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194-149
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy ~ Vincent Nathan Lowell Date: (¢ "- ,.~ Is~ ~,,~¢ · [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date:. ~si STATE OF ALASKA RECEIVED • ALA OIL AND GAS CONSERVATION COMMISSION JUN 1 4 2012 REPORT OF SUNDRY WELL OPERATIONS OGCC 1. Operations Abandon U Repair Well U Plug Perforations Li Perforate IS Other L Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ , 194 -149 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: AK 99503 ' 50- 733 - 10065 -01 .• On 7. Property Designation (Lease Number): .. 8. Well Name and Number: Granite Point Field (ADL0018742) Granite Point ST 18742 03RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Granite Point Field (Hemlock7Middle Kenai Oil Pool) 11. Present Well Condition Summary: Total Depth measured 12,411 feet Plugs measured 9,881 feet true vertical 11,930 feet Junk measured N/A feet Effective Depth measured 9,881 feet Packer measured 9,954 feet true vertical 9,743 feet true vertical 9,182 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 615' 20" 615' 615' 1,530 psi 520 psi Surface 1,969' 13 -3/8" 1,969' 1,966' 2,730 psi 1,130 psi Intermediate 7,859' 9 -5/8" 7,859' 7,814' 5,750 psi 3,090 psi Production 2,729' 7" 10,390' 10,216' 8,160 psi 7,020 psi Liner 2,193' 5" 12,411' 11,930' 8,290 psi 7,250 psi Perforation depth Measured depth 8,120' - 8,128'; 8,394' - 8,422'; 8,429' - 8,460; 8,693'- 8700'; 8,712'- 9,532; 8770' - 8,775'; 8,902' - 8,918' True Vertical depth 8,067' - 8,074'; 8,331' - 8,358'; 8,365' - 8,395'; 8,616'-8,623'; 8,634'- 9,414'; 8,689' - 8,694'- 8,815' - 8,830' Tubing (size, grade, measured and true vertical depth) 5" 9.2# / L -80 9,954' MD 9,182' TVD 9,954' MD Packers and SSSV (type, measured and true vertical depth) 7" Otis VTL 9,182' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 5 N JUL 2 4 2UIZ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 135 0 Subsequent to operation: 20 90 300 80 90 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 12 w Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil y , 12 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Phone 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature /. /" / Phone 777 -8300 Date 6.4f/ Z BBDMS JUN 15*2012°" III " - 1/Z i 7_, Form 10-404 Revised 11/2011 0 7 /ij //Z Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date AN -3RD Add perfs 50- 733 - 10065 -01 194 -149 5/19/12 5/20/19 Daily Operations .;..` . ,. 05/19/2012 - Saturday perf n h e e u - spf, 6 0 deg as n 2 00 psi high. RIH w GR CC L218 2-1/8"x16' HC, 6 ilowa d 5 p 8 RU lubricator and pressure test to 250 psi / / / p g p p p p g and tie into CBT 5" & 7" liners, dated 11- Jan -95. Spotted perf gun from 8,902' to 8,918'. Fired gun. POOH. All shots fired. RIH w /GR /CCL, 2- 1/8 "x5' HC, 6 spf, 60 deg phase perf gun from 8,770' to 8,775'. Fired gun. POOH. All shots fired. RIH w /GR /CCL, 2- 1/8 "x7' HC, 6 spf, 60 deg phase perf gun from 8,693' to 8,700'. POOH. 05/20/2012 - Sunday RIH w/2 -1/8 "x31' HC, 6 spf, 60 deg phase and tie into CBT 5" & 7" liners, dated 11- Jan -95. Spotted perf gun from 8,429' to 8,460'. Fired gun. POOH. All shots fired C -5B zone. RIH w/2 -1/8 "x28' HC, 6 spf, 60 deg phase. Spotted perf gun from 8,394' to 8,422'. Fired gun. POOH. All shots fired C -5B zone. RIH w/2- 1/8 "x8' HC, 6 spf, 60 deg phase. Spotted perf gun from 8,120' to 8,128'. Fired gun. POOH. All shots fired C -3 zone. RIH with spangs and standing valve and spanged standing valve off at 7,540'. POOH. RD lubricator. Secure well. Turn well over to production. 0 ASB U I LT Snna Platform Well No. An -3RD .H Hilcorp Alaska, LLC Actual Completion 1/16/95 CASING AND TUBING DETAIL PTD# 194 -149 API # 50- 733 - 10065 -01 CASING SIZE WT GRADE ID TOP BTM. RKB to TBG Head = 127 MSL Conductor 20" 94# H -40 19.124" Surface 615' Surface 13 -3/8" 54.5# 1 -55 12.615" Surface 1,969' 40#/ N80 /S Intermediate 9 -5/8" 43.5# & 95 8.681" Surface 7,859'(KOP) L , 47# Production 7" Liner 29# L -80 6.184" 7,661' 10,390' Liner 5" Liner 15 #/ 18# L -80 4.276" 10,218' 12,411' TUBING L , Long String Long String 3 -1/2" 9.2# L -80 2.992" Surface 7,681' 1 MI Short String Short String 3 -1/2" 9.2# L -80 2.992" Surface 7,615' 2 JEWELRY DETAIL I NO. Depth OD Item 1 7,481' 3.5" X Profile Nipple 3 2 7,588' KOBE Cavity I 3 7,647' 3.5" R Profile Nipple 4 4 7,680' 3.5" WL Re -entry guide PERFORATIONS Interval Zone Top Bottom FT SPF Date Comments C -3 ✓ 8,120' 8,128' 8' 6 5/20/2012 C - V 8,394' 8,422' 28' 6 5/20/2012 C - `/ 8,429' 8,460' 31' 6 5/20/2012 ,lk': - ' ." + C -7A 1/4 8,693' 8,700' 7' 6 5/19/2012 rw i14ti A, Vr =t v,; C -7 8,712' 9,532' Unknown Unknown Unknown , 3 "» z C -7B `/ 8,770' 8,775' 5' 6 5/19/2012 Reperf. ' f n- : #; C -7E ✓ 8,902 8,918' 16' 6 5/19/2012 Reperf. Hemlock 10,975' 11,116' 141' 6 1995 Isolated L , #r te: ,; ' ; ,,' ... `.i Hemlock 11,672' 11,855' 183' 6 1995 Isolated Hemlock 11,918' 12,170' 252' 6 1995 Isolated Hemlock 12,212' 12,265' 53' 6 1995 Isolated i F._ Plugs & Fish Depth Depth Item (Top) (Bottom) i 101114r31MAY4 ■ 9,881' 10,300' Cement Plug PBTD = 12,327' MD (11,868' TVD) 10,350' 10,912' Cement Plug TD = 12,411' MD (11,930' TVD) 10,912' 12,280' Top of TCP Guns Updated by DMA 6/14/2012 • • c a e 1 ,L\ ° � ; ; SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 June 12, 2012 Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 RE: No -Flow Verification Granite Point State 18742 3RD PTD 1941490 5,LNANED JUL 8 ZD12 Dear Mr. Myers: On June 11, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Granite Point State 18742 3RD located on the Anna Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that Hilcorp had the well lined up to calibrated flow measurement equipment with suitable range and accuracy. Granite Point State 18742 3RD was monitored for flow for three hours through calibrated flow measurement equipment. During the flow monitoring period, 100 standard cubic feet of gas per hour was initially measured, falling off to zero within the three -hour flow monitoring period. There was no liquid production to surface during the test. The subsurface safety valve must be returned to service if Granite Point State 18742 3RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Anna Platform. Sincerely, Cy James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors Subject: Re: Anna 3RD Date: Tu¢, 10 Scp 2002 12:01:02 -0800 From: Steve McMains <stcv%mcmains~admin.stat¢.ak.us> To: "Dolan, Jeff J" <dolanjj~unocal.com> Jeff, I will insert the perforation record into the well file and I will have to change the status on the 10-407 dated 10/6/1995 with Russell Schmidt signature, from suspended to oil producer. I see where you are trying to convert the well to an injector, but not complete as of yet. Steve "Dolan, Jeff J" wrote: Tom, I researched the well files regarding An-3RD. I found the 10-407 completion report dated 9/25/95 which suspended the well plugging the Hemlock interval @9,881' MD. Subsequent to that the Tyonek C7, C8 and C9 intervals were perforated on November 2nd 1995. Our records indicate that production was poor and erratic. The interval quickly watered out and was shut in in June of 1996. The well was turned on briefly in August of 1997 and quickly returned to 100% watercut. I have attached the perforating record from our database for the Tyonek C7, C8 and C9 job done on Nov 2nd 1995. I did not find any 10-403 or 10-404's documenting the perforation of the Tyonek. Do we need to prepare a 10-404 for the perforation job or will the perforation record be sufficient? Jeff ..... Original Message ..... From: Tom Maunder [mail to : tom maunder@admin, state, ak. us] Sent: Thursday, August 29, 2002 7:33 AM To: Tim Billingslea; Jim Mosley; Jerry Bowen; Jeff Dolan Cc: Steve McMains Subject: Anna 3RD Guys, I am throwing a wide net to get some information regarding the subject well. We are interested in the period since October, 1995. At that time, a workover was conducted, the Hemlock abandoned and the well suspended. It appears to have met the suspension criteria. Early this year, a 403 was submitted to convert the well to an injector without a packer. Recently Steve McMains was doing some work with regard to one of our production reports and it appears that production is shown for this well for some time in 1996 and it appears that there are perforations in the Tyonek C series that were added after the cement plugs were set in 1995. I'm not sure which of you can help us with some information. We would appreciate receiving copies of the information you may have in your well file so we can fill in the data gaps. Thanks. Tom Maunder An-3 Perf ll-2-95.xls Name: An-3 Perf ll-2-95.xls Type: Microsoft Excel Worksheet SGANNF-..D SEF ! Z Ke: anna Dttu ( appl i ca ti on /vnd . ms - excel ) > Encoding: base64 SCANNED S E P .1.! 2 2OO2 PERFORATING RECORD NELL: An-3RD FACILITY: Anna platform _FIELD: Granite Point APl: 50-733-10065-01 AFE: 751216 SERVICE CO: Schlumberger ENGINEER: Greg Langhamer ~JNOCAL WITNESS: Ralph Holman GUN TYPE: Enerjet SIZE: 2-1/8" CHARGE: 14 gr. SHOTS/FT: 6 PHASING (DEG.): 0 TIE-IN LOG C O M PA NY: Schlumberger :TYPE: CBL )ATE: 1/11/1995 RUN NO: 26 LAST PBTD TAG DATE: 9/25/1995 DEPTH: 9,881 HOW: E-line WELL INFORMATION WH CONNECTION: KB ELEVATION: 127 TBG. SIZE: 3-1/2" CSG. SIZE: 7" MIN. RESTR. DIA: MIN. RESTR. MD: HOLE ANGLE (MAX): NOTE: SHOOT THESE INTERVALS! PROPOSED INTERVALS TO BE PERFORATED SAND/ AlT DEPTHS TIE-IN LOG DEPTHS BENCH TOP BOTTOM TOP BOTTOM FEET SPF DEG C9 9,517 9,533 9,516 9,532 16 6 0 C8 9,149 9,207 9,146 9,204 58 6 0 C8 9,220 9,238 9,218 9,236 18 6 0 C7 8, 724 8, 764 8, 721 8, 761 40 6 0 C7 8,851 &861 8,848 8,858 10 6 0 C7 8,869 8,895 8,866 8,892 26 6 0 C7 8,931 8,957 8,928 8,954 26 6 0 0 0 0 0 0 0 0 0 0 0 0 TOTAL: 194 REMARKS NOTE: Actual depths perforated are CBL, not DIL depths. ACTUAL INTERVALS PERFORATED SAND/ DIL DEPTHS BENCH TOP BOTTOM FEET C9 9,516 9,532 16 C8 9,146 9,204 58 C8 9,218 9,236 18 C7 8, 721 8, 761 4O C7 8,848 8,858 10 C7 8,866 8,892 26 C7 8, 928 8, 954 26 0 0 0 0 0 0 0 0 0 0 0 TOTAL: 194 ICOMPLETION DATE: 1/2/19951 WELL TEST DATA BEFORE AFTER DATE: DATE: 12/3/1995 GROSS: 0 GROSS: 263 OIL 0 OIL 86 GAS (P): 0 GAS (P): 0 CUT %: CUT %: 67 TBG. PSI: TBG. PSI: 70 CSG. PSI: CSG. PSI: 65 JOB COSTS AFE ACTUAL E-LINE: $33,460 E-LINE: $33,009 TOTAL: SCANNED S E P .!_ 2; ;~00Z An-3 Perf 11-2-95.xls Froduct~on ~F ~ l Subject: Production GP ST 03RD Date: Wed, 24 Jul 2002 13:55:42 -0800 From: Steve McMains <steve_mcmains~admin. state.ak.us> To: Don Page <DPage~unocal.com> CC: John Hartz <jack_hartz~admin. state.ak.us>, Steve McMains <steve_mcmains~admin. state.ak.us> Don~ Over the years, we find errors in production reported against the wrong api caused by numerous reasons, one of the big problem is that the correct paper work, forms, weren't submitted by the operator in a timely manner and suspended and plugged wells not removed from production reports. When a problem is identify, production data needs to be corrected quickly. I discover or uncovered a production problem with well Granite Pt ST 03RD, api # 733-10065-01 that needs to be corrected. This well has been suspended (no perforations and cement down hole) since Sept 1995 and production was reported against the api number thru Dec 1997, and shut-in Jan 1998 thru June 2002. A production revision or reallocation of the oil reported after the suspend well date has to be correct and allocated to the correct API number. AOGCC request this problem be addressed and UNOCAL provide the appropriate corrected well production data. If you need additional information please email or call me at 793-1241. Steve i Name: steve mcmains.vcf ~-- . ~i Type- VCar~ (texffx-vcard) L_~steve mcmams vctt ' 7bit - ' ' ~ Encoding: I Description: Card for Steve McMainsi I of 1 7/24/2002 1:56 PM ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 07/24/2002 194-149-0 733-10065-01 GRANITE PT ST 18742 03RD 031 ADL0018742 CODE I NAME CODE AREA SHORE LATERL 145000 UNION OIL CO OF CALIFORNIA 820 COOK INLET BASIN OFF + + CODE I NAME FLDPOL FLDPOL FLDPOL FLDPOL FLDPOL 280152 GRANITE PT, HEMLOCK UNDEFINED 280150 000000 000000 000000 000000 CODE NAME CODE FEET CODE FEET MD TVD ............................... 00000 KB 127 12411 11930 0 +- -+ I 0729 N 0636 E 12 10N 012W S 2157 N 2423 E 12 10N 012W S SSSV DEPTH 7560 DEV i-OIL DEV 1-OIL DEV SUSP NO NO RCV YES 30002 PERMIT I PERMIT I DATE I DATE I DATE OF I RECORD I CONFID 11/30/1994 11/30/1994 12/07/1994 01/16/1995 09/25/1995 04/13/2001 42994 ........................................................................... CANNE i JUL ALASKA INDIVIDUAL WELL PRODUCTION AS OF 07/24/2002 WELL-NAME: GRANITE PT ST 18742 03RD API: 733-10065-01 LEASE: ADL0018742 OPERATOR: UNION OIL CO OF CALIFORNIA FIELD/POOL: GRANITE PT, MIDDLE KENAI SALES CD - 30 ACCT GRP - 002 FINAL STATUS: DEV I-OIL CURRENT STATUS: DEV SUSP ** OIL PRODUCTION ** 1995 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP SHUT-IN SHUT-IN SHUT-IN SHUT-IN HYD PUMP HYD PUMP DAYS 14 15 31 30 30 7 29 31 OIL 1,282 1,310 2,460 750 147 11 1,836 1,904 WTR 796 937 545 877 329 58 31 4,654 GAS 1995 TOTALS OIL 9,700 WATER 8,227 GAS CUM OIL 9 700 CUM WATER 8 227 CUM GAS 1996 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP HYD PUMP SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS 31 29 31 29 31 30 31 28 OIL 2,429 2,631 2,653 2,035 1,689 1,607 1,460 WTR 5,265 4,794 4,028 2,967 1,681 1,787 2,447 3,573 GAS 2,736 1,407 698 642 1,650 3,206 3,597 346 1996 TOTALS OIL 14,504 WATER 26,542 GAS 14,282 CUM OIL 24 204 CUM WATER 34 769 CUM GAS 14,282 1997 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN HYD PUMP HYD PUMP SHUT-IN HYD PUMP HYD PUMP HYD PUMP HYD PUMP DAYS 27 6 21 9 10 8 OIL 5,104 WTR 6,395 1,326 415 1,509 1,706 1,670 GAS 667 145 2,852 1997 TOTALS OIL 5,104 WATER 13,021 GAS 3,664 CUM OIL 29,308 CUM WATER 47,790 CUM GAS 17,946 1998 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS 1998 TOTALS OIL WATER GAS CUM OIL 29 308 CUM WATER 47 790 CUM GAS 17,946 1999 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS 1999 TOTALS OIL WATER GAS CUM OIL 29 308 CUM WATER 47 790 CUM GAS 17,946 2000 JAN FEB MAR APR MAY J-gN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS 2000 TOTALS OIL WATER GAS CUM OIL 29 308 CUM WATER 47,790 CUM GAS 17,946 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 07/24/2002 2001 J2%N METH SHIY~-IN DAYS OIL WTR GAS 2001 TOTALS OIL 2002 JAN METH SHUT-IN DAYS OIL WTR GAS 2002 TOTALS OIL FEB MAR APR MAY JUN JUL AUG SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN FEB SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL 29,308 AUG 29,308 SEP SHUT-IN CUM WATER SEP CUM WATER OCT SHUT-IN 47,790 OCT 47,790 NOV SHUT-IN CUM GAS NOV CUM GAS DEC SHUT-IN 17,946 DEC 17,946 ON OR BEFORE W PEEkilT ,o C)/' 9 6 Da'te~ I i/.-. . R U N D/:,, 'i" E._jR E C ',./D 94 .... 1 4 9 AII 94---. 149 Ail 94 .... ig9 A2~I~4ITHAL/~'/I_AT...L/ 107~0-1 1506 94.-- 149 BHC/SL 94- 'i 4 9 BHC/'SL 94.--149 BPSR 94 .... i 4.'-3, FMS 94.- 'i 4 9 !.... D T/CN L. 02/21/95 0 '''~ ' '~ ~ ~, ~./ ~.i/~,~ 02 / 2 i/' 95 02 ,/2 'i ,/95 02/' 2 i / 95 02/'2 'i/95 02/2 i/95 02/2 i / 95 94 - 'i 49 i,~UP (FORNATZON) ~.~-"~890-1241i 0,2/21/95 94 --- i 49 IR F T Ar'e dr'y d'¥tch sampies Was the we1 i cor'ed? Are weii 'tests requi'fed? 02/2 'i/'95 I"l 0 STATE OF ALASKA · ALAS? ...... OIL AND GAS CONSERVATION COMF '~ION . ELL COMPLET!. N OR RECOMPLETION R,-PORT AND LOG · ,~tatus of Well Classification of Service Well OIL E] GAS [~ SUSPENDED E~ ABANDONED[~ SERVICE 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 94-149/95-161 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519~ ,./~-~ ..r~ 50-733-10065-01 4. Location of well at surface 4! z..~/"? ~./Uqit,.or Lease Name 729' FNL, 636' FEL, SEC. 12, T, 0N, R12W, SM ', .... 4.-~, ~GlCCC~IT;E ~POINT FIELD ANNA At Top Producing Interval 1565' FNL, 1837' FEL, SEC. 12, T10N, R12W, SM.~ ~-'x~ WELL #31~D~ At Total Depth i ;~:~--'~'-~' 11. Field and Poo/ 2157, FNL. 2423' FEL. Sec. 12, T10N. R12W. SM : GRAN,TE PO,NT F,E,D _ · 5. Elevation in feet (indicate KB, DF, etc.)127, KB MSL 16' Lease Designati°n and serial N°'ADL 18742 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 09/19/95I 09/25/95I 77' Feet MSL 0 17.12,4IT°tall '/1Depth1,930'(M D +'f'VD) 18. Plug9881Back,/9743,Depth (M D +'I'VD) YES19. Directional[~ Surve~YNo L_~ 20. DepthN/Awhere SSSVfeet MsetD 21. ThicknessN/AOf Permafrost 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER GRADE TOP ~ BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 H-40 O' 615' 985 sx 0 13-3/8" 54.5 J-55 O' 1969' 17-1/2" 1200 sx 0 9-5/8" 40/43.5/47 N80/S95 O' 7859' (KOP) 12-1/4" 1500 sx O' 7" 29 LBO 7661' 10390' 8-1/2" 1172 sx O' 5" 18/15 L80 10218' 12411' 6" 378 sx 0 Plug #1 10350' 10912' 52 sx Plug #2 9881' (Tag) 10300' 83 sx 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforations SIZE I DEPTH SET (MD) I PACKER SET (MD) 3-1/2" 9.2# L-80 0-7681' Well abandoned awaiting 3-1/2" 9.2# L-80 0-7615' re-completion evaluation 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED NONE 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL- BBL GAS-MCF WATER- BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water· Submit core chips· 'None Form 10-407 rev. 7-1 - 80 CONTINUED ON REVERSE SIDE Submit in duj:fli(~a~ OCT 'i t 199'-'-5 AlaSka Oil & Gas Cons. Commission A~ch0ra0e 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , .., ,.. ,\ \ ~/ Signed G. RUSSELL SCH MIDT ~"L ~~ /~¢~e DRILLING MANAGER Date 10106/95 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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. re , ~ Item 28: If no cores taken, indicate "none". OCT 't ! Alaska 0il & Gas C0rts. ¢0rJmJssi.0~ ANNA 3RD DAY 1 (09/19/95) ACCEPT RIG 9/19/95 @ 00:00 HRS. RU OVER WELL. DISPLACE DOWN ANNULUS & UP LONG STRING W/FIW. 800 BBLS TOTAL. DISPLACE DOWN ANNULUS UP SHORT STRING - 200 BBLS. DISPLACE DOWN LONG STRING AND UP ANNULUS - 80 BLS. EACH CIRC. CLEAN. CAUGHT 60 BBLS OF CONTAMINATED MU @ INTERFACE OF FIW/MUD. DISPLACED DWN LONG STRING AND UP SHORT STRING W/11 PPG. SHUT DWN & OBSERVE. ANNULUS = 270 PSI, LONG STRING = 345 PSI, AND SHORT STRING = 345 PSI. WT UP MUD TO 12.0 PPG. CIRCULATE AND KILL WELL. SHUT DWN & MONITOR WELL. ANNULUS = 80 PSI. L.S. = 125 PSI. S.S = 60 PSI. WT UP TO 12.5 PPG AND BEGIN DISPLACING WELL. DAY 2 (09/20/95) DISPLACED WELL W/12.5 PPG MUD. SET BPV N/D TREE. N/U BOP. TEST BOP'S. PULL HANGER FREE POOH AND STAND BACK DUAL 3- 1/2" TUBING STRINGS. LID JEWERLY. DAY 3 (09/21/95) FINISH STANDING BACK 2-718" TUBING AND SEALS. RIH W/OTIS VTL PACKER RETRIEVING TOOL ON JARRING ASSY. ATTEMPT TO FREE PACKER W/60K OVERPULL WITHOUT SUCCESS. POOH. MADE TUBING CUT W/2.25" JET CUTTER AT 10051'. RIH W/SPEAR AND LATCH PACKER AT 9955'. PULL FREE W/O OVERPULL. OCr 995 0il ~, G&s Oo~s. Commis¢o~ ' 'N~cborage DAY 4-6 (09~22-24~95) POOH W/FISH RECOVERED PACKER FOUND PACKER FLOW CUT W/ELEMENTS COMPLETELY GONE. RIH W/OVERSHOT LATCH 2-7/8" TUBING AT 10051'. JAR ON TCP GUNS 4.5 HRS NO MOVEMENT. MAKE TUBING CUT AT 10912'. POOH LID 26 JTS OF TUBING FISH. RIH W/CEMENT STRINGER. LAY 15.8 PPG CMT PLUG FROM 10912' ~' TO 10350'. POOH TO 10320'~REVERSE OUT. ATTEMPT TO BRADEN HEAD SQUEEZE WI3000 PSI HELD FOR 0.5 HR NO CMT WENT INTO FORMATION. LAY 15.8 PPG CMT PLUG FROM 10300 TO 9800'.~'~ POOH, LID EXCESS PIPE. RIH WI6" BIT AND SCRAPER. TAG SOFT CMT AT 9860'. WOC W/CLEANING TANKS. CLEAN OUT CMT TO 9881'. DISPLACE 12.5 PPG MUD W/FILTERED INLET WATER. POOH LID 3-1/2" DP. (NOTE: STEEL ROD 1/2" X 8-1/2" FELL IN HOLE). CHANGE RAMS TEST SAME. R IH W/DUAL 3-1/2" KOBE COMPLETION. DAY 7 (09/25/95) MAKE UP TUBING HANGER AND LAND COMPLETION W/TAIL AT 7681'. N/D BOPE. N/U TREE CLEAN PITS. FINAL REPORT. OCT 'i '1 i99:5 Alaska Oil & Gas Cons. Commission Anchorage ANNA PLATFORM Vv~LL # 3RD GRANITE POINT (GP) ABANDONMENT DIAGRAM 9/25/95 J COMPLETION DESCRIPTION 1) 3-1/2" 9.2# L-80 SCBT Long String 0 - 7681' 2) 3-1/2" 9.2# L-80 SCBT Short String 0 - 7615 3) KOBE Cavity ~ 7588' 4) 3-1/2 .... X" Profile Nipple ~ 7481' 5) 3-1/2 .... R" Profile Nipple ~ 7647' 6) 3-1/2" WL Re-Entry Guide ~ 7680' . RKB = 127' PLUG #2: 10300' - 9881' TAGGED PLUG 01: 10912' - 10350' 52 b-'X TCP FISH 10912'-12280 PBTD 12,327' L 20" 94//Casing ~ 615' ~- 13-3/8" 54.5# Casing ~ 1969' Top of 7" Liner ~ 7661' 9-5/8" 40/43.5/47# N80/S95 Casing ~ 7859' (KOP) Top of 5" Liner ~ 10218' T' 29# L-80 BTC Liner ~ 10390' Hemlock Perfs 10975'-11116' H~nlock Perfs 11672'-11855' Hemlock P~fs ' 1918'-12170' H~ock P~ 12212'-12265' 5" lg&lS~ bS0 BTC L~ ~ 12411' STATE OF ALASKA AL./- k OIL AND GAS CONSERVATION COMI ~ION APPLICATION FOR SUNDRY APr ROVALS 1. Type of request: Abandon _ _ Suspend X__ Alter casing__ Repair well __ Change approved program __ 2. Name of Operator UNION OIL COMPANY OF CAUFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface 729' FNL, 636' FEL Sec. 12, T10N, R12W, S.M. At top of productive interval 1565' FNL, 1837' FEL, Sec. 12, T10N, R12W, SM At effective depth 2095' FNL, 2324' FEL, Sec. 12, T10N, R12W, SM At total depth 2157' FNL, 2423' FEL, Sec. 12, T10N, R12W, SM Operations shutdown Re-enter suspended well Plugging __ Time extension __ Stimulate __ Pull tubing _ _ Variance Perforate Other .... 6. Datum elevation (DF or KB) 5. Type of Well: Development X_ Exploratory -- StmlJgraphic __ Service ORIGINAL 127' KB MSL 7. Unit or Property name Granite Pt Anna 18742 8. Well number 3rd 9. Permit number 94-1.49 10. APl number 50-733-10065-01 11. Field/Pool ranite Pt. Field ~. ! ) feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 12411' 11930' 12327' 1180Z Size feet feet feet feet Plugs (measured) SEP 1 995 Junk (measured) ~3, Dit & Gas Cons. Commission ,., ~ch0rage Cemented Measured depth True vertical depth Conductor 615' Surface 1969' Intermediate 7859' Production 2729' Liner 2193' Perforation depth: measured 20" 985 sx 615' 615' 13-3/8" 1200 sx 1969' 1966' 9-5/8" 1500 sx 7859' (KOP) 7814' 7" 1172 sx 10390' 10215' 5" 378' sx 12411' 11930' 10975'-11116'; 11672'-11855'; 11918'-12170'; 12212'-12265' true vertical 10757'-10882'; 11362'-11525'; 11511'-11763'; 11777'-11830' Tubing (size, grade, and measured depth) 3-1/2" L-80 0-7303' 3-1/2" L-80 0-7627 2-7/8' L-80 7627'-9954' Packers and SSSV (type and measured depth) 7" VTL Packer @ 9954'; "RRO' SVLN @ 7560' 13. Attachments Description summary of proposal X_ Detailed operations program_ _ BOP sketch X_ 14. Estimated date for commencing operation 115. Status of well clas~ication as: 9-24-95 Pat Ryan 263-7864 16. If proposal was verbally approved Oil X_ Gas __ Suspended __ Name of approver Date approved Service 17. hereby certify that the fo~eoo~g is.t[u~elan~l corr,~et to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by the order of the Commission Original Signed By David W. Johnston Date September6, 1995 1Appr°va' (~~/~/ approved Copy C~"m~'eto m/is~rsr~r~-Date SUBMIT IN TRIPLICA~ ~~ Form 10-403 Rev 06/15/88 DRLG. MGR. DRLG. SUPT. DRLG. ENGR. ANNA 3RD SUSPENDED WELL PROCEDURE AUGUST 28, 1995 Backffround Information: The Anna 3 was redrilled to the Hemlock in December of 1994 with the completion of the well in January 1995. The well potentialed for 113 BOPD + 76 BWPD, and subsequently quit delivering oil. The well is currently shut in with shut in tubing and casing pressures equal at 1550 psi. When allowed to flow the well will immediately bleed offits pressure and deliver clear water out the annulus whose chlorides are 8700 ppm. Once the well is bled off and shut in, it will reach 1550 psi a_tier about 18 hours shut in. There is strong indication of a packer leak. The current configuration of the well is that it has no SSSV in the SVLN, the RA Sliding Sleeve at 7364' is open and there is a pump and standing valve in the cavity. Objective: To P&A the Hemlock portion of the well and leave it in a suspended status such that a Tyonek recomplction is possible ff evaluation of the Tyonek proves to have value. 1. Prior to skidding the rig, coordinate with production and retrieve the pump and standing valve with slickline. Close the RA sliding sleeve at 7364'. 2. Attempt to circulate both the long string and short string with FIW taking returns through the packer leak and annulus to production. This is an attempt to both remove any existing hydrocarbons from the well and establish the deepest point of circulation. If this circulation attempt fails, RU wireline and punch the 2-7/8" tubing sub at 9950' and circulate both the long string and short string taking returns through the annulus to production. Monitor pressures and flow rate once circulation is complete. Calculate and arrange for kill weight mud. 3. Skid rig, set BPV ("II" BPV profile), ND tree and NU and test BOP. 4. POH standing back 3-1/2" tubing. End of tubing has a straight slot locator. 5. RIH with "VTL" retrieving tool on drill pipe with jarring assembly. 6. Engage Halliburton "VTL" packer at 9955' and release same. POH with drill pipe, packer, and gun assembly. Have Halliburton TCP specialist available to lay down gun assembly. 7. RIH with 2-7/8" cementing string and attempt to work to 12,327' (PBTD). 8. Spot 75 sxbalanced plug f/12,327' - 11,512'. PUHto 11,512'. 9. Spot 75 sx balanced plug f/11,512' - 10,698' 10. Spot 75 sx balanced plug fl 10,318' - 9,855'. PUH to 9700' and CCH (WOC). 11. RIHandTagTOC. TOC must be no deeper than 10,118'. Notify AOGCC to witness tagging of this plug. 12. 13. 14. 15. POH laying down cementing string and drill pipe. RIH with 3-1/2" Kobe completion as a dual and land at 7500'. Set BPV, ND BOP, NU and test tree. Release rig. NOTE: ANY TUBING THAT IS LAYED DOWN FOR SBlPMENT TO THE DOCK MUST HAVE CLOSED END THREAD PROTECTORS AND THE TUBING MUST BE HANDLED AS OUTLINED IN PROPOSED ADDITION TO SECTION VI: PROCEDURES ALASKA REGION GUIDELINE FOR HANDLING EQUIP~NT WITH NATURALLY OCCURING RADIOACTIVE MATERIAL (NORM). ANNA PLATFORM WELL # 3RD GRANITE POINT (GP) COMPLETION DIAGRAM 2/21/95 3 4 5 6 13-3/8" 54.5# Cming ~ 1969' Top of 7' ~ (~ 7661' 9-5/8' 40/43.5/47# NS0/S95 Casing 1~ 7859' (KOP) COMPLETION DESCRIPTION 1) 3-1/2" 9.2# L-80 SCBT Long String 0 o 7627' 2) 3-1/2" 9.2# L-80 SC'BT Short String 0 - 7303' 3) KOBE Cavity ~ 7303' 4) "RA" Nipple ~ 7364' 5) "RA" Nipple ~ 7494' 6) "RRO" SVLN ~ 7560' SSSV Removed 2/21/95 7) 2-7/8" 6.4# L-80 BTC Tubing 7627' - 9954' 8) 7" HES "VTL' Packer ~ 9954' 9) "X' Nipple ~ 10035' 10) 3-3/8" TCP Guns 22gm ~ 6 jspf RKB = 127' ?m'D 12,327' 10 Top of S' Liner (~ 10218' 7" 29# L-80 BTC Liner ~ 10390' HemlockPerfs10975'-lll16' HemlockPeffal1672'-l1855' HemlockPerfsllglS'-12170' HemlockPerf~12212'-12265' 5' 18&15# L-80 BTC Liner (~ 12411' ANNA PLATFORM WELL # 3RD GRANITE POINT (GP) SUSPENSION DIAGRAM (~ROeOSED) COMPLETION DESCRIFrION 1) 3-1/2" 9.2# L-SO SCBT Long String 0 - 7500 2) 3-1/2" 9.2# L-80 SCBT Short String 0 - 7500' 3) KOBE Cavity ~ 7500' RKB = 127' PLUG #2: 10,318' - 9,855' 75 SX TAGGED i!!!!~."¥:! ::::::::::: .:.:.:.:.:.:. :.:::..:..::.-:: :.:.:.:.:.:,. .:c.:.:.:.: ....... ...... :.:c.:.:.:.~ .v........ :.:.:.:.:.:.: :::-..'::::5-..' ::::::::5::: .:.:.:.:.:.: .........~.. 20" 94~ Casing (~ 615' ~ 13-3/8" 54.5# Casing (~ 1969' Top ofT' Liner (~ 7661' 9-5/8" 40/43.5/47# NS0/S95 Casing ~ 7859' 0tOP) Top of S" Liner (~ 10218' T' 29# L-80 BTC Liner ~ 10390' PLUG #1: 12,327' - 10,698' 1508X PBTD 12,327' Hemlo~Peff~10975'-lll16' HemlockP~l1672'-l1855' Hemlock P~llglS'-12170' HemlockP~12212'-12265' 5" 18&15# L-gO BTC Liner ~ 12411' FILL-UP FLOW KILL LINE ANNULAR BOP 13%"3000 psi PIPE RAMS 13~/g' 5000 psi BLIND RAMS t' 13%"5000 psi i ~ , I DRILLING is'---~ i-P~~/G-U~ SPOOL L/"-4L.--%~3%'5ooo p CHOKE 5000 psi i ' 4" 5000 psi 13%"5000 psi LINE RISER 13 5000 psi SEP ~ 2 1995 Alaska Oil & Gas Cons. Commissior~ Anchorage coo BOP ACK 13 %" 50O0 psi ~ oui~o.--C OF' I~INOWAtLS FIANC£ PANIC I. IN£ -~ 5.000 PSI I. VA! 1/16 -SU F1 (;. W/R39 --~ BUND HUB ~ DERRICK .I' REU~ VALVE 10' VENT UN£ PaLL J5 ADJ. CHOKE-- ~$I' POR CI..AI~P HUB CONN~ON TANK ... .... IO' 150 lb. B[INO FIANCE OTP.) I0' 150 lb. FLANGE UUD CAS SEPERA10R 2" SIPHON UNE · E' 15o lb FIANCE j 1o t5 CtAUP W~ ~X~55 ~ ~/~g' --SU nc. lo, ooo lifO. CHOKE 10 PR00UCI1ON 8' UUD RE'IURN UNE UNOC4L I:::IiO/~E 14~lro(B COOK INLEt DwC,. CU-f:l?$.q2 CO~J~ lilt STATE OF ALASKA AL'f ",A OIL AND GAS CONSERVATION COMI., .,SION REPOR'I OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate . Plugging m Perforate B Pull tubing . Alter casing Repair well __ Pull tubing B Other X 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface 729' FNL, 636' FEL, Sec. 12, T10N, R12W, SM At top of productive interval 1565' FNL, 1837' FEL, Sec. 12, T10N, R12W, SM At effective depth 2095' FNL, 2324' FEL, Sec. 12, T10N, R12W, SM At total depth 2157' FNL, 2423' FEL, Sec. 12, T10N, R12W, SM 5. Type of Well: Development Exploratory Stmfigraphic 6, Datum elevation (DF or KB) 127' KB MSL feet 7. Unit or Property name GRANITE PT. ANNA 18742 8. Well number 3RD 9. Permit number/approval number 94-149, 10. APl number 50-733-10065-01 11. Field/Pool GRANITE POINT FIELD 12. Present well condition summary Total depth: measured true vertical 12411' feet Plugs (measured) 11930' feet Effective depth: measured 12237' feet Junk (measured) true vertical 11802' feet Casing Length Size Cemented Measured depth Structural Conductor 615' 20' 985 sx 615' Surface 1969' 13-3/8' 1200 sx 1969' Intermediate 7859' 9-5/8' 1500 sx 7859' (KOP) Production 2729' 7' 1172 sx 10390' Liner 2193' 5' 378 sx 12411' Perforation depth: measured 10975'-11116'; 11672'-11855'; 11918'-12170'; 12212'-12265' True vertical depth 615' 1966' 7814' 10215' 11930' true vertical 10757'-10882'; 11362'-11525'; 11511'-11763'; 11777'-11830' Tubing (size, grade, and measured depth) 3-1/2', L-80 0-7303' 3-1/2' L-80 0-7627' 2-7/8' L-80 7627'-9954' Packers and SSSV (type and measured depth) 7" "V'i'L' Packer @ 9954' RRO' SVLN @ 7560' w/SSSV removed 2/21/95 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A RECEIVED 0it & Gas Cons. Commission ^nchora 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 56 310 71 110 56 310 71 110 Tubing Pressure 80 80 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X__ 16. Status of well classification as: Oil X Gas __ Suspended Service Signed G. RusselISchmidt Title Drilling Manager Form 10-404 Rev 06/15/88 Date 3/09/95 SUBMIT IN DUPLICATE l~mrt of Daily Ol~rations Ann_a 3rd 2/12/95 thru 2/21/95: Pulled jet pump, dummy standing valve and wir¢lin¢ rctfieveabl¢ SSSV. Wait on pump parts. Run standard standing valve, and reciprocating pump in hole. Placed well on production 2/21/95. Well producing. ANNA PLATFORM WELL # 3RD GRANITE POINT (GP) COMPLETION DIAGRAM 2/21/95 3 4 5 6 L 20" 94# Casing ~) 615' ~, 13-3/8" 54.5# Casing (~ 1969' Top ofT' Liner ~17661' 9-5/8" 40/43.5/47# N80/895 Casing (~17859' CKOP) COMPLETION DES CRIPTION 1) 3-1/2" 9.2# L-80 SCBT Long String 0 - 7627' 2) 3-1/2" 9.2# L-80 SCBT Short String 0 - 7303' 3) KOBE Cavity ~ 7303' 4) "RA" Nipple ~ 7364' 5) "RA" Nipple ~ 7494' 6) "RRO" SVLN ~ 7560' SSSV Removed 2/21/95 7) 2-7/8" 6.4# L-80 BTC Tubing 7627' - 9954' 8) 7" tiES "VTL' Packer @ 9954' 9) "X" Nipple ~ 10035' 10) 3-3/8" TCP Guns 22gm ~ 6 jspf RKB = 127' 10 Top of S" Liner (~ 10218' 7" 29# L-80 BTC Liner (~ 10390' HemlockPerfs10975'-lll16' HemlockPeffsl1672'-l1855' I-Iemlock Pe~s 11918'-12170' R ECEIV£D Hemlo~kPeffs12212'-12265' ~fl 1 ,5 1995 ~.~. 0[1 & Gas Cons. ~mmisslon .~chom ~ 5" 18&IS# ~80 BTC ~ 12411' ~.~. STATE OF ALASKA AL,' ~ OIL AND GAS CONSERVATION COMM,JSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon m Suspend __ Operations shutdown m Re-enter suspended well__ Alter casing__ Repair well m Plugging m Time extension __ Stimulate Change approved program __ Pull tubing Variance __ I 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 , Location of well at surface 729' FNL, 636' FEL, Sec. 12, R10N, R12W, SM At top of productive interval 1565' FNL, 1837' FEL, Sec. 12, T1 ON, R12W, SM At effective depth 2095' FNL, 2324' FEL, Sec. 12, T10N, R12W, SM At total depth 2157' FNL, 2423' FEL, Sec. 12, T10N, R12W, SM Type of Well: Development X_ Exploratory __ Strafigraphi¢ Perforate Other X 6. Datum elevation (DF or KB) 127' KB MSL feet 7. Unit or Property name Granite Pt. Anna I ~ 7g"/~ 8. Well number RF.£EIV£D FEB 2 4 1995 0il & Gas Cons. Commission Anch0ra?,", Well 3RD 9. Permit number 94-149 10. APl number 50-733-10065 ,,..- O ~ 11. Field/Pool Granite Point Field 12. Present well condition summary Total depth: measured true vertical 12,411' feet Plugs (measured) 11,930' feet Effective depth: measured 12,237' feet Junk (measured) true vertical 11,802' feet Casing Length Size Cemented Measured depth Structural Conductor 615' 20" 985 sx 615' Surface 1969' 13-3/8" 1200 sx 1969' Intermediate 7859' 9-5/8" 1500 sx 7859' (KOP) Production 2729' 7" 1172 sx 10390' Liner 2193' 5" 378 sx 12411' Perforation depth: measured 10975'-11116'; 11672'-11855'; 11918'-12170'; 12212'-12265' True verticaldepth 615' 1966' 7814' 10215' 11930' true vertical 10757'-10882'; 11362'-11525'; 11511'-11763'; 11777'-11830' Tubing (size, grade, and measured depth) 3-1/2" L-80 0-7303' 3-1/2" L-80 0-7627' 2-7/8" L-80 7627'-9954' Packers and SSSV (type and measured depth) 7" '~V'rL" Packer @ 9954'; "RRO" SVLN @ 7560' 13. Attachments Description summary of proposal X Detailed operations program_ _ BOP sketch 14. Estimated date for commencing operation 115. 2/21/95 Pat Ryan 263-7864 16. If proposal was verbally approved Effective 2/17/95 - 2/24/95 2/17/95 Name of approver Blair Wondzell Date approved Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the fo~o~g ~ t~ f~~to the best of my knowledge. Signed G. Russell Schmidt ~ .~,~ ~ Title Drilling Manager FOR COMMISSION USE ONLY Date February21, 1995 Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test~ Subsequent form required 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Signed 8y David W. Johnston Approved Copy C ~t.n~. -2'~ S ~;tl~1, T~N~T R~I p~L~i.C~A TE ANNA PLATFORlVl WELL # 3RD GRANITE POINT (GP) COMPLETION DIAGRAM 20" 94//Casing ~ 615' 13-3/8" 54.5//Casing ~ 1969' Top of 7" Liner @ 7661' 9-5/8" 40/43.5/47//N80/S95 Casing ~ 7859' (KOP) COMPLETION DES CRIPTION 1) 3-1/2" 9.2# L-80 SCBT Long String 0 - 7627' 2) 3-1/2" 9.2# L-80 SCBT Short String 0 - 7303' 3) KOBE Cavity ~ 7303' 4) "RA" Nipple ~ 7364' 5) "RA" Nipple ~ 7494' 6) "RRO" SVLN ~ 7560' 7) 2-7/8" 6.4# L-80 BTC Tubing 7627' - 9954' 8) 7" HES "VTL" Packer ~ 9954' 9) "X" Nipple ~ 10035' 10) 3-3/8" TCP Guns 22gm ~ 6 jspf RKB = 127' 10 Top of 5" Liner@ 10218' 7" 29//L-80 BTC Liner @ 10390' Hernlock Perfs 10975'-11116' Hemlockeerfsl1672'-l1855' ~_~ ?_ 4 1995 Hemlock Perfs 11918'-12170' ,x~.a~ u~[ .& Gas Cons. Commission Anchora ° Hemlock Perfs 12212'-12265' 5" 18&15# L-80 BTC Liner ~ 12411' 21 February, 1995 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell: Unocal, as operator of the Anna Platform, request that the AOGCC grant a temporary waiver to produce GP 18742-3rd without a subsurface safety valve (SSSV). The well is currently shut-in due to a leaking packer, so total shut off of flow from the tubing-casing annulus not possible. Prior to being shut-in, the well was capable of flowing unassisted at approximately 60 BPD with a 40% water cut, and when assisted with a hydraulic pump, produced at 160 BPD, with a 40% water cut. Unocal would like to produce the well without the SSSV during the current drilling phase, to determine the economic viability of replacing the downhole packer. The operation of the SSSV has required several wireline runs which are difficult, and sometimes impossible, to perform while the drilling rig is on the platform. Completion of the drilling phase is scheduled for July/August, which should be enough time to properly evaluate the well. Background The GP 18742-3rd was completed as a Hemlock producer on January 17, 1995. A dual string KOBE completion with a wireline retrievable SSSV was run as it was anticipated that the well would initially flow at economic rates, but would have to be pump assisted as the reservoir pressure depleted. Unfortunately, the well initially flowed only 60 BPD (40% water-cut) and later produced at 160 BPD (40% water-cut) when assisted with a hydraulic pump. Due to the poor production rate, a downhole pressure build-up was performed. During the build-up, pressure was recorded at the surface from the tubing- casing annulus indicating the possibility of a packer leak. Further slickline work to confirm that the sliding sleeves in the tubing were closed, verifying that the surface pressure was due to a packer leak. The analysis of the build-up data resulted in a very tight (<lmd) formation with a reservoir pressure of 6,600 psi. RECEI /ED ~EE~ 2 4, '~995 ~ ~jtt & Gas Cons. Commission gnchora ,~ Justification The main reason to temporarily produce the well without downhole isolation is to determine if the well can economically support a workover to replace the packer. To date, the well has been produced sporadically due to operational problems associated with downhole hydraulic pumps with a SSSV. Due to the placement of the well on the platform (Leg 1), pulling of the SSSV is very difficult while the drilling rig is on the platform. The drilling will be located on Leg 1 throughout the current drilling phase as all of the wells will be drilled or redrilled from Leg 1. The removal of the SSSV during the evaluation period would allow for a more stable production period and would reduce the risk associated with the slickline runs that are required with SSSV operations. Unocal believes that GP 18742-3rd can be produced in a safe, prudent manner without downhole isolation. A combination of surface safety valves and the Iow productivity of the well will virtually eliminate the possibility of uncontrolled flow of fluid at the surface. The well is equipped with automatic surface safety valves with Hi-Low pressure shut-off. In addition, when the well is being pumped the tubing-casing annulus will be fluid free to approximately 7000' which will provide over 300 barrels of fill-up prior to flow at surface. Considering the initial flow rate of 60 BPD, it would take approximately 5 days to fill-up the annulus. If needed, the ability to mix and pump kill wait mud is also available during the drilling phase. If you need additional technical data please contact Tim Borgerding, reservoir engineer at (907) 263-7804 or Pat Kyan, drilling engineer at (907) 263-7864. Thank you for your assistance. Sincerely, G. Russel[ Schmidt Oil & Gas Gons. Commisff~on gnchora '~ Debra Childers Clerk Unocal Energy Resoun 'vision 909 West 9th, P.O. BOX ~, , t7 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL DATA TRANSMITTAL #7 I T o: Larry Grant · 300! Porcupine IAnchorage,, AK 99501 Alaska Oil & Gas IFrom: Debra Childers 909 W. 9th Avenue February 8, 1995 IAnchorage, AK Unocal 99519-6247 One blueline and sepia of the fo. JleW~g Granite Point 18742-3 RDc~"Aj3'ay Induction Imager 2" & 5" ?_ (_ ¢_.,? ~ . ~..-~-Borehole Compensated Sonic Log 2" & 5" ¢¥, CFr-, ,?~epeat Formation Tester ~;~rmation Microscanner -"l~ddge Plug Setting Record "~//~-~zi~muthal Resistivity Imager with Laterolog jthodensity Compensated Neutron ormation Mudlog RECEIVED Alaska Oil & Gas C~s. Corn~iSsl_o__rt. Anchorage Please acknowledg~ning and ~,uming one copy of this transmittal or FAX to (907) 263-7828. STATE OF ALASKA ALA~~-~ OILAND GAS CONSERVATION COMi~ ...... SION WELL COMPLET ...jN OR RECOMPLETION [,.,PORT AND LOG 1. Status of Well Class'ificafion of Service Well OIL I~ GAS [-] .SUSPENDED ~ ABANDONEI~ SERVICE F-] 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CAUFORNIA (UNOCAL) 94-149 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519 50-733-10085-01 4. Location of well at surface ..................... '~ .~ '" ~'~ ~'-~"~'~.' 9. Unit or Lease Name 729' FNL, 636' FEL, SEC. 12, TION, R12W, SM i ....... 'i ' ~;~ :~--~_%~'~ GRANITE POINT FIELD ANNA At Top Producing Interval ! J~/~;~.~)-~i ~; .,':~'-,E;.~.. ~-~,;c) ~. ~ 10. Well Number ......... .-~ ~ WELL #3RD 1565' FNL, 1837' FEL, SEC. 12, TION, R12W, SM );~i ~.___, . ~. At TotaJ Depth ._ ~ ......... .:~._~ · '-. ! 11 Field and Pool 2157' FNL, 2423' FEL, SEC. 12, TION, R12W, SM ~ .................... . ._ ........ ~z- GRANITE POINT FIELD 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 127'KB MSLI ADL 18742 12.411'/11.90o' 12.m7'/11.80~' l,~s [~ NO [~ 756O' ~oet ~D N/A 22. Typo Electri~ or Other I.o~ Run AIT/BHC/LDT/CNL/GR/SP/FMS/ARI/CET/CBT/RFT 23. CASING, ENER AND CEMENTING RECORD SIZE WT. PER FT. GRADE TOP I BOI'FOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED CASING 20' 94 O' 615' - - - 985 sx 0 13-3~8" 54.5 O' 1969' 17-1/2' 1200 sx 0 9-5/8' 40/43.5/47 N-80/*S95 O' 7859' (KOF) 12-1/4' 1500sx 0 7' 29# L-80 7661' 10,390' 8-1/2' 1172 sx 0 5' 15/18 L-80 10218' 12,411' 6' 3789x 0 . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforations: 6SPF/229M SIZE I DEPTH SET (MD) I PACKER SET (MD) 3-1~ 9.2# 0-7~03/0-7627 MD I'VD 2-7/8', 6.4# 7627'-9954' 9954 10975'- 11116' 10757'- 10882' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11672'-11855' 11362'-11525' DEPTH INTERVAL (MD) I AMOUNT& KIND OF MATERIAL USED 11918'- 12170' 11511 '-11763' NONE ~2212'-12269' 11777'-11~30' 27 PRODUCTION TEST Date First Production J Mefl~od of Operation (Flowing, gas lift, etc.) 1/16/95I Jet Pump Date of Test Hours Tested PRODUCTION FOF OIL-BBL GA~-MCF WATER-BBL CHOKE SIZE GAS-O~L RAllO 01/24/95 6 TEST PERIOD 28 18.8 19 2' 670 Flow Tubing Casing Pressure CALCULATED OIL- BBL GAS- MCF WATER- BBL OIL GRAVITY-APl (corO Press. 85 psi 100 psi 24-HOUR RATE 113 75.7 76 40 deg 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED FEB 1995 A_b,,si',a Oil & Gas Gores. ¢orr~rnissior~ ,a, nchor~ .-. Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVEFI~E SIDE 29. 30, GEOLOGIC MARKERS FORMATION TESTS ...... NAME interva~ te~ted, preesure data, all fluids recovered and gravity, .... MEAs. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Granite Pt. C-3 Sands 8126' 8072' RFT's: 4558, 4570 psig C-4 Sands 8155' 8100' RFT's: 3743, 2817 psig C- 5 Sands 8324' 8264' C-7 Sands 8725' 8647' C-8 Sands 9148' 9049' RFT: 4218' psig Hemlock 10844' 10633' West Foretand 11116' 10884' Jurassic 11274' 11026' Base Hemlock 11672' 1136~' 1% Top Hemlock 12292' 11842' Aia~i(,.~. Oii & GaS OOrlS, Oorrlmiss[o~l Anchor,'. ' ..........__ -- ,,__ 31. us'r oF A r^C.ME"TS 32. I hereby, cerl~fy that the foregqing is true and correct to the beSt of my knowledge Signed O. RUSSELLSCHMIDT TrUe DRILLING MANAGER Date 01126195 . . . 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'. ANNA PLATFORM WELL # 3RD GRANITE POINT (GP) COMPLETION DIAGRAM 2 3 4 5 6 L 20' 94# Casing (~ 615' 13-3/8" 54.5# Casing@ 1969' Top ofT' Liner @ 7661' 9-5/8" 40/43.5/47# N80/S95 Casing ~ 7859' (KOP) COMPLETION DESCRIPTION 1) 3-1/2" 9.2# L-80 SCBT Long String 0 - 7627' 2) 3-1/2" 9.2# L-80 SCBT Short String 0 - 7303' 3) KOBE Cavity, r~ , . ,3 7303 4) "RA" Nipple @ 7364' 5) "RA" Nipple (~ 7494' 6) "RRO" SVLN ~ 7560' 7) 2-7/8" 6.4# L-80 BTC Tubing 7627' - 9954' 7" HES "VTL" Packer ~ 9954' 9) "X' Nipple ~ 10035' 10) 3-3/8" TCP Guns 22gm ~ 6 jspf RKB -- 127' 10 Top of S" Liner ~ 10218' 7" 29# L-80 BTC Lin~ ~ 10390' Hemlock Perfs 12212'-12265' 5" 18&15# L-80 BTC Liner t~' 12411' DAY 1 - 5 ANNA 3 ABANDONMENT DAY 6-7 (12/06-07/94) 9-5/8" @ 10,577' 8.4 PPG (FIW) REM TREE & NU BOPE. POOH & LAY DN KILL STRING. ND BOPE & REPLACE DCB SPOOL. TEST BOPE. RU SCHLUM WL & RIH W/9-5/8" BP, GR/CCL. CORRELATE LOG & SET BP AT 7898'. POOH. MU WHIPSTOCK BHA#1. RIH. DAY 8-10 (12/09-11/94) 9-5/8~ @ 7859' KOP 9.2 PPG (FIW) ORIENT WHIPSTOCK 43 DEGREES LEFT OF HIGH SIDE AND SET WHIPSTOCK AT 7880'. MILLED WINDOW F/'7859'-7861'. POOH. MILL INDICATED THAT LUG WAS STILL INTACT. RIH W/STARTING MILL. MILLED WINDOW F/7861'-7863'. POOH. RIH W/WINDOW MILL ASSEMBLY. MILLED F/7863'-7873'. POOH. RIH W/PDC BIT ON DRESSING MILL ASSEMBLY. DRILLED F/7873'-7881'. DRESSED WINDOW F/7859'-7872'. WINDOW LOOKS GOOD. PERFORM LOT; EMW-14.1 PPG. POOH. RIH W/DRILLING ASSEMBLY. DRILLED 8- 1/2" HOLE F/7881'-8342'. DAY 11 (12/12/94) 9-5/8' @ 7859' KOP 9.2 PPG (FIW) DRILLED F/8342'-8963'. DAY 12 (12/13/94) 9-5/8" @ 7859' KOP 9.2 PPG (FIW) DRILLED F/8963'-9000'. POH F/BIT. RIH W/ROTARYASSBY. REAM F/8170'-9000'. DRILLED F/9000'-9169'. NOT ABLE TO HOLD ANGLE OR DIRECTION. POOH F/BHA. DAY 13 (12/14/94) 9-5/8" @ 7859' KOP 9.2 PPG (FIW) PU MOTOR & TIH. DRILLED F/9169'-9476'. DAY 14 (12/15/94) 9-5/8" ~__,, 7859' KOP 9.7 PPG (FIW) DRILLED F/9476'-9785'. TOH F/BIT. DAY 15-17 (12/16-18/94) 9-5/8" (~ 7859' KOP 10.6 PPG (FIW) RIH W/NEW BIT & BHA. DRILLED F/9785'-10,406'. RAISED MUD WEIGHT TO 10.6 PPG. SHORT TRIP, Oi( TOH FOR LOGS. RAN AIT- CNL-LDT-BHC-GR-AMS FROM 10394'-7859'. TOP CENTRALIZER SLID DOWN TOOL CAUSING FAULTY RESISTIVITY READINGS. RIH W/RFT. MADE 17 RFT SETS, LAYED DOWN RFT. RIH W/AlT TOOL AND LOGGED FROM 9480'-7859'. DAY 18 (12/19/94) 7" ¢___,, 10390' 10.6 PPG (FIW) RD LOGGERS. RU & RAN 7" F/7662'-10390'. CMT W/117~2SX CLASS _ "G" + .3% CFR-3 + .1% HR-5 + .2 GALJSX HALAD 344L (~ 15.8 PPG. DISP W/MUD. DID NOT BUMP PLUGS. SET LINER ON BOTTOM & RELEASED. SET LINER TOP PACKER. REVERSED OUT 105 BBL CMT. POH W/RUNNING TOOL. DAY 19 ( 1 2/20/94) 7"@ 10390' 10.5 PPG (FIW) CONT. POOH W/RUNNING TOOL, PULLING WET. LAYED DOWN EXCESS 5' DRILL PIPE & HEAVY WEIGHT. LAYED DOWN RUNNING TOOL WITH BOTH WIPER PLUGS STILL IN PLACE. TEST BOP. PU BHA 3-1/2" HEAVY WEIGHT & DRILL PIPE AND RIH. TAGGED TOL @ 7662'. CLEANED OUT CEMENT F/7662'-7678'. PRESSURE TESTED LINER LAP TO 3500 PSI, OK. RIH & DRILLED LANDING COLLAR @ 10250' & FLOAT COLLAR @ 10295' CONTINUE IN HOLE & TAGGED CEMENT @ 10,323'. PRESSURE TESTED CASING TO 3500 PSI, OK. DRILLED CMT F/10323'-10406' (ESTIMATED 3' OF NEW 6" HOLE). DAY 20 (12/21/94) 7"¢__. 10390' 11.9 PPG (FIW) DRILL STRING PLUGGED @ 10406'. PERFORM FIT DOWN ANNULUS; 17.1 PPG EMW W/10.5 PPG MUD IN HOLE. POH WET. MWD PARTED PLUGGING DRILL STRING. TIH. BRING MUD WT UP TO 11.3 PPG. DRILL TO 10416'. CONDUCT FIT; 17.1 PPG EMW WI11.3 PPG MUD IN HOLE. BRING MUD WT. UP WHILE DRILLING F/10416'-10491'. DAY 21-25 (12/22 - 26/94) 7"@ 10390' 12.9 PPG (FIW) DRILL F/10,491-597. POOH, LOST PART OF CONE. RIH WITH FISHING ASSEMBLY. CIRCULATE ON JUNK. POOH, ALL JUNK RECOVERED. RIH WITH BIT. DRILLED F/10597-667'. POOH FOR BIT. RIH WITH BIT & ROTARY ASSEMBLY. DRILL F/10667-767'. POOH F/BIT. RIH WITH BIT ON ROTARY ASSEMBLY. DRILL F/10767'-898'. DETECT ENTRY INTO WELLBORE. CIRCULATE OUT ENTRY & RAISE MUD WEIGHT FROM 12.1 PPG TO 12.7 PPG. DRILL F/10,898'-998'. POOH F/BIT. RIH W/BIT ON ROTARY ASSEMBLY. DRILLED F110998' - 11079'. 11,130'/51' DAY 26 (12/27/94) 7"@ 10390' 12.9 PPG (FlW) DRILL F/11079'-127'. POOH F/BIT. RIH W/MT BIT BOOT BASKETS. CIRC ON JUNK. POOH & RECOVERED SEVERAL INSERTS. RIH W/BIT & ROTARY ASSEMBLY. DAY 27 (12/28/94) 7"@ 10390' 13.0 PPG (FIW) RIH W/BIT. DRILLED Fl11,130'-11,274'. DAY 28 (12/29/94) 7" @ 10390' 12.9 PPG (FIW) DRILL Fl11,274'-11,283'. POH F/BIT. DRILL Fi11,283'-11,370'. R,E. CEIVCD Oas Cor~s, r_.;omrnissiol~ Anchor: ~ DAY 29-32 (12/30-01/02/94) 7"@ 10390' 12.9 PPG (FIW) DRILL F/11,370'-11,416'. POH F/MOTOR TO BUILD ANGLE AND TURN HOLE RIGHT. TIH W/MOTOR ASSMBY. DRILL F/11,416'-11,590'. POH F/BIT. TIH W/ROTARY ASSMBY. DRILL F/11,590'-11,805'. POH F/BIT. HOLE TIGHT @ 11,145' AND 10,725'. TIH W/ROTARY ASSMBY. REAM BRIDGE @ 11,316'. DRILL F/11,805'-12,008'. POH F/BIT. HOLE TIGHT @ 11,105', 10,787'-10,756'. HUNG UP @ 10,546', JARRED FREE IN 45 MINUTES. DAY 33 (01/03/94) 7"@ 10390' 12.9 PPG (FIW) CONT POH. LD MWD & PICK UP MONEL. DRILL COLLARS. TIH Wi6" ROTARY ASSBY. DRILL F/12008'-12137'. MAKE WIPER TRIP TO SHOE. TIGHT HOLE AT 10803', 10670' & 10590'. TIH. DRILL F/12137'-12145'. DAY 34 (01/04/95) 7"¢__. 10390' 12.9 PPG (FIW) DRILL F/12145'-12213'. POH F/BIT. PULLED TIGHT 10900'-10476'. RIH W/ROTARY ASSBY. DRILLED F/12213'-12265'. DAY 35 (0/05/95) 7' @ 10390' 12.9 PPG (FIW) DRILL F/12265'-12324'. POH F/BIT. BACK REAM F/10872'-10528'. STICKY SPOTS WOULD NOT CLEAN UP AFTER BACK REAMING. RIH W/BIT ON ROTARY ASSBY. DRILL F/12324'-12330'. R[CEIVEb i'-!::B ,', 9 ~' ._, · ~,~ ~ ..¥.:~,..~ & GaS u0liS. 001'rffrlissiofi Anchorr_ DaY 36-38 (01/06-08/95) 7"@ 10390' 12.9 PPG (FIW) DRILL F/12330' - 12411' (TD). SHORT TRIP TO SHOE, HOLE TIGHT IN SEVERAL PLACES. POH F/LOGS. RU SCHLUMBERGER. RAN AIT/BHC/CNL/LDT/GR/FT F/12,340'-10,390'. LOST 4 CENTRALIZERS OFF TOOL. RIH W/BIT TO PUSH CENTRALIZERS TO BOTTOM. POH. RAN FMS F/12,360'-10,770'. TOOL PULLED TIGHT @ 10770'. CLOSED ARMS & POH. RAN ARI F/11550'-10700'. RIH W/CLEANOUT ASSBY. POH, PULLED TIGHT IN SEVERAL SPOTS. RIH WI5" LINER AND HANGER ASSBY. DAY 39 (01/09/95) 5" ¢___, 12411' 12.9 PPG (FIW) CONT. RIH W/LINER. WASHED LINER TO 12,411'. ClRC AND COND. WELL F/CMT. CEMENT 5' LINER W/378 SX CLASS "G' CEMENT @ 15.8 PPG. BUMP PLUG TO 3600 PSI. TOL @ 10,218'. SET HANGER AND LINER TOP PACKER. REVERSE DRILL PIPE CLEAN, TRACE CEMENT TO SURFACE. POH. CHANGE RAMS AND TEST BOP & CHOKE MANIFOLD. DAY 40 (01/10/95) 5' @ 12411' 12.9 PPG (FIW) RIH Wi4-1/8" BIT PICKING UP 2~7/8' DRILL PIPE. TAG CMT ¢__. 12,099'. DRILLED CMT F/12099'-12327' (ETD). PRESSURE TEST CASING AND SHOE TO 3000 PSI Fl30 MINS, OK. DAY 41 (01/11/95) 5' ¢__, 12411' 13.0 PPG (FIW) POH. RU WIRELINE. RUN BOND LOGS F/12327' (ETD) - 7667' (7" TOL). RIH W/7" PACKER ON DRILL PIPE. TOP 5000' OF DRILL PIPE DRY. PSA 10150'. ACTUATE MULTI-SERVE VALVE WITH 900 PSI OF ANNULUR PRESSURE AND PERFORM DRAWDOWN TEST ON 5" LINER TOP. TESTED OK. REVERSE DRILL PIPE CLEAN AND POH. DAY 42 (01/12/95) 5"@12411' 13.0 PPG (FlW) RIH W/9-5/8" PACKER PU 3-1/2' TUBING. TOP 4000' OF PIPE DRY. PSA 7510'. ACTUATE MULIT-SERVlCE VALVE W/1150 PSI OF ANNULAR PRESSURE AND PERFORM DRAWDOWN TEST ON 7" LINER TOP. TESTED OK. REVERSE PIPE CLEAN AND POH. RIH W/4-1/8" MILL. PU 2-7/8" AND 3-1/2" TUBING AS NECESSARY FOR COMPLETION. DAY 43-45 (01/13-15/95) 5" @ 12411' 8.5 PPG (FIW) FINISH IN HOLE W/TUBING. DISPLACE HOLE TO WATER SPOTTING 3% KCL ON BOTTOM. PUH. RIH W/TCP GUNS AND "VTL' PACKER ON DRILL PIPE. TAG BOTTOM, POH AND POSITION GUNS TO PERFORATE HEMLOCK @ 10975'-11116', 11672'-11855', 11918'- 12170', AND 12212'-12265' WITH 6 SPF. DROP BALL AND SET AND TEST PACKER @ 9955'. POH. RIH W/KOBE. ASSEMBLY AND DUAL 3-1/2" TUBING STRINGS. STAB INTO PACKER AND PRESSURE ANNULUS TO 2500 PSI, OK. SPACE OUT AND LAND TUBING. SET BPV~S AND ND BOP. NU AND TEST TREE AND PRODUCTION LINES. REMOVE BPV'S AND SHIFT "RA" SLEEVE OPEN. CIRCULATED POWER OIL DOWN ANNULUS TO "RA' SLEEVE @ 7363'. CLOSE "RA" SLEEVE. PRESSURE ANNULUS TO 2000 PSI AND DETONATE GUNS. WELLHEAD PRESSURE BUILT TO 760 PSI IN 15 MIN. OPEN WELL TO TEST SEPARATOR @ 2100 HRS 1/15/95. DAY 46 (01/16/95) 5" @ 12411' 8.5 PPG (FIW) WELL FLOWING @ 4-6 BPH. ClRC BOTH STRINGS W/POWER OIL. NO INCREASE IN FLOW RATE. RU SLICKLINE. RIH AND SHIFT "RRO" SLEEVE OPEN. RIH W/SSSV. COULD NOT PASS KOBE. REDRESS SSSV & RIH. HAD TO WORK THRU KOBE AND "RA' SLEEVE. SET SSSV IN "RRO" NIPPLE. SEAT DUMMY STANDING VALVE AND PUMP JET PUMP IN PLACE. RELEASE RIG TO ANNA #50 @ 2400 HRS. UNOCAL ANNA Platform 3 Rd~l slot #1-6 Granite Point Field Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PGMS <0 - 7800'> Your ref : PMSS <7859 - 12411'> Our ref : svy4529 License : Date printed : 25-Jan-95 Date created : 12-Dec-94 Last revised : 8-Jan-95 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 58 44.738,w151 18 33.113 Slot location is n60 58 37.510,w151 18 46.082 Slot Grid coordinates are N 2551408.201, E 266811.833 Slot local coordinates are 734.00 S 640.00 W Reference North is True North UNOCAL ANNA Platform,3 Rd#1 Granite Point Field,Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <7859 - 12411'> Last revised : 8-Jan-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 W 0.00 0.00 100.00 0.17 260.08 100.00 0.02 $ 0.14 W 0.17 0.13 200.00 0.45 240.58 200.00 0.24 S 0.63 ~ 0.30 0.65 300.00 0.47 205.95 300.00 0.80 S 1.15 ~ 0.27 1.40 400.00 0.33 261.97 399.99 1.21 S 1.62 ~ 0.39 2.02 500.00 0.37 219.37 499.99 1.50 $ 2.11 ~ 0.26 2.58 600.00 0.65 263.58 599.99 1.81 S 2.87 W 0.46 3.39 700.00 1.57 265.17 699.97 1.99 S 4.80 ~ 0.92 5.05 800.00 3.10 263.55 799.88 2.40 S 8.85 W 1.53 8.58 900.00 3.45 258.18 899.72 3.32 S 14.48 W 0.46 13.69 1000.00 3.52 258.22 999.53 4.57 $ 20.43 ~ 0.07 19.24 1100.00 3.62 259.75 1099.34 5.76 S 26.53 W 0.14 24.89 1200.00 3.60 257.55 1199.14 6.99 S 32.70 ~ 0.14 30.62 1300.00 3.70 259.97 1298.94 8.23 S 38.94 ~ 0.18 36.41 1400.00 3.85 258.37 1398.72 9.47 S 45.41 ~ 0.18 42.38 1500.00 4.00 261.40 1498.49 10.67 S 52.15 ~ 0.26 48.55 1600.00 4.17 261.68 1598.23 11.72 S 59.19 W 0.17 54.88 1700.00 4.28 262.95 1697.96 12.70 S 66.49 ~ 0.15 61.38 1800.00 4.32 263.57 1797.68 13.58 S 73.94 ~ 0.06 67.94 1900.00 4.32 264.42 1897.40 14.37 $ 81.42 ~ 0.06 74.47 2000.00 4.42 262.45 1997.11 15.24 S 88.99 W 0.18 81.12 2100.00 4.38 264.92 2096.81 16.08 $ 96.61 W 0.19 87.80 2200.00 4.40 263.73 2196.52 16.84 S 104.23 ~ 0.09 94.42 2300.00 4.47 266.32 2296.22 17.51 S 111.93 W 0.21 101.06 2400.00 4.58 266.77 2395.91 17.99 $ 119.80 ~ 0.12 107.73 2500.00 4.62 264.17 2495.58 18.62 S 127.80 ~ 0.21 114.59 2600.00 4.67 265.45 2595.26 19.35 S 135.85 W 0.12 121.55 2700.00 4.48 266.47 2694.94 19.92 $ 143.81 ~ 0.20 128.34 2800.00 4.37 266.00 2794.64 20.42 S 151.51 ~ 0.12 134.88 2900.00 4.18 266.23 2894.36 20.93 S 158.95 ~ 0.18 141.21 3000.00 4.10 264.17 2994.10 21.53 S 166.14 W 0.17 147.40 3100.00 4.07 265.68 3093.85 22.16 S 173.23 W 0.11 153.53 3200.00 4.12 266.28 3193.59 22.66 S 180.35 ~ 0.06 159.60 3300.00 4.23 266.03 3293.33 23.15 S 187.62 W 0.12 165.78 3400.00 4.40 266.10 3393.04 23.66 S 195.12 W 0.17 172.17 3500.00 4.42 266.15 3492.75 24.18 S 202.79 ~ 0.02 178.70 3600.00 4.58 265.27 3592.44 24.77 $ 210.62 g 0.18 185.39 3700.00 4.53 266.25 3692.12 25.36 S 218.54 W 0.09 192.16 3800.00 4.43 266.03 3791.82 25.89 S 226.34 ~ 0.10 198.80 3900.00 4.40 265.97 3891.52 26.42 S 234.02 W 0.03 205.35 4000.00 4.50 265.85 3991.22 26.98 S 241.76 ~ 0.10 211.95 4100.00 4.42 266.27 4090.92 27.51 S 249.52 ~ 0.09 218.56 4200.00 4.55 267.65 4190.61 27.92 S 257.32 W 0.17 225.13 4300.00 4.58 270.00 4290.29 28.09 S 265.28 ~ 0.19 231.69 4400.00 4.70 270.13 4389.96 28.08 S 273.37 W 0.12 238.25 4500.00 4.67 271.32 4489.63 27.98 S 281.54 W 0.10 244.81 4600.00 4.83 270.82 4589.29 27.82 S 289.82 W 0.17 251.44 4700.00 4.65 272.80 4688.94 27.56 $ 298.08 ~ 0.24 258.00 4800.00 4.68 273.15 4788.61 27.14 S 306.20 ~ 0.04 264.34 4900.00 4.82 271.52 4888.27 26.81 S 314.48 ~ 0.19 270.86 All data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from RKB (127.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 234.24 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Platform,3 Rd~l Granite Point Field,Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <7859 - 12411'> Last revised : 8-Jan-95 Measured [nc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 5000.00 5.00 270.20 4987.90 26.68 S 323.03 W 0.22 277.73 5100.00 5.05 268.00 5087.52 26.82 S 331.79 W 0.20 284.91 5200.00 5.27 269.23 5187.11 27.03 S 340.78 ~ 0.24 292.33 5300.00 5.43 268.85 5286.68 27.19 S 350.10 ~ 0.17 299.99 5400.00 5.48 267.58 5386.22 27.49 S 359.60 ~ 0.13 307.88 5500.00 5.57 266.13 5485.76 28.01 S 369.22 ~ 0.16 315.99 5600.00 6.03 266.35 5585.25 28.68 S 379.30 W 0.47 324.56 5700.00 6.38 267.52 5684.66 29.25 S 390.10 ~ 0.37 333.66 5800.00 7.03 268.52 5783.98 29.65 S 401.7-/ ~ 0.66 343.36 5900.00 7.62 269.18 5883.16 29.90 S 414.52 g 0.59 353.86 6000.00 8.13 269.60 5982.22 30.05 S 428.22 ~ 0.52 365.06 6100.00 8.83 270.50 6081.12 30.03 S 442.97 W 0.71 377.02 6200.00 9.72 270.80 6179.81 29.84 S 459.09 W 0.88 389.9<2 6300.00 9.97 271.33 6278.34 29.53 S 476.18 W 0.27 403.67 6400.00 10.38 271.10 6376.77 29.15 S 493.84 ~ 0.42 417.78 6500.00 10.80 270.55 6475.06 28.89 S 512.22 ~ 0.43 432.54 6600.00 10.77 270.43 6573.30 28.73 S 530.93 ~ 0.04 447.63 6700.00 10.45 270.68 6671.59 28.55 S 549.34 ~ 0.32 462.46 6800.00 9.92 270.53 6770.02 28.36 S 567.02 ~ 0.53 476.70 6900.00 9.88 270.27 6868.52 28.24 S 584.21 ~ 0.06 490.58 7000.00 9.47 268.40 6967.10 28.43 S 601.01 ~ 0.52 504.33 7100.00 8.72 268.17 7065.85 28.90 S 616.80 ~ 0.75 517.42 7200.00 8.90 268.45 7164.67 29.35 S 632.11 W 0.19 530.11 7300.00 9.63 271.68 7263.36 29.32 S 648.21 W 0.90 543.15 7400.00 10.05 273.37 7361.89 28.56 S 665.28 ~ 0.51 556.56 7500.00 10.22 274.30 7460.33 27.38 S 682.84 ~ 0.23 570.12 7600.00 10.03 273.82 7558.77 26.14 S 700.37 ~ 0.20 583.62 7700.00 10.35 273.48 7657.20 25.01 S 718.03 ~ 0.32 597.29 7800.00 10.58 273.62 7755.53 23.89 S 736.16 ~ 0.23 611.35 7859.00 10.75 274.12 7813.51 23.15 S 747.06 W 0.32 619.76 7963.00 14.50 265.40 7914.99 ' 23.50 S 769.72 ~ 4.04 638.35 8056.00 15.20 252.40 8004.91 28.12 S 792.95 ~ 3.65 659.90 8149.00 15.10 247.00 8094.68 36.54 S 815.72 ~ 1.52 683.30 8243.00 14.60 235.10 8185.56 48.10 S 836.72 W 3.28 707.10 8338.00 14.90 222.70 8277.45 63.93 S 854.82 ~ 3.33 731.04 8433.00 16.10 212.60 8369.01 84.01 S 870.21 ~ 3.10 755.26 8527.00 17.80 207.50 8458.93 107.74 S 883.86 ~ 2.40 780.21 8621.00 19.00 211.30 8548.13 133.56 S 898.45 ~ 1.80 807.13 8715.00 18.20 212.20 8637.22 159.06 S 914.22 W 0.90 834.83 8809.00 18.30 206.00 8726.50 184.74 S 928.52 g 2.07 861.44 8903.00 18.00 201.90 8815.82 211.49 S 940.40 ~ 1.40 886.71 8960.00 18.30 201.60 8869.99 227.98 S 946.98 W 0.55 901.69 8995.00 18.20 201.70 8903.23 238.16 S 951.02 ~ 0.30 910.92 9089.00 17.20 206.00 8992.78 264.30 S 962.55 W 1.75 935.54 9184.00 16.80 209.50 9083.63 288.87 S 975.46 ~ 1.16 960.39 927-/.00 17.80 206.40 9172.42 313.30 S 988.40 ~ 1.46 985.16 9371.00 18.50 207.40 9261.75 339.41 S 1001.66 ~ 0.82 1011.18 9465.00 18.90 207.10 9350.78 366.21 S 1015.45 ~ 0.44 1038.03 9559.00 19.20 201.20 9439.64 394.17 S 1027.98 ~ 2.07 1064.54 9653.00 19.50 200.30 9528.34 423.30 S 1039.01 ~ 0.45 1090.51 Ali data is in feet un[ess otherwise stated Coordinates from slot #1-6 and TVD from RKB (127.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 234.24 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the mini~ curvature method. Presented by Baker Hughes [NTEQ UNOCAL ANNA Platform,3 Rc~l Granite Point Field,Cook Inlet, Alaska SURVEY LISTING Page 3 Your ref : PMSS <7859 - 12411'> Last revised : 8-Jan-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 9745,00 19.20 202.60 9615,14 451.67 S 1050.15 W 0.89 1116.13 9838.00 20.00 202.70 9702.75 480.46 S 1062.17 W 0.86 1142.70 9932.00 20.30 195.90 9791.01 510.97 S 1072.84 ~ 2.51 1169.20 10026.00 20.90 198.70 9879.00 542.54 S 1082.68 ~ 1.23 1195.63 10119.00 21.40 195.30 9965,74 574.62 S 1092.48 W 1.42 1222.32 10213.00 22.10 196.60 10053,05 608,10 S 1102.06 ~ 0.90 1249.66 10306.00 23.00 200.50 10138.94 641.89 S 1113.42 W 1.88 1278.63 10355.00 23.70 202.60 10183.93 659.95 S 1120.56 ~ 2.22 1294.97 10394.00 24.10 202.60 10219,58 674.54 S 1126.63 ~ 1.02 1308.42 10487.00 23.80 208.70 10304,59 708.53 S 1142.94 ~ 2.68 1341.52 10545.00 23.40 203.60 10357.74 729.35 S 1153.17 W 3.59 1362.00 10581.00 23.40 200.70 10390,78 742.59 S 1158.56 W 3.20 1374.10 10762.00 22.70 204.70 10557,34 807.95 S 1185.86 ~ 0.95 1434.45 10859.00 22.50 205.20 10646,90 841.74 S 1201.58 ~ 0.28 1466.96 10948.00 21.30 206.30 10729,47 871.65 S 1216.00 W 1.42 1496.13 11074.00 24.20 205.70 10845,66 915.44 S 1237.34 ~ 2.31 1539.04 11139.00 24.30 205.60 10904,92 939.51 S 1248.90 W 0.17 1562.48 11233.00 27.30 203.70 10989,54 976.70 S 1265.92 ~ 3.31 1598.03 11327.00 28.20 206.40 11072.73 1016.33 S 1284.46 ~ 1.64 1636.24 11368.00 28.00 206.40 11108.90 1033.63 S 1293.05 ~ 0.49 1653.32 11417.00 28.50 205.80 11152.06 1054.46 S 1303.25 ~ 1.17 1673.76 11511.00 31.70 223.40 11233,54 1092.68 S 1330.04 W 9.95 1717.84 11606.00 34.90 229.10 11312,95 1128.62 S 1367.75 W 4.71 1769.45 11700.00 36.20 230.00 11389.43 1164.08 S 1409.34 W 1.49 1823.92 11798.00 37.70 230.60 11467.74 1201.70 S 1454.67 W 1.57 1882.68 12131.00 41.75 237.00 11723,92 1326.82 S 1626.48 ~ 1.73 12239.00 42.75 238.00 11803,86 1365.83 S 1687.72 W 1.12 12411.00 42.75 238.00 11930.16 1427.70 S 1786.73 W 0.00 2095.22 Mag Single Shot 2167.71 Mag Single Shot 2284.21 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from RKB (127.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 234.24 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimc~n curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Platform,3 Rd#1 Granite Point Field,Cook [Met, Alaska SURVEY LISTING Page 4 Your ref : PMSS <7859 - 12411'> Last revised : 8-Jan-95 Comments in wellpath MD TVD Rectangular Coords. Comment 12131.00 11723,92 1326.82 S 1626.48 ~ Mag Single Shot 12239.00 11803.86 1365.83 S 1687.72 ~ Hag Single Shot 12411.00 11930.16 1427.70 S 1786.73 ~ Projected Data - NO SURVEY Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 3Rd Tgt#1 Revised 265700.000,2550820.000,0.0000105T'/.00 610.32S 1099.90W 27-Jun-94 3Rd Tgt#2 Revised 265215.000,2549955.000,0.000012127.00 1484.87S 1567.54W 5-Jul-94 All data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from RK8 (127.00 Ft above mean sea level). Bottom hole distance is 2287,08 on azimuth 231.37 degrees from wellhead, Vertical section is from wellhead on azimuth 234.24 degrees, Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ 1 I- 13RD J..... _. GOR(Mscr/bbls) .............................................................................................................................................................................................................. ~.., , Gas Rate (.CD)(Msof) ..................... ~ ............................................................................................ ~ ............................................................................................ , ~.~ ........................................................................................... !. .......... ~ .............................................. ~ ....... :...i .......... , ...................... ~ ................................................. -~.. --.::: .... Water Rate (CD) ( bbls) :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: _L. _. 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"~'-,~?*"~ ~ , , ..........................: I 92 I 93 I 94 I GRANITE POINT - HEMLOCK UNDEFINED OIL POOL 3~ Producing Wells () 10000 .~:::: I Oil R~te (CD) (bbls) i::i::i ::::i::!!:: :::: :: !i::i:: i :: :: :::: ::i i:: :: ::i ::i i:: i!i:: :: i :: :::::::::: :::::::: i:: :: :::::::::: :::::: ::::::i:: :::: !:::: :::::::: ~:.. -::: ....Water Rate (CD) (bbls) ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ." .....GOR(scf/bbls) ..................... :: ....................................................................................................................................................................................... 4.., ,,Cas Ra~ ¢D2( U~~...~ ............ ;...; ......... ; ........................................... ~ ........................................ ~...¢~¢ ............. 5 ...................... ...... .... ................ ................ ........ ................. 1000 ~ .................................................... ~ ~ ~}}~:.:.:.~ ~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......... ............................................................................................ ~ ........................................................................................... ~ ........................................................................................... ~ ........................................................................................... ? ........................................................................................... ~ ............................................................................................ ............................................................................................ : ............................................................................................ 2' ........................................................................................... ) ........................................................................................... : ~ ........................................................................................... ) ........................................................................................... :, ........................................................................................... : q ........................................................................................... :. ........................................................................................... ~ ........................................................................................... ~ ........................................................................................... ~ ............................................................................ ~..~ .......... ~ ........... ~............~..~ ........ ;..~ ................................................. d ........................................................................................... ~ ...................................................................... . .................... ~ ............................................................................................ : : i i : i : '=~u~ ............................................................................. , ......... ~..~ ......... , ............................................................................... ~. ............................................................................................ ~:::::::::::::::::::::::::::::::::~:$"::::: ~ ............................... · ................. ~ ...................... , .................. ~ ...... · .......... ,..~ · ................... , .................... ~ ......................... ~ ........................................................................................... : ~ ............................ i .................................... ~ ........................... i ..................................................................................................................................................................................... ~ ................... ~ ............................................................................................................................................................................................................................................................... : : " ..... ~ ...... ~ ....... ~ ...... * ...... 1 .............. [ r ...... a ....... r ...... * ...... 1 ............. * ...... a ....... ~ ....... r~ ...... ~ ....... [ ....... I ....... ~ ....... ~ ....... ~ ....... ~ ............. ~ ....... ~ ....... r ...... ~ ....... ~ ............. [ ~ ....... i ....... r ...... a ....... ~ ....... I 92 I 93 I 94 I ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCilORA, GE, ALASKA 99501-3192 PtlONE: (907)279-1435 TELECOPY: (907)27~-7542 November 30, 1994 G. Russell Schmidt Drilling Manager Union Oil Company of California (UNOCAL) P O Box 196247 Anchorage, AK 99519 Re: Granite Pt Field 3RD UNOCAL Permit No. 94-149 Sur. Loc. 729'FNL, 636'FEL, Sec. 12, T10N, R12W, SM Btmnhole Loc. 2221'FNL, 2242'FEL, Sec. 12, T10N, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Sincerely, Commi s s ioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .r'~A 1~, ¢JU If..UO R£C£ Vr D Alaska Oil & ~a~ bon~. 0om~'~'uu Unocal North Amerloan 011 & Gas Div~ion Unocal Oorporalion P,O, Box 190247 Anchorage, Alask~a. 99519-0247 Telephone (907) ~76-7600 UNOCAL November 29, 1994 00~ I ~ UF--/ Alaska Region Mr. David Johnston Commissioner Alaska Oil & Gas Conservation Commission 300t Porcupine Ddve Anchorage, AK 99501-3192 Dear Mr. Johnston: .PERMIT.TO.DP~LL:. ANNA__WELL ~I~3RD In reference to our amended application for Permit to Drill (For'm.10-401) for the Anna Platform well #3RD and our phone conversation with Blalr Wondzell, on November 23rd, regarding UNOCAL's proposed BOPE rating and the calculation of maximum allowable surface pressure. UNOCAL would like to submit the following to support our proposed plan and address the issues that Mr. Wondzell raised in our phone conversation, The Hemlock reservoir at Granite Point Field, although undefined, has been drilled and completed in five wells by both UNOCAL and Amoco. The f'rve wells drilled are GP 11-13RD; GP 50; MUC! 1; and Anna 3 & 9. UNOCAL recently completed GP wells 11-13RD and 50 in 1992, which offer the best available data to date. The Hemlock reservoir is characterized in these wells as a Daturally over-pressured fractured conglomerate sand. From PVT data the reservoir pressure has been recorded at various time intervals with results of 5500-7400 psi; the crude oil has an APl gravity of 40-42 degrees with a specific gravRy or 0.815; the bubble point is estimated at 2300 psi. During the production of GP 11-13RD and 50, the Initial maximum flowing wellhead pressures reported were 2600 psi and 1200 psi, respectively. The maximum shut-in tubing pressures on GP 11-13RD was 3800 psi. These two wells were drilled and completed with $000 psi working pressure rated wellhead and BOPE.' In reference to the calculation of Maximum Surface Pressure, Unocal's original submittal was based on a hypothetical gas 'kick' of 100 bbls. In this scenario the gas bubble is I~'ought to the depth of the last casing shoe, which results in the maximum BHP exerted at that point, The intent of the design is to check that the BHP does not exceed the fracture pre. ute at the casing shoe. This design is conservative for this case since a *kick' o1' !00 bbls is extremely unlikely, considering the detection equipment, training and guidelines tha~ the rig crews work with; historically "kicks' have usually been caught (in Unocal operations that I am famlltar with) with volumes of 10-20 bbls and most commonly less. Additionally, the Granite Point Field, as noted above, is an oil field with a BHP well ~bove the bubble point. -I'here is no gas cap in the field and there is no evidence to suggest that a pure gas "kick' could be encountered. An attemate design approach was discussed with Mr. Wonzeil, and is attached, in which MSP has been calculated for the case of a weli kick situation in which the wellbote is completely evacuated by Hemlock crude oi!. It is most likely that the wellbore would always contain some mixture of drilling fluid and crude for a ~se such as this, however, the extreme case ol~ oil to suvaco was reviewed to determine the maximum surface pressure. Please note the calculated MSP at 3966 psi, compared to the measure SITP of 3600 psi, ~ot well GP 11-13 UNOCAL believes this scenario to be extreme and offers it mainly as a check of the well design. UNUUML - Letter to Mr, David Johnston November 29, 1994 Page 2 .OV 29 Anchorage For the case of an hypothetical well designed to penetrate these obje~lves and expe~ed to encounter gas, a different wail design would be suggested, With knowledge of the gas properties the maximum surface pressure would be calculated and the well equipment sized to provide appropriate working pressure ratings. For the case of a well designed as an oil well which unexpectedly encountered gas under the stated depths and pressures, a well control problem would exist. Situation specific ccnditions would have to be evaluated to determine the most applicable course of action. The well would most likely be controlled by making all efforts to ensure that it was filled with fluid (even sea water); this would act to decrease the surface pressures and keep the well control within the rated working pressures of the surface equipment. With casing points similar to those for Anna #,3RD casing shoe integrity should not be a problem and the well could be shut in within the rate working pressure of the surface equipment as long as the total gas volume in the wellbore was not excessive. (Note that a gas influx of 100 bbls produces a maximum surface pressure of 3966 psi; MSP's in excess of 5000 psi would result from oorre;~pondingly higher influx volumes). It is also possible that the well could be diverted through the production facilities and/or the BOPE vent to reduce surface pressures to below the working pressure of the surface equipment until a dynamic kill procedure could be performed, similar to the procedure used recently at Endicott. This approach is not as appropriate for a well similar to Anna #3rd since 1) exceeding casing seat fracture pressure is not a problem; 2) the implied venting of large amounts of gas through the platforms systems creates a large risk to personnel on the facility and 3) there is not reel need for this well design to allow the well to ~ow gas to surface before starting measures to control ~. Alternately, a conventional well kill could be performed with the understanding that surface pressures could exceed the working pressure rating of the surface equipment. Surface equipment is tested to 50% beyond the rated working pressure when it is new and technically woulg have this capability; age and condition o1' the equipment and the rating of the casing strin§(s) Involved would also influence the actual capability of the well to perform a conventional kill. tt is most likely that a welt designed similar to Anna 3rd would have su[ficlent casing shoe integrity to allow pumping of fluids into the well and/or shut-in o1' the well before the wellbore had been completely evacuated by gas. in summary we feel that the design case based on the unlikely event of experiencing a 100 bbl gas kick is a conservative approach to the design of oil well Anna #3RD. The design check of evaluating the well with a column of Hemlock reservoir fluid to surface confirms this design, If you should have any questions regarding these permits please contact myself or Dan Williamson to discuss this matter luther. Thank you for your attention to these matters. (3. Russell $chmidt Drilling Manager GRS/leg f. Unocal North America Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region November 14, 1994 Mr. David Johnston Commissioner Alaska Oil & Gas Conservation Commissioner 3001 Porcupine Drive Anchorage, AK. 99501-3192 Dear Mr. Johnston: Please fred enclosed the "amended" application for a Permit to Drill (Form 10-401) for the Anna Platform well #3RD. The initial permit was submitted with UNOCAL letterhead dated September 13, 1994. UNOCAL has elected to change the proposed hole size and casing program. The initial hole to be drilled was 8-1/2" with a 7" liner from the kickoff point to total depth. The amended proposal is for 8-1/2" hole and 7 liner from the kickoff point to a interval just above the Hemlock, followed with a 6" hole and 5" liner to total depth. The timing to spud this well is approximately late November upon the completion of the ongoing Anna 11 redrill. UNOCAL requests that the following items be substituted for the appropriate items in the original permit; · Form 10-401 · Proposed Drilling Program · Maximum Surface Pressure Calculations · Schematic (existing plug & abandonment as of 10-13-94) · Proposed completion schematic If you should have any questions regarding these permits please contact C. Lee Lohoefer (Senior Drilling Engineer at 263-7642) assigned to this project. Thank you for your attention to these matters. Sincerely, G. Russell Schmidt Drilling Manager CLL/cll enclosure: Filename:AOGCCkAnna31tr. doc RECEIVED NOV '1 8 1994. Oit & Gas Cons. Commission ~-' STATE OF ALASKA _ ALASKA 'AND GAS CONSERVATION COl~' 'SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill ~ 1 lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry r-] Deepen []I Service I-I Development Gas [-I Single Zone[-I Multiple Zone 2. Name cf Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company cf California (UNOCAL) 127 KB, MSL feet Granite Point Field/Hemlock 3. Address 6. Property Designation P.O. Box 196247, Anchorage, AK 99519 ADL 18742 4. Location cf well at su'face Leg 1, Slot 6, GP Platform Anna 7. Unit or property name 11. Type Bond cs-= 729' FNL, 636' FEL, Sec. 12, TION, R12W, SM Granite Pt Field /~/J~/~ AK Statewide Oil & Gas Bond At top cf productive interval 8. Well number Number 1643' FNL, 1908' FEI_, Sec 12, TION, R12W, SM 3RD U62-9269 At total depth 9. Approximate spud date Amount 2.221' FNL, 2242' FEL, Sec. 12, T10N, R12W, SM November 28, 1994 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth ~ ..d Tm) property line 3372 feet 4' cf surface feet 5060 12,500'/12~128' feet 16. To be completed for deviated wells 17. Anticipated Pressure(s=, ~o AAC 25.035 (~) Kickoff depth 7900' feet Maximum holeangle 23 Ma~r, umsurf, ce 213 pslg At total depth l['rvD) 6994' 18. Casing program Settinq Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 13-3/8" 54.5 1969 0 0 1969 Existing Csg (1200 sx) 9-5/8" 40,43.5,47 ~180,S~5 BTC 10577 0 0 10577 10494 Existing Csg (1500 sx)\ 8-1/2" 7" 29 LSO BTC 2800 7700 7660 10500 10288' 620 sx 6" 5" 15 L80 BTC 2200 10300' 10086 12500 12128 230 sx 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured 13,114' feet Plugs (measured) 12150' Retainer true vertical 13,022' feet 11800' Retainer 11700' Retainer Effective depth: measured 9059' feet Junk (measured) 9070' Bridge plug w/3.5 sx cmt on top true vertical 8993' feet 9059'-8600' Abandonment Plug (cement) 8600'-8050' Abandonmnet Plug (cement) Casing Length Size Cemented Measured depth True vertical depth Structu'al SurfaceC°nduct°r 615' 20" 983sx 615'D ~ C~I'V ~E g Intermediate 10577' 9-5/8" 1500 sx 10577' Production ~ 0 V Liner 2821' 7" 650 sx 10280'- 13101' Perforation depth: measured Ai~.sk~ Oil & Gas Cons. C0mn See attached table Anch0rc.. true vertical 20. Attachments Filing fee ~: Property plat ~ BOP Sketch[~ Diverter Sketch [~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21.1 hereby certify that the foregoing i~)}r~ an/~o~r~best of my knowledge Signed G. RUSSELL SCHMIDT/~./~I~itle DRILUNG MANAGER Date 11/14/94 Commission Use Only Permit Number J API number Approval date .... J See cover letter ?~'-/'~.? 15o- ?.¢,.~-/r_,,~':-,,~ / //-".~' a" ~;Ifor other requirements Conditions of approval Samples required E] Yes-~ No Mud Iog required E] Yes J~ No Hydrogen sulfide measures ~ Yes ~' No Directional survey required ,~ Yes E] No Required workingpressureforBOPE E] 2M; E] 3M; E] 5M; E] 10M; E] 15M Other: ORIGINAL SIGNED BY by the order of Approved by RUSSELL A. DOUGLASS Commissioner the commission Date /~/-'-~'~ ",, ssi0n Form 10-401 Rev. 12-1-85 Submit in triplicate Procedure ANNA 3 RD, Option 3 (Whipstock, 8-1/2" & 6" holes) TimeEst. Cum Time Preliminary Procedure: 0.5 0.5 0.5 1 0.5 1.5 0.5 2 0.75 2.75 0.25 3 0.25 3.25 O.75 4 1 5 0 5 0.75 5.75 7 12.75 1 13.75 1 14.75 1 15.75 13 28.75 2 3O.75 1 31.75 1.5 33.25 1 34.25 2 36.25 1 37.25 1 38.25 O.5 38.75 0.5 39.25 1. Skid R428 to, Leg #1, Conductor #6 2. Set BPV. Nipple down tree. Nipple up 13 5/8" 5000# BOP's. 3. POOH, with 3-1/2" kill string. 4. Remove DCB spool, replace with new spool, NU BOPE & test same. 5. MU whipstock, starting mill and MWD BHA, RIH with same to 7900'. 6. Orient whipstock, set bottom trip system, shear bolt. 7. Mill 3-5' with starter mill. 8. POOH with starter mill assy,. RIH with window mill BHA. 9. Mill Whipstock window as required. 10. RIH, mill/dress window as required. 11. Drill 8-1/2" hole from 7900'-10500' (Top Hemlock). ROP=375' 12. Run open hole logs as required. 13. RIH, CCH for 7" liner 14. Run & cement 7" liner from 7700'-10500'. 15. Drill 6" hole from 10500'-12500'. ROP=150' 16. Run open hole logs as required. 17. RIH, CCH for 5" liner 18. Run & cement 5" liner from 12500'-10300'. 19. Clean out inside 5" liner, change well over to 3% KCL. 20. Run CET/GR log from ETD to TOC in both 5" & 7" liners. 21. Make up TCP guns / packer assy, RIH and set same. 22. RIH w/Kobe BHA and dual 3-1/2" tbg completion.. 23. Set BPV. Nipple down BOP's. Install wellhead. 24. Release rig & turn well over to production. Note: Mud weight required in the Tyonek 9.2 - 9.6 ppg, and in the Hemlock is 13 -13.5 ppg. Additionally, the Kobe BHA (3" pump) will be set in the 9-5/8" csg above the 7" liner. Revised November 09,1994 REC£[VED - '0£'~ NOV OJJ & Oas Cons. Commission 3PROCED.XLS Page 1 Anna Platform Well # 3 Redrill Granite Point Field 14-Nov-94 Hole Section Depth Interval: 7900'-10500' 8-1/2" hole size 7" casing from 7700' to 10500' Maximum Surface Pressure Calculation; Mud Weight ............................................. Shoe (9 5/8'") Depth ................................ Estimated Fracture Gradient (9 518" shoe) Total Depth .............................................. Bottom hole pressure gradient ................... Gas gradient (assume worst case) ............. 9.6 ppg 8000 feet MD 10500 feet MD 0.4992 psi/ft 7956 feet TVD 0.9 psi/ft 10286 feet TVD 0.45 psi/ft 0 psi/ft Wellbore volume with gas kick situation, is assumed to be a 100 bbl in 8-1/2" hole at 10500', which equates to situation of 86% mud and 14% gas. Maximum surface pressure=Bottom hole pressure-hydrostatic pressure MSP = BHP - (86% mud +14% gas) MSP = (10286'.45)-((0.86'(10286'.5))+(.14'(10286'0. I))) MSP = 213 psig ¥o Therefore the greatest hydrostatic pressure at the 9 5/8" shoe (HPsh) is when the gas bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the casing depth (HP csg) HPsh = MSP + HPcsg HPsh = MSP + (TVD x MW) HPsh = 4184 psi This (HPsh = 4184 psig) is less than the fracture pressure at the same shoe. (FPsh = 0.90 psi/ft * 7956' = 7160 psig) and thus sufficiently adequate to handle a well kick. HPsh - Pore Pressure @shoe is less than (<) Intemal yield of the 9-5/8" casing 4184-(7956'0.45) < 3650 psi 604 < 3650 psi Note: The 9-518" has been down graded based on casing inspection log and a new calculated internal yield based on remaining thickness. Hole Section 2 Depth Interval: 10500'-12500' 6" hole size 5" casing from 10300' to 12500' Maximum Surface Pressure Calculation; Mud Weight ............................................. Shoe (7") Depth ................................ Estimated Fracture Gradient (7" shoe) Total Depth .............................................. Bottom hole pressure gradient ................... Gas gradient (assume worst case) ............. 13.5 ppg 10500 feet MD 12500 feet MD 0.702 psi/ct 10286 feet TVD 0.9 psi/ct 12128 feet TVD 0.68 psi/ct 0.1 psi/Ct Wellbore volume with gas kick situation is assumed to a 100 bbl in a combined hole size of 6" (20003 and 8-t/2" (10500'), which equates to 94% mud and 6% gas. Maximum surface pressure=Bottom hole pressure-hydrostatic pressure MSP = BHP - (94% mud + 6% gas) MSP = (12128'.68)-((0.94'(12128'.702))+(.06'(12128'0.1))) MSP = 171 psig Therefore the greatest hydrostatic pressure at the 7" shoe (HPsh) is when the gas bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the casing depth (HP csg) HPsh = MSP + HPcsg HPsh = MSP + (TVD x MW) HPsh = 7392 psi This (HPsh = 7392 psig) is less than the fracture pressure at the same shoe. (FPsh = 0.90 psi/ft * 10286' = 9257 psig) and thus sufficiently adequate to handle a well kick. HPsh - Pore Pressure @shoe is less than (<) Internal yield of the 7" casing 7392-(10286*0.68) < 8160 psi 397 psi < 8160 psi Page 2 3MSP.XLS 30- Structural @ 82' BLM 20' Surface @ 615' 85 & 94~ 13-3/8' Intermediate @ 1969' 54.5, K-55, BTC Cement Plug F/8415'-7969' Cement Plug F/8974'-8415' Retainer @ 9070' TOL @ 10280' 9-5/8' Production @ 8050' 40-43.5~, N-80 & S-95, BTC Retainer @ 11700' Retainer @ 11800' Retainer @ 12150 7' L @ 13101' 35#, S-95 ANNA 3 REDRILL Plug & Abandonment as of 10-13-94 UNOCAL ENERGY RESOURCES ALASKA DRAWN: CLL DATE: 11-0g-94 FILE: ANNA3RD.drw KOBE BHA 8 10 11 12 I 14 __ 15 30' Structural @ 82' BLM 20- Surface @ 615' 85 & 94~ 13-3/8' Intermediate @ 1969' 54.5, K-55, BTC TOL @ 7650' 9-5/8' Production @ 7810' 40-43.5#, N-80 & S-95, BTC COMPLETION DESCRIPTION 1) Dual 3-1/2-, 9,2#, L80, SCBTC 2) Kobe BHA (3" system) F/?'-?' 3) 3-1/2- 'PA' sleeve @ ?' 4) 3-1/2' 'PA' sleeve @ ?' 5) Otis 3-1/2' RRO SSSV @ ?' 6) Otis "VL'I" Packer @ ?' 7) 3-1/2' "R' landing nipple @ ?' 8) 1/4' SS control line 9) One it. 3-1/2- tbg F/?' 10) Pup jt 3-1/2" F/?' 11) Crossover 3-1/2' x 2-7/8' 12) Jts of 2-7/8' F/?' 13) Mech. Tbg Release @ ?' (ID=2.25') 14) TOF @ ?' (2-7/8' tbg) 15) Btm of Fish @ ?' RKB = 127' TOL@ 10340' 7' Uner @ 10500' 29#, L-80 BTC Hemlock Perfs 'I'BA Fish; 3-3/8' OD TCP guns 'spent' and released ETD @ 12400' 5' L @ 12500' 15#, L80, BTC ANNA 3 REDRILL PROPOSED COMPLETION Option 3 UNOCAL ENERGY RESOURCES ALASKA DRAWN: CLL DATE: 11-09-94 FILE: ANNA3RD3.drw STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive '" Anchorage Alaska 99501-3192 Re~ THE APPLICATION OF Union ) Oil Company of California ) (UNOCAL) for an order granting ) an exception to spacing requirements ) of Title 20 AAC 25.055 to provide ) for the drilling of the Granite Point ) Field, Platform Anna 3RD ) development oil well. ) Conservation Order No. 340 Union Oil Company of California Anna 3RD October 14, 1994 IT APPEARING THAT: UNOCAL submitted an application dated September 26, 1994 requesting exception to 20 AAC 25.055(a)(3) to allow drilling the Granite Point Field, · Platform Anna 3RD development oil well to a producing location in an undefined oil pool that is closer than 500 feet to a drilling unit boundary. . Notice of opportunity for public hearing was published in the Anchorage Daily News on September 28, 1994 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The Granite Point Field Platform Anna 3RD well as proposed, will be a deviated hole drilled from a surface location 729' from the north line (FNL) and 636' from the east line (FEL) of Section 12, T10N, R12W, Seward Meridian (SM) to a proposed bottom-hole location of 2221' FNL and 2242' FEL of Section 12, T10N, R12W, SM. 2 UNOCAL is the sole owner of all offsetting spacing units. 3. An exception to 20 AAC 25.055(a)(3) is necessary to allow drilling ofthis well. CONCLUSION: Granting a spacing exception to allow drilling of the Unocal Granite Point Field, Platform Anna 3RD well as proposed will not result in waste nor jeopardize correlative rights. Conservation Ore, No. October 14, 1994 Page 2 340 NOW; THEREFORE, IT IS ORDERED: UNOCAL's application for exception to 20 AAC 25.055 for the purpose of drilling the Granite Point Field, Platform Anna 3RD well is approved as proposed. DONE at Anchorage, Alaska and dated October 14, 1994. ~aa~~Oi/~~i o n Commission Russell A. Douglass, Commiggioner Alaska Oil and Gas Conservation Commission Tu6kerman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day ifa holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). Unocal North American .... Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region September 13, 1994 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Sir: Attention: Mr. David Johnston, Commissioner Re: Anna Platform - Well 3/3RD Unocal Oil & Gas Operations hereby makes application to plug and abandon the existing well (Anna 3) back to 8000'. This depth (8000' MD) is the potential kick off point for the new well (Anna 3RD). Eight thousand feet is the proposed kick off point. Unocal believes that the existing 9 5/8" casing to 8000' is of good quality. However we want to confirm that before we commit ourselves to kicking off at 8000'. If the casing integrity is inadequate we would cut and pull the 9 5/8" casing to 2000' and redrill from that point. Anna 3RD will be drilled and completed in the Hemlock formation. There are no other Hemlock wells within 1000 feet of the proposed bottom hole location. We are submitting our application in two parts. The first part is the Sundry application. This will cover the plugging and abandonment operations. The second part is the Permit to Drill. The permit covers the ddlling portion of the proposed operations. We are proposing to conduct the plugging and abandonment operations first. Once the P&A operations are completed we will then evaluate the existing 9 5/8" casing. We are planning to P&A Anna 11 and reddll Anna 11RD while we are evaluating the Anna 3 casing. Therefore approximately three months will transpire between the Anna 3 plugging and abandonment operations and the subsequent Anna 3RD redrill operations. RECEIVED Gas Cons. Commission Alaska Oil & Gas Conservation Commission September 13,1994 Page 2 In support of the Sundry application please find the following enclosed; a) completed "Application For Sundry Approvals" b) table of existing perforations c) an outline of the proposed abandonment program d) wellbore schematic of the present completion status e) wellbore schematic of the proposed abandonment f) diagram of our proposed BOPE configuration In support of the Permit to Drill application please find the following enclosed; a) completed "Permit to Ddll" b) Cheque for $100.00 (application fee) c) table of existing perforations (pdor to re-drill) d) an outline of our proposed ddlling program e) a plot of the Projected days versus Depth f) diagram of our proposed BOPE configuration g) schematic of the choke manifold h) a copy of the proposed directional plan i) calculation of anticipated pressures j) a copy of the mud program(s) that was filed with EPA k) schematic of the Anna mud system I) wellbore schematic of the proposed configuration-no contingency (post redrill) m) wellbore schematic of the proposed configuration-contingency (post redrill) RECEIVED SEP 1 9 1994 Alaska.0il.& 6as Cons. C0mmissi.0~l "'". ~ch0ra~e. All of the aforementioned documentation is submitted in triplicate. If you have any questions or comments with regards to our application(s) please do not hesitate to call Jamie Ressler or Lee Lohoefer at 263-7800 or 263-7642, respectively. Attachments Sincerely, G. Russell Schmidt Ddlling Manager -_. STATE OF ALASKA L___ , AL (A OIL AND GAS CONSERVATION COM ~ON APPLICATION FOR SUNDRY APt-.ROVALS 1. Type of request: Abandon X__ Suspend __ Operations shutdown__ Re-enter suspended well__ Alter casing__ Repair well Plugglng __ Time extension Stimulate -- -- Change approved program __ Pull tubing __ Variance Perforate Other 6. Datum elevation (DF or KB) 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 5. Type of Well: Development X_ Exploratory __ ~"batfgraphlc __ -- 105' KB MSL 7. Unit or Property name GRANITE POINT ADL 18742 4, Location of well at surface Leg #1, Slot 6, Granite Point, Platform Anna 729' FNL, 636' FEL, Sec. 12, R10N, R12W, SM At top of productive interval At effective depth At total depth 871' FNL, 1658' FEL, Sec. 12, T10N, R12W, SM 8. Well number 3 9. Permit number ~10. APl number 50-733-10065 1. Field/Pool GRANITE POINT FIELD feet 12. Present well condition summary Total depth: measured true vertical 13,114' feet 13,022' feet Effective depth: measured 9,059' feet true vertical 8,993' feet Plugs (measured) Junk (measured) 12,150' D.C. Retainer 11,800' D.C. Retainer 11,700' D.C. Retainer 9070' Bridge plug w/3.5 sx cmt on top Casing Length Size Structural Conductor 615' 20' Surface 1969' 13-3/8' Intermediate 10577' 9-5/8' Production Uner 2821' 7" Perforation depth: measured See attached table true vertical See attached table Cemented Measured depth 983 sx 615' 1200 sx 1969' 1500 sx 10577' 650 sx True vertical depth 615' Tubing (size, grade, and measured depth) Long string: 3-1/2", 8977' Short string: 3-1/2", 8923' Packers and SSSV (type and measured depth) None 2 , : CEIVED S EP 1 9 1994 Gas Cons. C0mmissi.0.11 ' ~choratle 13. Attachments Perforation Table X 14. Estimated date for commencing operation ~ 5. 16. If proposal was verbally approved / Oil X_ D ate approved Description summary of proposal _ _ Detailed operations program_ _ BOP sketch -- -- Wellbore Schematic - Pre Abandonment X Wellbore Schematic - Post Abandonment X Status of well classification as: Gas __ Suspended __ Name of approver Service 17. I hereby cerlJ~~h~ he for g~ct to the best of my knowledge. Signed G. Rus~ellSchmldt - Title Drilling Manager FOR COMMISSION USE ONLY Date 9/07/94 (~ ~ ~ '~pr°va~x~;/- '~ '~-'''~--~ / Commissioner Date ~ Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test __ Location clearance Mechanical Integrity Test__ Subsequent form required 1--~- Approved by the order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA .. _AND GAS CONSERVATION COM, PERMIT TO DRILL 3SION 20 AAC 25.005 ,a. Type of work Drill E] Redrill [] Ilb. Type of well. Exploratory E] Stratigraphic Test E] Development Oil Re-Entry [] Deepen []I Service E] Development Gas E] single zone[-] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company o[ California (UNOCAL) 105 KB, MSL feet Granite Point Field/Hemlock 3. Address 6. Property Designation P.O. Box 196247, Anchorage, AK 99519 ADL 18742 4. Location of well at s~race Leg 1, Slot 6, GP Platform Anna 7. Unit or property name 11. Type Bond (sm mAcc ~.o~ 729' FNL, 636' FEL, Sec. 12, T10N, R12W, SM Granite Pt Field AK Statewide Oil & Gas Bond At top o~ productive interval 8. Well number Number 1643' FNL, 1908' FEI_, Sec 12, T10N, R12W, SM 3RD U62-9269 At total depth 9,Appr.oximate spud date Amount 2221' FNL, 2242' FEL, Sec. 12, T10N, R12W, SM January 1, 1995 $200,000 12. Distance to nearest 13. Distance to nearest well 14._ Number of acres in property 115. Proposed depth property line 3372 feet > 1000' feet 5060 12,500 '/12,128' feet 16. To be corn plated for deviated wells 17. Anticipated Pressure(,e m AAC 25.o~5 (,~ Kickoff depth 8000 feet MaximLrn holeangle 23 aa~rnumsurfac, 3000 psigAttotaldepffi{TVD) 7500 psi~l 18. Casing program Setting. Depth size Specifications Top Bottom Quantity of cema nt Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 13-3/8" 54.5 1969 0 0 1969 Existing Csg (1200 sx) 9-5/8" ~,0,43.5,47N80,S.( 5 BTC 10577 0 0 10577 10494 Existing Csg (1500 sx)\ 8-1/2" 7" 29 1_80 BT(3 4700 7800 7760 12500 12128 915 sx 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured 13,114' feet Plugs (measured) 12150' Retainer true vertical 13,022' feet 11800' Retainer 11700' Retainer Effective depth: measured 9059' feet Junk (measured) 9070' Bridge plug w/3.5 sx cmt on top true vertical 8993' feet 9059'-8600' Abandor~'nent Plug (cement) 8600'-8050' Abandonrnnet Plug (cement) Casing Length Size Cemented Measured depth True vertical depth Structu'al Conductor 615' 20" 983 sx 615' 615' Surface 1969' 13-3/8" 1200 sx 1969' Intermediate 10577' 9-5/8" 1500 sx 10577' RECEIVE[. Production Liner 2821' 7" 650 sx 10280'- 13101' Perforation depth: measured ~[P ]9 true vertical See attached table J~!a$~,a .0JJ .& Gas Cons. Con]n] ' ~ct~0r~_~ 20. Attachments Filing fee E~ Property plat [-] BOP SketchE~ Diverter Sketch ~ Drilling program [~ Drilling fluid program [~ TirB,e vs depth plot ~ ~_raction analysis [-[ Seabed report [-[ 20 AAC 25.050 requirements 21.1 hereby certify that tl~o~g~g~ ~e~e best of my knowledge Signed G. RUSSELLSCHMIDT Title DRILLING MANAGER Date 09/07/94 Commission Use Only Permit Number I API number I Approval date I See cover letter 50-;;~.g -/~ o ~',¢- ,~ / 9~,~ -//,~Z',~, , Jfor other requirements Conditions of approval Samples required J-'J Yes ~ No Mud log required J-J Yes ~ No Hydrogen sulfide measures J-1 Yes 'j~ No Directional survey required ~ Yes J-] No Required workingpressurefor BOPE J-J 2M; J-'J 3M; J--J SM; J-J 10M; J-'J 15M Other: by the order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate Anna 3 Perforation Intervals Prior to Abandonment Perforation Inte~als Perforation Intervals Top Bottom Top Boffom Zone Measured Depth THe Veal. Depth C-4 81501 8220 8107 8172 C-5 8250 8290 8202 8241 8307 8330 8258 8281 8347 8380 8297 8330 8382 8420 8332 8369 8422 8460 8371 8408 C-7 8700 8735 8644 8678 8820 8835 8761 8775 8840 8850 8780 8790 8895 8920 8834 8859 8960 8970 8899 8908 C-8 9100 9150 9036 9085 RECEIVED Gas Cons. Commissi0.n 3PROCED.XLS · ,NNA 3RD ,)utline 1. Rig up 2. Abandon existing completion. 3. Evaluate existing 9 5/8" casing 4. Set whipstock with permanent packer. Set @ 8050'+ 5. Control, directionally sidetrack off of plug. 6. Directionally drill 8.5" hole to TD (1 2500') See attached directional program for details Run and cement 7" liner Completion (TCP w/dual string tbg & Kobe pump) RECEIVED S EP 1 9 199~ Oil & Gas Cons. Commission Anchor~ ~:,.~ Page 1 3PROCED.XLS TimeEst. 0.33 1 0.13 0.25 1 1 0.5 0.75 0.75 O.25 0.33 0.42 1 0 O.33 0.25 0.67 0.17 0.5 0.75 31.75 1 1.94 1.5 0.67 0.75 0.33 1.12 1 Cum Time 0.33 1.33 1.46 1.71 2.71 3.71 4.21 4.96 5.71 5.96 6.29 6.71 7.71 7.71 8.04 8.29 8.96 9.13 9.63 10.38 42.13 43.13 45.07 46.57 47.24 47.99 48.32 49.44 50.44 50,44 ANNA 3 RD Preliminary Procedure: 1. MIRU, Leg #1, Conductor #, (Well 3). 2. Pump FIW to kill well.Set BPV. Nipple down tree. Nipple up 13 5/8" 5000# BOP's. . 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16, 17. 18. 19. 20. 21. 22. 23, 24. 25, 26. 27. 28. 29, Rig up and pull simultaneously on both strings (simply ensure they're "moveable"). RIH and cut short string. POOH w/short string. POOH w! long string. RIH open ended. Should tag EZSV @ 9059' Lay cement abandonment plug form 9059'-8600' Lay second cement abandonment plug from 8600'-8050' RIH w/gauge ring and junk basket to 8050' POOH. Evaluate 9 5/8" casing with USI. Release rig. Move rig to Anna 11. Move rig back over Well #3 Change out wellhead RIH w/permanent packer & whipstock key slot latch. Orient key slot latch RIH w/whipstock/Starter mill assembly. Latch into packer. Mill 3-5' w/starter mill. POOH w/Starter mill. RIH w/window milling assembly Mill whipstock window. Directionally drill 8 1/2" hole to 12500' TD. 140 fpd Run open hole conventional logs. Run & cement 7" liner from TD- 7800'. Clean out inside of liner. Circulate well over to 3% KCi fluid. Run SBT/NEU/GR log from ETD to TOL Make up TCP guns on bottom of dual completion w/Kobe BH^. RIH w/ TCP/Completion. Land in place. (guns 10800-12475'+/-) Set BPV. Nipple down BOP's. Install wellhead. Release rig & turn well over to production. Rev. 1 9/2/94 RECEIVED SEP 9 199 ~.~s~ ~[[ .& Gas Cons. Commission '-~-~,, ~n~hor~;~. Page 2 Anticipated Pressure: Maximum Surface Pressure Calculation; Mud Weight ............................................. Shoe (9 5~8") Depth ................................ Estimated Fracture Gradient (9 5~8" shoe) Total Depth .............................................. Bottom hole pressure gradient ................... Gas gradient (assume worst case) ............. ANNA 3RD 9/14/94 13.5 ppg 8000 feet MD 12500 feet MD 0.702 psi/ft 7956 feet TVD 1.1 psi/ft 12128 feet TVD 0.68 psi/ft --_ 0 psi/ft Wellbore volume with gas kick situation: 3/4 mud & 1/4 gas Maximum surface pressure=Bottom hole pressure-hydrostatic pressure MSP = BHP - (3/4 mud + 1/4 gas) MSP = (12128'.68)-((0.75'(12128'.702))+(.25'(12128'0))) MSP = 1862 psig Therefore the greatest hydrostatic pressure at the 9 5/8" shoe (HPsh) is when the gas bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the casing depth (HP csg) HPsh = MSP + HPcsg HPsh = 1862 + (7956'.702) HPsh = 7447 psi This (HPsh = 7447 psig) is less than the fracture pressure at the same shoe. (FPsh = I .I psi/fi` * 7956' = 8752 psig) and thus sufficiently adequate to handle a well kick. This scenado is considered extreme since actual well kicks have seen maximums of 300 psig on the shut in casing. Note: For these calculations the shoe is actually the point where we mill a window and kickoff out of the existing 9 5/8" casing. ~r RECEIVED S EP 1 9 1994 Al~s~ ~jii .& (~as Cons. Commission 1100 2100 3100 4100 5100 6100 7100 8100 9100 101OO 111oo 12100 TCP GUNS · _ .ha 3RD New Status(Post-Reddll) Tyonek is able to withstand heavy mud weights Ddlling Liner Not Required 10800'-12400' Z 0 13100 1100 2100 3100 4100 5100 6100 7100 8100 9100 101OO 11100 121OO 131OO TCP · _ .~a 3RD New Status (Contingency) (Post-Reddll) Tyonek not able to withstand heavy mud weights Drilling Liner Required GUNS 10800'-12400' © Z O 0 t- 0 0 0 REEEIVED S EP ]9 1994 Alas~ka~ .~JJl .& Gas Cons. C0mmissio. n .... -". ~chor~ FILL- UP ~ ~ . FL0~ 3"- 10M CHECK VALVE KILL LINE ANNULAR BOP ~" 3 Ye 5000 psi 3%" 5000 psi BLIND RAMS 13~/8"5000 pst H CR , HCR [-~ MANUAL !DRILLINGii I~ANUAL I i i 3" - ~ o ~ //' II it "%\ ,~" - ~ o ~ LINE RISER 5000 psi RECEIVED S EP 19 1994 Gas Cons. Commiss[o_n ~chor~. CHAKACHATNA RIG 428 BOPE STACK 13 %" 5000 psi VENT OUTSIDE OF WINDWALLS V~-5M ~/R~ Fb~E PANIC LINE 4" 5,000 PS1 BALL VALVE (TYP., 4 1/16-5M FLG. X ~i 1/16-514 HUB BLIND HUB CLAMP W/BX BUND WILLIS ADJ. 10,000 PSI HTO. CHOKE \ VENT UP OE~RICK 3' RELIEF VALVE SET AT 40 PSI VENT UNE CLAMP HUB CONNECTION BUFFER TANK TO PRODUCTION SEP~TOR 1o" 15o lb. BUND FL~GE (rm.) 10' 150 lb. FLANGE MUD CAS SEFERATOR SIPHON LINE 150 lb. FLANGE I To 8" MUD RETURN LINE UNOCAL CHOKE I~IIFO~ COOK INLET OWO. CY-1:12592 6OOO 8OOO 1OOOO 12OOO 14OOO Anna 3/3RD Days 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 o 3DAYDEP.XLS Days Depth 1 0 2 8800 3 8800 4 9059 5 8600 6 8050 7 8050 8 8050 9 8055 10 8O75 11 8245 12 8415 13 8585 14 8755 15 8925 16 9095 17 9265 18 9435 19 9605 20 9775 21 9945 22 10115 23 10285 24 10455 25 10625 26 10800 27 1O9OO 28 11000 29 11100 30 11200 31 11300 32 11400 33 11500 34 11600 35 11700 36 11800 37 11900 38 12000 39 12100 40 12200 41 12300 42 1250O 43 12500 44 12500 45 12500 46 12500 47 12500 48 12500 49 12500 50 12500 end P&A Csg Eval/Move rig to Anna 11 Move rig from Anna 11/Rig back up whipstock milling completed/start drill 8 1/2" hole Anna 3/3RD Days 1 4 7 1013161922252831 343740434649 HW Mud mq'd TD RECEIVED SEP 1 9 199~ A!ask~.Oil.& Gas Cons. Commission '"~' ~chor~..;~j RR Several months to transpire between Day 7 & Day 8 on Anna 3/3RD Unocal Enerejy Rest--?, Division Unoca~ CorDora[~on 309 West 9tl~ Avenue...O. Box 196247 -~ncnoraae. AlasKa 99519-6247 ~ieol3one ~9071 276-7600 UNOCAL. ' July 1, 1994 Environmental Protection Agency Region X 1200 Sixth Avenue Seattle, WA 98101 Attention: Kris Flint Dear Ms. Flint: NPDES Permit Cook Inlet/Gulf o1 Alaska AKG 285004 Anna Platform Unocal plans to drill six wells' 3RD, 11RD, 50, 51, 52, and 17RD on Anna Platform. The anticipated spud date for the first well is August 1, 1994. Wells 50, 51 and 52 will be batch drilled. The same mud formulation will be used on eactq well. Unocal requests approval of these fluids for each of these wells. Three drilling fluid types are proposed for use on the Anna Platform wells. The first is Generic Mud #1 from Table 1, page 50 of 54, of the Cook Inlet/Gulf of Alaska permit, with additives from Table 2, pages 51-53. The second is Generic Mud #2 from Table 1, page 50 of 54, of the Cook Inlet/Gulf of Alaska permit, with additives from Table 2, and additional materials. The third drilling fluid is a Non-Generic KCl mud aisc approved and used by Unocal on the Bruce and King Salmon Platforms. Unocal has requested approval for the Granite Point Platform. Unocal anticipates using only one mud system per well. However, two of the three mud systems may be used on the same well. An example of how this would work is as follows we would use mud system (1) on the intermediate hole section and mud system (2) on the production hole section. We would have mud system (1) circulated from the wellbore and removed from the mud pits prior to mixing mud system (2). Under no circumstances would mud systems be mixed or combined. RECEIVED S EP ] 9 1994 Gas Cons. Commission July '1. 1994. Ms. Flint Page 2 The Generic Mud #1 proposal uses only those products listed in Table # 1 and Table #2. The Generic Mud #2 proposal is identical to the muds and additives authorized for Baker ¢28. 29. 30. and King Salmon K-26. Note: The original request for 3 ppb of XC Polymer/Xanvis/Biozan was only authorized at 2 ppb. Mud #3 is a Xanvis FLO-PRO, Non-Generic Potassium Chloride mud system which is aireaay authorized for use on Bruce 42-2, B-30, and King Salmon K-24. Xanvis FLO-PRO is used to drill the production interval. Generic Mud #1 Permit Component Name M-I Trade Name Maximum Allowable Concentration KCl KCl 50 PPB Starct~ Polysai, FL7+, Bioiose 12 PPB Cellulose Polymer Drispac, Polypac Reg., Drispac SL Polypac UL Thermpac UL 5 PPB Xantham Gum Polymer XCD Polymer, Xanvis 2 PPB Drilled Solids 100 PPB Caustic Caustic 3 PPB Barite M-I Bar 575 PPB Seawater/Freshwater As Needed RECEIVED S EP ]9 1994 Oil & Gas Cons. Commission Anchor~.u~ July 1, 1994 Ms. Flint Page 3 Permit Component Name Aluminum Stearate Gelex Flakes of Silicate mineral Mica (Generic Mud Cf1) Table 2 M-! Trade Name Aluminum Stearate Gelex Mica Maximum AIIowat~ie Concentration 0.2 PPB 1 PPB 45 PPB Nut Hulls, cruslqed, granular Sodium Chloride Sodium Acid Pyrophosphate Chrome free organic mud thinner containing suifomethylated tannin Vegetable Plus Polymer Flakes & Granules Resinex Oleates in mixed alcohol Scitex Fatty Acid esters aikyi phenalic sulfides in a solvent base Organophyllic clay Glass beads Nut Plug Stock Salt SAPP Desco CF Kwik Seal Resinex Lube 106 Scitex Bit Lube II VG-69 As Needed 50,000 mg/I chlodde 0.5 PPB 0.5 PPB 50 PPB 4 PPB 2 PPB 6 PPB REC£1V£D 2 PPB SEP ~ 9 1996 Oil & 6as Cons. Commission12 PPB ^nchor~.~ 8 PPB Plastic spl~eres 8 PPB July 1, 1994 Ms. Flint Page 4 Generic Mud #2 Permit Component Name M-I Trade Name Maximum Allowable Concentration Bentonite M-! Gel 50 PPB Lignosuifonate Spersene CF 15 PPB Lignite Tannathin 10 PPB Caustic Caustic 5 PPB Lime Lime 2 PPB Barite M-I Bar 575 PPB Drilled Solids 100 PPB Soda Ash/Sodium Bicarb. Soda Ash/Sod. Bicarb. 2 PPB Cellulose Polymer Drispac/Poly Pac Reg. Drispac SL/Poly Pac UL/ Thermpac UL, Polysal 5 PPB Seawater/Freshwater As Needed RECEIVED SEP ] 9 1994- ~aska .Oil & Gas CoDs. Commission ' ~choraj~; July 1, 1994 Ms. Flint Page 5 (Generic Mud #2) Table 2 Permit Component Name Aluminum Stearate M-I Trade Name Aluminum Stearate Maximum Allowable Concentration 0.2 PPB Gelex Gelex 1 PPB Flakes of Silicate mineral Mica Mica 45 PPB Nut Hulls, crushed, granular Sodium Chloride Nut Plug Stock Salt As Needed 50,000 mg/I chloride Sodium Pyrophosphate SAPP 0.5 PPB Chrome free organic mud thinner containing sulfomethylated tannin Desco CF 0.5 PPB Vegetable Plus Polymer Flakes & Granules Kwik Seal 50 PPB XC Polymer Resinex Xanvis/Biozan Resinex 2 PPB 4 PPB Soitex Soltex 6 PPB Organophillic clay Suif-X ES VG-69 Zinc Oxide RECEIVED SEP '19 1994 A!~,sk~ u~ & Gas CODS. Commission Anchor¢u.~. 12 PPB As Needed July 1, 1994 Ms. Flint Page 6 (Generic Mud #2) Additional Materials Product Maximum Allowable Concentration Defoam X Polyplus (PHPA dry) Tackle PH-6 SP-101 Lube 167 or Tek Mud 8588 0.3 PPB 3 PPB 1 PPB 1 PPB 3 PPB 2% v/v Mineral Oil Spotting Fluid Component Name M-I Trade Name Kwik Spot Kwik Spot Mineral Oil Conoco LVT RECEIVED S EP 19 1994 Anch0ra.,,e July 1, 1994 Ms. Flint Page 7 Mud #3 Xanvis Fio-Pro Product Maximum Allowable Concentration Xanvis 4 PPB Caustic 1 PPB NaCl 50,000 mg/I chloride KCi 3 % V/V FL7 + 3 PPB Lowate (calcium carbonate) 75 PPB Please see the Cook inlet/Gulf of Alaska permit for additional details pertaining to substitution of products and handling of mineral oil pills. Bioassay data for the additional materials is available on request. If you have any questions, please do not hesitate to contact me at (907) 263-7832. Sincerely, G. Russell Schmidt Drilling Manager AZRB/kpm RECEIVED SEP 1 9 1994 Alsska Oil & Gas Cons. Commission July l, 1 Ms. Flint Page 8 bcc Lee Lohoefer damie Ressler Bob Haagensen, M-I Drilling RECEIVED S EP 1 9 1994- Gas Cons. CoBr~Jssion ~chora~ 09/15/94 15:35 FAX 205~$3 1280 ]~PA WASTE. WATER ~,~ ~ OPT/ONAI. FOP.VI ~ ~) ,~0~ -~ ~ALPROTE~ONAGENCY - ~ ~B~N~~ ~in~n 98101 001/007 Reply To A~tn Of: WD-137 Alice Z.R. Bullington Unocal Corporation Post Office Box 196247 Anchorage, Alaska 99519-6247 Re: NPDES AKG285014, Anna Platform, Well Nos~ ~RD, 11RD, 50, 51, 52, 1719D Dear Ms. Bullington: We have completed review of your July 1, 1994, request for authodzaUon to discharge any one of three. proposed mud/additive systems from Well Nos. 3RD, 11 RD, ,50, 51, 52, and 17RD on the Anna Platform. Authorization to discharge for each of the proposed mud/additive systems follows. GeneHc Mud 1 Based on our evaJuation of the proposed combination of generic mud 1 and additives from Table 2 of the permit, only some_ of the additives may be discharged in generic mud 1. Additives for discharge in generic mud 1 are limited as shown below because our worse-case cumulative toxicity esUmates Indicate that toxicity of the discharged mud (with all proposed additives) is likely to exceed the Agency's toxicity criterion of 30,00o ppm SPP. The following mud addi~es may be discharged In generio mud 1 at the concentrations listed on Table 2 of the permit. ° Aluminum stearate ° SAPP ° Vegetable plus polymer fiber, flakes and granules ° Flakes of silicate mineral mtca ° Inert spheres (glass, plastic) Generic Mud 2 Discharge of ~he following additives is authorized in generic mud 2, with additives from Table 2 of the permit, as requested. You must notify EPA ff any additives from Table 2 ot~ than those listed in your July 1, 1994 request wD! be present in the discharged mud. ° $?-101 (acrylic polymer), maximum discharge concentration shall not exceed 3 ib/bbl ° Tackle (Iow molecular weight polyoarboxylic acid salt), maximum discharge concentration shall not exceed 1 lb/bbl ° PHPA (also known as Poly Plus, high molecular weight anionic polymer), maximum discharge concentration shall not exceed 3 Ib/bbi ° Defoam X (blended defoaming agents}, maximum discharge concentration shall not exceed 0.3 ib/bbl ° PH-6 (carboxylic acid buffer blend), maximum discharge concentration shall not exceed 1 Ib/bbl Lube 167 or Tekmud 8588 (lubricants), max{mum discharge concentration shall not exceed 2% v/v RECEIVED SEP 1 9 1994- AI~!'~ Oil & Gas Oons. Gommi~sion ~ ~ch0r~H FAX 206 §~8 1280 EPA WAS.~ WATtle_ ~ ~_ · -2- ~002/007 ° XC Polymer and/or Xanvis and/or i~iozan (xanthan gum and welan gum polymers, respectively), total product concentration in discharge shall not exceed 2 I/obi Note that bioa~_~a_y test mpo~s submi~ed pursuant to Part il.B.l.k, of ~ permit, should include an inventory of mud components and addPJves present in the sample. The unks reported on the inventory for the sampled mud should be the same as the units of autl~rization (e.g.0 "lb/obi,' ' % v/v,' ' mg/i chloride'). We also give imerfm authorization for the discharge of residual amounts of Kwikspo~ mineral oil pill, formulated with Conoco LVT mineral oil, in generic mud 2. Should this formulation be used, we require that as much of the pill as possible be removed prior to discharge of the mud. Residual re'metal oil concentration in the discharged mud should not exceed 2% v/v. The discharged mud must comply with Parts ll.C.l,f,, g., and i, of the permit which also pertain I;o the discharge of residual mineral oil pill. ° the date of discharge · ° the results of the DnHling Fluids Toxicity Test on a sample of the discharged mud which comains the ma~mum concentration of rr~eral oil discha ,r(~! ! ° the mineral oil product used ~ volumes of Kw]-kspot spotting compound, mineral olt, water and barite in the pill ° total volume of the pill, total mud volume ° estimated Kwikspot spotting compound and oil content of the above sample, as determined from amounts added and total mud volume ° measured oil content of the above o~1 sample, as determined by the APl retort method ° totaJ volume of dnlllng mud containing p~l recovered ° estimated percent recovery of the pHI O.nclude calculations) ~ an it~mization of other drilling fluid speciaJty addkives oontained in the discharg~ mud AJso note that Part ILC. I.j. of the permit requires that chemical anaJyses for metals shall be provided for each discharged mud system that has contained mineral oil addith/es. ¢ . · Nongeneric Xanvis Flo-Pro Mud We authorize the discharge of the following potassium-based mud/additive system on an interim basis. Since ~he folloWing formulation is nongeneric0 additives from Table £ of the permit may not be discharged without prior aUthorization from Region ~0. This interim autho~ is based upon our previous evaluation of the proposed mud/additive system and upon end-of-well bioassay data for. discha~le of this same nongenerlc mud/additive system from o~er platforms in Cook Inlet. The nongeneric mud/add'ire system shall be sampled for bioassay when the maximum anticipated number of mud components and additives are in use. A list of mud componen[s and additive present in the sample must accompany the bioassay report, Product concentrations may be reported in terms of ~ same units as authorized below. (E.g., report potassium chtoride in I _ II I I ii - Cons. Commission 1,5:,36 FAX 206 553 1280 ~YA WA~'I'I": ~A'I'~.K ~-, I~I. UU~/UU7 -3- The following table lists authorized mud components and add,yes. The concentrations shown are maximum values and are not to be exceeded in the discharged mud. Component/Additive Xanvis (xanthan gum polymer) Caustic (potassium hydroxide) Sodium chiodde FL7 + (crosslinked derivafized starch) Lowate (calcium carbona',e) Potassium chloride Maximum Authorized Conoentrafion (Ib/bbl unless stated other, se) 4.0 1,0 60,000 mg/I chloride 3.0 75.0 ,5% v/v Any questions concerning this letter may be addressed ~o Kris Flint at (206) 553-8155. Sincerely, Charles W. Rice. Chief Ocean Programs Section co: Robert Dolan, ADEC/Anchorage S F_:P '~ 9 1994 Gas Cons. Commission ~ch0r~? 09/15/91 Rely To Attn Of:. WD-137 FAX 206~.553 1280 BPA ~AST~ UNITED STATES ENVIRONMENTAL PROTECTION AGENCY REGION 10 1200 Sixth Avenue Seattle, ~,.Vashlngton 98101 ~004/007 M ~EMO_RANDUM SUBJECT: TO; FROM: Background Specialt~ Mud/Additive Evaltmth3n and Authorization - Cook INet · NPDES F'de No AKG,?.85004, Un'al, Anna WeltJs 0RD, 11RD,. 50, 51, 52, 17RD Environmental Sclentt~.,~ ~.~I~~--._. ~f On July 1.1994. Unocal requested authorization to discharge both generic and non-generic dn31ing mud/additive systems from wells 3RD. 11RD, 50, 51, 52, and 17RD on the Anna platform. Unocal proposes to use 3 separate mud/addkive systems, the trinet two systems are based on generio muds 1 and 2 (as autl~orlzed on Table I of ~e permk), while the third system is nongeneric. Of these three proposed mud/additive discharge~ Region 10 has previously evaluated and authorized two. Each proposed mud/additive system is discussed in detail below. Evaluation - Generic Mud I 8ased on me cumu~'dve discharge toxicity estimated below, Region 10 cannot authorize the discharge of any addltives in this generic mud except for those which do not exhibit any apparent effec[ on [he toxicity of discharged muds. I/LC5Ocum -- 1/LCS0eM~ + 1/LC50. + 1/LC50.+~ .+ .... where 1/LCS0;um = the estimated cumulative toxic~ of the pmpesed discharge, 1/LCS0aM~-- the toxicity of the base mud (generic mud 1). and 1/LC50, & 1/LCS0n.~ = respectNe toyJcity of proposed additives [o the base mud 1/LC50== = (1/30,000} + (1/26,100) + 0/662,000) LCSO~= 30,000 ppm SPP (EPA 1984) LCSO~-- 26~,000 ppm SPP (California Mud, EHA ~84264, 4/84 containing Resinex, Bit Lube il, aluminum stearate, mica & nut hulls as proposed) LCSO,+~ = 662,000 ppm SPP (Alaskan Mud, EHA ~-84,399, 5/84 containing Desco CF, Benex, Durenex, 8oltex, as proposed~ plus other additives) 1/LC,50~= = 3.86753 X 10.~ so, est]mated 96-hr LCSO for the proposed discharge is 25,856 pprn SPP. This level is below the Agency's toxicity criterion of 30,000 ppm SPI=' (i.e., ii Is more toxic)~. In I:he best professional judgement of Region 10 only those additives which have not demonstrated any effect wilh respect to discharge toxicity may be discharged in genedc mud 1. Of the additives proposed for d~scharge in this mud, only the following are authorized: Aluminum steerate SAPP Vegetable plus polymer fiber, flakes and granules ° Rakes of silicate mineral mica ° Inert spheres (glass, plastic) RECEIVED Gas Cons. Commission -2- Evalue. fion - Generic Muds 2 With Additives The germric mud/additive syst~ proposed by Unocal has been evaluated and authorized by Region 10 for dtsct~e from the Bake~ and i~mg Salmon platforms tn the past_ (See atta~d memos for Baker Wells 28, 29 & 30 and I~Tmg Salmon K-26). Based on these prior evahJ~dOnS and bioassay daza for the d' ,m~j;;~_ ge of_ used muds (see Al~achrnent A: Mud Comparison Table: UNOCAL Anna), in the best professional judgement of Region 10, i~ is unlikely that the discharge of this mud/add'~dve system wll exceed ~he Agency's toxicity cr/terion of 30,O00 ppm SPP. Evaluation - Nongeneric Xanvis./FIo-Pro Mud As with the generic mud/additive system above, the system proposed bY UnocaJ has been evaluated and authorized by Region 10 for dischaJ'ge from other plazforn~ in Cook Inlet. (Se~ attached memos for Bruce Wells B-,3RD & 42-2 and Doily Van:len Well DT-RD2.) A~z;~hment B compares the ~ mud/'addldve system ~ the column labelled "Basic Formula') with ~ d[schargecl oo,'-~:~m~ns of l:his sysl:em from ~ wells. 96-hr LCS0 vaJues are also provided on this table. Note that t~ of this nongeneric mud system ranges from 23,724 ppm SPP (when mud was.not disc. J3argec0 to 279,483 ppm SRP. While the range of to~ exhibited by fl3e mud/additive system is broad, no disoharge of the mud at a toxlcEy of less than 30,000 ppm SPP occur. Thus, based on prior evaluations and bioa~say da~a for the discharge of this mud/additive system as a used mud, Region 10 authorizes the discharge of the nogeneric XANVIS or FLO-PRO mud/additive system. Mud Comparison Table for UNOCAL Arms; Mud Type Gemeric Mud 2, T2 Additives & Other Additives Comparison Table for XANVIS or FLO-PRO Muds, Nongeneric, Potassiurn-CHior~e-based Used Muds Memo to NPDES Fae AKG285005, Unocal, Baker Wells 28, 29 & 30 (dated 7/6/93) Memo to NPDES Fi~e AKG285008, Unocal, ~ Salmon Well K-26 (da~ed 10/20/93) Memo to NPDES File AK~ Unocal, Bruce Wetl B-3RD (dated 10/20/93) Memo ~o NJ=DES F'de Ai(G2~..~]0~ UnocaJ. Bruce Well 42-2 (dated 6/'4/94) Memo ~o NPDES File AKG28500g, Malattton, Dc~y Varden DT-RD2 (da;ted 2/2/93) The mud represented by this bffoassy datum centa~ Benex (instead of the requested Gelex) and Durenex (irtstead ofthe requested Resinex). Region 10 regards both of these product pairs &e., Gelex/Benexand Durenex/Resinex) as functional eq~. i,~alents and, in editions of TaJ)le 2 in the Beaufort Sea II and Chukeh! Sea general permits ('~sued subsequent to the Cook Inlet permit), these additives are authorized as being interchangeable. Other additives represented by l~is bioass~ report' (but not proposed by Unocal) are XC Plymer (xantftan gum), Pac-L (potyanionic cellulose polymer), and Barn Brine Defoam. Toxicity is the inverse of an LC50 value: so, as the LCSO value Increases, the toxicity associated Wil:h themud/addit/ve decreases. For example, an LC50 of 1,0043.000 ppm SPP is less toxic than the Agency criterion of 30,000 ppm SPP. ' RECEIVED SEP '19 1994 Oil.& Gas Cons. C0mrn[ssi01~" Anch0r~ ~ -~4~T~b~. UNOC. J~AmmW~Ik3RI2,11RD,~$1,$2~. 17l~O . ~ abov~ $0 10 2 4~.1 0.7 O.2 2.4 &0.] 0,2 1 0. I o,g& 1.~ 2.3 &2.~ 0.6 .~AC = pelyai,,~ cea. pety. Additiv~ ~o~ Tab~ 2 of permit ' ' , Mica NUl Hul].~ Salt D=~co CF K~ VO~9 ^dditivc~ NOT on Table 2 of,permit Dct~gn.X Polyplu= OPHPA dry) Tackle ' PH.6 S?-101 Lub~ 167 orTekMud ~ KwUz~-~ (~~ Lxrr) o.~ 1 45 50,000 m$/l C 0.5 0.~ $0 2 4 12 O.3 3 I I 1NIT~ :~ v^ 0.2 0,9 0.02 0,01 4.1 0,2: 0.3 $ o.$ & 0.7~ o.~ 1,6 2.7 RE¢£IVED SEP 1 9 1996 Gas Con,L Commission ~dh0raoo B__io,:.r~y l_.aforma~ion ~G2~500~, ~, ~2g, ~t~ ~~ " > l,~O,O~ ~m SPP ~~ ~20, ~ ~ ~! ~, ~le ~ 3/17~4 (~~g r~ NOT a ~n~ ~ ~ ~1 ~ ~i~ t~)) NOT D~~ED AKG28500~ ~ ~m~ 26, ~~ ~ > 1,~o,~ p~ SPP ~~ ~2 zos~ ~ ~ ~4, ~ ~ 1~ * Co~iom(in ~b~bb~)w~r~p~s~viAX/PPB~m~mi~$~ix~te~h~ma~imum~~mu~ed~tauy~im~duriug~x:we~L The~ conccnirationa aro m~t rtc~ily prt~c~t/~ th~ b/omr~7~ m~,d. Further ~ This trmd w~ NOT ~ H w~ "lo~t~' tO (absorbed by) tho fornmlJon. 09/15/94 15:38 FAX 206 §53 ~ UUI/UUI C~uziic OiOlt ~' N.~OH) FL'Y+ Po~.~sium dalorld~ PH~ . ·~. ~., :~". ~*~ ~+ ~.~ .~. ~ ,.: l 3 AKG2gS00~, Bruc~ ~.3P, D (2~ ~ ho~e), inv~x~cd 2/6~94 ]3cuc~ ]~3RD ,, Bru~ B,,31~D (~ lar~l) 1/17194 - _ 10/3/93 . i 3/2g/93 · O.;2 $,1 0.2 O.6 1.7 21.9 1.6 ('~') 23g 0.1 1.7 (-~-) ~:..:..., ~ · ... : .,~:.. :;y:~,~,r)..~.~ 0.2 (~-) ~.~ ! I 33.9 2.7 C++) 29,1 0.58 I_56 ]4,o: ?.32 1,3'9 0.3' NOT DL.~CHARGI~D · · NOT DI~CHARGI~ RECEIVED SEP 19 1994 ~!aska.Oil .& Gas Cons. Commission ' Anchor[.~? TRANSFER LINE ~UD STORAGE ii":.:;.L" .',A:'." . CUIT~NGS DISCHARGE I ti 55 e~ )~ t~? 80 B~ ~ i ~IUD CI F-AN£R ~ · j I DESANDER 105 BBL ,SAI,IO TRAP 30 BBL L t~UID$ ~' I CENTRIFUC4. CENTR/R/C,E · i [., i [ L. [ ' ~'i ....~ ....... :'---:'---'-'---:'¥ ] , i I I I :,,~ ,.~, I,J,, ' ~-'- ~ ,P~ cn~r i , ,I- ....... --i-J--!- ~--,__..._,4-,_ ..... ,,j -- ~~ ' j! i I : I : I I I I _.~::,- ..... J ~ · i i : i ~_ ..................... .f .'X._ .. _j~'~.__~IX_j. ~. .... ~"'x .... I i ....................... .--,'1~.--..~!'~--~ h--. J ......................... ...,:,_.__. _,i,__.,!,_ ........... ' ,._. __. ~__ .C~'?~. __0~. __O~r__. _I i = ' '~':: ' == :..-: =:=_'= ;= :=:-'~'-'-.' ~':.._'-_: r' :-'..'fA'-. .... ~ "'-'"~' ~ ..... ._t L ................... ~ ~_.....~x_.. _,,~..'x_ ......... .._,'-x .... ._f"~ t. . ................ -- : .... ;'u/ ...... w~ ....................................... ~.,~_ dl~ .~ _~:~_ .... ii ,,"' ...... ,-~-==q-~,;,;~ ......... "--'I ........ t'--'i'"~ ~ ...... /; i, PU~P / . i '~ .... ~ '~-- ...... t1,.-;-.,~ " i ~ ........... ~ ......... H" I~ I · ~ _ ~ MUD / ~ J : ~ ....... J-~ .... ~ _, ' - CL~ .' f~ I ~ ~ ~---~ ,~ , ~ · ! ~ : -. eUM .. '~ [[ ~ ' I ~ ~ ~ ........... ~ ~ T~I . ~ ..... -~ .....,_. ~-~--4~ ...................... ~x' ' ~'~'r/ i I ~ ..... ~ ......... ...... i .... ~ ~-~ "",~ ......... ~" Ill i¢-. -~ '", " I ~ i ~' -~-- ~, ~i~co~,, ~' ". ~~1 i i .... ~-'~'-- (~)SE[-F~O ~ ', Ill ~ Vr,r '~ I '. , . _ -__. ~ ................. . ',- ...................... ..... ........................ i ~- ~ '~ ................................ ~-~ ...............~ ..... ~ .............................................................. i i ~ ............... PIONEER ~ESANDER CUTITN¢$ UT'flNC, S DISCHARGE ....~ ,,~, , PIONEER S-800 SIOEWliVDER IdUD HOPPER MUD J J CO~OR ~fl MUD STORAGE ..... S~TEM : MUD PUMP OIL WE'l L A-. 1/ooP ~ . ISSUED I ~ ,..~."?d¢, / I."l ................................ ~,~ LOW PRESSURE MUD ~ UNOCAL CHN(ACHAI1,tA PROJECT PM RIG 428 - ff4-4 I i . o UNOCAL ANNA Platform 3 Rd#1 slot #1-6 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 3 Rd #1 Version #3 Our ref : proplO~ License : Date printed : 20-Sep-94 Date created : 27-Jun-94 Last revised : 20-Sep-94 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 58 44.738,w151 18 33.113 Slot location is n60 58 37.510,w151 18 46.082 Slot Grid coordinates are N 2551408.201, £ 266811.833 Slot local coordinates are 734.00 S 640.00 W Reference North is True North RECEIVED S EP 2 G 1994 Alaska Oil & Gas Cons. Commission Anchor~e UNOCAL ANNA Platform,3 Rd#1 Granite Point Field,Cook Inlet, Alaska Measured Depth Inclin. Azimuth True Vert. Degrees Degrees Depth PROPOSAL LISTING Page 1 Your ref : 3 Rd #1 Version Last revised : 20-$ep-94 8000.00 10.50 262.00 7956.22 8100.00 11.31 249.46 8054.43 8200.00 12.56 238.98 8152.28 8300.00 14.15 230.60 8249.58 8400.00 15.97 223.97 8346.15 RECTANGULA COORDINATE 83.79 S 731.11 88.50 S 749.32 97.55 S 767.82 110.91 S 786.59 128.57 S 805.59 R Dogleg Vert S Deg/lOOFt Sect 0.00 438.12 KOP - Sidetrack Pt 2.50 451.30 2.50 468.39 2.50 489.35 2.50 514.14 8500.00 17.94 218.72 8441.80 8600.00 20.04 214.50 8536.36 8700.00 22.21 211.07 8629.63 8735.61 23.00 210.00 8662.51 9000.00 23.00 210.00 8905.88 150.50 S 824.78 176.64 S 844.12 206.95 S 863.59 218.74 S 870.54 308.20 S 922.19 2.50 542.72 2.50 575.03 2.50 611.02 2.50 624.70 End Build & Turn 0.00 728.01 95OO.0O 10000.00 105OO.O0 10791.54 11000.00 11500.00 12000.00 12475.40 23.00 210.00 9366.13 23.00 210.00 9826.38 23.00 210.00 10286.64 23.00 210.00 10555.00 23.00 210.00 10746.89 23.00 210.00 11207.14 23.00 210.00 11667.39 23.00 210.00 12105.00 477.40 S 1019.88 646.59 S 1117.56 815.78 S 1215.24 914.43 S 1272.20 984.97 S 1312.92 1154.16 $ 1410.61 1323.35 S 1508.29 1484.22 S 1601.16 0.00 923.37 0.00 1118.74 0.00 1314.10 0.00 1428.02 Target #1 0.00 1509.47 0.00 1704.84 0.00 1900.20 0.00 2085.95 Target #2 RECEIVED S EP 2 6 1994. A. taska Oil & Gas Cons, Commission Anchorcse ALL data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from RKB (127.00 Ft above mean sea Level). Vertical section is from wellhead on azimuth 210.00 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL PROPOSAL LISTING Page 2 ANNA Platform,3 Rd#1 Your ref : 3 Rd #1 Version Granite Point Field,Cook Inlet, Alaska Last revised : 20-Sep-94 Comments in wel[path MD TVD Rectangular Coords. Comment 8000.00 7956.22 83.79 S 731.11W KOP - Sidetrack Pt 87-55.61 8662.51 218.74 S 870.54 W End Build & Turn 10791.54 10555.00 914.43 S 1272.20 W Target #1 12475.40 12105.00 1484.22 S 1601.16 W Target #2 Targets associated with this wel[path Target name Position T.V.D. Local rectangular coords. Date revised 3Rd Tgt#2 Revised not specified 12105.00 1348.00S 1615.00~ 5-Jul-94 3Rd Tgt#1 Revised not specified 10555.00 948.00S 1220.00~ 27-Jun-94 RECEIVED SEP 2 6 199q A~ssk~ Llil & Gas Cons. Commission Anchor~,~e All data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from RKB (127.00 Ft above mean sea [eve[). Bottom hole distance is 2183.26 on azin~Jth 227.17 degrees from wellhead. Total Dogleg for we[[path is 18.39 degrees. Vertical section is from we[[head on azimuth 210.00 degrees. Declination is 0.00 degrees~ Convergence is -1.14 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ Grani UNOCAL ANNA Platform,3 Rd#1 te Point Field,Cook Inlet, Alaska Measured Inclin. Azimuth True Vert. Depth Degrees Degrees Depth 8000.00 10.50 262.00 7956.22 8100.00 11.31 249.46 8054.43 8200.00 12.56 238.98 8152.28 8300.00 14.15 230.60 8249.58 8400.00 15.97 223.97 8346.15 8500.00 17~94 218.72 8441.80 8600.00 20.04 214.50 8536.36 8700.00 22.21 211.07 8629.63 8735.61 23.00 210.00 8662.51 9000.00 23.00 210.00 8905.88 9500.00 23.00 210.00 9366.13 1.0000.00 23.00 210.00 9826.38 10500.00 23.00 210.00 10286.64 10791.54 23.00 210.00 10555.00 11000.00 23.00 210.00 10746.89 11500.00 23.00 210.00 11207.14 12000.00 23.00 210.00 11667.39 12475.40 23.00 210.00 12105.00 . RECTAN COORD ! 817.79 S 822.50 S 831.55 S 844.91 S 862.57 S 884.50 S 910.64 S 940.95 S 952.?4 S 1042'.20 S 1211.40 S 1380.59 S 1549.78 $ 1648.43 S 1718.97 S 1888.16 S 2057.35 S 2218.22 S PROPOSAL LISTING Page 1 Your ref : 3 Rd #1 Version Last revised : 20-Sep-94 G U L A R Dogleg Vert N A T E S Deg/lOOFt Sect 1371.11W 0.00 438.12 KOP - Sidetrack Pt 1389.32 W 2.50 451.30 1407.82 W 2.50 468.39 1426.59 ~ 2.50 489.35 1445.59 ~ 2.50 514.14 1464.78 W 2.50 542.72 1484.12 W 2.50 575.03 1503.59 ~ 2.50 611.02 1510.54 W 2.50 624.70 End Build & Turn 1562.19 ~ 0.00 728.01 1659.88 W 0.00 923.37 1757.56 W 0.00 1118.74 1855.24 g 0.00 1314.10 1912.20 ~ 0.00 1428.02 Target #1 1952.92 ~ 0.00 1509.47 2050.61 ~ 0.00 1704.84 2148.29 W 0.00 1900.20 2241.16 ~ 0.00 2085.95 Target #2 RECEIVED SEP 2 6 i99q. A~SKa U~I & Gas Cons. Commission Anchor~,.;e. All data is in feet unless otherwise stated Coordinates from NE Corner of Sec. 12, TION, R12~ SM and TVD from RK8 (127.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 210.00 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Platform,3 Rd#1 Granite Point Field,Cook Inlet, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 2 Your ref : 3 Rd #1 Version Last revised : 20-Sep-94 Con~nents in wellpath COherent 8000.00 7956.22 817.79 S 1371.11W KOP - Sidetrack Pt 8735.61 8662.51 952.74 S 1510.54 W End Build & Turn 10791.54 10555.00 1648.43 S 1912.20 W Target #1 12475.40 12105.00 2218.22 S 2241.16 W Target #2 Targets associated with this wel[path Target name Position T.V.D. Local rectangular coords. Date revised 3Rd Tgt#2 Revised not specified 12105.00 2082.00S 2255.00W 5-Jul-94 3Rd Tgt#1 Revised not specified 10555.00 1682.00S 1860.00~ 27-Jun-94 RECEIVED SEP 2 6 1994 Alaska 0ii & Gas Cons. Commission Anchor;.~.~ All data is in feet unless otherwise stated Coordinates from NE Corner of Sec. 12, TION, R12~ SM and TVD from RKB (127.00 Ft above mean sea level). Bottom hole distance is 2183.26 on azimuth 227.17 degrees from wellhead. Total Dogleg for wellpath is 18.39 degrees. Vertical section is from wellhead on azimuth 210.00 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL Sfructure : ANNA Piafform Field : Granite Point Field Well : 3 Rd#1 Location : Cook Inlet, Alaska I I V 930O 11400 K0P - S~detxack Pt 22.60 End gt~d & Turn 3~d Tgti~l Revised 0 300 600 900 1200 1500 1800 2100 2400 Scale 1 : 150.00 Vertical Seclfon on 210.00 aztmulh wllh reference 0.00 N, 0.0~ E from $1o1 #1-6 Point KOP End of Build Target 'orget ..%Rd Tgt~2 Revised WELL. PROFILE DATA MD Inc Olr TVD North 8000 10.50 262.00 7956 -84 8736 25.00 210.00 8662 -219 10792 23.00 210.00 10555 -914 12475 25.00 210.00 12105 -1484 East Beg/lO0 -731 0.00 -870 2.50 -1272 0.00 -1601 0.00 Wesf ,~o,,,: 75.00 1050 900 750 §00 450 ,, $ 3Rd Tgt~l Rev~e~ RECEIVED SEP 2 6 1994 Alaska Oil & Gas Cons. Commission Anchorage 150 0 ~ O Created by : jones Date plotted : 20-Sep-94 Plot Reference is 3 Rd#1 Version #3 Coordinates ore in feet reference slot #1-6. True Vertical Depths ore reference RKB. --- Baker Hughes INTEQ --- I I V 1650 85O gOO g50 _ <-- West 1600 1550 1500 14,501400 1350 1500 1250 1200 1150 1100 1050 1000 UNOCAL Structure : ANNA Platform Well : $ Rd#1 Field : Granite Point FieldLocation : Cook Inlet, Alaska Created by : jones Dete plotted '. 20-Sep-94 Plot Reference is 3 Rd #1 Version #3. Coordinates ore in feet reference slot #1-6.' True Vertical Depths are reference RKB. --- Baker Hughes INTEQ --- ,.Scale 1 : 25.00 950 900 ~o s00 750 7~ e50 ~400 o I I V 1550 1650 1600 1550 150(31450 1400 1350 1300 t250 1150 1100 1050 WeSt 8O0 7~ 7~ 850 $COI~ 1 : 2~.00 ECEIVED 2 6 1994 Gas Cons. Commission - _,,00 Anchorage 1550 EXHIBIT 1 - PLAT MAP UNOCAL J Structure · ANNA Platform Well · 3 Rd#1 !,... . Field · Granite Point Field Location · Cook Inlet, Alaskai <-- West Scale 1:100.00 5400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 2oo_ _2oo ~ I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t I I I - NE 1/4 SECTION (12, TION, R12W, SM) '~' I 73,4,' FNL 840' FWL 8u~d ,~ Turn I_ -- I_ I_ · NW 1/4 SEGIION --, SW 1/4 SECTION SE '~/4 SECTION -- _, I I I I I I I I I I [ I I I I I I I I I I I I I I I I I I I I I I I I I 0 200 _ 2o0 b 0 . . . 4O0 40O 600 600 800 800 - ' - C) ,200_ - - - I - - 2000_ _2~ - _ 2200_ _~ - _ 2~0_ _2~ . 2~0_ 2800_ 3000_ _~ 3~0 3200 ~O~ 2800 2~ 2~0 ~ 2~ 1~ 1800 1 ~ 1200 1000 8~ B00 ~ 200 O 200 <-- West oo.oo SEP 2 Fo ~99~ A~as~ Uf~ & Gas GoDs. Gommission ADcborag~ JCreoted by : jones .Date plotted : 22-Sep-94 IPlot 3 Rd ~1 Version #3. Reference is Coordinates ore in feet reference NE Comer of Sec. 12, T10N, R12W SM. True Vertical Depths are reference RKB. --- Baker Hughes INTEO --- UNOCAL ANNA Platform 3 Rd#1 slot #1-6 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 3 Rd #1 Version #3 Our ref : prop1066 License : Date printed : 12-Aug-94 Date created : 27-Jun-94 Last revised : 6-Jul-94 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 58 44.738,w151 18 33.113 Slot location is n60 58 37.510,w151 18 46.082 Slot Grid coordinates are N 2551408.201, E 266811.833 Slot local coordinates are 734.00 S 640.00 W Reference North is True North RECEIVED cOEp '~ 9 1994 Gas Cons. Commission Anchor~,~ Grani UNOCAL ANNA Platform,3 Rd#1 te Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 3 Rd #1 Version Last revised : 6-Jul-94 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 8000.00 10.50 262.00 7956.22 83.79 S 731.11 W 0.00 438.12 8100.00 11.31 249.46 8054.43 88.50 S 749.32 W 2.50 451.30 8200.00 12.56 238.98 8152.28 97.55 S 767.82 W 2.50 468.39 8300.00 14.15 230.60 8249.58 110.91 S 786.59 W 2.50 489.35 8400.00 15.97 223.97 8346.15 128.57 S 805.59 W 2.50 514.14 8500.00 17.94 218.72 8441.80 150.50 S 824.78 W 2.50 8600.00 20.04 214.50 8536.36 176.64 S 844.12 W 2.50 8700.00 22.21 211.07 8629.63 206.95 S 863.59 W 2.50 8735.61 23.00 210.00 8662.51 218.74 S 870.54 W 2.50 9000.00 23.00 210.00 8905.88 308.20 S 922.19 W 0.00 542.72 575.03 611.02 624.70 End Build & Turn 728.01 9500.00 23.00 210.00 9366.13 477.40 S 1019.88 W 0.00 10000.00 23.00 210.00 9826.38 646.59 S 1117.56 W 0.00 10500.00 23.00 210.00 10286.64 815.78 S 1215.24 W 0.00 10791.54 23.00 210.00 10555.00 914.43 S 1272.20 W 0.00 11000.00 23.00 210.00 10746.89 984.97 S 1312.92 W 0.00 923.37 1118.74 1314.10 1428.02 Target #1 1509.47 11500.00 23.00 210.00 11207.14 1154.16 S 1410.61 W 0.00 12000.00 23.00 210.00 11667.39 1323.35 S 1508.29 W 0.00 12475.40 23.00 210.00 12105.00 1484.22 S 1601.16 W 0.00 1704.84 1900.20 2085.95 Target #2 RECEIVED SEP 1 9 199~ Oil & Gas CoDs. Commissi.on ' ~nchor~b~ All data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from wellhead (105.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 210,00 degrees. Declination is 0.00 degrees~ Convergence is -1.14 degrees. Calculation uses the minimum curvature methed. Presented by Baker Hughes INTEQ UNOCAL PROPOSAL LISTING Page 2 ANNA Platform,3 Rd#1 Your ref : 3 Rd #1 Version Granite Point Field,Cook Inlet, Alaska Last revised : 6-Jul-94 Comments in wellpath MD TVD Rectangular Coords. ConTnent 8735.61 8662.51 218.74 S 870.54 W End Build & Turn 10791.54 10555.00 914.43 S 1272.20 W Target #1 12475.40 12105.00 1484.22 S 1601.16 ~ Target #2 Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 3Rd Tgt#1 Revised not specified 10555.00 948.00S 1220.00~ 27-Jun-94 3Rd Tgt#2 Revised not specified 12105.00 1348.00S 1615.00~ 5-Jul-94 RECEIVED S EP ~ 9 199~ A_~aska, Oil .& Gas Cons. Commission '~,, Anchor~_~ ALL data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from wellhead (105.00 Ft above mean sea Level). Bottom hole distance is 2183.26 on azimuth 227.17 degrees from wellhead. Total Dogleg for wellpath is 18.39 degrees. Vertical section is from wellhead on azimuth 210.00 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ,.ELL PERMIT CHECKLIST GEOL ~ F~L~ UNIT# PROGRAM: exp [] dev [] redrll /f.J, ~6~7, ON/OFF serv [] ADMINISTRATION 1 2 3 4 5 6 '7 8 9 l0 11 12 13 ENGINEERING · Permit fee attached ................... · Lease number appropriate ................ Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ........ ...... Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... N N N N N N N N N 14. Conductor strin9 provided ............... ~ N 15. Surface casing protects all know~USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf cs9. ~_~ N 17. CMT vol adequate to tie-in lon9 string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ i~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate ........... ~ 24. Drilling fluid program schematic & equip list adequate .'Y~ N 25. BOPEs adequate ...................../';~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... (~ N 29. Is presence of ~2S 9as probable ............. Y ~ . ,,- · GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y Z 32. Seismic analysis 9f shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ......... / N 34. Contact name/phone for weekly progress reports .... /K Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: Z , ELL PERMIT CHECKLIST FIELD & pOOL ~--~O/~--~ WELL NAME UNIT# PROGRAM: exp [] dev [] redrll~' aery [] ADMINISTRATION APPR DATE . ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... ~ N Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool .............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without admi~st~:~ve approval. · .yY~ ~ Can permit be approved before 15- y ' . ...... APPR DATE 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg. . Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... Y~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N A 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate ........... ~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to .~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y N 28. Work will occur without operation shutdown ........ Y N 29. Is presence of H2S 9as probable ............. Y N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N/ 32. Seismic analysis of shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ......... t/N ' 34. Contact name/phone for weekly progress reports .... ~Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~W'~ BEW DWJ JDH BAD Comments / Instructions: TAB 'HOW/jo - A:~FORMS~cheklist rev 03/94
