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188-113
THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 E E PL E W M 'A,T E R IA L U N D E R " TH IS M A R K ER c:mv.k,~m~oc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Pluooed back for redrill 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-113 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21872 4. Location of well at surface 9. Unit or Lease Name 406' SNL, 205' EWL, SEC. 19, T11N, R15E ~; ~.~ Prudhoe Bay Unit At Top Producing Interval 10. Well Number N/A )~ 11. Field and Pool At Total Depth .:.~ :,..~,~. ,., ,, Prudhoe Bay Field/Prudhoe Bay Pool 1654' SNL, 1623' WEL, SE~. I'IN, R 14£ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 54' ADL 28307 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/27/88 11/20/88 3/5/95 N/A feet MSLI Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11550' MD/8709' TVD 9730' MD/8524' TVD YES [] NO [] None feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run CBT/MWD 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 2150 # Poleset 13-3/8" 68#/72# K-55/L-80 Surface 34 73' 17-1/2" 200 sx CS 111/600 SX 'G"/200 sx CS II 9'5/8" 48# L-80 Surface 8935' 12-1/4' 750 sx Class 'G" 7" 29# L-80 8605' 10317' 8-1/2" 500 sx Class "G" 4-1/2" 11.35# L-80 10244' 11525' 6" Slotted liner 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None 9984' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9950'- 11550' 354 CU ft Class "G"-squeezed to 2500 psi 9730'-9880' 107 cuft Class "G" 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on production N/A Date of Test Hours Tested TEsTPRODUCTIONpERIOD FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED APR 1 4 1995 Alaska Oil & Gas Cons. Commission ~chorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,~9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 8758' 8124' Shublik 8843' 8167' Sadlerochit 8974' 8226' RECEIVED APR 1 4 1995 4Ja~ (~ii &,~.,..._Gas Cons. Corn~niss!o.q 31. LIST OF A'I-f'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/ / ~,~ Title Drillina Enaineer Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 18-18 DESCRIPTION OF WORK COMPLETED PRE SIDETRACK CTU CEMENT PLUG 2/5/95 · RIH & tagged PBTD at 10206' MD. 2/17/95' Cement was pumped fullbore to Plug & Abandon the lower wellbore prior to Sidetracking: MIRU & PT equipment. Loaded the wellbore w/Hot Seawater, then pumped 49 bbls of 13.7 ppg cement to plug the lower wellbore & abandon the slotted liner interval located at: 10338 - 11482' MD (Zl) Ref. Log: BHCS. Followed cement w/73 bbls Seawater Flush, followed by 11 bbls Diesel, followed by Shutdown. Pressured up to 2130 psi max squeeze pressure. Left estimated top of cement at 10109' MD. Rigged down. 2/19/95' RIH & tagged cement at 9985' MD. PT P&A; failed. Rigged down. 2/21/95: MIRU CTU & PT equipment. RIH w/CT & tagged top of cement at 10248' MD. Circulated Hot Seawater, then PU CT & pumped 14 bbls of 13.5 ppg cement for P&A squeeze. Squeezed 8 bbls of cement away & attained 2500 psi max squeeze pressure, but well would not hold squeeze pressure above 1800 psi. POOH w/CT. Rigged down. 2/23/95 · PT tubing at 1650 psi/20 min; tested good. RIH & tagged up at 8988' MD. POOH w/bailer. RD. 2/24/95 - 2/26/95: MIRU CTU & PT equipment. Circulated Slick Seawater into well & RIH w/CT milling BHA. Milled cement from 8800' to 9950' MD & circulated clean. Lost circulation & stuck CT at 9730' MD. Could not pull CT free. Cut CT at surface, then RIH w/cutter & cut the CT at 9200' MD. POOH w/cutter & recovered 9200' of CT. PT tubing to 1500 psi. Left 530' of stuck CT fish w/BHA in wellbore. Rigged down CTU. RIH w/tubing cutter & cut the 3-1/2" tubing at 8765' MD. POOH w/cutter. Rigged down. Left the lower wellbore Plugged & Abandoned w/cut tubing for Sidetracking. RECEIVED APR 1 4 1995 Alaska Oil & Gas Cons. Commission Anchorage W/AAI SHARED SERVICE WELL: DS 18-18 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 02/27/95 08:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 02/26/95 (1) TD:11525 PB:l1481 RIG ON STANDBY RIG ON STANDBY WAITING ON DS 18-18A PREP. MW: 0.0 02/27/95 (2) TD:11525 PB:l1481 MOVE RIG 18-14A TO 18-18A MW: 0.0 STAND-BY - WAIT ON DS 18-18 PRE-RIG WORK TO BE COMPLETED AND LOCATION LEVELED. MOVE RIG DS 18-14A TO 18-18A. 02/28/95 (3) TD:11525 PB:l1481 03/01/95 ( 4) TD:11525 PB:l1481 L/D TBG HANGER MW: 0.0 FINISH MOVING RIG 18-14A TO 18-18A - HOOK-UP SERVICE LINES. ACCEPT RIG 0800 HRS 2/27/95. TAKE ON SEA WATER - PULL BPV WITH LUBRICATOR - NO WELL PRESSURE INSTALL 2ND VALVE ON ANNULUS - TEST 9-5/8" PACKOFF 5000 PSI -OK. CIRC WELL WITH SEAWATER PUMPING DOWN TBG RETURNS UP ANNULUS - DIESEL AND GEL DIESEL RETURNS. SET BPV AND TEST TO 1000 PSI - BLOW DOWN LINES. ND FMC 3-1/8" 5000 TREE AND ll"X 3-1/8" ADAPTER. NU 13-5/8" 5000# HYDRILL BOP STACK. PULL BPV WITH LUBRICATOR THRU STACK - MONITOR WELL - OK - R/D LUB. TEST BOP: TEST TOP PIPE RAMS, BLIND RAMS, CHOKE MANIFOLD, MUD MANIFOLD, KELLY, UPPER AND LOWER KELLY VALVES AND 3-1/2" TIW & IBOP TO 250/5000 PSI - TEST HYDRILL TO 250/3000 - WITNESS OF BOP TEST WAIVED BY JOHN SPALDING OF AOGCC. - COULD NOT TEST BOTTOM PIPE RAM DUE TO TOOL JT IN RAMS - WILL TEST AFTER PULLING TBG. MAKE UP SPEAR - BACK OUT LOCK DOWN SCREWS. SPEAR TBG BELOW HANGER - PULL TBG FREE 95K-L/D TBG HANGER. TIH - PU 4-1/2" DP MW: 0.0 CBU - MONITOR WELL - OK. POOH L/D 3-1/2" 9.3# L-80 EUE 8RD MOD TBG - RECOVERED 274 JTS & CUT JT. - TOP OF FISH @ 8783' TBG MEASUREMENTS - TBG IN GOOD CONDITION. SET TEST PLUG - TEST BOTTOM PIPE RAMS AND 4-1/2" IBOP TO 250/5000 PSI. INSTALL WEAR BUSHING - MOVE 3-1/2" PIPE IN DERRICK. MAKE UP FISHING ASSY #1 - 5-3/4" OVERSHOT D/WITH 3-1/2" GRAPPLE. TIH - PICKING UP 4-1/2" 16.6 S-135 DP. CAT HEAD NOT PULLING PROPERLY - ADJUST SHIMS ON CLUTCH PLATE. CONTINUE TIH PICKING UP DP. CLIP AND CUT DRILL LINE. CONTINUE TIH PICKING UP DP. WORK ON DRLL SIDE CAT HEAD - ADD ADDITIONAL SHIMS. CONTINUE TIH PICKING UP 4-1/2" 16.6 DRILL PIPE - 8500' PICKED UP @ 0600 HR. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage OPERATION: RIG : NABORS 2ES PAGE: 2 03/02/95 (5) TD:11525 PB:l1481 03/03/95 (6) TD:11525 PB:t1481 03/04/95 (7) TD:11525 PB:l1481 CIRC - DISPLACE TO MILLING FLD MW: 0.0 CONTINUE RIH. TAG AND LATCH FISH @ 8771'. JAR FISH FREE. POH WITH FISH. LAY DOWN 3 1/2" L-80 EUE TUBING WITH 1 3/4" COIL TUBING STUCK INSIDE OF TUBING, BOTH STRINGS WET, CUT COIL TUBING WITH MANUAL PIPE CUTTER COULD NOT DISLODGE COIL TUBING MUD MOTOR. RECOVERED TOTAL 312 JTS 3 1/2" TUBING FROM WELL, R/D CASING TOOLS, CLEAR RIG FLOOR. BREAK DOWN FISHING TOOLS. MAKE UP BHA #2, RIH, TAG FILL @ 9793'. P/U KELLY, WASH AND REAM 9793' TO TOP OF PACKER SLICK STIVK @ 9966' DP. CIRCULATED BOTTOMS UP, CHANGE OVER TO MILLING FLUID. CIRCULATE REDUCE MUD WT MW: 0.0 DISPLACE TO 9.6 PPG USED MILLING FLUID. POH TWO STANDS, MIX AND PUMP SLUG. POH FOR SECTION MILL. CHANGE OUT DRILLER SID CAT HEAD. MAKE UP SERVCO 5500 MILLMASTER SECTION MILL AND BHA. RIH AND SPACE OUT, P/U KELLY. CUT OUT WINDOW IN 7" CASING @9726'. MILL SECTION 9726 - 9729'. HOLE TAKING FLUID. STOP MILLING REDUCE FLOW, START CUTTING MUD, RUN CENTRIFUGE AND ADD WATER. RIH OPEN ENDED FOR KICKOFF PLG MW: 0.0 CONTINUE CUT MUD WT. CUT SECTION 9729 - 9759'. SLIGHT MUD LOSS. PUMP LOW VIS/HIGH VIS SWEEP AROUND TO AID HOLE CLEANING, MAKE CONNECTION. FINISH MILLING SECTION 9759 - 9776'. TOTAL 50' OF WINDOW 9726 - 9776'. PUMP LOW VIS/HIGH VIS SWEEP AROUND. POH, NO TROUBLE GETTING BACK INTO 7" CASING WITH SECTION MILL, 90' OUT OF HOLE STARTED PULLING TIGHT, BREAK CIRCULATION TO CLEAR UP TIGHT SPOT, LAY DOWN 9 SINGLE, WORK WAY INTO 9 5/8" CASING. LAY DOWN BHA ANS SECTION MILL, ONE BLADE SLIGHTLY BENT, 15% WEAR, MILL IN GOOD CONDITION. CLEAR AND WASH RIG FLOOR. RIH WITH OPEN ENDED DRILL PIPE FOR KICK OFF PLUG, BREAK CIRCULATION EVERY 1000'. 03/05/95 (8) TD:11525 PB:l1481 TEST BOP MW: 0.0 RIH WITH OPEN DRILL PIPE FOR KICK OFF PLUG, BREAK CIRC EVERY 1000'. PICK UP KELLY AT LINER LAP, ROTATE AND CIRCULATE. PUMP LOW VIS/HIGH VIW SWEEP AROUND. SMALL AMOUNT OF METAL IN RETURNS. CONTINUE RIH TO 9520', PICK UP KELLY. WASH 9520 TO 100' BELOW WINDOWN @ 9880'. PUMP 30 BBL LOW VIS SWEEP. ROTATE AND RECIPROCATE PIPE ATTEMPT TO CLEAN HOLE OF ANY METAL CUTTING BEFORE SETTING CEMENT PLUG. SET BALANCE KICK OFF CEMENT PLUG. POH 14 STANDS INTO 9 5/8" CASING. CEMENT IN PLACE. CIRCULATE ON DRILL PIPE VOL LONG WAY. HESITATE SQUEEZE. SQUEEZE TWO BBL AWAY, FINAL SQUEEZE PRESSURE AFTER ON HR. EST TOP CEMENT 9469'. POH. SLIP AND CUT DRILLING LINE. FINISH POH LAY DOWN 72 JTS 4 1/2" DRILL PIPE. FLUSH STACK, PULL WEAR BUSHING, OPEN RAMS DOORS CLEAN OUT METAL. SET TEST PLUG, TESTING BOP. RECEIVED APR 1 4 199§ A,~aska Oil & Gas Cons. Commission Anchorage MEMORANDUM TO: David Johns_.~~, Chairma5 ~ THRU: Blair Wondzeil, ~..~ P. I. Supervisor FROM: Bobby Fost~~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 23, 1995 FILE NO: SUBJECT: PE91BWCD.doc Perforation Cement Plug ¢~, ARCO - PBU - DS18-18 Prudhoe Bay Field Thursday, February 23, 1995: I traveled this date to ARCO's DS18-18 to witness the pressure testing and tagging of a cement plug set to abandon the perforations in preperation to side track this well. The first cement job on this well would not hold pressure and had to be re-cemented. I arrived on location as the wireline unit was rigging up to go in the hole. I spoke with Robert Swannie: ARCO wireline unit supervisior, about the tagging job. He said that the CTOC was 9,950'. The unit finished rigging up and the crew pressured up on the lubricator and the tubing to 1650 psig and held the pressure for 30 minutes. The tool string was run into the hole to 2,234' where it stopped at the SSSV. Robert said the valve should be locked open. We observed the SSSV control line pressure gauge at the tree and found it had 200 psig on it. This was pressure up to 4,000 psig and the tubing pressure was pumped up to 1800 psig. The valve, a tubing retriviable Camco TRDP, opened and the tool string was run on in the hole with the pressure held on the tubing. At 8,895' the tool string stopped. After working the tools up[ and down for almost an hour, it was decided to pull out of the hole. The tools were at 8,988'. The. tool string was equipped with a "bailer" and when the tools were out of the hole, there was no sign of cement nor any other material in the "bailer". Robert and I returned to the office and spoke with John Smart, ARCO wireline supervisior, and a desision was made to stop the job until a desision could be made as to what action should be taken. Friday, February 24, 1995: I met with John this date and he informed me that after speaking with the drilling department tha tit was decided to rig up a coil tubing unit and clean the cement/contaminated mud out of the tubing to the desired depth of 9,950'. I told John that de,sion sounded OK to me, but when the tubing was cleaned out to the desired depth I wanted another pressure test performed. John agreed and said an inspector would be notified so that the test could be witnessed. Summary: I witnessed the pressure test and .tagging of th~..unacceptiable cement plug set to abandor~-"e perferations in ARCO's DS18-1 ell. The pressure test and tagging will be performed at a later date. Sunday, February 251 1995: I received a call at 5:00AM this date from Dan Vanhouser, wireline supervisior, informing me that he would like to test the cement plug on well .DS 18-18 as soon as ! could be on location. I arrived at 6:30AM. A coil tubing had been used to clean out the excess cement in the tubing to 9,930'+- and as they were coming out of the hole the coil tubing became stuck at 9,700'+-. It was decided to cut the coil tubing off at the top of the tree and clear the coil tubing of the water being used to circulate with. A E Line unit was rigged up and the tubing was cut off at approximately 9,200' and the the water in the tubing was replace with methnol. The coil tubing was then spliced and the 9,200' of tubing ws pulled out of the hole. At this point a pressure test of 1600 psig was performed and held OK for 30 minutes. A workover rig will be moved in and try to recover the fish in the 3.5" tubing when the tubing is pulled so the well can be side tracked. Attachment: ARCO Wellbore Schematic Well: 18-18 Spud Date:10/26/88 Original RKBE:54' Top of Formation: 8974' Annular Fluid:Diesel Reference Log:BHCS ~-RCO Alaska, Inc. - Prudhoe---'%y API #: 50-029-21872-00 ' Completion: 12/5/88 Hanger Type: 3-1/2" FMC Gert IV-Retro Max Hole Angle: 91° @ MD: 11407' Date:00/00/00 Tie In: Type:PRODUCER Status:New Hanger:30' Angle @ TS:91° Angle @ TD:91° Date: 00/00/00 ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHEKE NOTED. J-1 Jewelry (J) Depth Description 1 2224' 3-1/2" Camco TRDP-1A-SSA SSSV Nipple ID=2.813" 2 8199' 3-1/2" Otis X Nipple ID=2.813" 3 9975' 3-1/2" TIW0vershot Seal Assembly 4 9984' 7" x 3-1/2" TIW SS Packer 5 10118' 3-1/2" Bottom of Baker/Brown Seal Assembly (Not Stung In) 6 10244' 5" x 7" Baker/BrownLiner Hanger W/PBR 7 FISH: 1-1/2" CA Circ Valve (Lost 12/07/88) Min ID: 3-1/2' Otis X Nipple ID=2.813" G-1 J-2 Casing and Tubing (C) Size weight Grade 1 13-3/8" 72# L-80 0 2 9-5/8" 47# L-80 0 3 7" 299 L-80 8605 4 4-1/2" 11.3# L-80 10338 5 4-1/2" 11.3# L-80 11482 3-1/2" 9.39 L-80 0 Top Bottom Description 3473' BTC Casing 8934' BTC Casing 10317' BTC Liner 11482' FL4S Liner-Slotted 11525' BTC Liner 9975' Tubing-PC I I C-2 J-3,4 J-5 J-6 C-3 P-1 J-7 Gas Lift Information (G) MD TVD Stn Mandrel Valve 3519' (3519') t CA-MMG-2 CA 8085' (7770') 2 CA-MMG-2 CA Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF 1 10338-11482 1A/lB 1144 N/A Oil Based Mud Datum 8700' SS= 0' MD PBTD=l1481' 8800' SS= 0' MD TD=11525' Ty~e Latch Port TRO Date RKED RKP 12/08/88 RKED RKP 12/08/88 Date Comments 12/08/88 SLOTTED LINER Revision Date: 05/22/93 by PTB Reason: 4D CONVERSION Previous Reason: 11/14/92 well 18-18 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging X Time extension __ Stimulate __ Change approved program __ Pull tubing__ Variance__ Perforate__ Other X __ Plugback for redrill 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development x KBE = 54' feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 406' SNL, 205' EWL, SEC. 19, T11N, R15E At top of productive interval N/A At effective depth N/A At total depth 1654' SNL, 1623' WEL, SEC. 13, T11N, R14E 18-18 9. Permit number 88-113 10. APl number 50- 029-21872 11. Field/Pool Prudhoe Bay Field/Oft Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11550 feet Plugs (measured) 8709 feet N/A feet Junk (measured) feet Length Size Cemented Measured depth 80' 20" 2150 # Poleset 110' 3435' 13-3/8" 2ooo sx cs ,//6oo ~ "G"~2oo ,x cs, 34 73' 8902' 9-5/8" 750 sx Class "G" 8935' 1712' 7" 500 sx Class "G" 8605'- 10317' 1281' 4-1/2" Slotted liner 10244'-11525' measured Slotted Liner Completion (10338'-11482' MD) true vertical Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing w/taft @ 10019'MD True vertical depth 110' 3473' 8258' 8090'-8667' FEB -9 1995 Alaska 0il & Gas Cons. Commission Anchora ~ Packers and SSSV (type and measured depth) Camco 'TRDP-1A-SSA' @ 2224' MD; TIW 'SS' Packer @ 9984' MD 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 2/15/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~,7~/g~,~, ,-~.~-¢~.~.~-- ~-~,.¢.- T~"c/~Z". ' Title DrftlingEngineerSupervisor .- FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test__ Location clearance__ Mechanical Integrity Test __ Subsequent form reauired 10- /'~ r,)'(' ,:';g nal Signed By (~vid W. Johnston Approved by order of the Commission IApproval N o.¢,,.~--_~~ Approved Copy Retucned · ~C~c./,"/.m..-~.'_~si'~er . ~. Date ~.~//~-/~.~'"~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE '~---- BP EXPLORATION ARCO Alaska, Inc. Subject: DS 18-18 Pre-rig Work / P&A Nabors 2ES will be moving on to DS 18-18 after completing DS 18-14A sidetrack on or @ Febuary 25, 1995. Contact the Nabors 2ES supervisor for moving schedule updates. The following is the work scope that must be completed prior to Nabors 2ES MIRU' 1. Lock open the Camco TRDP-1ASSA SSSV. Valve was set at @ 2224' MD. 2. Perform a full bore P & A to the well. Pump 28 bbls of cement to cover the perfs up to 10237' MD and to squeeze away 5 bbls. The volume break down is as follows: a. 1143' of 4.5" Slotted Liner = 19 bbls b. 100' of 7" 29# csg = 4 bbls c. Squeeze away = 5 bbls Note' The objective is to pump enough volume to fill slotted liner and to bring cement 100' above the top of slotted liner and inside of 7" casing 3. RU slick line. RIH and tag cement. POOH. ( AOGCC should witness this tag ) 4. RIH and cut the 3-1/2" tubing as close to TIW overshot assembly as possible. KOP will be at 9730' MD so it will have to be cut @ 9930' MD Kill the well, freeze protect. 5. Bleed tubing and annuli pressures to zero. Set BPV. Please test BPV by preassuring down inner annuli to 500 psi 6. Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Please provide total well preparation cost on the handover form. FEE~ "9 1995 Gas Cons. Commission Anch0ra. ~ BP Exploration (Alaska), Inc. Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 561-5111 Co-Operators, Prudhoe Bay Unit ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 DATE ' 4-t t-90 R E F:' E: R E: N C:: E ' A R C O M A C; N E: T I C T A P E ( S ) W :[ '1" H I... ]: ,S' 't" ]: N (.: ( ,:'~ ) · -S4 L'~-2S-90 '.5.-. 4 S-'22--90 5-'10A S-1 -90 8 "- ~' ':~ - 24 - 9 O 8-t 8 2-'25-90 CNI_ (S I:'A$,";) ,.JOB-'~-4249 CNL. (6 F'A,S'S) JOB~4'2'17 TDT-F' (6 PASS), RUN t JOB:~.'737::~S I"DT-'F' ( .S F:'A.':,'~? ) , RUN i.,__ ....-.., ,JOB:~:7.'.'~,71 '7 PI_E:A,~'E: .<:.'IGN AND F;,'FI"URN THE ATTACHED COPY AS' RE:CEII='T OF:' DATA. RECEIVED BY ....................... ~~ HAVE: A NICE DAY! SALLY FI£]FFECKER A'I"O- t 529 TRANS':~ 9 ,qPR 1 8 1990 ~laska Oil & Gas ~o~. ~missJo~ CENTRAL FILES (CH) CFIE'"VRON D & M TAMMAS BROWN (OH) EXXON MARAI'HON MOBIL ~ F'HILLIP$ 'Il* F'B WELL F'IL.E:S R & D ... BPX ~ ~FAI'E OF ALA~'I<A TEXACO A T' I_A ,~,' A 'T' I... A Zi.' ;:.?CH $ C FI .'_'~ C I..I P., C!. ? !3 X i (') "S' :_":~; :'::. A N C H 0 R A (.; F": A L A 2 K A c,, ? ..,-'~' i ,"-;,, ii..'. F: Ii..'. R E"_' iH C E ' A R r-: 0 rS A,~-.'..' Er D H 0 I_ E F: :[ N A !... 2 F:' L ~::. A ::? E 2 i (;- N ~c-~ i"-.i D F;,'tE T U F;.: N ]" i--i t:' ~,.'~ ~ T A C H E f) C 0 F' Y A 2 r', r' ..... :' ... . ' I--tAV'-~z A NICE _f':,AY'. A T (;) .... i 3 2 9 RECEIVED ','i- R A N ;<.,' :~ 9r3 .... ~" MAR - 8 t990 Alaska 0ii & Cons. Com Ssl0- · .-"" CENTRAL Iz'rLES, · · .-""C 1-.I E V R 0 N D & M '" E X T E N E.-' I 0 i'.! E X F:' L 0 I:;.: A 1" i 0 N · ~ i::X yl-I M 'it' ~._ M A F;..' A T H 0 N · ~ MOB i[ L - PHI L_L I F',~i: ,,,1E,.. L ~::' ]: I_. E. ;~ F'B t "~ , '-' -.- B F:' X ~-, ,?'f'ATE OF AI_AE.'KA '"' ]" !":; X A C 0 !..: ,' :; ?, i...; !...-: C A i'.t,......."" ARCO ALA2KA, iNC~ P, O, BOX i (') ':.'!) 3 6 (') ANC;HORAGE, ALA2KA DATE · J -3'-9~'} REFERENCE' ARCO F'RE£"$URE DATA · 5-5 9-i 3--89 BHI:: .... Fl._OWING GRADIEN'T' · 3'-i '? 6-t t-8'-T" BHF ..... FLOWING GRADIENT 6-'6 ":..;'-i 4-89 BHF ....5,'TATIC GRADIENT 6-14 9-7-89 BHF ....;~'TATIC GRADIENT 6-2i 9-'28-89 B, HF ...... F'LOW.," NG GRADIENT 9 -'= ' '3 ..... · ..:. '~ i i UY BHF ...... FI_OWING GRADIENT ,:.) _ '-, ,'-, 0 _ '-, ."~ _ (::, ,':, ,- .-'? ,- ~... ,..,.';. :(-.",'I-.IF-" '-,:'~TATIC GRADIENT 9-5;3, 9-2'?-89 BHF ....£TATIC GRADIENT 9-;5.5 9-5¢-89 BHF ..... 2'-f'A'i" I C' GF;.:AD I ENT 9-'5~ 9-~--S9 BI'IF .... Y'rAT:I:C GRAD l EN'i' i ;~J-2 '-',;'-i .7.,-89 BFtF .... 2'¥ATIC GRADIENT i 5-i I 9 ' i :5-'-89 BHP--i."TATIC GRADIENT i :S-Se 9-i 3-89 BI-'IF'--~'TATIC GRADIENT i 4-28 9-i '7-89 BI4P--.':,':.TATIC GRADIENT I 4-.'58 9-2-89 BI"tP--£,'TATIC GRADIENT t 5-2i 9-3-89 BHF ..... ;~."TATIC GRADIENT i6-2¢ t¢--4-89 BHP--£'TATZC GRADIENT t 8-i 8 '7-.'5-89 BI. IF .... ,'9'f'ATIC GRADIENT i 8-2t 7-5-89 BI.It::'--S'TATIC GRADIENT C A M L.' 0 C A id C 0 C A M C 0 C A M C 0 C A i',1 C: 0 C A M C 0 C A M C 0 CAidCO C' A M C' C1 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO C A M C 0 C A M C 0 CAMCO F'LEAZE Z. IGN AND ~,,'b..'~ JRN 'THE ATTACHED COPY AS I:;,'IECEiF'"I" RECEIVED BY HAVE A NICE DAY! ~ALLY HOFFECKER ATO-~ ~9 01: DATA~ DISTRIBUTION CENTRAL FILEY ~ PFtlLLIF'5' CHEVRON F'B WELl..' F]:I..E,:? '* D & M' ~ R & D EXTEN£ION EXPLORATION $ BPX ,,~ EXXON ~ ,~'~TATE OF ALA~'KA MARATHON ~ TEXACO · .-"' M 0 B I L ANCHORAGE, At_AS'KA DA Ti!i. · · 7- ~ 9-89 REI=ERENCE· ARCO CASED HOLE FINALS H I T N J E C T I 0 i',! F' Fi: 0 F:' I L. E S U R VIE Y COL. LAR/F'EF..'F F'!:;..' 0 i)U i'-: T I 0 N F:' Fit [.i F;' ]] L [; ,~: U I:( V E;' "'l"' F'I;:.ODUCT i ON F'I;..'OF i t..E ;!.;'tJl:;.'.VE"f F' I 'F ,S' F' I T :"--: i::'i::'ODUC. T I ON I::'ROI:: I i...E F'RODUCTIGN F'I;eOFII_E S'UI-i'¥1EY Pt-i:ODIJC'i" ]: ON F:'F;:OF I i_lS LEAK F:,ETECT i r/N LEAK i)ETECTION LEAK DETECTION, GR/CCL GR/CCL F't_EASE SI(;-iN ANI) RECEIVED BY HAVE A NICE DAY! SALLY HOFFECI<ER ATO-i 52:? RETURN THE ATTACHED COPY AS RECEJlF'T ........ r,--. ~ ......:,.:.' !;!} AF:'F'I --'z~--"L' .f. -~ ,. F;.'LJN i , ....~" RUN i , ]i:" F;,' U N1 , 2 ".S...%" RUN i, 5:" RUN i, 5" RI IhI i , RUN i, 5" I;:tJN i ., 5-" RUN i .~ 5" RUN i, i" RUN. i, i" RUN ~ , 5' RUN t, D" I-;.:UN ~ , _,.':"" I)A 'i"A C: A/'1C 0 ~':k ]'1_ ,q S' C A i"i !.. :0 C A i'i (".; L) C A M C 0 [; A f'i (:.' ',:J C A H C U C A d C (3 C A f'J C 0 C A M C 0 CAMCO DISTRIBUTION CENTRAL FILES ~- F'FIII_LIF'$ CHEVRON PB WELL FILES DaM R & D EXTENSION: EXPLORATION ~ BF'X EXXON ~ ~'"i"AI'E OF ALA~'I<A MARATHON :'.': TEXACO MOBIL . "- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMI LETION OR RECOMla'LETIOI',I REPORT Al,ID LO I 1. Status of Well Classification of Service Well OIL ~ GAS [~ SUSPENDED ,, , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-113 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-21872 4. Location of well at surface 9. Unit or Lease Name 406' FNL, 205' FWL, Sec.19, T!1N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. WelI Number N/A 1 8-1 8 At Total Depth 11. Field and Pool 1654' FNL, 1623' FEL, Sec.13, T11N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 54'J ADL 28307 ALK 2317 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/27/88 11/20/88 12/07/88I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth whereSSSV set t 21. Thickness of Permafrost 11550'MD/8709'TVD N/A ... YES ~' NO []I 2224' feet MDI 1900' (approx.) 22. Type Electric or Other Logs Run CBT/MWD -- 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91._5# H-40 ~,,rf 11r)' ... 9r),, 31 J0# Poleset .. 1:~-3/8" ~8_0/72.0# K-5_cJ/I-BO .~Hrf RZ;TR, 17-1/?,, ~nln ~ cR III, & 600 sx C!85s G-Top job ~./~_00 sx 9-5/R', b, 7 _0# I-Rr) -~,_, r f 8935' 12-!/4" 750 sx 7" 29.0# L-BO 4-1/2" 11.35# L-80 J 102b, 4' 11_~25' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ...... 3_1/2,, 10019' cj984' (DPM) , ,, Slotted Liner Completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST ..... Date First Production I Method of Operation (Flowing, gas lift, etc.) I '1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD II~ r Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE ..... 28. CORE DATA ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or v~ ~.S~n~ IoVc~PD · None MAY 1 0 1989 Alaska Oil & Gas C0n~. C0mmissior~ Anchorage CS II Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. F'ORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. I.,{ST OF ATTACHMENTS Mone 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ "~.~~J Title Regional Drilling Engrlgate - / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL ~ LOCATI~: LAT(~,-S) 0.00 ?Il! IN ~I~(?IP): INC%.I~?I~ AZI~'I. m4 340.60 RECEIVED APR 2 1 1989 Alask~ Oil & Gas Cons. Commissio~ Anchorage ~aLqCl~ Ig1116~ VERTIC~ ft ft ft 5100,00 0,0 5137.56 37,6 $137,~ 5231.55 94.0 5231.49 5293.,~ 62,0 5293.43 5323.86 30.3 5323,65 TARb~ STATIOM AZIRJI~t LATITUDE S~'TIO~ [NCLM, M/-$ ft d~ d~ ft 0,~ 0.~ 0,~ 0,~ 0.~ 1.~ 53.49 0,~ 2.27 2.M 6.~ 3.~ 5.17 3,51 11,73 6.~ 6.'~ 4,10 4,21 8,24 DEPARTIJ~ DISPLACB'ENT at AZIMUTlt ft ft deg 0.00 0,00 0.00 0,I8 0.4O 26,75 1,70 3,45 ~..48 2,21 6,63 17.45 2,49 8,61 16.79 DLS lOOft 0.00 3,33 2.09 1.57 2.55 5418.34 5513.03 5793.12 5890,41 94,5 5417.74 ?4,7 5511.79 92,9 54O3,49 187.2 5785,90 97,3 5879,48 14,99 6,18 358,54 16.70 2,28 16,86 7.79 2,26 25.43 7.16 351.89 27,65 1,37 27,69 2.83 1.32 40.02 10.~3 348.33 42.03 -1.14 42.~ 3~.45 4.10 81.75 15.00 345.70 82.~ -lO.~ 83.62 352.73 2.20 108.31 I6.72 339.82 108.34 -18.44 109.89 350.34 2.41 5985.66 6081,48 6172,85 6237,67 4329,67 ~.3 5970.51 96.0 &041.41 91.2 614{.55 ~.a 62~.3~ 92.0 13~.29 17.53 334.3~ 134.16 -29.34 137.34 347.~ 1.90 1~.99 20.01 333.70 161.94 -42.~ 167.52 345.17 2.59 19%37 21.91 ..'~.~ 191.21 -57.26 199.60 363.33 2.09 224,16 23.32 33~.53 213.75 -67.~9 224.27 342.3~ 2.37 261.0~ 24.09 33'/.51 247.&7 -82.63 261.09 ~1.5'J; 1.20 6422.42 6~.76 667%20 6769,7"3 ,58,66.17 92,a 4375,10 161,5 6520,43 95,2 6605,37 90,5 4445,41 96,4 6770,37 299.23 24.67 .334.89 282.70 348.8~ 26.76 333.59 345.82 411.92 27.56 331.,,5 384.37 453.71 28.15 332.09 421.~. 498.89 28.32 3ZLO~ 442.12 -98.08 299.23 340.87' 1.32 -128.~4 3~.94 339,61 1.34 -148,43 412,11 338.86 1,36 -I46.67 454.11 338.20 0.75 -189.48 499.~ ~.48 0.~ 6~I.~ 7148.~ 7~1.48 73~.~ 7430.~ ?4,9 4653,67 187,9 7017,30 92,9 7O97,60 126.0 7205,08 62.8 7257.85 636,~ ~,98 3;38,~ 5~,~ ~2.91 ~,~ 339,~ 431.51 748.61 ~,~ 3~.~ 692.74 782,57 ~.~ ~8.~ 7~.~ -209..~ 544.91 337.37 1.0~ -24~.0'J; &37.29 337.29 1.21 -262.48 ~3.96 337.41 0.53 -28~.43 749,69 337,52 1.~ -299.28 783.48 337,55 0.97 7462.39 7b'S~.80 7741,78 7842.55 31.7 7284.42 94.4 7~2.21 32.1 738~. 18 153.1 7510.08 100.6 758~.43 7W,91 33.~ 337.92 740.~ 8~3.~ ~.~ 334.~ 7~.~ ~1.~ ~.~ 334.~ 8~.~ 9~,~ 38,~ 330,~ 8.B8,~ 10~.92 ~,24 331,~ 9~.01 -305.73 ~01.04 337.56 -327.23 854.~ 337,48 -33~.28 873.29 337.42 -377,72 ?6%63 336,77 -4O7.96 1028.39 33~.63 1.16 3.29 0.96 2.17 1.I0 7937.40 8031.50 6125.29 8304,04 8319.31 94.9 7,~1.0~ 94.1 7731,09 93.8 7798.36 180.8 791%68 13.3 7928.39 108a.21 40.81 331.83 997.a0 1148,36 43.01 332.26 1053,32 1213.04 4~.32 3b"2,69 II11,26 1346.05 50.33 33'J.28 1231.59 13~6.00 47.61 333.40 1240.62 -436.71 1089.18 336.~ -466.18 1151.87 336.13 -496.37 1217.08 3315,~ -5'55.10 1350.91 335.74 -559.44 1360.92 335.73 1.66 2.3~ 2.48 2.97 23.11 8404.43 8564.06 8686.20 8750.96 87.1 7983.81 29.3 8001.08 128.3 8072.59 122.1 813a.35 44,8 8173.60 1422.7~ 53.34 .3,'5.72 1301 144~.3~ 54.39 33~..;'3 1322.83 1552.43 5'7.88 337.10 I420.48 !6~,42 56,97 :338,28 1515,70 1709.71 57,07 3,~. 12 15,~.31 -568.29 1428.07 335,6)' -598,02 1451.73 335,67 -640.65 155~.27 33~.72 -679.72 1661,13 335,85 -699,45 1715,39 335,94 6.69 3,58 2.8a 1.10 1.10 TN~I;E1' S'I'ATI~ ~I~.r!'H ~TITUD£ SI~L'TI~ II, L'U~. hl/-S ft ~e~ d~) ft 1767.2& 60,28 338,&6 1620o03 1808.77 42.11 337.31 1658,b5 1899.44 65.10 339,50 1742.91 t98~,~ ~,Tt .337,98 t823,83 2072,~ ~.29 338,65 1~3,11 E/-W ft ft -720.19 1772.90 -735.76 i814.42 -769.16 -8(~).~ 1991.~ -834.03 2078,~ AZIMUTH ~6,03 D~ 4,~ 4,59 3.53 2,23 2.14 9"~0.16 9344.08 9372.10 ?442.69 9534.74 94,2 838~i.05 93,9 8416,87 28.0 ~4Zi.91 70.6 8447.47 92.0 8474.40 2160.35 69.62 336.13 19M.28 2248.40 70.78 335.34 2064.84 2274.84 71.57 33~.8,7 2089.09 ~1 ~91 72.8:5 33~.99 2150.~ 24:29,74 73.13 33~.4~ 2231.78 -~69,25 2146,33 336,34 -*~:)5,% 2254,69 3:.36.32 -916,31 2281.21 336,32 -942.~ 2~.42 336.33 -977.44 2436.44 334.~ t.50 1.47 5.89 1,82 0,64 96~.42 9722,01 9817.51 ~11.~ 1~.51 94.7 8501,9~ 92.& 8528.89 ~.5 8556.31 93.8 8~1,~ 94.2 8605.53 2520.04 73.~ 33~,~ ~14,~ 2~.34 73.20 334,01 2'~.~ 26~.~ 73.43 3116.47 24~,25 27~9,57 74,85 336.35 2561.96 28~0,37 76.15 334.65 2644.92 -1014.05 2527.02 33~.34 -1050,18 261~,61 33{.33 -1087.03 2707.09 33~.32 -1123,15 2797,34 334,33 -1I~.~ 28~.50 334,30 0,61 0,26 0.52 1 2.2'3 10098.33 10191,67 10287.,M 10350.02 10380.59 92.a 93.3 ~47.17 96.0 __m~_7.21 62,4 8~78.o2 30.6 8682.Ol 2970,33 77.31 336.~ 2727.03 3041.07 77.52 334.99 2809.94 3154,50 78.3~ 33~.31 289~o10 ~I$.61 81.6& 334,34 2950,69 3245,71 8;].~ 333o41 29~.91 -1198.62 2978,82 33~,27 -123~.37 3069.91 33~.2~ -127%81 31~,~ 33~,22 -1301,94 322~.16 334,I9 -1315,28 ~5.44 336,17 1.94 1.14 0.~ 5.48 10412.79 1O507.48 10537.21 I0570.6a 32,2 ?4.7 ~9. 29,7 ~6a9,20 33,5 86a9,30 30,0 86a9,42 3277.53 85.24 334.41 30~.,~ 3371,51 89,98 :]33.79 3091.76 3401,01 89,85 333,18 3118,3~ ~,~ 89,80 3:3:3.45 3148.27 3463.94 89.77 333.~7 317~,08 -1329.37 3287,45 336.1:5 6.63 -1370,69 3381,98 ~6,09 5,05 -1383,~6 3411,~ 336,07 2,09 -1398,99 .344~{, 11 336.04 0,82 -1412,3~ 3475.04 336,02 0.40 10689.~ 1O748.40 1~9.70 10943.00 I1037,~ 89,2 ,~.0~ ~.& 8691,03 131.3 8,69~,28 /':3.3 8498.40 94.4 3552.~ ~.~ 33~.~ 3254.91 ~10.~ 8.~ 333.~ 3307,34 3740.93 ~.~ 334.40 3803.74 ~.71 333,~ 13482,16 -1452,12 3544.14 335,96 -1478.21 3622.65 335,92 -I53~.70 37~3,81 33~,~ -1563.34 ~17.~ 335.82 -1,.~Y~,26 3911,32 .33'3,77 0,41 1.32 0.98 1.78 1,10 11129,00 11221 11313,80 114~,10 91.4 ~10,59 92.? U14.~ 91.9 ~15.2& 92.8 8713.~ 29,5 8713.31 3987.98 8~.89 33{.98 ~48.53 4080.13 88.44 33:3.41 3731,74 4871.53 90.43 33~.02 3814.82 42~.9~ 91.30 33'J.43 3899.41 4293.31 90,82 333,6~ 3926.04 1.41 1.78 3.5'7 1.13 6,15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other MWD Submitted 2. NameofOperator ARCO Alaska, Inc. 3'AdCr.%s. SBox 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 406' FNL, 205' FWL, Sec.19, T11N, R15E, UM At top of productive interval N/A At effective depth N/A At total depth 1654' FNL, 1623' FEL, Sec.13, T11N, R14E, UM (MWD svy) 6. Datum elevation (DF or KB) RKB 36 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-18 9. Permit number/approval number RR-11%/9-nn3 10. APl number 50-'~29- 21872; 11. Field/Pool Prudhoe Ba), 0il Pool 12. Present well condition sUmmary Total depth: measured true vertical Effec!ive depth: measured true vertical 11550'MD 8709'TVD N/A N/A feet feet feet feet Plugs (measured) None Junk (measured) None Casing Length Structural Conductor 80 ' Surface 3435 ' Intermediate 8902 ' Production 1712 ' Liner 1281 ' Perforation depth: measured Size 20" 1 3-3/8" 9-5/8" 7" 4-1/2" Cemented Measured depth True vertical depth Slotted Liner Completion true vertical 2150# Pol eset 1lO'MD 2000 sx CS III & 3473 'MD 600 sx Class G - Top job w/200 sx CS II 750 sx Class G 8935'MD 500 sx Class G 8605'-10317'MD Slotted liner 10244'-11525'MD 110'TVD 3473 'TVD 8258'TVD 8090'-8667'TVD 8679'-8706'TVD Tubing (size, grade, and measured depth) 3-1/2", L-80, tbg w/tail @ 10019' Packers and SSSV (type and measured depth) Camco 'TROP-1A-SSA' SSSV ~ 2224~, TIW 'SS' pkr ¢ 9984 (DPM/ 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Alaska .0/1 & Gas Cons. C¢,mmlssl0n '"Anchorage 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~,- MWD ! Daily Report of Well Operations __ Oil ~ Gas __ Suspended __ 17. I hereby certify that_the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 0 Service (DAM) SW04/032 feet Date fZ~/z~ SUBMIT IN DUPLICATE CD~FARY AA'CO AI,ASXA~ INC. WELL NAI'IE DS I8-18 LOCATION 1 F'~'UI)I-E)E BAY I, OCATION 2 NO~91,1 SLOPE MAGhE'TIC D~LINA?ION 31.06 DATE: 23-l,EIU-88 WELL NLetBBR 0 ~ HEAl) LI~aqTION: LAT(~-S) 0.00 AZI)UTH FRON ROTARY TABLE TO TARGET TIE IH POINT(TIP) MBA,,qJRED DEPTH 5100.00 l'~!JE VE~T DIe-'TH INCLINATION 0.00 AZIMUI14 0.00 LATII'UDE(~-S) 0.00 D~A~q't,t~E(~-W) 0.00 DBP(E/-W) 0.00 RECEIVED ~ ,, r", ~ .? .~/' Alaska Oil & Gas Cons. C(.,,mrnission ~.. Armhorage M~ I~L VER'~Ir.d~I. 5100,00 0o0 5137o56 37,6 5137o56 5231,55 94.0 5231.49 5293.58 62.0 5293.43 5323.86 30,3 5323,65 St.EUEY RADIUS OF CLIR~TL.]~E TARC:~'T STATION AZIPIJI'rtLATITUO£ S~L'tTION INCLNo N/-$ ft deg deg ft 0,00 0.00 0.00 0.00 0.27 1.25 53.49 0,35 2,27 2.58 ~.17 3.00 5,17 3.51 11.73 6.25 6.95 4,10 4.21 8.24 O~ARTiJI~ OISPLqCI~X~IT at AZIMUTH ft ft d~ 0,~ 0,~ 0,~ 0, I8 0,40 26,75 1,70 3,~ 29,48 2,21 6,63 19,45 2,~ 8,61 16.79 DLS lOOft 0,00 3,33 1.57 2.55 5418.34 5'513.03 5605.90 3793.12 5890,41 94,5 5417.74 94,7 5511.79 92.9 5603.49 187.2 5785,90 97.3 5879.48 14.99 6.18 E~'~8,54 I6.70 25.63 7.16 351,89 ~.65 40.02 10.~ 348.33 42,03 81,75 15.00 ~5,70 ~,95 I~.31 I6,72 339,87 108,34 2,28 16.8& 7.79 2,26 1,37 27,69 2,83 1.32 -1,14 42,05 358,45 4.I0 -10,58 83,62 352.73 2.20 -18,44 1~,89 350.34 2.41 5985,66 6081,68 6172,&5 6237,67 ~329.67 9~,3 5970,51 96,0 //)61,41 91,2 6146,55 64.8 6206.38 92,0 6290,62 136,29 17.53 334;36 134,16 -29,34 137.34 347,&& 1,90 l&&,9~ 20,01 333,70 161,94 -42,&7 167,52 345,17 2,59 1',~',37 21,9t 333..95 191.21 -57,26 199,~ 3a3,33 2.09 224,16 23,32 33~,53 213,75 -67,89 224.27 342.38 2.37 261.0& 24,09 337.51 247.67 -82,&3 261,09 341.55 1.20 6422,42 6583,96 6679,20 6769,73 6866,17 92,8 ..4375,10 161,5 6520,63 95,2 ~0,5 6685,41 96.4 6770,37 2~,23 24,67 .334.89 282,70 368,88 26,76 333,59 345,82 411,92 27,56 331,35 384,37 453,71 28.15 332,09 421,62 498,89 28,32 333.08 462.12 -98,08 2~,23 340.87 1,32 -128.54 368,94 339,61 1,34 -148,63 412,11 338,86 1,36 -168.67 454,11 338,20 0.75 -189,68 499,53 337.68 0,52 6961,07 7148.~9 724t.6~ 7367.88 7430.65 94,9 6853,67 187,9 7017.30 ~,9 7097.~ 126,0 7205.08 62,8 7257.85 544.04 28,~ 334.76 502,95 636,22 29.98 338,85 587,87 682.91 30,.38 339.43 631,51 74~.61 32,53 337.84 692,74 7~2.57 33.04 33,8.46 724.~ -209.~ 544,91 337.37 -246,05 637,29 337.29 -262.68 683,96 337.41 -28~,63 749,69 337,52 -299.28 783.68 337.~ 1.0~ 1,21 0,53 1.83 0,97 7462,39 7588,86 7741,98 7842,55 31.7 7284,42 94,4 7362.21 32.1' 7388,18 153,1 7510.08 100,6 7588,43 75/9.91 33.26 337,92 740,40 853,24 35.76 334,.~ 789,36 $71.94 3~,07 334,69 806,36 963,70 38,40 330,76 8.~8,69 1025.92 3~.24 331.92 944,01 -305.73 801.04 3:37.54 -327.23 854.50 337.48 -335.28 873.29 337.42 -377,72 ?65.63 336.77 -407,96 1028.39 33..4.63 1,16 3,29 0,96 2,17 1,10 7'737.40 8031,50 8125,29 8306,04 8319.31 94.9 94,1 7731.09 93,8 7798,36 180,8 7919,68 13.3 7928,39 1086,21 ~,81 331.83 9~7.80 1148,36 43,01 332.26 1053,32 1213,04 45,32 ~'2,69 1111.26 1346,05 50.33 335.28 1231,59 1356.00 47.61 333.40 1240,62 -436,71 1009,t8 336.36 -4&&.lB 1151.87 336.13 -496,37 1217.08 335,93 -555,10 1350.91 335,74 -559,44 1360.92 335.73 1,66 2.36 2.48 2.97 23,11 8406.43 8435,72 8564.06 8686.~ 8750,96 87,1 7983,81 29.3 8001.08 128,3 8072.59 122,1 8138,35 64,8 8173,60 1422,79 53,34 .305.72 1301,27 1446,36 54,39 335,73 1322,83 1552,63 57,88 337.10 1420,48 !655,42 56,'~7 :338~,28 1515.70 1709,71 57,07 339,12 1566,31 -588,29 1428,07 335,67 -598,02 1451.73 335,67 -640.65 1558,?.7 335,72 -679.72 1661,13 335.85 -699.45 1715,39 3:35,94 6,89 3.58 2,8~ 1,10 1,10 PAGE HO, 3 "-' ~"')S 18-18 ME~ IHT~ VERTIC~ DEfl~ DEPTH ft ft ft ~I8.37 6?.4 8208.64 8~5.7~ 47.4 8231.49 ~967,10 I01,3 8276,52 9062,22 95,1 9155,94 93,7 835I 9344.08 9372,10 9442,69 9534,74 94.2 8385.05 93,9 8416.87 28,0 8425,91 70,6 8447,47 92,0 8474,40 ************* AHAORILL ********~:::c, SURVEY CALCUI~.TIOHS ***** P, AOIUS OF CURUA~ )~'IHO0******** TAI~ET STATION AZIMUTH LATITUDE SECTI~ IHCI~, ft deg de~ ft 1767,26 60,28 338.66 1620,03 1808,77 62,1i 337,31 16~,b'5 1899,44 65,10 33~,50 1742,91 1986.22 66.71 337.98 1823,83 2072.66 68,29 336,65 1903.71 DEPARTURE DISPLACEMB4T at ~/-g ft ft -720, I9 1772.90 -735.76 1814,42 -769,I6 1905,08 -~00.64 1'~91,83 -834,03 2078.40 2160,35 69.62 336,13 1984,28 22_48,40 70,78 335,34 2064,84 2274,P.A 71,57 336,87 2089,09 2341.91 72.85 336,99 2150.93 2429,74 73,13 336.,45 2231,78 AZIPUI14 deq 336.03 336.0B 336.19 336.30 -869.25 2166,33 336,34 -905.56 2254,69 336.32 -916.31 2281.21 336.32 -942.65 2348,42 336.33 -977.44 2436,44 336,35 D~ lOOft 4,~ 4.59 3.53 2,23 2,14 1,50 1.47 5.89 1.82 0,64 9629,42 9722,01 9817.51 ~?11.34 10~05,51 94.7 6501,98 ~2.6 8528.89 ~5.5 8556.31 ~.8 8581.95 94.2 66O5.53 2520,04 73,00 335,86 2314,63 2608,34 73,20 336.01 2395,53 2699,~ 73.43 336.47 2479,25 2789,5? 74,85 336,35 2561,96 2860,37 76,15 334,65 2644,92 -1014,0~ 2527,02 336,34 -1050,I8 2615,61 336.33 -1087.03 2707,09 336,32 -1123.15 2.797,34 336,33 -1160,95 2868,50 336.30 0.61 0.26 0.52 1,52 2.23 10098,33 10191,67 10287,64 10350.02 10360,59 92,8 8626,84 93,3 8647,17 96.0 8667.21 62.4 8678,02 3O.6 8682.01 ~70.33 77,31 336..06 2727.03 3061.07 77.52 334.~ 2809.94 31~4,50 78,38 33~,31 2895,10 3215,61 81,66 334,34 2~50.69 3245,71 83,35 333.41 2977.91 -1198,62 2978,82 336,27 -1236,37 3069.91 336,25 -1275,81 3163,7~ 336,22 -1301,94 322~.16 336.19 -1315,28 ~5,44 336.17 1.94 1.14 0.95 5.48 6.30 10412,79 10507.48 10537.21 I0570...~ 10600,64 32,2 8685.21 94,7 8689.15 29.7 8689,20 33,5 8689.3O 30,0 8689,42 3277.53 85,24 334,41 3371,51 89.98 :333,79 3091,76 3401,01 89.85 333,18 3118,36 3434.21 89.80 333,45 3148,27 3463,94 8%77 333,57 317~,08 -1329.37 3287.45 336,I5 -1370.69 .3381.98 336,09 -1383,96 3411,6~ 336.07 -1398,99 3445.11 336.04 -1412,35 3475,04 33~.02 6,63 2,(Y9 0.82 0.40 10689,83 10748,40 10879,70 10943.00 11037..~ 89,2 58.6 8691,03 131,3 8695,28 63,3 8698,40 94,6 8704.67 3552,45 89,42 333,47 3254,91 3610,56 ~.~ 333.63 3307.34 3740,93 87,63 334.40 34~,3O 3803.74 86,7I 333.7~ 3482.16 3897,43 85,69 33:3,52 3566,73 -1452,12 3564.14 335.96 -1478.21 3622,65 335.92 -1535,70 3753,81 335,85 -1563,34 3817.00 335.82 -1.~5,26 3911.32 335,77 0,41 1,32 0.98 1,78 1.10 11221.~ 11313,80 11406,60 11436,10 91.4 8710,59 92,9 8714,37 91,9 8715,26 92.8 8713.86 29.5 8713.31 3987,98 86.89 333.98 3648,53 4080,13 .98,44 333.41 3731,74 4171.53 90,43 336,02 ~14,82 4263.98 91.30 335,43 .3899,41 4293,31 ~,82 333,68 3~6.04 -1645,60 4002.47 335.72 -1686,73 4095.24 335.68 -1725,98 4187,11 3~,66 -1764,13 4279.90 335..E~ -1776.80 4309,39 335,65 1.41 1.78 3,57 1.13 6.15 ARCO ALASKA, INC~ P~ O~ BOX i ANCHORAGE, ALASKA DAl"r..i: · 4--t 9-.89 REFE:RENCE' ARC() DIRECTIONAl_ DATA i8-.i8 ii.--2S-88 D]:RECTIONAL. SURYEY ..~' C H '-" A N A F'i..EASE SIGN AND RE'¥1JRN 'I"HE A'!"'J'ACIqlED .,uF'Y A,",~ RECEIPT OF DATA REC:EIVED BY I-t A V E A N :!: C ['." D A Y ! SAL..L.Y HOFF:'iii:CKER ATO- t ~29 ~~ APPROVED ..~ .... Alas TRANS:~ 89 tv~'? . ka Oil & Gas Cons, CommissJo~ Anchorage D I $ T R I B U l' I 0 N CENTRAL F':[LE~, CFIEVRON D & M JI. '" · " ~ " 'i · '1 · ,,.[:.XTE:.N~ ION E. XF L. OF~AI'ION · ,. EXXON MARATHON MOBIL PHIl_LIPS F'B WEI...L F'IL.E$ (2 r ..... , · .,UI.. :[ [..",~" ) R & D BPX $1'ATE OF' ALASKA I"EXACO ARCO ALASKA, INC, F',O, BOX t00360 ANCHORAGE, ALASKA DATE' t-6-89 RE. FERE. NCE' ARCO MAGNETIC TAF'[:S W/t...ISTING t8-t8 t.-S-89 OH' RLL/GR/EWR/CNPS/F'(HOB/RATE/ROP ,JOB~881126 Pt..EASE SIGN AND REEI'URN THE ATTACHED COPY AS RECEIF'T OF DAI'A, RECEIVED BY ............................................ ~ALLY HOFFECKER AT0-'i529 TRANe' ~89~ APPROVED C~ ..... DISTRIBUTION NL BAR CENTRAL FILE£ (CH) CHEVRON D & M TAMMAS BROWN (OH) EXXON MARATHON MOBIL F'HILLIF'5' F'B WEL. L F'IL.E$ R & D · '"~ SAF'C .$ ,~"l'Al'E OF ALASKA TEXACO ARCO ALASKA, INC, F',O· BOX JO0:~60 ANCHORAGE, ALASKA 995i0 DATE: t'-6-89 REF E:.RE. NC, E ' AF;~C(] OPEN HC~L.i:: FINAL,S' 3-20/88 S'F'D/CNP-GAMMA & CAL..IPER EWR-GAMMA RUNS i-8, 2"^'"'". .~.:> RUNS J..-8, 2"&5" I":'LEASE SIGN AND REI"LIRN THE ATTACHED COPY AS RECEIF'T OF DATA, b A R NL. BAlk RECEIVED BY .................................................. HAVE A NICE DAY! SALLY HOFFECKER AT0-'t529 A F: F:' R 0 V E: D .... ..~. ..... D I $ 'l" R ]: B U "F I 0 N Naska Oil & ~as Cons. Commlssk: Anchorage CENTRAL FILES CHEVRON D&M EXTEN£ION EXPLORATION EXXON MARATHON MOBIL I~ I'lJ.l..L..[ ' ,. F'B WELt.. F]:LE:,S' Iq: & D SAPC STATE L1F ALASKA TE:XACO ""'"" STATE OF ALASKA A b-,..,KA OIL AND GAS CONSERVATION COM M b,,.,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown ~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate ~ Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 407' FNL, 206' FWL, Sec. 19, T11N, R15E, UN At top of productive interval 1980' FSL, 1100' FEL, Sec. 13, T11N, R14E, UN (approx.) At effective depth 1715' FNL, 1592' FEL, Sec. 13, T11N, R14E, UM (approx.) At total depth 1653' FNL, 1622' FEL, Sec. 13, T11N, R14E, UN (approx.) Development -X- Exploratory ~ Stratigraphic ~ Service ~ RKB 36' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-18 9. Permit number' 88-113 10. APl number 50-- 029-21872 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11550 'MD feet 8706 'TVD feet Plugs (measured) None Effective depth: measured true vertical 11481 'MD feet 8707 'TVD feet Junk (measured) None Casing Length Structural Conductor 80 ' Surface 3435 ' Intermediate 8902 ' Production 1712' Liner 1281 ' Perforation depth: measured None true vertical None Size 20" 13-3/8" 9-5/8" 7" 4-1/2" Cemented Measured depth True vertical depth 2150~J Poleset 1 lO'MD 2000 sx CS Ill & 3473 'MD 600 sx Class G - Top job w/200 sx CS II 750 sx Class G 8935 'MD 500 sx C1 ass G 8605'-10317'MD Slotted liner 10244 '-11525 'MD 110'TVD 3473'TVD 8258 'TVD 8090 '-8667 'TVD 8679 ' -8706 'TVD Tubing (size, grade, and measured depth) 3-1/2", L-80, tbg w/tail (~ 10019' .... Packers and SSSV (type and measured depth) Camco 'TROP-1A-SSA' 5SSV ~ 222~': TIW 's~, pkr ~ 9~ (np~) .. 13. A~achments Description summary of proposal ~ Detailed operations program Wel 1 History, 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver 15. Oil ~ Date approved Service Status of well classification as: Gas__ Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :~gn~i:~~ Title Regional Drilli ng Engineer FOR COMMISSION USE ONLY Approved Copy Returned //- ,~- ~'~¢.nmmissioner so representative may witness Plug integrity i BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH JApprova, No. ¢ ¢ ~¢),._~ Date Form 10-403 Rev 06/15/88 040/SA4 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Reporr' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish or borougl~ Field J Lease or Unit Auth. or W.O. no. ITitle State R-1R IWell no. Operator AI~ C:.Ct Spudded or W.O. begun IDate I RPrlD Date and depth as of 8:00 a.m. 10/27/88 ( TD: 190'( SUPV:DBJ 10/28/88 ( TD: 1395' ( 1: SUPV:DBJ 10/29/88 ( TD: 3365'( SUPV:DBJ 10/30/88 ( TD: 3500'( SUPV:DBJ 10/31/88 ( TD: 3500'( SUPV:DBJ Complete record for each day reposed DOYON 9 ) 90) APT~ 50-~99-21872 10127188 I ARCO W.I. 21,~n IHour Prior status if a W.O. :) 05) ) 70) ) 35) ) o) The above is correct Signat~,~ For form ~reparatton~and dis't~tlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. DRLG 20"~ 110' MW: 8.7 VIS: 27 NU DIVERTER FLOWLINES, HAD TO FABRICATE EXT. ON BELL NIPPLE. PU BA, SS,BS, 2 MONEL DC. FUNCTION TEST HYDRIL & VALVES ON DIVERTER SPOOL. PU & MU KELLY & SUBS, FILL HOLE & STACK, CHECK FOR LEAKS- LEAK AT HUB CLAMP. BLOW DN KELLY POH LD ONE DC. ND FLOWLINES. PU DIVERTER SPOOL & BN. FILL HOLE CHECK FOR LEAKS -OK. FINISH NU. RIH W/ BIT AND 2 MDC. PU KELLY AND SPUD AT 0400 10/27/88. DRLG TO 190' CHANGE BLADES OH 2 STAB. DAILY:S294,091 CUM:$294,091 ETD:S294,091 EFC:$2,914,000 POH 20"@ 110' MW: 9.3 VIS:245 DRLG F/ 190 TO 527. CIRC, DROP SURVEY, POH. CHAI~GE BIT, RIH, PU KELLY TAG BOT 7' FILL, LD i JT, REAM 40' TO BOTTOM. DRLG FROM 527 - 897. DROP SURVEY. POH CHANGE BIT, RIH. DRLG F/ 897 - 1395. CIRC. PROBLEMS W/ SUPER SUCKER AND CUTTINGS BOX (FREEZING UP), DROP SURVEY. POH. DAILY:S52,410 CUM:$346,501 ETD:S346,501 EFC:$2,914,000 DRLG 20"@ 110' MW: 9.5 VIS:147 POH, RETRIEVE SURVEY. RIH. DRLG F/ 1395 TO 2104, CIRC. RUN SURVEY. DRLG FR/ 2104-2508 CIRC. W.L. SURVEY, POH. CHANGE BIT. RIH. WASH 40' TO BOKTTOM. DRLG F/2508 - 3006. CIRC. W.L. SURVEY, DRLG F/ 3006-3365. DAILY:S53,284 CUM:$399,785 ETD:S399,785 EFC:$2,914,000 PREFORM TOP JOB 13-3/8"~ 3473' MW: 9.6 VIS: 60 DRLG F/ 3365 TO 3500. CIRC. ST. CBU. DROP SURVEY. POH. RUN 85 JTS 13-3/8" 72# L-80 AND 2 JTS 13-3/8" 68# K-55 TO 3473 FS, 3383 FC. RU BJ HEAD. RECIP CSG CEMENT CSG W/ 2000 SX CS III, & 600 SX CLASS G FULL RETURNS, BUMP PLUG TO 2500 PSI, FLOATS HELD CIP @ 0130 10/30/88. NOK CMT TO SURFACE.. RD BJ. ND DIVERTER LINES AND FLOWLINES PU DIVERTER SPOOL. RUN 1" TBG DOWN 20" X 13 3/8" ANNULUS TO 95' RKB. PREFORM TOP JOB. DAILY:S213,552 CUM:$613,337 ETD:S613,337 EFC:$2,914,000 PU BHA 13-3/8"~ 3473' MW: 8.3 VIS: 27 FIN 200 SX CS II @ 15 PPG, TOP JOB. TOP JOB ClP 0630 10/30/88. SET CSG SLIPS W/ 100,000~. MAKE ROUGH CUT, LD CUT JT. LD BELL NIPPLE, SET BACK AND SECURE DIVERTER ASSY. MAKE DRESS CUT, INSTALL HEAD, TEST TO 500 PSI, OK. BURN 2ND HOT HEAD TEST WELD TO 1500 PSI. OK. NU DRLG SPOOL AND BOP STACK, TEST TO 5000 PSI, ANNULAR TO 3000 PSI. AOGCC WITNESS WAIVED BY :~%WIiINS, INSTALL WE~. 3?C2ill~.CL=A/~LOOR SET MOUSEHOLE. RU GEOLOGRAPH LINE. PU BHA DAILY:S165,978 CUM:$779,315 ETD:S775,315 EFC:$2,918,000 AR3B-459-1 -D JNumber all dally well history forms consecutively es they are prepared for each well. jPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If lasting, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when tilled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting el oil strin§ until completion. County or Parish Istate District J~/:~CO J~T.~AS~J~ INC. NORTH SLOPE AK Lease or Unit JWell no, Field PRUDHOE BAY DS 18-1~8 Date and depth Complet ...... d f~)roe~)%da~)while drilling ..... k .... in prog .... as of 8:00 a.m. 11/01/88 ( TD: 5104'( SUPV:DBJ 11/02/88 ( TD: 5976'( SUPV:DBJ 11/03/88 ( TD: 6908'( SUPV:DBJ 11/04/88 ( TD: 7348'( SUPV:DBJ 11/05/88 ( TD: 7831'( SUPV:JE 11/06/88 ( TD: 8366'( SUPV:JE 6) 604) 7) 872) The above is correct F' Sign~,~ For form preparation end distribution see Procedurss Manual Section tO, Drilling. Pages 86 and 87 8) 932) 9) 440) o) 483) 1) 535) POH 13-3/8"8 3473' FIN TIH W/ BHA, FUNCTJION TEST MWD. RIH, KELLY, TAG CMT @ 3374 SET KELLY BACK. RU CIRC., TEST CSG TO 2000 PSI 30 MIN. DRLG FS @ 3473, RAT HOLE AND NEW FORMATION TO PREFORM LOT = 13.7 #/GAL. DRLG F/ 3515 - FLOWLINES. DRLG F/ 4132 - 5104. CBU. POH DAILY:S47,044 CUM:$826,359 ETD:S826, MW: 9.3 VIS: 36 LD 3 JTS DP. PU CIRC HEAD, BREAK CMT FC @ 3383, CMT 3515' POH INTO CSG 4132. REPAIR FOR BHA CHANGE. 359 EFC:$2,914,000 DRLG 13-3/8"@ 3473' MW: 9.4 VIS: 37 POOH. PU DYNA DRILL AND RIH. DYNA DRLD F/ 5104' TO 5880'. SURVEY. POOH. CHNG BITS, MWD. RIH AND DYNA DRLD TO 5976'. DAILY:S53,249 CUM:$879,608 ETD:S879,608 EFC:$2,914,000 DRILLING 13-3/8"@ 3473' MW: 9.5 VIS: 37 DRLG F/ 5976 - 6259. MWD, DROP SURVEY, PUMP DRY & SET BACK KELLY. POH. CHANGE OUT BIT, ADD LEAD COLLAR, STAB AND ORIENT THE SAME. RIH. REAM/WASH F/ 6204-6259. DRILL AND SLIDE F/ 6259-6908. DAILY:S59,458 CUM:$939,066 ETD:S939,066 EFC:$2,914,000 L/D 7 3/4" DYNADRILL 13-3/8"@ 3473' MW:10.2 VIS: 43 DRLG F/ 6908-7065. ORIENT AND SLIDE F/ 7065 -7106. GAS BREAKING OUT OVER BELL NIPPLE AND ROTARY TABLE. SIW. PRESSURE = 0 PSI. WT UP TO 9.8--SAME. WT UP TO 10. MUD/GAS ONLY BREAKING OVER BELL NIPPLE INTERMITTENLY. CIRC THRU CHOKE TO WT UP. SLIDE F/ 7106-7129. DRLG F/ 7129-7254. SLIDE F~ 7254-7348. MUD/GAS STILL BREAKING OCCASSIONALLY OVER BELL NIPPLE. INCR. WT TO 10.2. DROP SURVEY PUMP PILL POH. LD MWD, MONEL LEAD COLLAR, STAB AND DD. PU MWD W/ GR/RES. DAILY:S71,547 CUM:$1,010,613 ETD:S1,010,613 EFC:$2,914,000 RIH W/ BIT 13-3/8"@ 3473' MW:10.2 VIS: 55 PU DYNA DRILL AND MWD W/ GR & RESISTIVITY SENSORS. RIH. REAM AND LOG W/ MWD F/ 7222 - 7348'. DRLD F/ 7348' TO 7831' SURVEY. POOH. LD DYNA DRILL, BIT. PU NEW BHA AND RIH W/ SAME. DAILY:S54,398 CUM:$1,065,011 ETD:S1,065,011 EFC:$2,914,000 DRLG 13-3/8"@ 3473' MW:10.2 VIS: 45 RIH AND REAM F/ 7730 TO 7831'. DRLD TO 7892' LOST 700 PSI. POOH WET LOOKING FOR A WASHOUT. FOUND WASHOUT AT 30 STDS OUT. RIH. WASH/REAM. DRLD TO 8366'. DAILY:$44,784 CUM:$1,109,795 ETD:S1,109,795 EFC:$2,914,000 AR3B-459-2-B Number all daily well history torres conseculively as they are prepared for each well, JPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores*. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "ll~lerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. County or Parish Stat~l~K District ~CO ALASKA INC. NORTH SLOPE Field Lease or Unit iWell no. PRUDHOE BAY I DS 18-18 I I Date and depth Complet ...... d ~o6~]~ d~y while drilling ..... k .... in prog .... as of 8:00 a.m. 11/07/88 ( 1 TD: 8537'( SUPV: JE 11/08/88 ( 1 TD: 8672'( SUPV:JE 11/09/88 ( 1 TD: 8945'( SUPV:JE 11/10/88 ( 1 TD: 8945'( SUPV:DBJ 11/11/88 ( TD: 8945'( SUPV:DBJ 11/12/88 ( TD: 8945'( SUPV:DBJ ~) [71) 3) [35) ~) 273) 5) 0) 6) 0) 7) 0) RIH 13-3/8"@ 3473' MW:10.2 VIS: 42 DRLD TO 8520' SURVEY. POOH. CHNG BHA AND RIH. REAM F/ 8403 TO 8520'. DRLD TO 8537'. MWD NOT WORKING. CBU. POOH. CHNG OUT MWD AND RIH. DAILY:S61,872 CUM:$1,171,667 ETD:S1,171,667 EFC:$2,914,000 DRLG 13-3/8"@ 3473' MW:10.2 VIS: 42 RIH AND LOG W/ MWD F/ 8500' TO 8537'. DRLD F/ 8537' TO 8655' POOH. CHNG BHA. WASH AND REAM F/ 8599' TO 8655'. DRLD F/ 8655' TO 8672'. DAILY:S49,103 CUM:$1,220,770 ETD:S1,220,770 EFC:$2,914,000 DROP SURVEY 13-3/8"@ 3473' MW:10.4 VIS: 46 DRILL F/ 8672-8756. CIRC AND DROP SS SURVEY. PUMP DRY JOB & POH. RET. SURVEY. CHANGE OUT BHA. LD NON MAG STAB. CHANGE BLADE ON NB STAB. TEST MWD-OK. RIH. FILL DP WHILE RIH. BREAK CIRC. DRLG F/8756-8783. PU TO CHECK FLOW. SIW. CIRC GAS THRU CHOKE. DRLG F/ 8783-8896. CHECK FOR FLUID LOSS. SURVEY. DRLG F/ 8896-8945. CIRC AND FIN WT UP TO 10.4 PPG. SHORT TRIP TO 7491. NO TIGHT SPOTS. 15 BBLS TO FILL HOLE. CBU. DAILY:S49,613 CUM:$1,270,383 ETD:S1,270,383 EFC:$2,914,000 LD LANDING JT 9-5/8"@ 8935' MW:10.5 VIS: 49 DROP SUR. POH. PULL WEAR BUSHING. CHANGE RAMS TO 9 5/8, TEST BONNET TO 2500 RU GBR CSG TOOLS. RUN 209 JTS 9-5/8" 47# L-80 BTC AND BTC-MOD TO 8935. LAND CSG W/ 350,000#. RU BJ CMT HEAD. WELLHEAD NOT RIGGED UP TO CIRC W/ MANDREL HNG LANDED. PULL VR PLUG ON CSG HEAD. LOOP AROUND AND RIG UP HEAD. TEST TO 5000-OK CMT W/ 80 BBLS MCS-4 @ 10.5 PPG W/ 750 SX CLASS G. DID NOT BUMP PLUG, FLOATS HELD CIP @ 0530 11/10/88. RD BJ CMT HEAD. DAILY:S53,834 CUM:$1,324,217 ETD:S1,324,217 EFC:$2,914,000 RIH W/ 8" DC 9-5/8"@ 8935' MW:10.5 VIS: 48 FIN LD LANDING JT. INSTALL NEW PACKOFF. TEST TO 5000# OK. CHANGE TOP RAMS. ND BOP, INSTALL TBG HEAD. TEST TO 5000#. PUT DOYON DSA BACK ON. NU BOP AND TEST TO 5000~, ANNULAR TO 3000#. NU BELL NIPPLE. RIH W/ 8" DC. DAILY:S344,316 CUM:$1,668,533 ETD:S1,668,533 EFC:$2,914,000 DRLG CMT 9-5/8"@ 8935' MW: 0.0 VIS: CDL. POOH. CHNG BHA. RIH. TAG CMT AT 8803'. TEST CSG TO 3000 PSI. DRLD PLUGS AND CMT TO FC AT 8842'. TEST CSG TO 3000 PSI. DRLG FC & CMT. DAILY:S180,098 CUM:$1,848,631 ETD:S1,848,631 EFC:$2,914,000 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared or each well. IPage no ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntnrim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled Out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strinsi until completion. iCounty or Parish District ARCO ALASKA INC, I NORTH S'f,OPE State AK I Field JLease or Unit ?RODHOE IDS 18-18 Complete record for each da)' while drilling or workover in progress DOYON 9 Date and deptl~ as of 8:00 a.m. 11/13/88 ( TD: 9463'( SUPV:DBJ 11/14/88 ( TD: 9812'( SUPV:DBJ 11/15/88 ( TD:10280' ( SUPV:DBJ 11/16/88 ( TD:10502'( SUPV:DBJ 11/17/88 ( TD:10675' ( SUPV:DBJ 11/18/88 ( TD:10800'( SUPV:DBJ 11/19/88 ( TD:l1036' ( SUPV:DBJ 11/20/88 ( TD:11330' ( SUPV:JEJE 3) 518) 349) 0) 468) 1) 222) 2) 173) 3) 125) 4) 236) 5) 294) POOH 9-5/8"@ 8935' MW: 9.1VIS:140 FIN DRLG CMT, SHOE AND 10' NEW HOLE. CIRC AND COND MUD. FORM LEAK OFF TO 12.0 EMW. DISPLACE WATER BASE MUD W/ OIL BASE MUD. CLEAN SHAKER. DRLG AND SURVEY F/ 8955' TO 9463'. CIRC AND BUILD SLUG. POOH. DAILY:S64,624 CUM:$1,913,255 ETD:S1,913,255 EFC:$2,914,000 POOH 9-5/8"@ 8935' MW: 9.2 VIS:105 CHNG BHA. TEST MWD. RIH TO 7800'. BREAK CIRC. RIH TO 9296' REAM HOLE F/ 9296' TO 9463'. DRLD F/ 9463' TO 9812'. CIRC. PUMP SLUG. POOH. DAILY:S61,138 CUM:$1,974,393 ETD:S1,974,393 EFC:$2,914,000 POH 9-5/8"@ 8935' MW: 9.5 VIS:102 POH. CHANGE BIT. CAL AND TEST MWD AND BARIOD. TIH. DRLG F/ 9812 TO 10280. SLUG PIPE, POH. DAILY:S59,639 CUM:$2,034,032 ETD:S2,034,032 EFC:$2,914,000 CALIBRATE MWD 9-5/8"@ 8935' MW: 9.4 VIS: 82 FIN POH. CHANGE BIT. TEST ANADRILL MWD. RIH. BREAK CIRC. REAM FROM 10210-10280 DRLG AND SURVEY FROM 10280-10502. PUMP SLUG. POH FOR BHA CHANGE. DAILY:S54,979 CUM:$2,089,011 ETD:S2,089,011 EFC:$2,914,000 DRLG AT 10675 9-5/8"@ 8935' MW: 9.4 VIS: 68 TEST MWD. RIH. CUT DRLG LINE. RIH. BREAK CIRC AND REAM F/ 10425 TO 10502. DRLG F/ 10502-10675. DAILY:S61,069 CUM:$2,150,080 ETD:S2,150,080 EFC:$2,914,000 DRLG 9-5/8"@ 8935' MW: 9.1 VIS: 53 DRLD F/ 10675' TO 10690'. SURVEY. PUMP PILL. POOH. CHNG BHA. RIH. REAM 62' TO BTM. DRLD F/ 10690' TO 10800'. DAILY:S59,529 CUM:$2,209,609 ETD:S2,209,609 EFC:$2,914,000 RIH 9-5/8"@ 8935' MW: 9.3 VIS: 55 DRLD F/ 10800' TO 11036'. POOH. CHNG BHA. RIH. DAILY:S60,145 CUM:$2,269,754 ETD:S2,269,754 EFC:$2,914,000 RIH 9-5/8"@ 8935' MW: 9.0 VIS: 52 RIH. REAM F/ 10996' TO 11036'. DRLD F/ 11036' TO 11330'. CIRC FOR SAMPLES. POOH. CHNG BHA. RIH. DAILY:S62,906 CUM:$2,332,660 ETD:S2,332,660 EFC:$2,914,000 JWell no. For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil String is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish JStafeAK ARCO ALASKA INC. I NORTH SLOPE JLease or Unit Field I DS 18-18 PRUDHOE BAY I Complete record for each day while drilling or workover in progress DOYON 9 Date and depth as of 8:00 a.m. 11/21/88 ( TD:11550' ( SUPV: JE 11/22/88 ( TD:11550' ( SUPV: JE 11/23/88 ( TD:11550' ( SUPV: JE 11/24/88 ( TD:11550 PB: SUPV:DJ 11/25/88 ( TD:11550 PB: SUPV:DJ 11/26/88 ( TD:11550 PB: SUPV:DJ 11/27/88 ( TD:11550 PB: SUPV:DJ 26) 220) POOH 9-5/8"@ 8935' MW: 9.1 VIS: 54 FIN RIH. REAM F/ 11217' TO 11330'. DRLD F/ 11330' TO 11550'. SURVEY. POOH. LOGGED W/ BARIOD MWD F/ 9976' TO 10301'. POOH. DAILY:$55,881 CUM:$2,388,541 ETD:S2,388,541 EFC:$2,914,000 ) o) WO PLUG 9-5/8"@ 8935' MW: 9.4 VIS: 62 FIN POOH. LD BAROID MWD. CHNG BHA. RIH. REAM F/ 11500' TO 11550'. CBU. SPOT 75 BBL OF 11.3 PPG MUD. POOH TO 10505'. CBU. WASH AND REAM F/ 10474' TO 10518'. RU AND PUMP 40 BBLS OF "FORM-A-PLUG". WO PLUG. DAILY:S70,929 CUM:$2,459,470 ETD:S2,459,470 EFC:$2,914,000 RIH W/ 7" CSG 7"@10317' MW: 9.3 VIS: 57 RIH. TAG PLUG AT 9950'. REAM F/ 9950' TO 10317'.. CIRC HOLE CLEAN. POOH. LD HWDP. RU TO RUN 7" LNR. RIH W/ 7" LNR. DAILY:$88,797 CUM:$2,548,267 ETD:S2,548,267 EFC:$2,914,000 IWell no. TIH 7"@10317' MW: 9.40BM RIH W/ LINER ON DP F/ 8605'-10317'. BREAK CIRC AT SHOE. FIN RIH W, RU AND CMT W/ 500 SX CLASS G CMT. CIP AT 15:30 HRS, 11/23/88. POOH. RIH W/ DRESS OFF TOOLS. DAILY:S39,500 CUM:$2,587,767 ETD:S2,587,767 EFC:$2,914,000 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 DRLG CMT IN LNR 7"@10317' MW: 9.40BM LDDP. RIH TO 8096'. WASH AND REAM F/ 8096' TO 8207' (TAG CMT AT 8207'). DRLG MHD TO FIRM CMT F/ 8207' TO 8605' CBU. SLUG PIPE. POOH. LD BHA. CHNG BHA. RIH TO 8605'. TAG LINER TOP. DRL OUT TOP OF LNR AND CMT TO 8680'. DAILY:S123,755 CUM:$2,711,522 ETD:S2,711,522 EFC:$2,914,000 RUN CBT ON DP 7"@10317' MW: 9.40BM DRLD CMT STRINGER IN LNR TO 9926'. DRLD FIRM CMT TO 10223' (LANDING COLLAR) TEST CSG TO 3000 PSI. OK. DRLD LANDING COLLAR. DRLD HARD CMT TO 10268'. TEST LNR LAP AND LNR TO 3000 PSI. CBU. POOH. RU SOS AND RUN CBT TO 8439'. MU SIDE DOOR SUB AND RU CIRC HEAD AND CIRC FOR 10 MIN. PUMP WIRE DOWN AND LATCH UP. RIH TO 30' ABOVE FC AND LOG REPEAT SECTION. DAILY:S39,739 CUM:$2,751,261 ETD:S2,751,261 EFC:$2,914,000 SHORT TRIP 7"@10317' MW: 9.40BM FIN TIH W/ DP CONVEYED LOGS. RUN CBT. LOG F/ 10212' TO 8605'. POOH W/ WL. RU SOS. RIH. DRLD FC, CMT FS TO 10317' WASH AND REAM 8-1/2" HOLE TO 11550'. CBU. SHORT TRIP INTO 7" LNR. DAILY:$79~700 CUM:$2,830,961 ETD:S2,830,961 EFC:$2,914,000 AR3B~459-2-B INumber all da,ly well history forms consecutively IPage no. as they are prepared for each well. l ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name In describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field ARCO ALASKA INC. PRUDHOE BAY County or ~H SLOPE IStateaK L ...... U~ 18-18 IWell no. Date and deptl3 as of 8:00 a.m. 11/28/88 ( TD:11550 PB: SUPV:DJ 11/29/88 ( TD:l1550 PB: SUPV:DJ 11/30/88 ( TD:l1550 PB: SUPV:DJ 12/01/88 ( TD:l1550 PB: SUPV:JE 12/02/88 ( TD:11550 PB: SUPV:JE Complet ...... d f[~)~6~da.~ while drilling ..... k ....in prog .... RIH W/ LNR ON DP 7"@10317' MW: 9.40BM SHORT TRIP. WASH AND REAM F/ 10448' TO 10586'. RIH TO 11550'. CBU. POOH. LD EXCESS DP. RU AND RUN 32 JTS OF 4-1/2" 13.5#, L80 FL4S R-3 LINER. TIH W/ LNR ON DP. DAILY:S47,198 CUM:$2,878,159 ETD:S2,878,159 EFC:$2,914,000 RIH 7"@10317' MW: 9.40BM TIH W/ 4.5 SLOTTED LINER ON DP. LINER TOOK WT AT 10450,10500,10550, AND BOTTOMED OUT AT 10645. CIRC AND ATTEMPT TO WORK THROUGH, COULD NOT. PULL INTO 7" LINER, PUMP SLUG, POH. CIRC AND MIX 2ND SLUG. FIN POH. LD 4.5" SLOTTED LINER, RU WASH STRING. MU BHA. RIH TO CHASE SLIP SEGMENTS AND CLEAN OUT OPEN HOLE FOR LINER. DAILY:S43,500 CUM:$2,921,659 ETD:S2,921,659 EFC:$2,914,000 WASH AND REAM LEDGES 7"@10317' MW: 9.40BM RIH TO 8504. POH. LD 99 JTS. RIH TO 8577 WASH AND REAM FROM ABOVE TOL LOOKING FOR JUNK. HIT JUNK AT 9560 AND 9600. PULL UP TO 9530. WASH AND REAM THROUGH SAME SPOT, APPEAR TO HAVE PUSHED JUNK THRU SHOE AT 10317. HIT LEDGES AT 10465 THRU 10680'. WORK THRU TROUBLE SPOTS SEVERAL TIMES. CONTINUE TO WASH AND REAM TO 11550. HOLE PROBLEMS ENDED BELOW 10680. CBU SLUG PIPE, REAM BACK INTO 7" CASING. TIGHT AT 11160, 11073, 10630. WORK THRU EACH SPOT. TIH STACK OUT AT 10450. ATTEMPT TO WORK THRU. PU KELLY WASH AND REAM. DAILY:S50,472 CUM:$2,972,131 ETD:S2,972,131 EFC:$2,914,000 POH W/ 3.5 DP 7"@10317' MW: 9.3 OBM RIH TO 11340. PU KELLY REAM FR/11340-11550. CIRC AND COND MUD. POH. RU SLOTTED LINER. RUN 4-1/2" LINER W/ 2-1/16 WASH PIPE AND TIW MECHANICAL SET PACKER. ATTEMPT TO GO THROUGH THE 7" LINER LAP. TIW PACKER SLIPS CAUGHT AT 7" HANGER CARRYING THREADS 6' INSIDE LAP. BROKE CIRC, PACKER NOT SET, WORK LOOSE. PUMP DRY JOB. POH TO CHECK PACKER. DAILY:S45,178 CUM:$3,017,309 ETD:S3,017,309 EFCi$2,914,000 PU 6" TAPER MILL 7"@10317' MW: 9.30BM POOH W/ 4-1/2" SLOTTED LNR AND TIW TYPE SS 7" PKR. INSPECT PKR & LD PKR. LDDP, LNR. TEST BOPE TO 3000 PSI. PU 6" BIT, NEW BHA AND RIH TO 8605'. FILL DP AT 5000'. PU KELLY AND WASH AND ROTATE THROUGH LINER LAP. RIH SLOW TO 11550'. CIRC AND COND MUD. POOH. LD STAB AND BIT. DAILY:S51,648 CUM:$3,068,957 ETD:S3,068,957 EFC:$2,914,000 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively lPage no. as they are prepared for each well. l ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilting or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lltterll~" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District County or Parish IStat%K ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit PRUDHOE BAY DS 18-18 Complete record for each day while drilling or workover in progress DOYON 9 Date and depth as of 8:00 a.m. 12/03/88 ( TD:11550 PB: SUPV:JE 12/04/88 ( TD:11550 PB: SUPV:JE 12/05/88 ( TD:11550 PB: SUPV:JE 12/06/88 ( TD:l1550 PB: SUPV:JE 12/07/88 ( TD:11550 SUPV:JE ,9) =0) Well no. 2) The above is correct Signature ~ " , ~... For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 POH 7"@10317' MW: 9.40BM PU TAPERED MILL, RIH, INSTALL WATERMELON MILL 1720' ABOVE TAPERED MILL. MILL THRU LC AT 10223 AND LINER LAP AT 8605. CIRC BU. POH. LD MILLS. PU BIT. RIH TO 10448. WASH AND REAM TO 10544. STAND BACK KELLY AND RIH. CIRC AND COND MUD. ST TO 7" SHOE. NO TAGS. RIH CBU.PUMP DRY JOB. POH TO RUN 4-1/2" LINER. DAILY:S50,426 CUM:$3,119,383 ETD:S3,119,383 EFC:$2,914,000 RIH W/ TYPE SS PACKER 7"@10317' MW: 9.40BM FIN POH. RU GBR TO RUN 4.5" LINER. RIH W/ 29 JTS OF 4-1/2" SLOTTED LINER, 3 JTS BLANK PIPE, 2-1/16" WASH PIPE AND BAKER TYPE HMC 5" X 7" HANGER ASSY. RIH. SET 4.5" LINER SHOE AT 11525 W/ HANGER AT 10244. SET HANGER W/ 2200 PSI. CIRC AND PUMP PILL. POH TO 9645. LD PUP JTS AND CIRC HEAD. POH W/ DP. LD BAKER HANGER SETTING ASSY AND WASH PIPE. CLEAN FLOOR. PU BAKER 5" SEAL ASSY AND 6IW TYPE SS PACKER. RIH ON DP. DAILY:S48,647 CUM:$3,168,030 ETD:S3,168,030 EFC:$2,914,000 POE LD DP 7"@10317' MW: 9.70BM RIH W/ TYPE SS PACKER AND BAKER SEAL ASSY. UNABLE TO GO BELOW 10012'. WHILE WORKING AND TRYING TO GO DOWN, BOTTOM SLIPS SET ON PACKER. SET PACKER AT 9984' TESTED ANNULUS TO 3000 PSI. OK. RELEASED FR/ PACKER, CIRC AND PUMP PILL. POH. LD SETTING TOOL AND PU DUMMY OVERSHOT. RIH, SLIGHT TAG AT LINER LAP. RU CIRC HEAD. TAGGED POLISHED RISER AT 9972'. WASHED DOWN 9'. PU AND SHUT HYDRIL. REV CIRC AND WASHED DOWN OVER RISER. PRESS UP ANNULUS TO 800 PSI OK. PU TO CIRC. CIRC AND COND MUD. PUMP DRY JOB AND POH. DAILY:S101,174 CUM:$3,269,204 ETD:S3,269,204 EFC:$2,914,000 RU TO TEST ANN 7"@10317' MW: 9.70BM FIN LDDP. RU AND RUN 243 JTS 3-1/2" TBG, 2 GLM, X-NIPPLE & TIW OVERSHOT. PU CAMCO 3-1/2" SSSV & SS CONTROL LINES. TEST SAME TO 5000 PSI. OK. SPACE OUT & PU TBG HGR. DAMAGED TBG HGR. WO NEW 3-1/2" TBG HGR. MU NEW HGR & CONNECT CONTROL LINES AND TEST SAME TO 5000 PSI. OK. LAND TBG HGR. RILDS. DAILY:S146,746 CUM:$3,415,950 ETD:S3,415,950 EFC:$2,914,000 CAMCO SLICKLINE RIH W/ DU 7"@10317' MW: 0.0 RUN IN LOCKDOWN SCREWS ON 3-1/2" TBG HANGER(FMC GEN 4) TEST ANNULUS TO 3000 PSI FOR 30 MIN. OK. LD LANDING JT AND GBR TONGS. INSTALL BPV. CHANGE RAMS. ND BOPE NU FMC GEN 4 TREE. TEST TREE TO 5000 PSI-OK. RU CAMCO WIRELINE PULL DUMMY IN GLM @ 8085'. INSTALL ORFICE VALVE. DISPLACE OBM TO DIESEL. RIH W/ EQUALIZING DUMMY. DAILY:S89,216 CUM:~3,505r166 ETD:$3~505~166 EFC:$2,914{000 Date~ ~ \ AR3B-459-,2-B JNumber all daily well history forms consecutively JPage no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting Ihe entire operation if space is available. 2~,CO J~LASKA TNC, District PRUDHOE BAY Field AS2564 Auth, or W.O. no. NORTH SLOPE JCounty or Parish Lease or Uni~tL'' DRILL JTitle A,PI: 28307 DS 50-029-21872 fAccounting cost center code StateAK 18-18 IWell no. ARCO 21.0000 Operator SPUD A.R.Co. W.I. 10/27/88 Spudded or W.O. begun Date DOYON 9 Date and depth as of S:00 s.~.2/08/88 ( 4 Iotal number of wells (active or inactive) on this Dst ce_nt, e_r_ori.qr_to plugging and band(~]~nl~t eht~l~is well our I Prior status if a W,O, I TD:llO~U PB: SUPV:DJ Old TD New TD Released rig Date J Complete record for each day reported 3) RIG RELEASED/WELL SECURE 7"@10317' MW: 0.0 RIH W/ CAMCO SLICKLINE. INSTALL DUMMY IN GLM #2 @ 8085' MD. BLED 9-5/8" CSG PRESSURE TO 0 PSI. SET BPV. RD CAMCO. CLEAR FLOOR AND PREPARE TO MOVE TO DS 18-20. WELL SECURE. SITP 650 PSI, SICP 0 PSI. RIG RELEASED AT 0900 12/07/88 DAILY:S8,998 CUM:$3,514,164 ETD:S3,514,164 EFC:$2,914,000 Classifications (oil, gas, etc.) Producing method Potential test data PB Depth K nd of rg IType completion (single, dual, etc,) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Dtvl~lon of AtlsntlcRIchfteldCompan¥ ARCO ALAzTK*: F'~ 0 ~ BOX ANCHORAGE ~. _ A LA.,-,'~,' A:,. oo~,' ~,. ,._, ARCO OF'EN HOI_E F'INAL~;' i :!--:3 9 J 4--~9 ~._,°.-~ 8 ~8-~8 ~8-~8 · ..,L.:.~.,...iV .... l? ,_., ................................................ HAVE A NT;~'--' r.,,-.'~'r": ;:7. Ai...L.Y HC)FF'-ECi<.'c~''...,'.. TRAN,~ ¢ 8 8 7,.':} 2 APPROVED ....... 'ID :[ :"': T IR :[ B [J T ! 0 N Anc:~m'aga ..,'t#. . I I".i"1i.. ! '~.,i...~.. ~ C I--i E V F.: 0 N ~ D ~ EXTENST_ON EXF'I_ORA'F.T. ON MARATHON '" HO""" :[ L. 11' F'H :i: L. L. I F',i:..' F'B WELl... F' .E I_ E ,?-: Il: R & D · "' :,,' A F'C 1'!" · ,.~ ,?;' T A T E 0 F' A i.. A L",' K A · .-'"' ]'EXACf]. REF'ERENCE' ARCO CASED HOLE' FINALS PLEASE SIGN AND RETURN THE ATTAC'HED '"';';F'Y:.,..., Ac',., ,~'c""~:IF'T.~.,_.,_ OF' DA"F¢,, 'TRAN$ '""-"-' ' '" '"' A F' F'R 0 V Eu" D I S'TR :[ B tJ'l" I ON AT' L. A .'i: A'i LA£ A 'TL. AS S C ~.-i ARCO Alaska, Inc. Pes~ O~q.ce Box J00360 PERIOD OF CONFIDENTIALII_ DATE OF COMPLETION, SUSPENSION OR ABANDONMENT 30-DAY FILING DATE RELEASE DATE COMMgNTS DATE_ B.RPC.02 (05189) D. Martin Engineering Aide DM-hf Enclosure GRU13/OIO Alaska.Oil & Gas Cons. Commissioa qnchoraoe ~ ~ 3o ~ ~ ITY ~AP NO SCALE / I ~ LOCATED WITHIN PROTRACTED SEC~. 19 ~ 24, ~ il N., R. 14 E. ~ R. 15 E., U. M. ' / o16 '~' 18- 18 Y:'5 961 467.29 LAT: 70° 17'57,323 X: 691 951 .34 LONG.: 148°26'43.158 406' EN.L. 205'EW.L. PaD EL.:IT, 3 . 22e / o12 18.20 Y: 5 960~4.07 LAT.= 70°17'48. 180" ~0~ / . ~21 X: 692 21~.80 LONG.: 148°26'36.139 " ; ~/ ~.~0 18.21 Y:5 960659.30 L.~?' 70°17'49.32l'' X: 692 182.86 LO~.: 148°26'37.013" 1219 EN.L. 416' EW.L. PAD EL.:17.7 18.22 Y:5 960 737.88 LAT.: 70017'50.243'' '' X: 691 588.40 LONG.: 148°26'54.278" 1126' F.N.L. 176' EE.L. PAD EL.:I6.1 NOTES , .... I. ALL COORDINATES SHOWN ARE A.S.P ZONE 4 NAD 27 DATUM. 2. REFER~CE FIELD ~K LPB 88-29. 3. BASIS OF LOCATI~ FOR NEW CONDUCTORS 18.20,21 ~nchorage. P O..LY GiSTE.EO N.LiCENSE. TO P. C ,CE C NO [ ARCO Alaska, Inc.... ~.CRAIG g. SAVAGE~ DRIcL ,SITE ALASKA AND THAT THIS PLAT eg~:.~ .~ ~ ~ CONDUCTORS 18,20,21 & 22 REPRESENTS AN AS-BUILT SU~EY u~a~_ __~' .~_ ~ ~ ~.~ ~ AS- BUILT LOCATIONS DIMENSIONS AND OTHER DETAILS '.~~---- ~ I ~[~ ARE CORREC~ AS OF: I~ Og~ ~ ENGINEERS. PL~E~S' SUbVErtS Rev. ay Dote ' Description Appv'd. l~g' NO. N~P'~'CEa'IZm'mli Sh*'. 201of / J 11;~f TEL NO: ~004 P01 STATE OF ALASKA OIL & CAS CONSERYAT]ON CO.~IS$ION B.O.F.Eo Inspection P, cport Trip Tank Pit Cas Detectors Audio BOPE Stack .T_..~ s_ t_, P__.ressure_. ?ipe Rams ...... _.f_~ Test Results: Failures Repair or Replacement of failed eRuipm~nt Pump incr. c]os, pres. 200 Full Charge Pressure Attained: ~ mt~ sec Controls: Maste{~~ '"~ ''~Remete~3._ Blfnd~ switch cover~ Kelly and Floor Saf~t~ towe~' ~ellX / __Test ~ressure~~O O aii / Test Pressure~d~ No. Valve4 / Adjustable __,arau!e~l! o~_tea choke Test Time _hrs. _~ to. be made w'f~thin daya and Inspector./ ion office R E.CELV r cc - Operator, September 30, 1988 Telecopy: (907) 276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 18-18 ARCO Alaska, inc. Pe~it No. 88-113 Sur. Loc. 407'FNL, 206'FWL, Sec. 19, TllN, R15E, UM. Btmhole Loc. 3810'FSL, 1280'FEL, Sec. 13, TllN, R14E, Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverm~nental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled.' W~ere a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before'drilling below the shoe of the conductor pipe. V~M. 'truly yours, ":£-onnie C-~--.--~m{Ch" Comm±~sioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · "~.. STATE OF ALASKA ALASKA OIL..,4D GAS CONSERVATION COMN,...,SION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill ~ Redrill []j lb. Type of well. Exploratory [] Stratigraphic Test [3 Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone J;~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. RKB 367 Pad 18' feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe 0il Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28307 ALK 2317 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 407'FNL, 206'FWL,Sec.19,T11N,R15E,UM Prudhoe Bay Unit Statewide At top of productive interval (~ Target) 8. Well nu.mber Number 3300' FSL, 11 00' FEL,Sec. 1 3,T11N,R1 4E,UM 1 8-1 8 #8088-26-27 At total depth 9. Approxi. mate spud date Amount 381 0 ' FSL, 1 280 ' FEL,Sec. I 3,T1 1N,R1 4E,UM 1 0/08/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line From L2-29 8705 'TVD 1280' @ TD feet 140' (~ 8702'TVD feet 2560 11624'MD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth51 28 ' feet TVD Maximum hole angle 88°°1!..~¢ll~ximumsurface 2920 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 39' 39' 119 119' 2000 # Poleset 17-1/2' 13-3/8' 72.0# L-80 BTC 3461' 39' 39' 3500 3500' 325 sx CL G & 2160 sx 12-1/4' 9-5/8' 47.0# L-80 BTC/MOD 8935' 39' 39' 8975 8264' 380 sx (~1 '(~' 8-1/2' 7" 29.0# L-80 BTC 1918' 8674' 8112' 10592 8674' 390 sx C1 'G' 8-1/2' 4-1/2' 11.5# L-80 FL4S 1232' 10392' 8662' 11624 8705' Slotted open hole co 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~ Diverter Sketch,~, Drilling program~ Drilling fluid program,,~!!~. Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements Lq 21. I hereby certify tha,~ foregoing is true and correct to the best of my knowledge/~/¢,~, Signed Title Regional Dri 11 lng Engineer Date~7 ~ ""-"-/~ Commission Use Only (DML) PD3/020 PermitNumber I A~51 number I Approval date I See cover letter oo8""//'~,~ J 50--O2.'~-.. ~_ /~2'7.,~- J 09/30/88 J for other requirements Conditions of approval Samples requ. ired [] Yes ,~ No Mud Icg required Lq Yes ~ No Hydrogen sulfide measures [] Yes ,,~No Directional,survey required ,~Yes [] No Required working pre~ssure.~r ~/~2M~ E~ 3M; ~, 5M; [] 10M; [] 15M Other: //~/~7//~ by order of Approved byL "..~/~ /I~~,~~ Commissioner the commission Date rap1 . Form 10-401 Rev.~l~5 Submit i! triplicate Sill PBU DS 18-18 SL("D" THL) OPERATIONS SUMMARY 1. MIRU drilling rig. 2. Spud well and drill 17-1/2" hole to 3500'. o e Set 13-3/8" casing and cement same. Test casing to 25(X) psi for 30 minutes. ~d';?n).c ~ ?: .t~.<: L~.t.~?~ ~ .~..~..~ ,~.,~._,/,~ Pick up 12-1/4" bit and BHA. Drill 10' of new hole and perform leakoff test. Drill 12-1./4" hole to 5128' and kick off. Build angle at 1.615Q/100' at N 19~ 24' W to 8264' TVD, gq'~S MD (10' TVD above the top of the Sadlerochit). Angle at this point should 62Q 7'. Log Put River Sand with MWD GR/RES. 5. Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes, . Drill 10' of new 8-1/2" hole and perform leakoff test to 12.5 ppg EMW. Drill 8-1/2" hole, maintaining angle, to TD at 8705' TVD, 11,624' MD (50' past the base of the Sadlerochit). Log Sadlerochit with MWD tools as per program. 7. RIH and spot polymer/salt pill at the 7" liner point at 8674'TVD, 10592'MD. 8. Run and set the 7" liner with an external casing packer 40' above the 7" shoe. 9. Clean out the liner and pressure test to 3000 psi. Clean out the open hole to TD. 10. RIH with drill pipe conveyed cement evaluation logs. 11. Run and set the packer and 4-1/2" slotted liner across the open hole. 12. Run 3-1/2" tubing with a GLM at 3250' and 8100' MD. Pressure tubing to 3000 psi. 13. Nipple up tree. Displace tubing with diesel down to the GLM at 8100' MD. 14. Release drilling rig. DS 18-18 DRILLING PROGRAM (Cont'd) NOTE: a) In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon the completion of the fluid disposal process. b) The existing well within 200' of the proposed well is DS L2-29, 156' at 8700'TVD. c) The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. d) Maximum surface pressure is based upon BHP and a full column gas to TD (0.10 psi/ft). e) Based upon previous logs on DS 18, no potential productive zones are anticipated above 5000' TVD. PD3/020.2 Depth (TVD) Plas Density Visc. #/gal (CP) Surf 8.8 Funnel to to 160- 13-3/8" 9.2 300 Csg Point 13-3/8" Csg Shoe to K-10 8.8 Mi n i mum to Possible 9.2 DS 18-18 MUD PROGRAM Yield Point Initial IOM FL % #/100 ft2 Gel Gel CC/30M Oil Solids 40-60 30+ 50+ 25 0 8 2 2 5 15 3.5 to to to to 0 to 4 5 10 25 6.5 pH and Type of Mud Gel-Benex Spud Mud Low solids/ non-dispersed K-10 9.2 12 to TD to to 9-5/8" 10.2 20 Csg Point 6 2 5 4 2 4 to to to to to to 10 4 8 6 5 10 pH 9-10 Low solids/ non-dispersed 9-5/8" 8.8 Csg Shoe to to TD 9.4 18 12 10 5 WATER 0 to 5% Oil Base EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid fl ow sensor 5. Trip tank 6. Agitators 7. Mud cleaner PD3/020.3 TYPICAL MUD PIT SCHEMATIC 32 32 . BBLS BBLS TRIP TANKS DESILTER (97' BBLS) (97 BBLS) PILL PIT (36 SELLS) DESANDER (36 BBLS) SUCTION PIT (448 BBLS) MIX PIT (122 BBLS) DRAWING IS NOT TO SCALE NOTE: SYSTEM IS EQUIPPED WITH A DRILLING FLUID PIT LEVEL INDICATOR WITH BOTH VISUAL AND AUDIO WARNING DEVICES AND A FLUID FLOW SENSOR LOCATED IN THE IMMEDIATE AREA OF THE DRILLER'S CONSOLF. JG 7/24/87 TVD 5128 3500. 0'0' 0.00 SEO. I'1D~5128. 0'0' 0.00 SEC. ~ALE ! 'l IO00FT. NOTE" ~INATES RELATIVE TO SLOT 7OOO 82~4 8674 3439 I000 200O V.SECTION PLANEt N19°24'W PROPOS?d., P~r6. I AR ~:)ALE I ', IO00FT. 15' q,',~,, ,'{ '"' ARc6 ALASKA. INC. Prudhoe Bey. 't lope. Al WELL,~ 18 ~OT, 1800 , I 1700 I 1 600 I 1500 I 1 4OO I 1300 I 200 1100 I 4700 4600 4500_ 4400_ 4300_ 4200_ 4100 _ 4000_ 3900_ 3800_ 3700_ 1800 4OO ",,~ ? O0 \ \ O0 ~XX ~00 X ~SO0 X ~400 ~ 0 17'00 1 600 1 500 1 400 1:300 1200 1100 _ 4700 _ 4600 4500 _ 4400 _ 4300 _ 4200 4100 _ 4000 _ 3900 3800 3700 DOYON RIG #9 DIVERTER SYSTEM ARCO ALASKA, INC. SCHEMATIC FILL-UP LINE I RISER I FLOWLINE 2000 PSI / 10" BALL VALVE 10" BALL VALVE I I I I CONDUCTOR NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT 10" VENT LINE ! I WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. GSW 8/22/88 13-5/8" 5000 BLI ND RA~$ REY£NTER~ cI' IPIPE RA"S) 1 I DltlLLI#G I~~ SPOOL j , ~, ,, iPIPE RA";~~ :' ~ [ ] HEAD ALL BOP EQUIPMENT 5000 PSI RATED 14. 15 16. 17 !8 PS1 BOP STACK DIAGRAM ACCUMI_ILATOR CAPACITY TEST I CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID 2 ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT 15 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE 13-5/8" 80P STACK TEST 1 FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID £. CHECK THAT ALL HOL~ DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. 5. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4 FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF 5 MINUTES, THEN TEST AT THE HIGH PRESSURE 6 INCREASE PRESSURE TO 3000 PSI AND HOLD FOR A MINIMUM OF 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES INCREA5E PRESSURETO 5000 PSI AND HOLD FOR AT LEAST 3 MINUTES BLEED PRESSURE TO ZERO. 9 OPEN TOP 5ET OF PIPE ~,AM5 THEN CLOSE BOTTOM SET OF PIPE RAMS INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST 3 MINUTE5 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALYE AND ZERO PRESSURE DOWN- STREAM. 11 BLEED PRE55UREl'OZERO. OPEN BOTTOM SET OF PIPE RAMS 12 BACK OFF RUNNING .JOINT AND PULL OUT OF HOLE CLOSE BLIND RAr'IS AND TEST TO 5000 PSI FL-iR Al' LEAST $ MINUTES 13 BLEED PRESSURE OFF ALL EC~UIPPtENT OPEN BLIND RAMS I"IAKESURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL YALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLINGSUPERVISOR PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BORE DAILY. JO 8- 26- 35 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2> LOC (2 thru 8) (8) (3) Admin ~'toc'.. ~/3~_~ 9. '(9 tn=~ 1~)-- 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (5) BOPE (23 thru 28) (29 thru 31) (6) Add: Geology: ,,,Eh g~neer lng :~ ~Pc ,, ncs %~ SEW-~ rev: 08/11/88 5.011 Company ~rco , , _~. Lease & Well No. " YES NO Is the permit fee attached ...................................... 2. Is well to be located in a defined pool ............................. M0.?C ,, 3. Is well located proper distance from property line .................. ~./~r ,, 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ~ __ 7. Is operator the only affected party .................... ~,. ........... 8. Can permit be approved before fifteen-day-wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate .................. /~Fr' Does the well have a unique name ;~'~;r'...[. 1[.~.. [.[~. ] ..1. ~.'~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Is conductor string provided Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment.procedure included on 10-403 ............ Is ad q llb par ti pr pos d · e uate we ore se a on o e ........................... Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/b~., Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. ,, Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL CLASS STATUS GEO. AREA UNIT NO. //6 ~o ON / OFF SHORE o~ m ~S POOL ~o~ 50 O Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. .o RECEIVED ~,PR 1 8 1990 Alaska Oil & Gas Cons. Commi~lOll Anchorage ~mmmmmm~mmmm~m~mm~mm~mmm~mmm~ 872 DF:nV:ICE: : FLTC [:) h T F : :'~ 0 t C, 3 t 2 n MAX RE(t SIZE : 1024 FIT,F: TYPE : ~,0 Ih;C, ,PRIJL>Hi.~E t" h,~C., PR}J [){-,)L!E i-~ .A Y, t:,. S. ! 5 E I8 qat~e verlf:1cation Li. stir~c) cklu~beroer AlasKa ¢.c,m. DII~'.:~DQ Cer~ror TI:' [~;II.:[.,EF: lJ 4o I :I:'Y["E Fbt.~I[: I..',1 rir][.:F: t.-Ri.iF.,;f(:k:[~ F'i,{/IDS L r: (; g I. ¢,! G [) I 5 T ¢!' ]' C 'r: P. ! C F! t i~ ~] [~ S T / ~5 It A [5'. I, !il k 't' ~.. [':: - P - ¢ 0 T N G - P - 9 6 ;., o E i3 E (; I b~ ¢ I l~,i (; A 1 f) 4 9 0 .... · , ..,' , ~, ,, .. ,- ~ , . r_, , , !..,l~,:'F':;~ 7 [3P. .iT [')IP, IF;D!CA'.FE "i~,;?,T ~"~E FUt,b [.,E?.;GTH OF TkiE 8hOq.'TE[) L!NER !3 I., tJ [.: i, I a e.: 5 & S p E: E' C L I k: r,,~ T k E (} [.~ ~'..; 5')-.. [., C 0 I. = 7' 5 C a / T 8 C F IS Ware ~.,'erificst cblumPerqer Alaska Co~,;::.Lltin,] Center 29 .'. ? .~, ~,:' - 1. c* 9 (; 1(~:53 PACE: 3 50-02q-2I~72 'l'~li-;'.;~<t',-'.t\[~ DE;CAY :iCi.)[, ll. 3~a' TO 994o' T U ~,~ I v h PRtiDHOE ~AY ~ [:~.1 ~~:~ 50-029" 21872 FL 407~ ~:~"~'[,,~ & 206' 55C~" 19 ~C[,~ 379259 E P D F T O, AP'O FT 5 4 , E'ea PT 54. B~DF FT 5 3 , TOP FT 1 ! qSl. eLI F:r 11,40o, TI~I PT 99~5, ~ I~C Company ~,iame Field Name ~ell ~:a ~e APl Serial Number Field Location Sect,,on Townshi !o ~anoe C o ti ~ t v State or Province r,;at ion Service Order Number Perma~er~t datum !i~otto,~; !,,oq Interval Top L, oo Interval Time Log~er At Bottom t;'ePth Cha~ne] :,iame Sigma ('~e,.]t. ro~ Capt,~re Cross 5ectior.) Statt]s of 'TDT Shu~.t C;3rre~t Siqma for~ation - far detector (Ti-,'{'~:~) 5i. qma formakio~ - ~ear cetector ('IpTp) Siar, a borehcle - far detector Siq~a bnrehole - near aetector (TLTF') Far Ti)q'Y, Co~jf~t A~p.lJ. tude for'o~ation -- far detector ~ln~plitude borenole -- Far detector ~)plitt~de for;'nation - near detector (TDTP) ~raullt, udo f{orehole -- n~ar detector SIG~4 Correction ~oreho,!e siC:ma (corrected] -- ¢,'{inJ. trOr~ mooe monitor ratio (TOTP) T P T R a t i o Standard. ,iev]atio¢ of Si{~ma-forr~;atio¢ (TDTP) [{ackGro~Jl~d, ~,~ear (;ates Far RaCKqround Total counts an:alVZed - near detector Total counts analyzed -fcr detector [7'9TP) Total counts - near detector ('r[>'!'P) Total counts - far detector Selectec..i qates count rat:e - near detector Se.lacteal aates coun~ rate - f~r detector Inelastic counting rate - near detector ~nelastic countin9 rate - far detect:or $OT-P Tele,~etrv Error Cot~r~t. ~4ead Vol. t a<~e Status o~ ATE Raw ~ear .~st Gate Ra~ ~,~ea:r ~nd Gat:e Raw ~:~ear 3r,:: Raw ~ea~ 4tr, Gate Raw ~'¢ear 5th Gate Raw ~'<'ear 6t.a c;ate ~a~ t, ear 7t~ (;ate Ray; ~Jear ~;~t,.r~ Gate Raw Neet 9t~:~ Gat;e Raw Near loth Gate ~aw ~ear ! !t:h Gate Raw ~,;:ear !2th Gate Paw ~,?ear 13th Gate Raw ~,~'ear 14th date F:aw ~,~ear 1sir, Gate ~aw Near lGth Gate !{aw Far !.St date Raw Far 2nd Gate PAGE IS 'rar~e '~ter!.f~catJon t.,i. 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P S 1 6~ 2.179 TTEC, PS1. 1034.226 F:$2,PSI I 123 512 2172,619 398,0o5 PF2.PSI 416'607 F.:F6, PS 1: 580,357 :!.!56,994 RF14,PS[ 22.234 T ~:;: ~,,: S, P S 1 !2,142 STt)T,PSI 12.555 1'3,4('.~9 ~:TD17 PSI 409.57 '1, .A b ~':, ~:';. P 51. 1,2i7 TFiAT, PS!. 43,99! t 1. C~23,0i:~4 TSC~..:, PS 1 516. ('.'13 TT/EC,PS1 961 ,538 181 ,~. 9 10 $. 7.6 39 RF2, P;31. 506,9'44 PF6. PSI 743 , O ~'' =' :~ ') R [;' 1 (), P S I t472,222 ~F14, PS! l 6,703 T 6~.000 2!. 726 54..:109 587.975 6214n, 359 i I 360. 354 (i. 0,30 i ~; 6,410 2232. 143 253V.202 4002.976 38.700 959.~2! !242.559 2031,250 ~55.000 66,000 15.202 2..1..21.3 454,039 1.8!0 34782,414 634.1., ~a6 0 0 00 17o: 280 1 o 4.9 .t 1,335.565 2075"89] 38,700 442. 708 598.958 1242.559 135. 000 66.000. 13.5'73 23,228 468. 709 !,6!.5 42385,469 7777.904 0.000 220,590 i, 554 487 1726: 763 2904647, 46,44() 565.972 673,61t. 1 638, ~ 99 14 0,0 00 TPHI:. PS1 8B.Fi.F , PS 1 AFFD. PS 1 SBSI',PS1 TCA1F, PSI TSCF,PSI HV.PS1 R ~.;'i "PS1 R.~! I ,PS1 ~ ~-.:. ! 5. PSI ~F3,PS! RF7, PS! RF! 1,PS1 CCI.,. PS 1 P AG ~':: 12 12.740 33,346 221.4~6 ~.120 0,416 34095.125 6233.190 242.875 1235.119 1707.589 3947.172 2351.190 524.553 755.20~ 1908,482 1365.327 0.000 i7.903 62.177 95,091 0.377 0,370 19211.691 3502'872 242:375 1,168,1.55 840,774 1796.875 1696,428 357,143 345.9~i 837,05 1004,464 0,000 12,381 4.9,566 !!2,949 0.445 0'254 26243,91.4 4815,863 243,000 1!33,814 1077,;24 2443, I0 23!1,699 371' 528 454 861 1020 833 1451 359 0,000 "' · .... ,':: 5,3 13 **** FILE H E ~ l'~,~,~ ~ F!!~F ~AP.E : gSI'l' ,002 VSRS I 0~; : GO!.A04 IJ~TE ~lX REC SIZE : :!C24. LAST FI[,E : T P T-, P . P S 2 i0549' T4j 9944' iS ~'a~e veri,~ication Listinc: chlumherqer .~las<a Cio~)ut,~nr~ Cer:,ter PAGE: 14 COmpap.v Field ~el ! Lame &PT Serial Number Fiel, O Location Sect j, on Township ~anue Cou~t~ State o~ Province ~at ion Service Order Number Permanent [.,:.',a keasured From TYPE : CUF::V SJama (~',;'eutron. C:apt~re Cross Section) Status o~ TI)T Tr)'r Porosity TDT Shut, t: Current Sigma formation - near det. ector Siqma t)orehc>le - far detector (TDTP) S,iqrna borehol, e - near detect, or Far TD~;:;~ Count: Rate ~,~ear' T[)'i~~. CouOt Fate amDiitude formatJ, on -- far detector (TDTP) ,~mplJ..t':ude bc)reho]..e -- F"(ir detector &¢~plItude formation - near detector (*ZDTP) Aaplit~]de .Borehole -- r~ear ~}etector (Ti)TP) SZGM Correction 9~orehole sJ,~mo (corrected) --TDTP M~.l~:itro~ mode monitor ratio (TD1P) TDT )~at J.o Standard deviati..o~ o.[ S!,oma-forr~at::i(,>r) (TDTP) i~acKq~o(.inc)~ Mea~ Gates Far RacKqrodnd Total,. counts anal. y~ed - near detector' 15 q'('~,~t~ Tote! Co~nts - near detector TC~'r Total cnunts - far detector T~C~- Selecte~ cate~ count rat~-~ - near c~tector TSC[ Selected qates codnt rate - ~ar metector It~:,!r' T,~elastic cour~tinfl rate - near ~erector I~:F'[' [nelasti. c countinq rate: - ~ar det[:-cto~ (TDT~~) TTEC TF~I"-P Telemetr~ ~irror ~V ~ea~ S a,'T'C Status of R~:P ~'aw ~'Jear 2n:3 Gate R~',:4 Paw f.;ear 4tn <;ate ~6 Raw ~,,~ear 6th (;ate R~7 ~aw ~,,ear 7th (;ate 'R~:~ Raw rsee~ ~tn Gate ~O Raw Near 9tz~ Gate RNIO Raw Near ]Ot.h Gate RN!,I uaw ,'~ear 11tn <;ate R~l, 2 ~aw Near 12tn Gate RN13 Raw Near 13tn gate ~t. 4 Raw ~,tear 14th Gate R~15 Raw p,,.~ear!Sth <late Rb;16 .Raw ~ear 16tt~ Gate RF! Raw Far !st Gate RF2 Raw Far 2nd (;ate ~F3 Raw Far 3rd Gate RF4 Raw Far 4th <;ate RF5 Ra~ Far 5th. Gate RF6 Raw Far 6th Gate RF7 Raw Far 7t~ Gate RF8 Raw Far 8th Gate RFq Raw Far 9th Gate RF.]O Raw Far !Ot:h (;ate PFtl Raw Far lith Gate RF!2 Raw Far !2tn date RF!3 Raw Far },3tt'~ Gate RF!4 Raw Par 14th Gate RFI5 ~a',' Far !St:r, Gate RFI6 Raw Far 16ta (;ate G~ Gamma Pay TE?~S Tension CCI CCL .hcnO.1 i, t dde Tape Verificati.,::.,.u Listing ch.lUc~bercler ~].asKa Cot,,putT. ir~.c! ("entel' S I G ~'" P$2 C!.~ 379259 5! 8?DT Pfi~ 379259 T .Pk~ I PS2 P~'~ 379259 5,t.,. ISNU PS2 V 379259 SFFD PS2 CU 37~'259 51 8F~i P' PS~ Cf! 37q259 51 SE?IF' P52 C!l 379259 g¢ H~,~ P52 eli 379259 51 Fq'DT PS? CPS 379259 51 a,~ ~',q~ pe~ CPS 379259 AFFD PS~ CPS 379259 51 A[~FP PS~ CPS 379259 51 A~'NP P52 CPS 379259 ABND PS2 CPS 379259 51 8IGC P82 C[.~ ~79259 5! SIYB~ PS2 CJ ~79259 5! NYOF PS2 379259 51 T}~: A 7' P82 .379259 5!; SP5I P52 CU 3797259 5!. B ~.C~. P52 CPS 379259 F'E! A C PS2 CPS 379259 TCA.~ PS2 379259 TCAF PS2 379259 TCND PS2 CPS 379259 51 TCFD P52 CPS 379259 5! 400 0 !. 0 2 ! i 4 :190 00 0 2 ! ! 4 890 O1 0 2 1 I 4 000 O0 0 2 i 1. 4 40 <i 02 0 2 I, I 4 40O 02 0 2 1, i 4 4 (:, 0 () 1 0 2 .l ! 40 ,') 01 0 2 i 1 ,4 00 <.) 0 0 () 2 1, 1 4 0~ ~0 0 391, 00 0 2 1, 1 4 39 ! 00 0 2 390 00 0 2 I i .4 390 00. 0 2 I 1 4 40 o 0 ! 0 2 i 1 4 40 ,"u 01 0 2 !. 1, 000 00 0 2 !, i 4 000 00 0 2 ! ! 4 000 O0 390 17 0 2 1 391 1.7 0 2 1. 1 0 00 00 (.) 2 000 00 0 2 I, I 4 o C, 0 0 o 0 2 I 1 4 t) 8 O0000000OO 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 6g 0000000000 68 0000000000 68 0000000000 68 0000000000 68 OOO0000000 6B 0000000000 6 i! 0000000000 68 O000OO0000 68 0000000000 68 00000()()000 0000000000 68 000000oo00 68 O00000oooo 68 0000000000 6g 0000000000 68 0000000000 0000000000 PAGE: 16 IS Ta.r>e Verification 1,15ti~9 17 I ~ r'; [: PS2 CPS 379259 HV PS~ V 3'19259 5i SA'I'C P5~ ]79259 51 RKI PS2 CPS 379?.59 }{~2 PS2 CPS 3'19259 ~,N] PS2 CPS 37925~ kCJ 4 PS2 CPS 379259 5 R~5 PS2 CPS ]79259 51 RN6 PS2 CPS 379259 51 RN7 P52 CPS 379259 R~ PS? CPS 379259 ~,9 PS~ CPS 370259 ~;~N 1 ~ P82 CPS 379259 pNI2 PS2 CPS 379259 5!. RS13 PS2 CPS 379259 F:NI4 PS2 CPS 379259 R~,15 PS2 CPS 379259 51 ~l& RS2 CPS 379259 RFI P52 CPS 379259 5I RF2 PS2 CPS 379259 51 RF3 PS2 CPS 370259 RF4 P82 CPS 379259 51 ~F5 ~82 CPS 370259 51 RF6 PS2 CPS "~79259 51 RF7 PS2 CPS .37025a 5! RF9 PS2 CPS 379259 RFlO PS2 CPS 379~59 RFll PS2 CPS 379259 51 RFI2 PS2 CPS 379259 RF13 P82 CPS 379259 ~FI~ PS2 CPS 379259 5 RF15 PS~ CPS 379259 ~!~!6 P82 CPS 379259 GR P52 GAPI 379259 51 TF~S P82 bB 379259 5 CCL PS2 V 37925~ 51 CC)DE ([~EX) oO 0 oo 0 2' ! I 4 68 00000()00 O0 nC;(, 0(') 0 2 I 1 4 68 O00OO00000 00~ Oa 0 2 I 1 q 68 0900000000 39,) OU 0 2 I ] 4 68 000000(}000 n()o O0 0 2 l 1 -I 68 00000000~0 OhO Oo c) 2 1 1 4 6tl 0000000000 )90 C.,l 0 2 1 I 4 68 o0o0000000 39(7~ 02 o 2 1 1 4 68 00o000000o 39~ 03 0 2 I 1 4 fl~ 39~5 04 (~ 2 ! 1 4 68 OOOO000000 399 (') 5 0 2 I 1 4 6 ~ 0000 (:, 00000 ~90 Ob 0 2 ! 1 4 68 O0000000OO 39~ 07 0 2 ! 1 4 68 O0000nOc, oO 390 O~ 0 2 I 1 4 6~ <')O00000OO0 ~ 9 c) 09 0 2 I. 1 4 6 a 0 o O 0 o 00 () 00 390 1 O 0 2 ! 1 4 68 0000000000 390 1, 1 0 2 ! 1 4 68 0000000000 .]90 12 0 2 1 1 4 6a 0000000000 39c, ! 3 0 2 1 i ~ 6a 0000000000 390 14 0 2 1 1 ¢ 68 0000000000 39 ~) 15 0 2 1 1 4 68 000000 ~) 000 3'90 !6 0 2 ! 1 4- 6~ O0000OO000 391 Oi 0 2 I 1 4 6~ 0000000000 3 9:1 02 0 2 ! I ,I 68 0000000000 391 03 0 2 ! i ,4 68 0000000000 391 04 0 2 1 I 4: 68 0000000000 391 05 0 2 ! 1 4 68 0000000000 39! ()6 0 2 i 1 4 68 0000000000 39 ! 07 0 2 ! l 4 68 O000000000 391 0 ~ (.) 2 ! i 4. 68 0000 000 C)~} 0 39 :! () 9 0 2 ! 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Fi. eld Name APl Seri. al. Number Fielci Location Section TownshJ. p Range State or Province Nation 2ervice Urder ~,umber Permanent datum boq ~!easure~ From 22 SIG~: AFFP A F N A~kP SDS] '~C~: TCAN TCAF TCFD T S C TSCF I N ~,} D T T ~: C RN4 RN6 RNIO R~14 RN!S PF 2 Sinma (~.:eutro?: Capture Crns$ Settlor':) Status o! 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Inelastic countir~q ~ate - near detector !'nelastic countinq rate - far detector TDT-P Telemetry Error Count Head voltage Status of ATC Raw Near 1st Gate F~aw Ne~:~r 2nd Gate Raw Near 3rO Gate Raw Near 4tm Gate Rm. ~ear 5th Gate Raw Near ath Gate Raw Near Vt.l:~ Gate Raw ~ear 8tn Gate ~aw Near 9t~ Gate ~aw ~ear lOth Gate ~aw wear ! 1 th Gate Raw ~'4ear 12th Gate Raw Near 13th Gat. e R.a'~ Near 14th Gate Raw Near ~Stb Gate Raw ~]ear !dt.h ,gate Raw Far 1st Ga. te Tape VeriLicat. ior~ bi. stiffel ,ChlU.~,-,berqer ~las<a Cc~D':F.t]tj.~:q Cer:te¥ PAGE: 23 DP, Fl' ';;~ ..... R;~-;''''~'~'~'~ar _r,. a e .................................... 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ST 407' F:.l, g 2nO' /?:r, Flelo I..,ocation 19 Sect i de A[,i'~SbA 5taLe or province !SA ,~at ion ~itness ' ,Serv!ce ,.')roar r~umber Permanent ThBLE TyPg : CORV ............ ~.tn Cna, ~ r .....i rt~ e SlOma (;<~eutror, Car.,ture Cross 8ectior':~) Status o~ Tt:)T Porosi. ty TOT $~unt Current $iOma formation - far detector Si, oma f'orr~'~ation - near detector Slams borehole - far detector Sioma borehole - near detector Far TDT;4 Cogent ~ate ?~ear %D!:P Cou~)t ~{ate ~mplttUde forr!'ation --,far detector ~,~nlitude t~orehole -- Far detector ~plitude {:o~"matio. - near detector' A~plituOe f~ore~oie -- near detector SIG~ Correction Borehole si~n~a (correct. ed) -- TbTF' ( TDTP ) ( T D T P ) ( ID TP ) ( T [) ? P ) ~init, ron mode ~or~ltor ~atio (TDTP) T[?'T ~at io Standard deviation of: 6acKgr'ounCi, ?:;ear Gates ~'ar 6ac~ qro'or~c~ Total counts analyzed - near detect, er ( T I.)'!' 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PS4 468.750 6~7,32 :i RE'! q, P,%4 587. 797 1.402,530 RF'14,P~34 1473.2.t4 45,8 ,* 4. ti E.: N 5, F' G 4 I 90,000 PAGE: 2956,31.0 242.~75 1274.305 805.555 1892.361 1635,417 260,417 293,899 662.202 807.292 0.000 1,2,698 50,664 106,918 0,348 0,276 24348.027 4457,727 242.875 !159.722 103!,250 2298.611 2013.~89 305,060 401,786 937,500 1264,881 0.000 3R ch].u~,~her¢.~r ~].as~a ro~'~7~t~tinq C. er~ter 39 ... 2~57~ 029-21,872 T !i b b 0 PE H /t' i (.; R ~' · " .... r) I., E ;Y: 259 DEFI COI~):)8nV Fiel. d ~ame ~el,1 API Serial Number ~ le,l.d [,~ocat i. on Sect; ion 'to ~ n S ~ i p RanGe County State or Province ~ation ~itness' Service Order Number Permanent datum boq ~,'ea. sureO From chlu;'~ber:Ter Alaska Cc'~>u~J.,n~ Cer;t~r S 7: r' F~DT AP T~: SDS] t C ~ TCAF T C h D TCFD T ~ C ~'~ TSCF TTEC HV SnTC P ? 2 R~< 9 Stat~lS of (['.D~ · PT Porosit.¥ TOT Shunt Current Sigma for:nation - far detector Sfqma formation - near detector Sigma borehole - ~ar detector (TI)TP) Sigma nore~ole - near oetector Far TOT~;~ Cour~t kate ~ear ~O']F~ Cour~t Rate hmD].itune formation -- far detector A:~plitude {'~orehole -- Far detector ~mDlitude ~or~,ation - near detector A¢,PlStt]de ~orenole -- near aetector SIG,~ Correction ~%orehole sJqr~a [corrected) -- ~,4ini. tron mode monitor ratio TDT Rat ia Standard deviation of []icma-for'~atlor~ (TDTP) BacKGround, t'.{ear Gates Far BacKqrour~d Total. counts ar~al, yzed - near detector (TDTP) Total cou~t.s ~a].yzed - far detector (TDTP) Total counts- near detTector (T[;VP) ' Total, counts - ~;ar c~etector Selected qates count rate - near Oetector (TDTP) Selected qates count rate - t'er detect, or Inelastic countI~ rate - near oet:ector (TDTP) Inelastic countinh rate - far detector TOT-P Telemetry E:rror Count ?.Cecal Vo!.ta~e Status of Raw Near !.st gate Raw Near 2nd (;ate ko',, ~.~ear 3rd (;ate Raw Near 4th Gate Raw Near 5tn Gate Raw Near 6t.h Gate ?aw :~:~ear 7tn Gate Raw ~'~eor 8tn (;ate Ra~ ~,;eer 1(>th Gate F~aw ~,~ear :!.lt.h Gate Ra~ ~;ear i2ti:~ Gate Raw fi;ear 1]th Gate Raw ~ear 1,4th Gate Raw ~,~ear 15t~ Gate Rs'~ Near !6ta Gate Ro~ Far 1st ,Sate Paw Far 2nd (;ate P AGE; 4O C. hlUmrer:?.er ~!as~.~ (?~=~r:~t.~tinq Cet:t~r P A G E; 41. 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PSb 49144.297 9,8bi T,SC~:~, PS6 8650,854 1.22~ TTEC,PS6 O.O00 ! ,Iii P~'~2, PS6 20!.240 9,305 Ri'~6,PS6 1881, 944 7.36 !. R ;'~ 1 ,:~, P 86 2 t 1. f~. O 55 9,58? P ~'.~ I. 4, f:'S6 3()79,861 7.3el ;F~F?, PS6 42.570 B'036 ~Fo,P56 669,043 8.69() RFIO,PS6 926.339 O, 833 RF14. PS6 1: 51(). 417 6,750 TE':aS, P86 !85,000 7,1. O1 5'FDT, PS6 66,000 (~,7!5 SF;-~O' PS6 22,670 7. !. 03 ~..;~ T D T, P 56 41,14 O P 56 502,735 2,0 e, 2 A F, ~ r?. 'P 86 2,0 q 2 I., 24 ~ T f{ :A :'[', ....... 6,920 ~rcA~;, P' ..... , . o6 46867,~05 0 956 TTE:C,PS6 0.000 5,417 P~'2, PS{~ 176,472 5,278 aN6,PS6 1937.500 .3' 8~9 R~910,P56 2180.555 9.5¥3 9N]_4, PSO 2996,527 2,9!7 '[~F'2, PS6 34.830 5,139 i,~'F6, P56 649. 306 2,917 RFIO,PS6 854,167 6,805 RF14.PS6 1458.333 2.469 TF.F~S,PO~ l. S5,O00 TPHI , P56 AFC[',. PS6 SIgC.P8~ SDS I. PS6 'rcAF. TSCF,PSb HV. PS6 R~ 3. PS6 R,~7 . PS6 RN 11, PS6 Rt'.15. PS6 RF3.PS6 RFF.PS6 RF'I 1 , FS6 COb. PS6 TPHI. P86 SgHF', PS6 AFFD.PS6 S1GC,P56 SDSI,P86 TCAF, PS6 TSCF. PS6 H q, PS6 Rh~7 , PS6 RB 11. P86 RNI. 5.PS6 RF3, RF'7 , PS6 RF! I.PS6 RFI5,P$6 CCL. PS6 ',17P~ !, PS6 SBF{F. PS6 AFF[), PS6 SIGC, PSfi 8081, P86 TC.AF,P56 TgCF,P86 'aY. P86 RN3,P56 R.i'.) I ! , PS6 R~ ! 5, PS6 RF3,PS6 RFV.PS6 RF!I.PS6 RFI. 5,P86 CCI,, PS6 PAGE: 55 18.982 37.67b 116.690 3,494 0.430 19636.344 3466.506 242.625 993.303 1268.601 2972.470 1733.631 277'77~ 444,444 1131.944 864.583 0.000 i7.027 33.1~9 149.161 2,696 0,392 24302 859 4~78 024 242 625 fOB3 333 1409.722 3260.4!7 !913,194 342.262 535.714 1324,405 956,101 0,000 I8,676 30,6,17 147'744 2.738 0,442 22403,559 3942,662 242,500 !118,055 1392'361 3263'~89 I850'694 350,694 503,472 !291.667 888,889 0'000 ehl. t)mberc~e.r Al. asKa Cor?c, ut,ir',q (.er,.t:er P A (; E: 56 .1 ~;;-1 8,5o-029-21 !;372 ~' ! a-1 8,50-029-21.87 2 NL BAROID MWD LIS 9 TRACK MAGNETIC TAPE VERIFICATION LISTING RECORD TYPE 132 REEL HEADER ....................... RECORD LENGTH = 132 SRVCNM ]'R/MO/DA REELNAME RC PRETAPNM RLL-B 89/01/02 REEL-OOi Ol COMMENTS: TANDEM TOOLS.TOP TOOL=SSO,BOT TOOL=G58.658 LAYED N 5-BAD EWR. RECORD TYPE 232 COMMENTS .......................... COMPANY NAME WELL NAME FIELD NAME :ARCO ALASKA INC. :18-18 :PRUDHOE BAY COUNTY :NORTH SLOPE STATE : ALASKA COUNTRY : USA RIG : DOYON 9 COMPANY REP :MR. JACKSON RECORD TYPE 130' TAPE HEADER ...................... RECORD LENGTH = 132 SRVCNM YR/MO/DA TAPENAME RC PRETAPNM RLL-B 89./01/02 88-11-26 01 COMMENTS: TANDEM TOOLS.TOP TOOL=880.BOT TOOL=658.658 LAYED DOWN AFTER RU N 5-BAD EWR. RECORD TYPE 128 FILE HEADER ....................... RECORD LENGTH = FILNAM.NUM RLL-B .001 62 MAXRL 1024 P REV F LNAM E COMMENTS FOR THIS FILE :TOOL 658.SFD CALIPER CORCTD, RECORD TYPE 64 DATA FORMAT SPECIFICATION .......... RECORD LENGTH = TYPE SIZE CODE 4 i B 13 i B 14 4 A 15 I B 508 BYTES DESCRI PTI ON UP/DOWN FLAG = -1 OUTPUT DEPTH FLAG = 0 UNITS OF DEPTH IN DATA RECORDS = FT REP CODE FOR. OUTPUT DEPTH = D DATA SPECIF'ICATION BLOOKS NAME SRVCNM ORDERNUM UNIT LOGT CRVT CRVC APIM FILNUM SIZE PLVL R DEPT RLL-B 00000000 FT 0 0 0 0 O1 04 0001 D SGRA RLL-B 00000000 0 0 0 0 01 04 0001 D SGRB RLL-B 00000000 0 0 0 0 01 04 0001 D SNFO RLL-B 00000000 0 0 0 0 01 04 0001 D SNFI RLL-B 00000000 0 0 0 0 O1 04 0001 D SNNO RLL-B 00000000 0 0 0 0 01 04 0001 D SNN1 RLL-B 00000000 0 0 0 0 O! 04 0001 D SROP RLE-B 00000000 0 0 0 0 Ol 04 0001 D SGRC RLL-B 00000000 0 0 0 0 01 04 0001 D SENR RLL-B 00000000 0 0 0 0 01 04 0001 D CNPS RLL-B 00000000 0 0 0 0 01 04 0001 D RHOB RLL-B 00000000 0 0 0 0 01 04 0001 D CALP RLL-B 00000000 0 0 0 0 01 04 0001 D DEPT SNN1 CALP 8900.00 2819.69 -999.25 9000.00 3438 51 8 63 9100 O0 3526 29 9 12 9200 O0 3065 16 8 73 9300.00 4234.42 8.61 9400.00 3824.21 8.53 9500 O0 4t87 43 9600 O0 4068 04 8 64 9700 O0 3753.32 8.56 9800.00 ~.4,.'1 8.73 9900.00 3356.95 SGRA SGRB SNFO SNF1 SROP SGRC SEMR CNPS 164.00 133.59 728.34 656.54 --999.25 148.79 131.G7 51.64 30.92 31.28 1052.48 1019.15 104.52 31.10 302.54 22.56 16.52 14.50 1139.46 1072.92 90.18 15.51 963.39 20.65 60.23 48.47 840.17 828.52 45.32 54.35 51.57 30.97 20.81 19.09 1373.78 1377.03 31.95 19.95 664.10 12.70 19.43 17.43 1496.15 1478.62 21.05 18.43 2216.23 10.37 24.09 19.00 1379.84 1354.53 28.77 21.54 230.97 13.18 1.5.17 14.14 1447.35 1407.26 62.21 14.65 608.38 !2.02 29.59 25.97 1094.60 1066.19 31.86 27.78 2216.23 16.26 25.43 21~79 938.90 944.94 40.88 23.61 552.84 22.79 71.79 61.24 1021.47 977.44 21.09 66.51 93.14 27.41 SNN 0 RHOB 2746,27 -999.25 3409.49 2.37 .-',.J 4.z, . 54 2.38 3042,,03 2.65 4110.17 2.58 4055.44 2,51 4110.48 2.50 4168.93 2.51 3798.39 2.46 3383.54 2.51 3431,09 2.67 10000.00. 15.42 19.43 1128.03 40~8.9Q 37.44 17.42 718.03 8.50 10100.00 30.37 27.27 1072.25 3922.50 56.49 28.82 98.57 8.64 10200.00 26.47 26.32 761.10 3407.09 85.38 26.39 287.74 8.63 10300.00 61.32 54.14 711.02 3320.33 50.84 57.73 141.23 8.65 10400.00 37.32 34.78 754.38 3475.34 63.92 36.05 416.67 8.66 10500.00 -999.25 -999.25 -999.25 -999.25 15.22 -999.25 -999.25 -99_.~ 10600.00 -999.25 -999.25 -999.25 -999.25 11.61 -999.25 -999.25 -999.25 1112 16 1056 18 765 25 685 30 736 27 -999 -999 -999 -999 RECORD TYPE 129 FILE TRAILER ...................... RECORD LENGTH = 62 FILNAM.NUM MAXRL RLL-B .001 1024 NEXTFLNAME RECORD TYPE 128 FILE HEADER ....................... RECORD LENGTH = 62 FILNAM.NUM MAXRL RLL-B .002 1024 PREVFLNAME COMMENTS FOR THIS FILE :TOOL 880.SFD CALIPER CORCTD. .03 .03 25 .89 56 .96 5O .48 10 .29 25 .25 25 .25 3938.97 2.41 3786.50 2.75 3576.00 2.66 3230.48 2.54 3457.91 2,47 -999.25 -999.25 -999.25 -999.25 ~4 DATA FORMAT SPECIFICATION LENGTH = CODE i B i B 4 A I B 0 B RECORD TYPE RECORD TYPE SIZE 13 14 15 0 DATA NAME SRVCNM ORDERNUM DEPT RLL-B O000000O SGRA RLL-B 00000000 SGRB RLL-B 00000000 SNFO RLL-B 00000000 SNFi RLL-B 00000000 SNNO RLL-B 00000000 SNNI RLL-B 00000000 SROP RLL-B 00000000 508 BYTES DESCRI PTI ON UP/DOWN FLAG = -1 OUTPUT DEPTH FLAG = 0 UNITS OF DEPTH IN DATA RECORDS REP CODE FOR OUTPUT DEPTH = D TERMINATOR SPECIFICATION BLOCKS UNIT LOGT CRVT FT 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 = FT CRVC APIM FILNUM SIZE PLVL 0 0 02 04 0001 O, 0 02 04 0001 0 0 02 04 0001 0 0 02 04 0001 0 0 02 04 0001 0 0 02 04 0001 0 0 02 04 0001 0 0 02 04 0001 SGRC SEMR CNPS RHOB CALP RLL-B .00000000 RLL-B 00000000 RLL-B 00000000 RLL-B 00000000 RLL-B 00000000 DEPT SNNi CALP 8900.00 2796.54 -999.25 9000.00 3428.61 8.78 9100.00 3536.94 9.28 9200.00 3156.02 8.57 9300.00 4118.16 8.62 9400.00 4466.53 8 48 9500 O0 4382 53 8 4! 9600 O0 4106 76 8 58 9700.00 4019.39 8.68 9800.00 3506.23 8.73 9900.00 3542.34 8.45 0000.00 3985.02 8.62 0100.00 3924.23 8.53 0200.00 3482.12 8.72 0300.00 3270.87 8,51 0400.00 3458.63 8.57 0500.00 2879.47 9.33 0600.00 SGRA SROP 162.22 -999.25 25.85 104.52 28.86 90.28 60.14 45.32 25.24 31.95 19.99 21.05 22.05 28.77 16.48 62.21 24.91 31.86 23.89 40.88 73.70 21.09 20.70 37.44 33.08 56.49 24.39 85.38 63.85 50.84 39.17 63.92 77.91 15.22 85.85 0 0 0 0 0 0 0 0 0 0 SGRB SGRC 159.36 160.79 32.35 29.10 17.80 18.33 62.26 61,20 23.75 24.50 19.96 18.67 20.36 16.30 !6.39 23.16 24.04 28.50 26.20 65.85 69.78 17,57 19.14 41.23 37.16 26.58 25.49 63.55 63.70 41.41 40.29 91.51 84.71 101.80 0 02 0 02 0 02 0 02 0 02 SNFO SEWR 773.17 33.55 1001.81 368.03 1078.34 906.00 779.67 64.34 1407.31 1027.97 1560.89 1090.80 t472.80 195.63 1350.68 393.87 1187.00 565.51 962.37 486.31 1038.33 78.93 1181.76 785.42 1110.38 30.48 780.21 25!.17 733.47 141.23 787.80 416.67 776.88 11.72 733.13 04 0001 D 04 0001 D 04 0001 D 04 0001 D 04 0001 D SNF1 SNNO CNPS RHOB 817.00 2799.28 41.21 -999.25 1043.00 3435.39 21,00 2.34 1089.20 3493.48 '19.42 2.35 790.76 3128.35 29.29 2.47 1379.00 4250.00 1~ 15 2 =~ 1523.42 4378.50 9.56 2.48 1432.00 4353.92 10.51 2.40 1349.11 4246.59 12.58 2.42 1155.00 3903.07 15.87 2.46 951.96 3519.56 22.90 2.59 1030.59 3742.67 22.16 2.38 1129.98 4015.27 15.68 2.42 1100.70 3892.21 17.76 2.52 733.60 3563.44 26.40 2.49 743.18 3301.20 27.44 2.68 778.48 3460.19 25.22 2.40 783.48 2848.45 36.89 2.43 778.03 2864.29 10780.00' 75.33 97.47 817.57 3208.09 15.41 86.40 9.94 8.66 10800.00 77.32 106.35 852.28 3!29.42 18.62 91.84 10.22 8.75 10900.00 86.74 114.22 815.1! 3095.48 21.60 100.48 9.26 8.71 11000.00 58.26 84.20 77!.30 3223.84 18.28 71.23 159.46 8.45 11100.00 82.26 111.24 812.30 3110.08 26.6'7 96.75 10.33 8.49 11200.00 55.30 69.81 788.60 3098.86 68.32 62.55 49.77 9.21 11300.00 49.14 58.82 781.39 3204.61 67.64 53.98 62.85 9.34 11400.00 -999.25 -999.25 -999.25 -999.25 69.45 -999.25 -999.25 -999.25 11500 O0 -999 '~ - ~._ -999 ~= -999 zs '-999.25 15.44 -999.25 -999.25 -999.25 RECORD TYPE 129 FILE TRAILER RECORD LENGTH = 62 FILNAM.NUM MAXRL NExTFLNAME RLL-B .002 1024 RECORD TYPE 128 FILE HEADER ....................... RECORD LENGTH = 62 F I LNAM. NUM MAXRL PREVFLNAME F'..LL-B .003 1024 COMMENTS FOR THIS FILE :TOOL 880.REPEAT SECTION 836.23 32.54 788.25 34.92 802.28 32.90 785.02 29.89 811.54 34.77 758.18 33.22 737.86 31,04 -999.25 -999.25 -999.25 3118.15 2.44 3056.00 2.38 3099.22 2.38 3140,67 2.27 3040.64 2,29 3106.67 2.25 3110.93 2.28 -999.25 -999.25 -999.25 -999.25 RECORD TYPE 64 DATA FORMAT SPECIFICATION .......... RECORD LENGTH = 508 BYTES TYPE SIZE CODE DESCRIPTION 4 1 B UP/DOWN FLAG = -1 !3 I B OUTPUT DEPTH FLAG = 0 14 4 A UNITS OF DEPTH iN DA'TA RECORDS = 15 I B REP CODE FOR OUTPUT DEPTH = D 0 0 B TERMINATOR FT DATA SPECIFICATION BLOCKS NAME SRVCNM ORDERNUM UNIT LOGT CRVT CRVC APtM FILNUM DEPT RLL,B 00000000 FT 0 0 0 0 03 SGRA RLL-B 00000000 0 0 0 0 03 SGRB RLL-B 00000000 0 0 0 . 0 03 SNFO RLL-B 00000000 0 0 0 0 03 SIZE PLVL 04 0001 04 0001 04 0001 04 0001 R D D D D 8NNO 00000000 0 0 0 0 UUU~ 0001 8NN1 RLL-O 00000000 0 0 0 0 03 04 0001 D SRAT RLL-8 00000000 0 0 0 0 03 04 0001 D SGRC RLL-O 00000000 O' 0 0 '0 03 04 0001 D SENR RLL-B 00000000 0 0 0 0 03 04 0001 D CNPS RLL-B 00000000 0 0 0 0 03 04 0001 D RHOB RLL-B 00000000 0 0 0 0 03 04 0001 D CALP RLL-B 00000000 0 0 0 0 03 04 0001 D DEPT SGt~.A SGRB SNFO SNN! SRAT SGRC SENR CALP 9980 . O0 18.57 24 . 18 884.44 3470. D1 -999.25 21 . 37 476.04 9,31 10080 , O0 28,21 41 ,_90 1066,26 3834. O0 -99,9.25 35.06 205.62 8.38 10180.00 28.73 34.54 783.00 .:,4..:,~:. 00 -S, 99. '::'F, 31 64 504.16 9,00 10280. O0 34~03 35.51 '791. O0 3208.00 78.34 34· 77 321.63 8.63 10380,00 -999,2'5. -9£.~9,25 -999,25 ..~c~ 25 128.~:54~, -,::ra,a ~,~ -9~c., 25 -999,25 10480, O0 -999,25 -999,25 -999,25 -999,25 112,06 -_'9.99,25 -999,25 -999,25 RECORD TYPE 129 FILE TRAILER ...?. ................... SKIFI CNPS 821,78 22.88 1080,27 19,99 719,00 28,75 743,00 28.38 -999,25 -999,25 -999,25 -999,25 SNNO RHOB 3.25 3752.29 2.41 3320,00 2.51 3240.00 2.36 -999,25 -999,25 -999.25 -999.25 RECORD LENGTH = FtLNAM,NUM RLL-B ,003 RECORD TYPE 131 62 MAXRL NEXTFLNAME 1024 TAPE TRAILER ...................... RECORD LENGTH = 132 SRVCNM YR/MO/DA TAPENAME RC NXTTAPNM RLL-B 89/01/02 88-11-26 01 COMMENTS: TANDEM TOOLS.TOP TOOL=880.80T T001=658.658 LAYED DOWN AFTER R,U N 5-BAD EWR. RECORD TYPE 133 REEL TRAILER ...................... RECORD LENGTH = 132 SRVCNM 'Y'R/MO/DA REELNAME RC NXTRELNM RLL-B 89/01/02 REEL-O01 Ol COMMENTS: TANDEM TOOLS.TOP TOOL=880.BOT T001=658.658 LAYED DOWN AFTER RU N 5-BAD EMR.
