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178-036
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 18, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 04-14 PRUDHOE BAY UNIT 04-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/18/2024 04-14 50-029-20310-00-00 178-036-0 W SPT 8257 1780360 2064 1795 1797 1801 1799 313 469 481 506 4YRTST P Guy Cook 11/25/2023 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 04-14 Inspection Date: Tubing OA Packer Depth 630 2500 2438 2424IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC231124160644 BBL Pumped:3 BBL Returned:3 Thursday, January 18, 2024 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 178-036-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday, November 8, 2019 P.I. Supervisor SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial BP Exploration (Alaska) Inc. Well 04-14 FROM: Guy Cook PRUDHOE BAY UNIT 04-14 Petroleum Inspector 8257'Tubing Sre: Inspector Reviewed By- P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-14 API Well Number 50-029-20310-00-00 Inspector Name: Guy Cook Permit Number: 178-036-0 Inspection Date: 11/2/2019 Insp Num: mitGDCI91102133828 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-14 TYPe Inj W' TVD 8257'Tubing 984 512 984 2498 983 2450 986 ' 2437 ' PTD 1780360 IType Test SPT Test psi 2064 IA BBL Pumped: 2.2 BBL Returned: 2.6 OA 214 387 392 416 - Interval 4YRTST P/F - P - - - - Notes: Job performed with a triplex pump, bleed trailer and calibrated gauges. Friday, November 8, 2019 Page l of I BA ER PRINT DISTRIBUTION LIST F�UGHES a GE company COMPANY BP Exploration Alaska Inc. WELL NAME 04-14 FIELD Prudhoe Bay Unit COUNTY BHI DISTRICT PRUDHOE BA' Alaska AUTHORIZED BY Frank Schwarzrock EMAIL frank.schwarzrock(tilbhge.com 17 8035 3 125 5 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, 1-132-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. LOG TYPE RPM:PNC3D-CO LOG DATE August 27, 2019 TODAYS DATE September 24, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEt WILL NOT DELIVER TO P.O. Box) PERSON ATTENTION V t 1 BP North Slope. ' FDA. PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. ;Anchorage, Alaska 99505 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico jATO 3-344 1700 G Street Anchorage, AK 99501 3 lExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 (Anchorage, AK 99503 41 State of Alaska -AOGCC Attn: Natural Resources Technician 11 1333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 DNR - Division of Oil & Gas ... Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: David Inter TOTALS FOR THIS PAGE: FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Si (Compass) # OF PRINTS # OF COPIES I# OF COPIES # OF COPIES JJ 4 SEP 2 6 2019 AOGCC co IU 0 1 4 0 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPERATIONS (r i 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shuld&w %t '� i Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Push CBP To Bottom 0 2, Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5, Permit to Drill Number. 178-036 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 1 6. API Number: 50-029-20310-00-00 7. Property Designation (Lease Number): ADL 028324 8. Well Name and Number: PBU 04-14 9, Logs (List logs and submit electronic and printed data per 20AAC25,071): 10, Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9400 feet Plugs measured 9201 feet true vertical 9082 feet Junk measured 9129 - 9186 feet Effective Depth: measured 9201 feet Packer measured 8554, 8632 feet true vertical 8891 feet Packer true vertical 8268, 8344 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2665 13-3/8" 33-2699 33-2699 5380 2670 Intermediate 8233 9-5/8" 31-8264 31-7995 8150 / 6870 5080/4760 Production Liner 6545 7" 2855-9400 2854 - 9082 7240 5410 Perforation Depth: Measured depth: 9035-9249 feet SQNW True vertical depth: 8732-8937 feet JAN 0 2 2019 Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 29-8641 29-8352 4-1/2" Baker S-3 Perm Packer 8554 8268 Packers and SSSV (type, measured and 4-112" TIW HBBP Packer 8632 8344 true vertical depth) No SSSV Installed 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 8050 2 0 Subsequent to operation: 0 0 7005 326 750 14. Attachments: (required Per 20 AAC 25,07025 071, a 25,283) 15, Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ IGSTOR Printed and Electronic Fracture Stimulation Data ❑ ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: NIA Authorized Name: Worthington, Jessica Contact Name: Worthington, Jessica Authorized Title: Well In Engjoo Contact Email: Jessica,Worthington(Mbp.com Authorized Signature: M U41 Date: Contact Phone: +1 907 584 4281 Form 10-404 Revised 04/2017 1,,,✓ (11 '001w364 � Submit Original Only RBDMS'-�/ DEC 19 2016 Daily Report of Well Operations PBU 04-14 A!`TI\/ITVneTG CI IMhAARV ***WELL INJECTING ON ARRIVAL ***(Add Pert) RIG UP SWCP 4522. BEGIN DRIFT FOR CALIPER. 6/6/2018 ***CONT ON 6-7-18 WSR*** ***CONT FROM 6-6-18 WSR***(add pert) TAGGED STICKY BTM @ 9074' SLM WITH A 3.5" CENT & 3" SBLR. RAN PDS 40 ARM CALIPER PER PROGRAM FROM 9056' SLM TO 8400' SLM.-GOOD DATA 6/7/2018 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** CTU #9.1.75" Coil Job Scope: Log, Fluff & stuff Arrive on location. MIRU. Well flowing on arrival 9/5/2018 ***Continue to 9/6/18*** CTU #9. 1.75" Coil. ***Continue from 9/5/18*** Job Scope: Log, Fluff & stuff Continue rig up. Make up GR/CCL BHA and RIH. Log from 8600' to 8400' and paint a white tie-in flag at 8500'. POOH. Make up slim FCO BHA with 1.75" JSN and RIH. Tie-in at the flag and then RIH until a tag at 9137'. Attempt to jet deeper at max rate with both slick 1 % KCI and Schmmo-Be-Gone. Unable to jet deeper and cleaned liner and tubing with remaining SBG, tag believed to be the CBP left in the tubing tail. POOH while FP Coil, RDMO. 9/6/2018 ...Complete... ***WELL FLOWING ON ARRIVAL*** (pert) RAN 10' x 2 7/8" DUMMY GUN, 3" SAMPLE BAILER TO TD @ 9,127' SLM (empty) RAN 10' x 3 3/8" DUMMY GUN, 2.5" LIB TO 9,127' SLM (impression of possible top of tail pipe) 9/23/2018 ***CONT WSR ON 9/24/18*** ***CONT WSR FROM 9/23/18*** (perforating) RAN PDS 40 ARM CALIPER FROM 9,124' SLM TO 8,400' SLM (good data) 9/24/2018 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ***CONTINUED FROM 10-08-18 WSR**(perforating) RAN 3.50" CENT, 2.50" LIB INTO TAIL PIPE @ 9,128' SLM (impression of debris) RAN 4-1/2" X -LINE, X -CATCHER TO X NIP @ 8,596' SLM/ 8,605' MD (+10' correction) RAN 10'x 3" 3 PUMP BAILER 3 TIME TO 9,128' SLM (recovered —10 pieces of rubber, metal marks) RAN 3.25", 3.50" BARBELL, 2.50" LIB TO 9,128' SLM (impression of 1/2" x 2-1/2" arc) RAN 11' x 2.5" PUMP BAILER, SERRATED BOX TAP MULE SHOE 2 TIMES TO 9,128' SLM (recovered 1 piece of rbber, metal marks) RAN 3.805" CENT, 3.80" MAGNET TO 9,128' SLM (recovered packer slip) RAN 10'x 3" PUMP BAILER TO 9,129' SLM (recovered 1 piece rubber, metal marks) RAN 3.805" CENT, 3.80" MAGNET TO 9,129' SLM (no recovery) 10/9/2018 ***JOB IN PROGRESS, CONTINUED ON 10-10-18 WSR*** ***CONTINUED FROM 10-10-18 WSR***(perforating) RAN 3.25" CENT, FLAT MAGNET TO 9,129' SLM (various small metal pieces) 4 RUNS W/ 10'x 3.0" PUMP BAILER W/ 3.70" JUNK BASKET (Flutter cage) TO 9,129' SLM (various small metal pieces) 10/10/2018 ***JOB CONTINUED AFTER WEATHER HOLD*** ***CONTINUED FROM 10-10-18 WSR***(perforating) RAN 10'x 3" PUMP BAILER TO 9,129' SLM (recovered 1 gal schmoo, —6 small pieces of metal) RAN 3.805" CENT, 3.80" MAGNET (recovered 1" diameter thin washer) RAN 3.50" CENT, 3.00" LIB (impression of packer slip) RAN 4-1/2" BRUSH, 2.20" FLAT MAGNET (no recovery) RAN 2.5" HYDROSTATIC BAILER W/ 3.70 JUNK BASKET (flutter cage type) (recovered two small pieces of metal, 1 gal schmoo) 10/11/2018 ***JOB IN PROGRESS, CONTINUED ON 10-12-18 WSR*** Daily Report of Well Operations PBU 04-14 ***CONTINUED FROM 10-11-18 WSR***(perforating) RAN 3.50" x 3.70" BALIEN W/ 3 PRONG WIRE GRAB TO 9129' SLM (metal marks on outside of grabs) RAN 3.64" RELEASABLE SPEAR W/ 1.375"-1.50" GRAPPLE (retrieve 2nd grapple section) RAN 3.65" DECENTRALIZER 3.50" LIB (metal marks @ 6 -o'clock) RAN 10'x 3" PUMP BAILER W/ 3.70" JUNK BASKET (flutter cage type), SD @ 9,130' SLM (recover 12 small pieces of metal) RAN BAITED 3.50" x 3.70" BALIEN W/ FLAT BAR MAGNET TO 9,130' SLM (no recovery) RAN BAITED 3.75" FIXED JAW GRAB TO 9,130' SLM (no recovery, metal marks on bottom of grab) RAN 3.65" DECENT (DC -04), 3.50" LIB TO 9,130' SLM (several impressions, inconclusive) RAN 2.50" HYDROSTATIC BAILER W/ 3.70" JUNK BASKET (flutter cage type) TO 9,130' SLM (recovered 1 qt schmoo, 11 pieces of various metal) RAN 10'x 3" PUMP BAILER W/ 3.65" FLAT BOTTOM FINGER BASKET TO 9,130' SLM (recovered, steel, brass and composite bands) 10/12/2018 ***JOB IN PROGRESS, CONTINUED ON 10-13-18 WSR*** ***CONTINUED FROM 10-12-18 WSR***(perforating RAN PUMP BAILER W/ 3.65" FLAT BOTTOM FINGER BASKET TO 9,130' SLM (no recovery, no metal marks) RAN 3.65" DECENT, 3.25" LIB TO 9,130' SLM (impression of cbp core) RAN BARBELL W/ VARIOUS STARBITS TO CBP @ 9,134' SLM (2 hours total jarring down, no movement) RAN PUMP BAILER W/ 3.70" JUNK BASKET TO 9,130' SLM (recover - 10 pieces of composite, 2 - pieces of metal, 2 set screws) RAN BARBELL W/ VARIOUS STARBITS TO CBP @ 9,134' SLM (6 hours total jarring down, no movement) RAN PUMP BAILER W/ 3.65" FLAT BOTTOM FINGER BASKET TO 9,134' SLM (recover - 3 small pieces of composite) 10/13/2018 ***JOB IN PROGRESS, CONTINUED ON 10-14-18 WSR*** ***CONTINUED FROM 10-13-18 WSR***(perforating) RAN BARBELL W/ VARIOUS STAR BITS TO CBP @ 9,134' SLM (4 hours jarring down, no apparent movement) RAN PUMP BAILER W/ 3.70" JUNK BASKET TO @ 9,130' SLM RAN BARBELL W/ VARIOUS STAR BITS TO CBP TO 9,134' SLM (2 hours jarring down, appears to be making hole into cbp) RAN BARBELL W/ 2.75" BLIND BOX TO CBP @ 9,136' SLM (move 2' in hole) RAN PUMP BAILER W/ 3.70" JUNK BASKET TO @ 9,130' SLM (recovered numerous pieces of element, 4 ceramic slip buttons and composite) (12 hours total jarring down on cbp) 10/14/2018 ***JOB IN PROGRESS, CONT ON 10-15-18 WSR*** ***CONTINUED FROM 10-14-18 WSR***(perforating) RAN PUMP BAILER W/ 3.70" JUNK BASKET TO @ 9,132' SLM (3 large pieces of composite core, 2 chunks of element) RAN 2.85" CENT, 10'x 2.50" PUMP BAILER, 2.60" JUNK BASKET TO @ 9,138' SLM (5 cbp slips, -15 metal bits, hand full of composite core pieces) RAN BARBELL W/ 2.75" BLIND BOX TO 9,138' SLM (-1 foot of travel) RAN BARBELL STAR BIT S3 SD @ 9,134' SLM (move cbp down hole to 9,157' sim, recover 1-3/4" x 3-1/4" composite ring) RAN BARBELL STAR BIT S4 SD TO 9,157' SLM (no movement) RAN BARBELL 2.75" BLIND BOX TO 9,157' SLM, (no movement) RAN PUMP BAILER W/ 3.70" JUNK BASKET TO @ 9,157' SLM (recovered 1/2 gallon of composite flakes) RAN 10'x 3" PUMP BAILER TO 9,157' SLM (recovered 2 tbsp composite flakes) RAN PUMP BAILER W/ 3.70" JUNK BASKET TO @ 9,157' SLM (no recovery) 10/15/2018 ***JOB IN PROGRESS, CONTINUED ON 10-16-18 WSR*** ***CONTINUED FROM 10-15-18 WSR***(perforating) RAN BARBELL W/ 2.63 STARBIT S3 TO 9,157' SLM Oar one hour, no movement) R/D DUE TO HIGH WINDS 10/16/2018 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU 04-14 ***CONTINUED FROM 10-16-18 WSR***(perforating) RAN 4-1/2" X -LINE, X -CATCHER TO X -NIP @ 8,602' SLM/ 8608' MD (+6' correction) DRIFT W/ 16'x 3-3/8" DUMMY GUNS (3.66 od) TO 9,159' SLM / 9,165' MD 10/18/2018 ***JOB COMPLETE / DSO NOTIFIED OF WELL STATUS*** ***JOB STARTED ON 23 -NOVEMBER -2018*** (SLB ELINE: PERF) WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 0/0/0. RU. PT TO 3800 PSI. RUN 1: PERFORATE 9137'- 9152'W/ 3406 POWERJET, 6 SPF, 60 DEG PHASED, 91 SHOTS. CCL STOP DEPTH = 9124.2' RDMO. NOTIFY PAD OP ON DEPARTURE. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 0/0/0. 11/23/2018 ***JOB COMPLETE ON 23 -NOVEMBER -2018*** TREE= 5-1/8" GRAY WELLHEAD = ACTl1ATOR - ____-A------ _GRAY KB. ELEV = 64.0' BF. ELEV = 32.53' 'k 160 KOP = - - 5250' Max Angle = _.___-_._. -----------------9-1'-7'-1"- 28"(cD 7153' _. -_-. ._ _' Datum MD = 9-171._. Datum TV D = _____8800' SS :7 13-3/8" CSG, 72#, N-80 BTC, D = 12.347" I- I 2693' Minimum ID = 3.813" @ 2138' 4-1/2" OTIS X NIPPLE INGS AVERAGE 125 04-14 Wm WHEN ON MFETY NOTES: ?* FH�IWHBBP PKRS HAVE REDUCED TEST PRESSURE LIMITS. MAX ALLOWED PRESSURE IS 2400 PSI *** NOTE: BEWARE- TREE LEANS _tt I 2136' —F4 -1/2 --HES X NP, D = 3.813" 2368' 9-5/8" FOC 2483' 9-5/8" FOC 2866' —i BKR TACK SLV, D = 7.50" 2866' 9-5/8• X 7" ZXP LTP, D = 6.270- 28W 9-5/8" X 7" FLEX LOCK HGR, D = 6270" 7" SCAB LNR, 26#, L-80, BTC -M, 1.8102' 81 Q2' BKR TACK SLV, D = 7.500' 0383 bpf, D = 6.276" 8110' 9-5/8' X 7" BKR H PKR, D = 6.312" 8114_ 9-5/8" X 7" BKR HGR, D = 6.312" 9-5/8" CSG, 47#, N-80 BT&C, D = 8.681 • 8264' 9-6/8" CSG MILLOUT WINDOW 8264' - 8324' (SECTION MILL) 8622' 4-112" HES X NP, D = 3.813" 8643' 1—17" X 4-1/2' BKR S-3 PKR, D = 3-870- _----t_8608' -I4-1/2" HES X NP, D = 3.813" 8630' 4-1/2" FLUTED WLEG, D = 4.00" NOTE NOT STABBED INTO PBR (2' GAP) 4-1/2" TBG, 12.6#, L-80, TCH -0152 bpf, D = 3.958" 8630' 8632' 7" X 4-1/2" TIW HBBP PKR, D = 4.00" 4-1/2" TBG, 12.6#, L-80 XO TO 13-CRTBG 1-- 9129' ***Added tail info back into WBS. Depths are known from correction run made on SL 10/18/18. The tail is on fill and can move deeper with time.*** 4-1/2" TBG, 12.6#, 13 -CR, _0152 bpf, D = 3-958" I 9186' PERFORATION SUMMARY REF LOG- BHCS - AM ON 10/23/92 A NGLE AT TOP PERF: 14'Q9035' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2-7/8" 6 9035- 9056 O 07/17/01 3-3/8" 6 9137-9152 O 11/23/18 2-1/2" 4 9231-9249 C 11/08/92 FBTD 9368' 7" LNR, 26#, NT -80, _0383 bpf, D = 6276" 94OW 9129' ]FISH: CALIPER RAN 12/28/17 SHOWS THE BOTTOM 5T OF 4-1/2" TAIL PPE FELL OFF. (12/29/17) 9144'—�7'MARKER JT (19'} 9166' 4-1 /2' PKR SWS NP, D = 3.813" 9165' FISH: SL PUSHED CBP REMNANTS THAT WERE INSIDE TAP (10/18/18) 9173' 4-1/2" OTIS XN NP, D = 3.725" 9201' 1--1 SAND PLUG (TAGGED 11/13/2001) ?��FISH- FASDRLL DEBRIS (RIG- 11/25/06) & 3-5/8" COPPERHEAD, 2-1/2' OAL(10/28/06) DATE REV BY COWS NTS 01/02/18 GJB/JMD FISH: TAILPIPE FELL DH 06/11/18 MTWJMD CONED WAIN D 09/12/18 JWJMD FOO TO CBP/FD(ED SAFETY NOTE 11/07/18 ZV/JMD ADDED BACK IN TALPPE 11/26/18 NXW/J ADPBRFS (11/23/18) 12/17/18 DD/JMD ADDED BF R EV/EDIT TO CSG DEPTH PRUDHOE BAY UNIT WELL: 0414 PERMT No: 1780360 API No: 50-029-20310-00 SEC 35, T11 N, R1 5E 85' SNL & 466' ENL BP Exploration (Alaska) DATE REV BY COMMENTS 05/09178 ORIGINAL COMPLETION 10/25/92 RIG RED1411-1- / SIDETRACK 11/27/06 N4ES RWO 01/10/07 DCR/ PJC DRLG DRAFT CORRECTIONS 08/20/07 1 CR/PJC SAND PLUG (11/13/2001) 01/10/12 TMIWJMD ADDED H2S SAFETY NOTE • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg DATE: Thursday,November 19,2015 P.I.Supervisor Nap t I SUBJECT: Mechanical Integrity Tests ( ' BP EXPLORATION(ALASKA)INC. 04-14 FROM: Chuck Scheve PRUDHOE BAY UNIT 04-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.-J - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-14 API Well Number 50-029-20310-00-00 Inspector Name: Chuck Scheve Permit Number: 178-036-0 Inspection Date: 11/14/2015 Insp Num: mitCS151115073104 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-14 • Type Inj W' TVD 8257 • Tubing 804 - 804 • 798 - 802 - PTD 1780360 Type Test SPT Test psi 2064 - IA 307 2504 - 2447 - 2431 Interval 4YRTST P/F P OA 585 • 818 - 820 849 - Notes: rcC SCANNED SEP 1 62016, Thursday,November 19,2015 Page 1 of 1 • S +4 + I 14 Q V1 ~ V'. 3 CEI .• TREE= 5-1/8"GRAY Sit(NOTES: 1-126 HEADINGS AVEHAtiE 12b WELLI-EAD= GRAY 04-14 pp EN ON MI.'"FHUTIW HBEP PKRS HAVE ACTUATOR= AXELSON REDUCED TEST PRESSURE LIMITS. MAX KB.ELEV-= 64.0ALLOWED PRESSURE IS 2400 PSI "*"4-1/2" BBEV= 36.0' 2C35HREvOMEHT139:5/81`FAI00cTE:BEWARE-TREE LEANS KOP= 5250' Max Angle= 28"@ 7153' . 2136' —4-1/2"HES X NP,ID=3.813" Datum AU= 9171' Noi Datum ND= 8800'SS i mu "FOC 13-3/8"CSG,72#,N-80,0= 12. 2483' H9-5/8 347" H 2693' k 2855' —BKR TIEBACK SLV,0=7.50' Minimum ID = 3.725" @ 8681' 4-1/2" OTIS XN NIPPLE2 ,,.1 r I, - 2866' —I9-5/8-X 7"ZXP LTP,ID=6.270" r4 I • • 0 4 2884' —19-5/8"X 7"FLEX LOCK LNR HGR,ID=6.270" • • 1 • 0 4 4 • •4 0 I • 0 4 • 0 0 7"SCAB LNR,26#,L-80,BTC-M, -f8102' b 4 lb .0383 bpf,ID=6176" 8102' —E3AKBR TEBACK SLEEVE,D=7.5ar - 2 r 8110' H9-5/8"X 7'BAKB1 H FKR,ID=6.312" I I 8114' —9-5/8*X 7"BAKER LM HGR D.6.312" 9-5/8"CSG,47#,N-80/J/L-95,ID=8.681" — 8264' f--- 9-5/8" CSG MILLOUT WINDOW 8264' -8324' (SECTION MILL) I 8522' —4-1/2"HES X NP,ID=3.813' El 1 1 8543' l— "X 4-1/2"BKR S-3 PKR,0=3.870" 111 8608' —14-1/2"f X NIP,ID=3.813' I 8630' —4-1/2"FLUIUJWLEG,0=4.00" NOTE NOT STABBED INTO PBR(r GAP) 4-1/2"TBG, 12.6#,L-80,Tal,.0152 bpf, ID=-3.958" H 8630' / Z Cl 8632' —7 (4-1/2"ITN I-BBP R(R,ID=4.00" 4-1/2"TBG, 12.64,L-80 X0 TO 13-CRTBG — 8843' I-- I r 8463' 1-14-1/2"PKR SVVS NP,ID=3.813 1 III 8681' __[4:1,2.OTtS XN NIP,ID=3.725" 4-1/2"TBG, 12 6#,13-CR,.0152 bpf,ID=3.958" — 8693' 8694' —4-1/2"—WLEG,0=3,958" PERFORATION SUIWARY REF LOG BHCS-AWS ON 10/23/92 8692' -{ 1D1T LOGGED 10/29/92 ANGLE AT TOP FERF: 14°@ 9035' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Op n/Sq z DATE I 2-7/8' 6 9035-9056 0 07/17/01 I ' ') 2-1/2" 4 9231-9249 C 11/08/92 9144 H7"MARKB3 JT (19 9201' HSAND FLUG(TAGGED 11/13/2001) , Ilk ? —FISH-FASDRLL DEBRIS(RIG-11/25/06)& MID — 9358' 3-5/8"COPPER HEAD,2-1/2'OA L(10/28/06) • .!A. 4 7"LNR,26#,NT-80, .0383 bpf,ID=6.276" — 9400' " DA It REV BY COMMENTS DATE REV BY COMENTS RU)-10E BAY UNIT 05109/78 ORIGINAL COMPLETION WELL: 04-14 10/25192 - RIG REDRILL I SIDETRACK PERMIT Na:9780360 11127/06 N4ES RWO AR No: 50-029-20310-00 01/10/07 DCRI PJC DREG DRAFT CORRECTIONS SEC 35,T11N,RISE 85'SM..&466'EWL 08/20/07 CR/PJC SAND R_UG(11/13/2001) 01/10/12 IMsYJMD ADDED H2S SAFETY 1,0TE BP Exploration(Alaska) I • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, November 14, 2015 7:24 PM To: AK, OPS FS2 OSM; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE:Injector 04-14 (PTD #1780360) AOGCC MIT-IA Passed All, Injector 04-14 (PTD#1780360) passed an AOGCC witnessed MIT-IA on November 14, 2015. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Gw Well Integrity Coordinator Global Wells; Organization cc Wei MAS' 1 1201& Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator@bp.com From: A &C Well Integrity Coordinator Sent: Tuesda , vember 03, 2015 11:30 AM To: AK, OPS FS2 OSNT, S FS2 Field OTL; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Wireline Operations Su ntendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells . pt Engr; AK, OPS EOC Specialists; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Weilitegrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.reqg@alaska.gov) Subject: UNDER EVALUATION: Injector 04-14 (PTD #1780360) Place on Injection for Compliance Testing All, Injector 04-14 (PTD#1780360)was due for compliance testing January 01, 2015 and is now ready to be placed on injection. At the time,the well has been reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, December 19, 2014 10:42 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); Igbokwe, Chidiebere Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer Subject: NOT OPERABLE: Injector 04-14 (PTD #1780360) Well Due for Regulatory Compliance Testing Attachments: image001.png All, Injector 04-14 (PTD #1780360) is due for a four year AOGCC regulatory compliance pressure test on 01/01/2015. The well is waiting on flow line repairs and will not be placed on injection before this date. The well is reclassified as Not . Operable and will be placed on the Quarterly Not Operable Injection Report. Please call with any questions. Kevin Parks (Alternate: Laurie Chnier) BP Alaska - Well Integrity Coordinator Global i/V8lI5 GW Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com SCAtiNED DEC 2 9 2014 Imam',.' 2reject Well History File' Cover .ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / '~ ~""-~,_.~_ Well History File Identifier Organizing (done> RESCUe,' DIGITAL DATA OVERSIZED (Scannable) - Color items: [] Grayscale items: Poor Quality Originals: [] Other: NOTES: [] Diskettes, No. [] Maps: [] Other, No/Type · [] Other items scannable by large scanner BY: BEVERLY BRE~~ SHERYL MARIA LOWELL Project Proofing BY: BEVERLY BREN~~~HERYL MARIA LOWELl_ Scanning Preparation x30= . _ BY: BEVERLY BREN~SHERYL MARIA LOWELL OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DAT E¢~/~/~ ISI~ +.~/ --TOTAL PAGES ~/~5 DATE :~~/~ /S/~.~J. -/ - Production Scanning Stage I PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ' ' YES ! Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: , ' , YES NO ReScanned (individual page [special attention] scanning completed) ., RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 05, 2011 TO: Jim Regg e11 )1/4-(0 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04 -14 FROM: Bob Noble PRUDHOE BAY UNIT 04 -14 Petroleum Inspector Src: Inspector Reviewed By: i� p2 P.I. Supry ` Ya NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 04 - 14 API Well Number: 50 029 - 20310 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110101164832 Permit Number: 178 - 036 - Inspection Date: 1/1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04 -14 ' Type Inj. I W' TVD I 8257 ' IA 60 2500 - 2440 i 2430 - P.T.D 1780360 .TypeTest SPT 1 Test psi 2500 - OA o 0 0 o Interval 4YRTST p/F P - Tubing 1780 1780 1780 1780 Notes: yq(i, fe `t s4 20e) FEB tl r z 01 Wednesday, January 05, 2011 Page 1 of 1 Page 1 of 1 • • Fleckenstein, Robert J (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, October 10, 2007 4:12 PM To: Preble, Gary B (SAIC} Cc: Fleckenstein, Robert J (DOA) Subject: PBU 04-14, (#178-036, 50-029-20310) Hi Gary, I received a call earlier today from Bob Fleckenstein (793-1242). He stated that PBU 04-14 has been injecting gas since March. He says it looks like he needs ay~rrfdry con erting it to a WAG Injector. I checked my records and found that a RWO was performed on this well back in November 2006. 1 reported it on the Sundry at that time as being a Service Well on Water Injection. I have checked the data in the well file to determine if converting it to WAG was part of the plan and there is no reference to that... only that it was/is a Water Injector. I imagine you can take care of this one? Thanks, Terrie ~~.~~~~~:~ .1U_ ~ ~-~ 2011. 10/11 /2007 STATE OF ALASKA l~-/6'~~ ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Q CONVERT TO V1~G ~r Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension ~K~'~'~s~U~ Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~'~ Exploratory 178-0360 3. Address: P.O. Box 196612 Stratigraphic a~ SerVICe ~' 6. API Number: `~ ~`~ Anchorage, AK 99519-6612 50-029-20310-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 64 KB PBU 04-14 8. Property Designation: 10. Field/Pool(s): , ADLO-028324 PRUDHOE BAY Field/ PRUDHOE BRA` Pool 11. Present Well Condition Summary: , h -, ~ ~-' Total Depth measured 9400 feet Plugs (measured) None true vertical 9085.34(~b~ feet Junk (measured) None Effective Depth measured 9358 feet true vertical 9044 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 94# H-40 Surface - 2693' 29' - 109' 1530 520 Surface 2693' 13-3/8" 72# N-80 Surface - 2693' Surface - 2693' 5380 2670 Intermediate 8264' 9-5/8" 47# N-80 Surface - 8264' Surface - 7995' 6870 4760 Liner 1298' 7" 26# NT-80 8102' - 9400' 7846' - 9085' 7240 5410 Scab Liner 5247' 7" 26# L-80 2855' - 8102' 2855' - 7846' 7240 5410 Perforation depth: Measured depth: 9035 - 9056 9231 - 9249 _ True Vertical depth: 8731.32 - 8751.6 8921.08 - 8938.56 _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 8630' 4-1/2" 12.6# 13Cr80 8643' - 8693' Packers and SSSV (type and measured depth) 9-5/8"x7" baker h 8110 7"x4-1/2" bkr s-3 8543' 7"x4-1/2" tiw hbbp pkr 8632' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 13600 1835 Subsequent to operation: 56534 2766 14. Attachments: 15. Well Class after proposed work Copies of Logs and Surveys Run Exploratory ~ Development '~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number pr N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature, Phone 564-4944 Date 10/11/2007 Form 10-404 Revised 04/2006 /"1 R ~ G I N A L Submit Original Only • ~~ ®if! C®~TS~~~ATI®leT COAffirIISSI®1~T S,4R,4F1 PALIN, GOVERAlOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 4RE.009 Ms. Anna Dube, Well Integrity Coodinator ~ ~ ~ ~ (? ~j /~(n- BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 04E.009 (Well PBU 04-14) Dear Ms. Dube: Pursuant to BP Exploration (Alaska), Inc. ("BPXA") request dated April 19, 2007, the Alaska Oil and Gas Conservation Commission ("Commission") hereby cancels Administrative Approval AIO 04E.009, which allows continued water injection. This well exhibited production casing pressure communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has repaired the production casing pressure communication with a rig workover and has successfully performed a passing mechanical integrity test on January 7, 2007. Consequently, Administrative Approval AIO 04E.009 no longer applies to operation of this well. Instead, injection in well PBU 04-14 will be governed by provisions of the underlying Area Injection Order No. 4E. DONE at Anchorage, Alaska and dated May 2, 2007. Alaska Oit and Gas Conservation Commission Daniel T. Seamount, Jr. Cathy P Foerster Cornrnissioner Cor~irriissioner . MEMORANDUM TO: ,~ \ {' "p J, ¡ '" /}/; /'/ \ ¿¡(tn, "-~r.~ . ~ Jim Regg P.L Supervisor FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BA Y UNIT 04·14 Insp Num: mitJCr070 II 70ì3259 ReI Insp Num Packer ~._----,-----'~-'-'-~----~--~-~-"------~ ~~I_~~Type InL_~TVD P. T. . 1780360 TypeTest . SPT ¡ Test psi _~_._~______.L-._~____ Interval IN[TAL P/F P -~--~--------_. ._'---------- Notes 2.4 bbl's pumped for test. Wednesday, January 17,2007 . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 17,2007 SUBJECT: Mechanical Integrity Tests BP EXPLOR/\TION (ALASKA) INC 04·14 PRUDHOE BAY UNIT 04-14 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029·20310-00-00 Permit Number: 178-036-0 \ 1'D-tJ30 Reviewed Bv: P.I. Suprv ;r-~ Comm Inspector Name: John Crisp Inspection Date: 1/7/2007 8256 IA 280 2500 --------~._-~_._-----------_._~-- 2064 OA 670 805 15 Min. 30 Min. 45 Min. 60 Min. i 2440 2440 ! ! . ----~~.- --"-- 800 850 i Depth Pretest Initial ..r----~--..-~--- ---_._._-----------,..---~_.._--------_.._~-~----'--- v./ Tubing! 750 750 750 -~-------- ------------------ ..._---- &rMNED JAN 2 5 2007 -_._---~ 750 Pagc 1 of 1 . STATE OF ALASKA ~ _RECELVED ALA OIL AND GAS CONSERVATION COMalON DEC 1 2 2006 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Performed: AnchOrage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. o Development o Exploratory 178-036 3. Address: o Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20310-00-00 7. KB Elevation (ft): 64' 9. Well Name and Number: PBU 04-14 8. Property Designation: 10. Field 1 Pool(s): ADL 028324 Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9400 feet true vertical 9085 feet Plugs (measured) None Effective depth: measured 9358 feet Junk (measured) None true vertical 9044 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 111' 20" 111' 111' 1530 520 Surface 2693' 13-318" 2693' 2693' 5380 2670 Intermediate 8264' 9-5/8" 8264' 7995' 6870 4760 Production Liner 1298' 7" 8102' - 9400' 7846' - 9085' 8160 7020 Scab Liner 5247' 7" 2855' - 8102' 2855' - 7846' 7240 5410 , ,,'~. r r "["dC'" I " ;,"IIE .: '-' ,- t;L Perforation Depth MD (ft): 9035' - 9249' Perforation Depth TVD (ft): 873' - 8939' 4-112",12.6# L-80 1 13Cr80 8630' Tubing Size (size, grade, and measured depth): RR~?' _ RRQ4' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer; 8543' 7" x 4-112" TIW 'HBBP' packer 8632' 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from 8632'. Run 7" Scab Liner. Cement scab liner with 150 bbls Class 'G' cement (56 cu ft 148 sx). Run new 4-112" completion to 8630'. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Service 181 Daily Report of Well Operations o Exploratory o Development 16. Well Status after proposed work: 181 Well Schematic Diagram o Oil o Gas o WAG oGINJ 181 WINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 306-355 Printed Name Terrie Hubble Title Technical Assistant Signature ~r\.u .di ~ Date 12fr¿f VG;J Prepared By Name/Number: Phone 564-4628 Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 R,BDMS 8Ft. ;¡ 4: 20GB Submit Original Only nR'f: NAJ . Well Events for SurfaceWell - 04-14 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 04 -> 04-14 Date Range: 22/0ct/2006 to 31/0ct/2006 Data Source(s): DIMS, AWGRS Date Description 10/31/2006 T/I/0=250!0/250 Circ-Out, MIT OA PASSED @ 2000 psi. PASSED (Shut In)(Pre-RWO) Pumped 5 bbls Meth, 330 bbls 9.8 ppg NACI Brine, and 2 bbls Meth into TBG with returns from IA to Flowline of DS 4-26. Bullheaded 349 bbls 9.8 ppg NaCI Brine into IA. OA pressured up w/ 0.7 bbls Crude pumped. OA lost 100 psi in 15 min. w! total loss of 140 psi in 30 min. Freeze Protected Flowline of DS 4-26 w! 5 bbls Meth, 15 bbls Crude and 26 bbls Diesel. Final WHP's=O/O/O ** CONT FROM 10-29-06 WSR** FISHED CHEM CUTTER FROM 8655' SLM W/ CENTER SPEAR. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** **WELL SI ON ARRIVAL**{fish chem cut} SAT DOWN @ 8651' SLM W/ 2' STEM, 3.80" CENT, 3.75" LIB. SHOWED NO PIC. ** CONT ONTO 10-30-06 WSR** T/I/O = 200/0/300, temp = SI. MIT-T PASSED to 1000 psi. Pressured tubing to 1000 psi with 1.7 bbls of 60/40 meth. MIT-T lost lost 80 psi in 1st 15 minutes and 10 psi in 2nd 15 minutes for a total of 90 psi during 30 minute test. Bled tubing to 450 psi. Final WHP's = 450/0/300. WELL SHUT IN UPON ARRIVAL. PUNCHED TUBING FROM 8527' - 8529' TO EQUALIZE PRESSURE. CUT 4.5" TUBING AT 8583' WITH 3 5/8" PRS CHEMICAL CUTTER. 13.5" GAS GRAIN GENERATOR USED PER TELEPHONE CALL TO PIPE RECOVERY SYSTEMS. SEVERING HEAD SEVERED FROM TOOL AT THE CHEMICAL PORTS. 1/2 OF SEVERING HEAD, BULL PLUG, AND BOTTOM CENTRALIZER (TOTAL LENGTH APPROX 2.5') LEFT IN HOLE. PRE CUT T/I/O = 200/0/350. FINAL T/I/O = 200/0/350 **JOB COMPLETE** 10/27/2006 WELL SHUT IN UPON ARRIVAL. SET 4 1/2" HES FASDRILL BRIDGE PLUG WITH MID ELEMENT AT 8658'. CCL TO MID ELEMENT = 9.6', CCL STOP DEPTH = 8648.4'. MAX TOOL OD = 3.66". PLUG SET IN JOINT ABOVE THE SWS NIPPLE BELOW THE PACKER. PRE SET WHP = 480, IA = 0, OA = 300. FIRED 12' STRING SHOT WITH TOP SHOT AT 8573'. Tbg. Punch and Chem-Cut are next procedures. ***JOB NOT COMPLETED*** 10/26/2006 T/IA/OA= SI/200/0 Pre-rig well head MIT PPPOT-T Passed PPPOT-IC Passed Sting into test port on tubing head adapter flange to check for trapped pressure. Void was at 0 psi. Cycle all LDS on tubing spool. Operated OK. Test tubing hanger void to 5,000 psi. for 30 minutes. Sting into test void on IC hanger on Gray Gen. II, void was at 0 psi. Cycle all LDS on bottom of tubing spool and the top row on casing spool. All operated OK. Pressure up on test void to 3,500 psi for 30 minutes. T/I/O= 350/0+/200. Temp= SI. WHP's TBG & IA FLs (Pre eline). TBG FL near surface. IA FL @ 60' (3.5 bbls). ***WELL S/I ON ARRIVAL*** (ssv shut) DRIFTED TBG W/ 3.70" CENT & SAMPLE BAILER OUT TBG TTL TO 8750' SLM ***WELL LEFT S/I*** Digital Wellfile Events Source Well AWGRS 04-14 A'NGRS 04-14 10/30/2006 AWGRS 04-14 10/29/2006 AWGRS 04-14 10/28/2006 AWGRS 04-14 10/28/2006 AWGRS 04-14 AWGRS 04-14 AWGßS 04-14 10/25/2006 AYiSLRS 04-14 10/22/2006 Page 1 of 1 . http://digitalwellfile.bpweb.bp.comIW ellEventslHomelDefault.aspx 12/12!2006 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 11/14/2006 08:00 - 14:30 6.50 RIGD P PRE Prep Cellar for move. Scope down and lower Derrick. Prep Pipe shed, Pits, and Camp for move. Wait on Security. 14:30 - 20:30 6.00 MOB P PRE Move Rig and support equipment from NGI-Pad to DS 04. 20:30 - 21 :00 0.50 MOB P PRE Position loads on Pad and release Trucks. 21 :00 - 00:00 3.00 MOB N WAIT PRE Wait on DSM to finish building-up area around well slot. 11/15/2006 00:00 - 02:00 2.00 MOB N WAIT PRE DSM completed well slot prep. 02:00 - 04:00 2.00 RIGU P PRE Lay Rig Mats, Herculite and Cellar Mats. 04:00 - 04:30 0.50 RIGU P PRE Attempt to spot Sub Base with Sow. Unable to get Sub backed up on height mats. 04:30 - 06:00 1.50 RIGU N WAIT PRE Wait on Cat to push Sub Base over Well. 06:00 - 14:00 8.00 RIGU P PRE Spot Sub and Pits up on Rig Mats. 14:00 - 19:30 5.50 RIGU P PRE RU Lines to Pits and Tiger Tank. Begin taking on 9.8 ppg brine into the Pits. Keep steam on brine to warm up. Accepted Rig at 15:00 hrs. 19:30 - 20:30 1.00 WHSUR P DECOMP PU Lubricator and pull BPV with Drill Site Maintenance reps. About 100 psi on the Tubing beneath BPV. 20:30 - 21 :00 0.50 KILL P DECOMP RU to Tree to circulate well bore. Pressure test lines to 3,500 psi - good. 21 :00 - 00:00 3.00 KILL P DECOMP Open well to begin circulation. Tbg pressure = 60 psi, IA pressure = 60 psi. Taking returns to Tiger Tank. Break circuation at a rate of 4 bpm /120 psi with gas returns. Getting fluid returns with 27 bbls away. Increase rate to 5 bpm /1,200 psi with 200 psi on the IA. Stop with -150 bbls away to swap returns to the Pits, getting 9.8 ppg returns. Continue pumping with a rate of 5 bpm /1,800 psi with 80 psi on the IA. Pumped a total of 590 bbls of hot 9.8 ppg brine. Shut down and monitor well: Tbg pressure = 0 psi, IA pressure = 0 psi. 11/16/2006 00:00 - 00:30 0.50 WHSUR P DECOMP RU Lubricator and set TWC with Drill Site Maintenance Techs. 00:30 - 02:30 2.00 WHSUR P DECOMP Pressure test TWC from below to 1,000 psi. Due to the 9 5/8" having a Cretaceous leak @ 5,665', was not able to get a test for 10 mins. Achieved injection pressure of 1,000 psi with a rate of 3.5 bpm - pumped a total of 16.5 bbls. Test from above to 3,500 psi for 10 mins charted - OK. RD Test Equipment and suck out fluid from Tree. 02:30 - 04:30 2.00 WHSUR P DECOMP PJSM. ND Tree and Adapter Flange with Cameron reps. Inspect Hanger Threads, they are in good shape. The top threads are 5 7/8" RH Acme. 04:30 - 06:00 1.50 BOPSU P DECOMP NU 13 518" BOPE. 06:00 - 00:00 18.00 RIGD X DECOMP Not able to center Rig over BOP Stack. Attempt to align using turn-buckles and Sub-base Jacks. No joy. The Tree was crooked during initial rig up and had difficulty getting an accurate center measurement of Wellhead for spotting the Sub. Suck 9.8 ppg brine out of Pits into vac truck and standby to re-Ioad Pits once we are rigged up again. Break modules apart. Lower and scope Derrick. Back Sub and Pits Modules out. 11/17/2006 00:00 - 04:00 4.00 RIGU X MISC DECOMP Re-position Rig over Wellhead and re-spot Mats to accomodate changes. Spot Sub and Pipe Shed first. Work on spotting Pits. 04:00 - 06:00 2.00 RIGU X MISC DECOMP Raise and scope Derrick. Rig mud lines back up and rig back onto well. 06:00 - 07:00 1.00 RIGU X MiSe DECOMP Continue to rig mud lines. Re-fill Pits with 9.8 Ib/gal Brine. 07:00 - 11 :30 4.50 RIGU X MISC DECOMP Remove Kill Line from BOP Stack. Nipple-down and set back Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 BOP Stack. Level Sub Base one more time. Nipple-up BOP Stack. Everything looks good...finally! 11 :30 - 19:00 7.50 DECOMP Rig up test equipment. Test BOPE per BPIAOGCC requirements at 250/4000 psi. Test Hy-Dril at 250/3500 psi. Test was witnessed by AOGCC Inspector...C. Sheve. 19:00 - 19:30 DECOMP RD Test Equipment. Blow down and set back Kelly. 19:30 - 20:30 DECOMP RU Lubricator and pull TWC with Cameron and Drill Site Maintenance reps. Lay down Lubricator. 20:30 - 21 :00 0.50 PULL P DECOMP Make up Double-Spear per BFT Rep. 21 :00 - 22:30 1.50 PULL P DECOMP Plant Spear in Hanger. Pull 50K to ensure Grapples bit - OK. BOLDS with Cameron reps. Pull on Hanger. At 175K the Hanger popped free and weight fell to 11 OK. Pull Hanger and Tubing not free. Work up and down several times and still not free. Max pull reached was 205K (-100K over). Continue to work between 125K and 175K for 30 mins - No Joy. Utilizing (a) tubing stretch chart for 4 1/2" Tubing and (b) free point equation, they both indicate that we are not cut, anchor point is the Packer. Release Spear and lay down. 22:30 - 00:00 1.50 PULL P DECOMP Consult with Anchorage Engineering and decide to re-cut 4 1/2" Tubing with E-line. Call out E-line Truck. Will be chemically cutting +1- 2' below original cut. PJSM. ND Flow Riser. NU Shooting Flange. 11/18/2006 00:00 - 01 :30 1.50 PULL C DECOMP Wait on E-line Truck to arrive on location. Clear and clean Rig Floor. 01 :30 - 02:30 1.00 PULL C DECOMP E-line on location. Discuss job with Field Engineer. Spot unit outside of Pipe Shed. PJSM with Schlumberger and Nabors personnel. Discuss chemical cut job and hazards associated with chemical and wireline. 02:30 - 05:00 2.50 PULL C DECOMP RU Schlumberger E-line to Shooting Flange. Make up Chemical Cutter Toolstring with E-line reps. 05:00 - 06:00 1.00 PULL C DECOMP RIH with Chemical Cutter Assembly on E-line. 06:00 - 09:00 3.00 PULL C DECOMP Continue RIH with Chemical Cutter. Log tie-in pass (note: did not see any indication of the original) cut at 8,583'). Position Chemical Cutter at 8,585'. Fire cutter. Saw no indication the Cutter fired on surface. POOH and stop at 200' for PJSM. Fininh POOH. Lay down tools. Cutter appeared to have fired ok. Have SWS stand-by. 09:00 - 09:30 0.50 PULL C DECOMP Plant Spear. Work Tubing up to 200K. Tubing still not free. 09:30 - 10:30 1.00 PULL C DECOMP Work to free Spear. It is believed that the upper grapple is hung-up in the Tubing Hanger. (due to the Wellhead being tilted to starboard, the grapple continues to bite to the high side when we pull on the Spear). 10:30 - 13:30 3.00 PULL C DECOMP Pick-up Jars, 1 ea 4 3/4" Drill Collat, and Accelulator. Continue to work to release Spear. No-Joy. 13:30 - 15:30 2.00 PULL C DECOMP Lay down 4 3/4" Drill Collar. Pick-up 61/4" Drill Collar. Second Jar lick the Spear came free. Lost half of grapple in hole. Discuss plan forward with Anchorage Engineer. 15:30 - 16:30 1.00 PULL C DECOMP PJSM with Schlumberger E-line on Jet Cutter. RU E-line. 16:30 - 18:30 2.00 PULL C DECOMP RIH with Jet Cutter Assembly on E-line. RIH slowly due to uncertainty of where the upper half of the grapple may be in the Hole. 18:30 - 19:00 0.50 PULL C DECOMP Log into position with Jet Cutter on E-line. Find collars at 8,009' and 8,049'. Decide to cut @ 8,220'. Jet cut fired with good Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 11/18/2006 18:30 - 19:00 0.50 PULL C DECOMP surface indication (lost 100 Ibs of tension). POH with E-line. 19:00 - 20:00 1.00 PULL C DECOMP Set back E-line equipment on Rig Floor, have them standby. ND Shooting Flange and NU Flow Riser. 20:00 - 21 :00 1.00 PULL C DECOMP PU Spear Assembly. Plant Spear in Tubing Hanger. The Hanger came free with 175K, fell back down to 100K. Continue POH with Hanger - she is free! UW = 100K. Call out Control Line Spooling Unit. Recovered small piece of the grapple that broke off, still missing about half of a grapple in the Hole. 21 :00 - 21 :30 0.50 PULL C DECOMP RD Schlumberger E-line. Fill up hole with 37 bbls down the backside, fluid level- 500'. 21 :30 - 22:00 0.50 PULL C DECOMP RU Schlumberger Spooling Unit. 22:00 - 00:00 2.00 PULL C DECOMP POH with existing 4 1/2" Tubing Completion laying down in the Pipe Shed 1 x 1. At 00:00 hrs, out with SSV Nipple. Recovered 50 full Joints of Tubing. Recovered all Stainless Steel Control Line. Recovered 23 Control Line Bands and can see 1 in the Tubing Spool. According to Tubing Tally dated 10/24/92 there should have been 28 Bands. 11/19/2006 00:00 - 05:00 5.00 PULL C DECOMP Continue POH with existing 4 1/2" Tubing. Recovered a total of 205 full Joints of 4 1/2" Tubing. The jet cut looked really clean and not flared out. The cut joint length = 10.54'. 05:00 - 06:00 1.00 PULL C DECOMP RD 4 1/2" Handling Equipment. RU 3 1/2" DP Handling Equipment. Clear and clean Rig Floor. 06:00 - 06:30 0.50 PULL C DECOMP Service Rig. Inspect Derrick. Check PVT alarms. 06:30 - 08:00 1.50 FISH C DECOMP Install Wear Bushing. Make-up BHA #1 as follows: ICTO spear w/3.947 grapple, Bumper Sub. Oil Jar, 9 ea Drill collars, Acc Jar, Pump-Out-Sub. 08:00 - 13:00 5.00 FISH C DECOMP Trip in with BHA #1 with 3 1/2" Drill Pipe 1x1 from Pipe Shed (249 Jts). 13:00 - 14:00 1.00 FISH C DECOMP PUW = 125K. SOW = 116K. Pick-up Kelly (PUW w/Kelly = 129K). Tag 41/2" jut cut stump at 8,220-ft. Plant Spear. Jar on Fish to free at 8,585-ft (last chemical cut). Working and jaring Fish at 225K. No-Joy. Rotated TIW Latch Assembly out of TIW Packer (after several attempts). Gained 6K string weight. 14:00 - 17:00 3.00 FISH C DECOMP Circulated bottoms-up at 5.0 bpm 11,250 psi. Final circulating pressure = 800 psi. 17:00 - 21 :00 4.00 FISH C DECOMP TOH with 4 1/2" Tubing Fish standing back DP in the Derrick. 21 :00 - 22:00 1.00 FISH C DECOMP Spear on surface with 4 1/2" Tubing Fish. RD 3 1/2" Handling Equipment. RU 4 1/2" Handling Equipment. Continue TOH with Joints of 4 1/2" Tubing. Joint #8 had the Tubing Punch Holes in them, all open and looked clean. Joint #9 had one hole where one of the chem cuts was shot. Unable to find the 2nd cut on the Tubing. Suspect the 1st chem cut did nothing to the pipe and the 2nd chem cut made the hole in the pipe. The Joint itself was bent right at the hole that was made by the chemical cutter. The distance from the top collar to the hole was 21.60'. Recovered a total of (1) cut Joint, 9 full Joints of 41/2" Tubing, (3) Pup Joints, (1) X Nipple and (1) Latch Assly. 22:00 - 23:00 1.00 CASE P TIEB1 Clear and clean Rig Floor. RD 4 1/2" Handling Equipment. RU 3 1/2" Handling Equipment. 23:00 - 23:30 0.50 CASE P TIEB1 PU and MU 7" RBP per Halliburton rep on (9) 4 3/4" Drill Collars. 23:30 - 00:00 0.50 CASE P TIEB1 TIH with 7" RBP on 3 1/2" DP from Derrick. Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 11/20/2006 00:00 - 04:00 4.00 CASE P TIEB1 Continue RIH with 7" RBP on 31/2" DP. 04:00 - 06:00 2.00 DHB P TIEB1 In with 83 stands (249 Joints) of DP. UW = 122K, DW = 117K. PU 24.95' Pup Jt. RIH 18' and begin setting process. Set 7" RBP mid-element @ 8,181'. The top of the Plug is @ 8,177'. Dump 1,400# of sand on top of RBP. 06:00 - 07:30 1.50 DHB P TIEB1 Finish dumping sand. Flush Drill Pipe with Charge Pump. 07:30 - 08:00 0.50 DHB P TIEB1 Attempted to re-enter 7" Liner to tag sand. However, had trouble getting inside the the Running Tool. Calculated TOS -8,120', 08:00 - 11 :30 3.50 DHB P TIEB1 Trip-out with 3 1/2" Drill Pipe and Running Tool. Lay down Running Tool. 11 :30 - 12:30 1.00 CASE P TIEB1 Make-up BHA #2 as follows: Polish Mill, XO, Boot Basket, Boot Basket, Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, 9 ea Drill Collars. 12:30 - 15:00 2.50 CASE P TIEB1 Trip-in with BHA #2 and 31/2" Drill Pipe. 15:00 - 16:00 1.00 CASE P TIEB1 Pick-up Kelly. PUW = 127K. SOW = 120K. RTW = 125K. Pump Rate = 4.5 bpm/1000 psi. RPMs = 60. Tag top of 7" Tie-Back Liner at 8,102'. MiII/Polish with 2 - 3 K down weight. Polish of 7" Tie-Back with no problems. 16:00 - 17:30 1.50 CASE P TIEB1 Mix and pump a hi-vis sweep at a rate of 4.5 bpm I 950 psi. Continue circulating all the way around at a rate of 6 bpm I 1,600 psi. 17:30 - 22:00 4.50 CASE P TIEB1 Blow down and set back Kelly. Lay down 2 single Joints of DP. TOH with BHA #2 standing back DP in the Derrick. 22:00 - 22:30 0.50 CASE P TIEB1 On surface with BHA #2. Inspect Mill and the tattle-tells showed we bottomed out on the Liner Top. Break down and lay dowb BHA components with Baker rep. Call out Baker Packer rep. 22:30 - 00:00 1.50 CASE P TIEB1 Clear and clean Rig Floor. RD 31/2" DP Handling Equipment. RU 7" Handling Equipment. 11/21/2006 00:00 - 01 :00 1.00 CASE P TIEB1 Continue preparing to run 7" Scab Liner. 01 :00 - 06:00 5.00 CASE P TIEB1 TIH with 7", 26#/ft L-80 BTC-M Scab Liner. Baker Lok'd the 6' Baker ported seal Assembly with the Landing Collar Joint. Made up Joints to triangle mark. Utilizing (1) free-floating centralizer on every other Joint until we reach Joint #50. Stopped every 5 Joints to fill with 9.8 ppg brine. 06:00 - 06:30 0.50 CASE P TIEB1 Service rig. Inspect derrick. Check PVTs. 06:30 - 10:30 4.00 CASE P TIEB1 Con't to RIH wI 7" scab liner. Total = Shoe Track + 126 Jts. 10:30 - 11 :30 1.00 CASE P TIEB1 MIU liner hanger. RID 7" tools. RlU 3 1/2" handling equip. 11 :30 - 13:30 2.00 CASE P TIEB1 RIH wI scab liner on 3 1/2" DP. Fill every stand. 13:30 - 15:30 2.00 CASE P TIEB1 Space out seal stem in tie-back recepticle. Verify No-Go wI pressure @ 8102'. Pick-up Liner until pressure dropped-off. Mark Landing Jt. Lower Liner back to No-Go mark. Install cementing head. Landing Collar at 8,070'. Top of Liner Top Packer at 2,866'. (Holes in Casing at 5,665'). 15:30 - 00:00 8.50 CASE N WAIT TIEB1 Wait on cementing equip & trucks. Vac Trucks became available and on locaton @ 2000 hrs. Wait on cementers. Had to test re-blended cement. 11/22/2006 00:00 - 02:00 2.00 CASE N WAIT TIEB1 Wait on cementers. 02:00 - 04:30 2.50 CASE P TIEB1 Cementers arrived on location. Unload cement into silo. Spot in trucks & begin rigging up equip. 04:30 - 06:00 1.50 CASE P TIEB1 Con't to spot equip & prep to cement liner. 06:00 - 06:30 0.50 CASE P TIEB1 Operations and PJSM with all. Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11!27!2006 Spud Date: 10/19/1992 End: 11/27/2006 11/22/2006 06:30 - 10:00 3.50 CEMT P TIEB1 Perform final walk-thru. Prime up with Fresh Water. Fill Wellbore and establish circulation 2.5 bpmfi50 psi with 32 bbls Fresh Water. Pressure test lines at 4,600 psi. Good. Start Class "G" Cement at 16.0 Ib/gal, 5.6 bpm/1175 psi. Continue pumping 15.7 - 15.91b/gal Cement at 5.5 - 5.7 bpm. At 145 bbls Cement away Density = 15.84 Iblgal 5.7 bpm/600 psi. End Cement with a total of 150 bbls with a final density of 14.1 Ib/gal on last bbl. Drop Drill Pipe Dart. Bring SWSIDS pump back on line with 9.8 Ib/gal Brine for displacement. Expected to see OPD hit Wiper Plug with 19.0 bbls displaced. However saw no pressure spike (Cement was still falling downhole). Continued with displacement. 100 bbls away = 6.0 bpm/520 psi. 150 bbls away = 5.6 bpm/1300 psi. 200 bbls away = 2.6 bpm/1700 psi. Bumped Plug with a total of 222 bbls pumped at 2.6 bpm/1890 psi. Plug down at 09:48 hrs. Increase pressure to 4,000 psi. Plug latched and holding. Bleed pressure. No-Go Seal Stem. Set Flex-Lock Packer with 3,000 psi. Set ZXP Liner top Packer with 4,200 psi (saw Pusher Tool stroke). Bleed off pressure. Rotate Setting Tool out with 22 turns. 10:00 - 10:30 0.50 CEMT P TIEB1 Reverse circulated 3 Orill Pipe volumes. Recovered an estimate 5 bbls of cement. 10:30 - 11 :30 1.00 CEMT P TIEB1 Rig down circulating equipment. Break-out and lay-down cement head. Lay down space-out Pups. Clear floor. 11 :30 - 13:00 1.50 CEMT P TIEB1 Trip-out with 31/2" Drill Pipe and Setting Tool. Lay down Tool. 13:00 - 16:00 3.00 CEMT P TIEB1 Wait on Lab test. Prep Wellhead to change-out 9 5/8" Pack-off. Compressive strenght at 16:00 hrs = 550 psi. 16:00 - 17:30 1.50 CEMT P TIEB1 Pressure test liner top to 2000 psi for 30 min. Charted same. Tested good. RID test equip. 17:30 - 18:00 0.50 WHSUR P TIEB1 P/U running tool & pull Wear Bushing. Ud same. Bleed off OAP. 18:00 - 20:00 2.00 WHSUR P TIEB1 P/U pulling tool. RIH & engage top pack-off & Pull to floor. RIH & engage lower pack-off & pull same. Ud running tool. Note: Wellhead crooked. 20:00 - 00:00 4.00 WHSUR P TIEB1 M/U hydraulic running tool & Lower pack-off. RIH & set pack off. UD running tool. M/U upper pack-off & attempt to set. Having trouble seating pack-off. POOH, inspect & gauge pack-off. Re-run same. would not seat. M/U pack-off on stand of DCs. RIH & slack off all weight. Rock & wobble stand & pack-off finally seated. Orient & align pins. RILDS. Pressure test pack -off to 5000 psi, Tested Good. RID equip & clear floor. 11/23/2006 00:00 - 00:30 0.50 WHSUR P TIEB1 P/U runninjg tool. RIH & set Wear Bushing. RILOS. UD running tool. 00:30 - 01:30 1.00 CASE P TIEB1 P/U & M/U BHA #3 as follows: 6" Bit, 2 Boot Baskets, 7" Casing Scraper, Bit Sub, Bumper Sub, Oil Jars, 9 * 4 3/4" OCs. TL = 312.55'. RIH wI same. 01 :30 - 04:30 3.00 CASE P TIEB1 RIH wI BHA # 3 to clean out liner on 3 1/2" DP. 04:30 - 06:00 1.50 DRILL P TIEB1 Tag up @ 8053'. P/U kelly & break circulation. Drill cement from 8053' to 8064' P/U Wt = 130K, SIO Wt = 117K, Rot Wt = 124K. 70 RPMs, 4 BPM @ 800 psi, WOB 2-5K. Torq 2.5-3.5K ft-Ibs. 06:00 - 10:00 4.00 DRILL P TIEB1 Contine to drill out Shoe Track from 8,064' to 8,107'. Fell Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 11/23/2006 06:00 - 10:00 4.00 DRILL P TIEB1 throught. Tagged top of sand at 8,124'. Wash dow to 8,130'. 10:00 - 11 :30 1.50 DRILL P TIEB1 Pump a 40 bbl Hi-Vis sweep at 6.0 bpm/1700 psi. until clean. 11 :30 - 12:00 0.50 DRILL P TIEB1 Monitor Well. Set back Kelly. Lay down 3 singles. 12:00 - 13:30 1.50 DRILL P TIEB1 Cut and slip drilling line. 13:30 - 15:30 2.00 DRILL P TIEB1 Trip-out with 3 1/2" Drill Pipe and BHA. 15:30 - 16:00 0.50 DRILL P TIEB1 Lay down BHA #3. 16:00 - 17:00 1.00 EVAL P TIEB1 OAP = 750 psi. Bleed to O. Pressure test 9 5/8" Casing and 7" Scab Line. Pressure up to 4,000 psi. OAP = 500 psi. Bleed OA to O. Record Casing pressure test at 4000 psi/30 minutes. Lost 100 psi. OAP = 0 psi. 17:00 - 17:30 0.50 EV AL P TIEB1 Make-up BHA #4 as follows: Reverse Circulating Junk Basket, 2 Boot Baskets, Bit Sub, Bumper Sub, Oil Jars, 9 . 4 3/4" DCs. TL = 317.19'. 17:30 - 18:00 0.50 EVAL P TIEB1 RIH wI BHA #4 on 3 1/2" DP. 18:00 - 18:30 0.50 EVAL P TIEB1 Check PVTs. Inspect derrick. Crew Change. 18:30-21:00 2.50 EVAL P TIEB1 RIH wI BHA #4 on 3 1/2" DP. 21 :00 - 21 :30 0.50 EVAL P TIEB1 Tag up on fill @ 8131' Drill 1-2" dry. Kick in pump & wash from 8133 to 8143'. Pumped 5.8 BPM @ 2000 psi. 60 RPMs, Torq 2800 ft-Ibs. P/U 134K, SIO Wt = 115K, Rot Wt = 121 K. 21 :30 - 23:00 1.50 EVAL P TIEB1 Circulate bottoms up. Pumped 440 bbls. Recovered some sand & gelled fish eyes. Set back kelly & blow down lines. 23:00 - 00:00 1.00 EVAL P TIEB1 POOH WI BHA #4. Stand back 31/2" DP. 11/24/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Con't to POOH & stand back 31/2" DP. 03:00 - 04:00 1.00 CLEAN P DECOMP Break out RCJB. Completely packed off wI cement & metal cuttings. Clean out Boot Baskets. M/u BHA to re-run. 04:00 - 06:00 2.00 CLEAN P DECOMP RIH wI BHA #5, RCJB assy. 06:00 - 06:30 0.50 CLEAN P DECOMP Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 07:30 1.00 CLEAN P DECOMP Continue TIH wih RCJB re-run. 07:30 - 08:00 0.50 CLEAN P DECOMP Pick-up Kelly. PUW = 134K. SOW = 121K. 60 RPMs. 140 Amps. 6.0 bp/1900 psi. Wash through Sand from 8,143'- 8,160'. 08:00 - 09:30 1.50 CLEAN P DECOMP Circulate bottoms up until clean. Recovered 20/40 mesh Sand. 09:30 - 12:00 2.50 CLEAN P DECOMP Set back Kelly. Trip out with 3 1/2" Drill Pipe and BHA #4. 12:00 - 12:30 0.50 CLEAN P DECOMP Lay down BHA#4. RCJB was empty. Both Boot Baskets contained a little 20/40 Mesh Sand. 12:30 - 14:00 1.50 BOPSU P DECOMP Pull Wear Bushing. Install Test Plug. Rig up test equipment. PJSM. 14:00 - 18:00 4.00 BOPSU P DECOMP Perform weekly BOPE Test per BP/AOGCC requirements at 250/4000 psi. Test Hy-Dril at 250/3500 psi. State's right to witness the test was waived by L. Grimaldi. 18:00 - 18:30 0.50 BOPSU P DECOMP Check PVTs. Inspect derrick. Crew change. 18:30 - 19:00 0.50 BOPSU P DECOMP Finish BOP test. Tested kelly, LP 250 psi, HP 4000 psi. 19:00 - 20:00 1.00 BOPSU P DECOMP RID test equip. Pull test plug. Install Wear Bushing. 20:00 - 20:30 0.50 PULL P DECOMP M/U Halliburton retreiving tool. RIH to retreive RBP. 20:30 - 23:00 2.50 PULL P DECOMP RIH wI Halliburton retreiving tool on 4 3/4" DCs & 31/.2" DP. 23:00 - 00:00 1.00 PULL P DECOMP Tag up on fill @ 8163'. RlU to reverse out sand. Rverse out sand from 8163 to 8177'. 4 BPM @ 700 psi. reversed 3 tubing volumes. Recovered black viscous gritty material & sand. 11/25/2006 00:00 - 00:30 0.50 PULL P DECOMP Engage RBP. Release & verify plug is free. Allow RBP to equalize. 00:30 - 02:00 1.50 PULL P DECOMP Circulate bottoms up. Pump 5 BPM @ 1230 psi. 02:00 - 05:30 3.50 PULL P DECOMP POOH wI RBP & stand back 31/2" DP. 05:30 - 06:00 0.50 PULL P DECOMP Break out, UD RBP & reteiving tool. Recovered RBP Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 11/25/2006 05:30 - 06:00 0.50 PULL P DECOMP complete. 06:00 - 07:00 1.00 PULL P DECOMP Service Rig. Inspect Derrick. Check PVT Alarms. Wash floor. 07:00 - 08:00 1.00 PULL P DECOMP Make-up BHA as follows: 35/8" Junk Mill, Bit Sub, 4 Jts 2 7/8" PAC Drill Pipe., XO, XO, 7" Casing Scraper, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, 9 ea 4 3/4" Drill Collars. 08:00 - 10:30 2.50 PULL P DECOMP Trip-in with BHA #5 and 31/2" Drill Pipe from Derrick. 10:30 - 11 :00 0.50 PULL P DECOMP Pick-up 8 ea. 3 1/2" Drill Pipe singles from Pipe Shed. Pick-up Kelly. Tag top of TIW Packer at 8,632' 11 :00 - 13:00 2.00 PULL P DECOMP PJSM. Swap Wellbore over to Sea Water at 5.0 bpm/1500 psi. 13:00 - 14:30 1.50 CLEAN P DECOMP PUW = 144K. SOW = 116K. RTW = 112K. 60 RPMs. 150 Amps. Pump Rate = 5.0 bpm/1500 psi. Entery TIW Packer at 8,632'. Continue down to FasDrill Plug at 8,658'. Drill Plug. Fell free. Chase out of Tubing Tail at 8,694'. Pick-up one more joint. End of Mill at 8,733' and Casing Scraper at 8,604'. Well on slight vacuum. 14:30 - 18:00 3.50 CLEAN P DECOMP Circulate bottoms-up. Gas to surface. Continue to circulate until returns were clean. 18:00 - 18:30 0.50 CLEAN P DECOMP Check PVTs. Inspect derrick. Crew Change. Monitor losses 44 BPH. 18:30 - 19:30 1.00 CLEAN P DECOMP Prep to POOH. Monitor well get 1 hr loss rate, 45 BPH. 19:30 - 00:00 4.50 CLEAN P DECOMP POOH & UD 3 1//2" DP. 11/26/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP POOH & LD 3 1/2" DP. 01 :30 - 02:30 1.00 CLEAN P DECOMP Break out & UD BHA. 02:30 - 03:00 0.50 WHSUR P DECOMP P/U running tool. Pull Wear Bushing. UD running tool. 03:00 - 03:30 0.50 RUNCO RUNCMP Clear & clean rig floor. 03:30 - 05:30 2.00 RUNCO RUNCMP RIU 4 1/2" handling equip. RIU Torq Turn equip. PJSM 05:30 - 06:00 0.50 RUNCO RUNCMP Start running Completion. Pick-up Tailpipe Assembly and Packer. 06:00 - 06:30 0.50 RUNCO RUNCMP Service Rig. Inspect Derrick. PVT Alarms checked. 06:30 - 17:30 11.00 RUNCO RUNCMP Continue running 41/2" Completion. Had no trouble entering the 7" Liner top at -2,866 with the WLEG or the Packer. P/U 206jts & tagged up 7' in. 8632'. Torq turned all connections to 3850 ft-Ibs. Used Jet Lube Seal Guard on all threads. 17:30 - 18:00 0.50 RUNCO RUNCMP Performed space out of string. Ran 204 jts + 19.71' pup jt. WLEG @ 8629.67'. "X" Nipple wI RHC @ 8608'. Baker S-3 Packer @ 8542'. "X" Nipple @ 8522'. "X" Nipple @ 2136'. 18:00 - 18:30 0.50 RUNCO RUNCMP Crew Change. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 RUNCO RUNCMP Install 19.71' pup jt & M/U hanger & landing jt. 19:00 - 22:00 3.00 RUNCO RUNCMP attempt to land hanger could not get alignment pin lined up. Much difficulty wI crooked wellhead. Pull hanger & re-dress. Align hanger & land completion. RILDS. P/U Wt = 103K, SIO Wt = 95K. 22:00 - 00:00 2.00 RUNCO RUNCMP Tie onto annulus & bullhead wI 200 bbls of 120 degree seawater. Begin bullheading 260 bbls of 120 degree inhibited seawater. Pumped 3 BPM @ 530 psi. 11/27/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP Con't to bullhead 120 degree inhibited seawater into annulus. Pumped 3 BPM @ 530 psi. Pumped 260 bbls. 01 :00 - 03:00 2.00 RUNCO RUNCMP RIU Hot Oilers. Pressure test lines to 2500 psi. Bullhead 112 bbls of diesel down annulus. pumped 2 BPM @ 700 psi. Final Pump pressure 1000 psi.. Close in annulus. 03:00 - 04:00 1.00 RUNCO RUNCMP Bullhead 100 bbls of 120 degree seawater down tubing. 3 BPM Printed: 12/4/2006 10:08:42 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 04-14 04-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/14/2006 11/27/2006 Spud Date: 10/19/1992 End: 11/27/2006 23:00 - 00:00 1.00 WHSUR P @ 520 psi. Attempt to back out XO from hanger. Would not come free. BOLDS. Pull hanger to floor. Re-dress hanger. Noticed a bend in 4 1/2" pup below hanger right @ the coupling from attempting to tighten landing jt. Notified engineer of need to change out pup. RUNCMP Crew change. Inspect derrick. Check PVT alarms. RUNCMP Change out 4 1/2" pup below hanger & torq same. Land hanger & completion. RILDS. RUNCMP Wait on addtional diesel to freeze protect & fill annulus. RlU hot oilers & pump 32 bbls of diesel down tubing. Drop rodlball & allow to fall. Pressure up & set S-3 packer. Test to 4000 psi for 30 min. Chart same. Bleed off tubing pressure to 1500 psi & SI. Fill annulus wI diesel & work air out of annulus. Pressure up on annulus to 4000 psi & test for 30 min. Charted same. Bleed off annulus pressure, then bleed off tubing pressure. RID test equip. Blow down lines. RUNCMP Attempt to set BPV. Would not set. Pull plug. Inspect & check plug. RIH & set BPV in wellhead profile. Attempt to set blanking plug. No good. Drain stack & set blanking plug. Pressure up & test plug to 1000 psi for 10 min. OK. RUNCMP Drain stack. Blow down lines. Remove flow nipple. RUNCMP Crew change. Inspect derrick Check PVT alarms. RUNCMP N/D BOPE & DSA. RUNCMP N/U adapter flange & X-mas tree. Test hanger void 5000 psi, 30 min. Tested good. Fill tree wI diesel. Test tree, wing valve & swab valve leaking. Grease same. Test tree to 5000 psi. Tested Ok. Pull blanking plug. RUNCMP Secure well. Clean cellar. Release Rig @ 2400 hrs. 06:00 - 06:30 06:30 - 08:00 0.50 1.50 08:00 - 13:30 5.50 13:30 - 17:00 3.50 WHSUR P 17:00 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 23:00 1.00 WHSUR P 0.50 WHSUR P 1.50 BOPSU P 3.00 WHSUR P Printed: 12/4/2006 10:08:42 AM · 04-14 FROM DRLG - DRAFT TREE = WELLIHEJ.\D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 4-1/16" 5M GRAY AXELSON 64.0' 36.0' 5250' 28 @ 7153' 9171' 8800'SS 113-3/8" CSG, 72#, N-80, ID = 12,347" I Minimum ID = 3.725" @ 8681' 4-1/2" OTIS XN NIPPLE 7", 26#/ft, L-80 BTC-M scab liner Fully cemented. Ported seal stem stung into Baker tie-back sleeve at 8102'md. 6" Flutted WLEG. 4" ID, 2-ft above A<r. w!2' GAPINTBG (NOT TOUCHING) 14-1/2" TBG, 12.6#, L-80, TC· ID = 3.958" I 8512' 19-5/8" CSG, 47#, N-80IJ/L-95, ID = 8.681" 1-1 8264' NOTE: 4-1/2" 12.6# TBG IS L-80 TO 8643' & 13-CR TO 8693' 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID= 3.958" I 8693' ÆRFORA TION SUMMARY REF LOG: BHCS - A WS ON 10123/92 ANGLEATTOPÆRF: 14 @ 9035' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 9035 - 9056 0 07/17/01 2-1/2" 4 9231 - 9249 0 11/08/92 I PBTD I 9358' 17" LNR, 26#, NT-80, .0383 bpf, ID = 6.276" 9400' DATE 05/09/78 10/25/92 02/05/04 04/20/06 06/24/06 11/27/06 REV BY COMMENTS ORIGINAL COM PLETION RIG REDRlLL I SIDETRACK MJAITLP SETMCXVALVE TEL/PJC SET PXN PLUG@ 8681' TEl.../PJC PULL MCX@ 8681' (1/15/05) LHlPAG DRLG DRAFT CORRECTIONS DATE REV BY ~NOTES: ***BEWARE-TREELEANS*** *** ME TB6*** 2136' -i4-1/2" HES "X" NIP, ID = 3.813" 2358' -t 9-5/8" FOC I 2483' -t 9-5/8" FOC I 2855' 2866' 2884' 8102' 8110' 8114' 8522' 8542' 8608' BAKER TIEBACK SLEEVE, ID = 7.500" 9-5/8" X 7" BKRZXPPKR, ID - 6.312" 9-5/8" X 7" BAKER LNR HGR BAKER TIEBACK SLEEVE, ID = 7.500" 9-5/8" X 7" BAKER H PKR, ID - 6.312" 9-5/8" X 7" BAKER LNR HGR, ID = 6,312" 4-1/2" HES "X" NIP, ID - 3.813" 7" X 4-1/2" BKR S3 PKR, ID = 3.875" 4-1/2" HES "X" NIP, ID = 3,813" 8632' -t7" X 4-1/2" TIW HBBP PKR, ID - 4.000" 8663' -14-1/2" PARKER SWS NIP, ID - 3.813" -14-1/2" OTIS XN NIP, ID = 3.725" I -14-1/2" TUBING TAIL WLEG , H ELMD TT LOGGED 10129/92 9144' - 7" MARKER JT (19') I COMMENTS PRUDHOE BA Y UNfT WELL: 04-14 ÆRMfT No: "1780360 API No: 50-029-20310-00 SEC 35, T11 N. R15E 85' SNL & 466' EWL BP Exploration (Alaska) FRANK H. MURKOWSKI, GOVERNOR ALASfiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, Well n::¡me PBU 04-14 Sundry Number: 306-355 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditiotls~of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's pet.role~_.r;n field -inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Ccmmission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this2 day of November, 2006 EncL ~ 11- ð 0 STATE OF ALASKA ALAS Oil AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 \\ 1( 0 ~ 1. Type of Request: Suspend 0 Repair well 0 Pull Tubing 0 P.O. Box 196612, Anchorage, Alaska 99519-6612 II Ii Other 0 Perforate 0 Stimulate 0 Re-enter Suspended 5. Permit to Drill Number: Exploratory 0 Service 0 11S-0360 6. API Number: 50-029-20310-00-00 8. Well Name and Number: PBU 04-14 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: Perforation Depth MD (ft): 9035 - 9249 / Packers and SSSV Type: 9-5/S" BKR H PKRI 7" TIW HBBP PKRl4-1/2" CAM BAl-O SSSV 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch [] 15. Estimated Date for / Commencing Operations: Novemb,(2yd06 17. Verbal Approval: Date: Commission Representative: 12. Total Depth MD (ft): 9400 Casing Structural Conductor Surface Intermediate Production Liner No 0 10. KB Elevation (ft): 11. Field/Pool(s): 64 Prudhoe Bay Field I Prudhoe Bay Pool PRESENT WEll CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): ADl 028324 Total Depth TVD (ft): 9085 length Size 9044 Plugs (measured): None Junk (measured): None 9358 TVD Burst Collapse 83 " 94# H-40 111 2666 13-3/8" 72# N-80 2693 8238 9-5/1'1" 47#NaO/J/l95 8264 1298 7" 26# NT-SO 8102 - 9400 Perforation Depth TVD (ft): Tubing Size: 111 2693 1530 5380 520 2610 8731 - 8939 5-1/2"14-1/2"/4-112" Packers and SSSV MD (ft): l-SOI l-SOI 13Cr-80 8110'/8632'/2031' 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 7995 7846 - 9085 Tubing Grade: 68701815018150 4760/50S0/50S0 S160 1020 Tubing MD (ft): 271 S6431 8694 Service [] Abandoned WDSPL o o 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Name Title Drilling Engineer Signature Phone 564-5743 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity o ST Other: BOP Test ~ Mechanical Integrity Test ~ o P to 4000 ý' ~ . V~w1~J . Subsequent Form Required: l f!) - 4;0 Approved by: Form 10-403 Revised 06/2006 Date 10/31/2006 Prepared By Name/ Phone # DeWavne R. Schnorr 564-5174 Sundry Number: Location Clearance o APPROVED BY Date: Submit in D.uplicate 4-14i Rig Workover Scope of Work: Pull 4-%" completion, run and cement new 7" scab liner, run 4-%" L-80 "stacker-packer" completion. MASP: 2500 psi Well Type: Injector Estimated Start Date: November 22,2006 P k re- ri(3 ø: reD war : S 1 Drift for 4-1/2" chemical cutter/composite bridae-plua to WlEG. E 2 Set FasDriU·~icJge-plug in chrome pup joint just above the SWS nipple below the packer - set depth =þ~md. Chemical cut @ -8593'. (Ref: 2ES's 10/24/92 tubing summary). Chem cut desiredt '. e in the middle of the 151 full ¡oint above the packer. F 3 Circulate well with 9.8 ppg NaCL and FP w/ d~el cap the cut. PC leak so unable to CMIT. MITOA to 2000 psi. Bleed WHP's to 0 psi. 0 4 PPPOT-T and -IC. Function all LOS. 0 5 Set a BPV in the tubing hanger. Remove the well house & flow line. Level the pad as needed for the rig. Proposed Procedure ~.' 1. MIRU. NO tree. NU BOPE with 3-1/2" x 6" VBR pipe rams. Pressure test t(4"ÓOQ,PSi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulg~1I to clean seawater through the cut. 2. Pull and LD 4-%" tubing string to the cut. 3. Set retrievable bridge plug at -8150' MD. 4. Run and fully cement new 7" scab liner to -2900'md. 5. Run 4-%" L-80 stacker packer completion with Baker S-3 packer. Position packer at -8515' MD. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 4000 psi. Freeze protect to 2200' MD. 8. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum NO = 28 @ 7153' 9171' 8800' SS !IiIII S : fHUTIW HBBP PKRS HAVE REDUCED TEST PRESSURE LIMITS. MAX AllOWED PRESSURE IS 2400 PSI. 6/26/00- CAliPER SHOWED TBG IN FAlRfPOOR CONDITION. 27' 2031' 2358' 2483' 8643' NOTE: 4-1/2" 12.6# TBG IS L-BO TO 8643' & 13-CR TO 8693' 8693' PERFORA TION SUMMA RY REF LOG: BHCS - AWS ON 10/23/92 ANGLE A T TOP PERF: 14 @ 9035' Note: Refer to Production DB for historical perf data pn/Sqz DATE o 07/17/01 4 0 11/08/92 9358' COMMENTS 9-5/8" CSG MlllOUT WiNDOW 8264' - 8324' 8613' 8632' 8663' 9144' PRUDHOE BA Y UNIT WELL: 04-14 PERMIT No: ii>1780360 API No: 50-029-20310-00 SEC 35, T11 N, Ri5E 85' SNl & 466' EWl BP~iol1 (Alaska) TREE = WB..LHEAD = ACTUA TOR = KB. ElEV = BF. ElEV = KOP= Max Angle = Datum MD = Datum NO = 4-1116" 5M GRAY AXElSON 64.0' 36.0' 5 2S@7 9171' SSOO' SS 4-14i Proposed 14-112" TBG, 12.6#, l-SO, TC-IIID = 3.95S" 113-3/8" CSG, 72#, N-80, 10 = 12.347" I Minimum 10 = 3.725" @ 8681' 4-1/2" OTIS XN NIPPLE 7", 26#/ft, L-80 BTC-M scab liner Fully cemented. Ported seal stem stung into Baker tie-back sleeve at 8102'md. 19-5/S" CSG, 47#, N-80/J/L-95, ID = 8.681" I Unique Machine Overshot, L-80 14-1/2" TBG. 12.6#, L-80 X 13-CRXO I NOTE: 4-1/2" 12.6# TOO IS l-80 TO 8643' 8. 13-CR TO 8693' 14-1/2" TBG,12.6#,13-CR, .0152 bpf, 10= 3.958" I 8693' PERFORA TION SUMMARY REF LOG: BHCS - A WS ON 10/23/92 ANGLEATTOPPERF: 14 @ 9035' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/S" 6 9035 - 9056 0 07/17/01 2-1/2" 4 9231 - 9249 0 11/0S/92 I PBID I 9358' 17" LNR, 26#, NT-80, .0383 bpf, ID = 6.276" 9400' DATE 05109/18 10125192 02/05/04 04/20/06 06/24/06 DATE REV BY REV BY COMMENTS ORIGINAL COMPLETION RIG REDRlLL 1 SIDETRACK MJAITlP SETMCXVALVE TEl/PJC SET PXN PLUG @ 8681' TEl/PJC PULL MCX@ 8681' (1/15/05) -2100' 2358' 2483' § 8102' 8110' 8114' § .,. BAKER TIEBACK SLEEVE, ID = 7.500" 9-518" X 7" BKR ZXP PKR, 10 = 6.312" 9-5/8" X 7" BAKER LNR HGR BAKER TIEBACK SLEEVE, ID = 7.500" 9-5/8" X 7" BAKER H PKR, ID = 6.312" 9-5/8" X 7" BAKER LNR HGR, 10 = 6.312" 4-1/2" HES "X" NIP, 10 = 3.813" 7" X 4-1/2" BKRS3 PKR, 10= 3.875" 4-1/2" HES "X" NIP, ID = 3.813" 8613' H4-1/2" PARKER SWS NIP, ID = 3.813" 8632' -17" X 4-1/2" TIW HBBP PKR, ID = 4.000" I 8663' -14-1/2" PARKERSWS NIP,ID= 3.813" -14-112" OTIS XN NIP, 10 = 3.725" I -14-1/2" TUBING TAIL WlEG I H ElMO TT LOGGED 10/29/92 I 9144' -I7"MARKERJT (19') I COMMENTS PRUDHOE BA Y UNIT WB..l: 04-14 PERMIT No: "1780360 API No: 50-029-20310-00 SEC 35, T11 N, Ri5E 85' SNL & 466' EWl BF' Exploration (Alaska) RE: MIT - PBU 04-14 (4/30/2006) e e Hi Jim, As requested, here is the MIT form for the MIT-T and MIT-OA on well 04-14 (PTD #1780360). Please let us know if you have any questions. Thank you, Anna Dube -----Original Message----- fc"'. ¡ v~·_,,, ') '7 From: James Regg [mailto:jim regg@admin.state.ak.us]~Çf1~N~".!¡;~· (. ( Sent: Thursday, June 15, 2006 3:50 PM To: NSU, ADW Well Integrity Engineer Cc: Bob Fleckenstein; Winton GAubert Subject: MIT - PBU 04-14 (4/30/2006) The application for recently approved AIO 4E.009 included reference to passing MITT and MITOA completed 4/30/2006. Copies were not provided with the application, and I do not find the MIT results in our files. Please provide electronic copies of MITs. Thank you. Jim Regg AOGCC Content-Description: MIT PBU 04-14 04-30-06.xls PBU 04-14 04-30-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 6/20/2006 10: 16 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS 04 04/30106 Anna Dube C6 '" tJ J (Q \\ Packer Depth Pretest Initial 15Min. 30 Min. Well 104-14 I Type Inj. I N TVD I 8,343' Tubing 3001 2,500 2,390 2,350 Interval I 0 p.T.D.11780360 I Typetest I P Test psi! 2086 Casing 420 420 420 420 P/FI P Notes: MIT - T to 2500 psi for request for AA. OAO 10 0 0 Well 104-14 Type Inj. I N I TVD 8,343' Tubing 280 280 280 280 Interval I 0 P.T.D.11780360 I Type test I P I Test psil 2086 Casing 420 420 420 420 P/FI P Notes: MIT-OA to 2500 psi for request for AA. OA 0 2500 2390 2360 Weill I Type Inj.1 TVD I Tubing Interval I P.T.D. I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interva" P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing I Interval P.T.D.I / Type test I Test psil Casing P/F Notes: OA I TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU 04-14 04-30-06-1.xls C, J FRAAIK K. ~9ilURKO~SKI, GOt/ERfNOR ADVIINISTR.ATIVE APPROVAL, 4E.Oa9 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99~ 19-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 RE: PBU 04-14 (PTD 17$-036) Request for Administrative Approval Dear YIr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 04-14. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBL' 04-14 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in PBU 04-14 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform an annual MIT - OA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; i NIr. Steve Rossberg June 6, 2006 Page 2 of 2 4 • ~2 BPxA shall perform an annual tiIIT - T to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; ~. BPXA shall limit the well's Oa pressure to 1000 psi; b. UC ~A Shall lIrRrl~IIIat~1y Sllul. In e tiv~ii ana ~iotli~; tii~ ~Wt,ti, i~ uzccc i~ uiiy change in the well's mechanical condition; and ?. after well shut in due to a change in the well's mechanical condition, aOGCC approval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 P1~1 on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. d dated June 6, 2006. ;'1 ~~~1 ~~ , Cathy P~fFoerster Comrnlssloner .~ `~ 5 ;~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: SCHMOO-B-GONE Operation shutdown_ Stimulate _X Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X 4. Location of well at surface 82' FNL, 4812' FEL, Sec. 35, T11N, R15E, UM At top of productive interval 1268' FNL, 4012' FEL, Sec. 35, T11N, R15E, UM At effective depth 1323' FNL, 4060' FEL, Sec. 35, T11 N, R15E, UM At total depth 1345' FNL, 4070' FEL, Sec. 35, T11N, R15E, UM (asp's 713299, 5951801) (asp's 714135, 5950641) (asp's 714088, 5950584) (asp's 714079, 5950562) Perforate _ Other _ 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 04-14 9. Permit number / approval number % 178-0360 10. APl number 50-029-20310-00 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9400 feet Plugs (measured) 9085 feet Tagged PBTD @ 9298' ELM COR (07/04/2001) Effective depth: measured true vertical Casing Length Conductor 111' Surface 2663' Intermediate 8234' Liner 1298' 9298 feet Junk (measured) 8986 feet Size Cemented Measured Depth True Vertical Depth 20" 320 sx AS II 131' 131' 13-3/8" 5700 sx AS II 2693' 2693' 9-5/8" 1000 sx Class 'G' 8264' 7995' 7" 240 sx Class 'G' 8102' - 9400' 9085' Perforation depth: measured Open Perfs 9035'- 9056', 9231'- 9249' true vertical Open Perfs 8732' - 8752', 8921' - 8939' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) RECEIVED JUN 0 5 2002 5-1/2", 17#, L-80, Tubing @ 26'. 4-1/2", 12.6# L-80 Tubing @ 8643'. 4-1/2", 12.6#, 13-CR TT @ 8694' 7" x 4-1/2" TIW HBBP Packer @ 8632'. 4-1/2" Camco Bal-O SSSV Nipple @ 2031'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 05/22/2002 Subsequent to operation 06/05/2002 OiI-Bbl Representative Dailv Average Production or Injection Data Gas-Mcr Water-Bbl 18046 16454 Casing Pressure Tubing Pressure 1813 1677 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil __ Gas __ Suspended _ Service PW INJECTOR 17. I hereby certify that the foregoing is true, and correct to the best of my knowledge. ~,~/~ ~~~ Title: Techical Assistant DeWayne R. Schnorr Date June 06, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 04-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/29/2002 SCMOO-B-GONE--SBG: SSSV C/O OR STROKE 05/29/2002 SCMOO-B-GONE--SBG: SCMOO-B-GONE 05/31/2002 SCMOO-B-GONE--SBG: SSSV C/O OR STROKE 06/02/2002 ANN-COMM (AC-EVAL AND REPAIR): AC-CHIT TXIA; AC-EVAL; AC- MONITOR 06/04/2002 ANN-COMM (AC-EVAL AND REPAIR): AC-MITI'A; AC-MITOA EVENT SUMMARY O5/29/O2 DRIFT TBG W/4.5 BRUSH & 3.85 GR TO 1100'. WELL RETURNED TO OPERATOR FOR INJECTION. (UNABLE TO SET ISSSV DUE TO SCHMOO) O5/29/O2 PUMPED 170 BBLS SCHMOO-B-GONE FROM FREEZE PROTECT SKID, THROUGH FLOWLINE, AND DOWN TUBING. 05/31/02 SET 4 1/2" BTDP-1 (SER # HWS-96) @ 2012' SLM. TTL SPRING LOOKED GOOD. NO CLOSURE TEST. WELL ON VACUUM. RDMO. GIVE WELL BACK FOR INJECTION. 06/02/02 SHUT-IN MI INJECTION DUE TO T x IA COMMUNICATION. 06/04/02 MIT IA TO 2500 PSI , PASSED 1300/2430/250 MIT OA , PASSED 1300/625/1930. FLUIDS PUMPED BBLS 1 DIESEL USED FOR SURFACE EQUIP PRESSURE TEST (1 TEST) 6 50/50 METHANOL WATER 170 SCHMOO-B-GONE 171 TOTAL Page 1 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 06/03/2002 WELL-NAME: PRUDHOE BAY UNIT 04-14 FIELD/POOL: PRUDHOE BAY, PRUDHOE 1982 JAN METH DAYS OIL WTR GAS 1982 TOTALS OIL API: 029-20310-00 LEASE: ADL0028324 OPERATOR: BP EXPLORATION (ALASKA) INC SALES CD - 60 ACCT GRP - 204 FINAL STATUS: DEV i-OIL CURRENT STATUS: SER 1WINJ ** OIL PRODUCTION ** FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 24 31 7 27 31 21 8 30 31 92,500 71,766 61,846 12,314 55,554 61,818 37,446 14,488 62,867 71,334 92 461 898,261 95,782 227,604 60,466 251,712 294,805 168,855 72,887 293,731 513,794 541,933 WATER 553 GAS 2,877,897 CUM OIL 541,933 CUM WATER 553 CUM GAS 2,877,897 1983 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING SHUT-IN FLOWING DAYS 31 28 31 25 27 23 31 11 18 6 3 OIL 68,354 43,120 100,348 48,732 52,945 42,437 53,386 11,157 54,902 4,897 6,644 WTR 503 399 728 113 190 22 GAS 561,406 391,303 . 892,580 495,312 528,182 434,964 631,327 122,251 477,109 49,581 54,383 1983 TOTALS OIL 486,922 WATER 1,955 GAS 4,638,398 CUM OIL 1,028,855 CUM WATER 2,508 CUM GAS 7,516,295 1984 JAN FEB ~ MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH' FLOWING FLOWING ~FLOWING FLOWING SHUT-IN FLOWING FLOWING FLOWING FLOWING SHUT-IN SHUT-IN SHUT-IN DAYS 12 27 20 OIL 29,317 61,719 59,320 WTR GAS 287,023 366,281 439,744 1984 TOTALS OIL 180,961 WATER 2 5,795 42,356 FIELD/POOL: PRUDHOE BAY, PRUDHOE 2 3 2 2 10,618 9,308 2,494 2,390 77,637 64,275 16,951 15,619 GAS 1,309,886 CUM OIL 1,209,816 CUM WATER 2,508 CUM GAS 8,826,181 SALES CD - 60 ACCT GRP - 204 FINAL STATUS: DEV 1-OIL CURRENT STATUS: SER 1WINJ ** ENHANCED RECOVERY ** FEB MAR APR MAY JUN JUL AUG SEP OCT 1984 JAN METH DAYS OIL WTR GAS 1984 TOTALS OIL WATER 1,016,240 GAS CUM OIL CUM WATER 1,016,240 CUM GAS 1985 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC NOV DEC WTR INJT WTR INJT 11 31 312,777 703,463 METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 8 10 31 31 30 31 30 8 OIL WTR 697,729 680,103 800,057 603,579 197,192 2,267 857,793 789,973 736,807 652,640 715,554 226,697 GAS 1985 TOTALS OIL WATER 6,960,391 GAS CUM OIL CUM WATER 7,976,631 CUM GAS 1986 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 7 31 23 31 30 31 31 30 31 30 31 OIL WTR 113,714 818,179 635,452 773,353 723,700 789,610 737,925 673,572 868,313 929,472 1,023,199 GAS 1986 TOTALS OIL WATER 8,086,489 GAS CUM OIL CUM WATER 16,063,120 CUM GAS ALASKA INDIVIDUAL WELL PRODUCTION AS OF 06/03/2002 1987 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL WTR 967,476 884,071 968,294 1,045,031 1,041,332 1,017,210 968,614 1,054,319 1,039,900 1,022,432 1,089,523 790 193 GAS 1987 TOTALS OIL WATER 11,888,395 GAS CUM OIL CUM WATER 27 951,515 CUM GAS 1988 JAi~ FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL WTR 1,030,966 884,391 1,041,792 841,209 1,113,293 963,683 927,607 1,052,145 981,139 749,605 905,826 972 278 GAS 1988 TOTALS OIL WATER 11,463,934 GAS CUM OIL CUM WATER 39 415,449 CUM GAS 1989 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 30 17 31 30 31 30 31 OIL WTR 910,003 603,924 815,959 785,902 904,015 901,134 456,477 979,175 940,570 965,489 1,058,303 1,025 903 GAS 1989 TOTALS OIL WATER 10,346,854 GAS CUM OIL CUM WATER 49 762,303 CUM GAS 1990 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL WTR 1,070,125 1,001,991 1,163,340 940,988 861,527 872,613 872,422 797,408 522,624 927,587 914,946 972 776 GAS 1990 TOTA3~S OIL WATER 10,918,347 GAS CUM OIL CUM WATER 60,680,650 CUM GAS 1991 JAN FEB MAR APR MAY JLIN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 28 31 31 30 31 30 31 OIL WTR 984,076 844,617 440,826 650,172 906,284 499,984 353,998 381,415 574,588 289,468 208,130 235 995 GAS 1991 TOTALS OIL WATER 6,369,553 GAS CUM OIL CUM WATER 67 050,203 CUM GAS 1992 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 29 31 30 30 30 26 26 30 4 ~.~0~ 29 OIL WTR 130,507 125,988 79,456 93,470 63,302 51,761 172,769 133,285 115,680 17,452 19,901 106 900 GAS 1992 TOTALS OIL WATER 1,110,471 GAS CUM OIL CUM WATER 68 160,674 CUM GAS 1993 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 23 28 31 30 31 30 31 23 24 31 13 23 OIL WTR 66,440 88,996 126,563 102,302 108,213 100,776 108,900 61,006 71,862 105,489 35,571 89,179 GAS 1993 TOTALS OIL WATER 1,065,297 GAS CUM OIL CUM WATER 69,225,971 CUM GAS ALASKA INDIVIDUAL WELL PRODUCTION AS OF 06/03/2002 1994 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 26 27 31 28 29 31 30 31 OIL WTR 292,263 335,057 391,974 383,194 316,035 340,038 446,721 484,235 477,639 563,209 460,871 547,570 GAS 1994 TOTALS OIL WATER 5,038,806 GAS CUM OIL CUM WATER 74,264,777 CUM GAS 1995 JAi~ FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT SHUT-IN SHUT-IN SHUT-IN WTR INJT DAYS 31 28 31 23 28 30 6 1 27 OIL WTR 530,287 457,418 294,103 169,925 401,971 492,907 95,806 4 346,519 GAS 1995 TOTALS OIL WATER 2,788,940 GAS CUM OIL CUM WATER 77,053,717 CUM GAS 1996 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 29 31 30 31 30 31 28 30 31 30 31 OIL WTR 311,173 284,417 291,319 321,437 394,590 286,812 330,340 341,148 446,639 436,404 475,670 552,818 GAS 1996 TOTALS OIL WATER 4,472,767 GAS CUM OIL CUM WATER 81,526,484 CUM GAS 1997 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL WTR 597,123 548,300 548,797 586,911 485,172 401,906 449,695 405,841 278,515 260,589 150,562 180,215 GAS 1997 TOTALS OIL WATER 4,893,626 GAS CUM OIL CUM WATER 86,420,110 CUM GAS 1998 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 12 21 31 31 30 31 30 31 OIL WTR 372,322 330,354 308,752 315,386 97,647 132,746 285,473 315,465 242,866 291,752 342,043 219,270 GAS 1998 TOTALS OIL WATER 3,254,076 GAS CUM OIL CUM WATER 89,674,186 CUM GAS 1999 JAN FEB MAR APR MAY 07JN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 31 30 31 29 30 31 30 31 OIL WTR 284,728 325,127 410,063 400,104 686,661 416,463 497,874 231,405 442,853 487,512 471,142 486,858 GAS 1999 TOTALS OIL WATER 5,140,790 GAS CUM OIL CUM WATER 94,814,976 CUM GAS 2000 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT SHUT-IN WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 29 29 8 27 31 18 30 31 30 31 OIL WTR 482,060 455,448 445,580 290,364 407,426 504,510 251,494 537,758 543,125 479,841 494,138 GAS 2000 TOTALS OIL WATER 4,891,744 GAS CUM OIL CUM WATER 99,706,720 CUM GAS ALASKA INDIVIDUAL WELL PRODUCTION AS OF 06/03/2002 2001 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 29 31 24 31 31 29 31 30 31 OIL WTR 480,422 395,383 466,155 328,933 73,389 131,411 355,893 216,617 178,409 154,844 534,277 596,221 GAS 2001 TOTALS OIL WATER 3,911,954 GAS CUM OIL CUM WATER 103,618,674 CUM GAS 2002 JAN FEB MAR APR MAY METH WTR INJT WTR INJT WTR INJT WTR INJT DAYS 31 28 31 30 OIL WTR 678,989 620,574 591,153 528,489 GAS 2002 TOTALS OIL WATER 2,419,205 GAS JUN JUL AUG SEP OCT NOV DEC CUM OIL CUM WATER 106,037,879 CUM GAS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X AdPerfs/SandbacldMud Acid Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__ 4. Location of well at surface 82' FNL, 4812' FEL, Sec. 35, T11N, R15E, UM At top of productive interval 1268' FNL, 1268' FWL, Sec. 35, T11N, R15E, UM At effective depth 1303' FNL, 1230' FWL, Sec. 35, T11N, R15E, UM At total depth 1345' FNL, 4070' FEL, Sec. 35, T11N, R15E, UM ~sp~ 713299, 5951801) (asp's 714135, 5950641) ~sp~ 714099, 5950605) (asp's 714079, 5950562) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 111' Surface 2629' Production 8200' Liner 1298' 9400 feet Plugs (measured) 9085 feet 9201' feet Junk (measured) 8892 feet Size Cemented 20" 320 sx AS II 13-3/8" 5700 sx AS II 9-5/8" 1000 sx Class 'G' 7" 240 sx Class 'G' 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name ~~.., ~_~ '~ Prudhoe Bay Unit 8. Well number 04-14i 9. Permit number/approval num~ 178-036 '"'~ ~ 10. APl number 50-029-20310 11. Field / Pool Prudhoe Bay Oil Pool Tagged PBTD @ 9201' (11/13/2001). Measured Depth True Ve~icalDepth 175' 175' 2693' 2693' 8264' 7995' 8102'-9400' 9085' Perforation depth: measured Open Perfs 9035'- 9056', Perfs Covered with Fill 9231'- 9249' true vertical Open Perfs 8731' - 8751', Perfs Covered with Fill 8921' - 8939' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 TBG @ 26'. 4-1/2" 12.6# L-80 TBG @ 8632', 4-1/2" 12.6# L-80 TT @ 8692'. Packers & SSSV (type & measured depth) 7" x 4-1/2" TIW HBBP PACKER @ 8632'. 4-1/2" Camco BAL-O SSSV Nipple @ 2031'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/14/2001 Subsequent to operation 11/12/2001 OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 19499 5586 Casing Pressure Tubing Pressure 1805 1926 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended _ Service WAG INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: DS 4 Surveillance Engineer Form 10-404 Rev 06/15/88 · Date November 15, 2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 04-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/04/2001 07/17/2001 09/10/2001 10/11/2001 11/13/2001 PERF(ADD-PERF)-DRIFT/TAG PERF(ADD-PERF)' ADPERF SCHMOO B GONE: SBG TREATMENT IPROF: INJECTION PROFILE MISC-NRWO: SAND DUMP/MUD ACID 11/14/2001 MISC-NRWO: SANDBACK/ACID EVENT SUMMARY 07/04/01 DRIFT TO 9298'ELM W/2 7/8"DUMMY GUN. RATHOLE=49'. PUT BACK ON INJECTION.NOTIFY DSO 07/17/01 COMPLETED ADPERF. SHOT 21' INTERVAL (9035' - 9056') 09/10/01 PUMP SBG TREATMENT ACCORDING TO PROCEDURE. 10/11/01 IPROF, LOG FROM 8950'-9270', (NO TAG), SPINNER PLUGGING BELOW BOTTOM PERFS, STOP COUNTS AT 9000' AND 9100', ESTIMATE INJ RATE 16,500 BPD, WHP 1150 PSI INJECTING. SPLITS 100% INTO 9231'-9249' & 0 % INTO 9035'-9056'. ***DSO TO PUT ON INJ*** 11/13/01 MIRU DS CTU #3. RIH WITH 3" BDN. TAG AT 9301' CTMD. WASH SUMP WITH 1% KCL. LAY IN 3400# 20-40 RIVER SAND. TAG AT 9185' CTMD. RETAG AT 9182'. PT TO 2000 PSI. BLED OFF 200 PSI IN 5 MINUTES. RETAG SAND PLUG AT 9203' (UP WT). POH, PU 3" SJN AND DCV'S. RIH. RECONFIRM TAG AT 9201'. PUMP 10 BBLS 7.5% HCL, DISPLACE WITH KCL/NH4CL WTR. (SPEARHEAD BREAKDOWN). INITIAL INJECTIVITY = 1 BPM AT 2000 PSI. PUMP THE FOLLOWING ACID TREATMENT: 25 BBL NH4CL 90 BBL HCL 51 BBL HCL/HF 150 BBL NH4CL FINAL INJECTIVITY - 1.9 BPM @ 539 PSI. POH. RU N2 UNIT. JOB IN PROGRESS. 11/14/01 CONTINUED FROM WSR OF 11/13/01 BLOW DOWN REEL. RDMO. RETURN WELL TO INJECTION. FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (2 TESTS) 95 METHANOL WATER 165 SBG 90 1% KCL WATER 70 1% EXTRA SLICK KCL WATER 13 SAND SLURRY (3400 LBS SAND) 156 NH4CL WATER 100 7.5% HCL 51 9/1% HCL-HF 3206 18000 SCF N2 3948 TOTAL Page I 04-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 07/17/2OO 1 THE FOLLOWING INTERVAL WAS PERFORATED WITH 2-7/8" POWERJET GUN, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9035'-9056' Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 82' FNL, 4812' FEL, Sec. 35, T11 N, R15E, UM At top of productive interval 1268' FNL, 1268' FVVL, Sec. 35, T11N, R15E, UM At effective depth At total depth 1345' FNL, 4070' FEL, Sec. 35, T11N, R15E, UM 5. Type of Well: Development _ Exploratory__ St ratig raph lc__ Service__X (asp's 713299, 5951801) (asp's 714135, 5950641) (asp's 714079, 5950562) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 04-14i 9. Permit number / approval number 178-036 / approval #301-187 on 7/12/2001 10. APl number 50-029-20310 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9400 feet Plugs (measured) 9085 feet Effective depth: measured true vertical 9298 feet Junk (measured) 8986 feet Casing Length Conductor 1 1 1' Surface 2629' Production 8200' Liner 1298' Size Cemented Measured Depth True Vertical Depth 20" 320 Sx AS II 111' 111' 13-3/8" 5700 sx AS ~ 2693' 2693' 9-5/8" lOOO sx Class G 8264' 7995' 7" 240 Sx C~ass G 9400' 9085' RECEIVED Perforation depth: measured 9035' - 9056'; 9231' - 9249'. JUL B 4 ; 001 true vertical 8731' - 8751" 8921' - 8939'. Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-8o Tubing @ 26' MD; 4-1/2", 12.6#, L-80 Tubing @ 8643' MD; 4-1/2", 12.6#, 13CR 'Fl- @ 8694' MD. Packers & SSSV (type & measured depth) 7" x 4-1/2" TIW HBBP PACKER @ 8632' MD. 4-1/2" CAMCO BAL-0 SSSV Nipple @ 2031' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Iniection Data Gas- Mcr Water- Bbl 7422 14335 Casing Pressure Tubing Pressum - 1442 1489 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil__ Gas__ Suspended_ Service Water Inj____ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: DS 4 Surveillance Engineer Dan Babcock Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ¢hD ! F'_lkl A ! SUBMIT IN DUPLICATE~ 04-14i DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 7/04/2001' 7/11/2001- 7/17/2001- RIH & tagged PBTD @ 9298' MD. Tom Maunder from the AOGCC gave verbal approval for work to commence. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & performed tie-in. Shot 21' of add perforations f/: 9035' - 9056' MD (Zone 2C) Tie-in Log: AWS BHCS Log 10/23/1992. Used 2-7/8" carriers & all shots @ 6 SPF, random orientation, & 60° phasing. POOH w/ guns - ASF. RD ELU. Placed well back on PWl injection. Obtained representative injection data. This well is currently a Produced Water Injector. Later this summer, it will become a WAG injector as part of the Updip Victor Project. A letter will be sent to the AOGCC to inform them of the first date of MI injection. Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ (conv fl H~0 Inj Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ to WAG Inj) Change approved program _ Pull tubing _ Variance _ Perforate _X Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 64 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface v/ -/ ~/' 8. Well number 82' FNL, 4812' FEL, Sec. 35, T11N, R15E, UM (asp's 713299, 5951801) 04-14i At top of productive interval 9. Permit number / approval number 1268' FNL, 1268' FWL, Sec. 35, T11 N, R15E, UM (asp's 714135, 5950641) 178-036 At effective depth 10. APl number 50-029-20310 ~/' At total depth 11. Field / Pool 1345' FNL, 4070' FEL, Sec. 35, T11 N, R15E, UM (asp's 714079, 5950562) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9400 feet Plugs (measured) Tagged PBTD @ 9298' ELM COR on 7/4/2001.. true vertical 9085 feet Effective depth: measured 9298 feet Junk (measured) true vertical 8986 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 111' 20" 320 Sx AS, 111' 111' Surface 2629' 13-3/8" 5700 Sx AS, 2693' 2693' Production 8200' 9-5/8" lOOO Sx Class G 8264' 7995' Liner 1298' 7" 240 Sx C~ass G 9400' 9085' RECEIVED Perforation depth: measured 9231'-9249'. JUL 0 6 ; 001 true vertical 8921, - 8939'. Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth 5-1/2", 17#, L-80 Tubing @ 26' MD; 4-1/2', 12.6#, L-SO Tubing @ 8643' MD; 4-1/2', 12.6#, 13CR TT @ 8694' MD. Packers & SSSV (type & measured depth) 7" X 4-1/2" TIW HBBP PACKER @ 8632' MD. 4-1/2" CAMCO BAL-0 SSSV Nipple @ 2031' MD. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 10, 2001 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service __.(Prod Water Inj) 17. I hereby certify that the forego, lng is ty~e and correct to the best of my knowledge. Questions? Call Dan Babcock @ 564-5735. Signed "' i e: S urveillance Engineer Date Dan Babcock Prepared b~/Paul Raul' 564-579.c FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approva~ Plug integrity _ BOP Test__ Location clearance --I '---~"-' [ '-- ~ ~''''~ Mechanical Integrity Test __ Subsequent form required 1~40_~__4 '- D Taylor Seamount Approved by order of the Oommission Oommissioner Date ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Type S E bp July 5, 2001 BP Exploration (Alaska) [nc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: RE: Sundry Notice for 04-14i Add Perforations & Injection Status change (PWI Injection to WAG Injection). The permit number is #178-036. BP requests approval for proposed Add Perforations for well 04-14i. Currently, 04-14i is a produced water injector. As part of an Updip Victor WAG Project, BP also requests approval to convert this injector from PWI service to WAG service. Proposed add perfs for 04-14i are detailed below: IOR PR N DS-WL AFE JOB DESCRIPTION 1 0414 F56 DS D D/T 2 0414 F56DSD Perf 9035-9056' PRIORITY COMMENTS/OTHER Will need at least 9,100' Procedure: 1. (Slickline) Drift and tag the well. (DONE) Tagged PBTD @9298' ELM Corrected on 7/4/2001. 2. (E-line) RIH with 2-7/8" HSD gun with PowerJet HMX charges, 6 spf, 60° qb. Tie in to AWS 4-14A BHCS log (10-23-92) and shoot 9035-9056'. RDMO. Max Deviation: Min. ID: Last TD tag: Last Downhole Ops: Latest Test: Latest H2S value: Tie-in Log: 28 degrees @ 7153' MD 3.725" 8680' MD 9298' 7/4/2001 Set TT plug 5-6-01 na na AWS BHCS log (10-23-92) Discussion: Page 1 This well will be an MI injector in the Updip Victor WAG Project that should complete later this summer. Concurrent with the MI expansion project that includes this well is a RWO on 4-09i which is a Victor water injection well. The RWO on 4-09i is not scheduled until mid July but rig prep work has necessitated shutting in the well. Due to the lack of injection support from 4-09i, 4-01 has gone high GOR and is now SI. These perfs in 4-14i will help mitigate the loss of injection support in the area enabling 4-01 to be brought back on line. If you have any questions, please contact Dan Babcock at 564-5735 (office), at 250-1466 (cell), or by email at babcocDR@bp.com. Since_rely, DS 4 Surveillance Engineer Page 2 WELLHEAD= GRAY ACTUATOR=- AXELSON KB. ELEV = 64' BF. ELEV = 64' KOP = 5250' Datum MD = 9171' Datum TVD= 8800' SS J 5-1/2"TBG, 17#,L-80,0.0232bpf, ID=4.892" Id 26' 13-3/8" CSG, 72~, N-80, ID= 12.347" Id 2693' ITOPOF 7" LNR Id 8102' 19-5/8"CSG'47#'N'80/J/L'95'ID=8'681" I~ 8264' I Well ST'd in 10/92. Milled out window (TOW) 8264' Minimum ID -- 3.725" @ 8680' 4 112" OTIS XN NIPPLE 04-14i SAFETY NOTES: FHL/TIVV HBBPPKRS HAVE REDUCED 'I~r_ST PRESSURE LIMITS. MAX ALLOWED PRESSURE IS 2400 PSI. 6/26/00 - CALIPER SHOWED TBG IN FA IR/POOR CONDITION. 26' H5-1/2,, x 4-1/2. xoI 2031' 8613' CAM BAL-O SSSV NIP, ID= 3.812" 8632' H 7"X4-1/2"TIWHBBPPKRI I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" 8643' 8663' PARKERSWS NIP, ID=3.813" J 8680' H 4-1/2" OTIS XN NIPPLE ID=3.725" I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" Id 8694' FERFORATION SUMMARY REF LOG: BHCS (AWS) 10/23/92 ANGLE AT TOP PERF: 14 @ 9231' Note: Refer to Production DB for historical perf data Is, .l I Opn/Sqz I I 2-1/21 4 I 9231- 9249 I O I 1!/08/921 J 7" LNR, 26#, NT-80, 0.0383 bpf, ID: 6.276" Id 9400' 8694' H4-1/2,, TUs, TA,L WLEe I 8692' Id" .o-.o 10/29/92 1 DATE REV BY COMMI~ITS DATE REV BY COMMENTS 12/02/92 ORIGINAL COMPLETION 07/05/01 pcr minor corrections 12/30/00 818-MWH CONVER'I-I~) TO CANVAS 01/17/01 SIS-MD INITIAL REVISION 02/18/01 JKB/tp CORRECTIONS 06/26/01 DAV/tlh TBG CORRECTIONS PRUDHOE BAY ,UNIT WELL: 04-14 PEP, Mn-No: 178-03(~ APt No: 50-029-20310-00 SEC 35 T11N R15E 4070 FEL 1345 FNL BP Exploration (Alaska) ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360, ;horage, AK Transmittal #: 94021 99510,~ ~ Subject: From/Location: BHP Report John Degrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well I Log ~oi Tool Type Run, Scale Contractor NumberI (M-D-Y) 1-9 12-17-92 BHP - Camco /~ 1-14 8-11-92 BHP - Camco q 1-14 8-11-92 BHP - Camco 2-2 1-10-93 BHP - Camco 2-13 2-12-93 BHP - Camco 2-35 5-21-92 BHP 1 - Camco 3-15A 3-20-93 BHP1 - Camco 3-20 12-18-92 BHP Camco 4-7ST 5-17-92 BHP Camco 4-14 1-9-93 BHP Camco 4-29 12-28-92 BH P - Camco 4-42 4-27-92 BHP - Camco 5-9 2-21-93 BHP - Camco 5-16 2-21-93 BHP - Camco 5-25 2-21-93 BHP - Camco 5-31 2-21-93 BHP - Cam(x~ 5-33 1-29-93 BHP - Camco i 5-35 1-29-93 BHP - Camco !" 5-36 1-29-93 BHP Camco 9-24 2-15-93 BHP Camco 9-40 1-25-93 BHP Camco 9-51 3-20-93 BH P - Camco 12-7A 12-6-92 BH P - Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BH P - Carrxx~ 13-20 7-4-92 BH P - Camco 13,23A 7-4-92 BH P - Camco 13-32 7-3-92 BHP Camco 14-11 11-23-92 BHP Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco 16-30 9-28-92 BH P - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Camco 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BH P - Camco 17-21 12-21-92 BHP - Camco 18-15 6-14-92 BHP - Camco RECEIVED FE~ J ~, 1994 Alaska Oi! & ~a$ Co.s. '~nchorage C°rr~i$$ion ARCO Alaska, Inc. P.O.Box 1~ Anchorage, p. lnm1~;~ 99510 DATE: 10-8-93 77-..___.~_~_1- 11 ~_~Zi~2-12 15 4-29 4-42 ~-1 6-17 1 ~-2~ ~B-~-7-8 11-25 11-28 13-1 14-24 5 ~ -18 e 15-3o 16-7 16-31 ~17-21 8-29-93 Prod Proflle/ffc~l~le~ Run 1, 5" I~0-~ch 8-29-93 Prod Profllei~anl~~f Run 1, 5" ~0~-~\~oSch 8-29-93 Prod Profile {~lCe~~R~v,,un.~ 5" 9-7-93 ~j ~offie & S~ticlSt,~,~~~ 5" ~e~Sch 9-7-93 ~j ~offie A Static/~m)~~ 1, 5"~o-t~ch 9-3-93 ~ml B~t T~P R - ' 5" 9-8-93 ~j ~offie & Sta~c 1~1~~~'' 9-3-93 ~ B~t T~P R~ 1, 5"~-~ee Sch 9-4-93 Pe~Record ~-t~o~ R~ 1, 5" Sch 9-4-93 Pe~ Record ~-~ R~ 1, 5" Sch 9-10-93 ~uc~on~alt~l~e R~ 1, 1"&5" ~ Schq~ 8-31-93 USIT (Cement) Color R,m 1, 5''~ 8-31-93 USIT (~sion) ~lor R~ 1, 5"t~t~sq Sch 9-2-93 ~ B~t ~P R~ 1, 5"~~- SchR%~ 9-10-93 ~od ~offie~aq[i~~ H~m 1, 5'~ Sch 8-29-93 ~od ~offiel~t~~ R~m 1, 5" 9-5-93 C~ l~ ~ 1~~ R~m 1, 5" Sch 9-12-93 ~P ~%o R~m 2, 5" Sch 8-30-93 ~ Detectl~l~~ R~ 1, 2" 100-~5 Sch 9-10-93 Pe~ Record ~ zz~$-i~ R~ 1, 5" Sch 9-3-93 GR/CCL (TCP ~e-~) R~ 1, 5" 9-5-93 ~ ~/a~al~l~/e~ R~ 1, 1"&5" ~-Sch 9-7-93 ~ ~ ~- ~ R~m 1, 1"&5" Sch 9-4-93 Pe~ Record %~a~o R~ 1, 5" Sch RECEIVED BY_~~ '~ Have A Nice Dayl Sonya Wallace AT(~1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL the attached copy as receipt of data. # BPX # STATE OF ~KA The correct top logged interval for this log is 12,900 feet. The correct top logged interval for this log is 10,400 feet. ARCO AIuka, Inc. P.O.Box 1O0360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS -13 -4A 2-10./[ ~6-28 ~ ~.~ ~** J6-29A ~6-30 1-31-93 1-4-93 1-10-93 1-11-93 11-12-92 11-8-92 11-28-92 1-29-93 11-15-92 11-19-92 11-6-92 11-27-92 11-18-92 1-2-93 1-1-93 3-1-93 1-9-93 11-18-92 11-15-92 1-3-93 1-8-93 11-2-92 11-16-92 1-8-93 11-14-92 12-2-92 11-29-92 13-31-92 11-29-92 1-5-93 11-17-92 Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Pert Record Perf Record Perf Record Perf Record DSN Perf Record Collar (Inflatable Packer) Collar (To spot Jet cutter) Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Have A Nice Day Run 1. Run 1. Run 1. Run 1. Run 1. Run 1.5" Run 1. Run 1. Run 1, Run 1, Run 1, Run 1, Run 1, Run 1. Run 1. Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1. Run 1, Run 1. Run 1, Run 1. Run 1. Run 1, Run l, Run 1. Run 1, Sonya Wallace ATO-1529 HL~ HL~ HL~ HL8 HL~ HL~ HL~ HIS HLS HL~ HL.q HL~ HL~ HLS HL8 HIS HL~ HL~ HI~ HI~ HL~ HI,,q HLS HIS HLS HLS HI~ HL~ HL~ HL~ # PHIIA.IPS l'B W~ FII,E~ #BPX # STATE OF ALASKA RECEIVED These logs were ran in 1993 not 1992. The correct APl# for 4-14A is 504)29-2031000. ThC correct API# for 1~-29A Is ~d~02~22272-01. Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOI.~- FINALS 1-8-93 InJ Profile 1-10-93 Gas Entry 11-23-92 Prod Profile 1-9-93 InJ Profile 11-24-92 PITS 12-4-92 Prod Profile 11-19-92 InJ Profile 11-22-92' Ptunp-in Profile 1-12-93 Collar/Tubing Patch 12-3-92 GR/Collar 12-3-92 Prod Profile 12-3-92 GR/Coltsr 12-6-92 PITS Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco R~!n 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco R;m 1, 5" Camco R-n 1, 5" Camco R!!n 1, 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco ~~2-7A 12-10-92 CCL/Jewelry R~m 1, 4 22A GR/ColIar R;,n 1 ~'~ l.~..!_~ - 1-8-93 , ~~_~14-28 1-8-93 Prod Proffie. Run 1, ~~~1~-~ '7-1~5 . 11-22-92 Static Temperature Run 1, Please sign and return tl~e attached copy as receipt of data. .,CEiV,, Have A Nice Day! Sonya Wallace ATO-1529 APPROVED_ffz~) Trans# 93037 # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF AI2~KA_ RECEIVED MAR ~ 6 1993 The correct APl# for 4-14A is 50-029-20310-00. Alaska 011 & Gas Cons. Comml,~ieJor~ Anchorage ARCO Akska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-13-92 4-41 ~4-43 ARCO DIRECTIONAL DATA 1 0.18-92 MWD Directional Survey 10-30-92 MWD Directional Survey 10-26-92 MWD Directional 8urvey 10-27-92 Electronic 8urvey Sys~ 10-9-92 MWD Dlrection~l Survey 10-14-92 MWD Directional Survey ~to~Ll 10-29-92 MWD Directional Survey 7-15 10-14-92 MWD Dlrectio~! Survey '~~8-16A 10-3-92 ~--~I~ MWD Directional Survey Please sign and return_~e attached c~opLas receipt of data. RECEIVED BY~_~/~.~__ Have A Nice Day~ 8onya W~ ATO- 1529 Sperry Sperry Teleco Teleco APPROVED___~ Trans# 92252 CENTRAL FILF.~ CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL # PB WELL ~ R&D #BPX # ST. OF ~!~_ (2 COPIE~) '.A - AZiMt;T-: FE~( ROt. AF:':" TAE'~ T~ T~E7 :r TiE I'.i POiNT[TiP) INCL!NATI~! LATiTLC,~iN/-E }- 77e3..:,.? ~,?.. !42 ORIGINAL i., :..' .u'LJ ~541.62 .o.- INTi~%'AL ~, m?5~TICAL DEF~ ft fl C.,O '":"~'" "~' 225,S 6203,3C. 31.8 0233,26 24,5 8256.55 31,2 B266,37 ~.',IC:, 60 3'7.E 56~.' !2,21 31,6 ~.7~!,52 -3i,~- 8~3,65 ~7~..57 37,3 . B.784,4C 47,9 ~70,~ , .. T~.:;~ STATi~ AZI.~ZH ~TITLE'E SI~CT!DN INCi.N~ K,"-S f,-. deg de: ft 273,44 416, '.';2 426,.--~ I9 432,~' 17,77 177,8~=-,~,-~,=~n~' ~'" ~Y~O, 62 i6,4! 16i, _'-~ -i072,41 ~EF~:TLM:f DISPLACB~ ~t AZIMUTH. dm: 10~-5 t 140,3E 14i, ~.' 4,5i !41:60 4,~' 141.7? 142,03 44~,~ 1~,70 18~,K -1062,47 47,18 14,78 ~C,D,23 -i'~0.2! ~,5.~ 14,72 2!2,02 -1097,35 471,55 !4,~ 2!C.98 -!102,~7 481,2(' 15,44 209,~ -1111,24 B3~.., .OC 1 ~..7,7-'. 142,~C 7,46 ~.'m ?7 1372,61 142,59 ~,,~. 630,4l~ 1376.i~. 142,6E ~, C27,0~. 1378,~ !43,1~ !,21 l)~,25 1382,37 143,54 2,72 815.9! 1~7,87 !43,99 2,02 ARCO Alaslm; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 REFERENCE: ARCO CASED HOIF- FINALS , 1.5ST~9/~9_29.92 1-29/~-/°r 12-8-91 2-11 ?~-- ~ 10-26-92 2-22~2--~/~/ 10-26-92 ~*" ~ o/ 4-14~{ 10-29-92 7-11/~_- 72 8-14-92 7-13 ?~--2o 7-31-92 ~-r~/ ** 12-6A 8-10-92 ~' ~/-- ~" 12-22 8-10-92 14-41~2--~' 10-25-92 Perf Record TMD CCL (Pert) CCL (Peri) aaL/C~CCL Perf Record TMD (Borax) Peri' Record Perf Record GR/CCL (Perf Depth) Rim 1, 5" R-n 1, 5" R11n 1, 5" R-n 1, 5" R!ln 1, 5" R-n 1, 5" Run 1, 5" R-n 1, 5" R-n 1, 5" Run 1, 5" HLS HLS Arias Atlas Aths HLS HLS HLS HLS Sch Please sign and return the attached copy as receipt of data. .,E,V D RECEIVED DEC ~ 0 1992 Have A Nice Day! Sonya WAll~,ce ATO-1529 CENT- ~jas~II~RAL~ .&jas Cons. Commission # zru.,ZS~chorage # CHEVRON D&M # EXTENSION EXPLORATION # EXXON " MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA 'TEXACO The correct API# for 1-5ST is 50-029-20076-00. The correct APl# for 12-6A is 50-029-20401-01. STATE OF ALASKA ALAS,,,-, OIL AND GAS CONSERVATION COMMISSI~. REPORT OF SUNDRY WELL OPERATI 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X SIDETRACK 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 85' SNL, 466' EWL, SEC. 35, T11N, R15E, UM At top of productive interval 1268' SNL, 1268' EWL, SEC. 35, T11N, R15E, UM At effective depth 1334' SNL, 1215' EWL, SEC. 35, T11N, R15E, UM At total depth 1348' SNL, 1207' EWL, SEC. 35, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service X 9400 feet Plugs(measured) 9085 feet 9338 feet Junk(measured) 9025 feet 6. Datum elevation (DF or KB) KBE = 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-14i ST 9. Permit number/approval number 78-36/92-234 10. APl number 50 - 029-20310 11. Field/Pool Prudhoe Bay Field/Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 111' 20" 320 sx Arcticset II 111' 111' 2693' 13-3/8" 5700 sx Arcticset II 2693' 2693' 9346' 9-5/8" 1000 sx Class "G" 9346' 9029' 256' 7" 240 sx Class "G" 8102'-9400' 7846'-9085' measured 9231'-9249' true vertical 8921'-8939' Tubing (size, grade, and measured depth) 4-1/2", 12.6~ , L-80 tubing to 8643' w/4-1/2", 12.6#, 13CR80 tubing tail to 8694' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ' DEC 1 5 1992 Alaska 0il & Gas Cons. (;ommissiorl Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run x Daily Report of Well Operations x 16. Status of well classification as: Oil Gas Suspended Service Water Injection 17. I hereby certify that the.foregoing is true and correct to the best of my knowledge. Si,ned ~/('~/ TitleDrillingEnginoorSuporvisor'Z'""~~Date Form 10-404 Rev 0~,838 SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 4-14A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20310 PERMIT: APPROVAL: ACCEPT: 10/14/92 10:10 SPUD: RELEASE: 10/25/92 04:10 OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 10/15/92 (1) TD: 0 PB: 8716 NU BOP MW: 8.8 Seawater TAKE ON SEAWATER, PULL BPV. CIRCULATE CRUDE DOWN ANNULUS. SET BPV. ND TREE. NU BOPE. 10/16/92 ( 2) TD: 0 PB: 8716 10/17/92 ( 3) TD: 8306' (8306) 10/18/92 (4) TD: 8324' ( 18) 10/19/92 (5) TD: 8274' ( 0) 10/20/92 (6) TD: 8532'( 258) 10/21/92 ( 7) TD: 8844' ( 312) 10/22/92 (8) TD: 9300' ( 456) RIH W/BHA#i SECTION MILL MW: 8.8 Seawater CONTINUE TO NU BOPE & TEST. PULL HANGER FREE. PULLING FREE. REVERSE CIRC. PULL & LD 5.5 TUBING. SHOWED CORROSION. REPLACE & TEST 9-5/8 PACKOFF. TEST CASING. TEST RAMS & KELLY. INSTALL WEAR RING. MU BHA # 1 & RIH. MILLING 9-5/8 CASING AT 8306 MW: 9.4 VIS: 76 RIH W/SECTION MILL. PUMP SWEEP. CUT TO 8299' PUMP SWEEP. MILL TO 8306'. POH W/OPEN ENDED DP MW: 9.5 VIS: 72 POH W/OPEN ENDED DP. RIH W/MULE SHOE. LAY CEMENT KICKOFF PLUG. MU BHA #3 MW: 9.4 VIS: 52 INSTALL TEST PLUG & TEST BOPS. INSTALL WEAR RING. RIH TO 7992'. DRILL TO 8274' MWD TOOL FAILURE. PUMP DRY JOB. POH. DRILLING AT 8528 MW: 9.5 VIS: 54 MU BHA #3. TEST MWD. RIH FILL PIPE. KELLY UP. ORIENT MWD. ROTATE & SLIDE TO 8528' RIH W/DRILLING ASSEMBLY MW: 9.5 VIS: 52 CONTINUE DIRECTIONAL DRILLING 8-1/2 TO 8844'. CIRC & CLEAN HOLE. DROP SURVEY. POOH. PUMP DRY JOB. POOH. RIH W/BHA#4 W/LOCKED ASSEMBLY. CONTINUE DRILLING 8-1/2 HOLE MW: 9.6 VIS: 48 RIH W/BHA#4. RIH TO 8760'. WASH & REAM. DRILL 8-1/2 HOLE W/LOCKED ASSEMLY FROM 8844 - 9300'. E( EIVED DEC 1,5 1992 A~aska Oil & Gas Cons. Commissio~ Anchorage WELL : DS 4-14A OPERATION: RIG : NABORS 2ES PAGE: 2 10/23/92 (9) TD: 9400'( 100) 10/24/92 (10) TD: 9400' ( 0) 10/25/92 (11) TD: 9400 PB: 9338 10/26/92 (12) TD: 9400 PB: 9338 RUNNING 7" LINER MW: 9.6 VIS: 48 DRILLING 8-1/2 HOLE TO 9400' CIRC. SHORT TRIP TO 9-5/8 CASING SHOE AT 8264' CIRC. DROP SURVEY & PULL TO 9-5/8 CASING SHOE. CIRC. POOH. LOG ACROSS OPEN HOLE SECTION 8264 - 9400'. RIH W/4-1/2 HWDP. RUNNING 7" LINER. RIH W/CASING SCRAPERS MW: 9.6 VIS: 48 CONTINUE RUNNING 7" LINER. PUMP SWEEP. TEST LINES & CEMEMT. NU TREE MW: 8.5 Seawater RIH. REVERSE CIRC. REVERSE & CHANGE OVER TOS EAWATER. TEST 7 X 9-5/8. RUN 4-1/2 TUBING COMPLETION. TEST CONTROL LINES. INSTALL BPV. ND BOP. RIG RELEASES MW: 8.5 Seawater TEST SEALS. TEST CONTROL LINES. TEST TREE. PUMP SEAWATER & DIESEL. TEST ANNULUS. RELEASE RIG FOR TURN KEY PAD TO PAD MOVE 1630 HRS. SIGNATURE: (drilling superintendent) DATE: J 'ECEIVED DEC 1 § 1992 & Gas Cons. Oommissior, Anchorage 0 RIG 119 A ~.,...,..~,~ PRUDHOE BAY DS 4-14 ST GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY DS 4-14 ST WELL NAME PRUDHOE BAY LOCATION AL1092D44 JOB NUMBER GARY PAUL NAME MWD 10/29/92 TYPE SURVEY DATE DIRECTIONAL /T.? ('-'?~ ,~ SUPERVISOR ~2_d~_~ ~,~...~,.~__.C TITLE SIGNATURE TIE IN @ 8250.0 FT DEPTH INTERVAL FROM 9313.0 FT TO DATE SURVEY TAKEN 10/17/92 10/23/92 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING, Client .... : PRUDHOE BAY DRILLING Field ..... : PRUDHOE BAY Well ...... : DS 4-14 ST Section at: S,33.13,W Engineer..: GARY PAUL INC. S MEAS INCLN C DEPTH ANGLE 7 0 0.00 7 514 0.50 7 1008 0.25 7 1495 0.50 7 2660 0.50 VERTICAL-DEPTHS BKB SUB-SEA 0.0 -64.0 514.0 450.0 1008.0 944.0 1495.0 1431.0 2659.9 2595.9 7 2770 1.00 2769.9 2705.9 7 2864 0.75 2863.9 2799.9 7 2957 0.50 2956.9 2892.9 7 3050 0.75 3049.9 2985.9 7 3143 0.50 3142.9 3078.9 7 3237 0.75 3236.9 3172.9 7 3330 0.50 3329.9 3265.9 7 3423 1.00 3422.9 3358.9 7 3516 0.50 3515.9 3451.9 7 3610 0.50 3609.9 3545.9 7 3703 0.50 3702.9 3638.9 7 3796 0.75 3795.9 3731.9 7 3889 1.00 3888.9 3824.9 7 3983 1.00 3982.8 3918.8 7 4076 1.00 4075.8 4011.8 7 4169 0.75 4168.8 4104.8 ^ Survey Codes: 7/GYRO (GLDD (c)92 PDS414ST Sl.30 4:25 PM 2) SECTION DISTNCE 0.0 2.2 3.5 3.2 0.9 -0.4 -1.8 -2.9 -3.8 -4.7 -5.7 -6.6 -7.8 -9.0 -9.6 -10.0 -10.4 -11.3 -12.7 -14.1 -15.4 10/29/92 Computation...: MINIMUM CURVATURE Survey Date...: 10/23/92 KB Elevation..: 64.00 ft Reference ..... : AL1092D44/AFE: Magnetic Dcln.: 31.17 E RECORD OF SURVEY DIRECTION RELATIVE-COORDINATES CLOSURE BEARING FROM-WELL-HEAD DISTNCE BEARING DL /lOO S 31.00 W 0.0 N 0.0 E 0.0 N 0.00 E 0.00 S 31.00 W 1.9 S 1.2 W 2.2 S 31.00 W 0.10 N 66.00 E 3.3 S 1.3 W 3.6 S 21.03 W 0.15 S 39.00 E 4.6 S 1.0 E 4.7 S 12.72 E 0.10 N 73.00 E 7.0 S 9.1 E 11.5 S 52.33 E 0.05 N 38.00 E 6.1 S 10.1 E 11.8 S 58.89 E 0.60 N 40.00 E 5.0 S 11.0 E 12.1 S 65.63 E 0.27 N 32.00 E 4.2 S 11.6 E 12.4 S 70.21 E 0.28 N 65.00 E 3.6 S 12.4 E 12.9 S 73.87 E 0.46 N 51.00 E 3.1 S 13.3 E 13.6 S 76.96 E 0.31 N 51.00 E 2.4 S 14.1 E 14.3 S 80.20 E 0.27 N 38.00 E 1.7 S 14.8 E 14.9 S 83.34 E 0.31 N 45.00 E 0.8 S 15.6 E 15.6 S 86.94 E 0.55 N 43.00 E 0.0 N 16.5 E 16.5 N 89.87 E 0.54 S 85.00 E 0.3 N 17.2 E 17.2 N 89.00 E 0.47 S 81.00 E 0.2 N 18.0 E 18.0 N 89.36 E 0.04 S 83.00 E 0.1 N 19.0 E 19.0 N 89.81 E 0.27 N 70.00 E 0.3 N 20.3 E 20.3 N 89.25 E 0.51 N 68.00 E 0.9 N 21.9 E 21.9 N 87.76 E 0.04 N 54.00 E 1.6 N 23.3 E 23.3 N 85.98 E 0.26 N 56.00 E 2.5 N 24.4 E 24.6 N 84.27 E 0.27 DS 4-14 ST S MEAS INCLN C DEPTH ANGLE 7 4262 0.75 7 4355 0.75 7 4449 0.75 7 4542 0.75 7 4635 0.50 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RECORD OF SURVEY 4261.8 4197.8 -16.5 4354.8 4290.8 -17.7 4448.8 4384.8 -18.8 4541.8 4477.8 -20.0 4634.8 4570.8 -20.9 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 55.00 E 3.1 N 25.4 E N 52.00 E 3.9 N 26.4 E N 51.00 E 4.6 N 27.4 E N 61.00 E 5.3 N 28.4 E N 61.00 E 5.8 N 29.3 E 7 4728 0.75 4727.8 4663.8 -21.8 N 58.00 E 6.3 N 30.1 E 7 4822 0.75 4821.8 4757.8 -22.9 N 56.00 E 7.0 N 31.2 E 7 4915 1.00 4914.8 4850.8 -24.2 N 51.00 E 7.8 N 32.3 E 7 5008 1.50 5007.7 4943.7 -24.8 S 45.00 E 7.5 N 33.8 E 7 5101 5.00 5100.6 5036.6 -23.5 S 42.00 E 3.6 N 37.4 E 7 5195 8.50 5193.9 5129.9 -20.3 S 39.00 E 7 5288 12.00 5285.4 5221.4 -15.2 S 39.00 E 7 5381 15.50 5375.7 5311.7 -9.3 S 43.00 E 7 5474 18.00 5464.8 5400.8 -2.7 S 42.50 E 7 5568 19.00 5553.9 5489.9 5.0 S 41.50 E 13.1 21.7 30.7 40.9 51.9 63.4 76.0 90.0 104.3 118.5 S 42.00 E S 41.50 E S 41.00 E S 39.00 E S 39.00 E 7 5661 20.50 5641.4 5577.4 7 5754 20.75 5728.5 5664.5 7 5847 21.50 5815.2 5751.2 7 5941 22.25 5902.5 5838.5 7 6034 23.00 5988.3 5924.3 7 6127 23.25 6073.8 6009.8 7 6220 25.00 6158.7 6094.7 7 6314 25.75 6243.6 6179.6 7 6407 26.00 6327.3 6263.3 7 6500 26.00 6410.9 6346.9 4.8 S 44.5 E 17.7 S 54.9 E 34.3 S 69.5 E 54.0 S 87.7 E 76.1 S 107.6 E 99.6 S 128.5 E 124.0 S 150.3 E 149.2 S 172.4 E 176.1 S 194.9 E 203.9 S 217.5 E 7 6593 26.75 6494.2 6430.2 7 6686 26.75 6577.3 6513.3 7 6780 27.00 6661.1 6597.1 7 6873 27.50 6743.8 6679.8 7 6966 28.00 6826.1 6762.1 S 38.00 E 232.4 S 240.2 E S 37.00 E 262.6 S 263.3 E S 36.00 E 295.0 S 287.3 E S 36.50 E 327.7 S 311.3 E S 36.50 E 360.5 S 335.5 E 132.9 S 36.50 E 393.7 S 360.1 E 147.3 S 37.00 E 427.2 S 385.2 E 161.6 S 37.50 E 461.1 S 410.9 E 175.9 S 37.00 E 495.0 S 436.6 E 190.6 S 37.00 E 529.5 S 462.7 E Page 2 10/29/92 CLOSURE DISTNCE BEARING DL 11oo 25.6 N 82.96 E 0.00 26.7 N 81.67 E 0.04 27.8 N 80.40 E 0.00~ 28.9 N 79.40 E 0. 29.8 N 78.79 E 0.27 30.8 N 78.16 E 0.27 32.0 N 77.36 E 0.03 33.3 N 76.36 E 0.28 34.6 N 77.50 E 1.84 37.6 N 84.47 E 3.77 44.8 S 83.81 E 3.74 57.7 S 72.15 E 3.76 77.5 S 63.73 E 3.90 102.9 S 58.38 E 2.69 131.8 S 54.72 E 1.12 162.6 S 52.23 E 1.62 194.9 S 50.48 E 0.33 228.1 S 49.13 E 0.83 262.7 S 47.91 E 1.12'~-~ 298.1 S 46.85 E 0.81 334.3 S 45.94 E 0.50 371.9 S 45.08 E 1.93 411.8 S 44.24 E 0.92 452.0 S 43.53 E 0.36 492.5 S 42.95 E 0.00 533.6 S 42.45 E 0.81 575.2 S 42.03 E 0.24 617.6 S 41.71 E 0.36 660.0 S 41.42 E 0.59 703.2 S 41.15 E 0.54 ^Survey Codes: 7/GYRO DS 4-14 ST Page 3 10/29/92 S MEAS INCLN C DEPTH ANGLE 7 7059 28.00 7 7153 28.00 7 7246 27.50 7 7339 27.00 7 7432 27.00 7 7526 26.25 7 7619 25.75 7 7712 25.00 7 7805 24.75 7 7899 24.25 7 7992 24.00 7 8085 23.50 7 8178 23.00 3 8250 22.23 3 8485 19.70 · 3 8573 16.40 3 8673 14.70 3 8784 16.40 1 9313 13.50 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION RELATIVE-COORDINATES CLOSURE DL BEARING FROM-WELL-HEAD DISTNCE BEARING /100 6908.2 6844.2 205.4 S 37.00 E 564.4 S 489.0 E 746.8 S 40.90 E 0.00 6991.2 6927.2 220.0 S 38.00 E 599.4 S 515.8 E 790.8 S 40.71 E 0.50 7073.5 7009.5 234.2 S 37.50 E 633.7 S 542.4 E 834.1 S 40.56 E 0.59~--. 7156.2 7092.2 247.8 S 39.00 E 667.1 S 568.7 E 876.6 S 40.45 E 0.9~ 7239.1 7175.1 260.8 S 39.00 E 699.9 S 595.3 E 918.8 S 40.38 E 0.00 7323.1 7259.1 273.7 S 39.00 E 732.7 S 621.8 E 960.9 S 40.32 E 0.80 7406.7 7342.7 286.2 S 39.00 E 764.3 S 647.5 E 1001.7 S 40.27 E 0.54 7490.7 7426.7 298.8 S 38.00 E 795.5 S 672.3 E 1041.5 S 40.20 E 0.93 7575.1 7511.1 311.8 S 37.00 E 826.6 S 696.1 E 1080.6 S 40.10 E 0.53 7660.6 7596.6 324.8 S 37.50 E 857.6 S 719.7 E 1119.5 S 40.00 E 0.58 7745.5 7681.5 337.6 S 37.00 E 887.8 S 742.7 E 1157.5 S 39.91 E 0.35 7830.6 7766.6 350.6 S 36.00 E 918.0 S 765.0 E 1194.9 S 39.81 E 0.69 7916.1 7852.1 363.4 S 37.00 E 947.5 S 786.8 E 1231.6 S 39.71 E 0.68 7982.5 7918.5 372.8 S 37.00 E 969.6 S 803.5 E 1259.2 S 39.65 E 1.07 8202.5 8138.5 417.9 S 7.90 E 1044.5 S 835.7 E 1337.7 S 38.66 E 4.51 8286.2 8222.2 439.7 S 1.40 W 1071.6 S 837.5 E 1360.1 S 38.01 E 4.97 8382.7 8318.7 464.4 S 32.00 W 1096.6 S 830.4 E 1375.5 S 37.14 E 8.28 8489.7 8425.7 494.1 S 28.40 W 1122.3 S 815.5 E 1387.3 S 36.00 E 1.76 9000.7 8936.7 630.0 S 27.00 W 1243.0 S 751.9 E 1452.8 S 31.17 E 0.55 ^Survey Codes: i/SINGLE SHOT 3/MWD 7/GYRO DS 4-14 ST Page 4 10/29/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 100 164 0.16 164 0 0 S 31.00 W 0.20 S 0.12 W 200 264 0.26 264 0 0 S 31.00 W 0.51 S 0.30 W 300 364 0.35 364 0 0 S 31.00 W 0.96 S 0.58 W 400 464 0.45 464 0 0 S 31.00 W 1.57 S 0.94 W 500 564 0.47 564 0 0 S 16.32 W 2.31 S 1.33 W 600 664 0.42 664 0 0 S 13.03 E 3.02 S 1.37 W 700 764 0.37 764 0 0 S 42.38 E 3.46 S 1.17 W 800 864 0.32 864 0 0 S 71.74 E 3.54 S 1.01 W 900 964 0.27 964 0 0 N 78.91 E 3.40 S 1.12 W 1000 1064 0.28 1064 0 0 N 74.63 E 3.25 S 1.04 W 1100 1164 0.33 1164 0 0 S 89.97 E 3.19 S 0.52 W 1200 1264 0.38 1264 0 0 S 74.57 E 3.33 S 0.05 E 1300 1364 0.43 1364 0 0 S 59.17 E 3.70 S 0.58 E 1400 1464 0.48 1464 0 0 S 43.77 E 4.32 S 0.96 E 1500 1564 0.50 1564 0 0 S 43.03 E 5.01 S 1.42 E 1600 1664 0.50 1664 0 0 S 48.87 E 5.61 S 2.05 E 1700 1764 0.50 1764 0 0 S 54.70 E 6.14 S 2.72 E 1800 1864 0.50 1864 0 0 S 60.54 E 6.59 S 3.44 E 1900 1964 0.50 1964 0 0 S 66.38 E 6.96 S 4.19 E 2000 2064 0.50 2064 0 0 S 72.21 E 7.24 S 4.95 E 2100 2164 0.50 2164 0 0 S 78.05 E 7.42 S 5.72 E 2200 2264 0.50 2264 0 0 S 83.89 E 7.52 S 6.48 E 2300 2364 0.50 2364 0 0 S 89.73 E 7.52 S 7.21 E 2400 2464 0.50 2464 0 0 N 84.44 E 7.43 S 7.90 E 2500 2564 0.50 2564 0 0 N 78.60 E 7.25 S 8.54 E 2600 2664 0.52 2664 0 0 N 71.71 E 7.00 S 9.12 E 2700 2764 0.97 2764 0 0 N 39.89 E 6.20 S 10.09 E 2800 2864 0.75 2864 0 0 N 39.99 E 5.00 S 11.04 E 2900 2964 0.52 2964 0 0 N 34.51 E 4.14 S 11.68 E 3000 3064 0.71 3064 0 0 N 62.88 E 3.51 S 12.57 E DS 4-14 ST Page 5 10/29/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 3100 3164 0.56 3164 0 0 N 51.00 E 2.95 S 13.43 E 3200 3264 0.68 3264 0 0 N 47.21 E 2.21 S 14.33 E 3300 3364 0.68 3364 0 0 N 40.57 E 1.46 S 15.02 E 3400 3464 0.78 3464 0 0 N 44.12 E 0.38 S 16.07 E 3500 3564 0.50 3564 0 0 N 69.62 E 0.26 N 16.81 E 3600 3664 0.50 3664 0 0 S 82.67 E 0.25 N 17.63 E 3700 3764 0.66 3764 0 0 S 82.31 E 0.11 N 18.58 E 3800 3864 0.93 3864 0 0 N 77.22 E 0.13 N 19.95 E 3900 3964 1.00 3964 0 0 N 68.40 E 0.73 N 21.56 E 4000 4064 1.00 4064 0 0 N 55.78 E 1.52 N 23.11 E 4100 4164 0.76 4164 0 0 N 55.90 E 2.42 N 24.39 E 4200 4264 0.75 4264 0 0 N 54.93 E 3.16 N 25.46 E 4300 4364 0.75 4364 0 0 N 51.90 E 3.94 N 26.51 E 4400 4464 0.75 4464 0 0 N 52.64 E 4.76 N 27.54 E 4500 4564 0.69 4564 0 0 N 61.00 E 5.45 N 28.63 E 4600 4664 0.58 4664 0 0 N 60.06 E 5.94 N 29.51 E 4700 4764 0.75 4764 0 0 N 57.23 E 6.58 N 30.55 E 4800 4864 0.86 4864 0 0 N 53.73 E 7.33 N 31.66 E 4900 4964 1.26 4964 0 0 S 84.51 E 8.06 N 33.19 E 5000 5064 3.62 5064 0 0 S 43.18 E 5.68 N 35.54 E 5100 5165 7.38 5164 1 0 S 39.96 E 1.59 S 41.87 E 5200 5266 11.18 5264 2 1 S 39.00 E 14.27 S 52.14 E 5300 5369 15.04 5364 5 3 S 42.48 E 31.96 S 67.28 E 5400 5473 17.98 5464 9 4 S 42.50 E 53.79 S 87.48 E 5500 5579 19.17 5564 15 5 S 41.56 E 78.76 S 109.92 E 5600 5685 20.56 5664 21 6 S 41.87 E 105.87 S 134.18 E 5700 5792 21.06 5764 28 7 S 41.30 E 134.20 S 159.32 E 5800 5899 21.92 5864 35 7 S 39.88 E 164.01 S 185.04 E 5900 6008 22.79 5964 44 8 S 39.00 E 195.89 S 211.00 E 6000 6116 23.22 6064 52 9 S 38.12 E 229.12 S 237.59 E DS 4-14 ST Page 6 10/29/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 6100 6226 25.05 6164 62 10 S 36.94 E 264.58 S 6200 6337 25.81 6264 73 11 S 36.12 E 302.94 S 6300 6448 26.00 6364 84 11 S 36.50 E 342.10 S 6400 6559 26.48 6464 95 11 S 36.50 E 381.53 S 6500 6671 26.75 6564 107 12 S 36.92 E 421.90 S 6600 6783 27.02 6664 119 12 S 37.48 E 462.23 S 6700 6896 27.62 6764 132 13 S 37.00 E 503.38 S 6800 7009 28.00 6864 145 13 S 37.00 E 545.64 S 6900 7122 28.00 6964 158 13 S 37.67 E 588.00 S 7000 7235 27.56 7064 171 13 S 37.56 E 629.73 S 7100 7348 27.00 7164 184 12 S 39.00 E 670.19 S 7200 7460 26.78 7264 196 12 S 39.00 E 709.74 S 7300 7572 26.01 7364 208 12 S 39.00 E 748.25 S 7400 7682 25.24 7464 218 11 S 38.32 E 785.68 S 7500 7793 24.78 7564 229 10 S 37.13 E 822.48 S 7600 7903 24.24 7664 239 10 S 37.48 E 858.80 S 7700 8012 23.89 7764 248 10 S 36.78 E 894.42 S 7800 8121 23.30 7864 257 9 S 36.39 E 929.61 S 7900 8230 22.44 7964 266 9 S 37.00 E 963.49 S 8000 8338 21.29 8064 274 8 S 26.14 E 997.13 S 8100 8445 20.13 8164 281 7 S 12.90 E 1031.75 S 8200 8550 17.27 8264 286 5 S 1.05 E 1064.96 S 8300 8654 15.03 8364 290 4 S 26.12 W 1092.48 S 8400 8757 15.99 8464 293 3 S 29.27 W 1115.76 S 8500 8861 15.98 8564 297 4 S 28.20 W 1141.29 S 8600 8965 15.41 8664 301 4 S 27.92 W 1166.08 S 8700 9069 14.84 8764 305 4 S 27.65 W 1189.98 S 8800 9172 14.27 8864 308 3 S 27.37 W 1213.00 S 8900 9275 13.71 8964 311 3 S 27.10 W 1235.13 S 264.81 E 293.07 E 321.92 E 351.10 E 381.13 E 411.77 E 442.99 E 474.83 E 506.97 E 539.34 E 571.22 E 603.24 E 634.42 E 664.53 E 693.00 E 720.60 E 747.62 E 773.49 E 798.88 E 820.47 E 833.15 E 837.43 E 832.59 E 819.06 E 805.25 E 792.04 E 779.43 E 767.42 E 755.98 E DS 4-14 ST Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 10/29/92 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 0 0.00 0 -64 0 N 0.00 E 0 N 0 E 1000 0.25 1000 936 3 N 68.35 E 3 S 1 W 2000 0.50 2000 1936 3 S 68.48 E 7 S 4 E 3000 0.62 3000 2936 -3 N 47.26 E 4 S 12 E 4000 1.00 4000 3936 -13 N 65.44 E 1 N 22 E 0 N 90.00 E 0.0 4 S 20.44 W 0.1 8 S 32.26 E 0.1 13 S 71.98 E 0.4 22 N 87.49 E 0.3 5000 1.46 5000 4936 6000 22.73 5957 5893 7000 28.00 6856 6792 8000 23.96 7753 7689 9000 15.22 8697 8633 -25 S 52.23 E 8 N 48 S 39.00 E 194 S 196 S 37.00 E 542 S 339 S 36.91 E 890 S 553 S 27.83 W 1174 S 34 E 35 N 77.23 E 1.8 209 E 285 S 47.21 E 0.8 472 E 719 S 41.05 E 0.0 745 E 1161 S 39.90 E 0.7 788 E 1414 S 33.86 E 0.6 P~JDHOE BAY E)'R T~ LL ~'NG" Marker Identification 14D N/$ E/ii DS 4-~4 ST PLAN VIEW _ _~J,.~ , .~ ~ CLOSURE .... · 1453 ft at S 31.t7 E DECLINATION · 3t.17 E ,SCALE · ! inch = 200 feet I DRATdN !0/29/92 Great Land Directional Drilling . ._.____--~. : : % \ O lO0 <-klEST: EAST -> 2OO ~0 500 600 700 800 \\ t I .... I ,~. I. 1 300 900 tO00 t t00i200 t300 , ! ! I I I i I .I I '1 500 6O0 7OO DS 4- 4 ST VERTICAL SECTION VlEN Section at: S 33.i3 N TVD ScaZe' ! inch = 200 leek Dep Scale · ! inch = 200 feel D~a',,,m .... · ~0/29/92 Harker Identification ~ ~ 6ECTN ZNCLN k) SIDE-TRACKING POINT 6~0 7963 373 22.23 BI TD 9313 900& 630 13.50 MA~£TZC DATE: Tlr: E, EF'AFEUF£ ~ L' REEEIVED O EC 1 5 1992 Alask~ 0il & Ga~ rJons. Gornmissio~ Anchorage Fnma: NO, M~ASUF~: I.~%:AL ~rSR. TiCAL T~-.:~ S?ATi'-~ ~l~z"~H I. ATITLE'E " ..... D:rTri .~Y-S ft fi fl f.?. Oe~ d~i ft ~sr;,r,': C,,O -',~ -'-z~ ~,.~3 145,r.~ ,,... .... ...... , .,..,¢, .. 373,44 ..... 8485,30 2~5,3 6203,30 41~,~,2 i';', 70 172,12 -1045,05 ~5:7,08 31,8 8233,28 426,0 i9,03 175,45 8541,6~~ 24,5' 82%,57 432,~' 17,77 !77,87 8~2,~3 31,2 828.5,37 ~P,62 i6,42 162,38 -D72,4~ ~EFCE:T~2 £,ISPLACF~S~ ~.t 7"r ! . ¢j.d'!LrrH 142,3~ !41:60 141.79 I42,03 4,51 5,50 8610,60 ~2,21 8.*.',73,52 .".'. · 3t ,6 k~3,35 4~,18 14,78 ~D,23 .~.,~r~. ~..... ~, ':'~,, 1372,61 31,3 8383,~5 ~,5,~ 14,72 2!2,02 -10~'7,33 630,48 1376, ~,7 ~:~Ogu, ~_~ 4TM, . ,r~.. ~ ~,~_, ~ :,,~, ~. :Z~ .. ~_.~ ¢/ 8444,6I ~I,~ 15,44 209,64 -11t1.~ 8~,~ I~2.37 142,32 142,~ 143,13 143,51, 7,4~ !,,~ ,21 ,72 4.7,9 £',470 ~2 494,29 i3S7.8,9 143,% ARCO Ahska, Inc. P. O2~ox 100360 Anchorage, ,A]_~k~ 99510 DATE: 11-20-92 ~-*/~/ 11-1A?~'#> 11-3-92 # ~'~ 12-10A~.~ 10-28-92 # ~'¢~'~' 14-43~,{Wo~ 11-3-92 # ~'~' 17-1~;~/// 10-31-92 ARCO MAGNETIC TAPE(S] WITH LISTINGS DLL/AC/GR Run 1 DLL/C-ZDL/GR Run 1 DLL/MI~/AC/GR Run 1 DI~/aC/C~/Ca~ R,_,,, 1 BCS/DTE Run I Please sign and return the attached copy as receipt of dat~ RECEIVED BY_~_____~~ff___. Have A Nice Day~ Sonya Wallace ATO-1529 APPROVED .~~ Trans# 9225,~- --- CENTRAL FILES (CH) CHEVRON D&M # m~B OCAN~ (OH/CCT) # EXXON MARATHON MOBIL R&D #BPX # STATE OF ALASKA TEXACO RECEIVED NOV 1 9 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3-92 REFERENCE: ARCO OPEN HOLE FINALS 4-14~JT 14-41 14-41 14-41 14-41 14-41 10-23-92 SSTVD Run 1, 10-23-92 DLL/GR Run 1, 10-17-92 SSTVD ~fT-l]¢ ~ Run 1, 10-17-92 DIFL/GR -/ Run 1, 10-1792 BHCA/GR ~' Run 1, 10-1792 Z-DEN/CNL/GR (Raw) '/ Run 1, 10-1792 Z-DEN/CNL/GR (Pow) ~ Run 1, 10-1792 FMT/GR f Run 1. Please sign and return the attached copy as receipt of data. RECEIVED BY ff~L~--~/~-_~ Have A Nice Day! Sonya Wallace ATO-1529 APPROVED_ff~ Trans# 92242 Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas # CENTRAL FILES # Ct~VRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS # PB WELL FILES R&D # BPX # STATE OF ALASKA # TEXACO RECEIVED NOV 09 1992.. Alaska 011 & Gas Cons. Commission Anchorage ANADRILL 2401 C ,ABAR LOOP ANCHORAGE, ALASKA 99507 (907) 349-6575 Prudhoe Bay Unit P.O. Box 196612 Anchorage, AK 99519-6612 October 28, 1992 Attention: Nabors 2ES Drilling Engineer I have compiled a summary of Anadrill's performance on DS 4-14 ST) ~'N¢,~ q 0, 5 '4- Iq I~ SERVICES PROVIDED Directional surveying with downhole weight-on-bit and torque were picked up on OCT-18-92 at 8269' to kick off the well. These services continued to T.D. through bit run number three. On the first MWD run there was a tool transmission failure which necessitated a trip. On the next run the well was kicked off and drilled to the top of the Sadlerochit formation. We then pulled out of the hole and laid down the MWD and the motor at 8846' on OCT-21-92. OPERATING STATISTICS Directional surveys with downhole weight-on-bit and torque totaled 39.8 hours on DS 4-14 ST. Eleven surveys were taken of which the directional driller used four. The bottom hole location at the last survey was: Measured Depth: 8784' Vertical Depth: 8490' Target Section: 494' Latitude: 1123' South Departure: 816' East, with a final drift of 16.4 deg. and an azimuth of 208.7 deg. .lOB PERFORMANCE One MWD failure occurred after drilling 220' of cement and beginning a slide section. The tool turned off for about 10 minutes then came back on. After about 20 more minutes of sliding the tool turned off again and did not turn back on. Initially, mud invasion in the turbine was suspected, however, technicians diagnosed a failed capacitor which caused the loss of the 20 volt supply and the tool shut down. The top of the window was at 8264' and the kick-off began at 8269'. Downhole weight-on-bit was used to facilitate the kick off and the MEL log indicates that we drilled from cement to contaminated formation at 8285' and then into fresh formation at 8303'. This was a good hard plug and the kickoff was down and to the fight. For your convenience, I have included an ASCII file of the surveys along with a hardcopy of the surveys. I have also included a copy of the sticking pipe indicator (SPIN). Note the change in dimensionless torque through the sliding section just after 8300'. A crossplot demonstrates this change in T.D. showing one advantage of using MEL/SPIN. Anadrill appreciates the opportunity to supply services on your well and we look forward to continuing a healthy business relationship. mat ARm Aka{m, ~ Pus{; O~]ce Bce: 100360 Anch0mge, Alaska 99510-0360 Telephone 907 2?0 12 ],5 October 6,1992 A.O.G.C.C, Mr, Blair Wondzell Fax {{276-7542 Well # 4- 10-02-,q2 Cemented from 9299' to an estimated top o! 8550' with 60 bbls. cement.. Estimated 1 $ bbs. behind pipe. Achieved a 1"JO0# equeeze 10-05-92 Tagged cement at 8716'. Pressure tested squeeze to 1500# for 30 minutes, Attatchecl are t{~e well work logs for your review. We are currently continuing with well preparations for the r{g. Please notify myself or John at 659-5872 with any concerns or comments, oemake/John SmaF Senior Well Supervisor ECE]VED ARCO A!a~ka, Ine, 1~ m Submidiarf of Atl~ntioRiohfiei~lCempany Well Work Log "' - ............ - ' j&;co% ............. 'l'Activ~ty --)" ~STwe~l ,", ~es~J~tm ~'Wdm" J T~/TT ~s '" J -C'arrt~rPull~s~. wfKva~ve)" Ca;rlerSor,'No. ' !~a,,~, Re% (aS~C. w/Kv'aNe) j Carrier'S~r. No, I Min. ~st. IDePth ...l $~SV'R~I~As i Tubular Casing Proglems ,, Cost Estimate $ $ .,../. $ ,~ $ ~., Time Log Entry r~Compl~e ,,~.1 :: ...... ~ ~ncomplete ,~'~i;~l<rl (ii! ,~. ¢~',-,.-. ,-, .... ...... u~,;,s:, Coi~imis-s'ion " Anchoraq~ "' Page of WELl. WORK LOG 08:46 09:50 11'00 1._1:4_7. ~L2, :o5 1~:10 it3....20 4J0t88 MIRU 0hbkaan 1810 Biff. · .1. _3:30 Ball o.n eeN, attempt to j.et .past 13:4~ _. li-;i5 total BI~ awaY- ie~ pa~t ledge - nl~ ........................ _t_3;~o Istan rev..e,m,",ii~". No returns; Jet to <~lear,..~'zT.Z:i'~..:':_.s. ta~t getting remrmr@-appx. 1 BPM 14:30 tRetum-~ i~errn~ent - Pump thru nozzle- OGre reve~l~W_l-IIP_ to 1800# 15:0'0' :" ILosir~ returns a~in, Park nozzl~ ~"9000' - Pure 2~ BB~_~'-I~ cl~ coil ..... !15:30 .... [$_t3Br~ rave~jna t.O.,,Get bGII to surface.- g<3<~d returns 1~.:0.S. IBd ~ s~._.~e ':'~D pump e~l mtompt to r~-~-'~~- I~e:3o i~H. ~ ~'o-n"~-~ .................................................. !1e:40:'":..:[i~ ............... PT to 40001i RIH wi3,0" combo nozzle; Well on PWI @ 2,9 BPM ~84511 Tall i~ ~' OOrr to 9~' ;...~a.g..gi~.__..~ 9',a~.._.C.,orr.: ....... :/...."~__. ............. Pulled uo to 8800' [ ,R!H to Get below 8973' where w~J n~ed wT-IoB~ ~iN ........ $..et...down (~ 8973',,- U_n_able to g~.....p, ast; SD B/S Inj.!...$wit~_.....o_h t_o get for better rato 22 BBL8 M/W ...a~V,~_a.[- ...... Unable t._o..W.c~'k pa~t. Drop ball ( 51] BBLS 1 1~# Bio away ) 108:20 .... I.!o/3/oa .,,ot.,i,,~..j- ..... lmJ 08:10 IPT 400,,o~ R!H W/8' sti~ & .3.5" .l:~!..l·.d_ .ro~._..~zzl__e_: Well off PWI @ 3 gPM @ 830~ 0__9;4,5 09:~7 10:35 ..I 12:45 ,15:00 18:00 ,, 1"e:4~; ,, i .... , ~,, r ..... ..::::.,... Om TI'- Staq ~ing oement 8mall WI ~ .~ ~973' but did-not sm~;~ ............... .,'~!:~:.;k~ fiii& Ca~; i:;o,',s." g:~riil, i,~,i(.)~.~ ..... !?I0_-B.-~ @ itatg' CO..~ to ~ .L~j~...- _F_lag ..p~_~"9289' Ar, oho,-¢,.~ ..... G. ement up to Wt ......... Fluid .Io~..~..comir<l in h~h ® 1_5,,0-200-~ - Dum~ cemer~ - Call for fr~l~ mix w~ter Wa(...er on I~ation but comaminate, WI rn~!hanei - Send back to t~rd "- Start mtxir~l cement ,Cement ~ Wt .. PAGE NO, DATE ###### WELL WORK LOG LOG ENTRY loss 15 min, final FL @ 93 cc..i_n 30 min, on line w/FW down B~ ~ 830 )si. 28 bbl cmtl,..,u,.aWay, start aggr...eg, ated'c_mt; gl g~ i-~ii take retU~'~s al WItP:=IO0 psi start F'W 8Daoer. bbt FW FRC, G on Ilrte ~/~.!,54t biO, taka returns at WHP,5O0 PS!.~ _la__y_., in cmt POH at 1:1. at 7300' $1 choke go for 100.0..psi.,_pumpi~ al..1 bpmi' ._ "" lo 1000 !21:05 ~2t :,08 [21:48 21:55 ,22:02... 22:04 00:.3.0 01 ;, ;~.0_ ..... ,ma at lOOO S1 eheke 2.$ Take retuma at t000 psi $1 redUCed coil rate tO 0.5 ~J 3.5 b.,b,p (14 bbp tola. I} Take returns at 1000 ' down coil. .. held !000 psi for 22 mtn, go for 1200 psi, .1200 . Si choke,.go for 1,~)00 p~i Take ,relume at 12r~,, tr..pul 1 bbp..(l$ total bbp!. Start RIH jetting ,..al 80%. Coil 11~ , ~ ~ o' , PUH jettt,r~....._a.t 80%. , .... Ooi) at 7700', R!H.je. tt_lng at ~..o_.il at 885o'r atop Pumping, 153 bio away.,,,.,p_r_e.p to reverse out, ._ Bleed down CTP to 0 psi 8tart PWl ini down b,s, at 1;~',,0 psi, take return'~.....~E, c0il at o.s .bpm Increas_e.., ,1:~,, ! rate lo 1.2 RPM at 1200 psi. ,G~,Getttng 1:1 rMums ...rever~in~ out ..... ¢lean_r~.uma to aurlace .~1 B8 Inj - POOH ~P w/~/It0 MW lmm 2500' _._ . OOH DEK) FP Flowt~ PAGG NO. 21 4- 4 Spud Date: 04-19-78 Original IIKB; 64' Top of Sodlerochtt: 888C7 Anr~tusF!uid: Diesel Deference Log: BHCS 05-02-78 All Depths are RI(B MD to Top of Equipment, Arco Alaska Inc. - Prudhoe Bay Field API~: ,5OO'29-20310-00 Well 'rype: Water Injector Completion Date: 050~78 New ISJl Workover ri Hanger Type: Gray. Gen Ii Hanger: 25' Maximum Hole Angle: 28~ Angle Through Sod,: 16~- 1 Jewelly 2256' Baker PFVE ~ Nipple: iD · 4,~," 8472' Baker L Slitting Sleeve: ID -- 4.313" 8~,~x~' Baker ~ No-Go Nipple: ID = 4.223" 8617' BuRet ,SBR /~semDly 8~7' Baker $^B Packer 8679' 5-1/2' x 4-1/2" Crot~over 8736' BoRer R No-Go Nipple: ID - 3./,59" 8795' Baker Shear-out 8790' 4-1/2" TUDing Tall 879,t' ELM TuDing Tall (.LOgged 09;27-80) Minimum ID: Baker R No-Go Nipple: ID · 3.759" Calling ~ Tubing lO 13-3/8" 72# N-80 O' 2693' Casing 11 9-5/8" 47~ J/L-95/N-B0 0' 9&~6' Casing 5-1/2" 17# L-80 0' 8679' PC Tubing 4-1/2" 12.6~ N-80 8679' 8796' PC: Tubing Toil Peffo~at!on Data (ELM Depths) tnt~a~ ~ FT S~'F 8894-8984 4B ~0 0 ~04-~4 2C: 2D 0 8.9 12 11 PBTD-- 9300 TD ~ Dctum 8700' ~ = ~CI/2' MD 0800 :~ = 91 f0' MI.) 07436-92 CTU ,~ClUeeZe 07-06-92 C. TI J ~quee;,e D7-(16-9'2 CTU Squeeze 07-(~-9~. cru Squeeze 07-06-92 CTU Squeeze 07~6-02 CfU Squeeze 07-(]6-92 CTU Squeeze 12 Revision Dote: 01-15-92/Dy KLM Reason: REMOVE FILL Previous Revlsion: 07-07-92 Welt .... ORIGINAL STATE OF ALASKA ALA,..,A OIL AND GAS CONSERVATION COMMISS .... APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend x Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well__ Plugging x x Time extension __ Stimulate __ Change approved program Pull tubing Variance Perforate __ Other X 2. Name of Operator ARCO Alaska, inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 85'SNL, 466'EWL, SEC. 35, T11N, R15E, UM At top of productive interval 1226' SNL, 1387' EWL, SEC. 35, T11N, R15E, UM At effective depth 1319' SNL, 1439' EWL, SEC. 35, T11N, R15E, UM At total depth 1333'SNL, 1447' EWL, SEC. 35, T11N, R15E, UM __ Plugback for sidetrack 5. Type of Well: Development .__ Exploratory Stratigraphic __ Service xX RE EIVED s E P 1 ? 1992 Alaska 011 & Gas Cons. ~mmt~ Anchorage 6. Datum elevation (DF or KB) KBE = 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 4-14i 9. Permit number 78-36 10. APl number t,,, 50- 029-20310 '~1'; Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical 9365 feet Plugs (measured) 9147 feet Effective depth: measured true vertical 9300 feet Junk (measured) 8984 feet Casing Length Structural Conductor 111' Surface 2693' Intermediate Production 9346' Liner Perforation depth: Size Cemented Measured depth True vertical depth 20" 320 sx Arcticset Ii 111' 111' 13-3/8" 5700 sx Arcticset !1 2693' 2693' 9-5/8" 1000 sx Class "G" 9346' 9029' measured 8894~8984~ 9004~9024~ 9040~9060~ 9086'-9100~ 9143~9168~ 9180~9196~ 9210~9230' true vertical 8592'-8678', 8698'-8717', 8732'-8751', 8776'-8790', 8868'-8883', 8897'-8916' Tubing (size, grade, and measured depth) 5-1/2", 17tt, L-80 tubing to 8679' w/4-1/2", 12.611, N-80 tubing tail to 8796' Packers and SSSV (type and measured depth) 5-1/2" Baker SAB Packer @ 8667'MD, Baker PFVE SSSV Nipple @ 2256'MD 13. Attachments Description summary of proposal x Detailed operations program × BOP sketch.~ 14. Estimated date for commencing operation I O/25/92 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injection Suspended 17. I hereby certify ?at th_ e f~regoing is true and correct to the best of my knowledge. Signed ~b/~' ~- / / ~ Title Drilling Enc.:jineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Net~fy Commission so representative may witness ~ clearance.~___ ,. Plug integrity ~ BOP Test Location Mechanical Integrity Test Subsequent form required ~__~_.~_~__ Originat Signed By Approved by order of the Commission David W .Inhnst°n Form 10-403 Rev 06/15/88 ~'~ JApproval No~.~ Commissioner Date SUBMIT IN 1RIPLICA1E DS, 4,,14 P, lugb, ack Proce( ...e Procedure Outline: (Refer to attached wellbore schematic) 10. 1. Notify an AOGCC representative prior to commencing operations. 2. Rig up coiled tubing unit. 3. RIH with coil tubing circulating seawater. Lay a cement plug from current PBTD of + 9299' MD (69' below the bottom perforation at 9230' MD). Down squeeze the cement leaving the top of cement at least 100' above the top perforation (top perforation at 8894' MD -- cement top no deeper than 8794' MD). 4. RU slickline unit. RIH and confirm cement top at least 100' above top perforations. Note: Tag to be witnessed by AOGCC representative. 5. RU E-line and make a tubing cut at +/-8455' MD (near the bottom of the first full joint above the sliding sleeve) based on completion tubing tally. 6. Circulate well over to seawater and freeze protect well to 2000'. 7. Bleed tubing, inner annulus, and outer annulus to 0 psi. 8. Set 5-1/2" BPV and prepare Pad for RWO. 9. MIRU rig. Pull BPV. Circulate out freeze protection. Pull 5-1/2" tubing. After section milling the 9-5/8" casing from 8250' - 8310' MD, a kick-off cement plug will be laid from 8050'- 8410' MD. RECEIVED S EP 1/' 199 Alaska Oil & Gas Cons. Commission Anchorage General Purpose Worksheet Page No. Of / 4-o ~ ~ / DS ~-14-ST Sundry Permit Int,..mation Objective: The objective of the DS 4-14-ST is profile modification to the Lower Romeo. A sidetrack replacement wellbore is required in the 4-14i pattern to establish Lower Romeo injection. Due to the inability to eliminate the existing well's Zone 3 thief injection, no injection support is being provided to the pattern's LR offtake of 1100 BOPD (5000 RBPD total LR voidage). Establishment of LR injection in this pattern is of critical importance. Recent DS 4 development drilling has added two LR infill producers (4-38 and 4-41) to this pattern, while LR producers 4-31 and 4-32 have previously been cycled for pressure maintenance. Pressure surveys in the Lower Romeo in this pattern show the reservoir pressure to be around 3450 psi and dropping. Lower Romeo injection support is required to prevent continued pressure decline and associated gas cap influx, and support Lower Romeo production. A replacement wellbore is preferable to rig workover options such as a scab liner to provide a mechanically reliable wellbore capable of reestablishing long-term Lower Romeo injection support. The objectives of the 4-14-ST sidetrack are to plug and abandon the original perforations, pull the 5-1/2:.tubing, section mill a 60' window in the 9-5/8" casing, lay a cement plug across the section, kickoff and drill a new 8-1/2" hole to a target 200' west from the original wellbore, run open hole logs, run and cement a 7" 26# L-80 liner, and recomplete with 4-1/2" L-80 tubing. Perforations will be added post-rig. Procedure Outline: 10. 1. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation.Cut 5-1/2" tubing at 8455' MD. Circulate wellbore to seawater. Freeze protect. 2. MIRU workover rig. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set two-way check valve. ND tree. 5. NU 13-5/8" BOP's. Test BOP's to 5000 psi. Pull two-way check valve. 6. Pull and lay down 5-1/2" tubing. 7. Test intermediate casing packoff to 3500 psi and replace if necessary. 8. RIH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 8250' MD. 9. RIH with open-ended DP. Mix and pump 180 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. RECEIVED Page 1 S E P 1/' 1992 9/15/92 Al~st~l.Oii & 6as ~ns. Commission Anchorage DS ,,14-$T Sundry Permit Infv.mation 11. 12. 13. 14. 15. 16. 17. 18. 19. Drill with a 8-1/2" packed hole assembly to total depth of 9282' MD / -9004' ss TVD or 150' MD below the base of Sadlerochit at -8860' ss TVD. RU wireline and log with the DLL / GR / SP / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 26# L80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. Cement liner with 291 sacks based on 40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. RIH with 4-1/2" 9.2# L-80 NSCT completion string w/Z" packer. Circulate corrosion inhibitor down the annulus. Space out, land completion, and set packer at +/- 8650' based on 200' above tod of Sadlerochit'. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. R EEIVED S E P 1 ? 1992 Alaska 0tl & Gas Cons, Commissto~ Anchorage TJ Page 2 9/15/92 ARCO ~tnskn, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-21-92 REFERENCE: ARCO CASED HOLE FINALS 2-22 7-18-92 Prod Profile Run 1, 5" 3-32 7-20-92 Prod Profile Run 1, 5" 4-14 7-21-92 Inj Profile Run 1, 5" 4-41~/~/~'~ 7-19-92 Prod Profile/PITS Run 1, 5" 9-4 7-26-92 Prod Profile Run 1, 5" 9-27 7-19-92 Tie-In/Alpha Patch Run 1, 5" 9-36 7-27-92 Leak Detect Run 1, 5" 14-2 7-17-92 Prod Profile Run 1, 5" 15-23 ~/~/~r 6-22-92 GR Run 1, 5" 15-26~/-/~'v 6-20-92 GR ~ Run 1, 5" 15-27~ ~ 7-18-92 GR Run 1, 5" Please sign and return tt~e attached copy as receipt of data. __ ,E E VE Have A Nice Day! Sonya Wallace AT0-1529 APPROVED__~ Trans# 92194~ Cl~tnco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO R CEIVED SEP 1 5 1992 Alaska. Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA AND GAS CONSERVATION CC" REPORT bF SUNDRY WELL OPEH:ATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 85' S & 466' E of NW cr., Sec. 35, T11N, R15E, UM At top of productive interval 1226' S & 1387' E of NW cr., Sec. 35, T11N, R15E, UM At effective depth At total depth 1333' S & 1447' E of NW cr., Sec. 35, T11 N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-14i 9. Permit number/approval number 78-36 10. APl number 50 - 029-20310 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9365 feet Plugs(measured) 9047 feet Effective depth: measured true vertical Casing Length Conductor 111' Surface 2629' Production 9282' 9299 feet 8983 feet Junk(measured) Size Cemented 20" 320 SX Arcticset II 13-3/8" 5700 sx Arcticset II 9-5/8" 1000 sx CIG Measured depth True ve~icaldepth 111' 111' 2693' 2693' 9346' 9029' ECEIVED Perforation depth: measured All perforations squeezed but leaking true vertical All perforations squeezed but leaking. A U6 1 ? 1992 Alaska .Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8679' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8796' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8667' MD; Baker PFVE SSSV @ 2256' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 11733 4806 Tubing Pressure 1057 1014 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas , Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~iogr nj~0_404 ev~06/15~:8 ~ Title R79/t ¢1 WPl~ ~',~',' .~W . IWP Sr. Area Operations Engineer Date SUBMIT IN DUPLICATE 4-14i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE: IN,JECTION PROFILE MODIFICATION 6/26/92: RIH w/CT & reversed out fill from the wellbore from 9000' to 9297' MD. 6/28/92: RIH & tagged bottom at 9293' MD. 7/6/92: An Acid Wash & CTU Squeeze for Injection Profile Modification were performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4250 psi, then RIH w/CT and reciprocated an acid wash across the perforations at: 8894 - 8984' MD (Z4B) 9004 - 9024' MD (Z2C) 9040 - 9060' MD (Z2B) 9086 - 9100' MD (Z2B) 9143 - 9168' MD (Z2A) 9180 - 9196' MD (Z1B) 9210 - 9230' MD (Z1A) Ref. Log: BHCS 5/2/78. Pumped 100 bbls 15% HCI w/30% Xylene, followed by 40 bbls 1% KCI Water. Pumped 35 bbls of neat latex acid resistive cement, followed by 30 bbls of thixotropic cement, followed by 50 bbls latex acid resistive cement w/aggregate, followed by 15 bbls neat latex acid resistive cement, squeezing the open perforations (listed above). Placed a total of 97 bbls of cement behind pipe at 1500 psi maximum squeeze pressure. Contaminated cement & cleaned out contaminated cement from wellbore. POOH. Rigged down. 7/8/92: RIH & tagged bottom at 9299' MD. 7/21/92: Performed an Injection Profile indicating the squeezed top perforation interval was leaking. Returned the well to seawater injection & obtained a valid injection rate. The well has not been reperforated, and is currently injecting seawater through the top set of leaking squeezed perfs. A Sidetrack of the well is currently being evaluated. ARCO .a19sl~_~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO CASED HOLE FINALS 2-32 ?1-/I/ 6-21-92 Prod Profile Run 1, 5" 3-10 ??--~/ 6-20-92 Inj Profile Run 1, 5" 3-26~3--_/~'/ 6-28-92 Prod Profile Run 1, 5" 4-14 7o~' ~' 6-28-92 Temperature Run 1, 5" 5-5 7~' ~? 6-22-92 Prod Profile Run 1, 5" 7-5 6-23-92 Prod Profile Run 1, 9-38 6-30-92 Inj Profile Run 1, 5" 9-39 6-30-92 Inj Profile Run 1, 5" 12-17 ~-~'~/ 6-29-92 Leak Detect Run 1, 5' 13-158.l-/~'7 6-27-92 Inj Profile Run 1, 5" 13-29o°3-{/3 6-19-92 Prod Profile Run 1, 5" 13-32~-~'/~3 6-27-92 Inj Profile Run 1, 5" 14-14~/-/~ 6-26-92 Inj Profile ,Run 1, 5" 14-36o°.~-/~-~ 6-26-92 Inj Profile Run 1, 5" 16-7 ~5'->~ 6-19-92 Prod Profile Run 1, 5" CalTICO Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the attached copy as receipt of data. Trans# 92150 Have A Nice Day! Sonya W~ll~ce AT0-1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO ARCO Alaska, In, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1990 Mr. John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve . Anchorage, Alaska 99501 Dear John: · Please cancel the following 14 Forms 403 for which no Forms 404 were wri~en. Per the drill-site engineers, this work has not been done and is no longer planned. 1987 D~ate Sig ned 3-4 7-51 1/26/87 4-6 7-263 4/20/87 4-10 7°188 3/20/87 4-10 7-238 4/8/87 4-14 7-264 4/20/87 5-8 7-624 9/23/87 9-16 7-291 4/27/87 14-13 7-399 6/18/87 14-30 7-103 2/13/87 16-24 7-117 2/26/87 1988 3-9 8-826 11/2/88 3-13 8-854 11/17/88 6-13 8-316 4/28/88 9-34 8-864 11/21/88 Please call me ~ ~6~-4~10 if you have any questions ~~rnin~ these S. T. H~fecke,¢· Records ProSessor STH/ab/034 cc: J. L, Glaeser - ATO 1528 ¢ ,I ,! RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany APR 1 8 1990 ARCO Alaska, Inc Prudhoe Ba~ _ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 31, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-14, Permit No. 78-36 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/REK/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 4-14)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/~-~:IL AND GAS CONSERVATION £ --IMISSION ;~:~ iii~ APPLIC (ION 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 X Other X~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 85'S & 466' E of NWcr, Sec. 35, T11N, R15E, UM At top of productive interval 1226' S & 1387' E of NW cr, Sec. 35, T11 N, R15E, UM At effective depth At total depth 1333' S & 1447' E of NWcr, Sec. 35, T11N, R15E, UM 8. Well number 4-14 9. Permit number 78-36 10. APl number 50 - 029-20310 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9365 feet Plugs(measured) 9047 feet Effective depth: measured 9300 feet ~ '. ~ . ~i true vertical 8984 feet Junk(measured) Casing Length Size Cemented Measured JePth-';;q-;True vertical depth Conductor 111' 20" 320 sx Arcticset II 111' 111' Surface 2629' 13-3/8" 5700 sx Arcticset II 2693' 2693' Production 9282' 9-5/8" 1000 sx CI 'G' 9346' 9029' Perforation depth: measured 8894-8984'; 9004-9024'; 9040-9060'; 9086-9100'; 9143-9168'; 9180-9196'; 9210-9230' true vertical 8592-8678'; 8698-8717'; 8732-8752'; 8777-8790'; 8832-8856'; 8870-8883'; 8897-8916' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8796' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8796' MD Packers and SSSV (type and measured depth) Baker SAR packer @ 8667' MD; Baker "P" SSSV @ 2256' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved I Name of approver Date approvedI Service Injector 17. I hereby_certify that the fo_regoing is true and correct to the best of my knowledge. Signed ~~'~J~ Title Operations Engineering Manager 15. Status of well classification as: Oil Gas Suspended Date Y~-~'~.,,t~ FOR COMMIS~;ION H~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form re,(:[uired 10- Approval No. ¢0 "O~ 7 Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Commissioner Date /~pproved Copy Returned SUBMIT IN TRIPLICATE Well 4-14i Coiled Tubing Unit Cement Squeeze Project AFE #AP6168 Preliminary Procedure Objective: Perform a CTU cement squeeze to shut off an Upper Victor injection thief and establish injection into the Lower Romeo. 1. Perform a FCO to establish sufficient rathole below the lowest set of perfs. 2. Perform a Water Injection Profile. 3. Perform a full strength mud acid perforation wash treatment. The perforations will be washed using coiled tubing to pump the following: 5000 gallons HCI/Xylene 2500 gallons Mud Acid 2500 gallons 7.5% HCI RIH with CT. Pack the well with filtered seawater. Pump 95 bbls of cement followed by 2 bbls of fresh water. Squeeze off the , following perforations: Zone Present Interval Shot Density 4 8894-8984 4 SPF 2 9004-9024 4 SPF 2 9040-9060 4 SPF 2 9086-91 00 4 SPF 2 91 43-91 68 4 SPF 1 9180-9196 8 SPF 1 921 0-9230 8 SPF 6. Pump 200 bbls of contaminant following the fresh water and dilute the cement in the wellbore. 7. Jet or reverse out the contaminated cement 24 hours later. 8. Reperforate the following interval two weeks later: (Ref: BHCS 5/2/78) , Zone Proposed Interval Shot Density I 91 8 0 - 9 1 9 0 LSD REPERF 1 9 1 9 0 - 9 1 9 6 FSD REPERF 1 9 21 0 - 9 2 3 0 FSD REPERF Evaluate injectivity into Romeo. as per attached procedure. Perform Lower Romeo only stimulation/biocide 10. Perform post stimulation Water Injection Profile. 11. Reperforate Upper Romeo, Victor and Tango intervals: Zone Proposed Interval Shot Density (Ref: BHCS 5/2/78) 4 8 8 9 4 - 8 9 8 4 LSD REPERF 2 9 0 0 4 - 9 0 2 4 LSD REPERF 2 9 0 4 0 - 9 0 6 0 LSD REPERF 2 9 0 8 6 - 9 1 0 0 LSD REPERF 2 9 1 4 3 - 91 6 8 LSD REPERF 12. Put the well back on injection. Other well information: Current status: On produced water injection--30 MBWPD at 1778 psig ITP. Expected static bottomhole pressure: 3680 psi at 8800' SS Expected fluid in wellbore at reperforation: seawater. Drill Site 4-14i Lower Romeo Selective Matrix Stimulation ARCO Alaska, Inc. proposes to perform the following stimulation treatment: 1. If fill is above 9230' MD then perform a nitrified FCO. . Load The following fluids: a. 7000 gals. of 12% HCI acid with additives. b. 6000 gals. of 6% HC1:1.5% HF with additives c. 6000 gals of 3% HCI with additives d. 4500 gal 5% HOOH (hydrogen peroxide) in 4% NaCI water e. 8000 gals of 2% NaCI f. 6000 gals of 2% NaCI gelled with 50 Ibs/Mgal HEC and 3000 lbs B^F g. 24 bbl dead crude h. 100 bbl methanol 3. MIRU CTU, transports and pump trucks. 4. RIH with CT. Stop CT at 8850'MD and pump 24 bbl dead crude followed by 1 CT volume of 2% NaCI. . d, m. n. o. P. q r. S, t. U, Pump the following fluids down the coiled tubing to stimulate the Lower Romeo interval (9143' to 9230'MD): a. 1000 gal 12% HCI with additives to clean the CT b. 2000 gal gelled 2% NaCI with BAF c. 1000 gal 2% NaCI 1500 gal 5% HOOH I Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI Shut down for 3 hours 750 gal 2% NaCI with BAF 2000 gal 12% HCI with additives 2000 gal 6% HC1:1.5% HF with additives 2000 gal 3% HCI with additives 1000 gal gelled 2% NaCI with BAF 1000 gal 2% NaCI 1500 gal 5% HOOH 1 Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI Shut down for 3 hours Repeat steps 5.g through 5.o 750 gal gelled 2% NaCI with BAF 2000 gal 12% HCI with additives 2000 gal 6% HC1:21.5% HF with additives 2000 gal 3% HCI with additives 2000 gal warm Methanol (75 deg F) to dissolve BAF 6. POOH with CT. Pump remaining 2% NaCI and freeze protect. 7. RD and release CTU, pump truck and transports Reference Log BHCS 5/2/78 6 5 4 3 2 COILED TUBING UNIT BOP EOU ! PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS · 3. 5,000 PSI 4 1/6" HYDI~ULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX H]RELINE BOP EQUIPMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5,000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Aiaska 99510-0360 Telephone 907 263 z~248 Donaid F. Scheve Operations Engineering Manager April 15, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-14 Permit No. 78-36 Dear Mr. Chatterton: Attached is the "Intention" Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp Attachment cc: Standard Alaska Production Company Pi(DS 4-14)W1-3 WELLS/46 ARCO A~aska, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~-] Alter casing I'll Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska, 3. Address P.O. Box 100360, AnchoraAe, AK 99510 4. Location of well at surface 85' S & 466' E of NW Cr. Sec. 35, TllN, R15E, UM At top of productive interval 1226' S & 1387' E of NW Cr. Sec. 35, TllN, R15E, UM At effective depth At total depth 1333' S & 1447' E of NW Cr. Sec. 35, TllN, R15E, UM 5. Datum elevation (DF or KB) 64' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 4-14 8. Permitnumber 78-36 9. APInumber 50-- 029-20310 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured 9365 feet true vertical 9047 feet Effective depth: measured 9300 feet true vertical 8984 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 111' 20" 320 SX Surface 2693' 13-3/8" 5700 SX I n termed i ate Production 9346 ' 9-5/8" 1000 SX Liner Perforation depth: measured 8894-8984'; 9004-9024'; 9034-9054' · true vertical 8592-8916' Tubing (size, grade and measured depth) 5½", 17#, L-80 @ 8796' MD Packers and SSSV (_type and measured depth) SAB Hydroset Packer @ 8672' MD, Baker "R" SSSV @ 2259' MD ; 9080-9094'; 9137--9162' Measured depth ~ue Verticaldepth 111' 11].' 2693' 2693' 9346' 9029' 12.Attachments Description summary of proposal [] Detailed operations program [-J BOP sketch 13. Estimated date for commencing operation ~/1/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,~ertify that,the foregoing is true and correct to the best of my knowledge ~~~~~ Title Operations Engineering Manager Signed Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance[ "7 t,.,~ ~/ Approved by Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit icate TJI~.T.T..q//,~ T_ A. R'ITl-~e,.qlc, v_ ATO-1506. 265-6871 DS 4-14 PWI CTU SQUEEZE PROCEDURE AFE 794571 · . . e . . . , Tag PBTD. Last PBTD was ]2172 on 3/16/87. Stop injecting produced water until after squeeze. Rig up co~led tubing unit. Clean out fill to 9300'. I,owest perf ~s 9230'. Perform biocide treatment at end of fill cleanout. Acid wash perforations 8900-9230'. Ensure well is fluid packed before pumping cement. Pump 48 bbls cement down CT. Pressure up on squeeze to 5200 psi BHP and hold for 45 minutes. GIH contaminating cement to PBTD. Slowly bleed wellhead pressure while contaminating to leave a minimum of 200 psi d~fferential into the formation. WOC a minimum of 12 hours. Reverse out. contaminated cement. Freeze protect and leave positive pressure on the well. 9. Wait at least one week prior to reperforating. 10. Nitrogen lift top 3000' of fluid for drawdown during perforating. (Ref: BHCS 5/2/78) 4 spf Lower Romeo 4 spf Lower Romeo 26' 11. Reperforate 9190-9196' 9210-9230' 12. Evaluate injectivity into Romeo. (Separate AFE.) Perform stimulation if necessary. 13. Reperforate Victor and Tango intervals: (Ref: BHCS 5/2/78) 8900-8990' Limited shot density Upper Victor 9010-9030' " Lower Victor 9040-9060' " Lower Victor 9086-9100' " Tango 9143-9168' " Upper Romeo 9180-9190' " Lower Romeo 179' 14. Place well on injection. 15. Run post squeeze injection profile survey. AFE2/98 6 5 4 3 2 iii 1. 5000 PS1 '7" WELLHEAD CONN£CI'OR FLANG[ 2. 5000 PSI 4 1/16" PIP[ RAMS 3. 5000 PSI 4 4. 5000 PSI 4 1/6" SHEAR RAMS ,5. 5,000 PS! 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX CO ! LED TUB I NO UN I T BOP EOU I PMENT i ii m i i m 1. 5000 PSi ?" WELLHEAD CONNEC'I'OR IrLANG[ 2. 5000 PSI WIRELIN[ RAMS (VARIABL£ SIZE) 5. 5000 PSi 4 1/6" L UBRICA'I'OR 4. ,5000 PSI 4 1/6" FLOW 'I'UB£ PACK-OFF H I REL I NE BOP EOU I PMEN'[ Anchorage, Al~.s'~a 99.5~ (.) t}ATE' Apri[ 7, ~986 F:,'I.:.]F'EF:,'EN(L'.E ' AI',,CO C.,'~':~ s'ed I--Io I. e F'i n a !. D ]: .? "F R I B U "F I 0 i'-..! ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 18, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - DS 4 (Wells 14, 15, 28) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L138 Enclosure If RECEIVED F E B 2 ! ],986 AJaaka 0il & Gas Cons. Comm~il~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany gruJ cr' I II I I I II II III I IIII IIII I ~' I III II 0 EXISTING WELL HEADS / ~ NEW ~/ELL HEAD ! 2. PLAN PLANT COORDINATES AS PER j ~BEC DW~ PLD-2715-O0001~ S~ 401~ ~[~8 3. AS-BUlLT COORDINATES FOR WELLS , 14 A 15 REClEVED FROM VECO SURVEYING~ SECTION 35, TIlN, RISE~U.M.~ AK. LOCATION ~N SECTION STATE PLANE COORDINATES PLAN PLANT A/B PLANT COORDINATES t4 85.0' 4811' 5~51800.45 ~13~01.74 ~+00 i5 205~ 4787' 5951685.84 713529.27 (S) 0+20 1~60 28 149' 4798' 5951737.22 713516.14 0+35 16+60 0~35.10 16-t-59.49 RECEIVED Alaska Off & ~s Cons. A~c~or~g~ I I II I II I IIIII I IIII I I IIIII I II II II I I III I I I I I ~E~T1F!C~TE OF SURVEYOR, ~~~ ~S-~UILT WELL LOCATION 'HEREBY CERTIFY THAT I~ PROPERLY ~~..0...~4~1J. DRILL SITE No. 4 LAND SU~VEY)NG )N THE STATE OF ~*~~ ~ '~,'& ~ ~ . ,~. SURVEYED FOR' BY ~E OR 'JNDER ~Y SUPERVISION, f,'~_ ~ 6919~ ~ ~ AND THAT ALL DIMENSIONS AND ¢~¢~ % ¢~-~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date: January 29, 1985 Reference: ARCO CH Finals .... 4-6 Prod. Loggoing Svs. 1-9~ Production Profile 12-19Injection Profile 4-14 Spinner 18-3 Prod. Logging Svs. 4-4~- Spinner 1-9 CNL 15-9~-~epth Determination .J12-22Perf. Record 12-28Perf Record ~-17 EPL ~12-27Perf. Record ~4-8 Spinner 4-15 Spinner j6-3 Spinner ~t3-18Spinner ~6-3 Diff. Temp. _-.15-9 Collar Log ..2-15 Temp. Survey 12-27-84 #1 DA 5" 1-3-85 #1 Camco 5" 1-2-85 #1 Camco 5" 12-16-84 #1 GO 5" 1-10-85 #1 DA 5" 12-15-84 #1 GO 5" 12-20-84 ~1 GO 5" 11-9-84 ~1 Sch 5" 11-29-84 ~1 Sch 5" 12-3-84 ~1 Sch 5" 10-4-84 31 Sch 5" 12-1-84 ~1 Sch 5" 12-27-84 ~1 GO 5" 12-16-84 ~1 GO 5" 12-21-84 ~1 GO 5" 12-2b-84 ~1 GO 5" 12-21-84 ~1 GO 5" 12-2~-84 ~1 GO 5" 12-24-84 #1 GO 5" ~n and return tha attached copy as receipt of data. Received by Pam lambert Trans 016 ATO i429C Chevron D&M Exploration Services Extension Exploration Texaco Marathon Mobile Mmbile E & P Phillips Prudhoe Bay Well Files R & D Sohio State of Alaska ARCO Alaska, Inc. --- Prudhoe Bay E leering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 Permit # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS 17-10 Permit # 81-97 Dear Hr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb RECEIVED At t achment s JAN 2 5 19 5 cc: Sohio Alaska Petroleum Company Alaska Oil & Gas Cons. C0mmlssl0n Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL,~] OTHER [] 2. Name of Operator 7. Permit No. A~CO Alaska, Inc. 78-36 8. APl Number 50-- 029--203:].0 9. Unit or Lease Name Prudhoe Bav Oni~ 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (surface) 85'S & 466'E of NW cr Sec 35, TllN, R15F,,[~. (Producing Interval) 1226'S & 1387'E of NW cr Sec 35, TllN, R15E,UM (Total Depth) 1333'S & 1447'E of NW cr Sec 35, TllN, R15E,[~4 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28324 10. Well Number D.S. 4-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Perforate Stimulate Repair Well Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: Pull Tubing (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made [] Other ~] [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska Inc. has converted DS 4-14 to water injection service. the Flow Station 2 waterflood project. The well began receiving water on November 20, 1984. The well is part of 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. e .r The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" h'~ Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, ~. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 20, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 4-6 (22-3-10-15) Permit No. 76-83 DS 4-8 Permit No. 76-10 DS 4-10 Permit No. 76-42 DS 4-11 Permit No. 78-6 DS 4-14 Permit No. 78-36 DS 4-15 Permit No. 78-37 Dear Mr. Chatterton: Enclosed are the Sundry Notices and Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Enclosure~ cc: SOHIO Alaska Petroleum Co. File P1 (DS 4-6) W4-3 File P1 (DS 4-8) W4-3 File P1 (DS 4-10) W4-3 File P1 (DS 4-11) W4-3 File P1 (DS 4-14) W4-3 File P1 (DS 4-15) W4-3 RECEIVED NOV2 o 1984 ARCO Al&sk&, Inc. 18 · Subsidiary of AtlantlcRIchfleldCompany ..... STATE OF ALASKA ALASK,~ alLAND GAS CONSERVATION , MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E]( Water Injector ,~... 2. Name of Operator 7. Permit Number ARO0 Alaska, Inc. ?8-36 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 5o- 029-20310 4. Location of well at surface 9. Unit or Lease Name 85'S & 466'E of NW cr Sec 35, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1226'S & 1387'E of ~ cr Sec 35, TllN, R15E, UM DS 4-14 At Total Depth 11. Field and Pool 1333'S & 1447'E of NW cr Sec 35, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB] ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 116. No. of Completions 4/19/78 5/4/78 5/9/78J feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9365' ~D 9047' TVE 9300' ~D 8984' TVD YES [] NO []I 2195 feet MD 1900' (a~prox.) 22. Type Electric or Other Logs Run DTT,/SP, B~CS/C~/G~, FDC/e~/C~L/GR, O~L 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 111' 30" 320ex Arcticset II 13-3/8" 72# N-80 Surf 2693' 17½" 5700ex Arcticset II 9-5/8" 47# N-80 & Surf 9346' 12%~" 1000ex Class G cmt J & L-9!~ 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) 9040'- 9060' MD * Perf added 10/19/84 ~:: ~,796' 8,667' 9086'- 9100' MD w/4 SPF 9143'- 9168' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · 8894'- 8984' MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED '9004'- 9024' MD · '9210' - 9230' MD · '9180' - 9195' MD 8592' - 8882' TVD N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 29, 1982I Future Injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO N/A TEST PERIOD Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) 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.['.~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SLIDE - ~.-, .- ., : - , ~,,, ~.,~. ... . ...~.. ~., ,, ,- ~, O.. . ,.,..,, .. ,-, ,. ,-. . 29. '"" !i~.-: (~EO~0'(~ic'I~RI~ER~'" ": ~:::' ,' :' .?.' *" ":'.: ;" ;-: ;;~:;' i!'.;;i?'}; 'i'. ;'!' "' I~'oRMATI~N~TES~S '"'" '" '; ; '" · NAME _ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GQR, and.time of each phase. . Top _Sad_ ]~t 8880' 8578' Base S~t 9245' 8931' . 31. LIST OF ATTACHMENTS ,, .... · '.' ,,'-' :'-'..'1 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~l~,~~~ Title 1:~"_,~n~'1 l~-li~'~r 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ....... STATE OF ALASKA . ALASF DIL AND GAS CONSERVATION ,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 85'S & 466'E of NW cr Sec 35, TllN, R15E,UM (Producing Interval ) 1226'S & 1387'E of NW cr Sec 35, TllN, R15E,UM (Total Depth) 1333'S & 1447'E of NW cr Sec 35, TllN, R15E,UM '5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28324 7. Permit No. ?8-36 8. APl Number 5O- 029-20310 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 4-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations []{ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 10/19/84. RU, pressure tested equipment. RIH w/gun ~1, shot interval 9010-9030'MD (4SPF). Shut-in well, POOH, all shots fired. RIH w/gun 92, shot interval 8970-8990'MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, attempted to shoot interval 8950-8970'MD; gun misfired, shut-in well, POOH. RIH w/gun #3A, shot interval 8950-8970'~) (4SPF). Shut-in well, POOH, all shots fired. RIH w/gun #4, shot interval 8930-8950'MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #5, shot interval 8910'-8930' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #6, shot interval 8900'-8910' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 5/2/78 14. I hereby cer~fy that the fo, r,~going is true and correct to the best of my knowledge. ~~~~C _~~ Regional Engineer Signed . . Title The space betow for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date .................. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-6 DS 4-8 DS 4-10 DS 4-11 DS 4-14 DS 4-15 Permit No. 76-83 Permit No. 76-10 Permit No. 76-42 Permit No. 78-6 Permit No. 78-36 Permit No. 78-37 Enclosed are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/la - Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 4-6)W1-3 File PI(DS 4-8)W1-3 File Pi(DS 4-10)W1-3 File Pi(DS 4-11)W1-3 File Pi(DS 4-14)Wl-3 File PI(DS 4-15)W1-3 -- STATE OF ALASKA ALASK,. ~iL AND GAS CONSERVATION C ,dMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-36 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20310 OTHER [] 4. LocationofWell(Surface) 85'S & 466'E of NW cr Sec 35, TllN, R15E,UM (Producing Interval) 1226'S & 1387'E of NW cr Sec 35, TllN, R15E,UM (Total Depth) 1333'S & 1447'E of NW cr Sec 75, TllN, R15E,UM 5. Elevation in feet (ndcate KB, DF, etc?) ! 6. Lease Designation and Serial No. / 64' RKB I ADT. 2R324 72. 9. Unit or Lease Name Prudho0 Bay Unit 10. Well Number D, S. ·4-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate X[-] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 4-14 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. Proposed Perforation Intervals: 8894-8984' MD w/4 spf 9006-9024' MD Reference Log: BHCS 6/15/76 14. I hereb~/~rtif~ th~ fo~)goi~s tr.u: and correct to the best of my knowledge. Signed ~//'~~ ~ f~/~/ Title Regional Engineer The space below for Commission use Date /'/ Conditions of APproval, if any: Approved by Approw~d Copy ltoturn¢~l By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer September 17, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-6 (22-3-10-15) Permit No. 76-83 DS 4-11 Permit No. 78-6 ~~it No. 78-36 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/DWR/mjb Enclosures cc: SOHIO Alaska Petroleum Co. File P1 (DS 4-6) W4-3 File P1 (DS 4-11) W4-3 File P1 (DS 4-14) W4-3 RECEIVED SEP ! 81984 Alaska Oil & Gas Cons. CommJssJorl Anchorage · ~ STATE OF ALASKA (~' ALASK. ? DIL AND GAS CONSERVATION ,, .~MMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE%El Water Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 78-36 - 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20310 4. Location of well at surface 9. Unit or Lease Name 85'S & 466'E of NW cr Sec 35, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1226'S & 1387'E of NW cr Sec 35, Ti]iN, R15E, UM DS 4-14 At Total Depth I 1. Field and Pool 1333'S & 1447'E of NW cr Sec 35, TION, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKBI ADL 28324 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115'Water Depth, if offshore 116' No. of Completions 4/19/78 5/4/78 5/9/78I feet MSLI 1 17. Total Depth (MD+TVD) 1B.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9365' MD 9047' TVD 9300' MD 8984' TVD YES[] NO[] 2195 feet MDI 1900' (approx.) 22. Type Electric or Other Logs Run DIL/SP, BHCS/CAL/GR, FDC/CNL/CAL/GR, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surf 111' 30" 37_0.~× Arcf~-..q~l- TI 13-3/8" 72fA N-80 Surf 2693' 174" 570Osx Arcticset li 9-5/8" 47f~ N-80 & Surf 9346' 12~" lOOOsx Class G cmt J & L-95 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) '9040'- 9060' MD 5~" R_7q6' R Ag7, *9086'- 9100' MD '9143'- 9168' MD * Perf added 8/10/84 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. W/4 SPF DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9210' - 9230' MD 9180' - 9195' MD 8733' - 8882' TVD N/A 8 shots per foot 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 29, 1982I Future Injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO N/A TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECEiVE. D SEP 1 8 Alaska 0il & Gas C0r~s. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 8880' TRUE VERT. DEPTH 8578' 8931' 30. 9245' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~//~'~ ~ Jt~~ Title Regional Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item .5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing toot. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc.-~ Prudhoe Ba ~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer September 17, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 4-6 DS 4-11 Permit No. 76-83 Permit No. 78-6 Permit No. 78-36 Attached are "Completion" Sundry Notices for "Subsequefit Reports" on the above-mentioned well. Very truly yours, D. F. Scheve DFS/DWR/mjb Attachments CC: Sohio Petroleum File Pi(DS 4-6)W1-3 File Pi(DS 4-11)W1-3 File Pi(DS 4-14)Wl-3 RECEIVED SEP 1 8 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany · STATE OF ALASKA ALAS, OILAND GAS CONSERVATION )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL [] OTHER [] 2, Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 85'S & 466'E of NW cr Sec 35, TllN, R15E, UM (Producing Interval) 1226'S & 1387'E of NW cr Sec 35, TllN, R15E, UM (Total Depth) 1333'S & 1447'E of NW cr Sec 35, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 6. Lease Designation and Serial No. ADL 28324 7. Permit No. 78-36 8. APl Number 50- 029-20310 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 4-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 8/10/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 9148' - 9168' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #2, shot select-fire interval 9143' - 9148' MD (4 spf), pulled up, shot select-fire interval 9086' - 9100' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #3, shot interval 9040' - 9060' MD (4 spf), flowed well to clean up. Ran SSSV, secured well, RD. Ref: BHCS 5/2/78 RECEIVED SEP 1 19B Alaska 0il & Gas Cuns. Commission Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date ................. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In, Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 9, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-6 (22-3-10-15) - Permit No. 76-83 DS 4-11 - Permit No. 78-6 DS 4-14 - Permit No. 78-36 DS 4-15 - Permit No. 78-37 Enclosed are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. D. F. Scheve DFS/WT/mjb Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 4-6)Wl-3 File Pi(DS 4-11)W1-3 File Pi(DS 4-14)W1-3 File PI(DS 4-15)W1-3 .... STATE OF ALASKA ALASK, .)IL AND GAS CONSERVATION £ ,VIMISSION SUNDRYNOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL[] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell (Surface) 85'S & 466'E of NW cr Sec 35, TllN, R15E,UM (Producing Interval) 1226'S & 1387'E of NW cr Sec 35, TllN, R15E,UM (Total Depth) 1333'S & 1447'E of NW cr Sec 35, TllN, R15E,UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 64' RKB l ADL 28324 12. 7. Permit No'. 78-36 8. APl Number 50-- 029-20310 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 4-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [--I Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations to DS 4-14 with intent to convert to a water injection well. Perforations will be added to selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9040 - 9060' MD (20') 9086 - 9100' MD (14') 9143 - 9168' MD (25') REF: BHCS 5/2/78 RECEIVED AUG 0 9 i984 Alaska Oil & Gas Cons. Commission Anchorage 14. ' hereby ~rtj~v tha~_ the.f.~egoj~g is true and correct to the best of my knowledge. ~ .~/'/~.)~ / ~)/~¢~.~r Regional Engineer Signed _ itle The space below for ~ommission use (/ Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy R~turned -- By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office F ~360 Anchorage, A,,~.;ka 99510 Telephone 907 277 5637 November 6, 1982 Reference: ARCO Pressure Data D.S. 4-14' 10-7-82 Pressure Build-Up Survey D.S. 12-4A* 9-26/28-82 Pressure Build-Up Survey D.S. 16-12 10-14-82 Pressure Build-Up Survey Otis Camco Camco '*The service company lists this PBU as 12-4 however, the correct number is 12-4A. Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Trans. #604 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Post Office Box 360 Anchorage, ~-L3ska 99510 Telephone '. 277 5637 October 15, 1982 Reference: ARCO Case Hole Finals D.S. 6-21/~9-9-82 CCL/Perforating Record D.S. 6-21f 9-12-82 CBL/VD D.S. 6-21 / 9-9-82 CBL/VD Run 1 SCH Run 1 SCH Run 1 SCH D.S. 13-1~/ 6-20-82 Differential Temp. Survey Run 1,2,&3 CAMCO D.S. 12-2 ~/6-21-82 Differential Temp. Survey Run 1,2,&3 CAMCO D.S. 4-14~/ 10-7'-82 Spinner Survey Run 1 OTIS D.S. 13-17~9-26-82 ~ Spinner Survey Run 1 D.S. 3-6~/ 9-13-82 Engineered Production Log Run 1 /easesign and return the attached copy as receipt of data. Becky Benedict AFA - 403 . OTIS SCH Trans. 9550 DISTRIBUTION NORTH, GEOLOGY EXXON R&D MOBIL DRILLING GETTY~ ~. SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON DALLAS ARCO Alaska, Inc. Post Office b,~.~. 360 AnchoraGe, Alaska 99510 Telephone 907 277 5637 July 13, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: D.S. 4-14 D.S. 11-1 D.S. 11-2 D.S. 11-5 D.S. 12-7A D.S. 12-8B D.S. 12-9 D.S. 12-13 D.S. 14-5 D.S. 14-19 D.S. 14-20 Permit No. 78-36 Permit No. 81-123 Permit No. 81-128 Permit No. 81-155 Permit No. 81-175 Permit No. 81-167 Permit No. 80-93 Permit No. 81-87 Permit No. 78-64 Permit No. 81-45 Permit No. 81-70 Enclosed are Completion Reports for ~work done on the above-mentioned wells. Very truly yours, Regional Eng±neer DF S: TKKW Enclosures Distribution: Sohio Petroleum Co. ARCO Alaska, inc, is a Subsidiary of AtlanticRichfieldCoinpa:W ' . ' - .... STATE OF ALASKA -~-- ALASK~ ..... IL AND GAS CONSERVATION C,...¢IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. permit Number ARCO Alaska, Inc. 78-36 3. Address 8. APl Number P.O. Box 360 Anchorage, Alaska 99510 50-029-20310 4. Location of well at surface 9. Unit or Lease Name 85'S & 466'E of NW cr Sec 35, TllN, R15E, UM Prudhoe Bay Unit , At Top Producing Interval 10. Well Number 1226'S & 1387~E of NW cr Sec 35, TllN, R15E, UM D.S. 4-14 At Total Depth 11. Field and Pool 1333'"S & 1447'E of NW cr Sec 35, '£10N, R15E, UM Prudhoe Bay Field -- 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool 64' RKBI ADL 28324 1'2. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I15'Water Depth, if offshore 116' No. of Completions 4/19/78 5/4/78 5/9/78I ---- feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9365'MD 9047'TVD 9300'MD 8984'TVD YES [] NO [] feet MD 22. Type Electric or Other Logs Run DIL/SP, BHC S/CAL/GR, FDC/CNL/CAL/GR, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 111' 30" 3208x Arcticset II 13-3/8" 72# N-80 2693' 17-1/2" 5700sx Arcticset II q-5/8" 47~ N-80 & 9346' 12-1/4" 1000sx Class G J&L-95 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) 8 shots per foot 5-1/2" 8796' 8667' 9210' - 9230'MD 9180' - 9195'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8804' - 8852'TVD 27. PRODUCTION TEST Date First ProductiOn I Method of Operation (Flowing, gas lift, etc.) 3-29-82I ¥1ow±ng Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE.SIZE IGAS-OILRATIO 4-14-82 12.2 TEST PERIOD ~ 2288 5321 20 31I 2806 Flow Tubing Casing Pressure cALCULATED .1~ OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 1666 NA 24-HOUR RATE~ 3954 11095 0 33.2 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. t~nch0ra,qe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGICCMARKERS ' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH - GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,.d .,_,,.,,.,.,,,.,..o..-, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Post Office B,._ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 13, 1982 Mr. C.V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: D.S. 4-14 D.S. 12-7A D.S. 12-8B D.S. 12-9 D.S. 12-13 D.S. 14-5 D.S. 14-19 D.S. 14-20 Permit No. 78-36 Permit No. 81-175 Permit No. 81-167 Permit No. 80-93 Permit No. 81-87 Permit No. 78-64 Permit No. 81-45 Permit No. 81-70 Enclosed are Subsequent Sundry Notices detailing the work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DF S: TKKW Enclosures Distribution: Sohio Petroleum Co. ARCO Alaska, ir',.c, is; a SL.,bsidiary' of At!aaticRichfieldCon'~Daiiy STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360 Anchorage, Alaska 99510 4. Location of Well 85'S & 466'E of NW cr Sec 35, TllN, R15E, UM (surface) 1226'S & 1387'E of NW cr Sec 35, TllN, R15E,UM (top produc£ng) 1333'S & 1447'E of NW cr Sec 35, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 12. I 6 . Lease Designation and Serial No. ADL 28324 7. Permit No. 78-36 8. APl Number 50- 029.-.20310 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 4-14 1 1. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforation operations 3-26-82. Pressure tested tree, casing and wireline perforating equipment. Perforated 9210'-9230'MD and 9180'-9195'MD (ref BHCS 5/2/78) with 8 shots per foot. Well cleaned up flowing to test separator. Ran static pressure survey. Ran and set SSSV and tested. Installed and tested tree cap. Released well to Production Department, 3-29-82. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate , ARCO Alaska, inc. · Post Office B '~'~60 Anchorage, A,. Ca 99510 Telephone 907 277 5637 April 21, 1982 Reference: ARCO CASED HOLE FINALS D.S. 15-2 u/~ 3/7/82 CBL/VD Run 1 5" D.S.5-17/ 2/26/82 EPL Run - 5" D.S.2-19~,~j~' 3/20/82 ACBLfVDL Run 1 5" D.S.2-1~,,-' 3/24/82 CNL Run 1 5" D.S.15-3 ~,z,' 3/23/82 ACBL/VD Run 1 5" D.S.16-5~'~ 3/22/82 Collar & Perf Log Run 1 5" D.S.16-12~ ..... 3/20/82 Collar & Perf Log Run - 5" D.S.16-6 '~/ 3/24/82 Collar & Perf Log Run - 5" · D.S.16-13 ~'' 3/18/82 Collar & Perf Log Run - 5" · D.S.4-14 ~''' 3/27/82 Collar & Perf Log Run 3 5" D.S.4-!4 v~" 3/26/82 Fluid Density Log Run 1 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 117 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS ~ D&M SOHIO' GEOLOGY MARATHON CHEVRON ARCO Alaska. ;nc. is a s,J~s~',J'~ry o! AllanhcRichfieidCo;npany STATE OF ALASKA ARCO Alaska, Inc. · Post Office B'--~360 Anchorage, A,-oka 99510 Telephone ~07 277 5637' April 15, 1982 Reference: ARCO PRESSURE DATA D.S.4-11 3/27/82 D.S.4-14 3/28/82 D.S.14-3 3/14/82 D.S.9-6 3/5/82 D.S.12-3 3/5/82 D.S.13-1 3/13/82 Pressure Survey Pressure Survey 1! II 11 II 1! '~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 102 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ARCO Alas~..~. ~n¢. is a s.Jbs,'Ji~lry Of Atlan~;cR~chfleh;Company ARCO Alaska, Inc~- F,~ o rib SIo }istrict Post Office Anchorage, Ai~sk~:~. 99510 Telephone 907 277 5637 Jerry A. Rocl~on District Operations Engineer March 16, 1982 Mr. C. D. Chat Chatterton State of Alaska'- Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S. 4-11 D.S. 4-14 D.S. ll-1 D.S. 11-2 D.S. ll-3 D.S. 11-5 D.S. 1 D.S. 1 D.S. 1 D.S. 1 D.S. 1 Permit No. 78-6 D.S. Permit No. 78-36 D.S. Permit No. 81-123 D.S. Permit No. 81-128 D.S. Permit No. 81-147 D.S. Permit No. 81-155 D.S. 1-6 Permit No. 81-161 2-4A Permit No. 81-187 2-7A Permit No. 81-175 2-8B Permit No. 81-167 2-13 Permit No. 81-87 13-5 Permit No. 81-103 13-7 Permit No. 81-129 13-8 Permit No. 81-148 13-9 Permit No. 81-158 13-10 Permit No. 81-165 13-12 Permit No. 81-142 D.S.. 13-t9 Permit No. 81-180 D.S. 14-12 Permit No. 81-109 D.S. 14-13 Permit No. 81-101 D.S. 14-26 Permit No. 81-110 D.S. 12-14 Permit No. 81-138 Enclosed are our Sundry Notices detailing the work to be done on the above mentioned well. Ve~truly,,-")y°urs',.. · --,,~-~ _:: < -: - :'E,-,.--,--- .... a. A. Rochon JAR: TKKW :ml c Enclosure ARCO Alaska. Inc: is a subsidiary ol AtlanticRichliehlCol~-;pan? ~ STATE OF ALASKA .... ALASK, IL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78- 3 6 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50_029-20310 4. Location of Well 85'S & 466'E of NW or Sec 35,TllN,R15E,UM (surface) 1226'S & 1387'E of NW cr Sec 35, TllN,R15E,UM (top-producing interval) 1333'S & 1447'E of NW cr Sec 35,TllN,R15E,UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 64' 6. Lease Designation and Serial No. ADL 28324 9. Unit or Lease Name Prudhoe Bay Unit 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Subsequent Work Beported 14.. hereby cer~hat the fo,~g~oing ,s,~nd correct to the best of my knowledge. · ~, ~ t Signed / Title Dist. Opts. The space b/~/for Commission use EngJ neer Conditions of Approval, if any: By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company Norlh Alar--' District Post Office ...,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 19, 1980 Reference: ARCO Magnetic Tapes D.S. 3-6 RES 1 ENO · 2' EN~- 3 EN,'?, .4 ENG 2 GEO ]'t~_~- 3 GEOL / STAT TEC .... STAT TEC '- .................. "-CO~FER: :II.F.' 11/3/80 Tape #File 1 NLLG (Pass t-3)File 2 (Pass 4-5) 9250-9950 ii/ii/8o Tap~#/CN/MS 8600-9290 D.S. 7-lb 11/2/80 Tape# CNL/MSN 10000-10980 P.S. 14-5 10/30/80 Tape# C/O 8680-9350 D.S..17-h i0/29/80 Tape# CN/m$ i010o-ilgo0 ~/Please sign and return the attached copy as recefpt of data. Mary F. Kellis North Engineering Transmittal #827 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL ' GETTY '"' SOHIO ; '- ~RATHONcHEVRON - .., ARCO Oil and Gas Company is a Division ol AtlanticRichheldCompany ARCO Oil and Gas North Alask, ...,istrict Post Office Box 360 Anchorage, Alaska 99510 'Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 3, 1980 Reference: Arco Cased Hole Finals D.S. 2-13 9/25/80 CNL Run 2 D.S. 7-11 9/29/80 CNL Run 4 5" D.S. 7-14 9/28/80 CNL Run 2 5" li}i '- i 2 ENO 3 ENO 4 ENo 1 GEOL :~-~'EOL 3-bEOt. STAT TEE:-- STAT TEC CONFER: FILF: Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering TRANSMITTAL #773 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON Alaska 0il & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Oivision o! AllanticRichlieldCompany North Alaska ])istrkt Engineering T RANS M I T TA I, To' From' 3. A.' Rochon/~._~.,. ~_ .o 8 cc e'~ Transmitted herewith are the following for the subject well' Run No. SCale Xerox Sepia BL Line BHC Sonic/Caliper Log .... 1'-BHC Sonic/Caliper - Gam~na Ray Log ~"~~ BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL [f.Co.~ensated Formation Density Log _ ~" i Coinpensated Neutron-Formation Density ~ ~4'--~' .Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey -' Gyro Single Shot ~ltishot Drill Stem Test - Test No. Daal Induction Laterolog Formation Density Log Formation Density Log/Gan~n~a Ray Gmma Ray/CCL Laterolog Location Plat Microlaterolog .. Microlog ~'.'kldlog- Intm~al Sample Log. (A.R. Co~)'- Interval Synergetic Log 'I¥1)- DI L TVD-Porosity I,og !receipt Acknow].edged For' Date' ease return receipt Atlantic North Alaska Engineering P. O. Box 360 B)': ~'.iani,cHich~ieldCompany North Alaska District Post Office "~*' 360 Anchorage, ¢,,.,ska 99510 Telephone 907 277 5637 , 1978 Enclosed are prints of the following wells' Ganm~a-Ray Neutron Log . D.S. #4-9 5" Compensated Neutron D.S #4-11 5" Continuous Flow Survey D.S. #3-8 5" Borehole Audio Tracer Su~ey - Differential Temperature Log NGI '#2 5" Due to an error in reproduction, Some copies of sepias are prefolded. If this~of an), inconvenience to you, please request another copy and it will be sent as soon as possible. If all data is acceptable to you, please sign attached copy of letter and return it as receipt of data. Vez~y truly yours, R. A. Logue North Operations Engineering RECEIVED Division North T R A N S b l I 'J' 'J' A [.ted herewith are the £ollowing fox' the subject well' J. A. Rochon/R. No. Scale' Xerox Acid or Fracture Treatment Log · BHP Buildup & Flow Profile Su~ey Borehole Geometx~r Log. Carbon Ox)%en Log Casing Collar Log. Cement Bond Log Compensated Neutron Log - Cased Hole Core ~malysis - Interval Core No. Core Description (~!C) - Interval Core Description (Cony.) - Core No, Directional Surv.ey- Gyro - Single ' 'Engineering Production' Log · Fluid Analysis . Fluid Density Gamma' Ray Locatim~ Plat Monthly Well Test Data ~lud Log Perforat~g Record . State Reservoir Pressure Report Surveillance Reports Temperature Log Transient Pressure Surveys TFD Logs -. ~tel Induction I,aterolog - Compensated Fo~ation Density Log - Compensated Neutron-Fm2ation Density Log - BorM~ole Compensated Sonic Log - Porosity Log t,Jce.-i:p't: Acknow].edged '[ease ILe, t:urn P, eceJ.pt To: Ms. R. A. Logue Atlantic Richfield Company P. O. B. ox 360 Anchorage, Alaska 995]0 REC' iV D Atlant[cRichfi~ldCompeny --~ North Americ.-~.~ Producing Division North Alask ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 2, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, A1 aska 99501 Subject: DS 4-14 Permit No. 78-36 Dear Sir: Enclosed please find a Completion Report along with the Drilling History and Multishot Survey for the above-mentioned well. Very truly yours, Frank M. Brown District Drill ing Engineer FMB: j h Attachments SUBMIT IN D..;. _'ATE STATE OF ALASKA ~s~, OIL AND GAS CONSERVATION COMMITTEE II i [ i i i WELk cOmpLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 0F WELL: WELL WELL ~ DRY Other b. TYPE OF COMPLE~ON: %V F, LI. OVER EN BACK RESVR. Other 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. I. OC~TION OF WELL (Report location clearly and in accordance with any State requirements)* 8~'~f~c~466'E of NW cr Sec. 35, TllN, $15E, UM At top prod. interval reported below 1226'S & 1387'E of NW cr Sec. 35, TllN, R15E, UM At total depth 1333'S & 1447'E of NW cr Sec. 35, TllN, R15E, UM 5. AP1 NU1VI~12[CAL CODE 50-029-20310 6.LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDI~MN, A_LLOT'FEE OI{ TRIBE NA2~IE 8. UNIT,FAIkM OH LEASE NAME Prudhoe Bay Unit 9. WE~L NO. DS '4.-14 - ~ruqhoe ~l~ vrumnoe FOOl 11. SEC., T., R., lYI,, (BOTTOM HOL~ OLZJ EC'TiV E) Sec. 35, T11N, R15E, UM 12. P~R2M[IT NO. 78-36 P I~OW 1VL~Y* ROTARY TOOLS : -- CABI,E TOO! 9365'MD 9047'TVD 9300'MD 8984'TVD Single All 22. PtZODUCING INTERVAL(S), OF THIS COiVIPLETIO~I--TO~ITM, BOTTOM, N'AI~IE(MD AND TVD)' ,2'3. %VAS D!tiECTIONAL , SUI{ VEY MADE 'Fop Sadlerochit 8886'MD 8584'TVD { Base Sadlerochit 9254' MD 8939'TVD .~ Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/CAL/GR, FDC/CNL/CAL/GR,CCL i , i -- ii i iii ~5. CASING RECORD (Report all strings set in well) CA. SI2~G SIZE ] \VEiGHT, LB/FT. "G~A0~ D~TH SET 20" ~94~ Welded/ H.40I L13'3/8" I72~ Butt I N-8012693' 9-5/~" ~47~ Butt ~ N-80~9346' IJ&L-'951 , , ~ , 26. LINE~ ~CO~ SIZE TOP (.','ID) EOTTOB/i (.MD) SACKS CEMENT* i , 28. ERFORAT'~ONS Opw_;N TO P[iODUC O1hl (intcrval, size and number) N/A Ill I I~ I II II III j i iii i i 30. PFtODUCTION HOLE SIZE .1 CEMLNTING RECOIH) ] it.MoUNT PULLED I7-t/2"15700 sx ~rc.ticset II-~-~t ] 12-.1/4"[1000 sx Class G cmt SCiLEEN tR~.D) SJZE DEPTI-I SET (~qD) 5-'i/2" 8796' i 8667' 29. ACID, Si:©T, DE~lqli INTF_~VAL (MD) A?,I:.~UNI'~z~ND I~:!Ni) OF' MA'iEfIiAL USF:,D ~ PACIiEI~ SET ().iD) N/A iifFl~'ll ii i i iiiiii i - il Ill' DATE FIRST PI~ODUCTION ] P~ODUCTION NIEI[iO,D (Flowi~ng, ?;as tif[, pumping--size and type of pump, ¢1~':'~, f~qTATUS (Producing or / I tTEgT WITNESSED BY 82. LIST OF ATTACHMENT8 Dr~ll~n¢ H~story, Hult~shot D~rect~ona! Survey 33. I hereb~ certify that the forego~n~ and attachefl Infor~ation 1~ 6omp'lete and correct a8 determined from all-~'allable SIONED[~m'g:-''~-' /'' ~~ _ TITLE D~strlct Dr~ll~nq En~!neer DATE ......... i i *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct weJl completion report end log on all types of lanz{s and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attachments. Items'}0, and 2~2:: If this well is completed for separatc, prcduction from more than or~e interval zone (multiple completion), so state in item 20, and in iteq~ 22 show the prcJuci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the inter~,01 reported in item 30. Submit a separate report (page) on this form, adequately identified, for each edditional interval to be seperately produce, J, show- ing the ack:litional data pertinent to such interval. Item]6: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of ~ny mul- tiple stage cementing anti the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). 34. SUMMAItY OF FORMATION TF~'!'S IN(.'L,U!)IN(; INTERVAL TF,~TED, I~}~.ES. SLJRIg DATA AND ~COVERI~ OF OIL. GAS. 35. G ~GIC MARK~ WAT~ AND MUD NA~ MEAS. D~ ~U~ V~T. , . ' '36. C~E DATA. LL. lmm mm m m . . ,,, ,, DRILLING HISTORY DS 4-14 API 50-029-20310, ADL 28324, Permit No. 78-36 Spudded well @ 1300 hrs 4/19/78. Drld 17-1/2" hole to 2710'. RU & ran 13-3/8" csg w/shoe @ 2693', FC @ 2612' Cmtd w/5700 sx Arcticset II cmt w/0.6% D13R. Installed & tstd pkoff. Drld ~-hoe & 10' new-hole. Tstd form to 12.0 ppg. Drld 12-1/'4" hole to 932'3'.. Dropped multishot. Ran DIL/SP, BHCS, FDC/CNL logs. Ran sidewall cores. Drld to 936'5'. RU & ran 9-5/8" csg w/shoe @ 9346', lower FO @ 2487', upPer FO @ 2362~. Cmtd w/lO00 sx Class G cmt w/0.75% D65 mixed to 15.8 ppg. Sqz thru lower .FO 300 sx Arcticset cmt w/0.3% D13R & 0.2% D59 mixed to 15.7 ppg. Did Arctic Pack job thru upper FO. Displ mud w/wtr & wtr w/'CaCl2. Ran GR/CNL/CCL logs. Ran gauge ring & junk bskt. RU & ran 5-1/2" compl assy w/tailpi'pe @ 8796', pkr @ 8667', landing nipple @ 2256'. Pulled dummy valve Displ CaCl2 w/diesel. - NU & tstd xmas tree. Ran CCL/dummy gun. Press tbg ~or long term tbg tst. Released rig @ 2030 hrs 5/9/78. A PETROL.ANE COMPANY REPORT of SUB-SURFACE DIREC TiONA L SURVEY ATLANTIC RICHFIELD COMPANY COMPANY %4-14 WELL NAME PRUDHOE BAY LOCATI ON JOB NUMBER A578 SO314 TYPE OF SURVEY DATE MULTI-SHOT SURVEY 5-11-78 SURVEY BY EDWARD J. BUTLER OFFICE ALASKA -.ATL. ANT.I C.-, R I CHF-] ELD. COt~PANY O~ HAGNETJC ~ULTI~HOT..-.~LIEVEY BECL.I~AT[ON 31,~ D~Ge-~AST -COMPUTED-- FOR -EA. ST~AN WHIPSTOCK-. BY-~ Fe---~e-~L ].NDSEY- AND A-~SOC[ ATE5 , RECO~D_OF_ SURVEY ................................. ALL_ CALCUL.AT l ONS. PERFOR~ED...B:~ I. 8_ M_.ELECTI.{ON l C_ COMPUTER .~!EA.$,__DRIFT VERTICAL SUB ........... DRIF.T TOTAL.COORDINATES ............ C L O-5-.U .R-..E 5 ................. S/VERITY ................ SECT-ION .DEP?.;~..ANGLE ...... DEPTH .................. SEA ........ DJREC DiSTAnCE ................... ANGLE ............... D/GllOOFT .............. DISTANCE ..... ~' ...... O ....... ~ ................. 0.06 ............. ~-~,00-'" s~ .oow o.eo s o.oo w o oo s o o o ' o ~ __!0~B ....... 0....15 ..... 1007,9~ g~3,98 ..... N66,00E ................... 3.,7~+._S ......... 0,~5 E ~,77._5 6. 59._29 E ............ ~,~5~ ................................ ....... l~g5 ........ 0._30. ~9~e9? 1430.97 $39,00E .......... ~,~3 S 3.3~ [ _. 5.55 5 3~...5B.2~ ..E ............... 0,0Sl .......................... ~75.~ ...... 2660 0 30 2659.92 .25~5,92 N73,OOE 7.2~ S 12.50 E 14,44 5 59 55 3~ E 0,048 13.42 :~-~ ~ h-:_~-~- ..... o .... ~ ~ ~ ~. ~'~ .... ~ ~'o'5', ~ z ...... r~ 3 ~;'~o ~'":7~T-~';-"~ .'~-~-:'..'"s-.'~ ........ __Z".'~ ~-, ~ ~ ~:f' '_'--.';':~/z ~ '--~'Z_.'s"T~ ~-':4'~T:T~":'~.17:: '~b',, ~ ~': ..... 2~9._57 .... 0_._30 ..... 2956e 9"0 2892,90 .... _N32,00~ 3050 0 ~5 3049.89 2985,B9 N65,00E ...... 3143__ 0 30_. 3142,88 307B,B8 NSi,COE _~ ~3.7 ....0 45 ...... 3236,88 ~172eBB .... NSIeOOE _._9330_. _0 30 3329,87 ~265,87 .... }42F. ~ 0 3422,~7 3358,~7 N45,00E _~.51.6____0._30__3515,86... 3451,86 .... 3610 0 ~0 3609,85 3545,a5 $85,00E _ ~703__ 0 30 3702,~5 363~,85 _. 3796 0 45 3795,8~ 3731,84 . __38 ~t9 __. ! 0 38~6,83 382~,~3 N70, OOE 39B3 1 0 3g~2,82 3918,~2 N68,00~ 4262 0 ~5 ~.2Sl. 79 ~197.79 ..... 5,32 $ ....... 1~.57 £ ...... 15.51_$__.69.5~.2b.E ........ 0,266 .............. ~.50 S ~5,17 E 15.82 S 73 29 17 £ 0.259 12.93 3.83_ $ 15.92 E 16.37 $ 76 26 32 E 0.2&9 ........ I2,P' 3.30 $ I~.77 ~ 17,t0 $ 78 5! 49 E 0.269 .... ........ 2,69_$ !7,57__E .............. 17,77_.5._~1_.24._ 5...E ............. 0,Z~6 1,9.~ 1,02 O, 14 0,13 0,03 O,lO ....... 0,64 1,42 2.2~ 18,28 E 18,38 S 83 57 26 E 1~,09 E 19.11 5 ~6 55 42 E 19,93 E 19,93 S 89 3~ 20 E 20.67 21,48 2'2.48 23.8B 25.41 26.8~ 27.99 28.99 20.67 N 89 37 31 E 21.48 N 89 54 11 E 22.~a 5 59 43 58 E 23.88 N 89 52 10 E 25.~2 N 88 33 8 E 26,87 N 86 57 1~ E 29.08 N 85 25 18 g 29,14 N 84 1M 40 ~ 0.269 ~.2.8~ ...... 0.538 ;L2,6~ .... 0.53S ................. 1Z o.o3B .. 13,27 0.269 0.037 0.262 15.50 0,269 15.58 ..ARCO _.. DS 4-].~ ..................... ~4AGNETiC _.~ULTI.SHOT SURVEY ................................. NAY ...................... RECORD OF SURVEY .................... D M ............................... DE'G,, D ..... M ....... ~ .A4~9_ 0 ~5 ~,~,48.77 __~_63.~ ......... 9_ 3Q ......... ~63 ~ ,.76 ..... ~ 570,76 .... ~.728 ...... 0.~5 .~7~7,75 4663.75 __6822_._ 0 ~5 6821.7~ ~757,7~ _.Ioo8 ....1_3o... 5oo7.71 . _~5.195 8_ 30 5193,88 ....... I,~0E ..........*.~2 N 30.9~ E 31,25 N 81. 5Z _. 3 E..~ 0.014 1~,6~ l,O, OE ................ 5,10 a 31,g~ E ...... 3~,35 N 80..55 ~I..E 0,I~1 ..... 15,78 l?OOi ...................... 5,5!..a ............... 32,83. E ................... 33,30__N_.,80._,.!0 ........ O_.E ............ 0_,169 ............... 8,OOE 6,10_N ..... 3~,70.E ....... 3~.25 a Y? ~3 ~8.E ....... O.Z6~ ............ 16,08 6.00E ........... 6,77_N_ 3,.74 E. 35.3.9___N 78 57 37__E ........ ]D~02~ ................ 1~20 1.00£ 7.62 N ...... 35.~~. 2,00E 3.70 N ~1.36 E ~1.52 N 8~.._53 7 a 3.76~ ........ ~2~71 9eO0~ .......]7.55 S 5~o9~ ~ __ ~1.50 5 73 R~...53 E ........ 3.763'. ................ 50~Z9 3.00£ 3~.23 5 7~.~ E 81.02 5 65._ 0_..~3 E._. 3.776 ...... ._~56~ 19 0 5553.89 ~661 20 30 _._58~7 21.30 5815.21 __59~1 22 15_ 5902,~ _6127 2~ !5 6073,81 _ 6220 25 0 6158,68 6~07 26 0 6327.29 6500 26 0 6~0.87 -. 6593 ~6 45 6~94.~9 ___. ... 6686 26 45 6577.2~ _ 6780 27 0 6661.09 6873 27 30 6743.77 . 6966 28 0 682G.07 5~00,75 5666,~6 .. 54 5751,21 5838,~ S3 592~,28 53 6009.81 609~.68 6~63.Zg 53 6346,87 6430.19 $3 6513,2~ 6597.09 6679.77 53 6762,07 53 $~2 · 5OE ............... 53 · 91.. 1.50E 76.07 2,00E .... 99-52 1,50E ........ 123,96 1.OOE 1~9,16 g,OOE 175.9~ goO0£ 203.79 8.00~ 232,37 . ?.OOE 262.53 6,00E 29~.91 ........ 6.50E $27.64 6.50E 360,41 6,50~ 393,62 7.00E 427.i6 7.50E 460.99 7.COE ~94.8~ 7.005 529.46 9t.63 111.59 132.51 154.33 176.43 198.9~ 221.&5 2~4.19 267,33 291.29 . . 315,29 339 * 5~ 36~.lX ._ 3~9.I6 4!4,88 4~0.65 466,71 E ............ 106,31 .5_59...31 _48 E ............... 2,68? .......... ......... ??,OB ..... __~ E .... 135.0.5 5.. 55 ~.2 57 E I-0'7'0 .... 12~),85 ....... E 165.72 5 53 5_34 E 1,61~ ..... 160,22 ' E ............ 197,g5._5..51 .13_i0.E ......... 0,277 ............. 192,91. _ _ 45,.70 5 ~3 53 57 495.16 S ~3 17 30 536.21S ~2 46_11 577.85 5 ~2 20 ~ 620,19 $ ~1 59 il 662,63 5 41 40 57 705.80.S ~1 23 44 0,810 0,85~ . 261, ...... 0-806 ....... 297,17 ...... 0.317 333.69 ........ 1.891 __ 371.70 __~ 0,~23 ......... 411o96 0.268 ~52,~2 _ 0,000 493,Z7 ...... 0,806 53~,56 ...... 0.262 576,~X __. 0.2B8 618,89 ........ 0.550 ..... 661,47 0.538 _ 70~,7~ DRIFT VERTICAL ............ SUE) D.~IFT .......... TOTAL_.COORD!NATES ......... C L O._S U.R'_E $ ............ SEVERITY D H _.~3.2_.2~ 0 7239,03 7175,03._ $39,OOE 699,83_ $ ..... 599,29..E ... 92!,37 $ 4.0 3~.~29__E ......... 0,000 .............. 7526 26.15 ....... 7323.06 725g.06 539,00E ........... 732,57.S ..... 625,81. E ............. 963,48....$...~0.. ~0 21_.E ............ 0~796 ......... .__7805...2~ ~5. 7575.0~ 7511,04 $37,00~_ ~26.~8 S 700,09 E _ 1083.1~...$~0..!6 I.i ........... 0,~28 ........... 1082~! .... 7~.99.._.2~_15 .....7660.58 ...... 7596,58_S37o50£ ....... ~5~§1 ....... $ .......... 72~.66 E .........!!22~0.7._..$.~0 ........ 9_.~3_E ............ o,53g .............. .... ~085..2~ 30 ....7830,5~ 7766,58 536.00E ....... 917.87 $ ..... 76B,97 ~ ..... 1197,~2 $ 39_57 19 E .......... ~,56~ ............... ~!96.~9_~ 8272 22 0 8002,87 793a,$7 537,00E 976,11 S 812.~5 E 1269,99 $ ~9 46 18 E 1,06~ ................................................ __~45~ 19_..65 ..... a176.72 .... 811~,72 ......5~,59~ .......1GE9.798._$ ....... 850.72 E ...... I~3~,89...._~_.~9_3~..!~._.e ..........!,077 .............. _ ~6m$ 18 0 8353,60 8289,60 $33.00E._1080.35 5 . ~84.55 E _$7~ .... 17_30 8~2,17 .... a378.17 ...... 531.00E ..... 110~.40 $ .... 899,57 E .......... .... 883! 16 30 85~1,11 8467,11 S29.00E_.. 1127,9~ S.. 913.17 E __8924_.15..15 .... 8620.56 ._8§56.56 530.00E 1150,08 $ .. 929.69 .... 9017_15_15__8710.28 ...... 8646,20 .... $29.00~ ...... 1171.37_$ ....... 937,74_ E _9111 14 45 8801.08 8737,08 $29,00E 1192,65 $ 94.9,53 E . 920~ lq 30 8691,07 8827,07 $29.00E 1213,19 S 960.92 .... _.9Z~6__.1~ 30 8931.73 8867.73 S30,OOE 1222.34 $ 966.09 _9329. 14 30 _9006,28 B9~2.28 $~O.OOE 1239,0~ $ 975.73 E 1396.26 S 39..18 33 E_ _ 1,069 ............ 139~,Q ! .... 1~24,40 S 39 ...... 9.50 E .........0,572 ....... 1~51.25 $ 38 59 ~5 i 1.089 ........ 1~76,35 S 38 ~9 49 E .......... 1.346 ......... !~76.28 ..... 152~,~8 S 3S 31 30 E __ 0.5~2 15~7.6~ S 35 22 52 £ 0.~69 ...... 15~7.66 155~.03 $.3~ 19_17 E ___ 0.59~ ........... 1577.tl $ 38 13 12 E _.0.000 ....... !577.11 _ _ DOTTO,,',.! HOL.F. CLOSURE 1577.11 FEET AT $ 3B 13 12 E .ARCO._. DS 4.-].4 '~.AGNETIC ~ULTISHOT SURVEY ............... HAY_.09)1978 ...................... ................ DEP T.~ ............................ DEPTH. ...... SEA.~ DIFFE~fJJC~ii ..... i.'_~_~..C.O~ECT ION ............... TOTAL .... ~OORDI.~AT~,~ ..................................................... , 254 564 664 200 0 0 0.50 S 0.30 W 300 0 0 0,96 5 0,57 W 400 .......... o 0 ................................1,56 5 0,94..w 500 .... 0 ..... 0 2.~! $ ................. 600 . _0 0 ........ ~,08.$ .................... 1,~ W 700 ... 0 0 D,69 5 ......................... 0.)97 W 800 O O ... 9.9? S 0-39 - ~$~ 964, ..... 900 ............................ !o6A ................. ~o6~. ),ooo .......... .................. 1164 116~. 1!00 126~ 126~. 1200 ....... !A64 1~64. 1~00 ........ 156~ . 1~6~, 1500 ]~64 166¢e 1600 176~ ~76¢e 1700 186~ 1B64. 1800 ........ lg6~ 1964. 1900 3.89 $ 0.22 E 3.58 $ ............. !,22 E 3.6~ $ 1.83 E 3.86 S 2,~9 E 0 ........ 0 ~.27 $ ....... 3.1~ E 0 0 ~.89 S 3,7~ 0 0 5,50 $ 4.~6 E 0 0 6.03 $ 5.0~ E 0 0 6.50 $ ~.78 E _ ............... 0 0 6.89 S 6,56 f 206~ 206~. 2000 0 O ....... 2164 216~. 2100 0 0 ._ 226~ 226~. 2200 0 0 ..... 2364 236~. 2300 0 C _ ........... ~46~ ...... 2464, 2~00 0 0 ........ 2564 256~. 2500 0 0 __ 265~ 2666. 2600 0 0 _. 276& 2764. 2700 0 0 .................. 286~ 2864, 2BO0 .... 0 0 ...... ~964 2964, 2gO0 0 0 _.. 306~ 306~. 3000 0 0 316~ ~164, 3100 0 n ............. ~264 t264, 3200 0 0 __ ~354 3364. 3300 0 0 ........... ~a6~ 3a8~. FaO0 0 0 3B!,& 356a. 3500 0 0 _ 7.20 S 7.38 E 7.~2 S 8,22 E 7,56 $ 9,08 E 7,61 S 9.95 E 7,57 $ 10.82 E 7,22 S 12.53 E 6.51 $ 13,60 E 5,32.5 ..... 1~.57 E .................... 4.45 S 15,20 E 3,76 S 16.08 E 3.18 $ 16.92 E 2.43 S 17.~2 E ........................ ],66 5 18,50 f 0,57 S 19.53 f 0.09 N 20,28 E .. ......... _. ' ..... ~AGiiET!C MuL~T'IsHOT SURVEY TRUE VERTICAL SUB HD-TVD VERTICAL ................... 376~ ............. ~76~, .... 3700 _ 0 ............ 0 0,05 S ...... ~064 ~06~, ~000 0 ............. 0 1,30 N ............. 26,.66_E ................... ~36~ .... .~6~. ~300 ...... 0 ....................... 0 _ _ 3.72 N .......... BO,06 ............... 4664 4664, 4600 0 ......................... 0 .... 5.72 N .............. ~066 506&, 5000 0 ........ 0 5e?~ N .................. ~165 .................... 516~, ......... 5100 .......... 0 .................................. 0 ...................... 1,~9. $ ................ ............ 52~6 ...... 5266~ 5200 .... 2 ................... i ............. l&,12 5579 556~. 5500 1~ 5 78.71 $ 113,88 ............... 56B5 566~ 5600 '-' 21 ......... 7 105.79 S 5792 576~o 5700 2~ 7 13a.19 $ 163~22 .............. 5899 ......... 5fl~e 5800 .... 35 ................ 7 163o80 ............... 6008 ............ 59~° 5900 ....... ~3 ......... 8 .... 195~82 $ ..... ~5°00 6116 ~06~, 6000 52 9 228,96 $ 2~1,51 6226 516t, 6100 61 9 2~,5X $ 268,82 6337 626~. 6200 72 11 302.87 5 297°08 ............. 64~8 .... 636~. ___ 6300 ..... fla ............. 12 .... 342.I2 $ ..... ~25,81.E ~559 6~6~. 6400 95 Il 3~1.51S 35~°87 .................................................... 6~71 656~° 6500 107 12 a2~87 5 .............. 67fl3 6664. 6600 119 12 462,07 5 415.70 $~96 6764° 6700 131 12 503,51 5 447.01 7009 686~. 6800 145 14 545.57 S ~75,85 ........ 7122 6964. 6900 158 13 587.65 ~ 510,93 7235 706~, 7000 17! lJ 629,6z, S 5~3,15 ............................... .SURVEY .................................................. _~JAY .................. 7682 .............................. 7~6~, .......... 7~00 .................. 7793 ............ 756~. ...... 7500 ..... 229 11 790 ~ .......................... 766~ · ............ ~600 ........ BO12 776~. 7700 257 9 266 9 96~.43 5 802.89 ..................... ..................... 27~ B 995.57 5 826.7~ B969 866~, 305 9176 8~6~, ~2 ~ 1207, O~ S 957,5~ ......... .... ~15 3 1229.50.5 970,23 9121 786~, 7800 8230 796~, 7900 8398 8064e 8000 8100 ~200 ~00 8400 8500 8600 8700 9279 8964, 8900 .......................................... HEASUR ED VER T [ CAL 5U~ ..... 1000 99g. 935. ~,77 $ 0.41 E ....................... ~ooo ............ 2,99. 2935. .............. ~. 18. _S ............ 15.,q~ E ........... ~000 3999. 3935, .......... 0.75.N 25,68 E ................................ 5000 6999. ~835, 7.6~ N 37,57 6000 5956, 5892. 193,52 S 213,16 E .................... ........................................................ .............. 7000 6~56. 6792. 542.21 S 476.~2 8000 .......................... 7752. ......... 7688. ..................... 890.~b _.S ............. 7~B.6~ ......................... 9000 ....... 8~,93. 8629. .... 1167.67.S ...... 935.56 E ..... -_-. ............ j ~.T-.~-R.Poi:ATE:D.--TRU.£ ' V£RT'i~CA'L,--'"DEp THS';-'--CO~R D'i'N'~;~'T'~. s''' AND' "~'Lo.~u'R "F6'A--G I' v~-'-b'EpTi~'& TRUE ~C"ODE ..................... ~EASURE'D .......... VERT l CAL ................ TO'TAL ......... CO0'Ri~I N'~TES ................. C L- .... NAHE '" DEPTH L~E PTH ........... DISTANCE _ .............................................................. i- .... HORIZONTAL. VIEW CALE I% 500' ATLANTIC RICHFIELD COMPANY DRILL SITE 4-14 RADIUSIOF CURVATURE .................................. MAGNETIC MULTI- SHOT , J ! ! _ _ J : ? j ] ' .............. . .................................... VERTICAl_-'SECTION SCALE I"= i000 ATLANTIC RICHFIELD COMPANy ...... DRII.:L * SITE" 4-,14 -- RADIUS OF CURVATURE .... MAGNETIC MULTI- SHOT . , 5600- ...'-_-2-; ............ : ........ : *. .......... ALL DEP_THS SHOWN ARE TVD, : .... ~ .................. i .... 7600 .................. : ~ .... L ................. . : ........... ~_.. : , ._;&._; ...... 2_:_L L._' ........ '__&J~__-'-' , ....... ;' ~.' ...... ;-"-'*' =- .... ' ......... ~ ~----~ .......... ~_T_V_D =~00.6 .... .... ~ ~ ; ........ ,. ........ j ....... TMD= 9323: ' ......................... ............................. ............................................. ........ ; .... i ' ; DIRECTIONAL AND DI~/L~.ING CC~S~~ ATLANTIC RICHFTEr.~ CG4PANY Wk-~J. NO. 4-14 ~ICN PR~E BAY _MAY 9, 1978 ~TL-AN:T-IC--R"I CHF iELD COMPANY : DS' A-[ ~ ' '--- 4AGNETIC SINGLE' :SHOT SURVEY DECLINATION ~.~DEGe EAST ::'>' ~AD~ ~S-' OF''''~ CURVATURE '~ETHOD OF-- COHDUTATIONS K ~B. ELEV, ~-FEE~ ;OMPU'TED ..... FOR' DON BAKER INC; BY F,H, LIflDSE'"Y" AND ASSOCIATES ........................................................................................................................ RECORD" OF"'SURVEY ALL" CAI~CUL'ATION5 DEt~FOR,~ED BY' I'~) M ELECTRONIC CO~4PUTER ~'EA $'~'--DRI'FT "VERT I CAL ............. SUB .................. DRIFT .................... TO'TAL'" ¢OORD i NATE$ .................... C'"'I~ "O S'-'U""R" £'" $ ................ SEVERITY ........................ $ E C 1 JN ...... DEPTH'-'ANGLE DEPTH SEA DIREC DISTANCE ......... ANGLE .......... DEG/JOOFT ....... DISTANCE .... ................... D M DEG, ........... : D ...... M 5 ........... -O ..... O ..... 0 ............. 0,00 ..... -6~,00 531o00w"' ..................................................... 'O"00'-S ' 0.'()0 w O'00 S 0 0 0 W O.000 0.O0 ....... ~14 ......... 0 ...... S0 S13.'99 4~9.99 S3I.O0W 1.92 S ' 1.15 W 2,2~ 5 3i 0" 0'W 0.09'7 0,8[ ........ -I00'8 ....0 ..... 15 ......... 1007~ 98 ........9h3'*98 .....N66*'OOE ............... 3','7~ '"S ................ O. ~5 E ................... 3 * 77'""S ...... 6 "-S9 '2'9 -E ................. 0 ;0'5 i .............................. 1495 ........... 0 30 149A.97 1430'97 $39'OOE ............... t~"43 $ ........ 3.3~' E 5.SS'"S 36 '58' 24-E .... 0.051 .................... -2660 ......... 0 30 2659 28~2 0 ..... :SO ........ 28~+1 -9896 ...... 0 30 ...... 3895 '%922 ...... O'AS '~921 -50~ ..... 2 i~ ...... SO~ -~33B-13 '4~' '~331 '77 ..... 4969*'77 ........ ,56 ...... 5062.56 "6~ ....5215"65--S~7, · 3~ ..... 5267'3~ 539. 00E ............. 1'76 'S ........ 35' 00E .................. 6,O2-'S ......... 40. ODE ..... i5.18'5 ..... ~, DOE ............. 33.57 $ 62. OOE ........44'19'S ........ 71. 50 E - I~.~+4"5'"59--'5B '34 E .... 0,048 ~ ~ ..... E ................... 15, $ l"-" S '"' 6~- ~ 9 "-2 8 '"'E .............. 0' ~ 1 ~: 13 E 22.30 5'83 .... 0-33'-E ............... 0.027 19 E 33.20 5-88"'20 12'E ............ 0'02~ 90'"E ............. 35,'94'-5-'-B7 10 .....56-'"E ....... 23 E ..... ~O'68' S'-'SI .... 28""~2--E ............. 3.226 t9 E 50,53 S 72"'30-49 E .............. ~'842 23' E ............... -~O",~5-~-6'6---~'2-~S- E ......... ' 7o-s --'s .......... 3~ E 83.92 .... 5-'58-13 33-E ......... 5760 21 0 5735 -6[6~-'26 0 ..... 6i08 "-6517--26 .... 0 ..... 6'~28 -7099-27 '45 6947 -fi766'-17 0 ..... ~47~ 92n~ .... l&--30 .... ~9~0 DE ........ 57,0§-S ..........82 .'52-'E ............. ~00,32 ....$-'SS--20"-3A- E ......... 1'*-667 DE ......... 1'32.27-S .... 150.26'- E ....... 2OO'19'-5'--~8 38--29-E ......... 1~289 ............. o~ ...... ~,'9~ .... s ........ 2s~ '~s' '~ ........ ~s~.~6-' s'-~s"-~s-~6- ~ ....... 0,760 .............. DE .... 967~25'-5 ..... 3~2,46 E ......... 502.15--S-4'2--59- SS'-"E ..... O"5gO 500.04 · 80---7961-,BO SS6'OOE ....... 972,14 5 ...... 79fl..27 E .......12~7'89 S-S9 2S'"27-E 0.52'/ ........... · 'I9 S876.79 S30eOOE i2i~.88' $ ....... 9~Te~T'E ........ 1543.75 .....S 37 51--22'E .......... 0"52~ ............. 9025.11 8961,11'-SS0'OOE ....... 1237'42 5 ..... 95~.,08-'E ........ 156~,',97'-5-"37"44--§6"E ......... 0.575 ......... 15~'~"97'-- AOT'tO~'HOLE CLOSURE T : . .~ , , ..................... . A-RCO ............................................. ~4AGN-ETIC SINGLE SHOT SURVEY ................................................. MAY05~1978 .................................. ~ ~'ff'A'$ORED-'OEPTH "AND'"OTH~R'"DATA- FOR-EVE. RY-'~V~N .... 100 FE[T'""'OF SUB TRUE HEASU~/D VERTICAL SUB MO-T'VD ...... VERTICAL 264 ................................ 466 .................... 564 564 664 664 T64 764 86'~ ................................... 864 100 0 0 O, 200 .................... 0 ...................................... 0 .......................................... O. 300 0 0 O. 400 0 0 1. 50.0 0 0 600 0 0 700 0 0 800 ................ 0 i064 11'64 .........................i164 1264 '126~ ................... 1364 ......... 1~6~ ............... 16~ ........ ~6~ 176~ ....................... ......................... 1964 1964 964, 900 O 0 3, 1064' I000 0 ........ 0 ), * ............ 1100 ............... 0 .................................... 0 ................. 3, 1200 0 0 1300 .... 0 0 1'400 ......... 0 ...................................... 0 150'0 0 ........ 0 1500 0 0 ....... 1700 .............. 0 .............. 0 ...... 1~00 ...... 0 ........... 0 1900 0 ::: 0 6, 6. 2064 206~, 2000 216~ 2164, '-2100 2264 2264. 2200 2364 2364, 2300 2~64 2464, 2~00 2564 256~, 2500 2664 26~4, 2600 . 2?64 2764, 2700 2864 2866, 2800 2964 2966 306~ 3064 ....... 3164 ......... 3164 3354 3364 ~464 346h ............. 3564 ............... 3564 o .. 0 0 ~.0 "-2~00 ..........0 .................... ?:'0 .... -3000 ......... 0 ................ ~?0 .... . 7. 7, 7, 7, 7, 7. 6. 6. .5,, 19 5 0.11 W ~o"$ ................. o;30-W ......................................................................... 56 s ................. o'e~'w · - 3100 ..... O .......................... 0 · 3200 ....... 0 ....................0 .................... .. · 3300 · 3400 · 3500 31 08 69 97 89 66 64 86 27 50 03 50 89 20 ~6 $ 1,32 S 1.33 $ 0,97 5 0.39 5 0.22 $ 0.70 $ 1,22 $ 1,83 S ' 2,49 S .................... 3,14 5 3,73 _. S 4,36 $'- ............... 5,04- $ 5,78 6.56 5 7.38 5 8,22 S 9,08 61-5 ............. g,95 57 S 10.82 44 $ 11.69 23-5 i2.53 .......... 87 S .... 35 5 14.02 W 80 S 14,70 E 29 5 15,41 E 82--S ........ 16,15'E ...................................... ~O'"S .......... 16,91--E ....................................................... 0 O ......... 4,'Ol"S ............. 17,69 E ...................................................... 0 0 3,6'7 B ......... 18,50 E ............................................ 0 0 3.37 $ 19,32 E '~'E'A'SO'R'ED-'DEPT'R--AND--OTHE'R'-DATA-FOR--EV-£RY-"EVEN .... 1-Ob--FEET-"OF SUB S'EA""BEJ~IT'~"i- TRUE qE'ASUflED VERTICAL SUB ~-,~tD-TVD ................ VERTICAL DEPTH .......... DEPTH SE'A" DIFFERENCE ........ CORRECTION ............ TOTAL- -COORDINATES 366/+ ........... 366~ 37~4 ............................... 3764 386~+ 386,~ 3964 396~ ~56~ 4664 ................................. 4664 ~764 .................... 4764 ~86~ ~86~ 3600 ....... 0 3aO0 3, ooo o ............ ~00,0 ................ 0 .......... -4300 ................ 0 ............................................................................................................................. ~500 0 0 1,69 5 28.83 ......... , 6oo ........... o ......................................................................... ~700 0 0 ~,30 ~800 0 0 1.09 S 32,~4 ~96/+ .................. ~96~, .......4900 506~, 506~, 5000 5165 5164. 5100 5266 ....................... 526~' ............ 5200 5369 §36~. 5300 5~73 5464. 5~00 5578 556~, ....... 96-5 ............... 33 __ . 5500 I 2,75 5 36.g4 E 8.99 .5 42.98 E 21.81" 5 ................ 53.31 E ........................................ 40~05 S 67.80 £ 62.39 $ 87,,17 E ~6;71 $ i08'6~E 5684 5664 ........ 5791 ......... 5764 5~g9 ..................... 586~ 6007 .............. 5964 6116 ............... 606~ 6225 ........................ 6t64 6~6 ............. 6~6~ 666~ ........... 67~0 .......... 666~ ............ ?00~ ................. 5600 · 5700 2 J ........ 5~00 3 · -5900 ........~ · 6000 5 · 6100 ........ % · '" 6200 ..... 7 · ..... ~--6300 ...... 8 ..... 20 ............... 6 112.71 $ ..... 132.22 E 7 ...................... 7 .............. 140,.46--5 ....... 157.85 E ~ ............................ 7 .................................... t69.98--S ......... 186-.'57-'£ ............................... 2 8 201.0~ $ 211,~8 E 1 ............................ 9 .............. 233,93 5 ..... 239.36-E ........................ 1 1'0 ................................. 26~0-'S ......... 267~28'-E 1 .................... 10 .......... 30~,56- S ......... 295,55-E 1 ....................... 10 ..................... 342.37-$ ....... ~2~,l~"E ................................... . ....... 6400 ........ 92 ........... 11 ....................... 3e1'~6-~ ...........352;80'E · ..... 6500 ...... 10~ ...................12 ...................... ~21,21'S ....... 382'0~ E . 6600 ...... i16 ..................... 12 ...................... 461'~0-S--- ~12"00--E . ......... 6700 ..... 128 ........................... 1'2 .............................. 502~17"& ...........~4-2;'82--E , ....6900 ...... 15~ ..................... 13 ................. S84,26'S ............ 506.17 .... E ............. * ....7000 166 ................................. 12 ~-S~ORED--D~P Tt~i-"AND-OTHER'-'D~TA-' -FOR'-"[V E R'¥-[V~'N .... l O0--F E ~T'-'-O F ~-"S¢ ~, ...... SEA"' D'EP T R . ............ ~E~S'URED ................ VErTICAL'--SOB ........ ~D'~TVD ........... DEPTH ..................... DE~TH ...... SEA"'D~IFFE'RENC'E ................. CORRECTION ......... TOTA~ "-CO0'~OINATE~ .................. 7342 ............................. 7~64'e .............. 7100 ............. ~78 ............................... I'2 .................................................... 66'5~05-:i:'S '7~'5'~ 726~ ..... T2'O0 ........... i90 ~-~6~ .................. 73~; ........... 7300 ...... ~ol ...................................... '?a~ ................................. ~, ......... ?600 .......... 230 ............................................. ................ 8003 .............................. ??~'; ........... 7700 ............. ~ .......................................... 8~0 ...................... 826~, ......... 8200 .......... 276 ....................................... 6 ............... ~ __i015 8'646 ........................... 836~, ....... 8300 .....282 8?50 i' 8~6~'; .... 8~00 ......... 286-< 8855 .................. 856~, ......8500 ....... 291 .............................. .5 ................ '..'i1127 8959 .................... 865~' ........... 8600 --2957 ........................................ 4 .......... ;- 1153 906~ ...................... 876~'e ....... 8700 ~ 299 '~ ....................... ~ ....... 1177 ~i67 .......................... 886~, .......... 8800 303 ............. ~ ...................... ~ ...........:':" 1201 · 91 5' ......... 895,$9 E o06':'S ............ 923~85 ..... E ....................................................................... · ~2' S ....... 937~31-~ ............................................................. ,05 $ .... 950,36 N--TERP-OL~A'¥ED"--VALUE"S ~FO'I~"EVEN-~000 FE~T'-OF' HE'A~uRED DEPTH, ....................................................... TRUE ............. ~ASURED ......VERTICAL ................... SUB DEPTH DEPTH ~EA .........TOTAL (OORDINATE $ ~000 999. 9~5, ............. 3.77 $ ...... 0~1 'E ~000 ~999. ~9~5. 7'0~ 5 6~85 ~000 ............................... ~99~' ............ ~9~ ........................ 5'-;-61'-'5 ................. i~', 9~ ~000 ~999, 2,58 S 2~,0~ 5000 ~999, 6~35. 1.21 S 3~,~7 6000 5957, 5B93, 198.96 $ 209,91 ................... 8000 7761, 7697. .................. 884'67-'5 .........734,39 9000 870~, ~6~9, i16~'10 S 915,48 .................. ~ .................... i ..................SCALE!" I i ................................................. i ..................i ........................ DS-'4- t4 .................... ~ ........ : ............ ~ ............ MAGNETIC SINGLE SHOT SURVEY ....................... eo~ .................... ~ ........ ~ ............. ~ ............. RADIUS 1600 ................... ~ ................... ~ .................. . .... ; ........... I ........... : ............. : .... ....... ....... 4000 ........................... ~ ........... 4400 5200 ........... ~ .............. ~ ........ ~00 ....................... ,. - ...................... ; ..... ... 7200 __ 7600 . SCALE =BO0' '~ ' ' ATLANTIC RICHFIELD COMPANY , MAGNETIC SINGLE SHOT SURVEY RADIUS--u~ CURVATURE : . , ~ ~vu=~v~u~ TMD = 9333' . ............. At! anticRichfieldCompany North Ameri.c~n Producing Division North Alask{~, strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 10, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- DS 4-14 Permit No. 78-36 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, [rank M. Brown District Drilling Engineer /am Enclosures DEP~Yf OF NATURAL I{ESOURCES Division of Oil and. Gas Cc~servati~n O. K. Gilbreth, ~Jr~~ Director Hoyle H. Hamilton 7'~' ~'~:' ~ ~ ~ Chief Petroleum Engineer t:~trolem. ~r .~May 11, 1978 BOPE Tests - ~moo's DS 4-14 ~_~urf_~Lay, .April _20, ~8 - I de.p~_..u~ ray ~ at 8:30 ~ f~ a 9:00 ~~' ~,-i0:i0 ~I ~~~ via Wi~ fli~t ~9 f~ ~~~, ~i~g at ~:40 ~. I p~d ~~'s ~~~ ~y 91 for ~g ~ ~sts. _Fridayx:. ~April 21, 1978 - BOP tests on Mikkelsen Bay %1 initiated. Saturday, .~pril 22, 1978 BOP tests continued cn M/kkelsen Bay #1. Sunday, April 23, 1978 - BOP tests on M~kkelson Bay %1 v~me c~mplet~ ~'~Y'-'~~-~0~CO'S DS 4-14 where I arrived at 10:30 AM. Arco's drilling foreman w-~s C~=orge Bean and ~n rig %34 toolpus~_r ~s Orvin Graff. Tests began at 11:00 AM with shoe on 13-3/8" at 26~3'. Annular preventor tested to 3000 psig. ~ pipe rams, both wing valves in the kill line and wing ~ve and HCR valve in the choke line tested to 5000 psig. valves ~ twenty-six ~~°in the choke manifold tested to 5000 psi9. The ~ adjustable choke was free moving and Swaco superchoke actuated~. ~ pipe rams and blind rams tested to 5000 psig. ~le pi'~ up kelly to test that system I toured the location which was w~ll organized, reserve pit ~11 built, rig in good repair and well sign was in place. Acca~latcr pressure was 3000 psig and N2 backup bottles tested to 2400, 1800, 2000 and 2200 psig. Kelly cock and lower kelly valve tested to 5000 psig and both dart and ball type floor valves were Ln place. Tests %~re concluded at 3:30 PM and a field iD~c~ repc=wc prepared with a copy given to C~orge Bean, a copy mailed to Bob Hir~.~ and the original attac~ to this report. I deparbed Deadt~rse via Wien flight ~.20 at 8:45 I~4, arriving in An~rag~ at 11:05 I~4 and at my bxmnm at 11:40 t~. Friday, .APril 28, 1978 - Joe McGinnis called fr~.~ DS 4-14 to advise check tested to 5000 psis. Ln ~~: I witnessed successful BOPE tests cn Arco's DS 4-14. Al~a Oil and Gas Conservation C~ ~, Field Inspec~,n Report Drlg. Permi.t No.?~_. ~, %' ~ Well/F~mli~i~ Sec~T//~ Operator~~ "- Represen.~ed by ~__~) Name & Number j~ Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (1,)/~'Location,General (~ (~ () () () () () () ) 1. Well Sign ) 2. General Housekeeping ) ~. Reserve Pit-( )open( )filled ) 4. Rig ( ) Safety Valve Tests ) 5. Surface-No. Wells ) 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos, , , , 8. H~s. obser _, , , 9. BS&W __,___, 10. Gr. Bbls. ( ) Final Abandonment 11. P&A Marker 12. Water welt-( )capped( )plugged 13. Clean-up 14. Pad leveled )ection observation time_~_ hrs/~ () () () () Total ins Remarks Yes No (~() (~() (~y' ( ) (.~- ( ) (~- ( ) (~' ( ) (~- ( ) () ~'() () () ~.,. ( ) (~- ( ) Item (i~/~BOPE Tests 15./~C'asi'ng set 1:6. ~ fluid-( )wtr.--~---C)mud (~-~'~oil 17. Master Hyd. Control Sys.;~l~ psig 18. N2 btls~,~¥m,~,C~sig 19. Remote Controls .20. Drilling spool-~'!outlets 21. Kill Li~e-/~i~) Chec-~-~:-valve 22. Choke Flowline (~,)~HCR valve 23. Choke Manifold No. valvs/~flos~.~__ 24. Chokes-(~/4~emote( ).Pos.(~dj'i ' - 25. Test Plug-(~Wellhd( )csg( )none 26. Annular Preventer~lim~mosio 27. Blind Ramse~_~ps~o 28. Pipe Rams,~:t~_psiq~.~,) 29. Kelly & Kelly-cock~sig 30. Lower .Kelly valve,~-~psio 31. Safety Floor valv~s--Z~-~;;~-BV (~,)q~art Total number leaks and/or equip, fai'lure.s. / _ ..... ...4~,~_ ~_'.~' ~,,,~ ' ~,,,*~,"'...~-.~: ~ ? .~'-~ - ?,~::,. ~ cc~~Notify in _clays or when ready Inspected by Form~o.~-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR ATLANTIC RICHFIELD COMPANY 3. ADDRESS OF~)PERATOR P.O. Box 360, Anchorage, AK 4. LOCATION OF WELL 85'S & 466'E of NW cr Sec 35, 99510 TllN, R15E, UM 5. AP1 NUMERICAL CODE 50-029-20310 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8.~' UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 4-14 10. FIELD AND~OOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 35, TllN, R15E, UM 12. PERMIT NO. 78-36 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Oil POD' REPORT OF OPERATIONS FOR THE MONTH OF APRIL 1978 Spudded well @ 1300 hrs. 4-19-78. Drld 17-1/2" hole to 271~,~.,. "' RU 'i~Tshoe @ 2693'. Cmtd w/5700 s~ Arcticset II ctm. Drld sho~'~''& 10' form to 12.07 ppg. As of April 30, drld 12-1/4" hole to 8380' & ran 13-3/8" csg new hole. Tstd 14. i hereby certify that th~ forego,~ns is t~ue and co.act NOTE-Report on this form is required for each calendar month, regerdle,s of the status of operations, end must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month.unless otherwise directed. ~ril 11, 197.8 ~ B~, Unit ~ 4-14 Atlantic Richfield ~ I~_rmit ~. 78-36 Fra~ M. Brown District ~illinq Atlant~ ~/d~ield P. O. ~ 360 Anchorage, Alas~ 99510 Encl~ is ~ ~{~ appi~~o~ f~r Fumit %0 drill ~he above ref~ ~ at a location ~ Saction 35, H~wnship 1]/4, Range 15E, ~4. tgelt ~~, ~ ~, ~ a ~ log are not required. A directicmal Many rivers in Ai~ ~ ~heir drainage ~fstmms have been classified as i~f~t fc~ ~ spawnL~g ~ migration of ar~Klrc~3~ fish. Operations in ~ areas are subject to .AS 16.58.870 and the regulations p~ated ~ (Title 5, ~ ~istrative Code). Prior to commencing opera~ you may ~ contacted ~ ~ Mabitat Coordinator's office, Depar~ent of F~sh ~ ~. ~lUtic~ of any waters of ~ State is ~ited by kq 46, Chapter 03, Article 7 ~ ~ regula~~ prfma~gated thereunder (Title 18, Alaska Admi~zistrative ~, ~ 70) and ~ ~ Federal Wa~er Pollution Control ~, as ~. Prior to ~c~g operaticms you may be con~~ ~ a representative of ~ Dep~ftm~t of ~~ml Cc~se. rvaticm. Pursuant to .AS 38.40, ~ ~ '~ State Imka~_s, the Ala--~ D~k3rtment of ~ is being ~fied of the issuance of this permit to drill. To ~ us ~ ~ing field %Drk, we ~ appreciate your notifying this office within 48 ~ af*~ ~ we~ ~ ~. We ~t_~]d also like to be notified so ~hat a represe~tive of ~he Division may be .present to witness tes~_tng of blc~Dut pre~ent~ ec~aiFf~ent before su_~ casing shoe is drilled. F. M. P. Bo ~t ~ 4-14 2- April 11, 1978 In the ~ of suspensi(m~ or ~t please give this offioa adequate a~ance ~fication so that we may haw~ a witness present. Department of Fish and Game, R~ahitat Sectic~ w/o encl. ~t of Environmental ~tic~ w/o encl. D~parU~mt of ~, Supervl~, ~ ~w O~pli~ Divis~ w/o encl. ~ AtlantiCRichfieldCompany North Americ~ ProdUcing Division North Alaskt ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 30, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 4-14 Dear Sir- Enclosed herewith is our Application for Permit to Drill DS 4-14, a $100.00 filing fee and the required survey plat. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form 10-401 ' REV. 1-1-71 STATE OF ALASKA SUBMIT IN TRIP. fE (Other instruction~ on ~ - -, revise sid~)% OIL AND GAS CONSERVATION COMMITTD~? -~ PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [~ DEEPEN F-'] b. TYPE OF ~V~LL OIL GAS SINGLE MULTIPLE WELL ~ ~LL ~ ~HER ~NE 2. NAME OF OPE~TOR gtlant~c Richfield Company 3. ~DRESS OF OPE~TOR P.0. Box 360; Anchorage, ~laska 99510 4. LOCATION OF WELL At surface 85'S & 466'E of NW cr Sec. 35, TllN, R15E, UM At proposed prod. zone (@ 8800'SS) 1180'S & 1400'E of NW cr Sec. 13. DISTANCE IN billES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 6 Miles NE of Deadhorse 14. BOND INFORMATION: 35, TI!N, R15E, UM '11. API No. 50-029-20310 5. 6. LEASE DESIGNATION AND SERIAL NO. 0nADL 28324 7.IF INDIAN, ALLOTTEE OR TRIBE NAME 8.UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 4-14 to. a:'E~D.*ND POOX. OR 'V~qTd vruonoe ~ay Prudhoe 0il Pool SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, IllN, R15F, UM 12. ~EStatewide Surety and/or No. Federal 15. DISTANCE FROM PROPOS'ED * LOCAT[ON TO NEAREST P~OPERTY oR LEASE LINE, rt. 1180' (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION Insurance Co. #8011-38-40 16. No. OF ACRES iN LEASE 2560 19. PROPOSED DEPTH 9311'MD 89'55'TVD TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, F1r, 2645' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 64'RKB, 30' Pad Elevation (Gravel) 23. PROPOSED C,.~SING AND CEMENTING PROGRAbt ~mou,;. $100' 000 17. ND.ACRES ASSIGNED TO Tills WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START April 20~ 1978 SIZE OF }ibLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 lb. H-40 80"+MD 250 sx p'F II to surf · , , , ~17'~/2' 13-3'/8" 72' lb. MN-80 2700'7'MD Circ to surf - approx 5500 sx -12-1/4" ' 9-5/8" 47 lb. 80&95 9311'+MD 2600'+ cmt.c°lumn on ls.t st.q .. (Appro-x 1500 sx) Plus 300'+ colu~ · on 2nd staqe (Approx 300 sx) . . Atlantic Richfield Company proposes to directionally drill this well to +9311'MD, +8955'TVD to produce the Sadlerochit zone. Logs will be run across selected interval~-. A 13-5/-8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# N-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected intervals Within the Sadlerochit interval will be perforated, and reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. Well will be flowed to production facilities during perforating and testing. The downhole Safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen dkectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer pro.arm 24. I hereby cer~y~hat the Foregoing is True a.na~~ DA~ March 30, 1978 TITLE District Drl9. Eng,. space for State office use) SAMPLES AND CORE CHIPS REQ01RED [] YES [0 NO DI~ECT~ONA~ SURWV ~muI.Eo i~ ws ~ ~o CONDITIONS OF APPROVAL, IF ANY: blUD LOG [] v~s ~ OTHER REQUIREMENTS: A~P.I. NUMERICAL CODE 50-029-20310 PERMIT NO. APPOVED BY 78-36 APPROVAL DATE *See~nstruction On Reverse Side April 11, 1978 DATE April 11, 1978 SECTION 2 6 PROTRACTED 267' 202' SECTION 35 j~ 4888' 4864' 4859' 4789' LINE Z ®15 320' ..~ ~D.S~'. No. 4 SEC. 26 & 35, TIIN, RI5E UMIAT MERIDIAN 4764' Z JANUARY I 2, 1978 - CORRECTED PAD CONFIGURATION CERTIFICATE Of SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TH IS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION , AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. JANUARY 9, 1977 . DATE ~ SURVEYOR JANUARY 6, 1977 DATE OF SURVEY WELLS ~¢ /1 - 16 WELL /VO. 11 /_,qTT 7o* /~, ' zo. 086" ~_oN6. 148'~ / b '.3/ . Z34" WELL AIO. 12 LA77 70 ~ /6'/8 · 73!" LO,VG. /48° 1 b ' 2,<2.5/Z" WELL /V'O. ?5 -- /-~IT. 70 o /6' / 7 .778" LO,Va. 1480 I(~' z9 .783" WE/_L /VO. ]4 ZAT. 7o* /6' /& .625' LONG./48°/6' 29. 049" WELL /Vo. /5 LATT 70 ° 16' /:~.470" Lo/,/G./48 ° lb ' 28.327" WELL /v'O. 16 LAT. 7o° 16 ' 14 .313" Zo#6./48 o 16 ' 2 7. 602" A.S.P. C., ZONE No. 4 T 5 952 150.26 ,X' 7/3 Z/9.57 952 099. 57 7/3 Z4/ . 68 95/ 917. 16 7/3 Z70. OI Y 5 951 800.69 X 713 298.55 951 68~. 98 71.3 92(,. (:,7 951 567. 12 71.3 .954. 91 ARCO No. AFE HVL No. ATLANTIC RICHFIELD CO. AS -BUILT DRILL SITE No.4 WELLS 11 THRU 16 LOCATED IN PROTRACTED SECTIONS 268~ 35~ TIIN~RI5E, U.M. PREPARED BY HEWlTT V. LOUNSBURY AND ASSOCIATES 723 W. 6th AVE., ANCHORAGE~ ALASKA DATE JAN.6,1977 SCALE ! ~ :' ~ .... '~ CHKD. BY G.D. FIELD BK. ~r FOR NEW WELL PERMITS ...... Company ' ~f~(9 Yes No Remarks the permit fee attached ..................... ~< ~. Is well to be located in a defined pool ''~ 3. Is a registered survey plat attached ................. ,,<~<~:' 4. Is well located proper distance from property line ......... ~<,~ 5. Is well located proper distance from other wells .......... ~:~')~' 6. Is sufficient undedicated acreage available in this pool ........ 7. Is well to be deviated ....................... 8. Is operator the only affected party ................. 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond in force ................. ~-"'~: ll. Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. Is conductor string provided .................... /:-'~ 14. Is enough cement used to circulate on conductor and surface 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ........... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst ~"q9. Does BOPE have sufficient pressure rating - Test to $'~0~0 psig 20. Has DMEM approved Plan of Operation ......... ~', ...... Additional Requirements' Approval Recommended' Geology.' Engineer i ng' TRM ~ J~"-~ .... HHH __ JCM ~ HWK //-~.~ LCS RAD Revised 11/17/76 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is.accumulated at the end of the file under APPENDIX. ., No special'effort has been made to chronologically" -~ . .. organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company Atlantic Richfield Well DS 4-14 Field Prudhoe Bay County,State North Slope, Alaska Date 11-11-80 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR1 Gamma Ray Pass 1 CN/MS 0-100 SSi Short Space Pass 1 CN/MS 0-2000 LS1 Long Space Pass 1 CN/MS 0-2000 N£U1 Neutron Pass 1 CN/MS 60-0 GR2 Gamma Ray Pass 2 CN/MS 0-100 SS2 i Short Space Pass 2 CN/MS 0-2000 LS2 Lon~ Space Pass 2 CN/,MS .,, 0-,2000 NEU2 Neutron Pass 2 , CN/M.S ......... 60-0, ...... ,, .... · ,. , ,,. , PAGE ........ 1 ATLANTIC RICH2IELO CO.- .... D.S. PR~r3HOF BAY ..... NORTH SLO~'E,~LAS~(A HLAC ~54 9AT~ E~IERY l SAM~L.ES GR1 SSI Lgl ~EU1 P, 600.50 -0.12 0.00 815.03 ~5.00 57,37 901.10 .77 92~.1A S~O{~.50 55.ql ~R9.06 BIB.TI ~5.~4 5~.~5 1_82 NELI~ 84q.48 30.02 851.84 30.53 853.07 31.71 B49.39 31.23 B44.qA 30.02 BSl.B4 30.55 R53.07 31.?1 849.39 31.25 803.99 ~7.45 803.99 8~0.12 ~8.7~ 29.21 8607.50 5B.GO 898.~6 8~9.75 34.68 6~.46 865.$9 ~q3.25 .............. : ............. : ................ ~ ,,Li ,h.,.,_, .: .......................... iL,.. ~.....i ........... :,L,,,,.: ............. ~i..L;._._._:..L ...,; ..... ~ ........ Lh_ i..._,:_~LL....;.:.._,...h ,. i :~ _....; .................... .~,i,...> ; ' ' ~0~.50 4R.2B 1045.1~ 8~'5.52 43.53 57.00 99~.3~ ~?0.25 37.00 zO ,64 3,54 1029,~0 BBo.o~ 35,56 ~0,~.7 1009,77 .......................... ~"~'~-~';'so":-'"":""~;~'~ ...... ~:~s~,;-~---: ......... ~i~-,,:--~,~-~ ............ ~-~,~;--~-~ .......... ~"~";'~ ~ z o ~ s. ~ ~ o o. 9 2 ~ ~., o 39.07 914.42 ~3.07 954 I 33.q0 q!. ~1~.50 24.6 16 935.28 996 00.31 11 5 01 ~$15.50 25. 33.10 53.75 31.82 30.09 29.7& 28.95 28.81 ~9.0~ 28.73 ~D.7~ 5&!~ 50 P" 78 1179 49 1051 84 24 B3 2~ 68 1.1B1. 93 !0t3 BO .................. -""'~'"~g'-~'Tj'0"0'"":'; ........ ':'"'12g;g-g':'~ ~;'TT'5";"'8-;~:::'"'~f'0¥'~:::~"B-~::":Y''':~''' -~"i7-;'"" "'""~"g~ ~"q ...... i"i7 ~ ;27 .... 1 o o 6 4 ~ ......... :, ............ :,.,,, _:,:.,.::,.,,: ............... .......... .1::....{..:., ' .,,..... L.L:..,, ............. :_..i,:.,:,.__.;,i.,., ._,{_L:i._.~:L,,.,.,,,::.._._:::,: ............. ..L:.,JL,~::.,,....:::__.:;~.;,,...,:.,:; ................. ,:, ,...: · 8617.50 27.03 1170.9~ 102~.62 25.50 2~.29 117~.77 1001.5~ PAGE p ATLANTIC RICHFIELD CO ..... D,S N-I~ PR!.)DHDF BAY ..... NORTq SLODE,~LA.g.<A HLAC DATA E~/ERY i SAMPLES ~&2~.O0 20.27 11~5.30 9B1.90 2B.59 23.~6 1.130.~5 B62~.00 21.99 ....... :.,....,..,: ........ ;% ............. :.2 .; 2 .... ........... .; ................ ._...,.,:. ............ : .......... L. ~ ............ :._ .;.: ........... : .......,....,..%1.::%.-,. ............ L.., .....:..... 5._....LL..Z ........ : ............... _..%.: ............................................................................. .... : .................... ;_.... ;..: ....:.......L .,:L L...,...: ...... : ........... a.;,...._....; ................................. :,.:._...:.....i:L ...i......L ......... :.. ............. Li; ..... i.~ ............. : ....... :...: ........... ;. ........ g .......................... a6SO.O0 ~.87 1098.90 9~0.1B ~e.07 21.7~ 1109.B9 .... ........AL ...; ...... ................ ;L,.....:;:.:..Z:..:.: ,... L;;........;; ............................. ;...,.....:..L..'.._.-.:~ .......:,.. 1 ............... ~:._ .. L,::...~...i., ..: L:i :..L .............. i:............~,.,,....2~.L....:.:L .........:..,....:.. L...::L ....:.......... 2 ........... ; ........................................... % ....... ~ ........................ ' ..... 86~1,00 ~9,53 ~085,~7 9~1,~t 31,~7 22,]t 1103,78 ......... : '""- '"~' :~" ~ ~7~ ~ 0 ;" ~"-'~ -7' ' '~"~';": ....... - 1~-~ 5~-"-" ........ .... : .............. .;. ............... :].........:.i& ...2....&.~;..i ............... ................. :.... J=~....L.......... .......... ................. .....~L.....,..;......: Lg2 NEd2 1002.76 27.12 1000.31 26.6B 9~8.0~ 27.0~ 98~.0~ 28.15 9~1.90 9B]..90 28.07 9R1.90 980.67 997.18 27.a9 959.82 50.0% 959.82 30.17 8~32,00 19,0~+ 1069.60 930.37 ~9,B3 21.87 109~.90 950.00 Pg. RO 863~.00 22.3.1. 105~.95 911,96 ................. .12 ................. .. .......... &..._:_ ..:.;......;....._.....< .;2 .....:: ................... .............. ;. .................. .i......L..L......: ............ { ......... L......;,,._...,...t.........L;. ............... L........:.........,......._ .2::: .......... 2. i..J ..; :.:...._. ........... B63~.00 2q.57 1070.82 929.1~ 32.59 2q.R2 106~.71 9P~.2~ 31.93 ............ r: ................ ?'"'"T'~ "~"T"~VT"'~']~;' ........... 7'"'"-": "-~ ................ ' ~ :-~'"'":;' r'~7'' ~'f'r~"3g~';",'"'"~:'~'~':';'~"~'; ;-'"" ~'"?:-?";"~ :~;'~'7:'~"7T'' ;~'""--'~ ........... '''''?'''''' ......... .... ~7,00 2~,5 ~1 9~.6~ 29,0~ 86~9.00 25.91 8G~O.O0 25.6 ~G~l.00 25.1i 8642.00 27.40 .... ~. .............. :.:...... ......... : :.....~.:.: ............... .::._......: ............ :Z:. :...._;._ _..__ ....: ........................ ................... ..........: ........... :......_ ..: .............. ~.._. _... :,_._.... ........... .:i.......L: ............ .,_~..L_ a: ............... Li ............ .: 881,29 53.91 · 92 1 .15 3~.76 ,02 36,0% D~.88 866.56 36.00 ,5 2~ ~53.07 937.73 8~5.~2 32.B8 29.12 962.15 a29.75 5q.57 79~,9~ 55.~3 8:~4A, O0 3].,57 B49.BP_ 7'75.77 36,~4 2R,38 B75,~6 773,.~1 37,~7 ...................... L:. ............. :. _..... :. ............... ::.L......:; ........................... :..:......:. ........... .: ................... .:~...:....._..__..... ..................... ..: ........... :: .......... .i......: ........................ ....~:..: ............. L: . R~6~O,. O0 3p. 0~3 8~9.82 78B.0~ 3~.92 36.1.2 B57.1~ 7R3.13 38.39 PA~E ~ ATLANTIC RICH~IKLD CO. ..... O.S. %-14 mRUBHOF BAY ..... %IORTM SLO~E,ALASKA HLAC 6~5% DATA KVERY % SAMPLES GR1 SSI LS1 NEd1 ...................... :,,.,,:_..,,. ~ ......................... .......... ::,,; .......... ~:,., .................. ; ,---;,--: ......... .,,,.,, ,,: ............... 865!_.50 50.7~ 7~7.25 750.00 33.69 55.~1 757.~B ............................. .[~ ..:-...-- <.:...L[~L ........L.. -. :. ................................ : ........ : ..................... . ........................................ <: 865~.50 ~2.1~ 735.0~ 75'6.13 30.17 ~5.70 737.U8 ........................ L~..........~L ._.:.......] ::..~:L: .......... : .................................. ,....: ~....:.,....~ ._....:: .................... .L....._.~ .................... .~ .................. ~653.50 ~7,~2 7~2.37 775.77 28,11 ~9.63 73~.71 ................ ~,,.,, , .,..... ............. ;.....:, ......................... : . .:,.,;,,..,.~,., Z:,,: ........................... :.,.,..,,..; __.,..s.....&.,,,. L..,,.,,:.,: ............... B65~, 50 5~,~0 7~7.25 765.95 2~,99 53.93 7~.~1 ................. :"-"~77'" "';;':"';;'' .................... ,'""? '~': ........... ~"": ....... T;-"'";':" '-"':;"'"'";;~ ";"'-":' '- '}~;' '"['"'""": '":~'-'"':"~ ;;'"";;"": ...... ..... ,~..~..; ........... :~ ....... ,.........;. ........ L..... ~, .............................................................................. : .......... :........1 ................... : ................................................................ ~65fi.50 ~0,69 7&9.73 770.86 32.11 5B.97 7~3.13 .................. ~ .......... ?';"' ";~'":';T"-': ............. : ................ ;~; '"'"':' "- '"';~"'; ................ 2' T:'-;:; ~-"T"" ~'- ;" ~ ............ 4"~; ~ "~" '"~:" 4 '"'"3 ~ 7 .................... :'" "': .............. ;""" ................... ........... ..~.._:........S~.~5.~_.~:99_ .. ..:.:...5. ?_ ~:! ~.:.:..~?.3:~ ~. ................ :: ......... -. :~ ~ 00~'~' "''~" "'" ............... :' 7"" ': .......... "-'~'"; '5~eO~ ='~'7' '" ' '~;""--" .................... - ~0~ ~~'" '-'" ..... ~"':':'v ..... ..................... .: ......: ..:. ................................ .:.:......: ............ ... ............. .~....:.....: ................. :. .............. ........:...~.: .............. .:.... ~ ........... : ............................ ................. ~57.50 50,25 959.71 6~9.3~ ~0.52 55.77 9~5.52 LS2 752.~5 30.~ 752.q5 31.05 7q, 6.32 31,7B 7%5.09 ~,7% 756./3 ~1.8~ 76~.7~ 763.50 29.5fl 763.50 30.57 799.0B 853.07 35.55 39.60 ~$5~.50 34.15 1].96.55 9110.15 ~5.51 37.9~ 1169.50 931.59 ................................. Z. L S.-.....: ...... ~.;.. - ~ :~.......: ........... .L~.....:: ............. ..Z ........... :-:....._ L.__ .::...2 .....2 ...... :..... ............. . ..:.:._. Z; ................ : ...................... ]J.L.L..... :.._... _: ~ ~65n.50 e7.15 I~.S~ 9~0.37 ~e.03 29.3~ 12~n.87 qSn. O0 39.9~ B66].50 25,01 1001.22 85~.75 3~.68 32.~3 100q.55 8669.50 ~6~.50 :57.51 B66~.50 51.~i 8665,50 8&6~,50 5~,6~ 37.91 38.13 37,B0 783,13 32.85 7 .99 33.~0 .36 3~.61 ~:..6.~:::~?~.0% ~,~5 858.83 78~.3G 35.15 35.9~ ....... 35.97 86.~7.50 59,95 8q, 9. B2 79'2.9q ,~4.79 57.7~t 551.0~ 789.26 .................. ':'-'~':'~'7'::'~ '"-:'"': ......................................................... i .... : ....... ::TT:-~ T:"~i'":"~-'"' ":~5':'~ F":'~ ~:" ~'~ :"':"'~'"':::::i:ii ~':::'}"<':'~ ;-' ....... : ii ;''' T ......... 866~.50 45.09 ~66.91 7~5.15 36.26 51.23 87~.02 79~.17 .... ::"~ ................ '-'6'~-~6:;:b-'d'T-::"'~:i"i'~-6''~'::'-' ':'-$'"B" .......... "-~?~:~'~:~"~:-'::-'::'$' ~-~--':" .......... ~:~-'~'$ .............. ~'~"6','3'~ 7~5. ~ o 37, o o ..... ................... Z..L .................. ..~.-...~.2.... _.: ~ .-~.......LL ................. ..................... : ................... .......,.............::: ............ 2_.. ................. -:--.L_:::...~.~.~ .......... ...:. ....... ~-.-:.-.....~,.,...: .:-. ::... -: ...... ..... ~ ~S69.50 40.5% 877.90 772.09 4].~3 43.,9 ~79.12 795,~0 5670.50 ~7.79 8~3.71 757.35 39,01 52.09 86~.47 7a7.18 37.73 ...................... ~"~"?':i:'"::d-OTM.... :""~'~"?~'~"'~ ........ ?'-~:~":BY'--:"'?-~:~'~:~9"~:--'-":""'"-'~':~:; ':: ............ fi'i"~"i"~ ...... ~d"fi.~'~' 7s'3."s~ '35.'2 7 ............................... :..._.::.. :._.': ......... ,.,....: ........ : ............ :.....: ................... :~ ...................... ............. :_:.._ ......... :.... :_:.,:,...,.,., ..::....... ............. : ................. .............. ~.,..:,.,~,:.::.. ' ....... ~71.50 &2.0'4 713.0& 725.q-6 31.~+5 &5.27 728.9{~ 755.28 30.57 ................................ ~'~'?"~':;'~'O'~'-'""-':"?i'"Z'~'~':'"'"~"~"~"~' ........ ':'-?':~:~-~::i'~:--::'-":-~ '~"~"": ..... ~'i':2"~'~ ....... i'~ o5 7~o ~7 .... L ....................... .:: ..,.:..:., .: :: ,: .::,_ ._ :, ..... ......... .:...._L,.,.,,,..: ,,,,. :,: ......... :._:.._. :.:_..... :...,..,:,,. ,..:,.,,....:._.: _... :...._.._...._:. ,.,. _..: ........... :: _:.::.: ..:..,. ............ : ............ L, ...,:,~,...,: ~..........:....:....' ............. : ............. I · ~&72.50 79,R5 738.71 741.~1 35,01 78.75 735.9.~ 73S.g& Fq.57 ...................... """-~:~'?'~:';'~"' ......... .~```~.;.~9.:.:.....?.~:.~..2`.?.i.....:`..:.?.~y:i:~.:~`...`:....:.~:~?:9:~............`~.; 6i ~ ,"7'i 7~5.09 ' 3~.~ 7 .................... T':~'~'?':~";'"~'-~--':'""'""-~"fi'~:~'~'"" ......... ~:~'"2'~-~:-'"'-'::~"~'~'T~:'~~''' -':'-T-~'i:'~'~"~ .............. '~'~'~"~ ~ .......... ~t ,'~'S· s 9 ,'S ~ .................................... ,~Z :,,,:.,,,,,, ,~ ......... .: ..................................... ~,. ................................ ........ ~ ................. L ................... ,..j ................... _. .............. :.,:, .._,:,.......: .......................... ......................... ~ ~7~,,50 87.96 73~.60 7~1.ql ~.11 9~.8~ 7~.57 7~2.27 ~9.9l ................................. ~ '"~'-'~;"" '~" :'" '"'"'~ .............................. ~'"~ '"'~ .......... ~ ............................ ;'"'-:; "~"~"~'~ ........ :'" "'~ ....... ,-':"T'" ;77~ ................ ~' ................ ~ '"':'?" ?~'";'"'~; ................ ~:,o75.00 ......... 81,...08 .............. 5_.e- 55 90.~7 7~1.t5 7~.72 ~o7~,50 75.06 739.93 7~1.~1 3~,~ 8~.~ 7~1.15 775.77 . ~ . mAGE ~ ATLANTIC qICHmIELO CO. ..... D.S. ~-IN PRHOHOF BAY ..... NORTH SLO~E,ALA.SKA HLAC ~ATA EVERY I SA~OLES GR~ SSi L~l ~E~l G~ ~S~ ~S77,00 70.6q 75~.58 770.86 29.9~ 7G.66 76G.79 ........................... ; .......... ~......... ,._...c.......,..: .................................................... ,~., .,'...[' ................ :.-: ......... ~ ....................... .................... .: ......... , ..................................................... ;-..,- ................. .: .................... :-, - ~gTa. O0 ~7.9~ 770,~5 778.22 29,83 71.7~ 77~.5~ ................................. ~`~i``?`~%``~`6``~```y`"```i```g`~``?``"``~````:``?`B:~.~`:.~i:~`y?`~`~;:~```~`Y~```V?````~`~`~?;~```~``A:''''''' ............. '~"~'; a o 7 7 a. ........................................................ Z: ...................... ; ...................... .; ..................... : ..................................... ..: .................................................... :,; ............... :--,,-.- ~ ......................... , ................................................. 8~79.00 70.8~ 7q8,~7 7~,0~ 2~.33 80.22 ' ': .................... ~e50:7'"';; -':; ";'"' '7-'""'"'; ..................................... ~e~: ........ 7";"'"':' '---' ~1. ~:;"'7' '": ............ '-;'"'"; .............. :7:~.0~:'~;":' ~"7;";',?C '? ............... ~: .............. ~Oe~.;"'; ......... ': ....... ~:: ....... ..... ~'-~"'"~ '~ ...................................... ~ ................ ;::. ........... : .............................. :; ......... , ..................... ............. ;.... _,......; ................ .......... .: .......... ~..:; .......... .L:....~ .......... ; ...................................... 8~80.00 8Z.05 7~9.93 7~O.1B 32.~ 90.79 7~1 .15 7 8~1 .00 7~.87 7~,8~ 75~.91 32,00 8ff.28 ............. ':'"""'";':~"-':'~'~'~"~"~;"~';~;';~'~'~:'~"~ ........... :~"~'";';~"~"~??'--'";':~?~;~';~':~';¥>~:'~- ......... Y~"'~::;"~'~6~'-'"'"?'?'~'~':'i:'?~'~ TM ':"-'"';'"'"~';i~"";'~'~ 75'6 ............. :.,., ...., h.,..; ,,,..~;....~..: .............. %.LL.. Li....; ....................... : ........... i;.~.Z ...L ... _..:._... :...:..~ ............... .:.......:..:. :. ........... .~.:, ._...;..:......,L :.......Z.J...:,:...:.:T...._ _, .......:: .:..-.:.~:...-..~.......; .,L....~...i ........... _, 8G82.00 82.06 7~8.~7 7~5.77 32,15 82.56 750,92 8G53,00 8~,03 752.1~ 751.23 3~.0~ 82.92 752.1~ .......... '7=```~`"`:~:~`~:``;~`~:~`~`7``~`:`~:`~`~`~`~;`~`~i7`````~```:`?~``~ '~'?'?:'~? :""'~:'?: "~'~'~"V--?- ""~i. ~"b ......... 75'~",'i' ................. ;.....¢.,_L ......J...,.,....:.........~ .:.;....:_:. .............. : ..;... ,..-L._....L,..._..L2....J-,.....L... ......... ;.._,..i .......... . ...........:....... ;.i ..... :..,..-,.:- ..~ .....:; .:......<.,;........-:...--.....,:..-...;..i, .L .,:J .~ ,....::.......... :...;.....--.::,..~ .:., :::.-..., ............. ::.: ....................................................... .... ; .............. : :... -:.:.. _....:..:._. i~.; _ .;;.L%; ...L..-.::.. ...................... .. -..L:.;.....- :-.-....'..< ................. ~..._._..;.,......_...;; .............. : ........... ..:J.. :::;:... _~.:...,.... ,,..::.:..L.:..... :. _...;. ~,;.. :.:.k_ ...:,.L. -..,.... :..:. ...... ; ................. aGSS.O0 7~.~8 77~.89 7~7.55 3~.59 81.57 770.~5 LS2 NEd2 769,63 ~9.75 7a0.67 30.13 7~9.26 ag.0~ 791.7~ ~.07 79~.7~ ~7.67 78q.~6 77~.5~ 26.qS 763.50 27.5~ 754.9! 29.7~ 7q8.77 31.25 . 743°86 32.77 742.6~ 3~.95 7~5.09 ~.17 7~7.7~ ~.91 754.05' 35.71 7~7.7~ 56.55 ....... 736.50 ~.SR 7~.6~ ~4.~5 8 737.73 5~.9~ ....... 731.59 36.59 ........ 7:35.28 38.50 8690.00 7~5.09 37.11 asg~..oo 81. oo 9S9~.00 .~5 776.55 75 ~.~2 81.70 775.~ 752.~5 · .......... ..................... .................. ............. .................... .................. 7 o. a s~'~ ....... ................... ~ ....... ~;~'9'Y~:~ ......... /-""?"~"~-'~"=~'~-::~'"~TiV-F-?!~ ?-7~"-7~:~";i"~"~-: ............. ~'O-'"~'~"O ......... 7~"7'-"7'~' 7'75,77 : .......... i .......................................... L ............... :.........L .... ........ 2... :_._ 2 .... ~ ; ............. ARCO ALASKA INC PRUDHOE BAY Run 1' 23 - October - 1992 DLLIACIGR A~A$ R E C E IV E D ~~~~ NOV 19 1992 ~ taska Oil & Gas Cons. Commi~ Anchorage Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 5733.00 J. DAHL D. MOSTELLER D.S. 4 - 14A 500292031000 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 03-NOV-92 RUN2 D. WESTER RUN3 35 liN 15E 85 466 64.00 63.00 30.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 9.625 8264.0 REMARKS: DLL/AC/GR CIRCULATION STOPPED: 19:00 22-OCT-92. LOG TIED TO ORIGINAL D.S. 4 - 14 FDC/CNL/GR (5/2/78) AT WINDOW DEPTH. AC CYCLE SKIP IN SHALE ABOVE SADLEROCHIT (8880-8884, 8698-8702, 8368-8372) & ALSO JUST BELOW CASING SHOE. $ RECEIVED NOV 1 9 1992 Alaska Oil & Gas Cons. Commission Anchorage FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 8263.0 9369.0 8263.0 9389.0 8263.0 9358.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 8263.0 8263.0 8281.5 8282.0 8305.5 8309.5 8309.5 8330.0 8330.5 8330.0 8331.0 8340.0 8340.0 8344.5 8349.0 8358.5 8360.0 8360.5 8361.0 8364.0 8365.0 8368.5 8376.5 8381.5 8382.0 8382.0 8384.0 8391.5 8394.0 8393.5 8404.5 8413.0 8413.0 8420.5 8421.0 8420.5 8427.5 8461.5 8465.0 8465.5 8479.0 8479.0 8495.0 8494.5 8506.0 8516.5 8516.0 8525.0 8535.5 8541.5 8545.5 8545.5 8554.0 8556.0 8562.0 8568.0 8568.5 all runs merged; EQUIVALENT UNSHIFTED DEPTH LL3 LLD 8263.0 8263.0 8305.5 8330.0 8331.0 8344.5 8349.0 8358.0 8360.5 8363.5 8364.5 8368.5 8368.5 8377.0 8377.0 8382.0 8384.5 8392.0 8404.5 8404.5 8420.5 8421.0 8427.5 8461.5 8479.0 8506.5 8525.5 8536.0 8536.0 8542.0 8554.0 8556.0 8562.0 no case 8591.0 8591.5 8593.5 8595.0 8610.5 8617.0 8622.5 8629.0 8632.0 8658.0 8679.0 8700.5 8701.0 8708.0 8710.5 8720.0 8749.0 8751.5 8762.0 8778.0 8785.0 8786.0 8793.0 8803.0 8821.0 8830.5 8851.5 8866.0 8867.0 8870.5 8883.0 8883.5 8884.0 8894.0 8899.0 8906.5 8907.0 8908.5 8913.5 8917.5 8930.5 8959.5 8965.5 8981.0 9003.0 9013.0 9031.0 9031.5 9046.5 9057.5 9069.0 9070.0 9093.0 9093.5 9094.0 9096.5 9107.5 9110.5 9129.0 9136.5 8591.0 8595.0 8622.5 8629.0 8679.0 8700.5 8707.5 8720.0 8751.5 8762.0 8785.5 8821.0 8830.0 8867.0 8884.5 8908.5 9031.0 9069.0 9093.0 9110.5 8593.5 8610.5 8632.5 8658.5 8700.5 8710.5 8785.0 8830.0 8866.5 8884.5 8908.5 8914.5 9003.5 9031.0 9069.5 9093.5 9095.5 8591.5 8595.0 8610.5 8617.0 8632.5 8658.5 8700.0 8708.0 8749.0 8778.0 8785.0 8793.0 8802.5 883(]. 0 8851.5 8866.5 8871.0 8884.0 8894.5 8900.0 8908.0 8918.5 8931.5 8960.0 8966.0 8981.5 9003.5 9013.5 903]. 5 9046.5 9057.5 9069.5 9093.0 9107.0 9128.5 9136.0 9137.0 9139.5 9140.5 9149.5 9153.0 9166.0 9185.0 9185.5 9192.5 9196.5 9200.5 9201.0 9205.5 9218.0 9239.0 9239.5 9288.5 9289.0 9289.5 9297.5 9298.0 9302.0 9302.5 9314.0 9314.5 9315.0 9319.0 9353.0 9355.0 9405.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DLL $ REMARKS: CN WN FN COUN STAT 9136.5 9139.0 9140.5 9149.0 9152.5 9166.0 9185.0 9185.0 9185.5 9192.5 9196.5 9200.5 9201.0 9205.5 9218.0 9239.0 9239.0 9239.5 9289.0 9289.0 9289.5 9297.5 9298.0 9302.0 9302.5 9314.5 9314.5 9315.0 9319.0 9353.0 9355.0 9405.0 9405.0 9405.0 RUN NO. PASS NO. MERGE TOP 1 6 8263.0 1 6 8263.0 1 6 8263.0 OPEN HOLE MAIN PASS. MTEM, TENS, & TEND WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. $ : ARCO ALASKA INCORPORATED : D.S. 4 - 14A : PRUDHOE BAY : NORTH SLOPE : ALASKA MERGE BASE 9369.0 9389.0 9358.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL3 DLL 68 1 OHMM 4 6 LLD DLL 68 1 OHMM 4 7 SP DLL 68 1 MV 4 8 MTEM DLL 68 1 DEGF 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 82 Tape File Start Depth = 9405.000000 Tape File End Depth = 8263.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20566 datums Tape Subfile: 2 293 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8049.0 8263.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH - BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION of MAIN PASS. $ : ARCO ALASKA INCORPORATED : D.S. 4 - 14A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB 4 MTEM GR 68 1 DEGF 4 4 21 990 60 6 4 4 10 579 41 1 4 4 10 579 41 1 4 4 45 987 88 5 16 * DATA RECORD (TYPE# 0) Total Data Records: 1006 BYTES * Tape File Start Depth = 8263.000000 Tape File End Depth = 8045.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2186 datums Tape Subfile: 3 34 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 6 0.2500 VENDOR TOOL CODE START DEPTH GR 8049.0 AC 8248.0 DLL 8263.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9379.(] 9398.0 9367.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): 23-OCT-92 FSYS REV. JO01 VER. 1.0 1900 22-0CT-92 57 23-OCT-92 9400.0 9396.0 8050.0 9389.0 1800.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EB 8.500 8264.0 8263.0 KCL POLYMER 9.60 48.0 9.5 5.0 153.0 0.148 0.071 74.0 153.0 MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - 14A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0. 122 71.0 0.OO0 0.0 0.364 70.0 O.O00 O.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 TlR1 AC 68 5 TlR2 AC 68 6 T2R1 AC 68 7 T2R2 AC 68 8 CHT AC 68 9 TTEN AC 68 10 SPD AC 68 11 RD DLL 68 12 RS DLL 68 13 ED DLL 68 14 ID DLL 68 15 SP DLL 68 16 TEMP DLL 68 1 GAPI 1 US/F 1 1 US 1 US 1 US 1 US 1 LB 1 LB 1 F/MN 1 OHMM 1 OHMM 1 MV 1 A 1 MV 1 DEGF 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 39 859 45 0 4 40 514 81 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 64 * DATA RECORD (TYPE# 0) Total Data Records: 389 958 BYTES * Tape File Start Depth = Tape File End Depth = 9405.000000 8045.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 113064 datums Tape Subfile: 4 466 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 8852.0 AC 8852.0 DLL 8852.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9380.(] 9400.0 9358.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 23-OCT-92 FSYS REV. J001 VER. 1.0 1900 22-OCT-92 31 23-OCT-92 9400.0 9396.0 8050.0 9389.0 1800.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EB 8.500 8264.0 8263.0 KCL POLYMER 9.60 48.0 9.5 5.0 153.0 0.148 0.071 0.122 0.000 74.0 153.0 71.0 0.0 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - 14A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.364 70.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 TlR1 AC 68 5 TlR2 AC 68 6 T2R1 AC 68 7 T2R2 AC 68 8 CHT AC 68 9 TTEN AC 68 10 SPD AC 68 11 RD DLL 68 12 RS DLL 68 13 ED DLL 68 14 ID DLL 68 15 SP DLL 68 16 TEMP DLL 68 1 GAPI 1 US/F 1 1 US 1 US 1 US 1 US 1 LB 1 LB 1 F/MN 1 OHMM 1 OHMM 1 MV 1 A 1 MY 1 DEGF 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 39 859 45 0 4 4 40 514 81 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 23 415 80 5 4 4 84 503 82 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 161 Tape File Start Depth = 9406.000000 Tape File End Depth = 8846.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40284 datums Tape Subfile: 5 236 records... Minimum record length: 62 bytes Maximum record length: 958 bytes TaPe Subfile 6 is type: LIS 92/11/ 3 01 **** REEL TRAILER **** 92/11/ 7 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 9 NOV 92 12:30p Elapsed execution time = 39.71 seconds. SYSTEM RETURN CODE = 0 11 lJ 1111 111i 1t t i 11 1 t il 11 11 11 .Jill~l 77 17777777 177777 '? 77'7 '7 '7 7'7 77 7'1 77 77 7 ? 77 77 77 77 7'7 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 565655 555555 ! 777!7'/? i ? ?'777'? 77777 17 77 '/7 ll 77 ?? ?? 17 7"/ 17 17 000000 000000 0 <) 00 U 0 o 0 00 0000 0 0 0000 00 u 0 00 00 0 (D00 00 0 0 00 0 0 0 0 {") 0 O0 00 0 {) 000000 O 0000 0 *START* U ~ t t-: PCAb ~e.:b- l~LlOt, Jri tqiJNITUP ~-5 r, blOE.~ ~ P ~ ~ I IGTO'/,57()14J Jt~ U U D d LJ O ~ ) U D D u U D D iJ L) L) u u O d ti l) D t') D OAS~., ?O-UCT-?9 0~: il Oa.t'r~ 20-uCP-79 0~:~1:57 VV VV VV VV VV VV VV YV VV VV VV vV VV vv VV i 1 1I L 1 11 11 Ii ,I 1 II. 1 I 1 1. 1 1 1 1 i I. 1111 000000 000000 222222 000000 000000 222222 O0 ou O0 (?0 22 22 O0 O0 oO O0 522 22 0 0 o 0 0 t) 0 ~ o 0 0 0 2 2 00 0000 O0 0000 2 z 0 0 0 0 0 u !) 0 00 00 22 0 0 0 0 O U 0 (:~ 0 0 0 u 2 2 0000 ©0 O000 0,,) 22 0000 O0 0000 00 22 00 00 00 0 0 22 O0 ()0 O0 O0 22 000000 OUO0~'~O 2222222222 000000 000000 222222'2222 1~80 UAl'e; 20-0CT--79 i 0'70 7,5't0 ! 4 P~,EVIUL~ 'I'gFk ~A~L: o! 79/10/20 L P~ r,!G T ~: 1024 C~ITk, S t ~2 C 0 1 ~b 10650. 000 1 (il 600 . 000 10 5 O 0,0 0 0 10 ~00 , 000 10 i~00. 000 10 20 O. 000 10 t 00, o 00 ] 0000.000 9900 9800 9 7 0 V. 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