The URL can be used to link to this page

Home My WebLink About194-041MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-35 PRUDHOE BAY UNIT 13-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 13-35 50-029-22460-00-00 194-041-0 W SPT 8017 1940410 2004 1408 1408 1408 1409 129 148 147 148 4YRTST P Austin McLeod 8/3/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 13-35 Inspection Date: Tubing OA Packer Depth 42 2255 2223 2210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804185800 BBL Pumped:3.1 BBL Returned:1.4 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:14:13 -08'00' MEMORANDUM TO: Jim Regg�1��2ZsZ'� P.I. Supervisor �( FROM: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT 13-35 Insp Num: mitBDB210803134358 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-35 PRUDHOE BAY UNIT 13-35 Sre: Inspector Reviewed By P.I. Supry Comm API Well Number 50-029-22460-00-00 Inspector Name: Brian Bixby Permit Number: 194-041-0 Inspection Date: 8/3/2021 / Pretest Packer Depth Well 13-35 Type Inj w - TVD 8017 ' Tubing PTD 1940410 Type Test sP'r'Test psi 'I 2004 IA BBL Pumped:2 BBL Returned: 1.2 - OA InterVal 4YRTST --- P/F P --- Notes: j Pretest Initial 15 Min 30 Min 45 Min 60 Min 1588 ' r 1586 - 1588- 1588—-- 253 2364 2344 - 2344 154 - 178 178 177 j Thursday, August 5, 2021 Page I of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,August 30,2017 ((( P.I.Supervisor l )) 5 34/ SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 13-35 FROM: Chuck Scheve PRUDHOE BAY UNIT 13-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 0j�'— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-35 API Well Number 50-029-22460-00-00 Inspector Name: Chuck Scheve Permit Number: 194-041-0 Inspection Date: 8/28/2017 v Insp Num: mitCS170829084802 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-35 ' Type Inj W TVD 8017 Tubing 824 - 824 - 824 - 824 PTD 1940410 Type Test SPT Test psi 2004 " IA 80 2290 2265 - 2261 - BBL Pumped: 1.1 BBL Returned: 1.3 OA 177 179 - 181 181 Interval 4YRTST P/F P Notes: SCANNED ;:-EE; 2 Wednesday,August 30,2017 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 }g August 10, 2012 — 0�-� I \ f3 N',� Mr. Jim Regg 2.012 Alaska Oil and Gas Conservation Commission atjG �- 333 West 7 Avenue �o Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -13 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10404) DS -13 Date: 10131/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13 -02B 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13-03A 2090480 50029203250100, Sealed conductor NA NA NA NA NA 13 -04 1780630 50029203260000 Sealed conductor NA NA NA NA NA 13-05 1811030 50029206260000 Sealed conductor NA NA NA NA NA 13 -06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13-07 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13-08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13-09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13-10 1811650 50029206780000 Sealed conductor , NA NA NA NA NA 13 -11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 13 -12 1801420 50029205380000 Sealed conductor NA NA NA NA NA 13 -13A 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13-14 1621710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 -15 _ 1821570 50029208310000 Sealed conductor NA NA NA NA NA 13-16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 -17 1820260 50029207180000 Sealed conductor NA NA NA NA NA 13-18 1820350 50029207240000 Sealed conductor NA NA NA NA NA 13 -19 1811800 50029206900000 Sealed conductor NA NA NA NA NA 13 -20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13 -21 1820530 50029207890000 Sealed conductor NA NA NA NA NA 13 -22 1820770 50029207490000 Sealed conductor NA NA NA NA NA 13 -23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13 -24A 2042430 50029207390100 Sealed conductor NA NA NA NA NA 13-25 1820910 50029207610000 Sealed conductor NA NA NA NA NA 13 -26 1820740 50029207460000 Sealed conductor NA NA NA NA NA 13 -27 1961210 50029209490200 17.0 NA 17.0 NA 130.9 11/22/2009 13 -28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 -29L1 2020690 50029209286000 Dust Cover NA NA NA NA NA _ 13-30C 2080870 50029207680300 Sealed conductor NA NA NA NA NA 13-31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 13-32A 2012350 50029207980100 0.0 NA 0.0 NA 10.2 10/31/2011 13-33 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 13 -34 1821360 50029208110000 0.3 NA 0.3 NA 11.1 _ 10/31/2011 X 4 13 -35 1940410 50029224600000 0.9 NA 0.9 NA 5.1 11/17/2009 13 -36 1951670 50029226130000 0.0 NA 0.0 NA 4.3 10/31/2011 13 -37 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 50029208780000 1.0 NA 1.0 NA _ 5.1 10/6/2009 STATE OF ALASKA APR ~ 0q sKA~ AND GAS CONSERVATION COMMISS~ I~~~ORT OF SUNDRY WELL OPERATIONS 1. Operations ell ^ Plug Perforations Stirrlulate ^ Other 0 SAND PLUG SET ~ Performed: Alter Ca , Pull Tubing^ Perforate New Pool ^ ~.2~~1,'Vaiver^ Time Extension ^ 10002' Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ -~ /~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 194-0410 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ API Number: Anchorage, AK 99519-6612 50-029-22460-00-00 8. Property Designation (Lease Number) : \ 9. Well Name and Numbe~ ADLO-028315 PBU 13-35 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 10250 feet Plugs (measured) 10002' 4/24!10 feet true vertical 9210.17 feet Junk (measured) None feet Effective Depth measured 10103 feet Packer (measured) 8937' true vertical 9076.83 feet (true vertical) 8018' Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE - 110 SURFACE - 110 1490 470 Surface 3562 9-5/8" 47# NT-80 SURFACE - 3495 SURFACE - 3528 6870 4760 Intermediate Production 10189 5-1/2" 17# L-80 SURFACE - 10221 SURFACE - 9184 7740 6280 Liner Liner Perforation depth: Measured depth: 10080 -10100 = _ _ True Vertical depth: 9055.97 - 9074.11 _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.3# L-80 31' - 9046' 31' - 8117' P Packers and SSSV (type, measured and true vertical depth) 5-1/2"X3-1/2" BKR SABL-3 PKR 8937' ~ 8018' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 4858 1248 Subsequent to operation: 1052 1407 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^r Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ ^ 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: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 4/28/2010 13-35 194-041 • Sw Name Operation Date Perf Operation Code PERF ATTACHME Meas Depth Top NT Meas Depth Base Tvd Depth Top Tvd Depth Base 13-35 6/9/94 PER 10,080. 10,100. 9,055.97 9,074.11 13-35 9/23/99 APF 10,047. 10,063. 9,026.04 9,040.55 13-35 9/23/99 APF 10,068. 10,077. 9,045.09 9,053.25 13-35 12/29/01 FIL 10,088. 10,100. 9,063.23 9,074.11 13-35 9/26/04 BPS 9,903. 9,913. 8,895.43 8,904.5 13-35 8/2/08 BPP 9,903. 9,913. 8,895.43 8,904.5 13-35 8/12/08 BPS 9,017. 10,100. 8,090.56 9,074.11 13-35 6/27/09 BPP 9,017. 10,100. 8,090.56 9,074.11 13-35 8/2/09 APF 9,954. 9,969. 8,941.68 8,955.29 13-35 4/23/10 BPS 10,011. 10,100. 8,993.39 9,074.11 13-35 4/24/10 SPS 10,002. 10,011. 8,985.22 8,993.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE r1 U • 13-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/21/2010 `** WELL INJECTING ON ARRIVAL *** I B&F TBG WITH 3 1/2" BLB, 2.70" G-RING SD @ 9014' SLM, 9028' MD (XN NIPP 2.635" ID) RAN 3 1/2" BLB, 2.50" G-RING, TAG TD @ 10058' SLM, STKY BTM LRS LOADED TBG WITH 290 BBLS 1%KCL, 50 BBLS DIESEL FOR FREEZE .PROTECT 1 ***CONT ON 4-22-10 WSR*** 4/21 /2010 T/I/0=1900/420/3204 Assist slick line; Brush & flush (Profile Mod) Pumped 2 bbls neat meth to freeze protect F/L to lateral valve, Pumped 2 bbls neat meth ,and 235 bbls 180* diesel for brush and flush. Pumped 290 bbls of 1%KCL and 52 abbls diesel to load well for caliper. FWHPs= 800/0/280. Valve positions at time of departure; SV open (slick line on well), WV shut, SSV open, MV open, IA open, OA open. 4/22/2010***CONT FROM 4-21-10 WSR*** RAN PDS 24 ARM EXTENDED REACH CALIPER FROM 10,051' SLM TO SURFACE RAN 2.5" CENT, TEL & SAMPLE BAILER....TAG TT @ 9024' SLM +22' CORR. TO 9046' MD....STOP @ 9998' SLM (10,020' MD)...FLAG WIRE RAN BAKER IBP TO 9998' SLM, 10020' MD TOOL DID NOT RELEASE FROM ..IBP LEFT BAKER IBP AND SETTING TOOL IN HOLE (OAL 34' LEFT IN HOLE) ATTEMPTING TO FISH BAKER SETTING TOOL _ "**CONT ON 4-23-10 WSR*** 4/22/2010, T/I/0= 1200/0/160 Temp=S1 Assist SSL, Displace 1 %KCL from Tbg (Pull IBP). PPumped 100 bbls diesel down Tbg to load. Final WHPs 1400/0/160 ~Slickline on well a time of departure 4/23/2010 ***CONT FROM WSR 04-22-10*** (profile mod) ~_____~~__.__~ ;PULLED BAKER IBP SETTING TOOL FROM 9976' SLM RAN 2.50" LIB TO IBP @ 9989' SLM, 10011' CORRECTED ELMD (IMPRESSION OF IBP FISH NECK) CURRENTLY DUMP BAILING SLUGGITS ON IBP ~ 9989' SLM, 10011' MD ***CONT ON 4-24-10 WSR*** TREE _ ~ CIW WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = ~ 82 BF. ELEV = KOP = 1738' Max Angie = 39° ~a 2789' Datum MD = 9888' Datum TV D = 8800' SS ~ 13-35 31' -j4-112" X 3-1/2" XO, ID = 2.992"' 2017' 3-112" HES X NIP, ID = 2.813" 9-518" CSG, 47#, NT-80 BTC, ID = 8.681" I-I 3495' Minimum ID = 2.75" @ 8972' 3-1 /2" HES XN NIPPLE 7968' - -{5-1/2" 5WS X NIP, MILLED OUT TO 4.75" (06/20/09) $906' 3-112" HES X NIP, ID = 2.813" $937' 5-112" X 3-1/2" BKR SABL-3 PKR w /ANCHOR, ID = 2.79" $972' 3-112" HES X NIP, ID = 2.813" $9$4' ~--~ 5-112" OTIS XN NIP, ID = 4.455" 3-112" HES XN NIP, ID = 2.75" 3-112" TBG, 9.2#, L-80 TCII, .0087 bpf, I- j g046, ID = 2.992" 9046' ~--I3-112" WLEG, ID = 2.992" 9773' I-j5-112" MARKER JOINT PERFORATION SUMMARY REF LOG: MWD ON 03131198 ANGLE AT TOP PERF: 25° @ 9954' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnJSgz DATE 2" 6 9954 - 9969 O 08/02/09 2-118" 6 10047 - 10063 O 09/23/99 2-1/8" 6 10068 - 10077 O 09123/99 3-3/8" 6 10080 - 10100 O 06/09/94 PBTD 10103' 5-1/2" CSG, 17#, L-80 LTC MOD, ID = 4.892" 10221' ~~ S}Bf ~ lo,ozo ' ~-o DATE REV BY COMMENTS DATE REV BY COMMENTS 04/01!94 ORIGINAL COMPLETION 09/28/09 RRD/SV ADPERF (08/02/09) 04/04!94 LAST WORKOV ER 06/22!09 D16 RWO 06/28109 TLH DRLG HO CORRECTIONS 07103!09 JH/TLH NOT CHROME NIPPLES 07/14/09 DB/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 13-35 PERMff No: 1940410 API No: 50-029-22460-00 SEC 14, T10N, R14E, 1521' FSL & 1411' FEL BP Exploration (Alaska} ~~~~~~~ N0.5468 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gembell Street, Suae 400 Alaska Oil & GeS Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 0 Log Description Date BL Color CD 13.35 BBKA-00005 CROSS FLOW CHECK 02/07/10 1 1 A-02 AWJI-00072 MEMORY PROD PROFILE - 01/31/10 1 1 M-08 AYTO-00035 CROSS FLOW CHECK - 02/07/10 1 1 V-123 4-38/K-34 AWJN-00033 AWJI-00070 SCMT -~ C MEMORY PROD PROFILE 01/15H0 02/02/10 1 1 1 1 Y-36 AYKP-00061 RST 01/14/10 1 1 F-40 AZCM-00053 RST 12/29/08 1 1 01-14A P1.24L1-01 AWJF00067 12034915 MCNL OH LDWG EDIT (FLEX 01/07/10 - 08/12/08 1 1 1 1 V-224 09AKA0147 OH MWDA.WD EDIT 12/08/09 2 1 BP Exploration (Alaska)Inc.,.~V". ~ y•V,V,•„•~~„V ~~~~..~.","V V,•~yVrr ~.,..., ~~. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Slreel, Suite 400 Anchorage, AK 99503-2a39 ovt zrt n C ~Ch~!l1t1~~P~~l' Alaska Data & Consulting Services 2525 Gambell Street, Suite 4lM Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO. 5460 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 13-35 6148-00084 INJECTION PROFILE ~ Z-27 B3S0-00043 - GLS - Q 11/10/09 1 1 17-09 BSJN-00031 LDL - Q 01/07!10 1 1 05-38 AYKP-00063 PRODUCTION PROFILE - 01/11/10 1 1 P2-52 82NJ-00050 MEMORY XY CALIPER - 01/21/10 01/24/10 1 1 17-09 AGI-Ot AYKP-00064 BBKA-00003 USIT - / USIT (> - C 01/22/10 1 1 1 1 01-19B AWJI-00062 MCNL _. 01/18/10 1 1 H-13A 82NJ-00042 __ MCNL t{ 12/03/09 1 1 07-26 BALL-00007 RST ~ p 11/29/09 1 1 07-19A 2-14/0-16 83S0-00036 AZCM-00050 RST .-(~ RST (o - r 12/08/09 12/25/09 1 1 1 P1-24L1 12034915 OH LDWG EDIT (FLEX Q 12/08/09 1 1 W-217 09AKA0091 OH MWD/LWD EDIT 08/08/08 1 1 W-217 PBi 09AKA0091 ~ OH MWD/LWD EDIT 11/23/09 11/15/09 2 2 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH TOE ~~ ~xNwiauun iruasKa~ uic. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Jai'' ~~ ~ ~~ ~ ~~~ ~C~- Alaska Data & Consulting Services • 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 .. ~ , ~ . ~ ~w~9ti~~, ~ . _ ._a schlumberger NO. 5436 r t ZDD Alaska Data &Consulting Services t AN Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPC -04 AXBD -00061 MEMORY =GLS — 11/17/09 1 1 NK -38A AWJI -00057 MEM PROD PROFILE L — 11/04/09 1 1 14 -12 B3S0 -00033 PRODUCTION PROFILE 11/13/09 1 1 13 -35 B14B -00084 INJECTION PROFILE () 11/10/09 1 1 06 -08A B14B -00082 PLUGBACK SET W /X -FLOW CHECK — — 11108/09 1 1 H -30 AVIH -00031 PRODUCTION PROFILE 11/14/09 1 1 18 -11A B2NJ -00038 MEM CNL & SCMT 111/06/09 1 1 Y -23B AYKP -00055 GLS - - e- a 11/22/09 1 1 N -24 AYS4 -00109 PRODUCTION PROFIL / - 11/08/09 1 1 02 -31A AYKP -00053 PRODUCTION PROFILE 11/15/09 1 1 03 -01 B8K5 -00014 PRODUCTION PROFILE 1 - 11/24109 1 1 L -213 B581 -00017 INJ PROFILE W/WFL 11/19109 1 1 W -209 AYKP -00054 INJ PROFILE W/WFL - 11117/09 1 1 X -05 AP30 -00072 PRODUCTION PROFILE — 11/29/09 1 1 X -07 AYS4 -00111 PRODUCTION PROFILE Q — 11/27/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 131 Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ~ MEMORANDUM To: Jim Regg P.I. 5upervisor ~ ~ ~ ~ ~~ ~ ~1,~ l FROM: Jeff Jones Petroleum Inspector State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Friday, September 11, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-35 PRUDHOE BAY UNIT 13-35 Src: lnspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~r~` Comm Well Name: pRUDHOE BAY L1NIT 13-35 API Well Number: 50-029-22460-00-00 Inspector Name: JeffJones Insp Num: mitJJ090824091205 Permit Number: 194-041-0 ~ Inspection Date: 8~20/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - 13-35 T --- TYPe Inj. I G~ 'j'~ 8019 ~ jA Well T P.T.Di ~940410 TypeTest SPT i~Test psi i zoo~OA ~ -~~----- - ------ ~ 340 I 2210 zzo ~-zzo ' 2200 2200 z2o , zzo - ~ -~ Interval Irr~T~- p/F P__ '~ Tubin~ _ 9zo 9zo -~- 9zo 9zo ~-_~_ -~ - NoteS• 1 BBL 60/40 methanol pumped. I well inspected; no exceptions noted. ~}ry ~,ti,'~}'s .~~ , r "` _ _ L~J~}'~:,i ~ ~.~. Friday, September I 1, 2009 Page 1 of 1 ., ~ ~m ~ \~~~~ STATE OF ALASKA - , ALAS OIL AND GAS CONSERVATION COMM~ON '~~~ ~.~' ~~~ f~~a~~~ ~. REPORT OF SUNDRY WELL OPERATIONS~~d=. t~~~.~ ~~~: a,a `,, ~,=,~~s~,.~,~;,: 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~` ;;;., ;,:, PerFormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Ciass: 5. Permit to Drill Number: rvame: De~elopment r Exploratory Im 194-0410 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-22460-00-00 7. KB Eievation (ft): 9. Well Name and Number: 82.2 KB PBU 13-35 8. Property Designation: 10. Field/Poo!(s): ADLO-028315 PRUDHOE BAY Fieid/ PRUDHOE BAY Pool 11. Present Well Condition Summary: Total Depth measured 10250 feet Plugs (measured) None true vertical 9210.17 feet Junk (measured) None Effective Depth measured 10103 feet true vertical 9076.83 feet Casing Length Size MD ND Burst Collapse Conductor 80 20" SurFace - 110 SurFace - 110 1490 470 SurFace 3562 9-5/8" 47# NT-80 Surface - 3495 Surface - 3258 6870 4760 Production 10189 5-1/2"17# L-80 SurFace - 10221 Surface - 9184 7740 6280 1,~,=..,14'~t;^°e ~j :~ ` .. ~.. ;tpCy `' , ~w ,..u Ur~ ~ 44 ~UU,.1 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ ` Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 31' - 9046' i W ~°~ -+ ~~ ~ ~~ Ot O O _ ~ Packers and SSSV (type and measured depth) 5-1/2"X3-1/2" BKR SABL-3 PKR 8937' ~,~-~C-~-~,p~ 0 0 ~ ~ 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oi!-Bbl _ Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 2000 1507 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory [^` De~lopment I" Service ~- Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signature - Phone 564-4944 Date 8/6/2009 d~ ~ Form 10-404'Revised 04/2006 ~~-~+~ ~~~ s~i~ ~ e# ~^~°~*~ ~i, _ Submit Original Onty ., ~"g5( i3 r ~;~.- ,a~~/~, /~~ t 13-35 194-041 PERF OTTOCHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 13-35 6/9194 PER 10,080. 10,100. 9,055.97 9,074.11 13-35 9/23/99 APF 10,047. 10,063. 9,026.04 9,040.55 13-35 9/23/99 APF 10,068. 10,077. 9,045.09 9,053.25 13-35 12/29/01 FIL 10,088. 10,100. 9,063.23 9,074.11 13-35 9/26/04 BPS 9,903. 9,913. 8,895.43 8,904.5 13-35 8/2/08 BPP 9,903. 9,913. 8,895.43 8,904.5 13-35 8/12/08 BPS 9,017. 10,100. 8,090.56 9,074.11 13-35 6/27/09 BPP 9,017. 10,100. 8,090.56 9,074.11 13-35 8/2/09 APF 9,954. 9,969. 8,941.68 8,955.29 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ ~~ 13-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY """WELL SHUT-IN UPON ARRIVAL***[PERFORATING E-LINE] INITIAL T/I/0=50/0/0 PERFORATE INTERVAL FROI~I 9954' TO 9969' USING 2" HSD, 2006 POWERJET OMEGA, HMX (6 SPF, 60 DEG PHASING) API PERFO DATA: 21.8" PENETRATION, .22" ENTRANCE HOLE SWAB/SSV/WV--CLOSED; MV--OPEN; CASING VALVES--OPEN TO GAUGES; PAD OPERATOR NOTIFIED FINAL T/I/0=50/0/0 ""*JOB COMPLETE*"" FLUIDS PUMPED BBLS 1 diesel 1 Total STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM SION REP~ OF SUNDRY WELL OPE IONS ~~ 1. Operations PerFormed: p~~~~~~~ ~ l ^ ~ ^ ^ ^ Abandon ~ Repair Well - Re-Enter 5uspen ed We l Stimulate Plug Perforations ^ Alter Casing ~ Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ PerForate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 194-041 - 3. Address: -~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22460-00-00- 7. KB Elevation (ft): 82 2, 9. Well Name and Number: PBU 13-35 - 8. Property Designation: 10. Field / Pool(s): ADL 028315 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10250' - feet true vertical 9210' ~ feet Plugs (measured) None Effective depth: measured 10103' feet Junk (measwred) None true vertical 9077' feet Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 112' __ ., 1 ~.2'.._. 1490 470 SurFace 3562' 9-5/8" 3495' 3258' 6870 4760 I ntermediate Production 10189' S-1/2" 10221' 9184' 7740 6280 Liner r ~ LV UJ >~~~~'4s'`~~~~ .~UL «~ ~ ~ PerForation Depth MD (ft): 10047' - 10100' Perforation Depth ND (ft): 9026' - 9074' 3-1/2", 9.3# L-80 9046' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" BKR SABL 3 packer 8937' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Explor tory ^ Development ~ Service ~ Daily Report of Well Operations ' ~6. Well Status after work: ~ Well Schematic Diagram ^ Oil J Gas [!~ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 309-170 Printed Name Sondra Stewman Title Drilling Technologist ~j~"~ Prepared By Name/Number: D t~ ~` '~ Sig ature a Phone 564-5743 U l Sondra Stewman 564-4750 t ~~.G~~~/~Il~,~~~ Jl1L X 5 ?0~~ ~~6-09 ~ ~an Form 10-404 Revised 04/2006 Submit Original Only ~~IIIIS ~L ~u~ 1 ~ 2ao9 ,~~~`~~~'/~~~'o~ TR~ = FMC NEW STANDARD WELLHEAD = CNV ACTUATOR = BAKER C KB. ELEV = g2~ BF. ELEV = KOP = 1738' Max Angle = 39 @ 2789' Datum MD = 9888' DatumND= 8800'SS DRLG D~FT 9-5/8" CSG, 47#, NT-80, ID = 8.681" ~-~ 3495~ Minimum ID = 2.635" @ 9028' 3-1/2" OTIS XN NO-GO NIPPLE 3-1(2" TBG, 9.3#, L-80, TCII, IQ = 2.992" ~~ 9045' PERFORATION SUMMARY REF LOG: MWD ON 03/31/98 ANGLE AT TOP PERF: 25 @ 10047' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 10047 - 10063 ~ O 09/23/99 2-1/8" 6 10068 - 10077 ~ O 09/23/99 3-3/8" 6 10080 - 10100 ~ O 06/09/94 PBTD 5-1/2" CSG, 17#, L-80, ID = 4.892" SAFETY NOTES: "`*5-1/2" XN NIPPLE (STILI NAS w/5- CO~m TO RECONCIL)E BETWEErI CSG~TALLY & 13 -3 5 COIL COM PLETION TALLY 31' I~ 4-1/2" X 3-112" Xd, ID = 2.992" 2017~ 3-112" Ol'IS X NlP, ID= 2.813" -~ 7968~ 5-1/2" OTIS X NIP, Milled out to 4.75" (DATE`?) - $y4$' 3-1t2" OTIS X NIP, ID= 2.$13" $J3]' 5-112" x 3-1(2" BKR SABL 3 PKR w 1ANGHOR $J76'*'* 5-1/2" OTIS XN NIP (BUT NO 5-1!2" LC}CK MANDREL?), ID = 4.455" ("`SEE SAFEfY NOTE) - $~72' 3-1/2" NES X NlP, ID- 2.75" $Q~"$' 3-1/2" HES XN-Nip, EC~2.635 9046' 3-1;2" CHROME WLEG, Id- 2.992„ ~ ELMD TT NOT LOGGm ~ DATE REV BY COMMQJTS DATE REV BY COMMENTS 04/01/94 ORIGINAL COMPLETION 06/28/09 TLH DRLG HO CORRECTIONS 04/04194 LAST WORKOV ER 07/03/09 JHITLH NOT CHROME NIPPLES 06/10l08 JM/TLH DRAWING/DEPTHS CORRECTION 08/05/08 JCNUPJC PULL PXN @ 8998' (08/02/08) 09/03/08 KGPJC SET PXN @ 9003 (O8/12/O8) O6/22/09 D16 RWO PRUDHOE BAY UNff WElL: 13-35 PERMff No: 1940410 API No: 50-029-22460-00 SEC 14, T10N, R14E, 2311.13 FE12476.94 FNL BP F~cpioration (Alaska) _ ~ °.~ BR'E)CPLC)~RATI~N Page 1 of 7 Qperatia~n~ Sumr~a~y Re~c~rt Legal Well Name: 13-35 Common Well Name: 13-35 Spud Date: 3/24/1994 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 14 Rig Number: Date Frorn - TQ Hours Task Code NRT Phase Description of Uperations 6/12/2009 09:00 - 10:00 1.00 RIGD P PRE Skid rig floor to moving position. 10:00 - 11:30 1.50 MOB P PRE Move rig off well 06-05 and position on pad. 11:30 - 14:30 3.00 MOB P PRE Install front and rear boosters. 14:30 - 17:30 3.00 MOB P PRE Move rig f/ DS 6 to DS 13. 17:30 - 19:00 1.50 MOB P PRE -Set rig mats in front of N-9ES rig. -Move rig to back side of DS 13. Position on pad. 19:00 - 21:00 2.00 MOB P PRE -Remove tront and rear boosters. -Hang mouse hole and cellar doors. -Remove front booster bracing. 21:00 - 23:00 2.00 MOB P PRE -Spot rig over well 13-35. -Shim rig. 23:00 - 00:00 1.00 RIGU P PRE Skid rig floor to drilling position. 6/13/2009 00:00 - 01:00 1.00 RIGU P PRE R/U rig floor -Connect steam, air, water, mud lines and drains. 01:00 - 01:30 0.50 RIGU P PRE -Spot and berm rockwasher -Take on seawater to pits 01:30 - 03:00 1.50 WHSUR P DECOMP -Mobilize lubricator. Install and test same to 500 psi x 5min. -Pull BPV. RD lubricator -SIMOPS: Spot slop tank and RU hardline Acce t ri ~ 02:00 03:00 - 03:30 0.50 WHSUR P DECOMP Finish RU rig floor. 03:30 - 04:30 1.00 WHSUR P DECOMP -RU lines to IA and tree. Install secondary valve in IA -Check hard line with air. Test hardline w/ water to 3500 psi - Pass -Blowdown hardline. RU to reverse circulate 04:30 - 08:00 3.50 WHSUR P DECOMP Dis lace freeze rotect out: -Reverse circulate w/ 20 bbls of hot seawater down IA, taking returns out tubing to slop tank. 4 BPM ~ 960 psi. -Swap lines. Circulate in w/ 60 bbls of hot seawater down tubing, taking returns out IA to slop tank. 6 BPM ~ 1860 psi. -Let diesel migrate x 30 min. -Pump additional 20 bbls hot seawater down tubing, taking retums out IA to slop tank. i -Change lines to take returns to pits. Circulate S/S w/ 180 bbls seawater. 10 BPM ~ 1250 psi. 08:00 - 10:00 2.00 WHSUR P DECOMP -FMC Re d rod in TWC. -Test TWC f/ below to 1000 si x 10 min on chart. Test f/ above to 4000 asi x 10 min on chart. 10:00 - 11:00 1.00 WHSUR P DECOMP ND tree. 11:00 - 15:30 ( 4.501 BOPSUFI P 15:30 - 17:30 I 2.00 I BOPSUF{ P -Barriers: PXN plug ~ 9017', tested TWC in tubing hanger. DECOMP -Install 7-1/16" 5M x 13-5/8" 5M adapter spool. -NU BOP, choke line, riser and flow line. 13-5/8" 5M BOP configuration: -Annular preventer. -3-1/2" x 6" VBR (upper rams). -Blind rams. -Drilling spool (mud cross) w/ choke line and kill line. -2-7/8" x 5" VBR (lower rams). DECOMP RU to test BOP: ; ~. .~ BP EXPLGIRATI4N Page 2 of 7. ap~rations Summary Repo~t Legal Well Name: 13-35 ~,Common Well Name: 13-35 Event Name: WORKOVER Start: 6/10/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 14 Rig Number: ' Date i` From - To l Hours Task , Code NPT Phase I, D+ 6/13/2009 15:30 - 17:30 2.00 17:30 - 00:00 I 6.50 16/14/2009 I00:00 - 00:30 ~ 0.50 00:30 - 01:00 0.50 BOPSUF~P 01:00 - 03:00 2.00 WHSUR ~ P Spud Date: 3/24/1994 End: iption~of ~perati~ns ~~ P DECOMP -MU XOs to 3-1/2" test jt and screw into tubing hanger. MU XOs to floor valves and RU assy. to test. -RU testing equipment. P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 4000 psi high x 5 min each on chart w/ 3-1/2" test jt. Test upper rams w/ 3-1/2" test jt to 250 psi low - 4000 psi high. Test lower rams w/ 2-7/8" & 3-1/2" test jts to 250 psi low - 4000 psi high. Test witnessed by WSL and Tourpusher. Bob Noble, AOGCC Rep, waived witness of test. -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained ~ 33 sec. 4. Full pressure attained l~ 2 min 31 sec. 5. Nitrogen: 4 bottles x 2175 psi avg. DECOMP Cont. testing BOP: test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 2-7/8" test jt. Test witnessed by WSL and Tourpusher. Bob Noble, AOGCC Rep, waived witness of test. P -Summary of BOP test: tested 30 components 1. 13-5/8" annular. 2. 3-1/2" x 6" VBR (upper rams). 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams). 5. HCR valves (kill and choke) 6. Manual valves on kill Iine and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 2-7/8" HT PAC Inside BOP, 2-7/8" HT PAC & 2-3/8" IF FOSV (bail type), Upper and Lower kelly valves (upper and lower top drive IBOP). DECOMP RD testing equipment. DECOMP -RU Dutch system. -Instali lubricator. Test to 500 psi x 5 min. -Pull TWC. RD lubricator. 03:00 - 03:30 0.50 PULL P DECOMP RU to pull tubing hanger: -Remove long bales f/ top drive. -Install short bales and 4" elevators. -PU 1 jt 4" DP. MU XOs. 03:30 - 04:00 0.50 PULL P DECOMP -RIH and screw into tubing hanger. -Pull tubin han er to ri floor. Tubin han er ulled free ri awa . Seals pulled free w/ 155k PUW (blocks weight 50k). PUW 115-120k after seals free (blocks weight 50k). 04:00 - 05:00 1.00 PULL P DECOMP -Pump Safe Surf O pill. -Circulate SlS. 6 BPM ~ 1140 psi. -Mobilize equipment to handle coiled tubing to rig floor while circulating. 05:00 - 06:00 1.00 PULL P DECOMP RU e ui ment to handle 3-1/2" coiled tubin : ~ ~ B~P EXPLQRATION ' Rage 3 of 7 OperatiQns Sur~mary R~port Legal Well Name: 13-35 Common Well Name: 13-35 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date '' From - To Hours Tas'k Code N 6/14/2009 05:00 - 06:00 1.00 PULL P 06:00 - 12:00 ~ 6.00 ~ PULL ~ P Spud Date: 3/24h 994 Start: 6/10/2009 End: Rig Release: 6/22/2009 Rig Number: Phase : Description of Operations' DECOMP -Install air slips and C plate. Install dog collar. -RU hydraulic cutter. DECOMP -Attempt to cut 3-1/2" coiled tubing riqht below tubinq hanqer assy. Hydraulic cutter failed: it split the actuator from the knife body. Send hydraulic cutter to Schlumberger for repair. -Cut 3-1l2" coiled tubin below tubin han er ass . w/ manual pipe cutter. LD tubing hanger, 4" DP jt and XOs.. clamp. -Pull, cut and LD 3-1/2" coiled I 6/15/2009 12:00 - 00:00 I 12.00 I PULL I P 00:00 - 00:30 0.50 PULL P 00:30 - 11:00 10.50 PULL P on coiled tubing. Install cuts w/ manual cutter while h draulic cutter is re aired LD a rox. 30 ieces to this oint . DECOMP -Received repaired hydraulic cutter. RU same. -Cont pulling, cutting and LD 3-1/2" tubing in 15-foot pieces. Making cuts w/ hydraulic cutter. -LD Camco DS nipple w/ flow couplings ~ 3095' per coiled tubing tally dated 6-21-94. -Aprox. 204 pieces LD to this point DECOMP Lubricate rig. Inspect top drive. DECOMP Cont. pulling, cutting and LD 3-1/2" coiled tubing in 15-foot -Observe 20k loss in hook load after LD aprox. 300 pieces (+/- 4500'). Cont. pulling, cutting and LD. -After LD +/- 440 pieces (+/- 6600') observe 3-1/2" coiled tubin I 6/16/2009 11:00 - 12:00 1.00 PULL P DECOMP -RD coiled tubing handling equipment. -Clear rig floor. 12:00 - 12:30 0.50 PULL P DECOMP Lubricate rig. Inspect top drive. 12:30 - 13:00 0.50 FISH P DECOMP Mobilize tools for fishing BHA to rig ftoor. 13:00 - 14:00 1.00 FISH P DECOMP -Mobilize stacked tongs to rig f~oor. -RU to run 2-7/8" HT PAC DP. 14:00 - 15:00 1.00 FISH P DECOMP MU fishing BHA w/ spear + spear extensions + stop sub + bumper sub +jars + 3 jts 3-1/8" DCs + pump out sub. 15:00 - 00:00 9.00 FISH P DECOMP RIH on 2-7/8" HT PAC DP 1x1 f/ 118' to 7372'. 00:00 - 01:00 1.00 FISH P DECOMP -Cont. RIH on 2-7/8" HT PAC DP 1 x1 to 7672'. Tag top of fish. -Enter fish w/ soear extensions until bottom out on stop sub. 01:00 - 04:00 3.00 FISH P DECOMP POOH & LD 2-7/8" HT PAC DP to 4,850' md. -LD 2 7/8" PAC to pipe shed. 04:00 - 04:30 0.50 FISH P DECOMP Lubricate Rig. Inspect & service Top Drive. 04:30 - 09:30 5.00 FISH P DECOMP Continue to POH & LD 2-7/8" HT PAC DP from 4,850' to BHA ~ 118' md. -LD 2 7/8" PAC to pipe shed. 09:30 - 10:30 1.00 FISH P DECOMP LD Fishing BHA: -Bowen Spear, (3) Spear extensions, Spear sub, LBS, Oil Jar, -XO, (3) Drill cotlars, Pump out sub & XO. 10:30 - 12:00 1.50 FISH P DECOMP RU to LD 3 1/2" Coil Tbg. 12:00 - 12:30 0.50 FISH P DECOMP Lubricate Rig. Inspect & service Top Drive. 12:30 - 15:30 3.00 FISH P DECOMP POH w/ 3 1/2" Coil Tbg. -Cut & LD Coil Tbg in 15' lengths. -Recovered +/- 500' of Coil Tbg. ~ BP EXPLC~RATlQN Page 4 of 7 Op~erafiiQns Summary Report Legal Well Name: 13-35 Common Well Name: 13-35 Spud Date: 3/24/1994 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description: of Qperations 6/i 6/2009 15:30 - 16:00 0.50 FISH P DECOMP Clear Rig Floor. 16:00 - 16:30 0.50 FISH P DECOMP RU to run 2 7/8" PAC DP. 16:30 - 17:00 0.50 FISH P DECOMP P/U Fishin BHA: -Bowen Spear, (3) Spear extensions, Spear sub, LBS, Oil Jar, -XO, (3) Drill collars, Pump out sub & XO. 17:00 - 23:30 6.50 FISH P DECOMP RIH on 2-7/8" HT PAC DP 1x1 to +/- 7,450' md. 23:30 - 00:00 0.50 FISH P DECOMP Slip & Cut 59.5' of 1 1/4" Drilling Line. 6/17/2009 00:00 - 01:30 1.50 FISH P DECOMP Continue to Slip & Cut 51.5' of 1 1/4" Drill Line. -Service & inspect Top Drive & Blocks. 01:30 - 02:30 1.00 FISH P DECOMP Continue to RIH on 2 7/8" HT PAC DP 1x1 to +/- 8,200' md. -Obtain parameters: PUW 127k, SOW 110k. 02:30 - 03:00 0.50 FISH P DECOMP Taa Fish ~ 8,242 md. Enqage Fish w/ 10k down wt. -Noted 4k overpull on PU wt. -PUW 131k, SOW 112k. 03:00 - 10:00 7.00 FISH P DECOMP -P 1x1 singles. 10:00 - 11:00 1.00 FISH P DECOMP LD Fishing BHA: -Bowen Spear, (3) Spear e~ensions, Spear sub, LBS, Oil Jar, -XO, (3) Drili collars, Pump out sub & XO. -No Fish --Grapple does not look like it has been inside fish. 11:00 - 11:30 0.50 FISH P DECOMP Clear Rig Floor. 11:30 - 12:00 0.50 FISH P DECOMP P/U Fishin BHA: -Bowen Spear, (3) Spear extensions, Spear sub, LBS, Oil Jar, -XO, (3) Drill collars, Pump out sub & XO. 12:00 - 12:30 0.50 FISH P DECOMP Lubricate Rig. Inspect & senrice Top Drive & Blocks. 12:30 - 18:30 6.00 FISH P DECOMP I 2 7/8" HT PAC DP 1x1 to +/- 8,200' md. 18:30 - 19:00 0.50 FISH P DECOMP Obtain parameters: PUW 135k, SOW 115k -Ta Fish ~ 8 242' md. Run in 9' to NO-GO ~ 8 251' md. -Sat Down 10k. -Noted 15k over ull on PU wt to 150k. Fish came Free. -PUW 140k, SOW 117k. 19:00 - 00:00 5.00 FISH P DECOMP -POH, LD 2 7/8" HT PAC DP 1 x1 singles. -~ 7,230' md: - String weight was +/- 128k. -While POH, string wt spiked to 150k then dropped off to 125k. ~ -Stopped and observed situation. -Continue POH to 3,000' md. 6/18/2009 00:00 - 00:30 0.50 FISH P DECOMP Lubricate Rig. Service & inspect Top Drive & Blocks. 00:30 - 03:00 2.50 FISH P DECOMP Continue to POH. -LD 2 7/8" PAC DP 1 Xi to pipe shed from 3,000' to BHA ~ 118' md. 03:00 - 03:30 0.50 FISH P DECOMP LD Fishing BHA: -XO, P.O.S., (3) D.C's, XO, Oil Jar & L.B.S.. 03:30 - 04:00 0.50 FISH P DECOMP RU to cut & LD Coil Tbg in 15' lengths. 04:00 - 07:30 3.50 FISH P DECOMP Cut & LD Coil Tb Fish. -Recovered all Coil Tbg and Seal assembly. -Missmg e ast . o u e oe. 07:30 - 08:30 1.00 FISH P DECOMP Clear Rig floor of Coil Tbg equipment. 08:30 - 09:30 1.00 FISH P DECOMP Clean Rig fioor. 09:30 - 11:00 1.50 FISH P DECOMP Break old Spear off Spear assembly. -MU new BHA: 5" GS Spear, L.B.S., Oii Jar, XO, (9) 3 1/8" ~ ~ ` BP E~fPLC3RATIaN Page 5 of 7' t3perations Summary Rep~ort Legal Well Name: 13-35 Common Well Name: 13-35 Spud Date: 3/24/1994 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 14 Rig Number: ~a~e Frvm - To Hnurs Task Cade NPT Phase Description' of Operations~ 6/18/2009 09:30 - 11:00 1.50 FISH P DECOMP -P.O.S. & XO. to 285' md. 11:00 - 12:00 1.00 FISH P DECOMP PU 2 7/8" PAC DP 1 X 1 from 285' to 1,200' md. 12:00 - 12:30 0.50 FISH P DECOMP Lubricate Rig. Senrice & inspect Top Drive & Biocks. 12:30 - 18:30 6.00 FISH P DECOMP Continue to PU 2 7/8" PAC DP 1 X 1 from pipe shed. -PU 2 7/8" PAC from 1,200' to 8,500' md. 18:30 - 19:30 1.00 FISH P DECOMP PU & MU HES Storm Pkr & XO's. -Set Pkr 90' md below Riq floor. COE ~ 95' md. -LD 3 Jts of 2 7/8" PAC DP. 19:30 - 20:30 1.00 FISH P DECOMP RU & test HES Storm Pkr to 1000 psi / 10 charted minutes -, Pass. -RD test equipment. 20:30 - 22:00 1.50 FISH P DECOMP PJSM on nippling down the BOP stack. ND Flow line, Riser, Choke line & BOP's. 22:00 - 00:00 2.00 FISH P DECOMP Remove 7 1/16" x 13 5/8" Adapter Flange. -7 1/16" x 13 5/8" XO S ool and Faise Bowl. --Install 18" Ext. Spooi. 6/19/2009 00:00 - 02:30 2.50 FISH P DECOMP NU BOP's 02:30 - 04:00 1.50 FISH P DECOMP RU & test breaks on BOP stack. -Test to 250 psi low pressure & 4000 psi high pressure. Hold test for 5 charted minutes.- Pass. 04:00 - 07:00 3.00 FISH P DECOMP Replace Mandrel Packoff through the stack. -Test Packoff to 5000 psi for 30 minutes. 07:00 - 07:30 0.50 FISH P DECOMP Install Wear ring. 07:30 - 10:30 3.00 FISH P DECOMP RIH, latch Storm Pkr. POH w/ Storm Pkr.. -LD Storm Pkr & XO's. 10:30 - 11:30 1.00 FISH P DECOMP Continue to single in the hole w/ 2 7/8" PAC DP w/ GS Spear. -RIH from 8,406' to 8,962' md. 11:30 - 12:00 0.50 FISH P DECOMP Obtain parameters: PUW 142k, SOW 118k. 100 gpm / 1550 psi. -Slack off to 5k down wt to engage XN Lock ~ 8,989' md. -Attempt to pull free w/ Jarring ~ 175k & pull up to 210k. 12:00 - 13:00 1.00 FISH P DECOMP Obtain parameters: PUW 142k, SOW 118k. -Continue to attem t to Jar Fish XN Lock assembl free. -Jar ~ 175k & pull up to 210k. 13:00 - 14:30 1.50 FISH P DECOMP Release from Fish. -Wash top of XN Lock ~ 134 qpm / 2350 psi. -En a e XN Lock. Attempt to Pull Fish free. -Jar ~ 175k pull up to 215k. -Work pull up in 5k increments to 230k - Fish came free. -Monitor well & establish loss rate ~ 30 b h. 14:30 - 00:00 9.50 FISH P DECOMP POH w/ Fish. LD 2 7/S" PAC DP 1 X 1 to pipe shed. ~ -LD 3 1/8" D.Cs, & BHA. -Recovered Fish (XN Lock assembly) = 32.42'. Seawater losses for Tour= 56 bbls. Daily Seawater losses= 56 bbls. 6/20/2009 00:00 - 01:00 1.00 FISH P DECOMP Clear Rig floor o all oo s not nee ed for upcoming operations. -Mobilize New Mill BHA to Rig floor. 00:30 - 01:00 0.50 FISH P DECOMP Lubricate Rig. Senrice & inspect Top Drive & Blocks. 01:30 - 03:00 1.50 FISH P DECOMP PJSM on Making up Baker BHA. i, - ac, ou e m u, oot Basket, Bit Sub, XO, Flex Jt, String Mill, 8-Pac DCs. rnnceu: wca~cw~ o.v+.<~ ~~.~ ~ w BP EXPLQRATION Page 6 ot 7 Operations Summar~ Repor~ Legal Well Name: 13-35 Common Well Name: 13-35 Spud Date: 3/24/1994 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 14 Rig Number: Date : From - Ta' F=14urs Task Code NPT Phase Deseriptian of ~Rerations 6/20/2009 03:00 - 10:00 7.00 FISH P DECOMP RIH to X Nipple ~ 7,980' md. -Pick up 2 7/8" HT Driil Pipe ix1 from Pipe Shed. 10:04 - 12:00 2.00 FISH P DECOMP Tagged X Nipple ~ 7,980' md. -Obtain parameters: PUW 130k, SOW 114k, -80 RPM ~ 2k free TQ. 165 gpm ~ 2240 psi. -Mill 1'. -PU 2 Joints (50') work String Mill through same area. Seawater losses for Tour= 39 bbis. SPR ~ 7,980' md. 8.5ppg Seawater #1 20 SPM = 650 psi. 30 SPM = 1270 psi. #2 20 SPM = 710 psi. 30 SPM = 1300 psi. 12:00 - 13:00 1.00 FISH P DECOMP Contine R&R Strin Mill Across X Ni le Area. -Obtain parameters: PUW 128k, SOW 112k, ROT 120k. -120 RPM ~ 2k TGl. 173 gpm ~ 2270 psi. -Pump HighVis Sweep S/S 173 gpm ~ 2270 psi. 13:00 - 14:00 1.00 FISH P DECOMP RIH to XN nipple ~ 8,989' md. - Pick up 2 7/8" HT Drill Pipe 1 x1 from Pipe Shed. 14:00 - 14:30 0.50 FISH P DECOMP Tag XN Ni le ~ 8,989' md. -PUW 140k, SOW 118k, 210 gpm (~ 2790 psi. 14:30 - 16:00 1.50 FISH P DECOMP Pump HighVis Sweep. -S/S 190 gpm f~ 2970 psi. -Flow Check 10 min. 16:00 - 22:30 6.50 FISH P DECOMP POH LD 2 7/8" Drill Pi e to 500' 22:30 - 00:00 1.50 FISH P. DECOMP Cub Slip 59.5' of Dril~ing Line. -Service Top Drive. 6/21 /2009 00:00 - 00:30 0.50 00:30 - 02:00 1.50 02:00 - 03:00 1.00 03:00 - 03:30 0.50 03:30 - 05:00 1.50 05:00 - 06:00 1.00 06:00 - 12:00 6.00 12:00 - 12:30 0.50 RU 12:30 - 18:30 6.00 RU 18:30 - 19:30 1.00 RU Seawater iosses for Tour= 57 bbls. Dail Seawater losses= 96 bbls. RUNCMP LD BHA. Pup Jt & X0. -C/O Elevators. RUNCMP PJSM. -Continue to lay down 3 1/8" D.C's and BHA. RUNCMP Clean Baker tools. -Clear Rig Floor of all Tools Not Needed for Upcoming Operation. RUNCMP Pull Wear Ring. RUNCMP RU to run 3 1/2" 9.2# TCII tubin . -C/O Bails & Elevators. ~ -Install Single Jt Compensator & Elevators. -MU Safety Valve. Adjust Tongs. RUNCMP MU Tail Pipe & Packer Assembly to 159' md. RUNCMP RIH w/ 3 1/2", 9.2#, L-80,TCII Tb . -Utilize " Jet Lube Seal Guard" thread compound. -Optimum Tq = 2300 ft/Ibs. -RIH to Jt. # 106 to 3,392' md. RUNCMP Lubricate Rig, Inspect & service Top Drive. RUNCMP RIH w/ 3 1/2", 9.2#, TCII Tbg. -From Jt. #106 to Jt. # 281 ~ 9,015' md. RUNCMP MU Hanger & Landing Jt -PU 125k, SOW 108k. i.r ~- BP E~PLORATI(~N Fage 7 af 7' ~perations Surnmary ~eport Legal Well Name: 13-35 Common Well Name: 13-35 Spud Date: 3/24/1994 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 14 Rig Number: ' Da#e From - To Hours Task Code NPT Phase ` Description: ~f f~perations 6/21/2009 18:30 - 19:30 1.00 RUNCO RUNCMP -Land Tubing ~ 9,045' md. RIL.DS. 19:30 - 20:30 1.00 RUNCO RUNCMP Pump Down IA taking Returns out Tubing. -80 bbl Seawater & 100 bbl Seawater w/ Corrosion inhibitor. -126 gpm / 710 psi. 20:30 - 22:00 1.50 RUNCO RUNCMP RU Hot Oil. PJSM. -Test lines to 4,750 psi. -Pump 40 bbl Diesel Freeze Protection ~ 80 degrees. -84 gpm / 250 psi ICP. 84 gpm / 500 psi FCP. 22:00 - 23:30 1.50 RUNCO RUNCMP U-tube diesel between Annulus and Tubin . 23:30 - 00:00 0.50 RUNCO RUNCMP ro Ball & R d. -Set Packer w/ 4500 psi. on Tubing. I 6/22/2009 I 00:00 - 01:30 I 1.50 01:30 - 02:00 I 0.50 02:00 - 03:00 I 1.00 ~ 03:00 - 09:30 I 6.50 09:30 - 12:00 ~ 2.50 RUNCMP Continue to hold 4500 si on Tubin for 30 min. chartetl - ras -Bleed Tubing Pressure to 1,500 psi. -Pressure u on Annulus to 4,000 si / 30 min. Charted - Pass RUNCMP Suck Back on Lines w/ Hot Oil. -RD Landing Joint, XO's, Pump in Sub, & Test Lines. RUNCMP Install TWC, RU to Test From Above. -4000 si. 10 min. - ass. -RD Test Equipment. ~ RUNCMP PJSM on ND BOP Stack. -IVD BOP Stack, Suck out Stack. -Blow down: -Choke line, Kiil Line, Hole Fill, Bleed off & Mud pump line. -LD Mouse hole. -Remove Riser, Flow line, Turn buckles, Choke line & Spacer spool. -Remove Tie back stack, PU Adapter Flange and Tree. -Test Fiange to 5,000 psi. for 30 min. -Pass -Test Tree to 5,000 psi. for 10 min. -Pass RUNCMP RU Lubricator and Test to 500 psi. __ -Remove Double Valve, Pump in Flanges. -Install Gauges, RD Rock Washer, Pull in Conveyor. T/I/0= 0/0/0 Release Ria ~ 12:00 hrs. #13-35 Well History ~ Date Summary 05/17/09 PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1 "). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS (ET sryle), all moved freely (1 "). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 05/28/09 INITIAL WHP/IA/OA = 50/100/100 SHOOT 2' OF SMALL PUNCHER OVER INTERVAL 8963'- 8965' 9 HOLES SSV = C, SV = C, MV = O, WV = C FINAL T/I/O = 20/100/100 WELL SHUTIN ON DEPARTURE, NOTIFIED DSO UPON DEPARTURE 05/30/09 T/I/0= 0/100/100, Temp= S/I. Circ out well (RWO prep). Pumped 10 bbls 40" methanol, 276 bbls 120' seawater and 40 bbls 60" diesel down TBG taking returns up IA threw hardline to tiger tank. Closed in all block valves to tiger tank, and U-tubed TBG & IA for 30 minutes. CMIT TxIA '"`'PASS""" to 1000 psi. Pressured up TBG/IA with 1 bbl 60" diesel. CMIT TxIA lost 40/40 psi in 1 st 15 minutes and 20/20 psi in the 2nd 15 minutes for a total loss of 60 psi in 30 minute test (second attempt). Bled TBG/IA pressures back down to 0/0. FWHP= 0/0/140 06/01/09 T/I/O=VacNac/150. Temp=Sl. Bleed WHP's to 0 psi. (Pre RWO). MI line C~? 3350 psi. T& IA FL's near surface, OA FL ~ 60' (2.7 bbl). Bled OAP from 150 psi to 0 psi in 4 hours. Rig down and monitor for 30 minutes. OAP increased 3 psi in 30 minutes. No change in TP or IAP during OAP bleed or monitor. Final W H P's=VacNac/3. MV & SSV = OPEN. SV & WV = CLOSED. IA & OA = OTG. NOVP. 06/03/09 T/I/O = SSVNac/15. Temp = SI. Monitor WHP's (RWO prep). PWI. (MI line C~ 400 psi). 2"integral installed on OA. IAP unchanged. OAP increased 12 psi to 15 psi overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 06/03/09 T/I/O = 0/0/0 Set 4-1/16" CIW BPV #709 thru tree,l-2' ext. used..tagged C~ 96"...pre-rig..no problems. 06/22/09 T/I/O=Vac/0/0. Pulled 4-1/16" CIW H TWC thru tree, post tree test. Set 4-1/16" CIW H BPV #116 thru tree, rig move off well. 1- 2' ext. used, tagged ~ 100". No problems os/26/o9 T/I/O = 0/0/0 Pulled 4"ciw bpv used 1-2" ext and tag at 96" for post rig no problems 06/27/09 PULL BALL & ROD FROM 8,952' SLM / 8,972' MD PULL 3-1/2" RHC-M FROM 8,947' SLM / 8,972' MD DRIFT WITH KJ, 2.50 CENT, 2' 1" 7/8 STEM, T.E.L. AND SAMPLE BAILER..LOC TT C~3 9,023' SLM + 23' CORR + 9,046' MD TAG STICKY BOTTOM ~ 10,056' SLM + 23' CORR = 10,079' MD (RECOVERED SAMPLE OF SHMOO IN BAILER) Page 1 of 1 • SARAH PALIN, GOVERNOR ~-7~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CD~S+~IRQA-ItT01` L+O~II~+L+IO~ ~° s+ -7-7 ANCHORAGE, ALASKA 99501-3539 . ,.. PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 -4 ~~~~ `~~ ~~`` ~ , ~:~ ? ~ u ~ ~ 0~ Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-35 Sundry Number: 309-170 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approvai relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy Foerster Commissioner DATED this ~ day of May, 2009 Encl. STATE OF ALASKA J~ ~ ~~~ ALA OIL AND GAS CONSERVATION COMII~ION ~~~ S/,fD9 APPLICATION FOR SUNDRY APPROVAL ii~,~Y ~ ~'~ ~~~'~~ 20 AAC 25.280 ~t~S n _ ft . ~;r13 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ime xtensi nt ~r~t:huf ~~~ ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 194-041 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22460-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-35 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028315 ~ 82.2' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10250' 9210' - 10103' 9077' 9003' None C sin Len th iz MD TVD B rst II se trcurl nd ct r 80' 2 11 12' 149 470 Surface 3562' 9-5/8" 349 ' 3258' 6870 4760 Intermediate r i n 1 1 -1/ " 1 1' 9 4' 774 62 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10047' -10100' 9026' - 9074' 3-1 /2", 9.3# & 2-7/8", 6.5# L-80 8996' & 9008' Packers and SSSV Type: None Packers and SSSV MD (ft): 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 4, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564-5683 Printed Nam vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~ ~ Phone 564-5743 Date S~rf~®9 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: f Conditions of approval: Notify Commission so that a representative may witness ~- ~~~~sz ~~,-ny ^ Plug Integrity BOP Test Mechanical Integrity Test ^ Location Clearance Oth er: Subsequent Form Required: 1..~~ b APPROVED BY c- ~'~~ ~ COMMISSIONER THE COMMISSION Date ,~ A roved B Form 10-403 Revised Q/2006 Submit In Duplicate j~ • by c,,,,~.~~,, 13-35i Rig Workover (Injector tubing swap TxIA communication) Scope of Work: Remove 3.5" coil completion. Run 3.5" L-80 completion. Engineer: David Bjork MASP: 2427psi Well Type: Injector Estimated Start Date: July 4th, 2009 F 1 CMIT TxIA to 4000 si for 30 charted minutes. MIT OA to 2000 si for 30 charted minutes E 2 Tubin Punch 3-1l2" 7# coil tubin ~ 8,965'. reference tall dated 6-21-94 F 3 Circulate well through the tubing punch with seawater (8.6ppg) and diesel freeze protect to 2000' MD. CMIT TxIA to 1,000 si O 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 6 Set a CIW 4" T e H BPV in the tubin han er. O 7 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. The BOPE will be configured with 2-7/8" x 5" VBR's, blind shears and an annular preventer. NU and test BOPE to 250psi low/ 4,OOOpsi high. Test annular preventer to 3,500psi. 2. Circulate out freeze protection fluid and circulate well to clean seawater through the tubing punch. 3. Pull and LD 3.5" coiled tubing string. 4. recover 2-7/8" tailpipe and seal bore. 5. Change casing pack-offs. 6. Run 3-'h" L-80 completion with Baker SABL-3 packer. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 4000 psi. Freeze protect to 2,200' MD. 9. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = FMC NEW STANDARD WELLWEAD = CNV ACTUATOR = BAKER C KB. ELEV = 82' BF. ELEV = KOP = 1738' Max Angle = 39 @ 2789' Datum MD = 9888' Datum TV D = 8800' SS 9-5/8" CSG, 47#, NT-80, ID = 8.681" 13 -3 5 SAFETY NOTES: RWO Proposed 3-1/2" TBG, 9.3#, L-80, TCII, ID = 2.992" 8960' Minimum ID = 2.635" @ 9060' 3-1 /2" OTIS XN NO-GO NIPPLE PERFORATION SUMMARY REF LOG: MWD ON 03/31/98 ANGLE AT TOPPERF: 25 @ 10047' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 10047 - 10063 C 09/23/99 2-1/8" 6 10068 - 10077 C 09/23/99 3-3/8" 6 10080 - 10100 C 06/09/94 STD "' 15-1/2" CSG, 17#, L-80, ID = 4.892" 1 I 10221' I 2000' 3-1/2" OTIS X NIP, ID= 2.813" 7968' 5-1/2" OTIS X NIP, Milled out to 4.75" 8930' 3-1 /2" OTIS X NIP, ID= 2.813' - 8960' S-1/2" x 3-1/2" Baker SABL-3 Packer w/ i - 8976' S-1/2" OTIS X NIP, Milled out to 4.75" - 8990' 3-1/2" HES 9Cr X-Nip, ID=2.75 - 9060' 3-1/2" HES 9Cr XN-Nip, ID=2.635 DATE REV BY COMMEMS DATE REV BY COMMENTS 04/01/94 ORIGINAL COMPLETION 08/05/08 JCM/PJC PULL PXN @ 8998' (08/02!08) 04/04/94 LAST WORKOVER 09/03/08 KGPJC SET PXN @ 9003 (08/12/08) 08/01/01 RWKAK CORRECTIONS 05/06/03 ATD/KK LOCK MANDR~ CORRECTION 09/26/04 CAO/TLP SET PXN 06/10/08 JM/TLH DRAWING/DEPTHS CORRECTION PRUDHOE BAY UNff WELL: 13-35 PERMff' No: 1940410 API No: 50-029-22460-00 SEC 14, T10N, R14E, 2311.13 FEL 2476.94 FNL BP Exploration (Alaska) 'í~~~ ~¡;;-¡~ /1\ l'~ P '\ ~."",. :11 .,.1,,1\, \ . .; ,,'I :/" ''\, \1" .! '\' 'I' ':J . '~)II ,I "-'1L\' ~Ui;' ;\;' nJ)¡.! iì1' 'j, : ,I ~ .'=.J"Y ',' ,~ ( (-\ ;-'] il. "nl. :.1 :.Ir 1 :' !¡ j :::J I ¡ j ,il! ~~ w ,,-'\ .-;1' :~ ,---;"'~ 11 ./"""7 '""'"') ',I,. ,! /1:\I,('L:¡' "I;' )1\ i~ IllAi ~ U\~i~ FRANK H. MURKOWSKJ, GOVERNOR A.IiA.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. -¡r" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Well Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 tÞf if'" b 4J Re: Prudhoe 13-35 Sundry Number: 305-239 . r;' <) On't:"¡ -. ,- I'\UG ~~r r... t.. u"'" SGJi\f\W"EJ..J ~~\ ..~ r... v Dear Ms. Julian: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision uperior Court unless rehearing has been requested. ~ DATED thisJjday of August, 2005 Encl. 1. Type of Request: ( 00 6'-19-1J ~ {"It . llUG¡t _~ ! I ~ ~ ¡:,~) ( STATE OF ALASKA D~ fC¡!sRECL.'~\/FtJ ALASKA OIL AND GAS CONSERVATION COMMISSION AUG r; 2005 APPLICATION FOR SUNDRY APPROVAL 1 ö 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend U Repair well [] / Pull Tubing 0 c, Anchorage, AK 99519-6612 7. KB Elevation (ft): ~oprœnt 0 Stratigraphic 0 ^Iðt~ø Oil & G1.$ Can$ Commission Perforate U Walve,.,r I'~' Other U A~orage Stimulate 0 Time Extension L Re-enter Suspended Well 0 5. Permit to Drill Number: ~oratory 0 194-0410 / / Service ~ 6. API Number: / Abandon U Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska). Inc. 3. Address: P.O. Box 196612 50-029-22460-00-00 9. Well Name and Number: 82.2 KB 13-35 /' 8. Property Designation: ADL-028315 11. Total Depth MD (ft): 10250 Total Depth TVD (ft): 9210.17 10. Field/Pools(s): Prudhoe Bay Field 1 Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10103 9076.83 None Junk (measured): None Collapse 11160 6280 4760 460 Casing Length Size MD TVD Burst Liner 34 2-7/8" 6.5# L-80 8983 9017 8059.6 8091 10570 Production 10189 5-1/2" 17# L-80 32 10221 32 9184 7740 Surface 3462 9-5/8" 47# NT -80 33 3495 33 3258 6870 Conductor 80 20" 91.1# NT-80 34 114 34 114 2960 Perforation Depth MD (ft): 10080 - 10100 10068 - 10077 10047 - 10063 Packers and SSSV Type: Perforation Depth TVD (ft): 9055.97 - 9074.11 9045.09 - 9053.25 9026.04 - 9040.55 Tubing Size: 3-1/2" 9.3# Tubing Grade: L-80 Tubing MD (ft): 31 - 8996 ,....' 12. Attachments: D:saiDth.eSJmmaryofA-oposaI0 l::Etailed QJerations A-ogram 0 B:P Sketd1 0 o Packers and SSSV MD (ft): 0 o 0 o 0 o 0 13. Well Class after proposed work: E)q)loratory 0 ce\.elopment D "",/' Service 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: ,;'~., / ) 8/26/12005 \ ,,/ I ,--, Date: 15. Well Status after proposed work: 01 0 <?as 0 Plugged 0 Pbandoned 0 V\PGD GNJ D ~~) ~D Prepared by Sh~r~ Vestal 564-4424 Contact Jennifer Julian 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name , , Jer nif¡~JUlian Title Well Engineer Signature a 0/vJ "'"" Phone 564-5663 () COMMISSION USE ONLY Date 8/12/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~jDS-"'d-3C¡ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test æ! Location Clearance o Other: /V\ [T '"~...~ "^-'^."'-€ d .. - 40 4- ~ RBDMS BFL AUG ~ 2 2005 APPROVED BY COMMISSIONER THE COMMISSION ORIGINAL Date: <%/1 /~/ Form 10-403 Revised 11/2004 Submit in Duplicate ~. bp -'.~- .. . .. .. .. .. .,. Jj.... -.~... To: 2005 f J. Bixbyl D. Cismoski Date: July 18, Well Operations Team Leader From: Janet Sack Design Engineer Subject: 13-35 OA Cement DownsQueeze Procedure $22M PBD13WL35-N Est. Cost: lOR: StrateQic Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 F Establish LLR down OA 2 DHD Depress OA FL wi AL 3 F OA cement downsqueeze 4 F MIT OA cement downsqueeze after wac / 13-35 is ~~With TxlA communication. On 08/26/04 the well failed an MITIA with a LLR.-~ 2 bpm @ 1200 psi. A TTP was set on 09/26/04. It passed a CMIT / TxlA to 3000 psi on 10/12/04. On the same day an MITOA failed. This program is designed to pump a column of cement from the shoe to approximately 500' above the shoe for waiver compliance. The procedure includes the following major steps: 1. DHD 2. DHD 3. DHD 4. DHD 5. 0 6. 0 Establish LLR down OA Depress OA FL wI AL Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +1- 200 psi and fluid pack with crude as required. OA Downsqueeze M IT OA after waiting on cement. / If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Julian J. Sack JOB PLANNING DETAILS: w/o: S. Rossberg 10/12/04: MITOA failed: Pumped 6.9 bbls of diesel to pressure up to 3000 psi. In 15 minutes pressure was down to 400 psi. No LLR was attempted. (' Well has rapid TxlA communication, secured with a TTP. OA = 9-5/8" 47# NT -80 IA=5-1/2" 17#L-80 Shoe at 3495' OAxIA Annular Capacity=.0438 bbls/ft / Volume to shoe = 153 bbls 500' of cement = 22 bbls Displacement = 153 -5 (H~O spacer) - 22 (cement) - 5 (H?O flush) = 121 bbls /' Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 500 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 121 bbls at 30-60 degree F Crude: (volume needed to load OA) OS CW101: 10 bbls Arctic Set 1 Cement (15.7 ppg): 22 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsqueeze): DHD/FB: 1. Establish LLR down OA to ensure >2 bpm (/ 2. Depress OA FL wI AL. 3. Shoot FLs and record WHPs. 4. The day prior to the downsqueeze, bleed the OAP to +1- 200 psi. 5. Fluid Pack the OA with crude. CEMENTING OPERATIONS: ,;t FB Pumping 1. Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. 2. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 3. If well has IA x OA communication (well has not shown this communication to date), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. / Tie into the IA with either a LRS or HB&R pump. 4. Flood lines with warm fresh water and pressure test lines to 3000 psi. 5. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW101 surfactant (optional) c. ....300 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 22 barrels of 15.7 ppg Arctic Set 1 cement f. 5 bbls of fresh water flush g. 121 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 111 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 6. Shut down pumps and leave the well SI. Please DO NOT try to achieve a squeeze or to build squeeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. / Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 7. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. \ \ Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post Squeeze: FB: 8. MIT-OA to 3000 psi. Previous MIT-OA History: 10/12/04: MIT-OA -Failed. Pumped 6.9 bbls of ~ diesel to pressure up to 3000 psi. In 15 minutes pressure was down to 400 psi. Pumped another 12 bbls and saw no pressure increase. IA pressure never came up while pumping on OA. Bled down pressures. FWP's=60/0/140 .TREE::: FMC NEVV STANDARD r WELLHEAD::: CrN ACTUA TOR::: BAKER C KB, ELEV ::: 82' BF. ELEV = KOP::: Max Angle ::: Datum MD ::: Datum 1V 0 ::: 1738' 39 @ 2789' 9888' 8800' SS ( 1 3 -35 / SAFETY NOTES: () 3173' 1--i3-1/2"CAMDSSSSV NIP, 10:::2,812" I 19-518" CSG, 47#, NT-80, 10::: 8.681" 1-1 3495' µ .. Minimum 10 = 2.25" @ 9011' . . 7968' 1-1 5-1/2'~OTIS x NIP, 10::: 4,562" I 2~7/8" OTIS XN NO-GO NIPPLE I 8982' 1--i3-1/2" OTIS XN NIP, 10::: 2.75" I I TOP OF 2-7/8" TBG-COILED 1-1 ) ~ 8983' 1--i3-1/2" x 2-7/8" XO I 8983' I 1-"12-7/8" LOC SEAL UNIT I 1 8984' Z z---1 8984' 1- 5-1/2" OTIS XN NIP WI XN LOCK MANDREL, 10::: 4.455" I \ 8995' 1-"12-7/8" MULESHOEWLEG I I 3-1/2" TBG-COILED, 9.3#, L-80, ,0087 bpf, 10::: 2.992" 1-1 I 2-7/8" TBG-COILED, 6.5#, L-80, ,0056 bpf, 10::: 2.441" 1-1 PERFORA TION SUMMARY REF LOG: MWD ON 03/31/98 ANGLE AT TOP PERF: 25 @ 10047' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 6 10047 - 10063 0 09/23/99 2-1/8" 6 10068 - 10077 0 09/23/99 3-3/8" 6 10080 - 10100 0 06/09/94 PBTD 1-1 10103' 15-1/2" CSG, 17#, L-80, 10 = 4,892"1-1 10221' DATE 04/01/94 04/04/94 08/01/01 05/06/03 09/26/04 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOV ER RN/KA K CORRECTIONS A TD/KK LOCK MANDREL CORRECTION CAOITLP SET PXN DATE 8996' r- .------1 8998' 51 m 1-"1 SET PXN PLUG 09/26/04 I '~ I 9011' 1-"12-7/8" OTIS XN NO-GO NIP, 10 = 2.25" I l---; \ I 9017' 1-12-7/8" MULESHOEWLEG I 9017' 9022' 1-"1 ELMO TT LOGGED 09/23/99 I J~~.~ REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 13-35 PERMIT No: 1940410 API No: 50-029-22460-00 SEC 14, T10N, R14E, 2311.13 FEL 2476,94 FNL BP Exploration (Alas ka) Notification of Failed MITIA: 13-35 (PTD #1940410) ') ) Subject: Notification of Failed MITIA: 13-35 (PTD #1940410) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 27 Aug 20.0409:06:54 -0800 To:. "AOGCC- Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "AOGCC - Jim Regg (Ejrnail)" <jim_regg@admin.state.ak.us>, "AOGCC Bob Fleckenstein (E~mail)" ." " <bòb- fleckenstein@admin.state.ak.us> . " . .' CC: "GPB, FS3TL" <GPBFS3TL@BP.conl>, "GPB; FS3 DS Ops Lead~t ... <GPBFS3DSOpsLead@BP.com>, "NSU, ADW Well Operations Supervisor"'. .. " <NSUADWWellOperationsSupervisor@BP.com>, "Olsen, Clark A" <OlsenCA@BP.com>, "GPB,' WttIls OptEngff <GPBWellsOptEng@BP.com>, "GPB,Optimization Engr" " ""...., " " . <GPBOptimizationEngr@BP.conl>, "Reeves, DonaldF'i <ReevesDf@BP.com>, "Rossberg;"R " St<,:ven" <RossbeRS@BP.cQm>, "Gerik,Bob G (PRA)" <GerikBG@BP.com>, "Dube,Anna T" " <ADna.Dube@BP.com>, "Engel, HarryR"<EngeIHR@BP.com>, "Mielke, Robert L.". " . <robert.mielke@BP.com>. "" " " ". Hello Jim, Winton & Bob. Well 13-35 (PTD #1940410) failed an MITIA and has been SI. An MITIA on 8/26/04 failed and a leak rate of 2 BPM @ 1200 psi down the IA was established. Current plans are for the well to remain SI and evaluate for either administrative relief from Area Injection Order 4C or a tubing repair. Attached is an MIT form. Please call if you have any questions. «MIT PBU 13-35 08-26-04.xls» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943 -1154 Pager: (907) 659-5100, xl154 Email: NSUADWWel1IntegrityEnginee:r.-@bp.com Content-Description: MIT PBU 13-35 08-26-04.xls PBU 13-35 08-26-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 SCANNED NOV 0 2 2004. 1 of 1 9/2/2004 8:06 AM ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU /08-13 08/26/04 Joe Anders Packer Depth Well 13-35 Type Inj. S TVD 8,061' Tubing P.T.D. 1940410 Type test P Test psi 2,015 Casing Notes: MITIA Failed, LLR of 2 BPM @ 1200 psi established. Pretest Initial 15 Min. 30 Min. 1 ,150 1 J 175 1 ,1 00 900 1 J 120 1 ,200 Interval P/F 0 F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 13-35 08-26-04.xls MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission RandyRuedrich ~~/?.?..,~/a~DATE: May8,2003 Commissioner /'3_. ~ i-lt~/© SUBJECT: Mechanical Integrity Tests Jim Regg BPX P.I. Supervisor DS 13-35 FROM: John H. Spaulding PBU Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 13-35 IType,.j.I e I T.V.$.l~o~ I Tubingl 900 1900 I 900 I 900 Ilntervall 4 P.T.D.I 1940410ITypetestl P ITestpsil 2015 I Casingl 450 I 2520 I 2460 I 2460I P/FI E Notes: Well P.T.D. Notes: P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: IType Inj. Type test Type Inj. IType Inj. Type test Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Cold 50/50 MEOH was used for testing - probably causing the slight delieation from the start pressure. The well is currently injecting MI gas and is quite warm. M.I.T.'s performed: 1_ Number of Failures: 0 Attachments: Total Time during tests: '1.5 cc: MIT report form 5/12/00 L.G. 2003-0508_M IT_PBU_I 3-35_js.xls 6/16/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: P.T.D.I~0404~I Notes: P.T.D.I Notes: P.T.D.I Notes: WellI P.T.D.I Notes: P.T.D.I N ores: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / DS-13 05/08/03 John Cubbon John Spauldin~ Typelnj. J ~ Type test Packer Depths (ft.) ~ Pretest Initial 15 Min. 30 Min. ~D,~I8,98~,I 8,08~,I TubingJ 9001 9001 900J 9001 Intervat 4 Test psiI 2520J J Casin~lI 4501 25201 24601 24601 P/FI P Type Inj. Type Inj. Type Inj. Type Inj. Test Details: 4 Year MITIA TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 13-35 05-08-03.xls 73-35, (PTD 1940410) AOGCC witnessed MITIA ( Subject: 13-35 (PTD 1940410) AOGCC witnessed MITIA Date: Thu, 8 May 2003 22:56:31 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> To: "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, .,,~\~?L~ "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us> ~,~c~l CC: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder~admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@~BP.com> Hi Bob, Winton, and Jim, Please see the attached MITIA form for the AOGCC witnessed MITIA on 13-35. If you have any questions, please call. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 <<MIT PBU 13-35 05-08-03.xls>> ] Name: MIT PBU 13-35 05-08-03.xls I [-~,MIT PBU 13-35 05-08-03.xls1tEric°ding:Type: base64Micr°soft Excel Worksheet (application/vnd.ms-excel) I I of 1 5/14/2003 4:14 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor~' Chairman DATE' May 20, 2002 THRU' Tom Maunder ' FROM: Chuck Scheve PetrOleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX DS 13 PBU Prudhoe Bay I WellI 13-06A P.T.D.! 197-218 Notes: WellI 13-16 I P.T.D.I 182-148 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I S I T.V.D. 18614 I Tubing 11050 t~050 i i lnterva,"I 4' Type testI, P I Test.psil 2154 I Casing I 500 ] 2420! 2400 ! '2400I P/F' I -P Type testI P I Testpsil 2114 ICasingI 50 ! 2280 I 2250 I 22'50 ! P/F I -PP' ...... We,,J 13-32A I Type,nj.J S ! T.v.a. J~4e I Tubingl 1400 1~400 1~400 I~00 J,nterva, J I ,P.T.D.! 201-235' Type test[ P I Testpsil 2137 I Casing i,. 360 I 2270 I 2220 I 2220 I, P/F ,! ?' Notes: Initial test post coil tubing drilling side track WellI 13-35 Type lnj.} ~ i T.V.~. I~0~, I Tubing i~350 J~350 1'~200 11200 l,nterva,! 4 ., P.T.D.I 194-041 Type testi P J Test psi J 2015 J Casing J 400 I 2320 J 2280 J 2280 J' P/F J __P Notes' Notes: Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT iNJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 13 and wimessed the 4-Year MIT on wells 13-06A, 13-16, 13-35 and thi initial MIT on well 13-32A. The pretest robing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 4 wells demonstrating good mechanical integrity. M.I.T.'s performed' 4_ Number of Failures: 0 Attachments' Total Time during tests' 3 hours cc: MIT report form 5/12/00 L.G. MIT PBU DS 13 5-20-02 CS.xIs ~SCANNED JUN g "~ 2002 6/3/O2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 82 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3755' FNL, 1409' FEL, Sec. 14, T10N, R14E, UM 13-35i At top of productive interval 9. Permit number / approval number 2415' FNL, 2290' FEL, Sec. 23, T10N, R14E, UM 94-41 At effective depth 10. APl number 50-029-22460 At total depth 11. Field / Pool 2477' FNL, 2311' FEL, Sec. 23, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10205 feet Plugs (measured) Tagged PBTD @ 10120' MD (9/23/1999) true vertical 9169 feet Effective depth: measured 10120 feet Junk (measured) true vertical 9092 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 112' 20" 260 SX AS 112' 112' Surface 341 3' 9-5/8" 870 Sx cs III/375 Sx Class G 3495' 3258' Production 10139' 5-1/2" 670 sx c~ass G 10221' 9184' Perforation depth: measured 10047, _ 10063,; 10068, . 10077,; 10080, .f true vertical 9026' - 9041'; 9045' - 9053'; 9053' - 9071'. ~z~ · Tubing (size, grade, and measured depth) 3-1/2" CT @ 8996' MD; 2-7/8" CT @ 9017' MD. AnChora(~e Packers & SSSV (type & measured depth) No Packer. 3-1/2" Camco DS SSSV Nipple @ 3173' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 3908 934 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~/~ <~. ~ Title ARCO EngineeringSupervisor Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 13-35i DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 9/20/1999: 9/23/1999: MIRU CTU. PT'd BOPE. RIH & performed a FCO to hard BTM @ 10128' MD. Washed 50 bbls of SBG across perfs. Swapped to 50 bbls of DieseI-Xylene across perfs. POOH w/CT. FP'dwell. RD CTU. MIRU ELU. RIH &tagged PBTD @ 10124' MD. POOH. RD. MIRU ELU & PT'd equip to 3000 psi. RIH w/perf guns & shot 25' of Add Perforations @: 10047' - 10063' MD (Zone 4) Reference Log: MWD 3/31/1998. 10068' - 10077' MD (Zone 4) Used 2-1/8" carriers & all shots @ 6 SPF, random orientation, 0° phasing, & balanced press. Tagged PBTD @ 10120' MD. POOH w/guns. ASF. RD. Returned well to produced water injection & obtained a valid injection data. ANNULAR INJECTION DATA ENTRY SCREEN Asset .EQ& ......................................... Rig Name .............................................. Inj Well Nam~ ................................. Permit Start ...... ..4./..;[./.,q.& ...... Permit End ...... ..4./.,5./.,q.~ ...... Sur Csg Dep .3..4.9.5 .............. · ............................................................. Cumulative Data I Legal Desc ...................................................................................................................... Research ................................................................................................................... .Ch rzact, ed..=o,~¥..,~e r,t ..to...A. QG C.C..;~:.1.Z=,gZ ............... Dally Data DS 13-35 550 DS 13-31 DS 13-31 555 April 1 through April 5~ 1994 WELL LOG TRANSMITTAL To: State of Alaska June 28, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 13-35I The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' fun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. RFCEIVED JUN 2 8 1996 Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 , (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company PERMIT D A'TA /n AOG C C ueologica '1 lndi v;i duai Mater'i a i s T DATA__PLUS Wel'l "I ~q-X Inventor'y P a g e; '1 Date: 04/ 10/'96 RUN DATE._.R ECVD 9a,"-061 9~¢ - 04. 1 9L~ .-,- OL~ 1 9a.-Oh 1 94-0hl 9/¢-0/~ 1 9L~-OL~ 1 9a.,-. OL~ I vBGR/EWR/FXE ~GR/EWR?FXE ~, ~ T (C&C) ,..P,,CR F '~JRVE Y L 9908-10250~ L 8900-9210, L 8970-10100 L 8950-10080 L 9750-'10103 MWD , MD MWD , TVD R COMP DATE: 06/21/'9L~ R 03/21-06/21/9b R 0-9908 SPERRY SUN 05/2a/9,~ OS/2Z~/9a 05/27/9a- 07/11/9L~ 11/'1~/9~ 10/28/'94. 10/28/94 10/28/94 Are dry Was the Are Well is in COMMENTS ditch samp'les well cored? r'equired? yes ~ r'eceivec-L? yes yes aiysi's & description r'eceived? tests r'equir'ed? yes ~.._Received? ye--~ no Initial compliance yes BO ~'"~ STATE OF ALASKA r.,.~,~,~ ALAsKAr'oiL AND GAS CONSERVATION C,..,,,,,,,,,ISSION NELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SIJSPENDED [] ABANDONED [] SERVICE El< WAG Iniector 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 94-41 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 s0- 029-22460 4. Location of well at surface ~ .~ .~~a~?~, 9. Unit or Lease Name 1521' NSL, 1411' WEL, SEC. 14, T10N, R14~C~,~pL~.Ti_~.~,~' ~~ (c='/'~ ~'" ~' !~[~~~~~ i fl.Prudh°eBayUnitField and Pool At Top Producing Interval ~ ,,.~ ~DAT~2----~ 10. Well Number 13-35 2415' SNL, 2290' WEL, SEC. 23, TION, At Total Depth L~'"u ~ ~ Prudhoe Bay Field/Prudhoe Bay Pool 2458' SNL, 2315' WEL, SEC. 23, TION, R14~ 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE -- 82.2' J ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3/21/94 3/30/94 6/21/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J20. Depth where SSSV set J21. Thickness of Permafrost 10250'MD/9210' TVD 10103'MD/9077' TVD YES [] NO []! 3156' feet MD! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SE'I'rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 32' 112' 30" 260 sx Arcticset (Approx.) 9-5/8" 47# NT-80 33' 3495' 12-1/4" 870 sx CS 111/375 sx "G" 5-1/2" 17# L-80 32' 10221' 6-3/4" 670 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MDI Gun Diameter 3-3/8" 6 spf 3-1/2" 8978' XN Nipple ~ 8965' MD TVD 10080'-10100' 9053'-9071' Coil tubing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/23/94 I Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED 0CT 2 8 1994 Alaska 0il & Gas Cons. Commission Anchor~,~e Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOL~ MARKERS ION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sadlerochit 10045' 8942' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~ ~~~ Title Drilling Eno_ineerSuoervisor INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is Used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 RECEIVED OCT 2 8 1994 Alaska gll & (~as Cons. ~P/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 13-35I BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 03/20/94 08:30 SPUD: RELEASE: 04/01/94 05:00 OPERATION: DRLG RIG: NABORS 28E WO/C RIG: 03/21/94 ( 1) TD: 0'( 0) 03/22/94 (2) TD: 1990' (1990) 03/23/94 (3) TD: 3515'(1525) 03/24/94 ( 4) TD: 3617'( 102) 03/25/94 (5) TD: 5646'(2029) MAKE UP BHA MW: 0.0 VIS: 0 MOVE RIG FROM DS 4-45 TO DS 13-35. PREPARE WELL 13-35 FOR RIG. N/U DIVERTER. SPOT SUB OVER WELL. SPOT MOTOR COMPLEX, SLIDE RIG FLOOR AND SPOT MUD PITS. RIG UP RIG FLOOR. NIPPLE UP RISER AND FLOW LINE JETS. TAKE ON WATER IN MUD PITS. FUNCTION TEST DIVERTER. PICK UP, STRAP AND MAKE UP BHA. DRILLING MW: 9.0 VIS:325 MU & ORIENT BHA. ADJUST MOTOR. TEST MUD LINES T/3500PSI. FILL HOLE. REPLACE AIR BOOT IN FLOW LINE. DRILL F/109 T/1990. RUN CASING MW: 9.5 VIS:140 DRILL FROM 1990-2576'. CIRCULATE BOTTOMS UP. SHORT TRIP 18 STANDS TO 850'. NO PROBLEMS. DRILL FROM 2576-3515'. CIRCULATE BOTTOMS UP. SHORT TRIP TO 850' SLM NO PROBLEMS. CIRCULATE HOLE CLEAN. DROP SURVEY & PUMP DRY JOB. TRIP OUT OF HOLE TO RUN 9 5/8" CASING. RIG UP & RUN 9 5/8" SURFACE CASING. DRILLING MW: 9.5 VIS: 0 FINISH RUNNING 9 5/8" CASING, LAND CASING W/ SHOE @3495'. CIRCULATE AND CONDITION MUD FOR CEMENTING. CEMENT 9 5/8" CASING, DISPLACE W/ RIG PUMPS, BUMP PLUG. GOOD CIRCULATION THRU JOB, NO CEMENT TO SURFACE. CHECK FLOATS AND RU FOR TOP JOB. PUMP TOP JOB W/ 250 SX COLDSET III, GOOD CEMENT TO SURFACE. LD 1" AND CEMENT HEAD, BACK OUT AND LD LANDING JT, CLEAR FLOOR. ND RISER AND DIVERTER. NU SPLIT SPEED HEAD AND TEST. NU BOPE. PRESSURE TEST BOPE. PU 8 1/2" BHA AND ORIENT MWD. RIH AND TAG CEMENT @3411'. CIRC BOTTOMS UP, PRESSURE TEST CASING. DRILL PLUGS, FLOATS, CEMENT AND 10' OF NEW HOLE TO 3525'. CIRCULATE AND CONDITION MUD, SHUT IN AND PERFORM LOT. DRILLING FROM 3525-3617'. TFNB MW: 9.6 VIS: 44 DRILLING FROM 3525-4505' DHORT TRIP TO 9 5/8" CASING SHOE W/ NO PROBLEMS. DRILLIN~ FROM 4505-5646' PUMP SWEEP AND CIRCULATE SHAKERS CLEAN. TFNB. RECEIVED OCT 2 8 1994 Alaska Oil & Ga.~ ~,n.e ~nmm~-.k,, ~ELL : DS 13-35 OPERATION: RIG : NABORS 28E PAGE: 03/26/94 (6) TD: 7110'(1464) 03/27/94 ( 7) TD: 8100' ( 990) 03/28/94 (8) TD: 8778' ( 678) 03/29/94 (9) TD: 9440' ( 662) 03/30/94 (10) TD: 9970'( 530) 03/31/94 (11) TD:10250' ( 280) DRILLING MW: 9.8 VIS: 44 FINISH TRIP FOR BIT, BENCHMARK SURVEY @3617'. PRECAUTIONARY WASHA ND REAM 90' TO BOTTOM, NO PROBLEMS ON TRIP. DRILLING F/ 5646-6665'. SHORT TRIP TO 5500' W/ NO PROBLEMS. DRILLING F/ 6665-7110'. DRILLING MW: 9.6 VIS: 46 PUMP SWEEP AND CIRCULATE SHAKERS CLEAN. POH, CHANGE OUT MUD MOTOR AND MWD, ADJUST MOTOR FOR 1 DEG BENT HOUSING AND ORIENT. RIH WITH NEW BIT. CUT AND SLIP 104' OF DRILLING LINE. FINISH RIH WITH NEW BIT, BENCHMARK SURVEY @3544'. PRECUATIONARY WASH AND REAM F/ 7005-7123'. NO PROBLEMS ON TRIP. DRILLING F/ 7123-8100'. CIRCULATE FOR BIT TRIP MW: 9.6 VIS: 45 DRILLING F/ 8100-8468'. SHORT TRIP TO 7000' WITH NO PROBLEMS. DRILLING F/ 8468-8778'. PUMP SWEEP AND CIRCULATE FOR BIT TRIP. DRILLING MW: 9.6 VIS: 45 CIRCULATE SWEEP FOR BIT TRIP. POH TO CHANGE BIT, NO PROBLEMS. PULL WEAR BUSHING FOR SERVICE AND RE-INSTALL SAME. RIH WITH NEW BIT, BENCHMARK SURVEY @3617', PRECAUTIONARY WASH AND REAM FROM 8675-8778', NO PROBLEMS. DRILLING FROM 8778-9440'. CIRCULATE LCM PILL MW: 9.6 VIS: 44 , DRILLING F/ 9440-9908 . PUMP SWEEP AND CIRCULATE SHAKERS CLEAN. POOH FOR RLL LOGGING TOOL. LD MOTOR AND MWD TOOL, PU RLL TOOL AND CHANGE BHA. PROGRAM RLL TOOL. RIH WITH NEW BIT. CUT 104' OF DRILLING LINE. FINISH RIH TO 9773'. PRECAUTIONARY REAM AND WASH TO BOTTOM, HAD MINOR PACKING OFF @9835' AND CIRCULATED LARGE AMOUNT OF CUTTINGS ON BOTTOMS UP. DRILLING F/ 9908-9970'. HOLE STARTED SEEPING MUD #9967'. MIX LCM PILL AND SWEEP HOLE, LOSSES ARE STEADY AT 1/2 BPM. RU TO RUN 5 1/2" CASING MW: 9.6 VIS: 44 FINISH MIXING 20 BBL PILL, SPOT ON BOTTOM, LOSSES STABILIZED. DRILLING F/ 9970-9991' MIX AND PUMP 20 BBL PILL AND SPOT. MIX AND PUMP 75 BBL PILL AND SPOT, BUILD MUD VOLUME, HOLE STABLE. DRILLING F/ 9991-10250'. PUMP SWEEP AND CIRCULATE SHAKERS CLEAN. SHORT TRIP FROM 10250-8795', HOLE IN GOOD CONDITION. PUMP SWEEP AND CIRCULATE SHAKERS CLEAN, SPOT 50 BBL LCM PILL AROUND BHA. DROP TOTCO SURVEY. POH STANDING BACK 15 STANDS, CONTINUE POH, LD 5" DP. LD 8 1/2" BHA AND DUMP RLL DATA. RECEIVED 0CT 2 8 1994 A.Jaska Oil & Gas Cons. Commission Anchorr, ~ ~ELL : DS 13-35 OPERATION: RIG : NABORS 28E PAGE: 3 04/01/94 (12) TD:10250' ( 0) 04/02/94 (13) TD:10250' ( 0) P/U 2 7/8" DRILL PIPE MW: 9.6 VIS: 0 RU TO RUN 5 1/2" CASING, PULL WEAR BUSHING. RUN 282 JTS 5 1/2" CASING, PU LANDING JOINT AND LAND CASING W/ STRING WEIGHT OF 160K SHOE @10221', FLOAT COLLAT @10150'. CIRCULATE AND CONDITION HOLE @ 8 BPM, BATCH MIX TAIL CEMENT. TEST LINES. FLUSH BOPE AND LD LANDING JOINT. INSTALL 7 5/8" PACK OFF AND TEST. CLOSE BLIND RAMS AND PRESSURE TEST 5 1/2" CASING. PU 2 7/8" DRILL PIPE AND RIH TO FREEZE PROTECT 5 1/2" CASING. RELEASED RIG MW: 9.6 VIS: 0 FINISH PU 2 7/8" DRILL PIPE AND RIH TO 2300'. FREEZE PROTECT 5 1/2" CASING W/ 50 BBLS DIESEL, REVERSE CIRCULATE DIESEL FROM 2300' TO SURFACE. LD 2 7/8" DRILL PIPE. PULL SHORT BOWL PROTECTOR, INSTALL 12" FALSE BOWL W/ BPV IN PLACE. RILDS AND PRESSURE TEST UNDER FALSE BOWL. ND BOPE AND SET BACK. NU HOLD DOWN FLANGE AND PRESSURE TEST. TEMPORARY ABANDONMENT TREE. FINISH CLEANING PITS, SECURE WELL AND RELEASE RIG. SIGNATURE: (drilling superintendent) DATE: RECEIVED OCT 2 8 i99' Alaska Oil & Gas Cons. Commission Anchor~,,~ 13-35i DESCRIPTION OF WORK COMPLETED COILED TUBING COMPLETION INSTALLATION 5/10/94: Ran GR/CCL/USIT logs & tagged PBTD at 10101' MD. 6/9/94: RIH w/pedoration gun & tagged PBTD at 10103' MD. PU gun & shot initial perforations at: 10080 - 10100' MD (Z4) Ref Log: SWS USIT 5/10/94. POOH w/perf gun. Rigged down. 6/13/94: Ran & set Seal Bore & Tubing Tail Assembly in the well as follows: MIRU & PT equipment. RIH w/Seal Bore assembly, consisting of 5.5" X Lock Mandrel, 3" ID x 10' long Sealbore Extension, 2-7/8" OD x 15' long M8R Pup Joint, 2-7/8" X Nipple (2.313" ID), followed by 2-7/8" OD x 15' long M8R Pup Joint, 2-7/8" XN Nipple w/ 'D' plug installed, and a 2-7/8" WLEG w/half beveled Mule Shoe. Landed assembly in XN Nipple at 8964' MD. POOH w/setting tool, then RIH w/X-L RT, & 2-7/8" XXN Plug, & set in 2.25" No-Go XN Nipple at 8991' MD. POOH w/running tool, & PT casing & tubing tail to 1600 psi for 40 minutes; good test. RIH & pulled XXN plug, then pumped 8 bbls Diesel to flush tubing. RIH & set a DXN pump-thru plug in the XN Nipple at 8989' MD. POOH. Rigged down. 6/1 7/94 - 6/1 9/94: Ran & set a 3-1/2" Coiled Tubing Completion in the well as follows: MIRU 3-1/2" CTU & PT equipment. MU & RIH w/Seal Assembly & 3-1/2" Coiled Tubing (equipment details of assembly on schematic attached). Spooled CT to 5813' MD, then reversed in 22 bbls Meth Water, cut the CT, & moved in next 3-1/2" CT spool. MU Connector & continued RIH to land in sealbore receptacle. Set down at 8979' MD. PT seals to 1500 psi OK. Pumped 155 bbls Seawater followed by 28 bbls Meth Water down CT, cut CT at surface, MU connection, & MU & landed tubing hanger. PT CT x 5-1/2" annulus to 1500 psi for 30 minutes; OK. Rigged down. 6/21/94: RIH & pulled the 2-7/8" DXN Plug (listed above), then RIH & tagged PBTD at 10086' MD. RECEIVED OCT 2 8 1994 Alaska 0il & {~a$ Cons. Corrli/Ijssion Anchor~,.?. S_~:RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/94 DATE OF SURVEY: 032994 MWD SURVEY JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN . 0 .00 -77.50 0 0 157 157.00 79.50 0 12 247 247.00 169.50 0 12 337 337.00 259.50 0 24 427 426.99 349.49 0 30 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E N 12.80 W .13 .27N .06W S 35.50 W .41 .29N .19W S 30.10 W .22 .llS .44W S 47.50 W .19 .64S .88W VERT. SECT. .0O -.25 -.24 .20 .82 516 515.99 438.49 0 48 606 605.97 528.47 1 23 696 695.92 618.42 2 12 786 785.83 708.33 3 5 880 879.66 802.16 3 42 S 51.20 W .34 1.30S 1.65W S 48.50 W .67 2.42S 2.97W S 42.60 W .91 4.42S 4.96W S 41.00 W 1.00 7.53S 7.72W S 36.40 W .70 11.89S ll.19W 1.62 3.01 5.39 9.03 14.04 976 975.41 897.91 4 30 1072 1071.08 993.58 5 0 1167 1165.67 1088.17 5 35 1262 1260.14 1182.64 6 30 1359 1356.44 1278.94 7 18 1453 1449.56 1372.06 8 18 1548 1543.56 1466.06 8 23 1643 1637.49 1559.99 8 48 1738 1731.19 1653.69 10 6 1834 1825.45 1747.95 11 41 S 32.40 W .88 17.56S 15.05W S 32.70 W .52 24.26S 19.33W S 34.30 W .65 31.57S 24.17W S 34.10 W .95 39.85S 29.80W S 23.00 W 1.60 50.07S 35.29W S' 18.50 W 1.25 62.00S 39.77W S 17.20 W .22 75.14S 44.00W S 15.70 W .48 88.76S 48.02W S 14.10 W 1.40 103.83S 52.02W S 13.40 W 1.67 121.47S 56.32W 20.41 27.88 36.08 45.38' 56.55 69.17 82.91 97.08 112.66 130.81 1930 1919.24 1841.74 12 53 2025 2011.33 1933.83 15 30 2120 2101.92 2024.42 19 30 2216 2191.69 2114.19 22 0 2312 2279.13 2201.63 26 42 S 14 S 10 S 7 S 12 S 12 .10 W .60 W .20 W .30 W .50 W 1.26 141.33S 61.19W 2.88 164.10S 66.11W 4.34 192.32S 70.43W 3.21 225.79S 76.27W 4.90 264.43S 84.78W 151.26 174.55 203.03 236.97 276.54 2407 2362.45 2284.95 30 42 2503 2443.94 2366.44 33 5 2598 2522.27 2444.77 35 47 2693 2598.04 2520.54 38 24 2789 2673.06 2595.56 38 47 S 17 S 18 S 16 S 14 S 11 2885 2748.45 2670.95 ~37 42 S 1© 2979 2823.47 2745.97 36 24 S 9 3074 2900.18 2822.68 35 54 S 9 3169 2977.85 2900.35 34 24 S 8 3265 3057.80 2980.30 32 47 S 10 .80 W .30 W .40 W .70 W .60 W .90 W .00 W .00 W .30 W .40 W 4.99~ 308.39S 96.81W 2.52 356.61S 112.54W 3.06 407.90S 128.53W 2.94 463. liS 143.87W 2.06 521.41S 157.48W 1.23 579.69S 169.08W 1.84 635.46S 178.88W .53 690.81S 187.64W 1.63 744.88S 195.87W 2.06 797.29S 204..48W 322.06 372.55 426.09 483.31 543.18 602.59 659.16 715.09 769.65 822.68 NAL RECEIVED 0CT 2 8 1994 Alaska Oil & Gas Cons. Commission. Anchorc,.,~ S~kRY-SUN DRILLING SERVICES · ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/9 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 3361 3139.78 3062.28 3442 3210.68 3133.18 3554 3309.76 3232.26 3649 3393.98 3316.48 3745 3478.86 3401.36 29 53 27 53 27 42 27 23 28 17 DATE OF SURVEY: 032994 MWD SURVEY JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST S 13.60 W 3.48 846.13S 214.80W S 11.10 W 2.88 884.35S 223.20W S 14.20 W 1.30 935.30S 234.63W S 14.70 W .40 977.85S 245.59W S 10.50 W 2.25 1021.59S 255.35W VERT. SECT. 872.60 911.73 963.95 1007.86 1052.68 3840 3561.90 3484.40 3935 3644.46 3566.96 4029 3726.36 3648.86 4125 3810.16 3732.66 4220 3893.25 3815.75 29 47 29 30 29 17 29 6 28 53 S 12.00 W 1.76 1066.83S 264.36W S 10.40 W .89 1112.92S 273.49W S 11.10 W .42 1158.26S 282.09W S 10.40 W .41 1204.27S 290.83W S 10.90 W .33 1249.53S 299.34W 1098.79 1145.76 1191.89 1238.70 1284.73 4316 3976.75 3899.25 4411 4058.94 3981.44 4504 4139.56 4062.06 4600 4223.04 4145.54 4695 4305.96 4228.46 30 12 30 0 29 47 29 23 29 0 S 10.20 W 1.40 1296.07S 308.00W S 9.30 W .52 1343.03S 316.07W S -9.20 W .22 1388.78S 323.53W S 9.20 W .42 1435.59S 331.11W S 8.30 W .63 1481.40S 338.16W 1332.04 1379.62 1425.90 1473.24' 1519.48 4790 4388.73 4311.23 4885 4471.25 4393.75 4981 4555.00 4477.50 5076 4637.47 4559.97 5171 4719.12 4641.62 29 47 29 36 .28 53 30 36 30 53 S' 9.50 W 1.05 1527.47S 345.38W' S 9.30 W .23 1573.90S 353.07W S 10.20 W .86 1620.13S 361.01W S 13.00 W 2.31 1666.28S 370.51W S 15.00 W 1.12 1713.41S 382.26W 1566.02 1613.02 1659.87 1706.98 1755.53 5267 4801.87 4724.37 5362 4884.59 4807.09 5457 4967.60 4890.10 5551 5049.54 4972.04 5647 5133.30 5055.80 30 0 28 53 29 17 29 23 29 6 S 11.60 W 2.02 1760.73S 393.47W S 10.70 W 1.25 1806.55S 402.51W S 11.60 W .62 1851.88S 411.44W S 11.10 W .28 1897.05S 420.51W S 9.30 W .97 1943.21S 428.82W 1804.15 1850.84 1897.03 1943.09 1989.96 5742 5216.06 5138.56 5837 5298.50 5221.00 5933 5381.55 5304.05 6029 5464.40 5386.90 6124 5546.58 5469.08 29 42 29 53 30 17 30 23 29 47 S 12.50 W 1.77 1988.98S 437.65W S 12.10 W .30 2035.11S 447.70W S 12.30 W .43 2082.17S 457.88W S 13.00 W .38 2129.50S 468.50W S -13.70 W .73 2175.85S 479.50W 2036.55 2083.76 2131.91 2180.41 2228.05 6220 5629.89 5552.39 6315 5712.65 5635.15 6411 5796.78 5719.28 6506 5879.78 5802.28 6602 5963.50 5886.00 29 47 29 0 28 36 29 36 29 0 S 13.20 W .26 2222.25S 490.60W S 13.90 W .92 2267.59S 501.52W S 11.10 W 1.47 2312.72S 511.57W S 9.00 W 1.50 2358.21S 519.58W S 8.10 W .78 2404.67S 526.57W 2275.76 2322.38 2368.62 2414.76 2461.63 ~iRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/9 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 6696 6045.55 5968.05 6792 6129.31 6051.81 6888 6213.36 6135.86 6983 6296.45 6218.95 7078 6379.33 6301.83 DATE OF SURVEY: 032994 MWD SURVEY JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 29 23 S 10.60 W 1.37 2449.90S 534.02W 29 6 S 10.90 W .35 2495.99S 542.77W 28 42 S 10.90 W .42 2541.55S 551.54W 29 17 S 11.30 W .66 2586.74S 560.41W 29 12 S 11.10 W .15 2632.28S 569.43W VERT. SECT. 2507.40 2554.29 2600.66 2646.70 2693.1.1 7174 6463.05 6385.55 7270 6546.65 6469.15 7366 6630.24 6552.74 7461 6713.01 6635.51 7557 6796.60 6719.10 29 23 S 11.10 W .21 2678.38S 578.47W 29 30 S 12.30 W .62 2724.59S 588.05W 29 23 S 13.00 W .37 2770.65S 598.38W 29 23 S 12.00 W .52 2816.18S 608.48W 29 30 S 11.40 W .32 2862.39S 618.05W 2740.07 2787.27 2834.47 2881.10 2928.29 7651 6878.46 6800.96 7744 6959.68 6882.18 7838 7042.17 6964.67 7932 7124.97 7047.47 8027 7208.62 7131.12 29 23 S 12.00 W .33 2907.65S 627.42W 28 53 S 11.30 W < .65 2952.01S 636.57W 28 23 S 12.20 W .70 2996.14S 645.74W 28 6 S 12.70 W .41 3039.58S 655.33W 28 30 S 13.00 W .45 3083.49S 665.35W 2974.50 3019.80 3064.86 3109.35' 3154.39 8123 7293.02 7215.52 8215 7373.83 7296.33 8310 7457.32 7379.82 8405 7541.01 7463..51 8499 7623.61 7546.11 28 23 S'12.20 W .41 3128.12S 675.33W 28 42 S 12.50 W .36 3171.08S 684.73W · 28 17 S 13.70 W .74 3215.22S 695.00W 28 12 S 14.40 W .36 3258.84S 705.92W 28 47 S 13.40 W .82 3302.'38S 716.69W 3200.12 3244.09 3289.41 3334.36 3379.20 8593 7706.57 7629.07 8685 7789.03 7711.53 8778 7873.28 7795.78 8871 7957.71 7880.21 8966 8044.01 7966.51 27 17 S 14.10 W 1.63 3345.31S 727.19W 25 17 S 14.10 W 2.17 3384.84S 737.12W 24 47 S 14.40 W .56 3423.01S 746.81W 24 47 S 13.40 W .45 3460.87S 756.18W 24 36 S 13.40 W .21 3499.49S 765.38W 3423.39 3464.13 3503.49 3542.49 3582.18 9060 8129.52 8052.02 9156 8217.01 8139.51 9251 8303.96 8226.46 9345 8390.00 8312.50 9440 8476.34 8398.84 24 30 S 13.20 W .14 3537.50S 774.36W 24 6 S 15.00 W .88 3575.81S 783.98W 23 23 S 14.60 W .76 3612.80S 793.76W 24 6 S 13.60 W .86 3649.52S 802.97W 25 12 S 15.30 W- 1.38 3687.88S 812.87W 3621.23 3660.72 3698.95 3736.79 3776.39 9532 8559.52 8482.02 9628 8646.27 8568.77 9721 8730.42 8652.92 9813 8813.66 8736.16 9845 8842.64 8765.14 25 23 S 15.10 W .24 3725.82S 823.18W 25 17 S 14.60 W .25 3765.55S 833.71W 25 6 S 15.50 W .47 3803.78S 843.99W 25 17 S 14.60 W .47 3841.61S 854.16W 24 53 S 15.70 W 1.92 3854.71S 857.71W 3815.66 3856.73 3896.29 3935.43 3948.99 iRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/94 DATE OF SURVEY: 032994 MWD SURVEY JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9908 8899.79 8822.29 24 53 S 15.70 W .03 3880.25S 864.89W 3975.47 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3975.47 FEET AT SOUTH 12 DEG. 33 MIN. WEST AT MD = 9908 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 192.57 DEG. RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/94 DATE OF SURVEY: 032994 JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -77.50 1000 999.34 921.84 2000 1987.20 1909.70 3000 2840.37 2762.87 4000 3701.07 3623.57 .00 N .00 E .00 19.15 S 16.06 W .66 .66 157.68 S 64.86 W 12.80 12.13 647.77 S 180.82 W 159.63 146.83 1144.33 S 279.36 W 298.93 139.30 5000 4571.64 4494.14 6000 5439.38 5361.88 7000 6311.27 6233.77 8000 7184.89 7107.39 9000 8074.93 7997.43 1629.17 S 362.63 W 428.36 129.43 2115.20 S 465.20 W 560.62 132.26 2594.90 S 562.04 W 688.73 128.11 3070.94 S 662.45 W 815.11 126.38 3513.26 S 768.66 W 925.07 109.96 9908 8899.79 8822.29 3880.25 S 864.89 W 1008.21 83.14 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. kRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/94 DATE OF SURVEY: 032994 JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV, = 77,50 FT, OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 ,00 -77,50 77 77,50 ,00 177 177.50 100.00 277 277.50 200.00 377 377,50 300.00 .00 N .00 E .00 N .00 W .34 N .08 W .21 N .25 W .35 S .58 W ,00 ,00 ,00 ,00 ,00 .00 ,00 ,00 ,00 477 477,50 400.00 577 577,50 500,00 677 677,50 600,00 777 777,50 700.00 877 877.50 .800,00 .96 S 1,24 W 1,96 S 2.45 W 3.90 S 4.48 W 7.19 S 7.43 W 11.77 S 11,11 W .01 ,00 ,02 ,01 ,06 ,04 ,16 ,10 ,34 ,17 978 977,50 900.00 1078 1077,50 1000,00 1178 1177.50 1100,00 1279 1277.50 1200.00 1380 1377,50 1300,00 17.70 S 15.14 W 24.73 S 19,63 W 32'.53 S 24.83 W 41.49 S 30,91 W 52.56 S 36.34 W ,60 ,26 ,94 ,35 ,38 ,44 ,97 .59 .74 ,76 1481 1477,50 1400.00 1582 1577.50 1500,00 1683 1677,50 1600,00 1785 1777,50 1700.00 1887 1877.50 1800.00 65,87 S 41.07 W 79.93 S 45.48 W 94.76 S 49,70 W 111.93 S 54.04 W 132.08 S 58,87 W 3,73 1,00 4,81 1.08 6,00 1,18 7.56 1,56 9 · 68 2,13 1989 1977,50 1900,00 2094 2077.50 2000,00 2200 2177,50 2100,00 2310 2277.50 2200.00 2424 2377.50 2300.00 155.22 S 64.35 W 184.04 S 69.32 W 220.24 S 75,10 W 263.68 S 84.62 W 316.89 S 99.55 W 12 16 23 32 47 ,48 2,79 .69 4,21 ,22 6,53 ,70 9,48 ,00 14,30 2543 2477,50 2400,00 2666 2577,50 2500.00 2794 2677,50 2600,00 2921 2777,50 2700.00 3046 2877.50 2800.00 377.90 S 119,40 W 447.61 S 139.73 W 524,90 S '158.20 W 601,72 S 173.31 W 674.60 S 185.07 W 65 89 117 144 168 .84 18,84 ,44 23,60 ,19 27,75 .20 27,01. ,51 24,30 3168 2977,50 2900,00 3288 3077,50 3000,00 3404 3177,50 3100,00 3517 3277,50 3200.00 3630 3377,50 3300,00 744.64 S 195,84 W 809.56 S 206,83 W 867.07 S 219.78 W 918.89 S 230.48 W 969.59 .S 243.43 W 191,08 210,83 226,93 240,07 252,93 22,57 19,75 16,10 13,14 12.86 iRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/94 DATE OF SURVEY: 032994 JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3743 3477.50 3400.00 3857 3577.50 3500.00 3972 3677.50 3600.00 4087 3777.50 3700.00 4202 3877.50 3800.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 1020.87 S 255.21 W 265.95 13.02 1075.56 S 266.22 W 280.47 14.52 1131.31 S 276.86 W 295.46 14.98 1186.39 S 287.55 W 310.12 14.67 1241.00 S 297.70 W 324.51 14.39 4316 3977.50 3900.00 4432 4077.50 4000.00 4547 4177.50 4100.00 4662 4277.50 4200.00 4777 4377,50 4300.00 1296.50 S 308.08 W 339.36 14.85 1353.60 S 317.81 W 354.93 15.56 1410.20 S 326.99 W 370.20 15.28 1465.78 S 335.88 W 384.96 14.75 1521.13 S 344.32 W 399.'56 4892 4477.50 4400.00 5006 4577.50 4500.00 5122 4677.50 4600.00 5238 4777.50 4700.00 5353 4877.50 4800.00 1577.41 S 353.64 W 414.69 15.13 1632.35 S 363.21 W 429.20 14.50 1689.35 S 375.88 W 445.01 15.81 1746.94 S 390.64 W 461.36 16.35 1802.70 S 401.78 W 476.40 15.04 5468 4977.50 4900.00 5583 5077.50 5000.00 5697 5177.50 5100.00 5812 5277.50 5200.00 5928 5377.50 5300.00 1857.32 S 412.56 W 490.85 14.45 1912.51 S 423.54 W 505.60 14.75 1967.52 S 432.94 W '520.12 14.52 2023.30 S 445.17 W 535.28 15.16 2079.85 S 457.37 W 550.81 15.53 6044 5477.50 5400.00 6159 5577.50 5500.00 6274 5677.50 5600.00 6389 5777.50 5700.00 6503 5877.50 5800.00 2136.99 S 470.23 W 566.69 15.89 2193.05 S 483.69 W 582.13 15.43 2248.64 S 496.84 W 597.29 15.17 2302.41 S 509.51 W 611.54 14.25 2356.93 S 519.38 W 625.87 14.33 6618 5977.50 5900.00 6732 6077.50 6000.00 6847 6177.50 6100.00 6961 6277.50 6200.00 7075 6377.50 6300.00 2412.35 S 527.66 W 2467.60 S 537.33 W 2522.27 S 547.83 W 2576.31 S 558'33 W 2631.27 S ' ' 569.23 W 640.51 14.63 655.17 14.66 669.62 14.45 683.77 14.16 698.40 14.63 7190 6477.50 6400.00 7305 6577.50 6500.00 7420 6677.50 6600.00 7535 6777.50 6700.00 7649 6877.50 6800.00 2686.37 S 580.04 W 713.08 14.68 2741.65 S 591.77 W 727.95 14.86 2796.60 S 604.31 W 742.74 14.80 2851.80 S 615.91 W 757.55 14.81 2907.12 S 627.31 W 772.40 14.85 £~'~qRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/13-35I 500292246000 NORTH SLOPE COMPUTATION DATE: 4/ 4/94 DATE OF SURVEY: 032994 JOB NUMBER: AK-MW-40028 KELLY BUSHING ELEV. = 77.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7764 6977.50 6900.00 2961.66 S 638.49 W 786.86 14.46 7878 7077.50 7000.00 3014.81 S 649.78 W 800.67 13.81 7991 7177.50 7100.00 3067.03 S 661.55 W 814.09 13.43 8105 7277.50 7200.00 3119.92 S 673.55 W 827.85 13.76 8219 7377.50 7300.00 3173.03 S 685.17 W 841.68 13.82 8332 7477.50 7400.00 3225.78 S 697.58 W 855.42 13.74 8446 7577.50 7500.00 3277.83 S 710.77 W 868.92 13.50 8560 7677.50 7600.00 3330.76 S 723.53 W 882.79 13.87 8672 7777.50 7700.00 3379.56 S 735.79 W 894.75 11.96 8782 7877.50 7800.00 3424.90 S 747.29 W 905.15 10.40 8892 7977.50 7900.00 '3469.77 S 758.30 W 915.31 10.16 9002 8077.50 8000.00 3514.40 S 768.93 W 925.33 10.02 9112 8177.50 8100.00 3558.71 S 779.44 W 935.21 9.88 9222 8277.50 8200.00 3601.72 S 790.87 W 944.67 9.46 9331 8377..50 8300.00 3644.08 S 801.66 W 953.81 9.14 9441 8477.50 8400.00 3688.40 S 813.02 W 963.78 9.98 9551 8577.50 8500.00 3734.06 S 825.40 W 974.41 10.63 9662 8677.50 8600.00 3779.83 S 837.44 W '985.04 10.63 9773 8777.50 8700.00 3825.08 S 849.84 W 995.50 10.46 9883 8877.50 8800.00 3870.29 S 862.09 W 1005.93 10.43 9908 8899.79 8822.29 3880.25 S 864.89 W 1008.21 2.28 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. Date: September 20, 1994 P.O. Box 10036( I~,nchorage, AK Transmittal #: 94111 99S10,~ ~ Subject: From/Location: Telephone: To/Location: ARCO Static Pressure Survey's Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution Number! (M-D-Y) . 04-19 ~ 05-23-94 ~ Pressure Survey ! 1 SCH 04-45i { 07-05-94 j Pressure Survey { 1 SCH 11-29i ~ 07-08-94 ~ Pressure Suwey { 1 SCH 11-36 ~ 06-09-94 t PressureSuwey ~ 1 SCH 12-07A j 06-06-94 I Pressure Su~ey. ~ 1 SCH j 12-10A j 06-07-94 ~ Pressure Suwey ~ 1 SCH j 12-12 { 06-08-94 ~ Pressure Su~ey { 1 SCH ~ 12-16A ~ 07-07-94 ~ Pressure Su~ey ~ 1 SCH · 12-26 ~ 06-08-94 ] Pressure Su~ey ~ 1 SCH 13-31 ~ 06-09-94 Pressure Sudsy ~ 1 SCH 13-35~ 06-09-94{ Pressure Suwey ~ 1 SCH 18-01 ~ 06-04-94 ~ Pressure Suwey ~ 1 SCH 18-08 ~ 06-10-94 .~ Pressure Su~ey ~ 1 SCH ~ Number of Records: 13 Karla Zuspan Distribution: Central Files BPX State of Alaska Mobil Please Ie receipt Phillips Exxon D&M nd Date: ~smi ,I. ARCO Alaska, Inc. Is a Sul~sldlary of A~lamlcRIchflaldCompany ARCO Alaska, Inc. Date: Subject: From/Location- Telephone: To/Location: June 21, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Contractor Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 'i Sch ..... Number= ,(M-D-Y) t Scale '~' I 1-05ST 6-13-94 Dual Burst 1, 5" 1-06 I 6-13-94 1/ DuaiBurst ! 1 5" f 1-11 ~ 6-14-94 1-' Per[Record i 1 5" 1-25 6-10-94 t/ Per[ Record ~ 1 5" i 1-29 i 6-14-94 i'" Dual Burst i I 5" f 1-30 I 6'08'94 I/ CNL I 1 5" f 3-02 ¢ 6-07-94 ix Cutter i 1 5" ! 3-19 6-05-94 t-/ Per[ Record 1 5" ~"+- i 4-36 i 6-11-94 1~'' Per[Record i 1 5" t%'~ ! 4-41 i 6-12-94 iv/Cutter Record i I 5" '~O ! 5-11 I 6-11-94 I / Dual Burst I 1 5" ~ i 9-15 { 6-13-94 J / IniProf i 1 5" 5c~ t 9-18 I 6-14-94 ! / InjProf I 1 5" Z.~ { 9-25 f 6-14-94 i / injProf i i 5" LccJ i 11-35 i 6-11-94 j'.-' Per[ Record i 1, 5" ¢/.¢ i 11-36 i 6-07-94 I/ Per[ Record f 1, 5" 40 ! 13-31 ( 6-09-94 i'/'' Per[ Record i 1 5" ql I 13-35 i 6-09-94 1/' Per[ Record i 1 5" ~2.. ~. 14-03 i 6-15-94 i ~- Prod Log ! 1 5" 14-03 i 6-15-94 t,- Dual Burst l 1 5" ~ ! 16-23 1,6-13-94 '~' Leak Detection , , 5" t 16-23 ! 6-10-94' i/AlPha Tubing i 1 5" ?N 17-02 I 6-6-94 if PmdProf l 1,1 "&5" " 18-04 ! 6-12-94 f Dual Burst ! 1, 5" Sch 18-19 I 6-10-94 .--Leak Detection ~ 1, 1" & 5" Sch * The correct AP! # for 1-05ST is 50-029-20076-00 Number of Records: E. DoGroy Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska- ARCO Alaska, inc. Is a Subsidiary of AllamlcRIcMleldCompany ARCO Alaska, Inc. Date' May 24, 1'994 P.O. Box 100360, ~,~horage, AK Transmittal #: 94040 99510~ ~ Subject: From/Location: Telephone: To/Location: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 · (907) 263-4310 Distribution ARCO ' ~ Well i. Log Date Tool Type I Run, C0ntmctor i Number (M-D-Y) Scale ~=i OWDW'sw 4-29-94 v,// PITS 1, 5" SCH ~ ! 1-9A 5-14-94 ,//'~Per[ Rec . 1, 5" SCH -i,,,/~ ! 1~20 5-7-94 ~/' Perf Rec 1, 5" , SCH iq- '/'I 2-4 5-11-94 v/ Prod Pmf 1, 5" sCH --'Xj' 2-4 5-11-94 ,// CNL 1, 5" sCH iS0 2-5 5,-7-94 ;..~ Prod Pmf 1, 5" SCH 2-5 5-7-94 v/ CNL 1, 5" SCH t.3..Gii 2-18 i 5-8-94.. ~/ Prod Prof 1, 5" SCH ~c~ //. 2-20 4-30-94 ~.//Prod Prof 1, 5" SCH "~i 2-20 ,.. '5-:13-94 .~/' CNL 1, 5'~ SCH ~7_.. , 3-1-9 4-4-94 ~/~.. Bridge Plug 1, 5" SCH 3-29 ! 5'-3-94 ,,/ Bridge Plug ! 1, 5" SCH ~'~ /! 3-32A! 5-9-94 vuSIT (Cern & Con') ! 1, 5" SCH ~L~ ~X.I .3-32A ! 5-12-94 ..-' PerfRec 1, 5" SON ' ![~v/ 4-5A ~5-17-944 v/ PerfRec 1,5'" SCH X~ 4-5A 5-17-94 ~ USIT 1, 5" SCH 50 5-6 4-30-94 ,/ Prod Prof ' 1, 5" SCH ,,, , (,~ 5-35 5-3-94 ,// TDT-P 1~. 5" ..... SCH ~ 6-10 4-5-94 v/ Leak Detect 1, 5" SCH t . 5" SCH {,lO - 6-11 5-14-94 .'.'Packer Set Rec 1, 5'; SCH ~~ 6-22A 5-14-94 v~, PerfRec 1~5" SCH - 7-3 ~ 5-8-94 .,./ Prod Prof 7-3 5-7-04 ~ Per[ Rec . 1~.5" SCH !~,/ 7-2,3 5-10-94 !~'Jewelry Set Rec '" 1, 5"' ', SCH X~ 7-23 5-15-94 v'Oompletion Rec 1~ 5" SCH 9-13 5-16'94 ~ v"' ,Bridge Plug 1, 5" SCH 9-26 4-~-94 v"' Per[ Rec,,. 1, 5"'" SCH ~)7.. 9-42 5-15-94 v/' Leak Detect 1, 1" 2" 5"' $CH lur~ 9-47 ' 5-16-94 V Packer Set Rec 1,"5"' ' SCH ~q,. 11-36 j 5-18'94 .,/ USIT 1, 5" $CH IL,,9 t 12-8Bf 5-4-94 ,/' Prod Prof 1, 1" 5" SCH ~q~ i 13-8 5-2-94 v'~ In]Pmf 1, 5" SCH i,~g). ! 13-31 5-2-94 ,,, ,./ USIT I 1, 5" ,, SCH ~! ~ 13-35 I 5-10-94 ~ USIT I 1, 5" SCH ,~ i i4-7~ 5-13-94 v-Tubing patch Rec~ '1, 5" SCH ~r./ ! 14-15 i 5-17-94 ~ CNL f '1,5" SCH ?~ I 14-41 f 5-8-94 ,/Dual BurstTDT-P i 1, 5" SCH ~/c~' I 16-26 5-6-94 >-/ PerfRec t 1,5"" SCH Ill i 17-19 5-12-94 v'" Per[ Rec ~ 1, 5" S, CH i~:~ 18-1 5-16-94 v~ Perf Recl 1, 5" SCH '?0'- ~0- ~/O.- ff~- Ir~., Is a Subsidiary o! Atlan~lcRIchfleleComl:~ny ARCO Alaska, Inc. Date: Apr 22, 1994 P.O. Box 100360, "~?horage, AK Transmittal #: 94035 99S10.~ ~. Subject: From/Location: ARCO Open Hole Finals John E. DeGrey/ATO- 1529 Telephone: (907) 263-4310 To/Location' Distribution iWell . · Number: { 01-09A // 01-09A ~.-'~ ~i 01-09A '~ 01-09A :~q,..~ ~ 04-45 · I 04-45 9-34A Log Date i Tool Type (M-D-Y) i 03-17-94 i ~. Dual Lateroiocj 03-17-94 i¢' SSTVD 03-17-94 1/ BHCAJGR 03-17-94 !/,. CNL/GR 03-18-94 I 'MWD/TVD:DGR, . EWR-P4 03-18-94 03-30-94 i /MWD/MD:DGR, EWR-P4 9-34A 03-30-94 9-34A 04-19-94 12-13A 03-31-94 12-13A 03-31-94 12-13A 03-31-94 12-13A 03-31-94 13-31 04-14-94 13-31 04-14-94 13-35 03-31-94 13-35 03-31-94 15-07A 03-15-94 15-33 03-29-94 jvMWD/MD:GRC, , EWR,FXE I ,,MWD/TVD:GRC, ..~ r~ ~/R,FXE i,/ Slimhole ],/MWD: SSIVD ',,/, BHCA/GR ~/ CNL/GR ./Dual Lareroio~ ,/MWD/MD:GRC, EWR,FXE vlVlWD/TVD:GRC, EWR,FXE ' ,H~iWD/MD:GRC, , EWR,FXE , '/MWD/TVD:GRC, EWR,FXE ',/ Slimhole ' xMWD/MD: DGR, CNP,SLD ' ** ' 15-33 ' 03-29-94 vMWD/'I'VD:DGR, ~-"~/! , CNP,SLD ii I 15-33 03-29-94 ~MWD/'I'VD:DGR,EwR,FXE 15-33 03-29-94 t/MWD/MD: DGR, .?' _ EWR,FXE v"lncludes spiral 'notebook and disk DS#15 logs are Pilot Hole Number of Records: 22 Joh~n E. DoG re~~ Run, Scale 1. 2"&5" 1, 1"&2" 1. 2"&5" 1. 2"&5" 1. 2"&5" 1. 2"&5" 1-7, 2"&5" 1-7, 2"&5" 1,2" 1. 1"&2" 1. 2"&5" 1. 2"&5" 1. 2"&5" 1, 2"&5" 1, 2"&5" 1, 2"&5" 1, 2"&5" , 2" 1-9, 2"&5" 1-9, 2"&5" 1-20 2"&5" 1-20 2"&5" Contractor Atlas Atlas Atlas Atlas Sperry Sperry Sperry Sperry Sperry Atlas Atlas Atlas Atlas Sperry Sperry Sperry Sperry Sperr7 Sperry Sperry Sperry Sperry ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany a/IEMORANDUI i TO: THRU: FROM: Blair Wondze -~ Bobby Foste~~ Petroleum Inspector State of ska Alaska Oil and Gas Conservation Commission DATE: March 23, 1994 FILE NO: AGRICXBD.doc SUBJECT: BOPE Test - Nabors 28E ~ PTD~~~ ~ Wednesday, March 23, 1994: I traveled this date to ARCO's DS 13-35i being drilled by Nabors rig 28E and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows there were no failures. The rig was clean and all equipment appeared to be in good working order. The location was clean and there was good access to all areas of the rig. Summary: I witnessed the satisfactory BOPE Test on Nabors 28E - no failures - test time 2 hours, Attachment; STATE OF ALASKA' OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: 3/23/94 Drlg Contractor:......... NABORS ' ' Rig No. 28E PTD # ~, ,.94,4.,1 ..... Rig Ph~ '~'~ 65gL4883 ..... Operator: :''' ~' ARCOAj.~$~ Rep.: G. RAMSEY .[_ .,. , ,~,, i i.., ., , i ,. . il i , Well Name: DS 13-35i ..... Rig Rep.: . L. LINDER Casing Size: ..... 9'5/8 ........ S~t t~ ..... . ,~,~,p,,5" ...... Location: Sec. i'4 Ti"' l'bN 'R."" ~4E' M~ddlan "U' ' ' Test: ln'i~al"'".',X' Weekly ._ Other .,. ' ..................... Test MISC, INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK ,. Well Sign .. OK Upper Kelly / IBOP I ! 500\5000[ P Housekeeping: '"~ (Gen) Drl. Rig OK" Lower Kelly /IBOP "'i- i s00\sd0d ' I' P Reserve Pit 'N iA' _ ~..L Bali Type 1j 5o~00 ! P ....... lnsideBOP .1 . 5~),.6\5~ "! BOP STACK: Quan. Annular Preventer 1 Pipe Rams .... Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Pressure 500~000 50o So6o' 500~5000 0O o00' 2 500~000 MUD SYSTEM: V"rsual Alarm Trip Tank OK OK Pit Level Indicators - OK' r. ~)K~ Flow Indicator ' ~(" 'OK Gas Detectors 'OK OK · . P/F Test P CHOKE MANIFOLD: Pressure P/F P'' No. Valves 17[ ..500~000 I P ;"P' No. Flanges 42' I 500\5000 I P . i.P' Manual Chokes ..... 2 ........ I ! P P Hydraulic Chokes I , p.. - '15' ' ACCUMULATOR SYSTEM: System Pressure 3,000 ~ P Pressure After Closure ...... 1,55~ ....... ! P" 200 psi Attained After Closure '0' - minu~s' 27 ' sec. System Pressure Attained ..... 1"' minutes' 50" sec. Blind Switch Covers: Master:. 'YEs Rem~){e~j 'YES Nitgn. Btl's: .... 8 ~ 2000 . . . . Psig. ,, ,,t,,,[ [, [ ~ [[~. i] , [ [[ , NUmber of Failures: 0 ,Test Time: 2.0' Hours~ Number Of valves tested' ' 23 Re,ir or R~l~;~'~"~{'i~ii~'' Equipment will be made within _ 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC CommissiOn Office at: Fax N~). ' 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279.1433 RE~KS: VERY GOOD-TEST .1 ,.. , . . . : . · : ....... . . . ::..~ :: : : - : - : · i i i .IlI I Il( Il I Ill~ I.. Il I J I .JI II :.l. [ ~ '. ....... .Il I~ . 1. I I I . Il I I I Il flI } . ] . J 11 [ mlllll~[[I I . .~ . Distribution: orig-Well File c - OperJRig c- Database c - Trip Rpt File c - Inspector STATE WI?NEss REQUIRED.- YES X NO [, , i1 , , ~ : - 24 HOUR NOTICE GIVEN YES ,X., NO - . [ Ill l . Il I I .I I I Illl..I Ill · J__ I I Waived By: W~nessed By: FI-O21L (Rev. 7/19) AGRICXBD.XLS WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 March 18, 1994 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 13-35 ARCO Alaska, Inc. Permit No. 94-41 Sur. Loc 1521'NSL, 1411'WEL, Sec. 14, T10N, R14E, UM Btmhole Loc. 2728'SNL/ 2309'WEL, Sec. 23, T10N, R14E Dear Mr. Jordan: EncloSed is the approved application for permit to drill the above referenced well. The permit to drill 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and .of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the . Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department oS Environmental Conservation w/o encl. ~(~ r)ri,~h,H o,, recyctod papo, b y C,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepeni-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 80.1 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28315 4. Location of well at surface 7. Unit or property Name 11. Type Bond(~ee 2o 1521' NSL, 1411' WEL, SEC. 14, TION, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2512' SNL, 2286' WEL, SEC. 23, TION, R14E 13-35 U-630610 _ At total depth 9. Approximate spud date Amount 2728' SNL, 2309' WEL, SEC. 23, TION, R14E 3/25/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and 'rVD) property line ADL 28316 feet No close approach feet 2560~'' 10252' MD/9181' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (~e 2o ^^c 25.o~5 (e)(2)) Kickoff depth 55o feet Maximum hole ancjle~o.2~ o Maximum surface 2870 psig At total depth (TVD) ~100'/3750 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 112' 112" 260 sx Arcticset (Approx.) 12-1/4" 9-5/8" 47# L-80 NSCC 3441' 31' 31' 3472' 3265' 870 sx CS lll/375 sx "G"/250 sx CS ll 8-1/2" 5-1/2" 17# LaO/NaO BTC/LTC 10232' 30' 30' 10252' 9181' 406 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor su, c RECEIVED Intermediate Production MAR 1 4 1994 Liner Pedoration depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~l Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify t~,~ the foregoi~g~,~l~ is ~u_e and correct to the best of my knowledge Signed ~,/~ ~/'~ ~ Title Drilling Engineer Supervisor Date ./~-'//'' ' ~' ~, Commission Use Only Permit Number IAPI number IApproval date See cover letter ~' ~-.//- ~/'/ 150- 0.~'-2_2. ~'~<::~ I '2 - / ~. -- ?ti for other requirements Conditions of approval Samples required [] Yes ~I No Mud log requireo [] Yes J~ No Hydrogen sulfide measures [] Yes J~ No Directional survey requ~recl ~ Yes [] No Required working pressure for BOPE 1-12M; r-13M; J~5M; CIIOM; 1'-115M; Other: ORIGINAL SIGNED BY by order of Approved by RUSSELL A. DOUGLASS Commissioner tne commission Form 10-401 Rev. 12-1-85 Submit cate IWell Name: IDS13-35i Well Plan Summary I Type of Well (producer or injector): I WAG INJECTOR [ Surface Location: 1521'FSL 1411FEL S14 T10N R14E UM Target Location: 2512 FNL 2286'FEL S23 T10N R14E UM Bottom Hole Location: 2728 FNL 2309' FEL S23 T10N R14E UM I AFE Number: i 4J0253 I Estimated Start Date: ] 3/25/94 I~m: 110,252' I ITVD: I Well Design (conventional, slimhole, etc.): I Rig: I Nabors 28E I Operating days to complete: [ 15 19,181' I IaTE: 180.1 I Ultra-Slimhole Longstring Formation Markers: Formation Tops TVD (brt) MD (brt) K-12 6466 7141 K- 10 6996 7748 K-5 8102 9016 LCU/SAG RIVER 8899 9929 SHUBLIK 8926 9960 TSAD/Zone 4 8970 10010 Zone 4A/X-Ray 9001 10046 OOWC 9050 10102 Top HOT 9065 10119 TD 9181 10252 Casing/Tubin t'rogram: Hole Size Wt/l Hole Siz~ Csg/ - WtTFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80 32/32 112/112 12-1/4" 9-5/8" 47# L-80 NSCC 3441 31/31 3472/3265 8.5" 5-1/2" 17# L80/N80 BTC/LTC 10232 30/30 10252/9181 N/A 3-1/2" Coil 0.203" L80 Equiv N/A (+/-) 7071 29/29 (+/-) 8000/6393 Tubing RECEIVED Well Plan Summary MAR '1 4 1994 Alaska 0il & Gas Cons. Commission Anchorage Page 1 Logging Pro Open Hole'Logs: [' Cased Hole Logs: GR/BHCS/DIL from TD to 200' above TSAD CBL from TD to 500' above the TSAD Mud Program: ! Special design considerations ! None. SurthC'~ Mud Pro, p,e,rties: I ....... ' Dens'ity Marsh Yield 10 sec '" 10 min pH Fluid (PPG) V!scosityI Point gel ,, ,gel Loss 8.5 200 30 30 40 9 15 tO tO tO tO tO tO tO 9.2 ~'00 60 60 80 10 25 Ifi'termediate MUd PrO, perties: ! ', ' ' D~nsity 'Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Poin, t gel gel Loss N/A N/A , N/A , ,, 'Production Mud Pro erties"' Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel , Loss "'9.'0 25 8' 3 7 8 "4 tO tO tO tO tO tO tO 9.8 50 13 10 15 i0 10 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: ,1 550'@ 1.0 deg/100' l Maximum Hole Angle: { 29.24 DEG Close Approach Well: No close-approach wells. The above listed wells will be secured during the close approach. RECEIVED Well Plan Summary MAP, 1 4. 1994 Alaska Oil & Gas Cons. Commission Anchorage Page 2 , , , , , , , . , 10. 11. 12. Notes' a. bo Co Operations Summary DS 13-35i MIRU drilling rig. N/U diverter and function test same. Drill 12-1/4" hole to surface casing point. Run and cement 9-5/8" sudace casing. Nipple up mOPE and function test same to 5000/250 PSI. PU 8.5" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' new hole and perform leak-off test. Drill 8.5" hole to TD. Wiper trip, Primary plan is to Icg with GR/BHCS/DIL from 200' above TSAD to the base of Zone 4. Run and cement 5-1/2" production casing-- Bump plug with filtered Seawater. Test casing to 3500 psi for 30 minutes. Back out Landing Joint, Run & test packoff to 5000 psig. RIH w/2-7/8"" DP to 2000' and Displace filtered sea water w/diesel for freeze protection. POOH L/D 2-7/8"" drill pipe. . Freeze protect top 2000' of 5-1/2" x 9-5/8" annunlus with 60/40 methanol water mixtUre. ND BOP's, NU tree and test same. Release rig. MIRU wireline unit run cement bond Icg to 500' above TSAD. RDM© wireline unit. MIRU Coil Tubing Unit and perform coil tubing completion. Anticipated BHP: Maximum AntiCipated BHP: Surface Pressure' PlannedCompletion FlUid· 3650 psi @ 8800 sstvd 3750 psi @ 8800 sstvd 2870 psi 8.6 ppg Sea Water The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 :psi/fi). Based on previous logs at Drill Site 13, no potential productive zones are anticipated above 8819' TVD (TSAD). REC£1V£D MAR ] 4 1994- Alaska 0il & Gas Cons. Commission Anchorage DS13-35i CEMENT PLAN - BJ Casing Size: Circ. Temp.: Spacer: Lead Cement: Tail Cement: 9-5/8" SURFACE CASING 9-5/8", 47# 38°F 50 bbls fresh water ahead of lead slurry Retarder 12.2 ppg 1.92 cuft/sx Coldset III Additives: Weight: Yield: Class G Additives: Weight: Yield: Volume (sacks): 870 Mix Water: 10.5 gps Thickening Time: > 4 hrs @ 50°F Volume (sacks): 375 2% A-7, FP-6L lghs 15.8 ppg Mix Water: 5.0 gps 1.15 cuft/sx Thickening Time: >3-1/2 hrs @ 50°F Retarder 15.6 ppg 0.95 cuft/Sx Top Job: Coldset II Additive: Weight: Yield: Cement Volume Summary: (1) Lead slurry to surface w/ 100% excess Volume (sacks): 250 Mix Water: 3.7 gps Thickening Time: >2 hrs @ 50°F (2) Tail slurry volume: 375 sx, (to cover at least 500' of casing shoe w/100% excess + 80' shoe vol.). (3) Top job volume 250 sx (fixed volume) 5-1/2" LONGSTRING CASING Casi~g Size: Circ. Temp.: Spacer: 5-1/2", 17# 140°F 70 bbls of MCS-4 Spacer weighted 1 ppg above current mud weight Lead Cement: Tall Cement: Class G Additives: Weight: Yield: Fluid Loss: Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 203 A-2: 3%, FL-52: 0.4%, CD-32: 0.5%, FP-6L: lghs 11.0 ppg Mix Water: 20.92 gps 3.31 cuft/sx Thickening Time: >5 hfs @ 140°F 150-250 cc Free Water: 0.0 cc Volume (sacks'): 203 A-2: 0.1%, FL-52: 0.3%, CD-32: 0.5%, FP-6L: lghs 15.8 ppg Mix Water: 4.85 gps 1.14 cuft/sx 100-150 cc RECEIVED 1 4. 1994 -,.~,:: ~kd U;i & Gas Cons. C0rrlrnJssi0rl Thickening Time: 3.5 - 4.5 hrs @ 140°F,~ . g~nc~0ra-e Free Water: 0.0 CC Cement Volume Summary: (1) Lead Slurry to 500' MD above top of production packer at 8000' MD BRT with 30% excess (2) Tail Slurry to 500' MD above Top of Sadlerochit (top of SAD @ 10,010' MD) with 30% excess plus 80' of 5-1/2", 17# capacity for float joints TWB, 3/11/94 7 "'-'--i 5 c.--~ 20 m-.--' 19 D---, / 11 12 ---a13 27 28 D-..-.J l~-'J 30 New injectors with MI tripled with well 13-32 ~ 25 L-a18 ~-g17 ' =---D 23A DFJ 10/25/93 r rudhoe 13ay I)rilli /'A' Prudhoe Bay unit, Alaska Drill Site 13 Well: DS //13-35 Well Plan 'DS 13-35i WPi 3/10/94 7,50 HALL I BURTON D~ ILL lNG SYSTEMS CRITICAL. ~flINT DAIA MOOO.o0'lqc O.o0'Azl. TVDo N/S E/VEo TIE IN ON 550 55o o. o E Kr,. ~' STAR* 0.00' 0.00' OF BUILD ! 1.00'/100 Ct START OF BUILD 1050 5.00'19~.00' 1049 21 S 5 V E 1.5O'/tO0 - START DF 1383 IO.O0' 19~.00' 1380 64 S 14 V EN~ fl~ CURVE e345 ~9.~4' I*~.~8' ~8~ 378 ~ 6~ ~ VEST $AK 6813 ~9.~4' l~.~B' 6180 ~lO 546 K-rE 7141 ~9.~4' l*~.~e' 64a6 ~667 S580 V K-ID 7748 E9.~4' lg~.Ea' 6996 E957S 643 8~0~ 356~ S775 ~ K'5 9016 ~9.~4' ~ASE HRZ 9~gB ~9,~4' 19~.~8' 8340 3698 S 803 9649 ~9.~4' SAG RIVER 99~9 ~S.~4' 19~,R8'ce99 3998 s 870 ~ T~ SAD / ZONE 4 X-RAY 10046 ~9;~4'19E,~8* 9001 4053 S ~2 V PDVC 10079 ~9.~4']9E,~8' 9030 4069 S 885 ~C 1010H ~9.~4'19~.~8' 9050 4080 S 888 V H~T 10119 e9.~4'19~.~8' 9065 40B~ S BB9 V VERTICAL VIEW SCALE 500 fl:. / DIVISION TVD REF: RKB VERTICAL SECTION REF: WELLHEAD 0 8~8 1380 1500 2000~ 2~B2~ 2500~ 3000~ 3500-- 4000~ 4500 5000-- 0,00' e 0 MD TIE IN 0.00' e550 HD KDP / START DF BUILD E 1.O0°/tO0 Pt 1.00' E650MD ~.00' ~750MD 3.00' e850 4.00' ~950 MD 5.00' e1050 MDSTART OFBUILD ~ 1.50'/I00 6.50' ~ 1150 MD 8.00' ~ 1~50 10.00'E 1383 MD START DF CURVE R 2.00'/100 12.00' ~ 14B3 MD ~ 14.00' E 1583 MD ~ 16.00' ~ 1683 MD ~ 10.00' ~ 1703 MD ~ 20.00' ~ 1883 MD ~ 22.00' R 19B3 MD ~ 24,00' e 20B3 MD 2G,O0' ~ 2~3 MO ~ 29,24' E 2345 MO END OF CURVE HOF~IZON'rAL VIEW (TRUE NORTIt) SCAI,E ,500 fl. / DIVISION SURVEY REF: WELLHEAD ., I~oo-~,~.oa. 2000 . 192.24 2500 . 192.~E' 3000 . 192'28' / 3500 . 19~,28' 4000 . ~92 28- / 4~00 . /92.28. /. 5~00 . 192.28. / 6000 . 192'28' / 7000 . 192 2500 ~ ~500 . 192,2e · 1500 I000 500 0 500 MD, 3265 TVD .......... ~ .... ~ ...... l~ ...... ~;,' ]~F .... ~7~ .... ~;;I PROPOS['iD Bill, MD 10Z52 11 .oo-- ___. .............. : . .~ C 6~0 ...... .................... ..~ ~ ~a* p (,813 ~ ~'Egl gag 2569 ix~agt,;~ ~ti & Gas GOfls. C0mmiaaion / VERTICAL SECTION PI,ANE: 192.27 Travelling Cyllnde~ - No~mc~L Plane ReCe~ence Well - 13-351 WpI ND'. 0 - lCIi35P C¢. In1;e~vc~t, 50 All Dir'ect;ions Ret t;o Tr'ue Nor'th 33~b 0o 3/10/g4 7:43 om 60° 850 ~00 3ti~ 270o / r)( y, P. 40o EC£1V£D CLOSe_ST PCII~q S 15~'j7 0~. ~47 ~ 5~ ~70 I~373 ~73 ~ ~(x) ~71 70 34/O/ 4~ {~ 4{~ IX) 3:~, 40 1761 .~ 45 ~0.~ o ~X~~140 1775 I0 ~171 ti)ill ti) Ill 1/~) [~ ................................................ MAR 1 4 t994- t~rget 1 C~[TICAL P~]INT DAT/~ Alaska Oil & Gas Cons. Commission Anchorage TVD G~;d X O~id v 8970 685038 5g~7496 ND Inc Az;. 1 VD FiE tN O 0 ()go 0 (),go0 0 KI]) / .Xlt~l 5'.')0O.(~ {],[X]°:]~] [) O' ~JILD ~ Sl~l [)' BUILDl~O 5.(~ I~?(X~ 1049 sr~f D' 1~{3 10.(~ lCJP.~ 1~)0 CL~VEe [~NI) I ~' CL~VK R345 Pg 24° 1CP 2[1°PF~)~' K. 1~t 114! PgR4° lC~ 2i)°O4O(, 2661 ]~5fZ I~Z ()~U) Pg ~.)4° l c)2 ~)(P [K~40 [l~.[: (;C~:)i~).24°19~ ~l)°li(,'.Y.i SI ~JIiL lK O(Z,i) i~G P4 o 1 c)~ p({o ()~;~6, 40 torqet 1 / lfX]IO E~P4* lgiLP8o [)9/0 4OitC, T! t~' ~aI) / Z~ ~ 4 X-RAY 1(I146 agP4* lgf~ a~ giI]l 4C',:3 l~ iWC l(~7g Pg ;~4°1 g~ 2~(l° c)[ZK) ~lil lO119 Z!9.24°19;?L't)° g(~,5 4i;II8 (_J] " D' ~., WELL PERMIT CHECKLIST A~MINISTRATION WELL NAME ~EOL AREA 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... ~! Lease number appropriate ................ ~x Unique well name and number ............... IY Well located in a defined pool ............. ~Y Well located proper distance from drlg unit boundary.. '.Y Well located proper distance from other wells ..... Y Sufficient acreage available in drilling unit ..... Y If deviated, is wellbore plat included ...... '.. Y Operator only affected party ........... '... I.Y Operator has appropriate bond in force ......... I.Yi Permit can be issued without conservation order .... YJ Permit can be issued without administrative approval.. ~YI Can permit be approved before 15-day wait ....... ~ ENGINEERING APPR DATE GEOLOGY 14. Conductor string provided ............... '~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in surf csg to next string.., o~i ~ 18. CMT will cover all known productive horizons ...... O 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. ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate. ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to 5OC~ 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 H2S gas probable ............ ~ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/. 31. Da~a presented on potential overpressure zones ..... Y / ~)~ 32. Seismic analysis of shallow gas zones .......... Y/N /~/'~7/ , 33. Seabed condition survey (if off-shore) ......... y N ~ 34. Contact name/phone for weekly progress reports .... ~ N [exploratory only] ~EOLO~Y: ENGINEERIN¢: COMMISSION: Commen~s/Instructions: Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special'effort has been made to chronologically organize this category of information. · Tape ~ubfile 2 is type: LIS TAPE HEADER PRUDHOE BaY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 24-JUN-96 MWD RUN 6 6701.00 P. BROWN G. RAMSEY 14 i0N 14E 1521 1411 80.10 78.10 .00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 3495.0 8.500 10250;0 MWD - EWR4/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 - 5 WERE DIRECTIONAL ONLY. MWD RUN 6 WAS DIRECTIONAL, DUAL GAMMA RAY (DGR) , & ELECTROMAGNETIC 4-PHASE RESISTIVITY (EWR4). RE. CEIVEU JUN 2 8 1995 Oil ~: ~:..~u.~. ~mmismon An~orage FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9889.0 RP 9898.0 $ BASELINE CURVE FOR SHIFTS: UNKNOWN CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 9889.0 9885.5 9914.0 9910.5 9937.5 9933.5 9947.0 9943.0 9950.0 9947.0 9970.5 9967.5 9974.0 9971.0 9984.0 9981.5 9989.5 9987.5 9992.5 9990.0 9999.0 9997.0 10006.0 10004.0 10008.0 10006.5 10032.5 10028.5 10040.5 10036.5 10045.0 10043.5 10048.0 10046.5 10059.0 10058.0 10064.0 10063.0 10251.0 10250.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: all bit runs merged. STOP DEPTH 10227.0 10236.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 6 9808.0 10250.0 EDITED PASS. ALL MWD CURVES WERE SHIFTED WITH GR. /? ?SHIFT. OUT $ CN : ARCO ALASKA, WN : D.S. 13-35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME INC. Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 24 Tape File Start Depth = 10250.000000 Tape File End Depth = 9885.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5849 datums Tape Subfile: 2 123 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9885.0 EWR4 9895.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10226.0 10235.0 31-MAR- 94 MWD 1.98 3.93 MEMORY 10250.0 9808.0 10250.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0251CGR6 P0251CGR6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3495.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.60 44.0 9.1 500 5.0 2.100 .800 1.600 3.100 77.0 147.0 77.0 77.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 6. $ : ARCO ALASKA, INC. : D.S. 13 -35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 24 Tape File Start Depth = 10250.000000 Tape File End Depth = 9885.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5849 datums Tape Subfile: 3 89 records... Minimum record length: 62 bytes Maximum record length: 998 bytes rape Subfile 4 is type: LIS 96/ 6/25 01 **** REEL TRAILER **** 96/ 6/25 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 25 JUN 96 2:20p Elapsed execution time = 0.76 seconds. SYSTEM RETURN CODE = 0