINE DEPTH ANC, O h5 1-/-2 OTHLR L)~ T,-, (:YROSCuPIC SUHVEY FO,< LVLIqY LVk~ lO0 JOB FEET OF SUm S~:A DEPTH. 3i AdO 8O ] 70 '~7d 57,,) 67 o 77 i,rJ 970 1arc, 11 '/o 1 ?';' ~) 147 (; 1570 16Z0 1770 1F73 1~7,) 2:) 10 217G 2270 2 't 70 2476 25F0 267,) 2770 2870 2o7l ~ 174 32'/~ 33~0 3~86 35~ TRUE VEF:TICAL SUB uLPTn St A 170. 100 270 · 200 370. 470 · 4 570. 50C 67d · 770. 870, 800 970. 90~ 1070, lOGO 117 O · lzTO, ] 3 ?u. 13~.3 i47&. 1403 157(;. 1500 1670. 1600 177o. 17&O 1670. 1600 197C). i900 ?070 · 200O 2~7G. 2270, 2200 2370, 2300 2~70, 24G0 2570. 250J 2670. 2600 2770, 2700 2~70, 2970, 2900 3b ~u. 3170, 3100 3270, 3200 3370, 3300 3~70, 3400 357(). 3500 MD-TVD D I F F LRE,,:CE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 1 2 3 6 9 16 24 V~r~ [ I CAL CORRECTION I OTAL COOi-(D I~'~ATE. S 9 10 10 11 9 1 16 25 42 0,21 ~ 0,12 E O,p4 $ 0,11 L 1,00 S 0.27 1,19 S 0,91 E 0,39 S 1,90 o.4z iq 2.72 E .L.Ob :~I 3,30 E 1.45 N 3,61 F- 1.47 ,',i 4,48 L 1,49 h 4,97 E 1,3~- N 5,31 E 1,09 N 5,70 E 0.50 :q 5.7o i 0.02 S 5.90 2.74 b 6.52 E 4.:;4 .5 7.08 E b.55 $ d.6O L O.d8 S 9.4-7 L 7.V3 & 11.20 E o,21 6 13.9~ 7.90 S 16.65 7.7~+ S 19,20 d,55 S 21,37 i:. ,SD S 23,01 E · 02 S 24.21 E · 57 ~ 25.09 .94 $ 24.'79 E · 54 S 20,43 IF. .94 .5 12.64 E · 11 & 3.42 E .03 lq 33,48 · 17 t~ 61,Ob · 17 N 95.69 W .43 N 135,76 ; ,EASUF, L'O 9L~'TH FI-ii bY~O$CUF' I C SUi~VLY 100 JOb FEET Ot- BOSS-166;3 SUB SLA O[~Plm. 31 AUG 8U /-% F';I.. SLJi-, L D TI; 3704 4045 416!) 42~.9 4419 4b54 4591 4o67 bi()6 53B4 ~525 5~09 P~52 0239 63~3 6625 6667 0950 7090 7230 7369 7508 7646 77~3 7~19 ~053 8186 ~318 YLP, TICAL r c~[it SU~ ;' iD-T v'O VERTICAL SL.A DIi-FLRLKCE COllI~LC T ION 367C. 3600 35 377 (, · 37 o ',3 45 38 lO. 3800 58 3972). 3900 /4 4070 · ~OUO 94 4170, 4100 118 4270° ~+200 1:+9 4370, 43C0 184 4470, 440,0 221 4570. 4500 259 4670° 4600 297 4170. 4700 335 4870. 4800 374 4970. 4900 414 5070 · 5L~O0 454 5170. 5100 496 5270. 5200 539 5370. 5300 5~¢1 5470. 5400 625 5670. 5500 669 :~67C). 5600 713 5 170. 5700 755 5870, 5800 797 5970. 5900 838 6070 · 6000 880 6170. 6100 919 62 10, 62(50 960 63'?0. 6300 999 6470. 6400 1038 6570. 6500 1076 66'10. 6603 1113 6770, 67C0 1149 ~870. 680.; 1183 6970° 6900 1216 7070, 7060 1248 9 12 2 C 24 31 35 37 38 38 39 4O 40 42 43 42 44 44 44 42 42 41 42 39 41 39 39 38 37 36 34 33 TOTAL COOND I[,;AI'ES 49.53 I, 179,61 bo.Z1 :~ 227,78 07.9Z r,~ 280,72 90,94 N 404,16 104.3Z N 476,05 11d,99 I~ 558.3~ 135,62 N 047.56 152,19 N 739.76 160.40 ~q 184.~3 ,q 9J7.09 222.73 N 1115.25 243,93 ;4 1210.57 2~;.7U N 1307.05 267.o2 m 1404.50 Bl1.10 N 1503.46 335.07 ,~ 1602. 77 300.41 ~ 1702,~0 385,56 ~'4 lb03,17 4il,b? .N 1902,89 436.60 ~ 2000,87 461.93 N 2098,03 4~7,16 t~ 2194,~3 512.67 ,q 2291,7i 537.68 ,~ 2386,6~ 562.17 N 24dl.39 597.22 ~ 2574.94 612.24 N 2~68.2D 637.25 N 2759,96 660.99 N 2850.67 684,37 N 2939,74 707,35 N 3026,25 730,97 N 3110,53 753,95 N 3193,74 ARCO ~uEASU!~LD {.) L l'~ T H AND [,ATA GYROSCOPIC SURVEY EVERY EVEN 100 JOB NO, FEET OF B05S-16653 SUB SLA DLPTH, 31 AUG 80 871'3 b966 9~)9~ 9343 9469 9596 9 723 907'3 10096 10717 10337 10456 iOAgP lt)qo8 10o2 ? 11038 11152 11266 TRUE VL- R T I CAL L) r P T 7270, 7370, 7470, 75 lO · 767(], 7770, 76 '! 0 · 7970. 8070 · 6170. 0270, 8370. 8470, 8570. 8670, 8770, 8870, 8970, 9070, 9170. 9270, 9370, 9470, SUB SL'A /10 720 730 740 750 /60 /70 7bO 790 5 O0 810 620 b40 850 860 870 080 89O 90O 910 920 930 94O ii, D- T VD D IFF:F,'ENCE 1280 1311 1340 1369 1396 1423 1448 1473 1499 1526 1553 1579 1603 1626 1646 1667 1686 1704 1722 1738 1753 1708 1782 1796 VERTICAL CORRECTION 3Z 31 29 29 2'7 27 25 25 26 27 27 26 24 23 20 21 19 18 16 15 15 14 14 TwTAL COOt,ID I r~ATh~ 77o.m2 N 3276.33 798,69 ,~ 3358.15 820,76 14 3.37,06 841.93 N 3515.29 g63.00 N 3590,8~ 683,15 ii 3665,7g 901,97 ~ 3739,10 523.41 N 3811.3i 947,09 N 9/J,20 N 3957,70 i029,93 ,~ 4101.26 1059.i~ N 4168.88 1087,4~ N 42~3,93 1115,5~ N 4295,91 1t4~,42 N 4355,94 1174,~7 N 4413,13 1205,31 IN 4468,37 i23~,7b m 4522,33 1202,96 N 4574,36 i29i,63 N 4624,24 1319.94 N 4673,53 1347.09 N 4721.50 1375,43 Iq 4768,92 A~CO 7-? GYROSCOPIC SURVEY JOB NO, BOSS-i6663 AUG 80 INTERPOLATF9 VALUES FO TR MFAStJR[iD VERT I F)EP TH I.)E P EVEN LJ[ CAL IH 1000 999. 2000 lO99. 3O00 299~. 4000 3931. 50(~0 4693. 6990 5403. 7O00 6105. d©O0 6829. Oqg9 7596. lO00g 8391, llOOO 9236, 1000 FEET OF MEASURED DEPTH. SUB SEA TOTAL COORDINATES 929. 1.50 N 4.65 1929. 8,13 S 11,96 2928. 1,60 N 10,39 3861. 74,77 N 31b.98 4623. 189.13 N 949.53 5333, 344.02 N 1636.26 6035. 521,78 N 2325,70 6759. 698.41 N 2992.16 7526. 868,76 N 3610.94 8321. 1065.55 N 4183,27 9166. 1310.92 N 4657.14 1600 - 2000- 2400- 2800- SURFACE LOCATION IS 2722' SNL~ 499' EWL~ SEC. 22 T I0 N~ R 15 E~ U.M. VERTICAL SECTION ARCO OIL & GAS DRILL SITE 17-2 RADIUS OF CURVATURE GYROSCOPIC SCALE= I" = I000' SEPT. 8, 1980 ALL DEPTHS SHOWN AR E TVD $600 ~tr 8800 ~ 9200~ TVD= 9566' TMD = 11~375' HORIZONTAL VIEW ARCO OIL I~ GAS DRILL SITE 17- 2. RADIUS OF CURVATURE (~YROSCOPIC SCALE: I" = I000' SEPT. 8~ 1980 TVD = 9566' TMD = I 1~:575' T lONeR 15E, UM 16 21 15 CURVE DATA LOCATED IN THE APPENDIX ARCO Oil and Ga,~-Company North Ala~ D~stnct Post Ofhce Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon DIstrict Operahons Engineer September 23, 1980 Reference: ARCO Open Hole Finals D.S. 2-17 8/8/80 D.S. 2-17 8/8/80 D.S. 2-17 8/8/8O D.S. 2-17 8/8/80 D,S. 2-17 8/8/80 D.S. 11-4 7/21/80 8/1/80 D.S. 17-2 8/1/80 D.S. 17-2 7/31/80 D.S. 17-2 7/31/80 D.S. 17-2 8/1/80 FDC Run 1 5" FDC/CNL L~ Run 1 5" DIL/SFL Run 1 5" & 2" BHCS Run 1 5" & 2" Cyberlook Run 1 5" Cyberlook Run 1 5" FDC Run 1 5" /' FDC/CNL Run 1 5" DIL/SFL R~n 1 5" & 2" BHCS Run 1 5" & 2" Cyberlook Run 1 5" ~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #602 DISTRIBUTION North Geology Exxon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology Marathon State of Alaska Chevron ARCO Od and Gas Company ,s a O~v,s~on of AllantmR,chheldCompany ARCO Oil and Gas Company North Alaska District Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 12, 1980 Reference: Arco Directional Surveys _ ill i i · i COMM co/~M COMM ___L_RES ENG I 1 ENG_. . ~ 2 ENG-' I 3-FN$ J ~ ENO ' ' . I--1 GEOL.,, 3 GEOL/ STAT STAT TEC , ! I CONFER: i FILF: _ D.S. 17-2 8/31/80 Gyroscopic ?~~Please sign and return the attached copy as receipt o'f~ data. M.F. Kellis North Engineering TRANSMITTAL #586 DISTRIBUTION North Geology Exxon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology Marathon State of Alaska Chevron ARCO Od and Gas Company is a O~vtslon o! Atlant~cR~chheldCompany Alcska 0,~ & S '~ ' ~, Anchm age ARCO Od andi~? Company Al:ask~ P'o-3t ©fhc? ~:,c",, 'SO An.3r'."r'-'."e ,qi.'s',a 525'0 U~.co:,c~,e '.:07 277 E457 September 3, 1980 Reference: ARCO Directional Surveys D.S. 2-17 8/18/80 Single Shot 7/31/80 " " 8/2/80 Single Shot ~lease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #575 DISTRIBLrFION North Geology Exxon R & D Mobil Drilling Getty Eng. ~,~unager Phillips D & }I Sohio Geology ~Iarathon State of Alaska ~ewron ARCO C,I aha Gas Compony ~:~ q O,vl:,,on ol Atl~nJ,cA,chl~ tdComp,n¥ ARCO Oil and Ga.,~ Company Al~sk~ t~ ( Post O,~,ce Box 'SO Ancb.}rnge AI-~'~ 515~0 Te~ep,hor(: .-07 2~7 ~337 September 3, 1980 Reference' ARCO Magnetic Tapes D.S. 2-15 7/2/80 Tape #60645 D.S. 4-15 7/10/80 Tape #60655 D.S. 6-15 ~ 7/20/80 Tape #60667 ..,~ 7/31/80 Tape #60717 /~/~ease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #581 DISTRIBL~FION North Ceology F,~xon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Ce o 1 o gM 1~. lar a thon State of Alaska Che~Ton ARCO C,~I aP,] (}as Company is ,~ Diw~,on Of AIIJ~,I,~ g~c'~'~_'tJComp lqy .J ALASK.( ,IL AND GAS CONSERVATION ,IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Serwce Well -- OIL ~ GAS I-] SUSPENDED I-I ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Thc. 80-70 3 Address P.O. Box 100360, Anchorage, Alaska 99510 4 Location of well at surface ~"/zpN 2722' ~iL, 499' ~r'1,, Sec 22, _~_!.u., R15E, UN At Top Producing Interval 'T 1505' FNL, 1289' f14L, Sec 21, ~-1-~, R15E, UN At Total Depth 1323' FNL, 965' f-w'L, Sec 21, ~-1~, ELSE, UN 5 Elevation70, RKBIn feet (indicate KB, DF. etc ) ,P 6. LeaseADL .~""' ~ ~3/Designatl°n and Serial 12 Date Spudded 13. Date T D Reached 7/17/80 7/31/80 17 Total Depth (MO+TVD) 11375'H9- 9566'TVD 8 APl Number 50- 029-20486 9 Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-2 11. Fleldand Pool Prudhoe Bay Field Prudhoe Bay O[1 Pool 18 PlugBack Depth(MD+'rVD) 11304'H9 - 9503'TVD 14 Date Comp, Susp. or Aband. I 15 Water Depth, if offshore 116. No. of Completions 8/5/80 , [ feet MSL! StnRle 19. Directional Survey ] 20. Depth Where SSSV set [ 21. Thickness of Permafrost YES]~ NO t-I [ feet MD ! 22 Type Electr,c or Other Logs Run DIL/SP/BHCS/OR FDC/CNL/GR/CAL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP I BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 96# Weld H-40 Surf. 1110' Surf. [2676' 13-3/8" 72# Butt L-80 9-5/8" 47# Butt L-80 & Surf. 111348' RS95 24 Perforations open to Production (MD+TVD of Top and Bottom and 32" 17~" 12k" 250 sx Per~nAfrnst IT 1908 SX Fondu nlus ~00 sx 1300 sx Class 25. TUBING RECORD SIZE i OEPTH SET (MD) PACKER SET {MD) I 5~" ,nterval, slzeand number)*New Perfs w/4spf 10632 - 10642'HD (10') 8920 ' 9049'TVD 10651 - 10656'HD (5') 10668 - 10678'HD (10') 10686 - 10694'HD (10') *10728 - 10748'HD (20') *10764 ' 10784'HD (20') 103 q/~ ' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27 Date F~rst Production 6/9/81 Date of Test Hours Tested 6/22/84 6.2 Casing Pressure Flow Tubing Press. 567 PRODUCTION TEST I Method of Operation (Flowing, gas hft, etc.) Flowin~ PRODUCTION FOR. L IOIL'eeL [ GAS-MCF TEST PERIOD I~ 790.5 552.6 CALCULATED OIL-eeL GAS-MCF 24-HOUR RATE I~p 3060 2139 28 CDR E DATA WATER-eeL ICHOKESIZE IGAS'OILRATIO 0 R9 Rqq WATER-BBL lOlL GRAVITY-APl (corr) 0 I 26.2 Brief descr,ption of hthology, porosity, fractures, apparent dips and presence of mi, gas or water. Submit core ch,ps. N/A PI::/U ENLflNi:EfllNU WELL FILE Form 10-407 Rev 7-1-80 CONTINUED ON REVERSE SlOE ARCO Oil and Gas~* mpany Alaska Distl~ P~st Office Anchorage Alaska Telephone 907 2; 7' August 1, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-17, Permit No., 80-25 DS 11-17, Permit No., 80-73 DS 17-2, Permit No., 80-70 Dear Sir: Enclosed please find Monthly Reports of month of July on the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV: ruo work done in the REV.Fo~m No P-43-1-70 ( SUBMIT IN DUPLICATE ( STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20486 6 LEASE DESIGNATION AND SERIAL NO. ADL 28334 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, ^nchorage, ^laska 99510 DS 17-2 (xx-21-10-15) 4. LOCATION OF WELL 2722'S & 499'E of NW cr Sec. 22, T11N, R15E, UM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil 11 SEC. T. R. M. (BOTTOM HOLE Pool OBJECTIVE) Sec. 21, T10N, R15E, ug 12. PERMIT NO. 80-70 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for Month of July 1980. Spudded well @ 2100 hrs, 7/17/80. Drld 17-1/2" hole to 2697'. Ran 13-3/8" 72# L-80 csg w/shoe @ 2676'. Cmtd csg w/1908 sx Fondu cmt followed by 400 sx Permafrost II cmt. Installed & tstd pkoff to 2000 psi. NU & tstd BOP's to 5000 psi. Drld thru FC, FS, cmt, + 10' new hole. Tstd form to 12.5 ppg EMW. Drld 12-1/4" hole to 11,375'. As of 7/31/80, runnin9 open hole logs. 14. I hereby e t,~h~ the~~ S,GNED TiTLE.District Drilling EngineerDATE 8/1/80 · . NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ALASKA OIL AND GAS CONSERVATION COMMISSION H~y 1 H Hami 1ton Chairman/Commissi Thru: Lonnie C. Smith Commissioner July 25, 1980 Petroleum Inspector To Witness B.O.P.E Test= Well No. 17-2, ARCO Sec. 21-T10N-R15E-UM. Permit No. 80-70 ~u1¥ 19, 3.980 I left j-pad-where I witnessed a BOPE test, to drill site 17 to witness another BOPE test on well number 17-2. J.u,!.¥~ 20, 1980 I WitnesSed the BOPE tests on 17-2. There were no failures. I filled out an AO&GCC report, attached to this memo. In summary l I wirelessed the BOPE test on 17-2 that Rowan Drilling performed for ARCO. The tests were satisfactory. 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CObIMISSION B.O.P.E. Inspection Report Inspector Wel 1 / 7 -- ~ Operator ~ .~ C ~ Well / f- X Location: Sec ~ / T ;dA/R /~%C~M Drilling Contractor ,~,~c~./~./-/ Representative Permit # / ]~Caszng Set Rig ~ ? ~ Representativ~ Location, General ~/[~ Well Sign Gen~eral Housekeeping Reserve pit BOPE Stack Annular Preventer Pipe Rams Blind Rams , Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Test Pres sure Failures ACCUMULATOR SYSTEM Full Charge Pressure ~L9 ,'f 0 pslg Pressure After Closure '.]~ ~O~.) pszg 200 psig Above Precharge Attained:--. mmn,~ sec Full Charge Pressure Attained: _~ min~o sec Controls: Master f37//,,/ Remote , z-' Blinds switch cover ,z,2/f' Kelly and Floor Safety Valves Upper Kelly. Lower Kelly Bal 1 Type Ins lde BOP Choke Manifold NO. Valves / NO. flanges ~ ~z/ ~p;~'f,~- Ad] ustable Chokes / Hydrauically operated choke Test Time j hrs. Test Pressure Test Pressure Test Pressure /~/~ Test Pressure Test Pressure Repair or Replacement of failed equipment to be made within Inspector/Commission office not~.fied. ! days and Distribution orig. - AO&GCC cc - Operator cc - Supervisor July 11,1980 Mr. P. A. VanDusen District Drilling gngineer ARCO 0il and Gas Company P.O. Box 360 Anohorage, Alaska 99S10 Re: Prudhoe Bay Unit DS 17-2 Atlafftic Richfield Company Permit No. 80-70 Sur. Loc.: 2722ts i 499'E of NW cr Sec 22, T10N, R15E, Bottouuhole Loc.~ 1320'$ & 1320tB of NW cr Sec 21, T10H R158, UN. Bnolosed is the approved revised application for ]permit to drill the above referenoed well. The provisions of the cover letter, dated June 19,1980,' accoupsnying the original approved permit are in effect for this revision. Very truly ][ours, Alaska' Oil & Gas Conse~va~ ,sion Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor j Supervisor, Labor Law Compliance Division w/o encl. HHH~Bm ¢ ARCO Oil and G,.. Company Alaska District Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 11, 1980 Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 17-2 Dear Sir: Enclosed please find an amended application for Permit to Drill D.S. 17-2, along with accompanying Well-bore Proximity diagram and Horizontal Projection diagram. The bottomhole location of this well has been changed to 1320'S & 1320'E of NW cr Section 21, TION, R15E, Umiat Meridian. Very truly yours, P. A. Van Dusen District Drilling Engineer PVD/jh Enclosures RECEIVED JUL! ! Anchorage ARCO Oil and Gas Company ms a D,wsmon of AtlantlcR)ch(~eidCompany Form 10-401 REV. 9-1-78 STATE OF ALASKA SUBMIT IN 1 RIPLICATE (Other ~nstrucnons on ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN DEEPEN [] reverse side) SINGLE MULTIPLE la. TYPE OF WORK DRILL ~ b TYPE OF WELL OIL [] GAS [~] WELL WELL OTHER 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 K ELi: I V I:: L) 6 LEASE DESIGNATION AND SERIAL NO ADL 28334 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9 WELL NO DS 17-2 (xx-21-10-15) 10 FIELD AND ~I~3L, OR.=~rlLI~C~T Prudhoe uay ~le~a-Prudhoe Oil 1! SEC, T, R., M, (BOTTOM Pool 4 LOCATION OF WELL Atsurface JUL 1 1 1980 2722'S & 499'E of At proposed prod zone 1320'S &- 1320'E of NW cr Sec 21, TION, R~k, 13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 5 miles NE of Deadhorse, Alaska HOLE OBJECTIVE) ~[~% 21, TION, R15E, UM 14 BOND INFORMATION TWE Statewide S.,etyand/o, No. Federal 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest ring, umt, ff any) 1320' DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 2640 21 ELEVATIONS (Show whether DF, RT, CR, etc.) Pad Level - 36 RKB- 70' Insurance Co. #8011-38-40 16 No OF ACRES IN LEASE 2512 19 PROPOSED DEPTH 11~527'MD PROPOSED CASING AND CEMENTING PROGRAM Amo.nt $100,000 NO ACRES ASSIGNED TO THIS WELL 160 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORK WILL START July 1980 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 lb. H-40 80' 250 sx Permafrost II to surf. 17-½" 13-3/8" 72 lb. L-80 2700' Circ to surf {approx 2500 sx) Fo 12-%" 9-5/8" 47 lb. S-95 11,527' (Approx 1500 sx) plus 300'+ colu) & I-8C and 2nd stg (approx 30~ sx) nn Atlantic Richfield Company proposes to directionally drill this well to 11,527'MD, 9538'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 5-½" 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected inter- vals within the Sadlerochit interval will be perforated, and reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wire- line work. Well will be flowed to production facilities during perforating and testing. The downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal IS to deepen g~ve data on present productive zone and proposed new productive zone. If proposal is to ch'ffi or deepen d~recttonally, g~ve pertinent data on subsurface locations and measured and true vertwal depths. Give blowout preventer program 24. I hereby ¢alrtlfj~hat the Foregoing IS True and Correct ~1 (Tlus space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~ NO DIRECTIONAL SURVEY REQUIRED YES [] NO CONDITIONS OF APPROVAL, IF ANY PERMIT NO. APPROVED BY MUD LOG YES [~ NO OTHER REQUIREMENTS A P I NUMERICAL CODE APPROVAL DATE ~ ~a ~ / ?/ ,~'~ ~'~'~ TITLE C(lVlvIISS ICKIER DATE *See Instruction On Reverse Side ORDER OF. THE COMMI$$10~ ( l RRCO OIL RND Gl:IS OS 1'7. WELL NO: 2 PROPOSEO ' $CnLE 1 IN. = lO00 FEET PRUDHOE OFIY, NORTH_ SL_OP_E,___~L_FtSK~ .................................................................. J ERSTMRN WHIPSTOCK. INC. o .._aum~ _ : I ! I i -' ! I _ _ --~OoL_ ___i _ ! ~ __- ' i I .~. L.' ~, !.. i i . : I i. ~ 1 ~ _ _~_L~ooo -:-.;', I - I -- : ~:-: ~----~-,--l- i- l ---i-, - _ i ! - I -- /- ...... ::-': i--'- -.__i- ! - --i- -! -I-~'-ALA-~ -!I- ~p~o . ~ ! .I ~ -I ........ :l----' ....... __ I--T- - I' ' ....... : .... T- ~~~ i- : "-~---T. - - ~ ' ~--- l'----- -i ............. I'- I -1--' ........... ...... ! ........ i ...... I ........ ~ ....... I ...... ~~ .... i ...... i-~"---E .... ~ ..... · - - ~--- ' I ----r .......... i ~'----r- -~' ~" ' ~ ....... F ............. -~- , -! , ~- ~-- ~~k-:~-- -I-- ---1- ~ ~ ~vo.~OO, Tm.~O0 m'.O t ..... I .... / .-I J I I I_T"--.J / ---. -- -, ..... I .... F .-,I ~ i ! !-'r"-q~ -- -- mo__ _, . . ~___ ~e._so_mN_~. I I "I ,-"~- ~.~..___~_a__ ........ :~ .... ,~ i ....... ~ ...... ~-- ! .... ~ ~- . _~- '-- -I'--<F! ! --':~. - ~':'---'-- ...... ~-L ...... BUII.O_2._I/2_OEGZL_ - -: --'T-[' 7_L ___ ! , .... L-_ '- ~ '" , - -- L .......... [ ....... . ..... i -._'-: .~ zoo __ . i -:_:_: _::_ I _'-' _ Ii' :-t--:-i"3~' ?~_-_-_'~-I ....... i' i ' --;lc I ------ ----:-- t - K-12 TVD,,6630 T1~=7590 K-lO TVD.7115 Tt~-8246 DEP-3128 t / ~---VE~TICnL'~$ECTION: i RIVER ! TV~8800 TH1~0528 D~P.4666 I ._ SHU~IK TVD,.88"~ 11~10562 DEP.4689 [ 'OWC TVD-g095 T~)-I0927 DEP.4936 - THD-115~7 DEP=5340 - TV1~9628 THD-11649 DEP.S4~ ,ooo, oo,?, ,oo:: ._ -i'---,?!.--- - ( I. 16115 '- I I HEREBY CERTIFY THAT I AH - PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- D.S. ]7 - CONDUCTORS I THRU 6 BUILT SURVEY HADE BY HE, AND THAT ALL D IHENSIONS AND OTHER AS-BUIlT LOCATIONS DETAILS ARE 6ORRECT, AS 0F: DATE ~/ STATE PLANE LAT S LONG x = 7o8786 75h x: 7o87o2 5h6 -' LAT 70012 21.846' LAT 70012 25 308" JUL LONG = ~8°18':~.678" LON~ = ~h8°~'0~.8~" ~:." 2. Y = :327~]0.~h~ :. Y = :~28260.33~ '~h~, x = 7o~7~.~ x = 7o~7~.0~o LONG = 148o19'00.'394" LONG = 148°19'02.574'' ¢t~,¢;',- ~ 77~;~¢ 3. Y = 5928027. 297 6. Y = 5928376. 895 '- "; - -'* .~" X = 708730. 871 X = 708645.462 "'~ ~ )'"~r ~':, ~,.,¢'~' LAT = 70o12'24.151'' LAT = 70o12'27.611~ LONG = 148°~9'01.113'' LONG = 148019' 03.331" AtlanlicRichfieldCo~any ~ DATE. DRAWING NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT i PRUDHOE BAY 4.1b.~o IRNNUL,qR PRE:VENTOR . ¢) BLIND RRMS ._ ( ) PIPE RRMS - SPOOL (- ) PIPE RRMS~ . , 13- :]0~ ST''' ~' u,v,, Ac__cu, ,.__El_a t__o2L_Ca__pac i tv Test . . le 2e 3e me Be · 7~ Check and fill accun~ulator ressrvo~r to proper level v¢iLi~ hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regul~tor. Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing tin;e and 1100 psi remaining pressure.) 13-5/8" BOP STACK TEST Fill BOP stack and manifold with Arctic Diesel or Calcium Chloride Solution. Check that all hold down screws are fully retracted· Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws i n head. Close annular preventer and chokes and bypass valves on manifold. Test all components to 250 psi and hold for 10 minutes. Increase pressure to 3000 psi and hold for 10 minutes. Bleed pressure to 0 psi. Close top set of pipe rams and open annular preventer. Increase pressure to 5000 psi and hold for 10 minutes. Bleed pressure to 0 psi. Close bottom set of pipe rams and valves directly upstream of chokes, then open top set of pipe rams and chokes. Increase pressure to 5000 psi and hold for 10 minutes. Test remaining untested manifold valves(if any) with 5000 psi upstream o(.valve and zero pressure downstream. lO.,,Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 min. 11. Bleed pressure off all equipment open bottom preventer. Make sure manifold & lines are full of Arctic Diesel and all valves are set in drilling position. _ 12. Test standpipe valves to 5000 psi. 13. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 14.' Check operation of De Gasser. 15. Record test information on Blowout preventer test form. Sign and send to Drilling Supervisor. 16. Perform complete BOPE test once a week and functional operate BOP£ daily. ARCO Oil and G. Company North Slope D~strlct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 10, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservat ion Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 I-COM~[---I J IiI ENG----- i FiLF~ -- I Dear Sir' As per Alaska Oil & Gas Conservation Commission Regulations Section 20 AAC 25.035 Part (b)-2, Atlantic Richfield Company is requesting the Commission to waive the requirement of a surface hole diverter system for wells 17-2 thru 17-6. This request is based on information acquired in drilling 17-1. No hydrocarbons or other fluids were encountered in drilling to a depth of 2700'ss. Electric logs run in this interval also show no hydro- carbons or other fluids. P. A. VanDusen District Drilling Engineer PAV'MBW:cs Please acknowledge concurrence of this request by returning one sign~~,~y to us/~r our files. S i~m~tureB¥ ~OMMISSlONg~ Title ~a~ka [111 & G .s ,.~i~. vUl[lilllSSJOll Ancl~orage ARCO 0~1 and Gas Company ~s a Dtvls~on of AtlantlcR~chheldCompany ,Tune 19, .1.980 )ir. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O, Box 360 Anchorage, Alaska Re: Prudhoe Bay Unit DS !.?-2 ' Atlantic Richfield Company Permit No. 80-70 Sur. Loc. z 2722'$, 499'E of NW cr Sec Botto~hole ~coz 1320tS, 1320*w of NE cr Sec 28, T10N, RiSE, Dear Hz'. VanDusenz Enclosed is the approved application for permit to drill the above re£erenced well. Well 'samples, core chips and a mud log are not required. A directional survey is required, l£ available, a tape contain- ing the digitized log-information on all logs shall be sub- mitred for copying except experimental logs, velocity surveys and dipmeter surveys. Hany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration-of anadrc~aous fish. O~erations in these areas are subject to AS 16.50,870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations yoU may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any water's of the $~ate is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~Lr. P, A. VanDusen Prudhoe Bay Unit DS 17-2 -2- June 19, 1980 co~mencing operations you may be contacted by a representative of the D~partment of Bnvirom~ntal Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Departunt of Labor is being noti£ied of the issuance of this per. it to dril 1. To aid us in scheduling field woz'k, ~ would appreciate your notifyin~ this office within AB hours after the well is sledded. #e would also like to be notified so that a repre- sentative of the comsission may be present to witness testing of blowout preventer equipment be£ore surface casing shoe is drilled. In the event o£ suspension or abandonment, please give this o£fioe adequate advance notification so that we ~ay have a Very truly yours, Commissioner of g¥ ORD;rl OF IRE CO,'~U!SSI'ON Alaska 0tl & Gas ~nse~tion Co. lesion Enclosure cc: Department of Fish & Game, ~abitat Section wis encl. Dep&z-tsmnt of ~viro~ntal Conse~ation ~~~t of ~r; Supe~tsor, Lair Law C~pliance Di~sion w/o enol. i ARCO Oil and Gas{ 11pany Alaska Region Post Ofhce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 13, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 I CObAM COMM Subject: D. S. 17-2 Dear Sir: Enclosed please find an amended Wellbore Proximity plat for D. S. 17-2. The K. O. P. should read 2800' TVD. Please change any pre- vious plats to this corrected K. O. P. Very Truly Yours, P. A. Van Dusen District Drilling Engineer PVD:ruo Enclosure ARCO Od and Gas Company Es a D~ws~on of AtlanhcR~chheldCompany 22_ · ,,cEC7'ION' 2.~ ?22 3C~L£ ' 1'~ 14)0 ~ 70' ~ 5,,./00 ' ~4D. i 1'7-,2. /?'-%. 4 oo' ARCO Oil and Gas{ ~pany Alaska Region Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 2, 1980 Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~ubject' DS 17-2 Dear Mr. Hamilton, In compliance with 20 AAC 25.050, item (6), (1), (B) of the April 1980 Regulations, enclosed please find a plat of Wellbore Proximi- ties for the above-mentioned well. Very Truly Yours, P. ^o Van Dusen D~c~ D~ll~ng Eng~nee~ PVD/ro Enclosure ARCO Oil and Gas Company ,s a Division of Atlant,cR,chfleldCompany ARCO Oil and Gasp's rnpany North Alaska'~ -~str~ct Post Ofhce Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 15, 1980 .Hoyl e Hami 1 ton State Of Alaska Alaska Oil & Gas Conservation Co~ni ssion 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 17-2 Dear Sir' Enclosed please find the Application for Permit to Drill DS 17-2, along with the $100.00 filing fee and as-built survey. Very truly ~vours, P. A. VanDusen District Drilling Engineer sp Enclosures ARCO Oil and Gas Company is a Division of AtlanhcR~chf~eldCompany Form 10-401 REV. 1-1-71 la. TYPE OF WORK b. TYPE OF WELL OIL WELL r~l STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN OTHER £ SUBMIT IN TR~, .ATE (Other lnstructfons on reverse side) DRILL r~ GAS WELL E~ 2 NAME OF OPERATOR DEEPEN r-] Atlantic Richfield Company SIN E lviULTIPLE ~ 3 ADDRESS OF OPERATOR P. 0. Box 360, Anchora9e, Alaska 99510 LOCATION OF WELL ~ ~.~, ' )I ' ~ At surface 2722'S & 499'E of NW cr Sec 22, TION, R15E,/Ufl~,,~ A~lP~°C~g°d~°~320'W of NE cr Sec 28, TION, R15E, UM APE #50-029-20486 6 LEASE DESIGNATION AND SERIAL NO ADL 28334 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9 WELL NO. DS 17-2 (xx-28-10-15) 10 FIELD A~ID POOI.,.OR WII,HCArn vrudnoe uay rle~d-Prudhoe 0il Pnol 11 SEC, T , R., M , (BOTTOM HOLE OBIECTIVE) Sec 28, TION, R15E, UM 13 DISTANCE IN MILES AND DI1LECTION FROM NEAREST TOWN OR POST OFFICE* 12 5 miles NE of Deadhorse, A1 aska 14. BOND INFORMATION Federal Insurance Co. #8011-38-40 $100~000 ~E Statewi desumy and/or No Amount 15. DISTANCE FROM PROPOSED * 16 No OF ACRES IN LEASE 17. NO,ACRES ASSIGNED LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. 1320' 2512 160 (Also to nearest dng, umt, ff any) 18 DISTANCE FROM PROPOSED LOCATION 19 PROPOSED DEPTH 20 ROTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED,3733 11,715 ' MD Rota ry OR APPLIED FOR, FT 21 ELEVATIONS (Show whether DF, RT, CR, etc.) 22 APPROX DATE WORKWILL START Pad Level - 30' RKB - 64' July 1980 23 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 lb. H-40 80' 250 sx Permafrost II to surf. 17-%" 13-3/8" 72 lb. L-80 2700' Circ to sufr (approx. 2500 sx) Fondu 12-%" 9-5/8" 47 lb. S-95 11~715' (Approx. 1500 sx) plus 300'_+ column on 2nd st.q (app 300 sx) Atlantic Richfield Company proposes to directionally drill this well to 11,715'MD, 9737'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 5-½" 17# L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected inter- vals within the Sadlerochit interval will be perforated, and reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wire- line work. Well will be flowed to production facilities during perforating and testing. The downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal IS to deepen g~ve data on present productive zone and proposed new productive zone. If proposal ~s to drill or deepen chrect~onally, give pertinent data on subsurface locations and measured and true vertical depths. G~ve blowout preventer program 24' I hereb~'dd~the F°?~g]7~n~ ;°~ec~-- TITLE SIGNED, /r · ~,, · ~~ DATE/{~Y lAi /~0 District (Tim space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] Y~S ~/~ ~o DIREL~IONA£ SI]RVEY REQUIRED y~s [] NO CONDITIONS OF APPROVAL, IF ANY MUD LOG ~N [] YES O OTHER REQUIREMENTS Dri 11 i ng Eng. A.P I. NUMERICAL CODE PERMIT NO.. ~O ?~ '~ /-) APPROVAL DATE June 19, 1980 /~.~,2~/Q~' ~ssioner APPOVED BY TITLE DATE DY ORDE'~R O~ THE C~,~IS$10'N*See" ' Instruction On aeverseSide 06/19/80 ~ 16~15 [ ..... '2h- -- ;1~ I I HEREBY CERTIFY THAT PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALAS~ AND THAT THIS PLAT REPRESENTS AN AS- D.S. 17 - CONDUCTORS 1 THRU 6 BUILT SURVEY HADE BY HE, AND THAT ALL D IHENSIONS AND OTHER AS-BUILT LOCATIONS DETAILS ARE CORRECT, AS OF: DATE ~/ STATE PLANE LAT S LONG 1. Y = 592779~.39~ ~. Y = 59281~.192 X = 708786.754 X : 708702. 546 ~A~ ~ 9 1~. "~'~'~"r-: LAT = 70o12'21.846'' LAT 70o12'25.308'' _ /~ ,;,~.,,. LONG = 148o18'59.678'' LONG 148°19'01.~ Oi] ~.G~m,~,,~[~ 2. Y = 5927910.446 5. Y 5928260.936 · ,~ ' ~,- ', '~, X = 708758. 898 X 708674. 050 ..... LAT = 70o12 LONG = 148o19'00.394" LONG 148°19'02.574'' ~'~,,;,, ,~:, ,, :',' 3. Y = 5928027.297 6 Y = 5928376 895 .' '~ ........ X = 708730.871 X = ~8645 462 ~'~"=,~. ...... ~,' .... LAT = 70°12'2~.151'' LAT = 70°12~ 27.611~ LONG = 1~8°19'01.113" LONG = 1~8°19' 03.331" I IIIII AUanticRichfielgCompany ~ ,OATE' DRAWING Ho: NORTH AMERICAN PROO ClNG OIV,SlON AEASKA OISTRICT- PRUDHOE BAY I I CHECK LIST M0R NEW WELL PERMITS Item Apjprove Date (1) Fee ~/6~f_. 7'/"~° / -(2) Loc. / (4) Casg~ ( 5 ) BOPE Company 1. Is the permit fee attached ......................................... · Yes ~ 2. Is well to be located in a defined pool ............................ 3. Is a registered survey plat attached ...... 4. Is well located proper distance frcm property line ................. 5. Is well located proper distance frcm other wells .. 6. Is sufficient undedicated acreage available in this pool ........... 7. 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 ........... ' '' ' .. ~"' 11. Is a conservation order needed ...... ~. .......... " .......... . ...... - .... 14. Is enough cement used to circulate on conductor and surface ........ 15. Will cement tie in surface and intermediate or production strin s .. 16 Will cement cover all known productive horizons ................. Additional Requirements: ~.~ 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 17. Will surface casing protect fresh water zones ...................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to psig ..~ Approval Recked: Geoloqy: Engineering: HWK LCS BEW rev: 03/05/80 Item Approve Date (1~ Fe..e /~ ~-~ ~ ~, 1. Is the permit fee attached ......................................... -/ / ~ 2 Is well to be located in a defined pool (2) Loc. 3. Is a registered survey plat attached ............................... 4. Is well located proper distance frcm property line ................. 5. Is well located proper distance frcm other wells ................... ( 4 ) ca, s~.~ 6. is sufficient undedicated acreage available in this pool ........... 7. Is well to be deviated .............................................. ~ / 8. IS operator the only affected party ................................. ~ / 9. Can permit be approved before ten-day wait .......................... ~ 10. 12~s operator hav~ a l~nd in force ................................... / 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is cor~iuctor string provided ....................................... 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... 16. Will cen~t cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to ~oo Approval Reccmmended: Yes No , -- Lease & Well NO. Remarks Geology: Engineering: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically .. organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil Well DS 17-2 g Gas Field Prudhoe Bay County,State North ~lope, Alaska Date 10-22-80 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR Gamma Ray CN/MS 0-100 SSN Short Space Neutron CN/MS 0-2000 LSN Long Space Neutron CN/MS 0-2000 ,.NEU Compensated Neutron ..........CN~S 60-0 ,, ,, hDV i Anchora[le ErC N~MBFD 6409.00 ~ CUR~ES t ~R S~N I S~I NELl ................................................... ~'""'~'-8~-~"Z~-~'--f'6- - t"~ ~"~'-0 ;' 0 0 LE~iEL ~CfN6 0,5000 t ¢ ~;'-'"E"~-~'~'F~-Ts-' ."'E'p '-'"'R"E'c"8 R ~'- Anchorage DARE 1 ARCO OIL & PR[~gHO~' RAY ..... NORTH SLO3m_oALAS<A .')AT A ~_VFR Y I 17-~ HLAS ~09 GR SS~ L~N looon.oo lOOOn.5o 10001.00 10001.50 1000~.00 10002.50 1000~o00 118,87 1 6 39.1 10 1 1 1001q,50 lO0,gR 59G.09 ~Rl.03 ............. i'""O-O'"~'"~T'~"O .................... l"l'"b--;'"9-1 .................... '~"8'3-;'-'~-g .................... ~'"'t'"~-'2'"9'i ............................... .~.~.;..~ ~..~L.~..._...~.~Si~,,.~;.L Z~. .................................................................... :..~i:Z ............................. ...........,....,~: ............. X ................................ I OOPX.50 1.2~,7~ 582. G~ ~67.5G ............ .,. .............................................. ......................................................................... ..................................................................... 3ARE p ARCO OIL ~RIIOHOr BAY ..... ~IO~TH SLOPE,ALaSKA 3ATA £;/rRY I S~LES 17-2 HLAC 6~09 1002~.50 1002~,00 10026.50 ln027.o0 10027°50 1NO2A,O0 1002R,50 1002qo00 1002qo50 6.6,7 581.~9 ~R8. ,7 $R.08 .19 4.0, 10 37.00 157.9' 75 465.89 41 13 DAr~E ~ ARCO Oil ~ GAS ...... D..~. PRIIDHO~' RAY ..... MORT-{ SLODE,ALAS<A dATA FVF:RY 1 SA;~'~LES 17-8 HLAC G~09 10051.00 1005~.5~ 1005p.00 1005~.5o 10053.00 '~ oo5~.oo ~Li~.. 3~ ---~'~-":'~-~ ....... i'i-"~'"2 ~"3 ....... ~'~ s .'"~"7 '~'"~ g"i'O"O ~ 0. s s I 0057.50 1~0.81 55~. ~0 ~51.65 ~22"~i - I 0059.50 13~.80 5GG.75 ~GG.~ff ~0.TB mOO6A.50 136.27 575.B1 :~::~::~:::~:~:~ .......... .......................... 10 100G5.50 10 1006-/.50 135.09 599.76 ~B~.g8 ?:?:i~: ?': i~:? ..... :::::::::::::::::::::::::::L`~`:::::::::::::::::::::::::::::``:`-`~::::::::::::::::::::~:::;:~:--:: ................... ..................... .................. I OOGR.50 111.27 635.21 ~96.9~ ~1.06 :, Z J~:~,~i~i~ ,~, ................................. ....................................................... ~O0&q.50 100,98 G21.TG I 007~,50 99,75 ~7~. SS 510.~0 :~:~::~::~.::: ::::::::::::::::::::::::::::::::::::::::: ::~: ::L:~,...,..,.=============================== t::::.:::i:: ...................... ::::.::~ :::: ::::: :~::: :::::::~:: ::: ...................... ::.:._. ::z...,::Lt:,~..,..: ......................................... . .... 10072.50 J05.39 7~.3~ ~B9.7~ ~.79 ~AGE q ARC~ OIL ~ GAS ...... 'PRIIDHOF RAY ..... HORTq ~ATA FVrRY 1 17-2 HLAS ~09 SS~! 1007~.50 lOO7q.on 10079,50 10080.00 10080.50 1 1 7.87 ~0 .9B ~ 11 000000 7777777777 000000 11 000000 7117777777 000000 1111 O0 O0 77 O0 O0 1111 O0 O0 77 OO O0 11 O0 0000 77 O0 0000 11 O0 0000 77 O0 0000 11 O0 O0 O0 77 O0 O0 O0 11 O0 O0 O0 77 O0 00 OO 11 0000 O0 77 0000 O0 11 0000 O0 77 OOOO O0 11 O0 O0 77 O0 O0 11 00 O0 17 00 00 111111 000000 77 000000 111111 000000 77 000000 7177777771 7177777771 17 77 17 77 77 77 17 71 77 77 77 77 17-.1 660666 0OO000 7777777777 11 066066 000000 77777~7777 Il 66 00 00 77 1111 66 O0 O0 77 1111 66 00 0000 77 11 06 O0 0000 77 11 66600666 O0 O0 O0 77 11 60660660 O0 O0 O0 77 11 60 60 0000 O0 77 66 66 0000 O0 77 11 66 66 O0 O0 77 11 66 60 O0 O0 77 11 bbbbb6 000000 77 111111 666666 000000 77 111111 7777777777 7777777777 77 77 77 17 77 11 77 77 77 77 17 17 CCCC M M CCCC PPPP RRRR U U DDDD H H OO0 EEEEE C MM MM C P P R ~ U U D D H H U 0 ~ C M MM C P P R R U U D D H H U 0 E C M m C ..... PPPP RRRR U U O D HH~H O O ~EEE C M M C P ~ R U U O D H H O O E C M N C P R R U U D D H H U O E CCCC M N CCCC P R R UUUUU DDDD H H OOO EEEBE *START* U~EH PCAL [10707,607171 dOB *HIP 8E~. 5176 DAT~ 25-AUG-80 16:15:50 MUNITtIR bW8 KLlOE37 APR-80. *5TART* *bTAET* USEP PCAL [10707,b0717] dub SHiP SEQ. 5176 DAT~ 25-AUG-80 10:15:50 MONIT[JR 8~$ KL10EJ7 APR-80. *START* VV ~¥ EEEE~EEEEE R~RRRHRR VV qV EEEEE~E~E RRRRRRRR VV VV EE RR RR VV VV EE RR RR VV VV EL RH kR VV VV LE HR HR VV VV EEE~E~LE RRRRHRRH VV VV LEELELLL HRRRRRRR VV VV Ek RR RR VV VV kk RR RR VV VV EL RR RR VV VV EE ~R HR VV EEEkE~EEEE RR RR VV EEEEEEEEEE ~R RR Illiii Illiii II I1 II 11 11 ii 1I 11 1I Ii 11Ili1 iiiiii YX XX ¥¥ YX ¥¥ YX ¥¥ XX 000000 000000 222222 000000 000000 222222 O0 O0 O0 00 22 22 O0 O0 O0 O0 22 22 O0 O000 O0 0000 22 00 0000 O0 0000 22 00 O0 00 OO O0 O0 22 O0 O0 O0 O0 O0 O0 22 0000 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 O0 O0 O0 22 000000 000000 2222222222 000000 000000 2222222222 *STA~T* USER PCA6 [10707,60717] JOB SHIP MONITOR 5~S KLlO~.37 APR-BO. *START* DSKH:¥ERI~X.002<057>[10707 60717] CREATED: PR1NIED: 25-AUG-80 SWITCHES: /~ILE:~URT /CUPIE$:I /SPaC1NG:I /L1MII:81 5176 DAT~ 25-AUG-B0 25-AUG-80 15:50:21 lb:lb:50 SCHLUMBERGER CUMPUTING C~NI~R 10707,60/17 LENGTH: 1)2 REEL NAME: P.C.A.b. SkRV]C~. NAME: RSEL CUN'[1NUATIUN NUM~E~: PREVJUUS ~kEL NAME: C[]MMENT6: bi6 ~URMAT CUSTUME~ TAPE DATE: 80/ 8/24 TAPE HEADEB LENG1H: 1 ~2 ]]APE hAME: b0717 [)ATE: 80/ 8/24 SEPV ICE NAME: EDIT ']'AP~ CONTINUATION NUMbeR: PR~VIOU6 TAP~ NAME: C~]MMkN16: UNIBUS W~bb 1DkNTi~ICATIUN NUMB~ IS 50-029-20~86 ~'A[~E C[)MMKNT6 DATE bUGGED 01-AUG-80/hUN UNE/CA61NG 1].37" 92~ 8 2LTL/Bi1 61Z~ ~ ]~]75/DEN6 10.10/P~ I~.O/VlSC 1;.0 6~C/~bUiD LOSS 4.8 ML/R RM ~.89 ~ 12 D~/RM~ ~.71 8 55 D~/~MC N-A/ 12.25 PILE [~EADER 1024 BYTES I,LNGIH: 62 BITE6 E1LL NAME: EUi2 .001 MAXIMUM PHY6ICAL RECORD LENGTH: PRLVIUU6 ~ILE NAME: wkbb 611'L IN~URMAIIUN RI~,CORD ATLANTIC klCHF'I~LD CU. D.S. 17-2 PRUDHOk N. SLOPE ALA6KA DATA ~ORMAT 5PkCII'ICATI(JN LILNGq_ H: 610 b~TE8 r~ ~'4 rRt BLOCKS: IYPE 0 SIZE 1 RkP CODE 6b 0 DAI'UM ~P~C1FICATI()N I~bOCKS: iC TOUI, 1 DkP2 2 SP DIL 4 1LM DIL 5 5~LU DIL 6 GA BHC ? UT BHC 9 CALl CNL 10 DPHU fDC 12 ~HUB CNL 1 ~ N~AT CNL ~ ~ NCNL ~5 ~CNg CNb SVURD# UNITS APl APl AFl AP1 Fib~# ~lZg ~XP PROC SAM BNP DEPT SHIF'I fT 0 0 0 0 0 4 0 0 i b8 0 0 MV 7 1 0 0 0 4 0 0 1 b8 0 0 OHMM 7 12 4b 0 0 4 0 0 1 UB 0 0 O~MM ~ 12 44 0 0 4 0 0 1 b8 0 0 OHM~ 1 22 1 0 0 ~ 0 0 I b8 0 U GAPI bO 31 32 0 0 4 0 0 1 b8 0 0 US/f bO 52 32 0 0 ~ 0 0 1 68 0 0 GAP1 ~2 31 32 0 0 4 0 0 1 b8 0 0 IN ~2 28 1 0 0 4 0 0 1 68 0 0 G/C3 42 44 0 0 0 q 0 0 1 b8 0 0 PU 42 68 3 0 0 4 0 0 1 68 0 0 G/C~ 42 35 I 0 0 4 0 0 I 08 0 0 C/C 42 42 1 0 0 4 0 0 1 08 0 0 CPS 42 ]4 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 b8 0 0 DLPTH 11 ]60. 000 11300.000 11200.000 11100,000 11000.000 10900.000 10800,000 10700.000 lObO0.O00 10500.000 10400.000 MNEMONIC SP NCNb fit-' Gl-' DRHO NCNb 8P DRHO NC~I., SP DR.HO NCNb SP G~ DRHO NCNL SP DHHU NCNb NCNb GR DRHU NCNb SP GR NCNb SP DRHO NCNb 8P GR D~HO NCNb VAL -39 102 -0 2264 -18 102 0 2318 -82 35 0 2050 -90 -0 2984 -79 38 0 2530 LIE .375 .563 .011 .000 .875 .750 .043 .000 .625 .750 .088 .000 .250 .219 .009 .000 .875 .007 .000 -87.188 27.172 0.0lb 2552.000 -57. 49. 0. 2548. -82. 31. O. 2504. -37. 118. O. 3086. -10. 185. 0. 1993. -10. 112. O. 1873. 500 406 018 000 813 531 011 000 418 125 027 000 789 250 032 000 383 438 029 000 MNLMUN1C iLD DT NPHI D2 NPHI fCNb bT NPHI ~CNL DT NPHi ~CNb ILD DT NPHI tCNb lbD UT NPHi ~CNb lbD Df NPHi DT NPH1 ~CNb lbD DT NPBI ~CNb 1LD DT NPHi ~CNb lbo DT ~CNb VALUE 5.133 82.188 36.815 074.500 4.238 81.750 30.713 698.500 2.139 95.000 29.688 817.000 3.405 78.000 24.072 1047.000 1.842 95.000 29.053 794.000 2.053 93.188 26.758 834.O00 8.406 79.000 27.051 821.500 24.234 92.{75 25.293 909.500 54.281 b9.750 16.211 1588.000 3.043 105.000 41.162 473.750 1.597 112.188 40.157 456.500 MN&MUNIC GR i'(HOB GR IbM GR RHOB IbM GR ibm GR 16M GR RHUB IbM GR RHOD ibm OR RHiJB IbM RHOD IbM GR ~HOB ILN GR VAbOk 5.012 100.188 2.072 4.234 115.813 2.021 2.209 37.250 2.496 4.555 26.45J 2.307 2.117 39.844 2.23b 2.279 28.094 2.250 8.4bl 05.750 2.340 15.B75 31.297 2.307 32.594 133.250 2.598 4.547 190.625 2.430 1.b57 117.938 2.4bl MNEMONIC SFLO CAb1 NRAT SFbU CAb1 NRA'I 8FbU CALl NRAT 6FLU CAb1 NRAT 6FLU CALi NRAT ,5FLU CALl NRAI 8FLU CALl NRAT CALl NRAT 8i.'bO CALl NRAT ,5FLU CALl NRAI SFLU CALl NRAI' VAbU~ 5.54J 5.095 2.941 4.793 13.206 3.035 3.225 12.o80 2.951 9.203 12.901 2.584 3.Lb4 12.50J 2.904 2./99 12.400 2.14U 8.398 13.000 2.183 1~.909 12.414 2.052 364.bO0 13.391 2.072 3.799 11.5OO 3.730 2.039 11.172 3.b04 10300.000 10200,000 10100.000 10000,000 9900.000 9800.000 9700.000 9600.000 9500.000 9400.000 9jO0.000 MN LMUNIC ~P NCNL GR DIqH(I NCNb GR DRHU GR DRHU NCNb SP DRHU NCNb SP GR DRHO NCNb SP DRHO NCNL 6P D~HU NCNb SP DRHO NCNb SP DRHU NCNb SP DRHO NCNb VAL -2O 109 o lu93 -17 294 0 2200 -21 364 0 1877 -21 196 0 1885 -17 149 0 2494 -29 131 0 2192 -17 184 0 2194 -15 114 0 2538 -15 87 0 3266 o9 102 0 2526 -26 86 0 2708 UL .297 .813 .O67 .000 .484 .000 .018 .000 .250 .500 .004 .000 .125 .375 .025 .000 .094 .875 .Olb .000 .875 .000 .021 .000 .625 .625 .010 .000 .000 .625 .037 .000 .375 .563 .045 .000 .b09 .063 .040 .O00 .938 .188 .017 .000 MN LMONIC lbD DT NPHi ~CNb lbD mPhl lbD DI NPHI ~CNL DT NPH1 FCNL UT NP~I ~CNL IbD DT NPHi PCN6 IbD DT NPH1 ~CNb iLD DT NPHI fCNb DT NPHI PT fCNL iLD DI NPHI V AblJE 1.b47 lOb,150 35.986 497.000 3.309 99.563 34.961 614.500 3.762 105.188 39.844 467.00O 2.721 107.750 42.236 431.750 2.867 96.375 34.180 703.O00 2.848 97.188 34.961 531.500 1.720 101.375 39,941 542.500 2.408 88.000 28.809 761.500 3.979 76.375 24.072 llb2.000 2.488 88.188 29.443 750.000 2.078 88.375 31.250 844.500 MNLMONIC GR RHU~ IBM GR RHOD GR IbM bR RHOB GR RHOB GR RHUM OR hHUB GR I-<HtJB G~ GR RHUD VAbUL 1.t>69 10/,313 2.381 3.000 289.000 2.467 3.756 339.500 2.338 2.811 195.125 2.~92 3.363 151.250 2.486 2.936 132.b25 2.539 1.828 1 11.500 2.393 2.4bl 109.125 2.484 4.131 83.938 2.486 2.551 104.438 2.523 2.199 89.500 2.432 MNI".MUN lC CALl NRAT NRAI SFDU CALl NRA£ CAbi NRAI CALl NRA'I CAbl NRA I' CALl NRA1 CAbi NRA1 SFDU CALl NRAI 6FLU CALl NRAT CALl NRA'I VAbUH. 1~.234 $.410 3.319 lo.234 3.354 4.484 15.010 3.592 3.451 15.900 3.748 5.0Ob 14.4U4 3.264 3.525 17.656 3.$91 1.782 15.398 3.bO1 2.385 lb.552 2.963 3.490 lq.409 2.b23 2.480 15.b48 3.014 2.289 15.2i9 3.123 DLPTH 9200,000 9100.000 900O.000 8900,000 8800.000 8700.0O0 8600.000 8500,000 8400.000 8300.000 8200.000 MNLMIJNIC SP DBHU NCNb SP DRMO NCNb SP GR DRHU NCNb SP GR DHMU NCNb SP GR DRHO NCNb SP DHHU NCNL SP GR DRHtJ NCNb SP GP DRHO NC Nb SP GR DRHO NC N b SP GR DRHO NCNb SP DRHU NCNb VALUL -3.086 97.875 0.020 2604.000 -21.281 84.000 0.012 2786.000 -11.555 93.250 0.018 2626.000 -17.688 90,500 0.039 2536.000 -11,680 88.625 0.011 2540.000 -9.555 90,875 0.023 2284.000 -27.266 95.813 0.026 2800.000 -26.234 157.000 0,046 2508.000 -21.906 106.375 0.042 2530.000 -30.094 86.125 -999,250-999.250 -35.438 -999.750 -999,250 -999,250 MNkMUNiC ILL DT NPH1 ~CNb DT NPHI ~CNL IUD NPHI ~CNL ILL DT NPHI ~CNL iUD UT NPH1 fCNL OT NPH] ~CNL DT NPHI ~CNb DT NPHI ~CNL ll.O NPHI ~CNb IUD NPHI ~CNL ILD DT {MPl-i 1 ~CNL VALUE 2.186 89.375 28,{74 793.000 2,395 87,375 27.734 881.500 2.]b3 88.188 25.244 891.500 2.03] 89.750 29.541 796.000 1.817 92,315 31.104 703.500 2.0Lb 93,563 32.568 b66.000 2.898 88.563 26.367 892,000 3.211 92.750 28.111 804.500 1.984 93,]75 34.424 706.500 2.307 93.000 -99925.000 -999.250 3.561 -999.250 -99925,ooo -999.250 MNeMONiC ILM GR HHOB GR IbM 1bM GR ibm RHOB ILM GR HHOD GR GR IbM GR IbM GR RHUB VALUL 2.242 99.000 2,432 2.439 91.625 2.486 2.436 97.250 2.434 2.113 90.375 2.428 1.860 86.063 2.402 2.072 96.313 2.422 3.389 98.438 2.441 3.234 152.315 2.484 1.951 105.~1~ 2.459 2.~05 -999.250 -999,250 3.553 -999.250 -999,250 ~,~NLMON lC SFLO CALl NRA'I' CALl N~AT SFLU CALl NRA'£ SFbU CALl NRAT CAbi NRAY CALl NRAI' SFLU CALl NRAT 8~bU CAUl NRAI' CALl NHAI CALl NRAT CALl NRA~ VAbU~ 2.123 14.965 2.910 2.322 1~.930 2.879 14.9Z2 2.71] 1.5.023 3.002 1.765 15.242 3.11] 2.045 15.266 3.211 3.143 15.164 2.197 3.371 17.328 3.00U 1.511 11.000 3.344 2.2~9 -999.250 -999.250 ].lbb -99~.250 -999.250 DEP'I'H 8100.000 8000.000 7900.000 7800.O00 7700.000 1600.000 750V.O00 7400.000 7300,000 7200.000 7100.000 MNLM{.)I,{ lC tip DRHU NCNL DRtIU NCNb SP GR DRHU NCNb SP G~ NC Nb SP GR DRHO NCNb SP DRHU NCNL SP GR DRHO NCNb Gk DRHO NCNb DRHO NCNb GR DRHO NCNI, SP GB DRHO NCNb VALUE -28.422 -999.250 -999.250 -999.250 -29.375 -999.250 -999.250 -999.250 MNEMONIC VALUE ILL 3.436 DT -999.250 NPHi -99925.000 l"CNL -999.250 iLL 3.375 UT -999.250 NPH1 -99925.000 l"CNb -999.250 -42.819 ILD 4.043 -999.250 DT -999.250 -999.250 NPHI -99925.000 -999.250 l"CNb -999.250 -67.875 ILL 3.260 -999.250 DT -999.250 -999.250 NPHi -99925.000 -999.250 ~CNL -999.250 -50.031 ILD 3.170 -999.250 DT -999.250 -999.250 NPHI -99925.000 -999.250 ~CNb -999,250 -35.219 IUD 4.000 -999.250 bT -999.250 -999.250 NPHI -99925.000 -999.250 fCNL -999.250 -32.719 lbD 3.713 -999.250 DT -999.250 -999.250 NPHI -99925.000 -999.250 l"CNL -999.250 -66.563 -999.250 -999.250 -999.250 -54.031 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -96.875 -999.250 -999.250 -999.250 IbD 3.484 DT -999.250 NPHI -99925.000 ~CNL -999.250 ILD 4.262 DT -999.250 NPHI -99925.000 ~CNL -999.250 ILL 3.063 DT -999.250 NPHi -99925.000 ~CNL -999.250 lED 1.614 DT -999.250 NPHI -99925.000 l"CNb -999.250 MNEMUNIC G~ hHOD GR ILM GR IbM GR RHOD 1 LM hHOB IbM GR G~ RH[JB GR RHU~ ILM VALUE 3.449 -999.250 -999.250 3.~75 -999.250 -999.250 4.039 -999.250 -999.250 3.134 -999.250 -999.250 3,449 -999.250 -999.250 3.887 -999.250 -999.~50 -999.250 -999.250 4.070 -999.250 -999.250 4.352 -999.250 -999.250 3.486 -999.250 -999.250 2.172 -999.250 -999.250 MNEMONIC SFLU CALi I,,{RA 1 CALI N RAT CALl NRAT CALI NRAi' SFLU CALl NRA1 SFDU CALl NRA~ SFLU CAb/ N RAT ill"GU CALl NRAT SF6U CALl NRAT ,LFi..,U CALl NRA'I' $["bU CAb/ NRA 1' VAbU~ 3.186 '999.2bO -999.250 -999.250 -999.250 3.910 -999.250 -999.250 b.3Yl -999.250 -999.250 3.021 -999.250 -999.250 3.494 -999.250 -999.25U 3.104 -999.250 -999.250 0.422 -999.250 -999.250 3.90~ -999.250 -999.250 4.297 -999.250 -999.250 5.010 -999.250 -999.250 DEFTH 7000.000 bgo0.O00 6800.000 6700.000 b600.O00 6500.000 6400.000 6300,000 b20O.O00 6100.000 6000.000 MNLMON1C VALUE. MNI~M(JN iC VALUE SP -111.625 iLD 1.197 GR -999.250 DT -999.250 DRHO -999.250 NPHI -99925.000 NCNb -999,250 ~CNL -999.250 SP -87.438 ILL 2.582 GP -999.250 DT -999.250 DRHO -999.250 NPHI -99925.000 NCNL -999.250 ~CNL -999.250 SF -99.625 ILL 2.629 GR -999.250 DT -999.250 DRHO -999.250 NPHI -99925.000 NCNb -999,250 ~CNL -999.250 SP -87.875 ILD 2.223 GR -999.250 DT -999.250 DRHU -999.250 NPHi -99925.000 NCNb -999.250 fCNL -999.250 -57.063 -999.250 -999.250 -999.250 SP DIRHU NCNb ILD 4.316 DT -999.250 NPHI -99925.000 ~CNL -999.250 SP -69.750 ILD 3.879 GR -999.250 DT -999.250 DRHU -999.250 NPHI -99925.000 NCNb -999.250 ~CNL -999.250 SP -103.000 1LD 3.254 GR -999.250 DT -999.250 DRHO -999.250 NPHI -99925.000 NCNb -999,250 ~CNb -999.250 -50.188 -999.250 -999.250 -999.250 -37.844 -999.250 -999.250 -999.250 GR DRHO NCNb SP lbD 4.359 DT -999.250 NPHI -99925.000 ~CNL -999.250 1LD 3.520 UT -999.250 NPH1 -99925.000 fCNb -999.250 SP -65.31] ILL 4.391 GE -999.250 DT -999.250 DR}tO -999.250 NPH1 -99925.000 NCNL -999.250 fCNb -999.250 SP -101.750 ILL 1.505 GR -999.250 DT -999.250 DRHt] -999.250 hPH1 -99925.O00 NCNL -999.250 ~CNL -999.250 MNLMONIC GR GR RI-tIJ~ kLM GR RHOI~ GR RH(Ji5 1LM G~ RH{3B GR GR RHO~ GR ~HOb RHOB GR IBM GR RHOB VALUL 1.663 -999.250 -999.250 3.322 -999.250 -999.250 3.295 -999.250 -999.250 2.609 -999.250 -999.250 4.082 -999.250 -999.250 4,492 -999,250 -999,250 3.750 -999.250 -999.250 4.102 -999.250 -999.250 3.393 -999.250 -999.250 b.496 -999.250 -999.250 1.789 -999.250 -999.250 MNEMUNIC 8~I~U CAL, I NRA]? 6FLU CALl CALl NRAT ~FbU CAb1 NRA'i SFLU CALl NRAT S~bO CALl NRAI SFbO CALl NRAT SFbU CALl NRA[ CADI NRAI SFLU CALk N~A'I' SFDU CALl NRA~ VAbO~ 4.992 -999.250 -999.250 b./19 -999.250 -999.250 5.395 -999.250 -999.250 5.254 -999.250 -999.250 3.461 -999.250 -999.250 -999.250 -999.250 5.926 -999.250 -999.250 4.262 -999.250 -999.250 2.770 -999.250 -999.250 14.141 -999.250 -999.250 2.b~b -999.2b0 -999.250 OkPTI. i 5900.000 5800.000 5700.000 5600.000 5500.000 5400.000 5300.000 5200.000 5100.000 5000.000 4900.000 MNkMONIC VAL Uk MNEMUNIC VALUE SP -61.625 lbD 5.402 GR -999.250 UT -999.250 DRHU -999.250 NPHI -99925.000 NCNb -999.250 FCNL -999,250 ~P DRHU NCNb .563 ,250 .250 .250 -117 -999 -999 -999 IbD 1,349 DT -999.250 NPH1 -99925,000 fCNb -999.250 SP -91.563 ILL 2.557 GR -999.250 DT -999.250 URHO -999.250 NPHI -99925,000 NCNL -999.250 ~CNL -999,250 .025 ,250 ,250 ,250 SP D R H 0 NCNb -lO0 -999 -999 -999 ibD 1,925 DT -999,250 NPHI -99925,000 FCNL -999.250 8P -63.656 ILD 4.195 GR -999.250 DT -999,250 DRHO -999.250 NPH1 -99925.000 NCNb -999.250 FCNL -999.250 -79 -999 -999 -999 -123 -999 -999 -999 -96 -999 -999 -999 -lOb -999 -999 -999 -127 -999 -999 -999 -60 -999 -999 -999 8P DRHU NCNb GR DRHU NCNb SP DRHO NCNb .625 .250 .250 .250 .625 .250 ,250 .250 .188 .250 .250 .250 .125 .250 .250 ,250 ,125 .250 .250 .250 ,375 .250 .250 .250 SP GR DRHO NCNb GR DI~HO NCNL SP GR DRHU NCNb ILL ],928 DT -999,250 NPHI -99925,000 FCNL -999.250 IDD 1.419 UT -999.250 NPftl -99925.000 ~CNL -999.250 1LD 3,074 DT -999,250 NPHI -99925.000 fCNL -999.250 IbD 2.238 DT -999.250 NPHI -99925.000 ~CNL -999.250 1LD 1.581 DT -999.250 NPHI -99925,000 fCNL -999.250 ILO 4.238 DT -999,250 NPHI -99925,000 FCNL -999.250 MNkMONIC I bM HHU~ GR G~ RHOB 1LM GU ~HOB IbM IbM RHUB IbM GR RHUB VALUE 4,855 -999.250 -999.250 1.b2b -999.250 -999.250 2.980 -999,250 -999.250 2,402 -999.250 -999.250 4.141 -999.250 -999.250 4.141 -999.250 -999.250 1.478 -999,250 -999.250 3.009 -999.Z50 -999.250 2.480 -999.250 -999.250 1.700 =999.250 -999.250 3.850 -999.250 -999,250 MNEMONIC bFbU CALl NtqA f ~FbU CALl NRA'I 8FbU CALl NRAT 8FLU CALl NRA'I CALl NRA'I ~FLU CALl NRAT 8FLU CALl CALl mRA£ SFbU CALl NRAT 6FLU CALl NbtAT Sf'bU CALJ. NRA'I VALUK ~.152 -9~9,250 -999.2b0 2.0t~4 -999.250 -999.2b0 3.520 -999.250 -999.2b0 4.258 -999,250 -999.250 3.748 -999,250 -999,250 4,344 -999.250 -999.250 1.gbl -999.250 -999.250 3.~93 -999.250 -999.250 3.O19 -999.250 -999.250 2.208 -999.250 -999,250 3.184 -999.250 -999.250 4800.000 4700.000 4600.000 4500.000 4400. 000 4300.000 4200.000 ~100.000 4000.000 ~900.000 3800.000 MNLMON1C VAL UE MNkMUNIC VALUE tip -14.063 ILD 4.484 GR -999.250 DT -999.250 DRHO -999.250 NPHI -99925.000 NCNb -999.250 ~CNL -999,250 5P -71.625 ILD 5.113 G~ -999.250 OT -999.250 DRHO -999.250 NPHI -99925.000 NCNL -999.250 ~CNL -999.250 SP -104.313 ILD 3.832 GR -999.250 OT -999.250 DRHO -999.250 NPHI -99925.000 NCNb -999.250 fCNb -999.250 SP -82.500 lbD 4.719 GR -999.250 DT -999.250 D~liO -999.250 NPBi -99925.000 NCNL -999.250 ~CNL -999.250 SP DRHO NCNb NCNb -76. -999. -999. -999. -113. -999. -999. -999. -68. -999. -999. -999. -74. -999. -999. -999. Gk DRHO NCNb 5O 5O 5O 5O 13 50 50 50 50 50 50 50 25 5O 50 5O SP DRHO NCNb ILD 4.875 DT -999.250 NPHi -99925.000 ~CNL -999.250 lhD 4.535 DT -999.250 NPHi -99925.000 FCNL -999.250 ILD 5.734 DT -999.250 NPHI -99925.000 ~CNL -999.250 ILD 7.152 DT -999.250 NPHi -99925.000 fCNL -999.250 6P -85.125 ILD 6.461 GR -999.250 DI -999.250 DRHO -999.250 NPH1 -99925.000 NCNb -999.250 ~CNL -999.250 5O 5O 5O 5O SP DHHU NCNb -83. -999. -999. -999. -88. -999. -999. -999. SP DHH t! NCNb 00 5O 5O 5O lbD b.~67 DT -999.250 NPHi -99925.000 fCNL -999.250 ILD 6.215 DT -999.250 NPHI -99925.000 fCNL -999.250 MN~M[JNIC ILM RHOB ibm GR GH }{HOB IbM GR GR GH IbM ibm GH ibm RHOB lbM GR VAhUk 4.309 -999.250 -999.250 4.570 -999.250 -999.250 4.086 -999.250 -999.250 4.084 -999.250 -999.250 4.254 -999.250 -999.250 5.258 -999.250 -999.250 5.070 -999.250 -999.250 b.828 -999.250 -999.250 b.~48 -999.250 -999.250 b.92b -999.250 -999.250 b.951 -999.250 -999.250 MNEMUNIC 6f'bU CA6~ NRAT ,SFbU CALl NRA £ 6FbU CAbl h~A'.r SFhU CAb/ NRA£ SFLU CALl NHAT SFLU CAbl N R A'.i.' SFbU CAb1 NHA'I' CAb1 N R A 5FbU CALl NRAI CALl 5ebU CAb1 NHA'£ 4.301 -999.250 -999.250 4.512 -999.250 -999.25U J.OB9 -999.290 -999.250 5.422 -999.250 -999.25U 4.115 -999.250 -999.250 7.11~ -999.250 -999.250 5.301 =999.d50 -999.250 O.q~O -999.250 -999,250 U.Ul] -999.2b0 -999.250 e.949 -999.250 -999.250 1.bS~ -999.250 -999.250 DkP'I H 3600.000 5500.000 3400.000 3300.000 3200. 000 3100.000 3000.000 2900.000 2800.000 2700.000 ['. M [,I i~ iC 8P DJ{HO NC mb GR DRM£1 NCNL SP GH DP, HO NCNL bP GR URHU NCNL SP D~HU NCNb NCNL SP DRHU NCNL SP GR DRHU NCNb DRHu NCNb GR DHHU NCNL SP NCNb VAL -70 -999 -999 -999 -89 -999 -999 -999 -63 -999 -999 -999 -56 -999 -999 -999 -999 -999 -999 -88 -999 -999 -999 -105 -999 -999 -999 -95 -999 -999 -999 -108 -999 -999 -999 -52 -999 -999 -999 -93 -999 -999 -999 UE .063 .250 .250 .250 .O25 .250 ,250 .250 MNkMONiC VALUE JLD 5.211 DT -999.250 NPHi -99925.000 fCNb -999.250 lbD 4.508 UT -999.250 NPHi -99925.000 ~CNL -999.250 .656 ILL 4.594 .250 DT -999.250 .250 NPHI -99925.000 .250 ~CNL -999.250 .969 ILL 3.256 .250 DT -999.250 .250 NPH! -99925.000 .250 ~CNL -999.250 .00~ ILD 2.436 .250 DT -999.250 .250 NPHI -99925.000 .250 ~CNL -999.250 .088 .250 .250 .250 .500 .250 .250 .250 .375 .250 .250 .250 .6U8 .250 .250 .250 .438 .250 .250 .250 .875 .250 .250 .250 lbD 2.200 DT -999.250 NPHI -99925.000 ~CNL -999.250 ILL 1.302 DT -999.250 NPHi -99925.000 ~CHL -999.250 ILD 2.354 DI -999.250 NPHI -99925.000 PCNL -999.250 ILD 2.623 DT -999.250 NPHI -99925.000 ~CNL -999.250 ILD 2.355 DT -999.250 NPHI -99925.000 ~CNb -999.250 ILL 1.304 DT -999.250 NPHI -99925.000 ~CNL -999.250 MNkMUNIC HHU~ ibm ILM ibm IbM ILM GR GR G~ .~ HOi~ VALUE 5.012 -999.250 -999.250 5.02'1 -999.250 -999.250 ~.438 -999.250 -999.250 3.016 -999.250 -999.250 2.402 -999.250 -999.250 2.021 -999.250 -999.250 1.431 -999.250 -999.250 2.631 -999.250 -999.250 3.027 -999.250 -999.250 2.098 -999.250 -999.250 1.499 -999.250 -999.Z50 MNLNUNIC CALl NRAI' SFLo CALl NRA1 CAb1 NRAT $~LLI CALl NRAT CA6I NRAT NRAT 8FbU CALl NRAT SFLU CALl NRA£ SFLU CAb1 NRA1' CALl NRAI' CALl NHAT VAbUL 5.115 -999.250 -999.250 6.121 -999.250 -999.250 4.840 -999.2~0 -999.Z50 2.904 -999.250 -9~9.250 2.395 -999.250 -999.250 3.635 -999.250 -999.250 2.053 -999.250 -999.250 3.132 -999.250 -999.250 5.137 -999.250 -999.250 2.39~ -999.250 -999.250 2.055 -999.250 -999.250 DIsP'].'H 2600,000 MN~MUNIC g~ DRHO VALUIL -46.938 -999.250 -999.250 -999.250 MNLMONIC VALUk ILD 2000.000 DT -999.250 NPBI -99925.000 ~CNb -999.250 MNkMUNIC GR VAbUk 2000.000 -999,250 -999,250 MNEMONIC SFbU CAbl NRA'I VAbU~ 20UU.OOU -999.250 -999.250 SUMMAHY OB DA'lA RECORDS NOMBLI~ 01' RECORDS: 1088 bLNGIH O~ LA~i' RLCUfqD: 54b BY'ILS ~ILL I'HAIbLR LLNGIH: b2 t~YILS ILL NAME: Lbll' .001 MAXIMUM PHYSICAL IqLCO~D LENGTH: NLX~ fiLL NAbIL: 1024 BYTES TAPE I'hA1LL~ LLNG'IH: 112 UY~LS TAPE NAME: ~0717 DALE: 80/ 8/24 SERVICE NAME: EDIT YAPk CONtINUAtiON NUMBER: O1 NL~T TAPE NAME: C[]MMENT6: UNIOUL WLhL IDENTIFICATION NUMBL~ i$ 50-029-2048~