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Home My WebLink About193-123MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-16 PRUDHOE BAY UN PTM P2-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 P2-16 50-029-22397-00-00 193-123-0 G SPT 8584 1931230 2146 2756 2756 2754 2753 91 97 98 98 4YRTST P Bob Noble 5/10/2023 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 UN PTM P2-16 Inspection Date: Tubing OA Packer Depth 990 2254 2257 2268IA 2752 98 45 Min 2267 60 Min Rel Insp Num: Insp Num:mitRCN230511161316 BBL Pumped:1.4 BBL Returned:1.4 Tuesday, July 25, 2023 Page 1 of 1           MEMORANDUM TO: Jim Regg P.I. Supervisor i2%1 Sq FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 8, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA) INC. P2-16 PRUDHOE BAY UN PTM P2-16 Src: Inspector Reviewed By: P.I. Supry J-J�o— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-16 API Well Number 50-029-22397-00-00 Inspector Name: Austin McLeod Permit Number: 193-123-0 Inspection Date: 5/5/2019 Insp Num: mitSAM190505132637 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-16 Type Inj a iTVD ossa - Tubing 3074 "; 306 4 sass - 3052 PTD 1931230 Type Test SPT Test psi 2146 IA zsa zsoo - — 2472 2451 2440 - BBL Pumped 4.1 BBL Returned: ii 23 OA z 9z - 95 - 94 93 - Interval 4YRTST !P/F P Notes: MIT -IA Wednesday, May 8, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg DATE: Wednesday,May 13,2015 P.1.Supervisor 1' 1'14 (i� SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC P2-16 FROM: Lou Grimaldi PRUDHOE BAY UN PTM P2-16 Petroleum Inspector Src: Inspector Reviewed By._ P.I.Supry �P�e'_- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-16 API Well Number 50-029-22397-00-00 Inspector Name: Lou Grimaldi Permit Number: 193-123-0 Inspection Date: 5/7/2015 lnsp Num: mitLG150507205222 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-I6 Type Inj W 'TVD 8584 Tubing 1687 • 1722 - 1695 - 1724 - 1723 _ 1722 • PTD 1931230 - Type Test SPT Test psi 2146 • IA 338 2801 - 2797 - 2782 2767 - 2767 Interval i4YRTST P/F P ,/ OA 398 655 - 657 - 651 644 643 , Notes: 3.1 bbl's diesel pumped 2.6 bbl's returned.The first test was unstable due to rate fluctuations.As I was not there for the majority of the readings I discounted that test.I don't consider any part of that test as valid due to the pressure and rate fluctuations.2nd test on this well '/ today as 1st was inconclusive due to apparent flow rate deviations.All pertinent paperwork supplied prior to test. ed ') PR'SS4A)-es p t©+- CArre -GJe((sc�e pEp J U L 1 3 2015 Wednesday,May 13,2015 Page I of I • • ' + i' + I • I a• i i • . r . .• Q/ •• -:-,t St. ri . 4.-•,.. I t j, i'\ C''' ••••........... • .....: `.' N • n• .............. .....V.'r IS\ • a A -...): • • • • • 0 • •• . in • • • ;3.• • 0 • • • • • 0 II • 0 ., • • ' 1::: . • • r 1 0 • • . a • as . i F.....' t ... rri Sr J • 1 .• .. * . .• • ili,l . • s-t . , ... r. -:-1 ..,-4 ._,...• ' I i V., ' ! . . TREE= 7"1/16 CM/ SM ,1IOTES:H2S READINGS AVERAGE 125 ppm WELLHEAD= FMC WHEN ON MI,WELL REQUIRES AN SSSV ACTUATOR= BAKER C P2-16 "*CHROME NIPPLES' KB ELEV= 51 5' BF ELEV= KOP= 4341' Max Angle= 44°@ 10025' r 2245' -15-1/2"HES X NIP(CR),ID=4.562" Datum MD= 10054' Datum TVD= 8800'SS 13-3/8"CSG 68# NT-80 BTC ID=12.415" , --I 3692' - • 9-5/8"X 7"BKR C-2 ZXP LTP,ID=6.95 --I 3997' p 9-5/8"X 7-5/8" BKR FLEXLOCK III HGR, ID=6.92 H 4017' �•• t t a• 9612' --I5-1/2"HES X NIP(CR),ID=4.562" Minimum ID =3.725" @ 9793' 44 r; ♦4 • 4-1/2" HES XN NIPPLE �: ':• 9628' —15-1/2"x 4-1rz°XO,ID=3.958° • ,•� i• 9686' H 7-5/8"X 4-1/2'HES TNT PKR,ID=3,855" 5-1/2 TBG, 17#, L-80 TCII, .0232 bpf, ID=4.892" —I 9628' . 4t• re 1 .• : 9721' --I4-1/2"HES X NIP(CR),ID=3.813" �•• • :� ' , 9793' —I4-1/2"HES XN NIP(CR),ID=3.725" • •• 4-112'TBG, 12.6#, L-80 TCII,.0152 bpf,ID=3.958" —{ 9826' \ j. 9826' —4-1/2"WLEG, ID=3.958" • • • 7-5/8"SCAB LNR,29.7#,L-80 HYD 521, H •9845' �•4, • ,• 9845' —17-5/8"X 5-1/2"FORTED XO,ID=4.892" • 0459 bpf,ID=6.875" :�•••� '�.• 9871' _I-9-5/8"X 5-1/2"UNIQUE OVERSHOT ..� ►+ 5-1/2"TUBING STUB(04!08/11) --I 9860° ••••4 1••�• ♦♦ I•• 9888' —5-1/2"PARKER SWS NIP(9-CR),ID=4.562" ••••4 ►• W ►•••• ••••4 •••• ••1 ' 9905' 19-5/8"X 5"TW HBBP PKR w/ANCHOR LATCH ASSY,ID=4.870" l ). -•-......".-- 9911' --17"MILLOUT EXTENSION, ID=6.210" 9916' —17"X 4-1/2"XO,ID=4.830" I r1 9942' —15-1/2'PARKER SWS NIP(9-CR),ID=4.562" I 19960° H5-1/2"OT1S XN NIP(9-CR),ID=4.455" 5-1/2'TBG,17#,L-80 NSCC, H 9984' / • 9984' —15-1/2"WLEG,ID=4.892 .0232 bpf,ID=4.892' 9984' —ELMD TT LOGGED 01/26/94 PERFORATION SUMMARY • 10118' —19 5/8"MARKER JOINTS(2) REF LOG:ATLAS DIUGR ON 09/13/93 • ANGLE AT TOP PERF:43°@ 10125' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10125- 10165 C 04/28/08 3-3/8" 6 10126- 10410 C 01/27/94 2-7/8" 6 10300- 10375 C 04/28/08 PBTD -1 10436' ". ♦weir eAve 111111111111111111111111 9-5/8"CSG,47#,NT-80S NSCC, ID=8 681" —{ 10518' tIM41.11.14)111.6 DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTY RE UNIT 09/16193 POOL 7 ORIGINAL COMPLETION WELL, P2-16 04/15111 N7ES RWO(SCAB LNR) PERMIT No."1931230 04/30/11 PJC DRLG DRAFT CORRECTION AR No. 50-029-22397-00 05/02/11 WI-V PJC FINAL DRLG CORRECTIONS SEC 14,T12N,R14E,1184'FWL& 27'FNL 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 19,2015 TO: Jun Regg ` q 5116t(15S Pi Supervisor '� SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC P2-16 FROM: Lou Grimaldi PRUDHOE BAY UN PTM P2-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry `fr NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-16 API Well Number 50-029-22397-00-00 Inspector Name: Lou Grimaldi Permit Number: 193-123-0 Inspection Date: 5/7/2015 Insp Num: mitLG150519092041 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P246 Type Inj W TVD 8584 - Tubing 2102 - 2130 . 2084 2122 _ 2080 2097 , PTD 1931230 -Type Testi SPT Test psi 2146 IA 178 - 2800 _ 2805 2807 . 2815 . 2817 , Interval 4YRTST PAF I r OA 309 • 578 582 585 • 589 - 593 , Notes: First test today,deemed inconclusive due to apparent flow rate deviations.Please see subsequent test mitLG150507205222. • %MOD JUL 1 3 2015. Tuesday,May 19,2015 Page I of I • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg • AUG tk 8 die Alaska Oil and Gas Conservation Commission 333 West 7 Avenue icf3-i9- 3 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that 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 s • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM -2 Date: 04/302012 ' I Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na pal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 1020 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA -) P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2-31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2 -41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2 -43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2 -44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2 -47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A , 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 2Q2011 Not Operable Injector Rep • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. ' . «Not Operable Injector Report 2Q2011.zip» Notes on wells: JUL 1 2 2011 Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 /P2 -16 PTD #19312 0') li repaired PC On / U -10 ( DTxTA comm. That was leak repaired and with TxIA comm. a tubing patch 04/15/11 on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720): MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission U l � P.I. Supervisor �=� ri 7/ DATE: Wednesday, June 08, 2011 TO: 1 SUBJECT: Mechanical Integrity Tests P.ry BP EXPLORATION (ALASKA) INC P2 -16 FROM: John Crisp PRUDHOE BAY UN PTM P2 -16 Petroleum Inspector Src: Inspector Reviewed By: ??�n P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN PTM P2 -16 API Well Number: 50 029 - 22397 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110517120911 Permit Number: 193 -123 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P2-16 Type Inj. wFTVD 8584 IA 230 2410 2420 2420 P.T.D; 1931230 ' TypeT6st SPT Test psi 2146 - 1 OA 30 250 240 240 Interval 4YRTST P/F P Tubing 1780 1780 1790 i 1760 Notes: 2 bbls pumped for test. No problems witnessed. *AIMED iUR 1 3 NI) Wednesday, June 08, 2011 Page 1 of 1 05/06/11 St Wane NO. 5738 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 6 Log Description Date BL Color CD /'''')* P2 -16 BBSK -00061 USIT 04/04/11 ,,_ '1 1 1 1- 3510 -25 BBKA-00101 PRODUCTIeNPROFILE _ 04/04/11 1 �[�(�."� 1 P2 -52 BJGT -00027 CROSS FLOW CHECK ' — 1 b 04/14/11 1 r� ( 1 03 -37 BJGT -00028 INJECTION PROFILE U (i = •'' —' 1 39 04/16/11 1 L 1 2-42/P -13 BAUJ -00076 MEM LDL / Irk - / b / 04/15/11 - 1 1 „ 1 N -11C 13H4H -00048 PRODUCTION PROFILE ` ;, 04/19/11 1 • 1 02 -12C BD88 -00098 lii7a'Y:: _. , Eglallnff/YTM 1 S -120 BD88 -00100 MEM INJECTION PROFILE 0 .„ ti -(C - 04/25/11 1 1 1 P1 -09 BJOH -00024 1J:Le]rA[A1reIJ9:IslaM ^1 05/01/11 1 i 1 P1-09 BJOH -00024 • 05/02/11 �` 1 1 , • P2 -43 BG4H -00049 • � �. 04/28/11 1 1 16 -21 BJGT -00030 PRODUCTION PROFILE ' - F ►>f�� 1 09 -26 B1388 -00104 MEM LDL / 'Ah" • • A3 3 04/30/11 1 �4 1 04-33A BLPO -00095 MEM PRODUCTION PROFILE ` 40 4Y a o 04/30/11 1 ;f 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 , ,,,:'- ' jUN 01 201 1 • • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, May 18, 2011 Jim Regg P.I. Supervisor � e,,5-(711, SUBJECT: Mechanical Integrity Tests c BP EXPLORATION (ALASKA) INC P2 -16 FROM: John Crisp PRUDHOE BAY UN PTM P2 -16 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 1132-- - NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN PTM P2 -16 API Well Number: 50- 029 - 22397 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110517120911 Permit Number: 193 -123 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I P2 -16 - 'Type Inj. W TVD 8744 - 1 IA I 230 2410 2420 2420 - p.T.D 1931230 ' TypeTest 1 SPT Test psi 2186 ' OA 30 250 240 240 Interval 4YRTST - p/F P Tubing 1780 i 1780 1790 1760 Notes: 2 bbls pumped for test. No problems witnessed. Wednesday, May 18, 2011 Page 1 of 1 STATE OF ALASKA y ALASKA* AND GAS CONSERVATION COMMIS* RECEIVED REPORT OF SUNDRY WELL OPERATIONS vii\'( '') S '' 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re-EiXtRapeillgi tett CMS. WitaiS810n ® Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver CO Othe 'ArIcn#GTeg6 ❑ 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 -` 193 - 123 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 4 50 - 029 - 22397 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 034624 & 365548 4 PBU P2 - 9. Field / Pool(s): Prudhoe Bay Field / Point McIntyre Pool 10. Present well condition summary Total depth: measured 10535' feet Plugs (measured) None feet true vertical 9202' feet Junk (measured) None Effective depth: measured 10436' feet Packer: (measured) 9686' & 9905' feet true vertical 9130' feet Packer: (true vertical) 8584' & 8744' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 3655' 13 -3/8" 37' - 3692' 37' - 3691' 5020 2270 Intermediate Production 10481' 9 -5/8" 37' - 10518' 37' - 9190' 6870 4760 Liner Scab Liner 5874' 7 -5/8" 3997' - 9871' 3996' - 8719' 6890 4790 Perforation Depth: Measured Depth: 10125' - 10410' True Vertical Depth: 8903' - 9111' Tubing (size, grade, measured and true vertical depth): 5 - 1/2 ", 17# x 4 - 1/2 ", 12.6# L & 9Cr 9826' 8686' 5 -1/2 ", 17# L -80 9860' - 9984' 8711' - 8801' Packers and SSSV (type, measured and true vertical depth): 7 - 5/8" x 4 -1/2" HES 'TNT' packer 9686' 8584' 9 -5/8" x 5" TIW HBBP Packer 9905' 8744' 11. Stimulation or cement squeeze summary: Intervals treated (measured): ,.. MAY 1 0 2011 Treatment description including volumes used and final pressure: Cut tubing at about 9874' (Pre -Rig). MIRU. Cut tubing a second time at about 9873'. Cut tubing a third time at about 9430'. Pull tubing in several runs. Dress off stub to about 9860'. Run 7 -5/8" Scab Liner (29.7 #, L -80). Cement Scab Liner w/ 124 Bbls of Class 'G' (1.16 Yield). Run new completion. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A 19,102 (05/03/10) N/A N/A Subsequent to operation: N/A N/A 10,321 (05/03/11) 1,850 1,243 13. Attachments: ❑Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory L Developments Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: GINJ ❑ Oil SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG WAG WINJ 16. 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 Wilmer Hoffman, 564 -4592 311 - 066 Printed Name Terrie Hubble Title Drilling Technologist g 1�' V e 6 OS/ Prepared Bye 564 - 462 Si natur � / Phone 564 - 4628 Date f � � Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 : DIM MAY 06 2011 4 Submit Original Only 7 /24., 5. • . P2 -16, Well History (Pre Rig Workover) Date Summary 2/22/2011 WELL S/I ON ARRIVAL. DRIFTED TBG W/ 4.43" CENT, TEL, & S.BAILER, LOC TT @ 9955' SLM / 9984' ELM (29' CORRECTION). TAGGED TD @ 10384' SLM / 10413' ELM, ALL CLEAR, TOOLS FELL A LITTLE SLOW FROM —6300' TO TBG TAIL (FLUID PACKED). BAILER HAD A SMALL AMOUNT OF SCHMOO. WELL S/I ON DEPARTURE, NOTIFIED DSO. 3/1/2011 T /I /O = 1800/600/260. Temp = SI. WHPs FL on T. (pre RWO). No AL. Tubing FL @ 5100' ? (120 bbls). Integral installed on IA. 3/3/2011 WELL SHUT IN ON ARRIVAL. INITIAL T /I /O = 600/300/100 WELL KILLED WITH 290 BBLS OF 1% KCL PRIOR TO LOGGING AND FINISHED WITH 60 BBLS OF METH FOR FREEZE PROTECT. RIH WITH CCL - HALLIBURTON SHORTY SETTING TOOL - HALLIBURTON COMPOSITE (OBSIDIAN) PLUG WITH 4.37" OD. OAL = 24' WEIGHT = 200 LBS. RIH AT 100 FT /MIN AS PER HALLIBURTON INSTRUCTION. UNABLE TO GET PAST SWS NIP @9942', CONFIRMED WITH WSL, APE AND HALLIBURTON TO SET PLUG @ 9937.8' (ME). CCL STOP DEPTH = 9930', CCL TO TOP ME = 7.8', CCL STOP DEPTH = 9930'. PLUG SET @ 9937.8' (ME), TOP OF PLUG = 9936.6'. POOH AND UPON RETURNING TO SURFACE TURNED CONTROL OF WELL TO LRS FOR MIT -T TO 3000 PSI. LEAVE EQUIPMENT ON LOCATION TO RETURN 4- MARCH -2011 TO PERFORM JET CUT. 3/4/2011 HAD TROUBLE GETTING THROUGH SSSV. POWER JET CUT TUBING WITH 4.15" SCP CUTTER AT 9874', POSITIVE SURFACE INDICATION OF FIRE. DEPTH REFERENCED TO TUBING TALLY DATED ,.—j 18- JAN -1994. MAINTAINgD 5200 PSI ON SSSV WHILE PULLING TOOL STRING BACK UP `''' THROUGH SSSV. FINIAL T /I /O = 400/520/340 WELL SHUT -IN ON DEPARTURE, DSO NOTIFIED. JOB COMPLETE. 3/7/2011 T /I /O = 400/520/300 Well Head is FMC 13 -5/8" 5k with 7" x 6" Cameron Upper Tree Inspected leak on well head called in by Schlumberger, external Alemite leaking on IC casing hanger void. Install high pressure bleeder tool on Alemite fitting, check pressure on void 35 psi, bled pressure to 0 psi. Tighten Alemite fitting in Tubing spool bottom flange, re- torque IC lock down pin directly under Alemite fitting. Remove High pressure bleeder tool and install cap on Alemite fitting. Report findings to PE on location. 3/7/2011 WELL S/I ON ARRIVAL. TAGGED 5 -1/2" OTIS TRSV @ 2,202' SLM (2,228' MD) W/ 4.75" CENT (No issues). RAN 4.75" CENT, 13' x 1 -1/4" STEM, FLAPPER CHECKER TO 2,202' SLM (Pins indicate flapper open). SET 5 -1/2" R -LOCK W/ HO SLEEVE IN 5 -1/2" OTIS TRSV @ 2,228' MD. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 3/9/2011 T /I /0= 200/600/300 temp =si Circ out Tx IA, Freeze protect [RWO Prep] Rigged up to tree cap and pumped 13.2 bbls neat meth TBG in attempt to achieve TxIA communication. TxIA communication achieved. Pumped 1256 bbls 9.8# Brine & .5 bbls neat meth down TBG, up IA & down Jumper line to well #17 F /L. Pumped 22 bbls DSL down TBG for F /P. RD TBG, RU IA. Pumped 7.3 bbls neat meth down Jumper line to well #17 to F/P line. Isolate well #17. U -tube TBG to IA. U -Tube TBG to IA. FWP =0/0/0 3/28/2011 T /I /0 = 0/0/0 Conduct PJSM. Verify barriers. Rig up lubricator to set BPV. Tested to 500 psi low and 3500 psi high. (pass) Set 6" CIW J BPV @ 114" w/ 1 -2' ext. Rig down lubricator, install tree cap and test to 500 psi. (pass). Job Complete. Page 1 of 1 i _ 0 I ' forth America - ALASKA - BP' ' Page t of V; operation,SummarY.Report Common Well Name: P2 -16 , AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 iX 00T38-E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date I From - To I Hrs I Task I Code I NPT NPT Depth Phase I Description of Operations (hr) (ft) 3/26/2011 112:00 - 00:00 , 12.00 ' MOB P PRE i RIG DOWN & MOVE OFF OF WELL I REPAIR ROLLER BEARINGS ON IRON I ROUGHNECK. 1 - WELD & BOLT UP FLANGES IN PUMP ROOM. I- CHANGE OIL AND FILTER ON TOP DRIVE - RD PITS & MEZZANINE - RD FLOOR & RU BRIDLE LINES `- DISCONNECT FROM HI -LINE POWER i ' I -,LD DERRICK , - MOVE PIT AND SUB MODULES OFF OF 1 WELL I 1- STAGE SUB & PITS AT END OF PAD I ,- INSTALL JEEP ON PIT MODULE REMOVE RIG MATS FROM AROUND WELL 3/27/2011 00:00 - 12:00 12.00 I MOB P r PRE WAIT ON PRE -WORK TO BE COMPLETED ON P2 -16 - CLEAR ALL EQUIPMENT FROM AROUND WELLHEAD - SPOT EQUIPMENT FOR RIG MOVE I - PREPARE SAFE WORK PLAN FOR CHANGING LOWER BOP PIPE RAMS I - PJSM ON CHANGING OUT LOWER PIPE RAMS - CHANGE OUT LOWER PIPE RAMS TO 3.5" X , - CHANGE OUT VALVES ON STEAM LINE AND : I FUEL STATION I - ELECTRICIAN WORKING ON CAMERA IN DERRICK - POLICE AREA AROUND WELLHEAD. 12:00 00:00 12.00 MOB P PRE WAIT ON PRE -WORK TO BE COMPLETED ON P2 -16 I - SERVICE #2 AIR COMPRESSOR - REMOVE GEL FROM BULK TRAILER WITH I SUPER SUCKER - REPLACE DERRICK FALL ARREST BLOCK AND CABLE - REPAIR STEAM LEAKS CHANGE OUT EXTERIOR LIGHT BULBS ON i LPIT COMPLEX 3/28/2011 00:00 - 01:00 1.00 MOB P ! PRE PRE -SPUD MTG WITH CREW ON P2 -16 WO 01:00 - 12:00 I 11.00 MOB P PRE WAIT ON PRE -WORK TO BE COMPLETED ON P2 -16 - WAIT ON OPERATIONS TO COMPLETE SAFE OUT OF WELL ON P2 PAD ! - GRAVEL WORK TO START ONCE WELLS I ARE SAFED OUT !- CONTINUE TO WORK PM & MAINT ISSUES ON RIG Printed 4/29/2011 10:52:37AM I :' ': i , , . ':' - , : . , ,' ' , '': - . " ott6Arherici ALA BP'; Page 2 of 27 ' Optiratioif Summary Report . - Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) ! Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: [ Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date I From - To Hrs Task ! Code I NPT I NPT Depth I Phase I Description of Operations 12:00 - 00:00 12.00 MOB P I PRE WAIT ON PRE -WORK TO BE COMPLETED ON I P2 -16 I - SAFE OUT OF WELLS ON P2 PAD I I COMPLETE - GRAVEL WORK TO STARTED CONTINUE TO WORK PM & MAINT ISSUES ON RIG -�- SPOT MISC. RIG EQUIPMENT ON P2 PAD - PREP TO MOVE SAT. CAMP, SHOP, AND PITS ! 17 ADD MUFFLER EXHAUST DEFLECTOR TO I CHEM !Mk PUMP ** 3/29/2011 00:00 - 08:00 I 8.00 MOB P ' - PRE I MOB SAT.' CAMP SHOP, AND PITS FROM DS5 TO P2 PAD ! - SET CAMP, AND SHOP. SPOT PITS ON P2 PAD 08:00 - 17:30 ! 9.50 MOB P i � — PRE — MOB SUB FROM DS5 TO P2 PAD - SPOT SUB ON P2 PAD 117:30 - 19:30 2.00 MOB P PRE } RAISE DERRICK ! - RAISE CATTLE CHUTE I . HANG BRIDLE, PIN BLOCKS & TOP DRIVE I- INSTALL TORQUE TUBES & HANG TREE 19:30 20:30 1.00 MOB PRE P ---A-- I ;SAFETY MTG WITH OPERATIONS ! I PERSONNEL ON SAFE OUT OF CLOSE !. PROXIMITY WELLS 20:30 00:00 I 3.50 MOB P PRE SAFE OUT WELLS & LO/TO VALVES & SSV'S I PRIOR TO SPOTTING RIG / 3/30/2011 00:00 - 01:00 ' 1.00 MOB P PRE SAFE OUT WELLS & LO/TO VALVES & SSV'S PRIOR TO SPOTTING RIG 01:00 - 04:00 I 3.00 MOB I { I P PRE I ATTEMPT TO SPOT RIG OVER WELL - UNABLE TO CLEAR WELL HOUSE 18 AND GET PITS TO ALIGN PROPERLY. WILL HAVE TO REMOVE WELL 18 WELL HOUSE 04:00 - 10:00 ' 6.00 MOB N P RE W/O WELL HOUSE TO BE REMOVED - WAIT ON CRANE 10:00 11:00 1.00 MOB N PRE PULL WELL HOUSE FROM WELL # 18 11:00 12:00 1.00 MOB N PRE SPOT SUB OVER WELL P2 -16 12:00 - 15:00 ! 3.00 MOB N I PRE j SPOT PIT COMPLEX ' - SPOT CUTTINGS TANK - SPOT TIGER TANK - INSTALL SECONDARY ANNULUS VALES ON IA & OA, * *RIG UP EMERGENCY SHUT DOWN SYSTEM : FOR CLOSE APPROACH WELLS ON RIG FLOOR ** ** RIG ACCEPTED AT 1500 HRS 3/30/2011 TAKE ON 9.8 BRINE 15:00 - 17:00 I 2.00 MOB 1 N PRE 17:00 - 18:00 ' 1.00 MOB 1 N I PRE FUNCTION TEST EMERGENCY SHUT DOWN FOR CLOSE APPROACH WELLS ! I CREW ORIENTATION ON EMERGENCY ! I SHUT DOWN FUNCTION - -- ** CONDUCT RIG EVACUATION DRILL ** Printed 4/29/2011 10:52:37AM orth America ^may /� c��¢y BP 3 p� .. Ot'$FC At11 @PICA ALAS v F �F- _ Page J of LL ', Aeration Summary Report'', Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre , Site: Pt Mac 2 1 I Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ' Phase I Description of Operations (hr) 1 (ft) I 18:00 - 20:00 I 2.00 MOB N fi PRE T RIG UP DSM LUBRICATOR & TEST I - 250 PSI LOW FOR 5 MIN AND 4000 PSI HIGH FOR 5 MIN. GOOD TEST PULL BPV 20:00 C 21:00 1.00 WHSUR N I DECOMP 1 RIG UP LINESTO CIRC OUT FREEZE PROTECT 21:00 00:00 3.00 WHSUR N DECOMP CIRC OUT FREEZE PROTECT , r- REVERSE OUT THE DIESEL FROM THE TUBING. I , - 3 BPM AND 200 PSI. - PUMPED 56 BBLS OF HEATED 9.8 PPG I BRINE. � - TOOK 26 BBLS TO CATCH FLUID - RECOVERED —5 BBLS OF DIESEL. - CIRCULATE OUT THE DIESEL FROM THE ANNULUS. - 3 BPM AND 350 PSI. - PUMPED 50 BBLS OF HEATED 9.8 PPG SOAP SWEEP. - CHASED SOAP SWEEP WITH HEATED 9.8 1 PPG BRINE. 1 - 6 BPM AND 700 PSI. 1- RIG DOWN ND BLOW DOWN LINES. - PUMPED 750 BBLS 9.8 HEATED BRINE AND GOT BACK 660 BBLS - LOST 26 BBLS ON INITIAL FILL UP & 64 BBLS WHILE PUMPING - DYNAMIC LOSS = 25.6 BPH - RECOVERED A TOTAL OF 10 BBLS OF DIESEL FREEZE PROTECT. - MONITORED WELL -- WELL WAS STATIC. 3/31/2011 100:00 - 01:00 1.00 WHSUR P I DECOMP RD CIRC SYSTEM I- RD AND BLOW DOWN EQUIPMENT DECOMP 01:00 03:00 l 2.00 � WHSUR P I RU DSM LUB & SET TWC � - PRESS TEST 250 LOW & 4000 PSI HIGH. CHARTED. GOOD TEST I , - CONDUCT ROLLING TEST ON TWC FROM BELOW TO 500 PSI. 10 MIN CHARTED. GOOD TEST RD DSM LUBRICATOR 03:00 - 03:30 0.50 WHSUR P DECOMP I ND TRFE RU FILL UP LINE TO IA FROM SECONDARY , I I KILL LINE & CIR TO KEEP BACKSIDE FULL - STATIC LOSS RATE 18 BPH START TO NIPPLE DOWN TREE HAD 5 ' BOLTS LOOSE ANC) NOTICED TWC LEAKING BY - TIGHTEN BOLTS BACK UP 03:30 - 04:30 1.00 WHSUR P DECOMP ATTEMPT TO TEST BPV FROM BELOW AND ABOVE STILL LEAKING AT LOW PRESS. ' CALL W 0430 05:00 0.50 WHSUR P DECOMP OS TO DISCUSS OPTIONS I Printed 4/29/2011 10:52:37AM �}I {1'/�t71�361Ea ALA$KPR - BFI Page 4 of 2T' ' C peratior . r Summary Report Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) I Project: Point McIntyre 1 Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26 : 16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) Date From - To l Hrs Task Code ' NPT NPT Depth ' Phase I Description of Operations (hr) (ft) 05:00 - 06:30 r 1.50 WHSUR P DECOMP I CONDUCT A ROLLING TEST FROM BELOW 1 , TWC TO TEST TREE BREAK • - RU DSM LUBRICATOR & TEST 250 PSI LOW 1 & 4000 PSI HIGH FOR 5 MIN. ' CONDUCT ROLLING TEST ON TREE BY ' PUMPING THRU LEAKING TWC TO 500 PSI, FOR 10 MIN CHARTED - -.TREE VALVES OPEN WITH PRESS GAUGE IN LUB TO VERIFY 500 PSI ON TREE. WHSUR P '-PULL TUC 06:30 10:00 3.50 DECOMP I RU DSM LUB & SET TWC - PRESS TEST 250 LOW & 4000 HIGH I CHARTED. GOOD TEST - PERFORM ROLLING TEST ON TWC FROM j BELOW TO 500 PSI, FOR 10 MIN CHARTED. ' i GOOD TEST ' ;- REPEAT TEST TO 500 PSI DUE TO EXCESS VOLUME OF FLUID BLED FROM LUBRICATOR. GOOD TEST & BLEED OFF. 1 10:00 - 12:00 2.00 WHSUR P i ' - DECOMP I ND TREE & ADAPTER RU FILL UP LINE TO IA FROM SECONDARY , KILL LINE & CIR TO KEEP BACKSIDE FULL j- STATIC LOSS RATE 15 BPH • ' 1 ND TREE AND ADAPTER ' 12:00 - 13:30 1.50 BOPSUR P 1 DECOMP !CHECK HANGER THREADS ON 7" NSCC - TREADS IN GOOD SHAPE ' - TAKE RKB MEASUREMENTS ,13:30 - 14:30 1.00 BOPSUR P DECOMP WAIT ON DRILL SITE OPERATOR TO SHUT IN 1 I WELLS AND BLOW DOWN - SI WELLS AND BLOW DOWN 15, & 17, WHILE ' HANDLING BOP STACK. ' 14:30 17:00 j 2.50 BOPSUR 1 P DECOMP 1 ,NU BOP - SET STACK ON WELL - TORQUE BOLTS WITH SWEENY WRENCH - INSTALL RISER & TURN BUCKLES - PAD OPERATOR PUT WELLS 15 AND 17 BACK ON LINE. 17:00 - 18:00 1.00 BOPSUR P DECOMP PU 4" TEST JOINT W/ 7" NSCC X -O, 4" TIW, & DART VALVE 18:00 00:00 1 6.00 . BOPSUR 1 P DECOMP TTEST BOPS WITH 4" TEST JOINT, - TEST BOPS AS PER ADWOP & AOGCC REGULATIONS - ATTEMPT TO TEST TOP PIPE RAMS, TIW, KILL LINE AND STANDPIPE MANIFOLD - 250 PSI LOW TEST GOOD. 4000 PSI HIGH LEAKING BY START CLOSING FLOW PATHS AND TESTING TO FIND LEAK - FOUND TOP DRIVE AIR ACTUATED IBOP AND MAN. IBOP VALVES LEAKING. ' - WASHPIPE WILL NEED TO BE REPLACED - LEAKING ' - ISOLATE TWC, TIW & TOP PIPE RAMS CHANGE TO TWC, BTM PIPE RAMS, TIW. FOUND TWC LEAKING AT A RATE OF 5 PSI PER MIN. I AOGCC REP JOHN CRISP WAIVED WITNESS OF TEST TEST WITNESSED BY JEFF LOFTIS AND NABORS REP BRIAN TIEDEMAN Printed 4/29/2011 10:52:37AM n r th America - ALASKA BP Page 6 o 27 Re ort eratton Summary p Common Well Name: P2-16 -- - -__ AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 I End Date: 4/15/2011 IX4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. L UWI: Active Datum: 26 : 16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT 11 NPT Depth Phase Description of Operations (hr) (ft) TEST BOPS WITH 4" TEST JOINT 4/1/2011 00:00 05:00 5.00 BOPSUR ! P DECOMP - TEST BOPS AS PER ADWOP & AOGCC I 'REGULATIONS I - TESTED CHOKE MANIFOLD VALVES. - 250 PSI LOW / 4000 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. ' - TESTED DART VALVE, KILL AND CHOKE P - HCR AND MANUAL VALVES, AND jO1 BLIND/SHEAR RAMS. 250 PSI LOW / 4000 PSI HIGH FOR 5 fi CHARTED MINUTES. GOOD TEST. I - TESTED UPPER RAMS, 3 1/2" X 6" VBR. - 250 PSI LOW / 4000 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. - TESTED LOWER RAMS, 3 1/2" X 6" VBR.. -.250 PSI LOW / 4000 PSI HIGH FOR 5 1 ! ;CHARTED MINUTES. GOOD TEST. , I - TESTED ANNULAR PREVENTER. , I - 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. 05:00 - 07:30 2.50 BOPSUR I N DECOMP I CHANGE OUT TOP DRIVE LOWER IBOPS MANUAL AND AIR ACTUATED l 07:30 - 10:00 2.50 BOPSUR N 7 DECOMP I CHANGE OUT SWIVEL PACKING 10:00 15:00 5.00 BOPSUR P DECOMP 'TEST BOPS WITH 5.5" TEST JOINT - TWC LEAKING FROM BELOW HAD TO PUMP WITH RIG PUMP TO CLOSE TWC. 1 1 - TESTED UPPER RAMS, 3 1/2" X 6" VBR. I - 250 PSI LOW / 4000 PSI HIGH FOR 5 ! CHARTED MINUTES. GOOD TEST. - TESTED LOWER RAMS, 3 1/2" X 6" VBR.. - 250 PSI LOW / 4000 PSI HIGH FOR 5 CHARTED MINUTES. I TEST WITNESSED BY DUNCAN FERGUSON AND NABORS REP BIFF PERRY ' AOGCC REP JOHN CRISP WAIVED WITNESS OF TEST 15:00 - 16:00 '', 1.00 BOPSUR P DECOMP RD TEST EQUIPMENT , - BLOW DOWN CHOKE, KILL LINES AND MANIFOLD 16:00 - 18:30 2.50 BOPSUR P DECOMP RU DSM LUB AND DUTCH RISER TO PULL I TWC 1 PRESS TEST 250 LOW & 4000 HIGH I CHARTED. GOOD TEST ' - TWC LEAKING. MADE SEVERAL ATTEMPTS BEFORE GETTING A GOOD TEST - PULL TWC TWC HAD TRASH ON TOP OF AND INSIDE ' VALVE BODY. 18:30 - 19:30 1.00 BOPSUR P DECOMP RD DSM LUB. & DUTCH RISER 19:30 21:00 1.50 PULL P DECOMP RU TO PULL 5 1/2" NSCC TUBING 21:00 - 22:00 1.00 BOPSUR P I DECOMP TEST 3.5" TIW - FAILED TEST ' - REPLACE KR VALVE ON KOOMEY UNIT Printed 4/29/2011 10:52:37AM 00 Ameri = A LASKA'- BP `' Page 6 of Z7 - Cape ary Report I"dt4C�C1 .:U�!ilri - Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre l Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ( Description of Operations — I � NPT Depth Phase 22:00 00:00 2.00 PULL P DECOMP WORK 5 1/2" TBG 1 - MU LANDING JOINT TO TBG HANGER W/ 9 :1/2 TURNS - BOLDS I- WORK TBG I I- PU TBG HANGER WITH 165K ' - STAGE PU WT WORKING UP AND DOWN TO 230K I j- NO MOVEMENT OTHER THAN PIPE STRETCH 4/2/2011 00:00 01:00 1.00 PULL 1 X DECOMP CONT TO WORK PIPE WITH NO FREE I 1 MOVEMENT WORK 5 1/2" TBG WORK TBG I j STAGE PU WT UP 10K EACH TIME FROM 230K UP AND DOWN TO 50K - PULLED 75% OF MAX TENSILE - NO MOVEMENT OTHER THAN PIPF STRETCH 4.50 PULL X DPRB 01:00 05:30 DEC CIR BOTTOMS UP THRU CHOKE I- CLOSE UPPER PIPE RAM AND CIRCULATE THRU CHOKE 3BPM @210PSI SHUT DOWN PUMPS AND OPEN PIPE RAMS MONITOR WELL - WELL STATIC - BLOW DOWN CHOKE , ' * *CONDUCT WELL KILL DRILL ** 05:30 06:30 1.00 PULL DECOMP X I DPRB , LAND TBG HANGER & RD LANDING JOINT - FMC REP RILDS BACK OUT LANDING JOINT -- _ — — - BLOW DOWN TOP DRIVE 106:30 10:00 3.50 PULL X I DPRB DECOMP RU SLICKLINE TO PULL HOLD OPEN SLEEVE IN SSSV RU SLB SLICK LINE LUBRICATOR AND BOPS TO DUTCH RISER 10:00 11:00 1.00 PULL X DPRB DECOMP PRESSURE TEST LUBRICATOR - TEST AGAINST BLIND RAMS - PRESS TEST 250 LOW FOR 5 MIN, AND 3500 PSI HIGH FOR 5 MIN. CHARTED. GOOD TEST BLEED OFF & BLOW DOWN 11:00 PULL DECOMP 12:00 1.00 X DPRB - ! RIH TO 2227 WLM WITH SLICKLINE AND I LATCH HOLD OPEN SLEEVE - JAR FREE & POOH ' - RECOVERED HOLD OPEN SLEEVE 1 12:00 13:00 1.00 PULL X DPRB DECOMP RD SLB SLICKLINE 13:00 - 16:00 3.00 PULL X WAIT DECOMP W/O SLB E -LINE UNIT - HAD TO MACHINE SSSV HOLD OPEN I SLEEVE TO RUN WITH GUN I ** CONDUCT RIG EVAC DRILL ** Printed 4/29/2011 10:52:37AM ortt Ariieric a -- :ALASKA 8# - Page'70f27 : Ion Report' . Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre TSite: Pt Mac 2 Rig Name /No.: NABORS 7ES ; Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT I NPT Depth I Phase I Description of Operations (hr) eft) 116:00 - 21:00 5.00 PULL X DPRB 1 I DECOMP ' RU SLB E -LINE UNIT AND PRESSURE CONTROL EQUIPMENT - PJSM ! I - RU LUBRICATOR AND GREASE HEAD TO I DUTCH RISER - MAKE UP TOOL STRING AND MAKE UP LUBRICATOR. I PRESSURE TEST AGAINST BLIND RAMS IAND TEST E -LINE PRESSURE CONTROL SYSTEM - PRESS TEST 250 LOW FOR 5 MIN, AND 3500 PSI HIGH FOR 5 MIN. CHARTED. GOOD TEST i I - BREAK LUBRICATOR AT QT SUB. 21:00 - 23:00 2.00 PULL 1 X DPRB T DECOMP I MAKE UP JET CUTTER AND SSSV HOLD I I j OPEN SLEEVE - PJSM ,- MAKE UP JET CUTTER AND SSSV HOLD I OPEN SLEEVE MU LUBRICATOR AND PRESSURE TEST BREAK AT QT SUB. GOOD TEST . 1.00 PULL ' X DPRB ' DECOMP I RIH WITH SLB JET CUTTER 23:00 00 00 . 4/3/2011 00:00 - 03:00 3.00 I PULL 1 X t DPRB 1 I DECOMP ! RIH WITH JET CUTTER '- SET SSSV HOLD DOWN SLEEVE IN SSSV ' PROFILE - SET DOWN ON FLAPPER AT 2231' WLM I I - SLEEVE NOT SET, FLAPPER IS NOT OPEN. I , I- UNABLE TO PULL UP DUE TO HOLD OPEN SLEEVE NOT SET STAGE UP PUMP TO OPEN THE FLAPPER I AND WORK DOWN. I - ABLE TO GET BY FLAPPER AT 2231' WLM. 1 1- GET ON DEPT AND CUT 1 FT ABOVE OLD , CUT (OLD CUT an, 9874' WLM) I : : - FIRE CUTTER - GOOD INDICATION THAT GUN FIRED - LOST 100# STRING WT - AMP SPIKE/DROP 1 NOTE - WE DID LOSE THE CCL WHEN GUN _ FIRED 03:00 PULL X 04:00 1.00 DPRB DECOMP POOH WITH E -LINE TOOL STRING - TAG UP ON FLAPPER WHILE COMING OUT © 2231 WLM. I - ATTEMPT TO WORK BY FLAPPER - TAGGING UP AT SAME SPOT EACH TIME - I 2231' WLM 1 - TOP OF E -LINE TOOL STRING APPEARS TO BE CLOSING FLAPPER 04:00 06:00 ' 2.00 I PULL X DPRB DECOMP I WORK E -LINE WHILE PUMPING TBG TO OPEN ,FLAPPER - PUMP DOWN TBG @ 1/2 BPM © 70 PSI IN AN ATTEMPT TO HOLD OPEN FLAPPER - STAGE PUMP RATE UP AT 1/2 BBL INCREMENTS TO A MAX OF 2 BPM © 150 PSI - WORKING LINE, UP AND DOWN WHILE I I I PUMPING. - UNABLE TO PULL UP PAST 2231' WLM. MAKE NOTIFICATIONS PRIOR TO WORKING TOOL STRING PAST SSSV FLAPPER. Printed 4/29/2011 10:52:37AM oath America BP , PagE 8of 2 j peratian Summary Report Common Well Name: P2 -16 i AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 1 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES 1 Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From 07 00 (hr) PULL Code ft) Phase Description of Operations NPT NPT Depth ( ) DPRB ( DECOMP j WORK E -LINE WHILE PUMPING DOWN TBG TO OPEN FLAPPER - PUMP DOWN TBG STAGING PUMP UP TO 8 BPM @ 1352 PSI MAX IN AN ATTEMPT TO I HOLD OPEN FLAPPER I- WORKING LINE, UP AND DOWN WHILE 1 I PUMPING. '- UNABLE TO PULL UP PAST 2231' WLM. 07:00 08:30 1.50 PULL X DPRB DECOMP CONT TO WORK E -LINE :- yNABLE TO PULL UP PAST 2231' WLM. - E -LINE PARTED AT 2800 FT /LBS. 1 1.50 POOH WITH -LINE I 08:30 - 10:00 r 150 PULL 1- X D i DECOMP 1 RD SLB SHEAV AND PRESSURE CONTROL — EQUIPMENT .10:00 - 13:00 3.00 PULL X DPRB , DECOMP RU SLB SLICKLINE ' t- RU SHEAVES, LUBRICATOR, BOPS TO } � DUTCH RISER - 13:00 - 13:30 I 0.50 PULL X i DPRB I DECOMP PRESSURE TEST SLB SLICKLINE PRESSURE 1 , CONTROL EQUIPMENT - TEST AGAINST BLIND RAMS - PRESS TEST 250 LOW FOR 5 MIN, AND 3500 I , I I PSI HIGH FOR 5 MIN. CHARTED. GOOD TEST !- BLEED OFF & BLOW DOWN 13:30 14:30 1.00 PULL X DPRB j DECOMP I RIH HOLE WITH SLICKLINE & PULL SSSV HOLD OPEN SLEEVE - - LAY DOWN HOS I- 14:30 - 15:00 I 0.50 PULL X DPRB DECOMP I RUN NO-GO ON SLICKLINE - MU NO -GO TO TAG TOP OF SSSV • , I - PRESS TEST LUB AT QT SUB I - RIH & TAG TOP OF SSSV. FLAG LINE. - POOH - LD NO-GO 15:00 16:30 1.50 PULL X DPRB DECOMP D 1 - . i DECOMP RUN MODIFIED HOLD DOWN SLEEVE WITH MULE SHOE l - MU HOS - PRESS TEST LUB AT QT SUB - RIH & SET HOS IN SSSV DECOMP POOH H 16:30 18:30 2.00 PULL X DPRB 1 RUN LEAD IMPRESSION BLOCK - MU LIB 1 - PRESS TEST LUB AT QT SUB TAG TOP OF FISH WITH LIB AT 9920' . - POOH LD LIB 18:30 20:30 2.00 PULL X DPRB DECOMP I RUN 2" JU WITH 3.6" OD BELL GUIDE I I - MU FISHING TOOLS ' - PRESS TEST LUB AT QT SUB I RIH - LATCH FISH WITH 2" JU - POOH - LD FISHING TOOLS AND ALL OF THE SLB E -LINE TOOL STRING _ _ - ** RECOVERED ALL OF THE FISH ** 20:30 -- 21:00 -- 0.50 PULL X I DPRB DECOMP 'RIG DOWN SLB SLICKLINE AND PRESSURE EQUIPMENT 21:00 - 22:00 i 1.00 PULL 1 X DPRB I DECOMP RIG DOWN DUTCH RISER Printed 4/29/2011 10:52:37AM f • a Ame rica ALASKA BP - Page 9 0 r27 • ' Aeration Summary Report. . Common Well Name: P2 -16 -- A - FE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre I Site: Pt Mac 2 Rig Name /No.: NABORS 7ES I Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26 : 16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations 1 (ft) PULL X DPRB 122:00 - 23:00 1.00 DECOMP WORK 5 1/2" TBG ' - PU LANDING JOINT AND SCREW INTO TBG HANGER - BOLDS I I I- ATTEMPT TO PULL TBG ' - UNSEAT HANGER WITH 165K - WORK PIPE UP IN INCREMENTS TO 290K WITH PIPE STRETCH ONLY 23:00 00:00 1.00 PULL X DPRB DECOMP -- — - -- - - ' ' CIRC COND y - CIRC AT 3 BPM THRU CHOKE AT 204 PSI 4/4/2011 00:00 - 00:30 0.50 PULL X DPRB I DECOMP 'WORK 5 1/2" TBG - ATTEMPT TO PI II L TBG - WORK PIPE UP IN INCREMENTS TO 310K WITH PIPE STRETCH ONLY . 00:30 - 02:30 2.00 PULL X DPRB DECOMP i CIRC BOTTOMS UP THRU CHOKE - CLOSE UPPER PIPE RAM AND CIRCULATE 'THRU CHOKE ' -3 BPM @210 PSI - SHUT DOWN PUMPS AND OPEN PIPE RAMS , - MONITOR WELL - WELL STATIC BLOW DOWN CHOKE _ I ** WELL KILL DRILL (D5)** 03: 0.50 PULL X DPRB ; 03:00 ._ 'SERVICE T- SERVICE TOP DRIVE 09:00 6.00 PULL X ! DPRB ' DECOMP WAITING -_ TATI 02:30 - 03:00 0.50 X DECOMP - ' � ON LOG INTERPRETATION MONITOR WELL WITH HOLE FILL ON I- STATIC LOSSES ARE 8 -10 BPH 09:00 - 13:00 4.00 PULL X DPRB ' DECOMP WORK PIPE - WORK TBG WHILE PUMPING - PU 170 -315K - 6 BPM @ 380 PSI - PUMP 40 BBLS HI-VIS SWEEP WHILE WORKING PIPE - 6 BPM@ 415 PSI ' - PU 170K -300K I STATIC LOSSES 9 BPH , DYNAMIC LOSSES 12 BPH - - -- - - -- - -- 14:00 1.00 PULL X DPRB — - - -- - - -- DECOMP I -- - - - - -- - - - -- ... -- - -- - - -- 13:00 LAND HANGER & RD LANDING JOINT RILDS 14:00 16:30 2.50 PULL X ' DPRB DECOMP RIG UP SLB E -LINE 16:30 - 20:00 3.50 PULL X DPRB 1 DECOMP , RIH WITH SLB USIT TOOL - LOG FROM 9900' TO 2000' 20:00 - 21:00 1.00 PULL X DPRB DECOMP i RD SLB E -LINE 21:00 - 23:30 2.50 PULL X DPRB DECOMP RU SLB SLICKLINE - PRESS TEST LUBRICATOR 300 PSI LOW AND 3200 PSI HIGH FOR 5 MIN EACH. GOOD TEST 23:30 - 00:00 I 0.50 I PULL X DPRB 1 DECOMP ' RIH WITH RETRIEVING TOOL 4/5/2011 00:00 - 01:00 1.00 PULL N DPRB DECOMP RIH TO 2223' WLM WITH SLICKLINE AND LATCH HOLD OPEN SLEEVE i - JAR FREE & POOH '- RECOVERED HOLD OPEN SLEEVE Printed 4/29/2011 10:52:37AM aitft Am rica "A SKA P' gage 10 i t 27 "_ , • , . , „ _ . : , • , er'ation StirOma Re P � ort P Event om mon Well Name: P16 AFE No Type: W ( ) �._ Common WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: , Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth' Phase Description of Operations 01:00 150 PULL N (ft) - -- - -- -- 02:30 r) � DPRB DECOMP RUN MODIFIED HOLD OPEN SLEEVE WITH (r MULE SHOE (4.20" ID) I - MU HOS ' - PRESSURE TEST LUBRICATOR AT QT SUB - RIH & SET HOS IN SSSV POOH - R D SLB SL ICKLINE 02:30 N DPRB 04:30 2.00 PULL DECOMP !MAKE UP LANDING JOINT - PU 7" NSCC HANDLING TOOLS & TONGS I '- MAKEUP LANDING JOINT & SPACE OUT ; I PICK UP TO 176K LBS, 10 K LBS OVER I STRING WEIGHT. 04:30 08:30 4.00 PULL N DPRB L. SET SLIPS TO HOLD TENSION ON STRING. I DECOMP I RIG UP SLB E-LINE WITH PRESSURE , ,CONTROL EQUIPMENT. ;- PJSM WITH RIG CREW AND SLB E -LINE ; :CREW. - PICK UP AND RIG UP SHEAVES. RIG UP GREASE HEAD AND GREASE !BASKET. I - MAKE UP JET CUTTER AND RUNNING TOOLS. j- RUN IN THE HOLE TO 300' WITH JET 09:30 'CUTTER. 08:30 - 1.00 PULL N DPRB I DECOMP PULL OUT OF THE HOLE WITH THE JET 1 CUTTER BHA. AFTER DISCUSSION WITH TOWN DECIDED TO MODIFY BHA. I - PULL OUT OF THE HOLE FROM 300' 09:30 10:30 1.00 PULL N DPRB DECOMP MODIFY THE JET CUTTER BHA. - CHANGED THE BHA CONFIGURATION. - ADDED SECOND CENTRALIZER 9' ; ,ABOVE FIRST. - RUN IN THE HOLE TO 300' WITH THE JET I CUTTER. PERFORM A ROLLING PRESSURE TEST ON THE LUBRICATOR. I , - 500 PSI FOR 5 CHARTED MINUTES. - GOOD TEST. 10:30 - 13:30 3.00 PULL I N DPRB DECOMP RUN IN THE HOLE WITH THE JET CUTTER ON I E -LINE AND CUT TUBING. - FROM 300' TO 9430'. - FIRED JET CUTTER AT 9430'. I - PULL OUT OF THE HOLE WITH E- LINE. 1 13:30 16:30 3.00 PULL N 1 DPRB DECOMP CONFIRM TUBING CUT AND RIG DOWN SLB E-LINE. - PICK UP ON 5 1/2" TUBING AND CONFIRM CUT. - UP WEIGHT = 160K LBS, DOWN WEIGHT , I = 142K LBS. MONITOR WELL. - STATIC LOSS RATE = 7 BPH. - RIG DOWN SLB E -LINE. 16:30 - 18:30 1 2.00 PULL P DECOMP TERMINATE CONTROL LINE AND LAY DOWN TUBING HANGER. - LAY DOWN THE 7" SPACE -OUT PUPS TO I THE 5 1/2" TUBING HANGER. TERMINATE THE 1/4" SS CONTROL LINE. LAY DOWN THE TUBING HANGER. Printed 4/29/2011 10:52:37AM „ , ■ ' , , ■ , , ttli America :!. ALASKA -,, BP r 1 r : ' i '; . ' : ': iFfeP I I 0517 , : ' ; ' : H, ', ! : : ■ 1 : '''': I: OperatiortSummary Report, :: : :' :', , :: : : :;: Common Well Name: P2-16 AFE No Event Type: WORKOVER (WO) ; Start Date: 3/25/2011 End Date: 4/15/2011 X4-00T38-E (3,050,000.00 ) [ I _ Project: Point McIntyre Site: Pt Mac 2 Rig Name/No.: NABORS 7ES 1 Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date I From - To Hrs I Task Code 1 NPT I NPT Depth Phase I Description of Operations (hr) 1 1 L (ft) . 18:30 - 20:00 1.50 PULL P DECOMP CIRCULATE A BOTTOMS UPS. - PUMPED 467 BBLS AT 11 BPM AND 350 PSI. ' - RIG UP TO PULL AND LAY DOWN 5 1/2” TUBING. :- FMC RE-DRESSED THE TUBING HANGER. - INSTALLED NEW SEALS. - PLUGGED CONTROL LINE , I PENETRATIONS. , 1 - INSTALLED TWC. I I - MONITORED WELL. - t - STATIC LOSS = 7 BPH. .r 20:00 - 00:00 4.00 PULL P DECOMP , PULL AND LAY DOWN 5 1/2" TUBING AND 1/4" I ; SS CONTROL LINE. - PULL FROM 9430' TO 7576'. . H. UP WEIGHT = 135K LBS, DOWN WEIGHT = I 130K LBS. 1 , - CONTROL LINE BROKE ON JT #28. - RECOVERED CONTROL LINE ON JT #32. 4/6/2011 00:00 - 02:00 2.00 PULL P DECOMP I PULL AND LAY DOWN 5 1/2" TUBING AND 1/4" SS CONTROL LINE. I 1 - FROM 7576' TO 7202' I , - UP WEIGHT = 125K LBS. • I . I , - TERMINATE CONTROL LINE AT SSSV. , . • I- RIG DOWN CONTROL LINE SPOOLING UNIT. I - RECOVERED 22 SS BANDS AND ALL OF THE CONTROL LINE. 02:00 - 08:00 6.00 PULL 1 P DECOMP PULL AND LAY DOWN 5 1/2" TUBING. - FROM 7202' TO SURFACE. - RECOVERED THE FOLLOWING: - 226 JOINTS OF 5 1/2" TUBING. - 1 GLM. 1 1 - 1 SSSV. , 1 - 1 CUT JOINT OF 5 1/2" TUBING. 1 -- - 10.05' LONG AND 6.625" OD OF CUT. 08:00 - 08:30 0.50 PULL 1 P I DECOMP RIG DOWN TUBING HANDLING EQUIPMENT. 08:30 - 09:00 0.50 BOPSUR P ' ED COMP FUNCTION TEST BOPS. , I I I - FUNCTION UPPER PIPE RAMS, LOWER PIPE I 1 I RAMS AND BLIND SHEAR RAMS TO CLEAN I , , I OUT ANY SS BANDS OR DEBIS TRAPPED IN I I ITHE RAM CAVITIES. ' 09:00 - 09:30 , 0.50 WHSUR P , I DECOMP : INSTALL WEAR BUSHING. 1 09:30 - 10:00 0.50 FISH 1 P DECOMP SERVICE TOP DRIVE AND DRAWWORKS. 10:00 - 12:00 2.00 FISH N ' DPRB 9,420.00 DECOMP PICK UP BHA #1, OVERSHOT BHA. - 8 1/8" OD OVERSHOT W/ HOLLOW MILL EXTENSION. - OVERSHOT EXTENSION. - BUMPER SUB. 1 1 - OIL JARS. - (9) 6 1/4" SRILL COLLARS. - INTENSIFIER. , I - PUMP OUT SUB. 12:00 - 21:00 9.00 1 FISH , N ' DPRB 9,420.00 ' DECOMP RUN IN THE HOLE WITH BHA #1 ON 4" DRILL PIPE. - FROM 320' TO 9371' DPM. - PICKING UP DRILL PIPE FROM THE PIPE SHED. , L I Printed 4/29/2011 10:52:37AM orth At'C4erica -a AL PK 1 BP' ' Page 12 of V' eration Surnma . R ort p P, Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase I Description of Operations 21:00 - 21:30 0.50 FISH N DPRB 9,420.00 1 DECOMP I ESTABLISH FISHING PARAMETERS AND DRESS -OFF FISH. I I - UP WEIGHT = 174K LBS, DOWN WEIGHT = :150K LBS. I I - 5 BPM AND 430 PSI. - 60 RPM AND 4K FT -LBS TORQUE. - ROTATING WEIGHT = 165K LBS. ' -.TAG TOP OF FISH AT 9420' DPM. _ _ - DRESS OFF TOP 2' OF FISH. - -- -- - - - - -- - - -- -- 21:30 00:00 2.50 FISH N DPRB I 9,420.00, DECOMP ENGAGE FISH AND WORK FISH. I - ENGAGED FISH. ' - JAR ON FISH WITH 225K LBS AND PULL TO 1 ; 250K LBS:. - CONTINUED TO WORK FISH AND I I 1INCREASE PULL. - MAX JAR ON FISH WITH 325K LBS AND PULL TO 375K LBS. GAINED 2° AFTER JARRING FOR 2 HRS. — 9,420.00 4/7/2011 00:00 - 00:30 0.50 FISH N DPRB 9 DECOMP CONTINUE TO WORK FISH. ' - CONTINUE TO JAR ON FISH AT 325K LBS AND PULL TO 375K LBS. i_ FISH PULLED WITH 20K LBS DRAG. 00:30 - 01:00 0.50 FISH N DPRB 9,420.00 DECOMP PUMP OUT 5 STANDS OF 4" DRILL PIPE. PUMPING AT 10 BPM AND 1345 PSI. , � - UP WEIGHT = 185K LBS. - STAND BACK 5 STANDS OF 4" DRILL PIPE. LAY DOWN 1 SINGLE JOINT OF 4 "DRILL / PIPE. I / 101:00 - 06:30 5.50 FISH I N DPRB 1 9,420.00 DECOMP CIRCULATE A BOTTOMS UP. - CIRCULATING A BOTTOMS UP. - 10 BPM AND 1345 PSI. , . '- BEFORE BOTTOMS UP WAS ACHIEVED GAS I LEVELS AT THE POSSUM BELLY WENT TO 50 I I LEL WITH A SIGNIFICANT AMOUNT OF SILT I COMING ACROSS THE SHAKERS. - DECIDED TO SLOW DOWN PUMP RATE AND DIVERT THROUGH THE GAS BUSTER TO I VENT GAS. - NO INCREASE IN FLOW RATE. - CLOSED RAMS AND REDUCED RATE TO 3 BPM AND 190 PSI. AFTER PUMPING A BOTTOMS UP OPENED I ' BACK UP AND MONITORED THE WELL. - STATIC LOSS RATE = 8 BPH. - NO GAS. BEGAN PUMPING ANOTHER BOTTOMS UP AT MAX RATE TO CONTINUE TO REMOVE SILT FROM WELLBORE. I 06:30 - 10:30 ' 4.00 FISH N I DPRB 9,420.00 DECOMP I PULL TF THE HOLE FISH. WITH BHA #1, OVERSHOT - FROM 9417' TO 775' DPM. - UP WEIGHT = 60K LBS, DOWN WEIGHT = 60K LBS. 10:30 11 :30 1.00 FISH N DPRB 9,420.00 DECOMP LAY DOWN BHA #1. PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. I - STAND BACK DRILL COLLARS. .- LD BHA #1 TO THE FISH. Printed 4/29/2011 10:52:37AM flit Art erida 'ALASKA BP Page 1 Operation Sturman/ Report , : Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 'X4- 00T38 -E (3,050,000.00 ) I Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26 : 16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) Date From - To I Hrs I Task Code NPT I NPT Depth Phase Description of Operations ' (hr) { (ft) 11:30 - 14:00 , 2.50 FISH N DPRB 9,420.00 DECOMP I LAY DOWN THE RECOVERED 5 V2" TUBING. 1 I- RIG UP TUBING HANDLING EQUIPMENT. I - LAY DOWN FISH. - RECOVERED THE FOLLOWING: - TOP CUT JOINT OF 5 1/2" TUBING. - LENGHT = 31.44'. - 9 FULL JOINTS OF 5 1/2" TUBING. I - GLM ASSEMBLY WITH 2 PUP JOINTS. ' - CUT JOINT OF 5 1/2" TUBING. I - LENGHT = 4.15'. I - OD AT CUT = 6.125 ". - GOOD, CLEAN CUT. rt 114:00 - 16:00 2.00 FISH N DPRB 9,420.00 { DECOMP I; RIG DOWN THE TUBING HANDLING EQUIPMENT AND SERVICE THE RIG. - RIG DOWN DOUBLE STACK TONGS. MAKE SERVICE BREAKS ON OVERSHOT ASSY. - SERVICE TOP DRIVE. CLEAN RIG FLOOR. 16:00 - 18:30 2.50 FISH N ; DPRB I 9,844.00 ' DECOMP I PICK UP AND RUN IN THE HOLE WITH BHA #2, DRESS -OFF ASSY. I I ' ! PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. PICK UP BHA #2 AS FOLLOWS: - 8 1/2" x 5 9/16" DRESS -OFF SHOE - (2) WASHOVER EXTENSION - INNER DRESS -OFF MILL I - WASHOVER BOOT BASKET - PINxPIN`XO' - 8 1/2" STRING MILL I - (2) 7" BOOT BASKET I - BIT SUB ' - (2) STRING MAGNET - 6 1/4" BUMPER SUB - 6 V4" OIL JAR I - PUMP -OUT SUB I I I - (9) 6 1/4" DRILL COLLAR I XO' OVERALL LENGTH = 356.18'. MAX OD = 8.50 ". j -- -- '- - -= -� - -- MIN ID = 1.50 ". 18:30 20:30 2.00 FISH - N . DPRB 9,844.00 DECOMP RUN IN THE HOLE WITH BHA 2 ON 4" DRILL I - I I PIPE FROM THE DERRICK. - FROM 356' TO 4000' DPM. - UP WEIGHT = 110K LBS, DOWN WEIGHT = ! 105K LBS. 20:30 - 21:00 0.50 FISH N DPRB 9,844.00 DECOMP ! WORK STRING MIl I ACROSS I INFR TOP PACKER SETTING DEPTH. - UP WEIGHT = 110K LBS, DOWN WEIGHT = 105K LBS. ROTATING AT 60 RPM, 1.3K FT -LBS I I TORQUE. - ROTATING WEIGHT = 107K LBS. I 12 BPM AND 1111 PSI. 1 21:00 - 23:00 2.00 FISH N DPRB 9,844.00 DECOMP CONTINUE TO RUN IN THE HOLE WITH BHA ' #2 ON 4" DRILL PIPE. I I - FROM 4000' TO 9844' DPM. ' - UP WEIGHT = 175K LBS, DOWN WEIGHT = 140K LBS. N DPRB C - 23:00 00:00 1.00 FISH 9,844.00 DECOMP UT AND SLIP 117' OF DRILL LINE. INSPECT AND SERVICE DRAWWORKS. Printed 4/29/2011 10:52:37AM - •pith a-ALASKA ,I3P ,‘: :;-: , 0 • , , Page :14, of Zr, - , . ,„ ,.. ' ''.:. „' c - ,; : ' • Operation :Summary Report „ : : Common Well Name: P2-16 [ AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 I X4-00T38-E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name/No.: NABORS 7ES '1 Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. i I UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs I Task Code I NPT NPT Depth I Phase I Description of Operations I ' (hr) (ft) I t 1- , 4/8/2011 00:00 - 02:00 2.00 1 FISH N 1 DPRB 9,848.00 DECOMP I ATTEMPT TO DRESS-OFF 5 1/2" TUBING _ I 1 i I STUB. I I I I - ESTABLISH MILLING PARAMETERS. - UP WEIGHT = 190K LBS, DOWN WEIGHT , I = 145K LBS. I , - 60 RPM AND 6K FT-LBS TORQUE. , I - ROTATING WEIGHT = 168K LBS. , 1 1 I - 5 BPM AND 495 PSI. I . I - WASH DOWN AND TAG TOP OF TUBING I I STUB AT 9884' DPM. 1 , - CONTINUE TO REAM DOWN 11' TO INNER I I MILL. - ATTEMPTED TO MILL OFF TOP OF TUBING STUB. „ I - WORKED WEIGHT ON BIT FROM 5K - 20K LBS. 1 ' - NO INCREASE IN TORQUE 1 - ATTEMPTED TO WORK WITH PUMPS ON 'AND OFF. I I - APPEARS THAT THE 1' CUT PIECE IS SPINNING. I 1 - LESS THAN 1/2 BBL OF SILT ACROSS THE SHAKERS AT BOTTOMS UP STROKES. 02:00 - 06:00 4.00 FISH N , DPRB I 9,848.00 DECOMP PULL OUT OF THE HOLE WITH BHA #2, DRESS-OFF ASSY. 1 , I - FROM 9848' TO 356' DPM. 0600 - 08:00 2.00 FISH N ! DPRB I 9,848.00 DECOMP LAY DOWN BHA #2. , 1 I - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. I - STAND BACK DRILL COLLARS. - RECOVERED THE FOLLOWING: -7 & 1/2 SS BANDS, 7 WITH THE BUCKLES INTACT. - 1 GALLON OF CEMENT CHUNKS. I : - 1/2 GALLON OF METAL FROM THE MAGNETS. 1 1 1 1 - 1.43' PIECE OF 5 1/2" TUBING. - GOOD, CLEAN CUTS ON BOTH ENDS. 1 : 1SEE ATTACHED PHOTOS. 08:00 - 09:30 : 1.50 BOPSUR P , DECOMP RIG UP TO TEST BOPE. - PULL WEAR BUSHING. , 1 - INSTALL TEST PLUG. 1 ' - PICK UP TEST TOOLS. Printed 4/29/2011 10:52:37AM • rfh Amer ICB AKA �3 P age 15 of Qpera an Summary Repo Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: 1Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs r Task Code NPT NPT Depth I Phase Description of Operations (hr) ( ft ) 09:30 - 14:30 1 5.00 BOPSUR P ' DECOMP TEST ROPE PER AOGCC REGULATIONS AND BP ADWOP POLICY. - PRESSURE TESTED TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MINUTES. - TESTED ALL CHOKE MANIFOLD VALVES TOTAL). ) . MANUAL CHOKE AND MANUAL KILL (Y)f 1 VALVES. - HCR CHOKE AND HCR KILL VALVES. 1 l . - FULL OPENING SAFETY VALVES (3 1/2 ", / S3'( 14 AND 5 "). tt I � - 4" DART VALVE. TOP DRIVE AIR ACTUATED IBOP. - LOWER MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS. - UPPER VBRS WITH 4" TEST JOINT. - LOWER VBRS WITH 4" TEST JOINT. - TESTED THE- 'ANNULAR PREVENTER WITH I I 4" TEST JOINT. - 250 PSI LOW AND 2500 PSI HIGH FOR 5 CHARTED MINUTES. I - TESTED THE SUPER CHOKE. ' ` . - 250 PSI LOW AND 3200 PSI HIGH FOR 5 CHARTED MINUTES. ,: TESTED THE MANUAL CHOKE. - 250 PSI LOW AND 3300 PSI HIGH FOR 5 j I CHARTED MINUTES. 1- PERFORMED AN ACCUMULATOR I DRAWDOWN TEST. - 14 SEC TO 200 PSI, 95 SEC TO FULL PRESSURE. - 5 BOTTLES WITH 1950 PSI. - ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER. - AOGCC, CHUCK SCHEVE, WAIVED THE 14.30 15:30 1.00 BOPSUR P STATE'S RIGHT TO WITNESS THE TEST. DECOMP I RIG DOWN BOPE TEST EQUIPMENT. - BLOW DOWN TOP DRIVE AND ALL LINES. I - PULL TEST PLUG. INSTALL 8 3/4" ID WEAR BUSHING. 15:30 - 17:00 1.50 FISH P DECOMP !TICK UP AND RUN IN THE HOLE WITH BHA I #3, DRESS -OFF ASSY. - PJSM WITH RIG CREW AND BAKER FISHING I REPRESENTATIVE. I I -PI BHA W CK UP B #3 AS FOLLOWS. I I - 8 1/2" x 5 9/16" DRESS -OFF SHOE - (2) WASHOVER EXTENSION - INNER DRESS -OFF MILL - WASHOVER BOOT BASKET I PIN x PIN `XO' - (2) 7" BOOT BASKET , - BIT SUB - (2) STRING MAGNET - 6 1/4" BUMPER SUB - 6 1/4" OIL JAR - PUMP -OUT SUB - (9) 6 1/4" DRILL COLLAR XO' , I OVERALL LENGTH = 351.85'. , ' MAX OD = 8.50 ". MINID= 1.50 ". Printed 4/29/2011 10:52:37AM I ALASKA - BP' Page . 16 . of 2 Operation Summary Report . - - Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: ! Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. LUWI: Active Datum: 26 : 16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) 1 (ft) 1 17:00 21:00 4.00 FISH P � DECOMP [RUN IN THE HOLE WITH BHA #3 ON 4" DRILL PIPE. I - FROM 351' TO 9840' DPM. 121:00 - 23:30 2.50 FISH P DECOMP , DRESS -OFF TUBING STUB. ! !- ESTABLISH MILLING PARAMETERS. 1 - UP WEIGHT = 187K LBS, DOWN WEIGHT 148K LBS. I - 60 RPM AND 6.5K FT -LBS OF TORQUE. � - ROTATING WEIGHT = 168K LBS. - 6 BPM AND 580 PSI. - 12 BPM AND 2100 PSI. WASH DOWN AND TAG TUBING STUB AT 9859'. - CLEAN OUT CEMENT AND WASH DOWN TO 9870'. 1 I- DRESS -OFF THE TUBING STUB WITH THE INNER M ILL. WEIGHT - 15K - 25K'LBS HT O N BIT. G - 60 -80 RPM. I -`7K - 11K FT -LBS TORQUE. ! - 4 BPM AND 305 PSI. 1- PICKED UP AND SLID OVER TUBING STUB WITHOUT EXCESS DRAG. - CONFIRMED THIS WITH AND WITHOUT ROTATION AND PUMPS. 23:30 - 00:00 0.50 ! FISH P DECOMP CIRCULATE A 50 BBL HIGH -VIS SWEEP. - 12 BPM AND 2070 PSI. 4/9/2011 ' 00:00 - 01:00 1.00 FISH P DECOMP I CONTINUE TO CIRCULATE 50 BBL HIGH -VIS I SWEEP. - 12 BPM AND 2070 PSI. 1 - PUMPED A TOTAL OF 748 BBLS. ' ! - A SIGNIFICANT AMOUNT CEMENT ACROSS THE SHAKERS WITH THE HIGH -VIS SWEEP. 01:00 - 03:00 2.00 FISH P DECOMP PULL OUT OF THE HOLE WITH BHA #3, 1 ! I DRESS -OFF ASSY. ! I - FROM 9840' TO 5413' DPM. 03:00 04:00 I 1.00 FISH P DECOMP ! INVESTIGATE NOISE FROM DRAWWORKS. - REPAIRED CLAMP THAT VIBRATED LOOSE. - CLAMP HOLDS HANDLE FOR THE DYNAMATIC. 04:00 05:30 r 1.50 1 FISH P I DECOMP PULL OUT OF THE HOLE WITH BHA #3. ' - FROM 5413' TO 351' DPM. 05:30 - 08:00 2.50 FISH P ' DECOMP ' LAY DOWN BHA #3. - PJSM WITH RIG CREW AND BAKER FISHING 1 REPRESENTATIVE. ! LAY DOWN 6 1/4" DRILL COLLARS. 1 - CONFIRM TATTLE TALES ON INNER DRESS -OFF MILL. 08:00 - 11:30 3.50 FISH P DECOMP PICK AND RUN IN THE HOLE WITH A 95/8" 1 RTTS PACKER._ , - TO 6941' DPM. ' - UP WEIGHT = 127K LBS, DOWN WEIGHT = 115K LBS. Printed 4/29/2011 10:52:37AM rth America * ALASKA BP Page 1z a e 4i, fi < t�►perat1ot Summa Re ®rt Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 End Date: 4/15/2011 I IX4- 00T38-E (3,050,000.00 ) Project: Point McIntyre 7 Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING IN I UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task I Code I NPT NPT Depth Phase I Description of Operations , (hr) ( ft) 1 11:30 - 12:30 ! 1.00 FISH P DECOMP SET RTTS AND TEST CASING INTEGRITY. I I I - RTTS CENTER OF ELEMENT AT 6932' DPM. I - TEST 9 5/8" CASING FROM 6932' TO I SURFACE. - 250 PSI LOW 4000 PSI HIGH FOR 30 !CHARTED MIN. - GOOD TEST. - 4.9 BBLS TO PRESSURE UP. - 4.8 BBLS BLED BACK. - WSL CALLED AND CONFIRMED TEST " WTL. 12:30 - 14:00 1.50 i FISH P DECOMP I RELEASE RTTS AND RUN IN THE HOLE. - FROM 6932' TO 9571' DPM. - UP WEIGHT = 170K LBS, DOWN WEIGHT = 132K LBS. 14:00 - 15:30 1.50 FISH P DECOMP I SET RTTS AND TEST COMPLETION PACKER AND BRIDGE PLUG INTEGRITY. - RTTS'CENTER OF ELEMENT AT 9560' DPM. I . I j - TEST BELOW RTTS TO COMPOSITE PLUG AT 9937' I - 250 PSI LOW 3000 PSI HIGH FOR 10 CHARTED MIN. - GOOD TEST. t - 1.9 BBLS TO PRESSURE UP. I I , - 1.5 BBLS BLED BACK. - RELEASE RTTS. - MONITOR WELL. - STATIC LOSS RATE = 3 BPH. - RD TEST EQUIPMENT AND BLOW DOWN LINES. 1 15:30 - 20:30 5.00 FISH P DECOMP PULL OUT OF THE HOLE AND LAY DOWN THE 20:30 00:00 3.50 WHSUR 9 5/8" RTTS. P DECOMP I INSTALL THE TUBING HANGER WITH TWC I INSTALLED AS A BARRIER. I I - PULL THE 8 3/4" WEAR BUSHING. INSTALL THE TUBING HANGER WITH TWC. RUN IN THE LOCK DOWN SCREWS. TES T FROM BELOW. - ROLLING TEST AT 33 GPM AND 690 PSI. 1 FOR 10 CHARTED MIN. - TEST FROM ABOVE. - 250 PSI LOW 1000 PSI HIGH FOR 10 1 CHARTED MIN. - GOOD TEST. 4/10/2011 I 00:00 01:30 1 1.50 BOPSUR P DECOMP CHANGED UPPER PIPE RAMS TO 7 5/8" I FIXED. II I Printed 4/29/2011 10:52:37AM ' ' orth. America - ALASK BP' Page 18 of 2 7' parattiort Summary Report Common Well Name: P2-16 v., AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES 1 Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft)! 01:30 - 05:00 3.50 BOPSUR P DECOMP ;PRESSURE TEST UPPER PIPE RAMS PER BP ADWOP AND AOGCC REGULATIONS. 1 - INSTALL 7 5/8" TEST JOINT. 1- ATTEMPT TO TEST TO 250 PSI LOW. - FLUID LEAKING PAST TWC. - CAN NOT GET THE POPPET TO SET. RIG DOWN TEST JOINT AND CLOSE BLIND SHEAR RAMS. 1 - USE RIG PUMP TO SET TWC BY PRESSURING UP TO 1000 PSI. - INSTALL 7 5/8" TEST JOINT. i- TEST UPPER PIPE RAMS. - 250 PSI LOW 4000 PSI HIGH FOR 5 ^ I CHARTED MINUTES. - GOOD TEST. '- RIG T RIG DOWN S EQ UIPMENT. 1 - PULL TUBING HANGER WITH TWC 'INSTALLED. ' 05:00 - 06:30 1.50 CASING P DECOMP RIG UP 7 5/8" LINER RUNNING EQUIPMENT. 06:30 - 12:00 5.50 CASING P DECOMP ' RUN IN THE HOLE WITH 7 5/8 ", 29.7 LB /FT, L -80, HYDRIL 521 SCAB LINER. - TO 2675'. UTILIZE TORQUE TURN EQUIPMENT. - OPTIMUM TORQUE = 10,100 FT -LBS. - FILLING ON THE FLY AND TOPPING OFF EVERY FIVE JOINTS. CHECKED FLOAT EQUIPMENT. UP WEIGHT = 94K LBS, DOWN WEIGHT = I 90K LBS. 12:00 - 18:00 6.00 CASING P DECOMP CONTINUE TO RUN IN THE HOLE WITH THE 7 ' 5/8" SCAB LINER. 1- FROM 2675' TO 5845'. ' - UP WEIGHT = 178K LBS, DOWN WEIGHT = i 167K LBS. 1.00 DECOMP 18:00 - 19:00 CASING MAKE UP LINER HANGER AND LINER TOP _ PACKER TO 7 5/8" SCAB LINER. , - PJSM WITH RIG CREW AND BAKER REPRESENTATIVE. BAKER 7.625" x 9.625" FLEXLOCK III LINER HANGER. - SET TO SHEAR AT 2800 PSI. I - BAKER 7.625" x 9.625" ZXP LINER TOP ! I PACKER. I - WITH C -2 LINER RUNNING TOOL. - MIN. SETTING FORCE = 50K LBS. RIG DOWN CASING RUNNING EQUIPMENT. 19:00 - 20:30 1.50 CASING P DECOMP ' RUN IN THE HOLE WITH THE 7 5/8" SCAB LINER ON 4" DRILL PIPE FROM THE DERRICK. I - PICK UP THE FOLLOWING: - 4 1/2 IF x HT40 'XO'. - HT40 x 3 1/2 IF 'XO'. - (9) 4 3/4" SPIRAL DRILL COLLARS. - 3 1/2" IF x HT40 'XO'. - 4" DRILL PIPE PUP (4.51') FOR SPACE OUT. 4" DRILL PIPE PUP (15.14') FOR SPACE OUT. ' - RUN IN THE HOLE WITH 1 STAND OF 4" DRILL PIPE. - TO 6278'. - UP WEIGHT = 187K LBS, DOWN WEIGHT = 175K LBS. Printed 4/29/2011 10:52:37AM �t �met : ALA>KA �P' Pag�19of2 O pera i o n Summary Repo .: Common Well Name: P2 -16 ' AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) i Project: Point McIntyre , Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT 1 1 NPT Depth Phase Description of Operations (hr) (ft) ' hr 20 :30 22:00 1.50 CASING P DECOMP I CIRCULATE 150% LINER VOLUME. I - STAGE UP TO 5 BPM AND 493 PSI. _L _ - PUMPED A TOTAL OF 400 BBLS. 22:00 - 00:00 2.00 CASING P DECOMP ' RUN IN THE HOLE WITH THE 7 5/8" SCAB LINER ON 4" DRILL PIPE FROM THE DERRICK. - FROM 6278' TO 8064'. UP WEIGHT = 218K LBS, DOWN WEIGHT = 1175K LBS. - DRIFT DRILL PIPE OUT OF DERRICK. - USING A 2 5/16" DRIFT. FILLING THE LINER EVERY 10 STANDS WITH CASING P -- 9.8 PPG BRINE. _ L. -- 4/1 1 00:00 01:00 1.00 DECOMP ;CIRCULATE A BOTTOMS UP. ,- STAGE UP TO 5 BPM AND 555 PSI. PUMPED A TOTAL OF 222 BBLS. 01:00 03:00 2.00 CASING Ir P DECOMP. CONTINUE TO`RUN IN THE HOLE WITH THE 7 5/8" SCAB LINER ON 4" DRILL PIPE FROM THE DERRICK. - - FROM 8064" TO 9849'. 1 .- UP WEIGHT = 250K LBS, DOWN WEIGHT = 185K LBS. - DRIFT DRILL PIPE OUT OF DERRICK. - USING A 2 5/16" DRIFT. / 1- FILLING THE LINER EVERY 10 STANDS WITH , 19.8 PPG BRINE. - PICK UP THE BAKER CEMENT HEAD AND A SINGLE JOINT OF 4" DRILL PIPE. l IN THE HOLE AND NO -GO AT I I I CONTINUE 9874'. - WITNESS BOTH SETS OF SHEAR PINS i ON OVERSHOT SHEAR. - PICK UP TO UP WEIGHT AND 2'. 03:00 - 04:30 1.50 CASING P . i DECOMP CIRCULATE A DRILL PIPE AND LINER 1 VOLUME. - STAGE UP TO 5 BPM AND 775 PSI. - PUMPED A TOTAL OF 310 BBLS. 1 � RIG UP SCHLUMBERGER CEMENTERS Printed 4/29/2011 10:52:37AM _ „ rth. Ameri = ALASKA BP ' P age 20 'of 2 Aeration Summary Report ■ Common Well Name: P2 -16 �— AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 4/15/2011 IX4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre „ Site: Pt Mac 2 I Rig Name /No.: NABORS 7ES 1 Spud Date/Time: ! Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth ! Phase I I Description of Operations (ft) (hr) 04:30 - 07:30 3.00 CASING P DECOMP PLACE CEMENT AND SET LINER HANGER ! AND LINER TOP PACKER FOR 7 5/8 ", 29.7 LB/FT, HYDRIL 521 SCAB LINER. ,- PJSM WITH THE RIG CREW, ��,1 SCHLUMBERGER CEMENTERS, BAKER COMPLETIONS REPRESENTATIVES AND 50'6 CH2MHILL VAC TRUCK DRIVERS. I- PUMP 5 BBLS OF WATER. - PRESSURE TEST ALL SURFACE LINES. - 250 PSI LOW 4500 PSI HIGH. -PUMP 124 BBLS OF 15.8 CLASS 'G' CEMENT. - YIELD = 1.16 CU FT /SK. - MIX WATER = 5.099 GAUSK. - PUMP CEMENT DOWNHOLE. - 4 BPM AND 400 PSI FOR 6 MIN. -,5 BPM AND. 540 PSI FOR 17 MIN. I - REDUCE RATE TO 3 BPM AND 140 PSI FOR 6 MIN. 1 - TOTAL PUMP TIME 29 MIN. - DROP PLUG AND DISPLACE WITH RIG ! PUMPS. - KICK OUT PLUG WITH 5BBLS OF WATER ' FROM SLB. - DISPLACED WITH 9.8 PPG NACL BRINE. - 5 BPM AND 300 PSI. - 3 BPM AND 89 PSI. - DID NOT SEE PLUG LATCH. - CONTINUE TO DISPLACE AT 5 BPM AND 200 PSI. - CEMENT AT THE PORTED SUB 188 BBLS ' IN. I - PLUG BUMPED WITH 290 BBLS OF 9.8 PPG BRINE PUMPED. PRESSURE UP TO 4000 PSI TO SET THE LINER HANGER. - POSITIVE INDICATION OF HANGER SET ! AT SURFACE. - HANGER SET AT 3980 PSI. BLEED OFF ALL PRESSURE AND VERIFY I THE FLOAT IS HOLDING. I I I - CLOSE FOSV AND RIG DOWN THE CEMENT I LINE AND CEMENT HEAD. - RELEASE THE BAKER RUNNING TOOL. I 1 - 15 TURNS TO THE RIGHT. - PRESSURE UP TO 1000 PSI. - PICK UP TO EXPOSE THE DOG SUB. - OBSERVED PRESSURE DROP. - CIRCULATE 50 BBLS OF 9.8 PPG BRINE AT 7 BPM. - SET DOWN 50K LBS TO SET THE BAKER ZXP LINER TOP PACKER. - ROTATE TO CONFIRM PACKER IS SET. PICK UP TO CLEAR LINER TOP. - LINER TOP SET AT 3996'. "` CEMENT IN PLACE AT 06:48 "" ' SEE SCANNED CHART 07:30 08:00 0.50 CASING P DECOMP CIRCULATE OUT CEMENT. - 12 BPM AND 1270 PSI. 20 BBLS CEMENT CONTAMINATED BRINE ! RECOVERED. - LAY DOWN CEMENT HEAD. Printed 4/29/2011 10:52:37AM :. - ottkt America' - ALASKA - BP. Page 2t 0„27 ; peratron Summary Report Common Well Name: P2 -16 Event Type: WORKOVER (WO) Start Date: 3/25/2011 ; End Date: 4/15/2011 iX4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES , Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26:16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT ' NPT Depth Phase Description of Operations (hr) CASING P _I (ft) DECOMP 108:00 10:00 I 2.00 1 1 PULL OUT OF THE HOLE, STANDING BACK 4" I DRILL PIPE. l ;- FROM 3996' TO SURFACE. 1 - LAY DOWN LINER RUNNING TOOL. I 1 I I 1 - CONFIRMED DOG SUB SHEARED. 10:00 11:30 1.50 r WHSUR 1 P 1 DECOMP I PULL WEAR RING AND INSTALLED TEST ' PLUG. f - PRESSURE TESTED BLIND SHEAR RAMS I AND TEST PLUG. - 250 PSI LOW 1000 PSI HIGH FOR 10 CHARTED MIN. 11:30 :30 - 12:00 0.50 WHSUR P DECOMP I CHANGE UPPER PIPE RAMS TO 3 1/2" x 6" - I VARIABLE BORE RAMS. 12:00 14:30 - - - 2.50 I WHSUR I P ! DECOMP I PRESSURE TESL PIPS RAMS PER BP ADOWP IAND AOGCC REGULATIONS. -TEST UPPER 31/2" x 6" PIPE RAMS WITH BOTH 4" AND 5 1/2" TEST JOINT. - 250 PSI LOW 4000 PSI HIGH FOR 5 I CHARTED MIN. - TEST LOWER 3 1/2" x 6" PIPE RAMS WITH 5 ! ! 1/2" TEST JOINT. , - 250 PSI LOW 4000 PSI HIGH FOR 5 ; CHARTED MIN. 14:30 - 17:00 2.50 WHSUR P DECOMP ! REMOVE AND REPLACE THE 95/8" MANDREL PACK -OFF. I BACK OUT THE LOCK DOWN SCREWS. PULL 9 5/8" PACK -OFF WITH 15K LBS UP WEIGHT. INSTALL NEW 9 5/8" PACK -OFF. 1 -RUN IN LOCK DOWN SCREWS. ; I - PRESSURE TEST PACK -OFF. FOR - 250 PSI LOW FO 5 CHARTED MIN. - 5000 PSI FOR 30 CHARTED MIN. ! - GOOD TEST. SEE ATTACHED CHART. ,17:00 - 18:30 1.50 CASING P DECOMP PRESSURE TEST THE 9 5/8" CASING AND 7 I 5 /A" LINER - 500 PSI FOR 5 CHARTED MIN. 4000 PSI FOR 30 CHARTED MIN. - GOOD TEST. SEE ATTACHED CHART. I - LOST 40 PSI IN THE FIRST 15 AND 10 PSI THE SECOND 15 MIN. 5 BBLS OF 9.8 PPG BRINE TO PRESSURE I 1 ' UP. - 5 BBLS BLED BACK AFTER TEST. - INSTALL THE 8 3/4" WEAR BUSHING. **WTL NOTIFIED ** 18:30 20:00 1.50 FISH P , DECOMP PICK UP BHA #4, 63/4" CLEAN -OUT ASSY. - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. I - PICK UP THE FOLLOWING: ' 1 - 63/4" BIT. - BIT SUB. j - BUMPER SUB. - OIL JAR. j , 1 - (9) 4 3/4" SPIRAL DRILL COLLARS. , ! _ -'XO' BACK TO DP. i 20:00 - 00:00 4.00 FISH P I DECOMP I RUN IN THE HOLE WITH BHA #4. I - FROM 300' TO 9694' DPM. I - UP WEIGHT = 175K LBS, DOWN WEIGHT = 142K LBS. Printed 4/29/2011 10:52:37AM • O f t h America =, ALASKA -.BP Page 22' af27 eratcan Summary Report: Common Well Name: P2 -16 1 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 1 End Date: 4/15/2011 1X4-00T38 -E (3,050,000.00 ) Project: Point McIntyre I Site: Pt Mac 2 Rig Name /No.: NABORS 7ES I Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To 1 Hrs Task Code ' NPT NPT Depth Phase 1 Description of Operations i (hr) 4/12/2011 00:00 - 01:00 I 1.00 FISH P (ft) DECOMP DRILL OUT CEMENT STRINGERS IN 75/8" SCAB LINER. - FROM 9694' TO TOP OF PLUGS AT 9762' I DPM. - UP WEIGHT = 170K LBS, DOWN WEIGHT = I 1 145K LBS. - 80 RPM AND 6K TO 8K FT -LBS OF TORQUE. I- ROTATING WEIGHT = 155K LBS. - 5 BPM AND 600 PSI. - WEIGHT ON BIT = 10K LBS. 1 01:00 - 04:00 3.00 FISH P DECOMP I DRILL UP WIPER PLUGS AND CONTINUE TO I DRILL OUT 75/8" SHOE TRACT. DRILL OUT PLUGS AND LANDING COLLAR AT 9762'. - DRILL OUT CEMENT AND FLOAT COLLAR AT i 9796'. 1- DRILL CEMENT DOWN TO PORTED 'XO' AT 1 9845'. I , - TAG WITH 5K LBS. - UP WEIGHT = 170K LBS, DOWN WEIGHT = 145K LBS. 80 RPM AND 6K TO 10K FT -LBS OF TORQUE. - ROTATING WEIGHT = 155K LBS. 1- 12 BPM AND 1950 PSI. WEIGHT ON BIT = 10K - 15K LBS. ' 04:00 - 05:00 1.00 FISH 1 P DECOMP PUMP A 500 BBL HIGI+VIS SWEEP. 10 BPM AND 1850 PSI. 05:00 - 09:00 4.00 FISH P DECOMP PULL OUT OF THE HOLE WITH BHA #4, 6 3/4" CLEAN -OUT ASSY. - FROM 9845' TO 300' DPM. 09:00 - 10:00 1.00 FISH P DECOMP I LAY DOWN BHA #4. - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. - STAND BACK 43/4" DRILL COLLARS. ! ' 1 - LD THE REST OF THE BHA COMPONENTS. 10:00 - 11:30 1.50 FISH P I DECOMP PICK UP BHA #5, 43/8" MILL ASSY, AND RUN IN THE HOLE. PJSM WITH RIG CREW AND BAKER FISHING !REPRESENTATIVE. - PICK UP BHA #5 AS FOLLOWS: ' - 4 3/8" MILL. - BIT SUB. - (5) 2 7/8" HT -PAC DRILL PIPE. ! XO' 1 - FLOAT SUB W/ FLOAT. 1 ' - BUMPER SUB - OIL JAR I - PUMP -OUT SUB I - (9) 4 3/4" DRILL COLLAR -'XO' OVERALL LENGTH = 464'. MAX OD= 5.00 ". MIN ID= 1 ". 11:30 - 16:00 4.50 FISH P DECOMP RUN IN THE HOLE WITH BHA #5. , - FROM 464' TO 9764' DPM. - UP WEIGHT = 178K LBS, DOWN WEIGHT = 140K LBS. 16:00 - 17:00 1.00 FISH P 1 DECOMP CUT AND SLIP 122' OF DRILLING LINE. 17:00 - 17:30 0.50 FISH P DECOMP 1 SERVICE AND INSPECT TOP DRIVE AND DRAWWORKS. - CALIBRATE BLOCK HEIGHT. Printed 4/29/2011 10:52:37AM • orttt America LASKA BP` !age 23 of 27 Operation Summar r'If Report Common Well Name: P2 -16 1 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES I Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) 17:30 - 18:00 0.50 FISH I P DECOMP ESTABLISH MILLING PARAMETERS PRIOR TO ; !CLEANING OUT THE 5 1/2" SHOE TRACT. I I UP WEIGHT = 178K LBS, DOWN WEIGHT = I 140K LBS. I- 60 RPM AND 5.5K FT -LBS TORQUE. - ROTATING WEIGHT = 156K LBS. 1- 7 BPM AND 1640 PSI. -WASH DOWN AND TAG CEMENT AT 9841'. - 3K LBS WEIGHT ON BIT. 18:00 - 23:30 5.50 FISH P DECOMP I CLEAN -OUT 5 1/2" SHOE TRACT WITH BHA #5. - FROM 9841' TO 9917' DPM. 1 , UP WEIGHT = 178K LBS, DOWN WEIGHT = I i 140K LBS. - 60 RPM AND 6.8K FT -LBS TORQUE. - ROTATING WEIGHT = 158K LBS. 1- 7 BPM AND 1640 PSL - WEIGHT ON BIT = 3K - 5K LBS. 23:30 00:00 0.50 FISH P DECOMP DISPLACE WELLBORE TO CLEAN 120 DEG F, 19.8 PPG BRINE. - RECIPROCATING FROM 9917' TO 9858' DPM. - ROTATING AT 60 RPM AND 5.5K FT -LBS FREE TORQUE. ' - UP WEIGHT - 178K LBS, DOWN WEIGHT = I :140K LBS. I- ROTATING WEIGHT = 158K LBS. ■ — — 8 BPM AND 1870 PSI. 4/13/2011 T00:00 00:30 0.50 FISH P DECOMP CONTINUE TO DISPLACE WELLBORE TO CLEAN 120 DEG F, 9.8 PPG BRINE. - RECIPROCATING FROM 9917' TO 9858' DPM. / - ROTATING AT 60 RPM AND 5.5K FT -LBS FREE TORQUE. UP WEIGHT - 178K LBS, DOWN WEIGHT = 140K LBS. ROTATING WEIGHT = 158K LBS. _ - 8 BPM AND 1870 PSI. . 00:30 - 04:30 4.00 FISH P DECOMP CLEAN PITS AND FILL WITH CLEAN 120 DEG F, 9.8 PPG BRINE. - CONTINUE TO CIRCULATE CLEAN BRINE. - 3 BPM AND PSI. 08:00 3.50 FISH I 04:30 N WAIT - TI - . I 9,917.00 I DECOMP I WAITING FOR ADDITIONAL 9.8 PPG BRINE BEFORE DRILLING OUT COMPOSITE PLUG. - THREE CLEAN TRUCKS ROUND - TRIPPING FOR FLUID. - BACKLOG AND LINE AT BOTH HOT WATER PLANT AND MUD PLANT. 08:00 - 10:30 2.50 FISH N WAIT 9,917.00 ! DECOMP WAITING FOR CONTROL OF WORK AUDIT. - EXPECTED PETER FAULKNER TO AUDIT THE RIG. Printed 4/29/2011 10:52:37AM oral Amertca ALASKA BP • P age 24 027 , • Operation. Summary Report ; q Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 I End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES I Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT I NPT Depth Phase I Description of Operations (hr) 1_ I DECOMP 10:30 - 12:00 1.50 FISH P I r MILL OUT COMPOSITE BRIDGE PLUG. I- ESTABLISH MILLING PARAMETERS: - UP WEIGHT = 180K LBS, DOWN WEIGHT 140K LBS. - ROTATING WEIGHT = 156K LBS. I - 60 RPM AND 6K FT -LBS TORQUE. - 7 BPM AND 1385 PSI. - DRILL PLUG FROM 9921' TO 9925'. - 3K TO 5K LBS WEIGHT ON MILL. - RETURNS DROPPED OFF 10 %. - WEIGHT DROPPED OFF. i- CHASED PLUG DOWN TO 9947'. - BULLHEAD 65 BBLS OF HEATED 9.8 PPG BRINE. - CLOSED ANNULAR PREVENTER. - .BULLHEADED DOWN IA AND DRILL PIPE. I 10 BPM AND 1035 PSI. j- MONITOR WELL. j - STATIC LOSS RATE = 46 BPH. - CHASE PLUG REMAINS OUT TAILPIPE AT 9984'. 12:00 - 23:00 11.00 FISH I P DECOMP I PULL OUT OF THE HOLE AND LAY DOWN `DRILL PIPE. - FROM 9764' TO 464' DPM. 'i - STATIC LOSS RATE AT THE TOP OF THE LINER = 14 BPH. 15 BPH. STATIC LOSS RATE AT THE BHA S 23:00 00:00 1.00 P DECOMP T = FISH T - - = - ---- - PULL OUT OF THE HOLE AND LAY DOWN BHA #5. — - FROM 464' TO 173'. DECOMP CONTINUE LAY DOWN BHA #5. 01:30 - 04:00 2.50 RUNCOM P TO _— - , T 4/14/2011 00:00 01:30 1.50 FISH P RUNCMP 'RIG UP TO RUN 4 V2" x 5 V2 ", TCII COMPLETION. - MAKE UP HANGER AND LANDING JOINT ' AND PERFORM A DUMMY RUN. I- RIG UP 4 1/2" TUBING RUNNING I EQUIPMENT. 'I - RIG UP SINGLE JOINT COMPENSATOR. I - RIG UP TORQUE TURN EQUIPMENT. - ORGANIZE AND INSPECT COMPLETION JEWELRY IN THE PIPE SHED. 04:00 07:00 3.00 RUNCOM P 1 RUNCMP RUN 4 1/2" x 5 1/2 ", L -80, TCII COMPLETION. PJSM WITH RIG CREW AND HALLIBURTON COMPLETIONS HAND. I PICKUP MR � RIG UP 51/2 HANDLING PLETION JEWEL EQUIPMENT. Y. - RUN IN THE HOLE WITH THE 5 1/2 ", 17 LB/FT, TCII TUBING. - LIST OPTIMUM MAKE UP TORQUE = 4350 FT -LB. - TUBING IS NOT MAKING UP PROPERLY. - STOPPED THE JOB AND CONSULTED ENGINEERS. Printed 4/29/2011 10:52:37AM c�i't{t; ACYt @ftCa .- ALA3KA' ESP ` Page 25 of 27 perafi ©n Summary Repo r Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 End Date: 4/15/2011 1X4- OOT38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 H , Rig Name /No.: NABORS 7ES I Spud Date/Time: Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: Active Datum: 26:16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs Task Code ! NPT NPT Depth l Phase Description of Operations (hr) I 07:00 - 11:00 4.00 RUNCOM ;` N '� WAIT 353.00 RUNCMP DISCUSSIONS WITH RWO ENGINEER, CASING HAND AND CHRIS SHUMATE WITH UNIQUE MACHINE. - OPTIMUM TORQUE FOR THE 5 1/2" WAS INCREASED TO 5500 FT -LBS. 1- SEE SCANNED AND ATTACHED LETTER ' 1 AND SPECIFICATIONS. - RWO ENGINEER GENERATED AN UPDATED _ OPS NOTE TO REFLECT THESE CHANGES. 11:00 - 12:00 1.00 1 RUNCOM P RUNCMP CONTINUE TO RUN IN THE HOLE WITH 5 1/2 ", ' L -80 TCII COMPLETION. - LAY DOWN 5 1/2" TCII CONNECTIONS TO . j THE 4 1/2 ".TCI I AT 197'. - CLEAN AND INSPECT ALL THREADS. ' - INCREASE OPTIMUM TORQUE VALUE TO 5500 FT -LBS. CONTINUE TO RUN IN THE HOLE WITH THE 1 ! 5 1/2" TCII TUBING. 1 -' FROM 19T TO 605'. - UP WEIGHT = 45K LBS, DOWN WEIGHT = _ , 45K LBS. 12:00 - 00:00 12.00 RUNCOM - P I RUNCMP CONTINUE TO RUN IN THE HOLE WITH THE 5 1/2" TCII TUBING. / - FROM 605' TO 8269'. J - UP WEIGHT = 148K LBS, DOWN WEIGHT = 135K LBS. - - RUNCMP OPTIMUM TORQUE = 5500 FT -LBS. 4/15/2011 00:00 RUNCOM 01:30 1.50 i CONTINUE TO RUN IN THE HOLE WITH THE 5 1/2" TCII TUBING. - FROM 8269' TO 9808'. - UP WEIGHT = 168K LBS, DOWN WEIGHT = ' ' 148K LBS. - OPTIMUM TORQUE = 5500 FT -LBS. 01:30 - 02:30 1.00 RUNCOM P RUNCMP MAKE UP AND LAND TUBING HANGER. - PICK UP FMC 13 5/8" X 7" CROSSED OVER TO 5 1/2" TCII TUBING HANGER. - RUN IN THE HOLE AND LAND THE TUBING HANGER. - WIRE LINE ENTRY GUIDE AT 9825'. - UP WEIGHT = 168K LBS, DOWN WEIGHT ' = 148K LBS. - RUN IN THE LOCK DOWN SCREWS. , BACK OUT THE LANDING JOINT AND LAY I ' DOWN. 02:30 - 03:30 1.00 RUNCOM P RUNCMP RIG DOWN TUBING HANDLING EQUIPMENT AND RIG UP TO BULLHEAD CORROSION INHIBITED BRINE AND DIESEL FREEZE PROTECT. - PRESSURE TEST LINES TO LITTLE RED. - 250 PSI LOW 4000 PSI HIGH. 03:30 05:00 1.50 RUNCOM P RUNCMP I BULLHEAD 270 BBLS OF 120 DEG F CORROSION INHIBITED 9.8 PPG BRINE I DOWN THE IA. RIG UP TO SPIKE FLUID DIRECTLY OFF OF VAC TRUCK. I - 4 BPM AND 520 PSI. 05:00 06:00 1 1.00 RUNCOM P I RUNCMP ' RIG UP AND BULLHEAD DIESEL FREEZE PROTECT. - PUMP 10 BBLS OF 80 DEG F DIESEL DOWN ' THE IA. - 2 BPM AND 400 PSI Printed 4/29/2011 10:52:37AM '.: :, ttt� Amet�Ca � AL�I$Kfi� BP` ' Page 26'4 27 , Operation Siummaryc,Report . Common Well Name: P2 -16 �� AFE No Event Type: WORKOVER (WO) Start Date: 3/25/2011 , End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 I_ ) - Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES i Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. L UWI: Active Datum: 26 : 16 9/2/1993 00:00 @51.50ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT 1 NPT Depth Phase Description of Operations 07:00 1.00 RUNCOM P (ft) RUNCMP (hr) (ft) 06:00 - RIG UP AND BULLHEAD 225 BBLS OF 120 DEG F 9.8 PPG BRINE DOWN THE TUBING. - 6 BPM AND 1200 PSI. 07:00 - 07:30 I 0.50 RUNCOM P 1 RUNCMP BULLHEAD 5 BBLS DIESEL FREEZE PROTECT 1 i DOWN THE TUBING. - INSTALL LANDING JOINT WITH HEAD PIN. - 1.5 BPM AND 25 PSI. 07:30 - 10:30 3.00 RUNCOM P �'� r RUNCMP SET HALLIBURTON 'TNT PACKER AND MIT ' ' I THE TUBING AND IA. - DROP.1 7/8" BALL & ROD. LAY DOWN THE LANDING JOINT AND CLOSE I i THE BLIND SHEAR RAMS. I PRESSURE UP ON THE TUBING TO 250 PSI 1 1 ', AND HOLD FOR 5 MIN. - CONTINUE TO PRESSURE UP AND SET 'TNT' ' PACKER. PACKER SET AT 2400 PSI. I- CONTINUE TO PRESSURE UP AND MIT TUBING. 4000 PSI FOR 30 CHARTED MINUTES. ' - GOOD TEST. - LOST 32 PSI IN THE FIRST 15 MIN. - LOST 0 PSI OVER THE SECOND 15 MIN. BLED THE TUBING BACK TO 1500 PSI. - PRESSURE UP AND MIT THE IA. I 1 1 1 i - 250 PSI FOR 5 CHARTED MIN. - GOOD TEST. - ATTEMPT TO TEST TO 4000 PSI FOR 30 I CHARTED MIN. - SENSATOR BLADDER POPPED AT M (( 3200 PSI. - BLED OFF IA PRESSURE TO 0 PSI. I - REPLACED SENSATOR BLADDER. - PRESSURE UP IA AND TEST TO 4000 PSI , FOR 30 CHARTED MIN. _ 1 - GOOD TEST. - LOST 29 PSI IN THE FIRST 15 MIN. - LOST 2 PSI OVER THE SECOND 15 MIN. '- RIG DOWN AND BLOW DOWN ALL TEST EQUIPMENT. - DISCUSSED MIT TEST RESULTS WITH ADW ' ' WELLS MANAGER, STEVE ROSSBERG. - SEE SCANNED AND ATTACHED TEST CHART. 10:30 - 13:00 2.50 WHSUR P I RUNCMP INSTALL 63/8" "J" TYPE TWC. - RIG UP DUTCH RISER AND DSM HYDRAULIC LUBRICATOR. - TEST LUBRICATOR TO 250 PSI LOW 4000 PSI HIGH FOR 5 CHARTED MIN. - INSTALL TWC IN TUBING HANGER PROFILE. RIG DOWN THE LUBRICATOR AND DUTCH RISER. 13:00 - 14:00 ' 1.00 WHSUR P RUNCMP PRESSURE TEST TWC. - TEST TWC FROM ABOVE TO 250 PSI LOW 4000 PSI HIGH FOR 10 CHARTED MIN. - GOOD TEST. - SEE SCANNED AND ATTACHED TEST CHART. Printed 4/29/2011 10:52:37AM rth America B - Page 27 00 27 , Operation: Summary Repo Common Well Name: P2 -16 AFE No Event Type: WORKOVER (WO) I Start Date: 3/25/2011 End Date: 4/15/2011 X4- 00T38 -E (3,050,000.00 ) Project: Point McIntyre Site: Pt Mac 2 Rig Name /No.: NABORS 7ES Spud Date/Time: I Rig Release: 4/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 26 : 16 9/2/1993 00:00 ©51.50ft (above Mean Sea Level) " Date From - To Hrs i Task 1 Code NPT I NPT Depth I Phase I Description of Operations (hr) — ft 14:00 - 16:00 2.00 BOPSUR I P I RUNCMP I NIPPLE DOWN AND STAND BACK BOP I STACK. I - BLOW DOWN ALL LINES AND SUCK FLUID I OUT OF STACK. I- NIPPLE DOWN BOP STACK AND SECURE ION STUMP. 16:00 - 18:00 2.00 WHSUR P RUNCMP I NIPPLE UP ADAPTER FLANGE AND TREE. 18:00 19:30 1.50 WHSUR P 1 'RUNCMP TEST ADAPTER FLANGE AND VOID. i ,- 250 PSI LOW FOR 5 MINUTES. I- 5000 PSI HIGH FOR 30 MINUTES. - -- 19:30 - 22:00 ! 2.50 j WHSUR P 1 RUNCMP. GOOD TEST. PRESSURE TEST TREE TO 250 PSI LOW AND 5000 PSI HIGH. - RIG UP TEST EQUIPMENT. - TEST TREE TO 250 PSI LOW FOR 5 ; CHARTED MIN. - GOOD TEST.. I j I ' 1 -TEST TREE TO 5000 PSI FOR 30 CHARTED 'I ' ', MIN. 1 ' I HAD TO WORK VALVES AND PACK THE i GREASE SEVERAL TIMES. - DID OBTAIN A GOOD TEST. - WSL AND P2 PAD OPERATOR DISCUSSED CLOSE PROXIMITY WELL SHUT -IN PROCEDURE AND LOCK OUT / TAG OUT PROCEDURE TO BE USED FOR ADJACENT I WELLS: 13, 14, 15, 17, AND 18. MARK PATTESON, STEVE ROSSBERG, DOUG CISMOSKI, AND JIM WILLINGHAM ONSITE TO TALK TO RIG PERSONNEL L. LOOK AT RIG AND L 22:00 - 23:00 1.00 WHSUR I P 1 RUNCMP SECURE TREE AND CELLAR FOR RIG MOVE. j RIG DOWN ALL TEST EQUIPMENT. REMOVE SECONDARY ANNULUS VALVES. - INS TALL FLANGES AND GAUGES. 23:00 - 00:00 1.00 WHSUR P RUNCMP j RIG DOWN FLOOR EQUIPMENT AND PREPARE RIG FOR TRANSPORT. * ** RIG RELEASED FROM P2 -161 AT 00:00. * ** Printed 4/29/2011 10:52:36AM r • TREE = 7- 1/16" CIW // SAFETY NO WELL REQUIRES AN SSSV *** WELLHEAD = mm FMC P2 -1 CHROME NI LES" *" ACTUATOR = BAKER 'C KB. ELEV = -_- - 51.5' BE ELEV = II 111 -K-op= 4341' I 2245' 1 HES X NIP (CR), ID = 4.562" I Max Angle = 44° @ 10025' Datum MD= 10054' Datum N_D =- 8800' SS 13 -3/8" CSG, 68 #, NT -80 BTC, ID = 12.415" H 3692' 19-5/8" X 7" BKR C-2 ZXP LTP, ID = 6.95 I-I 3997' I9 -5/8" X 7 -5/8" BKR FLEXLOCK III HGR, ID = 6.92 H 4017' V • ■ ♦ �� 9612' 1-15-1/2" HES X NIP (CR), ID= 4.562" I Minimum ID = 3.725" @ 9793' $ 4-1/2" HES XN NIPPLE �� • 962$' J�51 /2 ° xa- 1 /2 °xo,ID= 3,958" :� A 9686' --I 7 -5/8" X 4 -1 /2" HES TNT PKR, ID = 3.855" I = 15 -1/2" TBG, 17 #, L -80 TCII, .0232 bpf, ID = 4.892" IH 9628' ♦ 0 . �� 9721' - I4 -1(2" HES X NIP (CR), ID = 3.813" I v N 04, • I •: 9793' -f 4 -1/2" HES XN NIP (CR), ID= 3.725" I •4 414 4-1/2" TBG, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" H 9826' 9826' 1-14-1/2" WLEG, ID = 3.958" I 7 -5/8" SCAB LNR, 29.7 #, L -80 HYD 521, 9845' 4, : 9845' H X 5 -1/2" PORTED XO, ID = 4.892" .0459 bpf, ID = 6.875" . ♦ � 4. .0459 9871' - 19 -5/8" X 5 -1/2" UNIQUE OVERSHOT I ,.!i - ♦ 5 -1/2" TUBING STUB (04/08/11) I 9860' • ♦• ♦• ►� ♦�� ♦ ♦ ♦ ♦� ►,♦.♦. 9888' H 5 -1/2" PARKER SWS NIP (9 -CR), ID = 4.562" I ■ ♦ ♦ ♦ i ♦ ♦ ♦ ♦ 1 • ∎ ► ♦ A ♦ & 9905' I 9 -5/8" X 5" TNV HBBP PKR ■ 1 . w / ANCHOR LATCH ASSY, ID = 4.870" 9911' 1-17" MILLOUT EXTENSION, ID = 6.210" I 9916' H7" X 4 -1/2" XO, ID = 4.830" I 9942' IH 5 -1/2" PARKER SWS NIP (9 -CR), ID = 4.562" I 9960' IH 5-1/2" OTIS XN NIP (9 -CR), ID = 4.455" I 5 -1/2" TBG, 17 #, L -80 NSCC, H 9984' 9984' I -15 -1/2" WLEG, ID = 4.892 I .0232 bpf, ID = 4.892" I 9984' IH ELMD TT LOGGED 01/26/94 I PERFORATION SUMMARY REF LOG: ATLAS DIL /GR ON 09/13/93 I 10118' 1-19-5/8" MARKER JOINTS (2) I ANGLE AT TOP PERF: 43' @ 10125' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10125 - 10165 C 04/28/08 I 3 -3/8" 6 10126 - 10410 C 01/27/94 2 -7/8" 6 10300 - 10375 C 04/28/08 I PBTD H 10436' •rnrv•Vm•Ipi 9 -5/8" CSG, 47 #, NT -80S NSCC, ID = 8.681" IH 10518' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS POINT MCINTYRE UNIT 09/16/93 POOL 7 ORIGINAL COMPLETION WELL: P2 -16 04/15/11 N7ES RWO (SCAB LNR) , PERMIT No: n931230 04/30/11 PJC DRLG DRAFT CORRECTION API No: 50- 029 - 22397 -00 05/02/11 WH/ PJC FINAL DRLG CORRECTIONS SEC 14, T12N, R14E, 1184' FWL & 27' FNL I BP Exploration (Alaska) • • [E ELAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM111S ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 David Reem Engineering Team Leader 11 a.- BP Exploration (Alaska), Inc. t ?j ✓ V P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P2 -16 Sundry Number: 311 -066 Dear Mr. Reem: StAINED MAR 1 1 N)) 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. 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 reconsideration. A request for reconsideration 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 1 day of March, 2011. Encl. • STATE OF ALASKA RECEIVED U >i A� OIL AND GAS CONSERVATION COMMON " � � APP FOR SUNDRY APP 3-,-// 20 AAC 25.280 A ^_ - 1. Type of Request: A kit Oil St Be a Cuu . C ,uulil ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - ® Repair Well ❑ Change Approved Prog IC11Crage ❑ Suspend ❑ Plug Perforations ❑ Perforate ■4 Pull Tubing ❑ Time Extension ✓ ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate - ® Alter Casing - :1 Other Cement 7 -5/8" scab liner 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 193 -123 - 3. Address: _l Service ❑ Stratigraphic 6. API Number - P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22397 -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 P2 -16 Spacing Exception Required? ❑ Yes Z No _ 9. Property Designation: 10. Field / Pool(s): ADL 034624 & 365548 Prudhoe Bay Field / Point McIntyre Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10535' ' 9202'' 10436' 9130' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 3655' 13 -3/8" 37' - 3692' 37 - 3691' 5020 2270 Intermediate Production 10481' 9 -5/8" 37' - 10518' 37' - 9190' 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10125' - 10410' 8903' - 9111' 5 - 1/2 ", 17# L - 80 9984' Packers and SSSV Type: 5 Otis TRSV SSSV Packers and SSSV 2228' / 2227' 9 x 5" TIW HBBP Packer MD (ft) and TVD (ft): 9905' / 8744' 12. Attachments: 13. Well Class after proposed work: 0 Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development - 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 15, 2011 ❑ Oil - 0 WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby cert• . hat the foregoing is true and correct to the best of my knowledge. Contact Wilmer Hoffman, 564 -4592 Printed Na il David Re Title Engineering Team Leader Prepared By Name/Number Signature i Phone 564 -5743 Date 2 — /-- 20(/ Elizabeth Barker 564 -4628 Commission Use Only Conditions of approval: Notify Commission at a representative may witness ( ,ill /� /n , Sundry Number: (/l.[/ '✓ ❑ Plug Integrity OP Test Mechanical Integrity Test ❑ Location Clearance 4 Oa, p 3Z, re b9 s .—_ / Other: 1F Z SOD es . . Ann ,A, LAW "-re--; f l �' '►) W-i- ca M t r 4 .(4tr StF4--blt ;njec�C. oit. , Subsequent Form Required: / 6 - `io ,/ THERO 3 /d /J / Approved By: \ COMMISSIONER THE COMMISSION ION Date Form 10-403 - evi = � '+ Submit In plicate ORIGINAL 46 3_ • b P GP P2 -16i Expense Rig Workover Scope of Work: Pull existing 5 - %" L -80 completion, cement a 7 -5/8" scab liner, replace 9 -5/8" packoff, run 5 -h/2 L -80 e. completion with 4 -1/2" tailpipe. P PP MASP: 3,135 psi Well Type: WAG Injector . Estimated Start Date: March 15 2011 Production Engineer: Bob Gerik Intervention Engineer: Wilmer Hoffman Pre -Riq Work Request: E 1 SBHPS. Run USIT to determine cement top in IA for cutting the tubing. DONE: Field pick TOC at 9,888'. F 2 MIT -OA to 2,000 psi. LLR if fails. Load tubing and freeze protect. W 3 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. S 4 Drift tubing for 5 -1/2" composite plug and 5 -1/2" jet cutter. Set 5 -1/2" composite plug at 9,970' MD. MIT -T to 3,000 psi for 10 charted minutes. E 5 Jet cut the 5 -1/2" tubing at 9,874' which is in the upper half of the 20' pup joint below GLM #1. (based on Schlumberger USIT log dated 11/28/2010) F 6 Circulate the well with 9.8 ppg brine and place a diesel freeze protect cap on top to protect surface equipment. CMIT TxIA to 500 psi. ✓ 7 Set a BPV in the tubing hanger. O 8 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine through the cut. • ND tree. NU BOPE consisting of annular, 3 -1/2" x 6" VBRs, shear rams, flow cross and 7 -5/8" fixed rams. Pressure test BOPE to 4,000 psi high /250psi low. Test the annular to 3,500 psi. 2. Pull and LD 5 -' /2' tubing to the cut. 3. Dress off 5 -1/2" tubing stump. 4. RIH with 9 -5/8" RTTS to 6,950' and pressure test the casing above leak at 6,975' to surface to 4,000 psi for 30 charted minutes. If fails, move up hole looking for leak to determine top of scab liner depth. 5. Run and cement a 7 -5/8" Hydril 521 L -80 scab liner from 5 -1/2" tubing stump at 9,874' up to —4,000' with —100 bbls of 15.8 ppg cement. 6. Change out 9 -5/8" mandrel packoff. 7. PU 6 -3/4" bit to drill out 7 -5/8" shoe tract. 8. PU 4 -3/4" bit to cleanout 5 -1/2" tailpipe and drill out composite plug. Push composite plug out of tailpipe. 9. Run 5 -'/2' L -80 completion with a 4 -1/2" tailpipe (7 -5/8" x 4 -1/2" packer). 5 -1/2" X Nipple will be run at 2,200' MD and an MCX valve will be run post -rig to comply with SSSV regulations. 0 t • • 10. Displace the IA to packer fluid and freeze protect to 2,000' MD. Pump KWF and freeze protect to 2,000' MD down the tubing. 11. Set the Packer, test tubing and IA to 4,000 psi. 12. Set BPV. ND BOPE. NU and test tree. RDMO. i + + TREE'= CNN • I WELLHEAD = FMC SA. NOTES: P2 -16 ACTUATOR = BAKER C KB. ELEV = 51.5' BF. ELEV = KOP= 4341' Max Angle = 44" @ 10025' Datum MD 10054' 2228' I- 15 -1/2" OTIS TRSV SSSV, ID = 4.562" I Datum TV D = 8800' SS O 13 -3/8" CSG, 684, NT -80, ID = 12.415" H 3705' I , L GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE '1 1 4001 4001 5 OTIS -LBD DMY T2 0 4 2 9848 8702 43 OTIS -LBD DMY T2 0 06/01/06 4 117 .) ,,,,/tn"../s 9806' - 9882' I- CMT PKR SQZ MILLED (02/24/06), ID = 4.83" t (PER 07/12/10 CALIPER) Minimum ID = 4.455" @ 9960' A w 9888' I— I5 -1/2" PARKER SWS NIP, ID= 4.562" I 5 -1/2" OTIS XN NIPPLE Cis ---. 9905' I- 9 -5/8" X 5" TIW HBBP PKR 1�"' _ w / ANCHOR LATCH ASSY, ID = 4.870" 1 , 9911' H 5' MILLOUT EXTENSION, ID = 6.210" 9916' H7" X 4-1/2" XO, ID = 4.830" I 9942' H5-1/2" PARKER SWS NIP, ID = 4.562" I ' 9960' 1-15-1/2" OTIS XN NIP, ID = 4.455" I 5- 1 /2 " TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I--I 9984' I ' 9984' I-- 15 -1/2" WLEG, ID = 4.892 I 9984' I-I ELMD TT LOGGED 01/26/94 I PERFORATION SUMMARY REF LOG: ATLAS DIL /GR ON 09/13/93 ANGLE AT TOP PERF: 43° @ 10125' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10125 - 10165 0 04/28/08 3 -3/8" 6 10126 - 10410 0 01/27/94 2 -7/8" 6 10300 - 10375 0 04/28/013 PBTD H 10436' j ►''''♦'''''''''••• 9 -5/8" CSG, 47 #, NT -80, ID = 8.681" H 10535' DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 09/16/93 ORIGINAL COMPLETION 04/29/08 TEL /SV ADPERFS (04/28/08) WELL: P2 -16 10/17/05 TWS /PJC HES FASDRILL PLUG 05/06/08 PJC DRAWING CORRECTIONS PERMIT No: 93 -123 11/06/05 JLM/TLH PLUG PULLED (10/16/05) 07/29/10 SWC/ PJC CMT SQZ CORRECTION API No: 50- 029 - 22397 -00 02/24/06 MR/PJC DRILL FASDRILL @ 9860' SEC 14, T12N, R14E, 1184' FWL & 27' FNL 03/23/06 RLM/TLH CMT PKR SQZ /MILLED (02/24/06) 06/01/06 KSB /PAG C/O GLV II BP Exploration (Alaska) TREE = " CM1 WELLHEAO = FMC • P2-1 6 i SAF0 NOTES: Plan to install MCX in X nipple at ACTUATOR= BAKER -2, post -rig KB. ELEV = 51.5' proposed RWO BF. ELEV = KOP = 4341' Max Angle = 44° @ 10025' Datum MD= 10054' I 2200' I— 5 - 1/2" X Nipple = 4 562" Datum TVD= 8800'SS MC X. 'b be. T ^¢, 13 - 3/8" CSG, 68 #, NT - 80, ID = 12.415" I— 3705' I i 9 -5/8" x 7 -5/8" LTP and Hanger @ - 4,000' / :7' 0A • 5 -1/2 ", 17 #, L -80 tubing Minimum ID = 4.455" @ 9960' • 5 -1/2" OTIS XN NIPPLE 4 5 -1/2" X Nipple, ID = 4.562" 7 -5/8" x 4 -1/2" production packer 7 -5/8 ",29.7 #, L -80 cemented scab liner 4 -1/2" X Nipple, ID = 3.813" I I 4 -1/2" XN Nipple, ID = 3.725" 4 -1/2" WLEG 5 -1/2" x 7 -5/8" ported XO 4i` # I 5 -1/2" x 9 -5/8" Unique Overshot ir 5-1/2" tubing cut at 9,874' - - b 9888' 1-15-1/2" PARKER SWS NIP, ID= 4.562" 9905' I 9 -5/8" X 5" 11W HBBP PKR X =, w / ANCHOR LATCH ASSY, ID = 4.870" N 11 9911' — 15' MILLOUT EXTENSION, ID = 6.210" 9916' I X 4 -112" XO, U = 4.830" I 9942' H 5-1/2" PARKER SWS NIP, 10 = 4.562" II 9960' H 5-1/2" OTIS XN NP, ID = 4.455" I 5-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 9984' 9984' — 15 - 1/2" WLEG, ID = 4.892 I 9984' H ELMD TT LOGGED 01/26/94 PERFORATION SUMMARY REF LOG: ATLAS DIL/GR ON 09/13/93 ANGLE AT TOP FERF: 43° @ 10125' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10125 - 10165 0 04/28/08 3 -3/8" 6 10126 - 10410 0 01/27/94 2 -7/8" 6 10300 - 10375 0 04/28/08 PBTD — 10436' ♦tmtvttt 9 -5/8" CSG, 47 #, NT -80, ID = 8.681" H 10535' DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 09/16/93 ORIGINAL COMPLETION 04/29/08 TEL /SV ADPERFS (04/28/08) WELL: P2 -16 10/17/05 TWS /PJC HES FASDRILL PLUG 05/06/08 PJC DRAWING CORRECTIONS PERMIT No: 93 -123 11/06/05 JLM/TLH PLUG PULLED (10/16/05) 07/29 /10 SWC/ PJC CMT SQZ CORRECTION API No: 50- 029 - 22397 -00 02/24/06 MR/PJC DRILL FASDRILL @ 9860' 1/14/11 WJH Proposea RWO SEC 14, T12N, R14E, 1184' FWL & 27' FNL 03/23/06 RLMITLH CMT PKR SQZ /MILLED (02/24/06) 06/01/06 KSB /PAG C/O GLV III BP Exploration (Alaska) 12/30/10 NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838A Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 /.r 6 Anchorage, AK 99501 J � Job # Log Description Date BL Color CD E-05 BL65 -00011 MEM DDL 12/18/10 1 1 � AVM-110056 1 • PIMIMIP. ,a _/ • 11/27/10 1 a 4,'. 1 BCZ 2-00033 IgcL.l.I.. {e tl19� . ef' 12/08/10 INIIIIIMPula.tz'Y:AII•111•111=1111111•1111111 BG4H -00022 INJECTION PROFILE 4111/E%rMIR AY1M -00058 •1.97auy1 �s • — �� ! BUN-00017 i�a sFra1L ��t � -- BCZ 2 - 00030 it Vk4 0r'_ipy rim-- E BCRJ-000566 11=1:71,MCIEWSWEllcriairenealliMMEMMEMMIlliterAiMIEMMINIMMIEMINI IMEMICIMMEMI BBSK -00043 IId81X•31iUti .ltll9X 4tanirznY 04Tj -- -co is-_ 15-26B B1388-00080 MEM PROD PROFILE _ 6 • — irms■ 12/12/10 1 AWili all 2- 28B/0.19 BCRJ-00055 PROD PROFILE e — a •T,_ ®�! ' -- • 07-23B AY1M-00056 SCMT _ k" 02-21A BBSK-00042 SCMT SCMT d!'tL — c'1� 10 a 6( L'.' r � � __ : ��r SCMT ? - S �: i r P2-16 B5JN-00077 USIT I. 7 ' . / / ' • • 1 1 05-27B BAUJ-00049 MCNL ' Q — i t • _ OS — 16-0613 BBSK-00037 RST .; • r '11,6 1 093 - 000 RST • 09/20/10 :.:: 2 C H E DIT PDC- I GR USIT rS ' �k W-219 BGZ7-00012 C H EC - -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP 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 • Loi 4ED 14 12/30/10 Schkoberger NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 995034838/1 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 1../- 6 Anchorage, AK 99501 Job 0 Log Description Date BL Color CD E -05 BL65 -00011 MEM DDL _ 12/18/10 1 1 - 3B AY1M -00056 PROD PROFILE 1. •,_ —/ 11/27/10 1 11 -12 BCZ2-00033 PROD PROFILE xiDg .... r . � 1" -Y� 1 01 -25 BG4H -00022 INJECTION PROFILE + ;r� . _ ; !►man 1 04 -24 AY1M -00058 PROD PROFILE 1 P2 -16 MN- 0 Ii _ V yj - 1 A-41 BCZ2 -00030 MMld FiGLZp 1 04 -08 BCRJ- 000566 . - - • ESICKC4:71re 12/06/10 1 • VI 1 01 -24A BBSK -00043 16t lire v i raMii"1T 1 04-10 AV1H -00051 ., - - . • / . _ 12/07/10 1 r S 1 L1 15-26B BD88.00080 MEM PROD PROFILE _ • — Z 12/12/10 1 M ♦ , 1 2- 28B/0.19 BCRJ -00055 PROD PROFILE _ & — •. r • 07 -236 AY1M -00056 SCMT _ •.. T +�1 I 11/23/10 6 ( , 1 1 02 -21A BBSK -00042 SCMT a(r — l7 �'" 11/23/10 • 1 1 02.22B BL65 -00006 SCMT I O - Y 12/11/10 „ • 1 1 18 -126 BBUO -00029 SCMT ('S 08 /30 /10 ♦ 1 1 P2 -16 B5JN -00077 USIT t I - I 11/28/10 1 1 05 -278 BAUJ -00049 MCNL • , — 09/18/10 1 4 ♦ y 1 16-06B BBSK-00037 - • ✓ �!TT • 11/1 1 E: •st. 1 G -098 BGZ7-00005 RST 09/20/10 1 l 1 E -34L1 B088-00050 MCNL � - I � 09/28/10 1 1 W -219 BGZ7-00012 CH EDIT PD -GR USIT — a 11/22/10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP 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 �, j , 2/ ` r( ` e [� . "I 1Y1t�,E � t • Alaska Deta 8 ConsuMing Services 2625 Oamba9 Shoat. gaps 400 Anelrorega, AK 99503-283a A7TN: Bafh Well lg~ _ ~ ~3 ~~.-c~ Job 4 Log Description 07/27/10 N0.5587 Company: State o/ Alaska Alaska Oi18 bas Cons Comm AKn: Christine MehMten 333 West 7th Ave, Suite 10D Anchorage, AK 99501 Date BL Color CD P2-18 F03A B85M-00027. AYKP 00096 LDL - d 07/20!10 1 1 V-225 - SBKA•00099 SCMT ~ U 07/22/10 / 1 5.100 2-58/S-09 1-15IP-25 W-19A 01-228 5-20 04-20 8.18 05-32A H-2S P2-34 SC22-00014 BCZ2-00010 AYKP-00094 BCRD-00038 AZ2F-00042 AY1M-00042 SCRJ-00020 AYKP-00082 SBKS-00040 BCRD-00017 AVYO.00063 StT l1StT w r LDL LDL - USIT ~ MCNL -- RST RST RST RST ~ RST .~ RST 07/01/10 07/14/10 07//7H0 07/11/10 07/25/10 05/19H0 05107/10 05/30/10 08/02/10 05119/10 05H0110 04!17/10 / 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 1 PLEASE ACKNOWLEDGE REC EIPT gY SK6NM h: eun aanmuurr_ nue nnnv e.n.,.... t3P exploration (Alaska)Inc. PetrotechnlcalDataCemer LR2.1 900 E. Benson Blvd. Alaska Data b Consulting Servkxts 2525 Gambol! Slreet, SuXa 400 Am:horaga, AK 99503-2939 JUi~ ~ t?, 201 ~~~~ ~~ ib NOT OPERABLE: Injector P2 -16 (PTD# 1931230) Failed MIT -IA Page 1 of 1 41 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, June 03, 2010 1:25 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Facility OTL; AK, OPS LPC Board Operator; AK, OPS LPC DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Warner, Ross L Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Quy, Tiffany; Wellman, Taylor T; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Injector P2 -16 (PTD# 1931230) Failed MIT -IA Attachments: Injector P2 -16 (PTD #1931230) TIO Plot.doc; Injector P2 -16 (PTD #1931230) schematic.pdf All, Injector P2 -16 (PTD #1931230) failed a MIT -IA to 4000 psi on 6/2/2010. The well is a water and gas injector that was on produced water injection at the time of the failure. The well shall cease injection and should be freeze protected as soon as operationally possible. The well will be reclassified as Not Operable. Plan forward: 1. Slickline: Setting a plug in the end of the tubing 2. Fullbore: MIT -T and CMIT TxIA to 4000 psi. If fails, perform a Leak Detect Log. A copy of the TIO plot and wellbore schematic are included for reference. «Injector P2 -16 (PTD #1931230) TIO Plot.doc» «Injector P2 -16 (PTD #1931230) schematic.pdf» Please let us know if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 JUL 1 2 ZD11 7/5/2011 • Injector P2 -16 (PTD #1931230) TIO Plot 06 -03 -2010 Well. P2-16 3,000 -4F- 1hg -II- LA 2,000 0A 00A 000A On 1.000 einimmnr 03/06/10 03/13/10 03/20/10 03/27/10 04/03/10 04/10/10 04/17/10 04/24/10 05/01/10 05/06/10 05/15/10 05/22/10 05 /29/10 • STATE OF ALASKA -s~~ ~ ~~vr~'~ AL OIL AND GAS CONSERVATION COM ION ~® REP~T OF SUNDRY WELL OPER~10 MAY ~ Y 2 ~rS , 008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ I~r Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extensio pm m'ss~ l o~ l orage Change Approved Program [] Operat. Shutdown ~ Perforate 0 - Re-enter Suspended We 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 193-1230 - 3. Address: P.O. Box 196612 Stratigraphic Service !~ 6. API Number: Anchorage, AK 99519-6612 50-029-22397-00-00 7. KB Elevation (ft): 9. Well Name and Number: 51.5 KB ~ P2-16 8. Property Designation: 10. Field/Pool(s): ADLO-365548 ^ POINT McINTYRE Field/ POINT McINTYRE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10535 feet Plugs (measured) None true vertical 9202.4 - feet Junk (measured) None Effective Depth measured 10436 feet true vertical 9130.12 feet Casing Length Size MD TVD ~ Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 - 112 32 - 112 1490 470 SURFACE 3674 13-3/8" 68# NT-80 31 - 3705 31 - 3704 5020 2270 PRODUCTION 10505 9-5/8" 47# NT-80 30 - 10535 30 - 9202 6870 4760 ~~~~~ Iv1AV ~~ f ~ L U Perforation depth: Measured depth: SEE ATTACHMENT - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 30 - 9984 0 0 - Packers and SSSV (type and measured depth} 5" TIW HBBP PACKER 9905 5-1/2" OTIS TRSV SSSV 2228 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~"' ~,~~` ~ ~ 1Q~~ T t d i i l l i reatmen escr pt ons nc uding vo umes 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: 23365 1968 Subsequent to operation: shut-in 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ' Development `"" Service +~"` Daily Report of Welt 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 Preb Title Data Management Engineer Signature Phone 564-4944 Date 4/29/2008 Form 10-404 R ised 04/2006 ~~ ~ ~ ~ ~~ ~ ~..$~~ Submit Original Only P2-16 193-1230 PERF ATTACHMENT Welibore: P2-16 MDT MDB TVDT TVDB 1/27/1994 10/17/2005 2/26/2006 4/27/2008 4/28/2008 10,125 10,126 8903 8904 APF 10,126 10,165 8904 8932 APF 10,126 10,410 8904 9111 PER BPS BPP 10,300 10,350 9031 9067 APF 10,350 10,370 9067 9082 APF 10,370 10,375 9082 9086 APF AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 • • • P2-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY - -- -~ 4/26/2008''`***WELL INJECTING ON ARRIVAL. T/I/0:900/250/0"""" RIH WITH 2.88" DUMMY GUN TO DRIFT AND TAG. TAGGED BOTTOM AT, iCCL DEPTH OF 10357. CCL TO BOTTOM OF DUMMY GUN IS 20.9'. TD=10378' ELI~II. PERFORATED INTERVAL FROM 10315' - 10375' W/ 2 7/8" PJ 2906 GUNS, 6 SPF, 60 DEG. "`'`**JOB CONTINUED ON 27-APRIL-2008.*"'' 4/27/2008"`***JOB CONTINUED FROM 26-APRIL-2008**** 'TD=10378' ELM. PERFORATED INTERVALS FROM 10300' - 10315' AND ' '110125' - 10165' WITH 2 7/8" PJ 2906 GUNS, 6 SPF, 60 DEG. :HAD 2 MIS-RUNS DUE TO GUNS NOT FIRING. 'RIG DOWN AND MOVE TO 02-28 TO DO PRE-RWO JET CUT. **'`*JOB NOT COMPLETED. CONTINUED ON 28-APRIL-2008*'** 4/28/2008 ***'`JOB CONTINUED FROM 27-APRIL-2008**** 'RETURN RESUME JOB TO PERFORATE INTERVAL FROM 10,125' - 10,165' 'WITH 2 7/8" PJ 2906 GUNS, 6 SPF, 60 DEG. 'TD=10378' ELM AS EARLIER TAGGED. WELL LEFT SHUT IN. T/I/0=300/25010 '~'`*JOB COMPLETED*`~ _ _ __.. __ FLUIDS PUMPED BBLS 2 diesel 2 Total 01/18/08 tA~i~f~~~~a~~ NO. 4560 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o n fl Alaska Oil & Gas Cons Comm 9~@`5 Attn: Christine Mahnken Anchorage, AK 99503-2838 ~,h.~~~R~~.~ ~LT~ y, ~ 2~~~ ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Well .Inh $ Inn nncrrin4inn n~4n RI Rnl... rn L-219 11966240 MDT ~-- (C 12/22/07 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LDL ~ ` ~ 12/31/07 1 V-211 12021135 MEM INJECTION PROFILE Of{~- a~ 12129/07 1 V-216 12021136 MEM INJECTION PROFILE U 12130/07 1 L-219 12017479 ISOLATION SCANNER CBL _ ~., 01/02/08 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL - 01/04108 1 15-04B 12005202 MEM CEMENT BOND LOG 12/28/07 1 G-31A 11962778 SCMT j - C 01/01/08 1 S-26 11978425 USIT 12/29/07 1 02-16C 11628793 MCNL ~- ~ 08/28/07 1 1 G-046 11628765 MCNL - ~ ~ 04106/07 1 1 K-02D 11209613 MCNL ~ L 07/21/06 1 1 17-076 11649940 MCNL - ?~ / ~ 02/17107 1 1 L2-28 11975742 RST - 12/05/07 1 1 Z-06 11968821 RST ~ 12/13/07 1 1 PLtASt AGKNUWLtUGt KtGtIPI t3Y SIGNING AND RETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. - Petrotechnical Data Center LR2-1 , ~ , f 1~ -~~ 900 E. Benson Blvd. _ , Anchorage, Alaska 99508 Date Delivered: ~,~,,~'°~ ~, ~; ,'O~~i3 y,, r` .;d Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: • • ~~ . . SchluDlbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 L ATTN: Beth . 'I' \f) ,¡. ~I~ec,· IÞ' ~ l MPC-08 ) IVTI'":r- ro P2-16 07 -02A R-13 D-11A S-42 S-43 16-07 16-21 1-09A1L-21 2-68/S-17 1-23/0-15 Z-46 A-09A L3-11 SCANNED SEP 1 8 2007 Job# Loa Description Date BL N/A RSTIWFL 08/10/07 1 11767136 MEM INJ PROFILE t JT(\, lç. q - '^-:+ 08/12/07 1 11856185 INJECTION PROFILE j)..,-" Ie. 1-::< - L:.:l~ 08/02/07 1 11649983 MEM PROD PROFILE ic¡r~ - î'1i 'is' 08/07/07 1 11856186 INJECTION PROFILE / ,-r-" /' --~ - rl-/LI 08/02/07 1 11649982 MEM PROD PROFILE ,C/," - ~~ 07/26/07 1 11686773 LDL ¡c,-(" -~ 08/02/07 1 11855804 LDL Jq4-^~~ 08/02/07 1 11855806 STATIC PRESSURE SURVEY 11(~-::¡o4 08/04/07 1 11855805 STATIC PRESSURE SURVEY J 15:'\ -~l~ 08/04/07 1 11849930 SBHP SURVEY J q ~ _ ^!:)C) 08/04/07 1 11630491 LDL I "7Ó( _r'Ä-'+ 07/27/07 1 11846802 STATIC PRESSURE SURVEY U:r.(\ ~ lCi¿,¡ -I;::). 5r 08/11/07 1 11057080 CH EDIT PDC GR (USIT);JI1."'Í -J:'=\l -¡:t l~ "_l;"'¡ 12/14/05 11216203 MCNL .Ql1D-I~U'" /<"{¡,Qt.1 06/29/06 1 11801065 RST I "'if:) ~'A I .... ,--~ '\~ 05/31/07 1 PLEASE ACKNOWLEDGE RECEIP~"Ql ~~I~~~.~~N,~ RpURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, \f'\ I""~ \I, .0 il---' f¡ \/f ~.". Petrotechnical Data Center LR2-1 . '.,""'- .... '!"'- l! ). v-_~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: "' f' C ,J LJ 2007 /\\j',:,:'j '(,i'~,-) {"'~;I I> >, '. ' ", " " <":',^), ',,_,,:J, (\,,: (':!-!);',; (,.,OPt;, (;('ìnlr~l(3~?¡~(Wß 08/30/07 NO. 4396 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color CD 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ""''''''''go. AK ""'D ~ ATTN: Beth C .~ Received by ,. .---- X-36 (PTD #1961670) and P2-16 (PTD #193') MTIAs Jim, Winton, and Bob, Please see the attached MITIA form for the 4 year UIC required tests for wells X-36 (PTD #1961670) and P2-16 (PTD #1931230). AOGCC representative John Crisp witnessed X-36. «MIT PBU X-36 09-05-06.xls» «MIT GPMA P2-16 08-30-06.xls» Thank you, jlnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED SEP 2 ? 20GB PBU X-36 09-05-06.xls Content-Description: MIT PBU X-36 09-05-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 GPMA P2-16 Content-Description: MIT GPMA P2-16 08-30-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 9/11/2006 8:52 AM . . " n O(·¡lll00 . \,--ærì Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test I~ ~ry OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / pt Macintyre / P2 08/30/06 Anna Dube \C\'?)-" lll-:!) Packer Depth Pretest Initial 15 Min. 30 Min. We1l1P2-16 I Type Inj. I I TVD I 8,744' Tubing 1,310 1,390 1,390 1,390 Interval! 0 p.T.D.11931230 I Typetest I P Test psi I 2186 Casing 300 4,000 3,900 3,860 P/FI P Notes: MITIA to 4000 psi pre-MI swap. OA 90 470 460 440 Test not witnessed by AOGCC representative Weill I Type Inj. I TVD I Tubing Interval! p.T.D.1 I Type test I I Test psi I Casing P/FI Notes: OAI Weill I Type Inj.1 I TVD I Tubing Interval I p.T.D.1 I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test/ I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFl9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT GPMA P2-16 08-30-06-1.xls . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanicallntegríty Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERA TOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I X pad 09/05/06 Anna Dube John Crisp ".~." . <I '",' V-,l' ¡ 1 , t' L.'ì.tjív i !:,'\ ' Packer Depth Pretest Inilial 15Min. 30 Min. Well1X-36 I Type Inj. I W TVD ! 8,775' Tubing 1,375 1,375 1,375 1,375 Interval I 4 p.T.D.11961670 I Type test! P Test psi! 2193.75 Casing 550 2,390 2,340 2,340 P/F! P Notes: AOGCC State Witnessed for UIC Compliance. OA 250 470 470 480 Weill I Type Inj. I ! TVD I Tubing Interval I P.T.D.I I Type test I Test psi Casing P/F Notes: OA Weill I Type Inj.' TVD I Tubing I Interval! P.T.D.I I Type test I I Test psi Casing I P/FI Notes: OA Well' I Type Inj.' I TVD I Tubing Interval P.T.D. I Type test! I Test psi Casing I I P/F Notes: OA Weill Type Inj.1 I TVD I Tubing Interval P.T.D.I I Type testl I Test psil Casing P/F! Notes: OA TYPE INJ Codes D = Dnlling Waste G = Gas , ::: Industrial Wastewater N = Not Injecting W = Water MIT Report Form 8Fl 9/1/05 TYPE TEST Codes M :;:: Annulus Monitoring P ::: Standard Pressure Test R:;:: Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V::: Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU X-36 09-05·06-1 xis 1. Operations Abandon D Repair Well [2] Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: a STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM.'ON REPORT OF SUNDRY WELL OPERATIONS D D D RECEIVED P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic 0 JUN 1 2 2006 Stimulate D Other 0 WaiverD TimeAlalka~i[91 Ga~ CUII~. C:unf1\issi n Re-enter Suspended Well D Anchorage 5. Permit to Drill Number: 3. Address: 193-1230 f.7I 6. API Number: 50-029-22397-00-00 9. Well Name and Number: Exploratory Service 51.5 KB P2-16 ADL-365548 11. Present Well Condition Summary: 10. Field/Pool(s): Point Mcintyre Field/ Point Mcintyre Oil Pool 8. Property Designation: Total Depth measured 10535 true vertical 9202.4 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 10436 true vertical 9130.12 feet feet Casing Conductor Surface Production Length 80 3674 10505 Size 20" 91.5# H-40 13-3/8" 68# NT -80 9-5/8" 47# NT -80 MD 32 - 112 31 - 3705 30 - 10535 TVD 32 - 111.98 31 - 3704.18 30 - 9202.4 Burst 1490 5020 6870 Collapse 470 2270 4760 ;....f·' j. ~~ ~¡ ~ (X, It h,J N .....·:''''tr't4 ,,~ t~H"" - ~ ~ " .L ¿i Perforation depth: Measured depth: 10126 - 10410 True Vertical depth: 8903.9 - 9111.14 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 30 - 9984 Packers and SSSV (type and measured depth) 5-1/2" Otis TRSV SSSV 5" TIW HBBP Packer 2228 9905 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9806-9882 RBDMS BFl JUN 14 2006 Treatment descriptions including volumes used and final pressure: BBLS Fluid Summary: 457 MethlWater; 13881% KCL; 1931 Crude; 20 Biozan; 30 Flopro; T/I/O 830/1367/0 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory 01 Development 16. Well Status after proposed work: Oil 0 Gas 0 WAG Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service f.7I x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ f.7I WDSPL 0 Sundry Number or N/A if C.O. Exempt: 305·275 Contact Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 Date 4/11/2006 Form 10-404 Revised 04/2004 ORiGiNAL Submit Original Only e e P2-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ¡';¢i ~ I I ACTIVITYDA TE ISU~I~RY 10/17/2005 ***CONT. FROM 10-16-05*** (Pre pkr sqz) PULLED 5.5" XN LOCK RAN 5.5" X LINE RUNNING TOOL, LOCATED NIPPLE @ 9865' SLM RAN HES FASDRILL BRIDGE PLUG AND SET @ 9860' SLM, 5' ABOVE TOP X NIPPLE ***LEFT WELL SI, TURNED OVER TO DSO*** 10/18/2005 ***CONT. FROM 10-17-05*** MIT- T, TO 3000 PSI, GOOD TEST RAN 5.5" OM-1, SD @ 2208' SLM, FLAPPER CLOSED ON TRSV RAN FLAPPER CHECKER TO 2208' SLM AND CYCLED TRSV, FLAPPER CONFIRM OPEN RAN 5.5" OM-1 TO STA. #2 @ 9830' SLM, RECOVERED DGLV W/T2 LATCH ***WELL LEFT SI, TURNED OVER TO DSO*** 10/19/2005 T/I/O= 825/225/ 0 .. Pumped 5 bbls meth for spear followed by 989 bbls crude for (CIRC OUT) F W P = 650 / 650 / 650 12/24/2005 **** WELL SHUT IN **** (tag fast drill) RUN 4.0" LIB TO 9862' SLM, IMPRESSION OF FAST DRILL PLUG *** LEFT WELL SHUT-IN RETURN WELL TO DSO *** 1/17/2006 T/I/O = 240/800/190. Temp = SI. TBG & IA FL (pre pkr squeeze). TBG FL @ 685' (45 bbls). IA FL @ surface. 1/19/2006 T/I/O=320/440/60 Circ-Out tubing & IA (Pre-Cement Squeeze]Pumped down tubing, taking returns from IA to the flowline of P2-18; 5 bbls neat meoh, 1060 bbls crude. FWP'S=350/300/400 1/19/2006 CTU #5: Packer Cement Squeeze; Arrive on location. Well SI upon arrival. MIRU CTU #5. Cut 60 ft. of pipe. RU lubricator & stab on well. Displace coil to meth and PT. VECO RU hardline loop from P2-16 IA to P2-18 tree cap. Test BOP. Make up BHA: 2.1" C/R, 2.0" stinger, 3.0" BJN. OAL 6.43 ft. Stab back on well and PT lubricator. LRS rigged up to circulate crude down tubing taking returns from IA to P2-18 flowline. Total crude circulated: 1060 bbls. LRS rigged down. Freeze protected flowline on P2-18 w/ 60/40 meth. DS Cementers arrived on location. Continued on WSR 1-20-06 ... 1/20/2006 CTU #5: Packer Cement Squeeze; Continued from WSR 1-19-06.... DS Cementers rigged up. Start RIH slowly due to bad wraps on reel. Increased ROP to 80 ft/min after 1505 ft. Stopped at 4971' due to bad wrap on reel. Fixed pipe problem. Damaged hydraulic rams on level wind in the process of repairing coil tubing wraps. RIH and tag FasDril plug, corrected depth. Flagged pipe @ 9873' corrected. E-line on location called for radio silence. Check for gas in IA. Gas at surface. Rig up hose to slope tank and bleed gas for 2 minutes, gas returns with trace crude. Line up to gauge tank and pump 9 bbls MeOH down tubing taking returns up IA to gauge tank. Gas returns with trace crude. Switch to open top tank with gas buster and pump 9 bbls MeOH. Gas returns with trace crude. Decision made to recirc IA with crude. POOH and repair level wind hydraulic rams while waiting for crude and reloading cement. Radio silence! Wait on crude delivery. Cont' on WSR 1/21/06 ... 1/21/2006 CTU #5, Packer Sqz; Cont' from WSR 1/20/06... Waiting for crude. RIH with 3.0" BDN. Circulate 871 bbls dead crude down IA taking returns up the tubing. Take sample at IA, crude. Batch mix 10 bbls Larc cement as per ~ e e program. Lay in 10 bbls cement on top of FasDrill plug with IA isolated. Open IA to gauge tank and squeeze 7 bbls into lA, lost 1.5 bbls and saw a pump in tubing and IA pressure when cement with aggregate hit packer. Shut in IA. Open backside and jet biozan, switch to slick water and continue jetting from 9740' ctm to 9000' ctm, made 3 passes down and 2 passes up at max rate and pressure. Freezing off in pack-off at 1197' ctm. Pumped hot slick kcl 2 bbls out nozzle pull free, POOH while pumping hot kcl. Park coil in lubricator and begin pumping MeOH to freeze protect coil. RBIH and freeze protect wellbore and P2-18 flowline. Secure well. Shut down to extreme cold. *** Job Complete *** 1/24/2006 CTU #5, Cmt Sqz; End weather standby. Dig out and rig down CTU #5. 2/4/2006 ***WELL S/I ON ARRIVAL *** FUNCTION TEST TRSV, GOOD TEST TAG (TOC) TD @ 9784' SLM ***CONTINUE ON 02-05-2006 WSR*** 2/5/2006 ***CONTINUE FROM 02-04-2006 WSR*** POOH WITH 4.485" GR AND SAMPLE BAILER. TAGGED TOC @ 9784' SLM. BAILER EMPTY. ***TURN WELL OVER TO DSO.*** 2/13/2006 TIO = 1450/1800/30. Temp = SI. TBG & IA FL (Pre MITIA). TBG & IA FL both at surface. 2/15/2006 T/I/O= 1500/2000/0 MIT-IA to 4000 psi. [PASSED] on 2nd attempt. Pumped 6.5 bbls of 50 deg. diesel to achieve test pressure. IA lost 20 psi. in the 1 st 15 min. and 0 psi. in the 2nd 15 min. for a total loss of 20 psi. Bled pressures back. Final WHP= 1300/1800/0. 2/24/2006 CTU #9 w/1.75" Chrome CT. *** Continued from 02/23/06 WSR ***. MU/RIH w/ Weatherford 2-7/8" motor/4.4" mill, displacing coil. Coil pressured up @ 2286'. POOH. On surface & thaw out hydrates. RIH to mill cement & fasdrill & circulate @ .7 BPM. Tag cement at 9806' ctm and mill cement down to 9882' ctm and see Fasdrill plug. Mill through plug holding -350 psi WHP. WHP dropped once plug was through TT. RIH and tag at 10383' ctm. Pump 10 flo pro sweep and RBIH to 10397' ctm and PUH hole. Hang up at 10370'. Work free and continue to chase OOH. Had significant amounts of gas with returns while POOH. Discontinue chasing out due to excessive gas and possible NGL's. Freeze protect coil. Freeze protect well with 58 bbls 60/40 methanol water. Hang freeze protect tag on tree, contact DSO and phone in final straps. *** Continued on WSR 25-Feb-06. *** NOTE: lAP appeared to be tracking WHP within +/- 500 psi at various points during the job. 2/25/2006 CTU #9 w/1.75" Chrome CT. *** Continued from WSR 24-Feb-06 *** Encounter problems with tree valves having ice in them. Thaw out and flush w/meth. RDMO. *** JOB COMPLETE *** 2/26/2006 T/I/O=50/700/0. MIT- IA to 3000 psi. [FAILED] Pumped 50 bbls of diesel down lA, to establish a LLR of 2 BPM @ 2900 psi. FWP's=600/1000/0 RECEiVED Scblumberger JU~! 0 8 2006 NO. 3828 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ~'\ ·1 ~",,,\^t..,,, ecmmissiOn ;~~~\."".1 ':.:11,,;~ ~'\,,;1"'· Anct'tCmc,e . . .... . .,. . . ~"'I~j, ~",\rS r ::Þ'\iJ fJ· 0......- (:i Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501,J..-3 Field: Prudhoe Bay \ 9\"21 \ WI CD J # L D L C el ob OQ escription Date B olor 2-2z I '11- - 840M 11136744 tiL::; 11/13/01) 1 P2-16 1!tc.:..~ - I ;::J'~ 11058238 WFL 08/18/05 1 P2-36 ¡ C¡'t - ¡ (..,{-' N/A LDL 07/13/05 1 P2-50B /'"1,""- - 0<70: N/A LDL 07/16/05 1 16-03 !4fi -c' I 11076454 INJECTION PROFILE 07/28/05 1 P2-36 i'ì'1 -II ..,b 11051061 GLS/LDL 06/15/05 1 4-18/5-30 i-i'i> -II è 10564459 PSP GLS 04/18/03 1 1-33B/L-24 ¡ G 'A' - ;::)..çS 10889175 SCMT 10/12/04 1 04-41 A ì C;'''} - ~ç", N/A LDL 07/18/05 1 15-09A I C¡ .3 - I.~"'í< N/A OIL PHASE BOTTOM HOLE SAMPLE 02/02105 1 09·17 ! T'~ -r.~~"< 11076460 INJECTION PROFILE 08/18/05 1 16-09A C¡ I - ()~"K 11051089 PRODUCTION LOG W/DEFT 08/18/05 1 16·11 i"i<ti -117<: 11058249 LDL 09/14/05 1 17-02 I~e- 0 'TO N/A SENSA MEMORY LDL 10/17/05 1 NK-38A D(~~ -fJ';,./ / 10687734 MDT 02/27/05 1 R-35 iC1''Z,-¡fil 11212863 USIT OS/26/06 1 D-09A I c;C:; - ():% <., ~ 11221576 USIT OS/27/06 1 L5·16 I"X "1. - n \, e, 11212864 USIT OS/28/06 1 K-08A ;:) .,,~ - i'-II') 11054182 MCNL $ ì'~ ...is;l 06/06/05 1 1 H-04A '¡(';) -Jt/' I 10715365 MCNL :# 1:~<F7 ~ 11/27/03 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth , /"\ II / r {:, j ~ //1/ L)-JV\u',,-- 06/01/06 e e e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . Mechanical Integrity Test \i7 _ â :;!ðG ð;....rZtlíCi ì t Email to·Wmton_Aubert@admm.state.ak.us;Bob_Fleckenstem@admm.stateak.us;JimRegg@adminstate.ak.us; Tom Matlder@admin state.ak us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration Alaska, Inc Prudhoe Bay 1 Point Mcintyre 1 PM 2 06/01/06 Joe Anders \C\y \~"3 Packer Depth Pretest Initial 15 Min. 30 Min. WellP2-16 I Type Inj. I N TVD I 8.744' Tubing 480 500 500 500 Interval 0 P.T.D.11931230 I Type test I P Test psi I 2186 Casing 450 2,500 2,500 2,500 P/FI P Notes: MITIA to 2500 psi post Packer Squeeze OA 300 320 320 320 Weill I Type Inj. I I TVD I Tubing Interval I p.T.D.1 I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD Tubing I I I Interval I p.T.D.1 I Type test I Test psil Casing I I I P/FI Notes: OAI I I I Weill I Type Inj.1 I TVD I Tubing I I I I Interval P.T.D.I I Type test I I Test psil Casing I I P/F Notes: OA I I I TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) ,'.." t,¡.Ì\.~¡"t~n ¡UN '; B LQUG i:)1.,,"n¡n¡.....;,..< '" 2006-0601_MIT _PBU_P2·16.xls tP~ .F)¡er _ STATE OF ALASKA . AlAWA Oil AND GAS CONSERVATION COMi\1$SION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 51.5 KB 8. Property Designation: ADL-365548 11. Present Well Condition Summary: Total Depth measured 10535 true vertical 9202.4 Effective Depth measured 10436 true vertical 9130.12 Casing Conductor Surface Production Length 80 3674 10505 Size 20" 91.5# H-40 13-3/8" 68# NT -80 9-5/8" 47# NT -80 Perforation depth: Measured depth: 10126 - 10410 True Vertical depth: 8903.9 - 9111.14 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sharmaine Vestal Form 10-404 Revised 04/2004 r .I Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development [] Stratigraphic [] feet feet feet feet MD 32 - 112 31 - 3705 30 - 10535 j"'Cll,i\,tf,trÜ ij ~~.........~n\ ~t:.. r, 5-1/2" 17# 5" TIW HBBP PACKER Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory Service 193-1230 M 6. API Number: 50-029-22397-00-00 9. Well Name and Number: P2-16 10. Field/Pool(s): Point Mcintyre Field/ Point Mcintyre Oil Pool Plugs (measured) Junk (measured) TVD 32 - 111.98 31 - 3704.18 30 - 9202.4 (' L ~j L-80 RBDMS 8Ft API{ 1 4 2006 None None Burst 1490 5020 6870 200:3 30 - 9984 9905 RECEIVED APR 1 4 2006 Alaska Oil ~ Gæ Collapse 470 2270 4760 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN Title Data Mgmt Engr Phone 564-4424 Service G INJ [] WINJ M 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil [] Gas WAG 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: 305-275 Date 4/11/2006 Tubing pressure P" WDSPL r Submit Original Only e e P2-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 10/17/2005 ***CONT. FROM 10-16-05*** (Pre pkr sqz) PULLED 5.5" XN LOCK RAN 5.5" X LINE RUNNING TOOL, LOCATED NIPPLE @ 9865' SLM RAN HES FASDRILL BRIDGE PLUG AND SET @ 9860' SLM, 5' ABOVE TOP X NIPPLE ***LEFT WELL SI, TURNED OVER TO DSO*** 10/18/2005 ***CONT. FROM 10-17-05*** MIT- T, TO 3000 PSI, GOOD TEST RAN 5.5" OM-1, SD @ 2208' SLM, FLAPPER CLOSED ON TRSV RAN FLAPPER CHECKER TO 2208' SLM AND CYCLED TRSV, FLAPPER CONFIRM OPEN RAN 5.5" OM-1 TO STA. #2 @ 9830' SLM, RECOVERED DGLV W/T2 LATCH ***WELL LEFT SI, TURNED OVER TO DSO*** 10/19/2005 T/I/O= 825/225/0 .. Pumped 5 bbls meth for spear followed by 989 bbls crude for (CIRC OUT) F W P = 650/650/650 12/24/2005 **** WELL SHUT IN **** (tag fast drill) RUN 4.0" LIB TO 9862' SLM, IMPRESSION OF FAST DRILL PLUG *** LEFT WELL SHUT-IN RETURN WELL TO DSO *** 1/17/2006 T/I/O = 240/800/190. Temp = SI. TBG & IA FL (pre pkrsqueeze). TBG FL @ 685' (45 bbls). IA FL @ surface. 1/19/2006 T/1/0=320/440/60 Circ-Out tubing & IA (Pre-Cement Squeeze]Pumped down tubing, taking returns from IA to the flowline of P2-18; 5 bbls neat meoh, 1060 bbls crude. FWP'S=350/300/400 1/19/2006 CTU #5: Packer Cement Squeeze; Arrive on location. Well SI upon arrival. MIRU CTU #5. Cut 60 ft. of pipe. RU lubricator & stab on well. Displace coil to meth and PT. VECO RU hardline loop from P2-16 IA to P2-18 tree cap. Test BOP. Make up BHA: 2.1" C/R, 2.0" stinger, 3.0" BJN. OAL 6.43 ft. Stab back on well and PT lubricator. LRS rigged up to circulate crude down tubing taking returns from IA to P2-18 flowline. Total crude circulated: 1060 bbls. LRS rigged down. Freeze protected flowline on P2-18 w/ 60/40 meth. DS Cementers arrived on location. Continued on WSR 1-20-06 ... 1/20/2006 CTU #5: Packer Cement Squeeze; Continued from WSR 1-19-06.... DS Cementers rigged up. Start RIH slowly due to bad wraps on reel. Increased ROP to 80 ft/min after 1505 ft. Stopped at 4971' due to bad wrap on reel. Fixed pipe problem. Damaged hydraulic rams on level wind in the process of repairing coil tubing wraps. RIH and tag FasDril plug, corrected depth. Flagged pipe @ 9873' corrected. E-line on location called for radio silence. Check for gas in IA. Gas at surface. Rig up hose to slope tank and bleed gas for 2 minutes, gas returns with trace crude. Line up to gauge tank and pump 9 bbls MeOH down tubing taking returns up IA to gauge tank. Gas returns with trace crude.Switch to open top tank with gas buster and pump 9 bbls MeOH. Gas returns with trace crude. Decision made to recirc IA with crude. POOH and repair level wind hydraulic rams while waiting for crude and reloading cement. Radio silence! Wait on crude delivery. Cont' on WSR 1/21/06 ... 1/21/2006 CTU #5, Packer Sqz; Cont' from WSR 1/20/06 ... Waiting for crude. RIH with 3.0" BDN. Circulate 871 bbls dead crude down IA taking returns up the tubing. Take sample at lA, crude. Batch mix 10 bbls Larc cement as per program. Lay in 10 bbls cement on top of FasDril1 plug with IA isolated. Open IA to gauge tank and squeeze 7 bbls into lA, lost 1.5 bbls and saw a e e pump in tubing and IA pressure when cement with aggregate hit packer. Shut in IA. Open backside and jet biozan, switch to slick water and continue jetting from 9740' ctm to 9000' ctm, made 3 passes down and 2 passes up at max rate and pressure. Freezing off in pack-off at 1197' ctm. Pumped hot slick kcl 2 bbls out nozzle pull free, POOH while pumping hot kcl. Park coil in lubricator and begin pumping MeOH to freeze protect coil. RBIH and freeze protect wellbore and P2-18 flowline. Secure well. Shut down to extreme cold. *** Job Complete *** 2/4/2006 ***WELL S/I ON ARRIVAL*** FUNCTION TEST TRSV, GOOD TEST TAG (TOC) TD @ 9784' SLM ***CONTINUE ON 02-05-2006 WSR*** 2/5/2006 ***CONTINUE FROM 02-04-2006 WSR*** POOH WITH 4.485" GR AND SAMPLE BAILER. TAGGED TOC @ 9784' SLM. BAILER EMPTY. ***TURN WELL OVER TO DSO.*** 2/13/2006 TIO = 1450/1800/30. Temp = SI. TBG & IA FL (Pre MITIA). TBG & IA FL both at surface. 2/15/2006 T/I/O= 1500/2000/0 MIT-IA to 4000 psi. [ PASSED] on 2nd attempt. Pumped 6.5 bbls of 50 deg. diesel to achieve test pressure. IA lost 20 psi. in the 1 st 15 min. and 0 psi. in the 2nd 15 min. for a total loss of 20 psi. Bled pressures back. Final WHP= 1300/1800/0. 2/23/2006 MIRU CTU #9 w/ chrome coil. Continued on 02/24/06 WSR. 2/24/2006 CTU #9 w/1.75" Chrome CT. *** Continued from 02/23/06 WSR ***. MU/RIH w/ Weatherford 2-7/8" motor/4.4" mill, displacing coil. Coil pressured up @ 2286'. POOH. On surface & thaw out hydrates. RIH to mill cement & fasdrill & circulate @ .7 BPM. Tag cement at 9806' ctm and mill cement down to 9882' ctm and see Fasdrill plug. Mill through plug holding -350 psi WHP. WHP dropped once plug was through TT. RIH and tag at 10383' ctm. Pump 10 flo pro sweep and RBIH to 10397' ctm and PUH hole. Hang up at 10370'. Work free and continue to chase OOH. Had significant amounts of gas with returns while POOH. Discontinue chasing out due to excessive gas and possible NGL's. Freeze protect coil. Freeze protect well with 58 bbls 60/40 methanol water. Hang freeze protect tag on tree, contact DSO and phone in final straps. *** Continued on WSR 25-Feb-06. *** NOTE: lAP appeared to be tracking WHP within +/- 500 psi at various points during the job. 2/24/2006 Assist Coil/ Heat Upright Tank 2/25/2006 CTU #9 w/1. 75" Chrome CT. *** Continued from WSR 24-Feb-06 *** Encounter problems with tree valves having ice in them. Thaw out and flush w/meth. RDMO. *** JOB COMPLETE *** 2/26/2006 T/I/0=50/700/0. MIT- IA to 3000 psi. [FAILED] Pumped 50 bbls of diesel down lA, to establish a LLR of 2 BPM @ 2900 psi. FWP's=600/1000/0 FLUIDS PUMPED BBLS 57 Diesel 186 Meth 2049 Crude 992 1 % KCL 30 Flopro 3314 TOTAL (fù1rr'\~r:ì? \" ~'" ¡! / t\ \1 ., ¡! \'1:1 I.w" I: i:? ij I 1 ,/ I .' ~ \ 'J I' t¿/ U L/u 1,' ::...=1 ,'0\ .j¡-1 ! :1 II " : !1¡!I¡..,j .I : 'I ,I Ii \:!..).J ;--, . -", ..............., ~ -, ,..--, .i 1 ~\ n ' \ Y ,'"' J I 1/::' / ì I, j ~ '\ I, J; 'j \ - ! / ¡ 1;\ ~\ ./ Jj \!! ' . J \', I.!.J:, Ù,;,ji ~ ..~ ~'\.~ :~: ;~' '.i U-'\j FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Ross Warner Production Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 /03- J;µ Re: PT McIntyre P2-16 Sundry Number: 305-275 ~~l~,AJ~~~ ir\~k;:L S E P 2~ 1 2.005 Dear Mr. Warner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~t~þ John k. Norman Chairman 5f DATED this 21 day of September, 2005 Encl. 1. Type of Request: rr STATE OF ALASKA ( A~ .<A OIL AND GAS CONSERVATION COMMI~SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: q / to / zg,q,$:, ',:\\\ :,r, i;\".~',,:~lr""; VJ GA-· t'CD 1) ,~'2.\JÛ) J¡ 'C ~ .l '~I ..."~,,~.','~. '.:.}~.'~ \ :~:. ;I~ í'. ," ì:~ " . Other U Abandon U Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 / Wpii~é[:LJ:I";~ fI, ,:"".~:"t,'~)~: I,~ -r3'~ " --.' Stimulate 0 Tin:,e 'Ëxt~nsion D Re-enter Suspended Well 0 5. Permit to Drill Number: Suspend U Repair well 0 Pull Tubing 0 Perforate U Development 0 o Exploratory 0 ·107 OGOO jcjs-/2.~ WGA- Stratigraphic Service ø / 6. API Number: 50-029-22397 -00-00 /.- Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 51.5 KB P2-16 /' 8. Property Designation: ADL-365548 11. Total Depth MD (ft): 10535 Casing Conductor Surface Production Total Depth TVD (ft): 9202.4 10. Field/Pools(s): PT Mcintyre Field 1 pt Mcintyre Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10436 9130.12 None Junk (measured): None Collapse 470 2270 4760 Length Size MD TVD Burst 80 20" 91.5# H-40 32 112 32 112 1490 3674 13-3/8" 68# NT -80 31 3705 31 3704 5020 10505 9-5/8" 47# NT -80 30 10535 30 9202 6870 Perforation Depth MD (ft): 10126 - 10410 Perforation Depth TVD (ft): 8903.9 - 9111.14 Tubing Size: 5-1/2" 17# Tubing Grade: L-80 Tubing MD (ft): 30 - 9984 Packers and SSSV Type: 5" TIW HBBP Packer Packers and SSSV MD (ft): 9905 12. Attachments: Descriptive Sum m ary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for . 62., Commencing Operations: 9 91 005 16. Verbal Approval: C _,.' Date: Commission Representative: 13. Well Class after proposed work: Exploratory 0 Development 0 Service ~ ./" 15. Well Status after proposed work: Oil 0 ,/ Gas 0 Plugged 0 Abandoned 0 WAG ø GINJ 0 WINJ 0 WDSPL D Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Printed Name Title ,~oss Warner _ // Signature ~ ~~hone 564-5359 COMMISSION USE ONLY Contact Ross Warner Production Engineer Date 9/15/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (~5 --~15 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other "lL L T ~¡ ~ ~J , RBDMS BFl SEP }1, 1 Z005 Subsequent Form Required: l o~· 40 4 . Approved by: rJ/I¡ ¡J ~ ~ COMMISSIONER APPROVED BY THE COMMISSION Date: 9 -- z/ -- 05 Form 10-403 Revised 11/2004 OR\G\NAL Submit in Duplicate bp .'\" ,';"'1 . 0·', Jo' I'.;"" "';'., '.:,',.,',..... ,. .:' " ,',.~,~',' '\, 'i' 1'" 1'1'1; ,""¡ 'S \::'f' -'L BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 September 16, 2005 Alaska Oil & Gas Conservation Commission Attention: Mr. Winton Aubert 333 west 7th Avenue, Suite 100 Anchorage, AK 99501 / \~-:? \C\?J Dear Mr. Winton Aubert: Reference: Sundry Notice for P2-16---Packer Squeeze. BP Exploration (Alaska) Inc. proposes to perform a Packer Squeeze on well~. (-._._....'~...' Attached is the program for restoring this well to its full capabilities as an injector. ..,/ Summary: Step 1 2 3 4 5 Type S C S C o P roced u re Pull TTP. Set FasDril1. MIT T. Pull DGLV #2 Packer squeeze. / wac 2 days. MIT IA. Tag TOC. Mill cement & plug. Underream Casing. MIT-IA / (pre squeeze) Currently this well is shut-in. Service work will begin when approval is received from your organization. If you have any questions please contact: Jennifer Julian at 564-5663 or Ross Warner at 564-5359 Sincerely, '") ~4<L /~~-C-_ Ross L. Warner "bp .'. ,\It.'~I. -.....~ ~...- ~~- --:..- '*.~ ~..... ·I'~~~\" ". { To: J. Bixby/D. Cismoski, GPB Well Ops TL NSU, ADW Well Operations Supervisor Date: September 15, 2005 From: Jennifer Julian, Design Engineer for Ross Warner Subject: P2-16i Packer Squeeze Cost Code: PMP02WL 16-N Est. Cost: $200 M lOR: 600 BOPD Please perform the attached packer squeeze procedure. This procedure includes the following steps: Summary: Step 1 2 3 4 5 Type S C S C o Procedure Pull TTP. Set FasDril. MIT T. Pull DGLV #2 Packer squeeze. WOC 2 days. MIT IA. Tag TOC. Mill cement & plug. Underream Casing. MIT-IA / (pre squeeze) ./ Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: 44 degrees @ 10025' 4.455" @ 9960' Otis XN nipple 10381' on 3/29/05 LDL 8/18/05 Not in Data Base BackQround Information: This well has been an injector since late 1994. Recent rates and pressure were about 25,000 bwpd at 2100 psi. The well was put on MI early in February and would only take about 8-10 mmcfpd at 3450 psi. A Schmoo-Be-Gone job was pumped 2/25 and capacity increased to 17.5 mmcfpd. On March 12th CGF shut down about 3 times and could not supply rate to this pad. The well was fully opened again 3/15/05, but capacity was only about 10.0 mmcfpd. The target rate for this well is about 20-30 mmcfpd. On 3/20/05 the IA started to rise and eventually a pressure of ,..,2600 psig was observed. The bleeds became unmanageable and MI gas was observed during a bleed April 5, 2005. On 5/13/05 the well was taken off of MI and put back on water injection. On 7/9/05 an inspection caliper was run in the tubing. The interpretation of this log was the tubing is in fair to good condition. Page 1 of 9 f P2-16 Packer Squeeze On 8/7/05 a PXN plug was set and the following pressure testing took place: 1. MIT of the tubing passed @ 2500 psig. IA did not communicate. 2. MIT of IA failed. A leak rate of 1.3 to 1.6 bbl. Imin. was observed at ,..,2200 psig. On August 18, 2005 a Water Flow Log was run and it clearly indicated that the packer was leaking in this well. Tubing to production casing integrity needs to be acquired for this well to be utilized as a WAG injector. The alternate remedial repair for this well would require a Rig Workover . Objective: / The primary purpose of this packer squeeze is to repair a confirmed packer leak (LDL run 08/18/05) on this WAG injector. Perfs will be protected with a Halliburton composite Fas Drill plug in the tailpipe. Cement will be circulated into the IA through an open GLM pocket. A cement plug will be left in the tubing to prevent possible U-tubing of cement back into the wellbore. After WOC, the cement and composite plug will be milled up, the IA will be pressure tested, and the well will be put back on injection. If you have any questions or comments regarding this procedure, please contact: Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. Ross Warner at (W) 564-5359, (H) 333-9017, (Cell) 250-3441. cc: w/a: Well File R. Warner J. Julian Andy Parker G ANC Well Work Programs LPC Lead DS Operator LPC DS Operator w/o: S. Rossberg 2 P2-16 Packer Squeeze ./ TOC at -9750' ~ packer at 9905' DD " ~~ SWS Nipple at 9943' D~ ., XN Nipple at 9960' DD - '- . 5.5" TT at 9984' DD / 9-5/8" liner ~ _____ 5-1/2" tubing _~ GLM# 2 at 9848' z Fas Drill Composite Plu~ set @ 9973' DD Cement Volume in TubinÇl (9973'-97501) * .0232=5.2 5.2 bbls Cement Volume in Annulus (9905-97501) * .0438= 6.8 6.8 bbls Total Cement to Pump 5.2 + 6.8 = 12 bbls total 3 P2-16 Packer Squeeze SQueeze TarÇlet Place cement in the tubing by IA annulus to repair confirmed packer leak. /' LLR through packer leak was 1.6 bpm at 1700 psi during LOL on 8/18/05 (with TTP in hole) M IT - T to 2500 passed on 8/9/05 IA volume to packer is 434 bbls Tubing volume to composite plug to be set at 9973'00 is 231 bbls Note: well has TRSV. Pre-Squeeze Slickline & Fullbore 1. Shoot fluid levels on IA and tubing. Rig up to pump down tubing and take returns up IA. 2. RU SL, pumps, and crude. 3. Pull TTP at 9943'00. Make correction to DO. 4. Load tubing. 5. Set Halliburton Fas Drill at 9973' DO (in the middle of the 20' pup above WLEG). See attached tubing tally. 6. MIT-T to 3000 psi to ensure Fas Drill plug is holding. 7. Pull DGLV in station #2 at 9848' and leave open. 8. Fluid pack IA and tubing with crude. Establish circulation rate down tubing, taking returns up IA holding 100 to 200# backpressure. CTU Packer Squeeze It is important that the IA is liquid packed with crude during the squeeze. Shortly before the squeeze, shoot a fluid level on the IA to see if the annulus is liquid packed. 9. RU CT and squeeze equipment. NOTE: Rig up surface equipment to allow returns from both the 9-5/8" and the CT/Tbg annulus. 10. Pump down tubing and up IA to confirm circulation through open GLM #2 by opening up returns from the lA, holding 100-200# backpressure. Confirm 1-for-1 returns to a 40 bbl open-top tank. 4 P2-16 Packer Squeeze t 11. RIH with large hole nozzle (no checks). Tag Fas Drill plug. Pick-up until full string weight is observed. Correct depth to top of Fas Drill plug (DO). PUH 10' and flag pipe. PUH & park coil at 9800'. 12. Batch mix 12 pumpable bbls LARC cement to meet the following specifications. (Use current BP liner blend, per Dowell Lab) Volume to Pump Cement Type Filter Cake Thickening Time Fluid Loss Target Acceptable Range Rheology 12 bbls total 6 bbls Neat LARC w/B-82, 3% BWOC 6 bbls LARC wI aggregate w/B-82, 3% BWOC* .85" firm cake ± 0.15" in lab 3-5 hours at 1800 F at Depth 75 cc/30-minutes at 170°F BHCT 50 - 90 cc/30-minutes at 170°F BHCT YP>5 with no settling or gelation in fluid loss cell. *Use current best practices for cement for aggregate volume. · Catch a sample of the cement for QC testing. Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. Line up cementers to the coil. · Ensure all gas is out of the system. Do not proceed with squeeze unless the tubing is liquid packed and gas free. · First step will be to lay in all cement in tubing and then pulling CT to safety and parking. Then IA will be opened and cement will be circulated into IA as detailed in steps below. 13. RIH to flag. Line out cementers to the CT. Pump the following down the coil: · 10 bbls spacer water · 3 bbls neat LARC cement · 6 bbls LARC cement wI aggregate · 3 bbls neat LARC cement · One coil volume of spacer water · 1.5# biozan gel for cement clean-out SI in IA and take returns up the backside (tubing x CT annulus) while pumping water spacer. Switch to LARC while continuing to take returns up the backside. Maintain 100-200 psi backpressure. Pump 2 bbls LARC out the nozzle (86' of cement above nozzle) and then lay-in 1:1 while PUH (This step is to ensure that you don't dilute cement as you pull up). Strap returns in the 40 bbls tank. 5 P2-16 Packer Squeeze · Monitor IA pressure while laying in cement in tubing to account for cement U- tube. · Water flush volume is critical, so use the internal 1 0 bbls tanks in the pump van to gauge flush volume. SAFETY: 12 barrels of cement would extend up the tubing to 9456' DD if no cement is placed in the annulus (assuming Fas Drill plug at 9973' DD). 14. With the nozzle at safety of at least 9350', SO pumping, SI backside (tubing x CT annulus). Compare pump volume to return volume in the 40 bbl tank. 15. Open IA to returns to the 40 bbl tank. Begin pumping at minimum rate down the CT. Circulate 7 bbls through the open GLM pocket and up the IA. SI IA and gauge volume of returns. Monitor the IA and tubing pressures at equilibrium. NOTE: With Fas Drill plug at 9973' DD, the final cement top in the tubing and annulus should be -9750' -100' above the GLM#2 16. Open the choke on the backside (tubing x CT annulus) and begin pumping biozan down the CT for clean out. Launch ball and begin jetting with biozan down maximum depth of 9740' MD. 17. Switch to friction reduced water. Make 3 down passes and 2 up passes at 800/0 from 9740' to -9000. Take barrel count to ensure 1: 1 returns. Jet uphole at 800/0 running speed and max CT pressure, washing GLM#1 and TRSV thoroughly. Replace voidage trying to maintain a balanced well bore. This step is critical to the success of this job-particularlv on this job which has very little cement in the annulus. 18. Freeze protect the top 2,500' of the well bore while POOH. Continue to closely monitor the chanQes in wellhead pressure to maintain a balanced well bore. 19. Leave tubing pressure so the well bore will be balanced between the tubing and casing at the packer. Post-SQueeze DHD 20. After 2 days WOC, MIT the IA to 3,000 psi. Establish LLR if MIT fails. / Post-SQueeze SL 21. RU slickline unit. Tag cement top. 6 P2-16 Packer Squeeze Post-Squeeze CT Mill Cement Plua 22. RU CTU and RIH with mill and motor to mill through the -223' cement and Fas Drill plug. 23. Continue to below perfs to ensure no cement fell past the packer. POOH at 80%. 24. Make up another BHA and underream the 9-5f" casing to 1 0,41 0' MD (+/-). 25. MIT IA to 3000 psi. Contact State Inspectors to witness testing. / 26. If MIT-IA passes, put well on injection. 7 (t P2-16 Packer Squeeze ~ .... .. .. ::'.': I TUBING sU~MÄRY' .... ............. .. ·:·II·'~~ .:.: ..:¡ I· :..:... ::;:. j: 1'·:,':' .... ," ...... .' ,. .: ,- '-',- ,. ..'.... , . : ~ : ~ : : ":l""",,,,, .j~~r' .. ....." ....."....... ....... . ................. ....................... .. .................... ................. . .,........ .. .. ..........-.... 242 JTS ON RACK "9976.48 FT ON RACK FIG WELL # TUBING TUBINGWT. DOYON 14 P2-"6 . ,. "........ . '... ::<L~~$.:::¡C··:· . H4tit·· .. Date 1f18/94 l·80 NSCC . . :236 JTS RAN 97;28.1:5 FT RAN 39.00P:KB TO SF ,ITEM Description Includes: SIZE, TYPE, CONN~CTION (JTS;'.#) . ITEM 5.5" WlEG NSCC 9CR 5.5" 17# L-BO NSCC PUP 5.5" 17# L-80 X/O BTS NOD 8 X NSCC P I 5~:5·~OTISOlXNII. NIPPLE: 9CR 5.5" 17# L~80 X/O NSCC B X BTS P 5.5" 17# L~80 NSCC PUP 5.5" 17# L-80 NSCC PUP 5;5" PARKER "SWS" NIPPLE 9CR 5.5" 17# L·80 NSCC PUP 5.5" 17# L-80 NSCC PUP TJW BOTTOM CONNECTION TIW MILLOUT EXTENTlON I. . iTIW 9 5/8" X 5" HBBP PKR TIW LACTCH ASSV 5.5" 17# L·BO NSee PUP !5.5" 17# L-80 NSeC PUP 5.$·~ PARKER "SWS" NIPPLE 9CR 5·.5" 17# l-80 N see PUP 5.5" 17# L-BO N sec PUP 5.5" 17# L~80 X/O BTS NOD 8 X NSCC P :5~51·:0PTIS:I~l..IäD" SPM G LM #1 5.5" 17# L·BO X/O NSCC BX BTS P 5.5" 17# L-80 N see PUP JT#1-141)5.5" 17# l·BO NSCC T8G 5.5" 17# L-80 N see PUP 5.5'· 17# l-80 X/O BTS NOD 8 X NSCC P 5.5" OPTIS "L8D" SPM GLM #2 5.5" 17# L-80 X/O Nsce B x 8T5 P 5.5" 17# L-80 NSCC PUP iJT#142-183)5.5" 17# L-80 NSCG TaG :5.5" 17# L-80 -Ñsce PUP FLOW COUPLING, 9CR !S~5T' OTIS SERIES 10 UTRSV" 9CR I FLOW COUPliNG 9CR 5.5" 17# L·80 NSCC PUP JT#184·236)5.S" 17# L-80 NSCC TBG r NSCC B X 5.5 NSCC P 7'" NSCC P X P FMC TBG HGR TOP THREAD 7" NSCC RTTOTBG SPOOL ID 4.892 4.892 4.892 4.455. 4.892. 4.892 4.892 4.562' 4.892 4.892 4.830 6.210 4.808 4.750 4.892 4.892 4.562 4.892 4.892 4.892 4.61.0 4.892 4.892 4.892 4.892 4.892 4.610 4.892 4.892 4.892 4.892 4.892 .4.562 4.892 4.B92 4.892 4.892 6.184 00 6.530 6.100 6.100 ·:/6.1Ö:Ø ,: 6.120 6.120 6.120 6.070 6.120 6.120 7.641 7.020 8.313: 7.188 6.120 6.120 .6.070 6.1 20 6.1 20: 6.1 '00, 1;1'80: 6.1 20' 6.120' 6.120 6.120 6.100 7.780' 6.120 6.1 20 6.1 20 6.1 20 6.100 8'; 4 00 ¡ 6.100 6.120' 6.1 20 7.500 7 _ 000 .... . lENGTH TOP BOTTOM 1.28 < 9982J4f 9984.09 < 19. 65·,:99 63~i6 ''::'9982l81 ....... 2.03è:;:9961.13(::::9~(6'3~:ï:6: ':':::1.4:1 ·9959~?'?~:'il:i~:~Jr~:t~ 1.88 :::9:957¡S4 : 99'S9l12 S.449952~40 : ". 9957~84 9. 5 6'::Ú9'~42/8499 52'.40 :. '1.33. 9941.51. 9942.84 19.53 9921.98 :.: 9941.51 5.50 9916.48 9921.98 .76 9915.72 9916.48 5.15 9910.57 9915.72 4.95 9905..62 9910.57 1.50 9904.12 9905.62 5.50 9898.62 ...: 9904.12 9.50 9889.12 9.~9a.62 1.33 988.~.. 79 9889.12 19.19,:' :'9868.60 9887.79, 1'"-' - . . ,.. 9.67 . 9,858.:~3 ,.:.::...98~·a:~6D.' 2.02,' . 98~()~91 .:: 9~.58.93· ':'9.03 9847"88'.:::.~856.9J 1.89 9845.99'.: 9847.88. 9.63 9836;36· ... 9845.99: 5813.53 4022.83 .::: ·9836.'36: 9.37' 4013.46" :'4:022.83. 2.02 4011.44 401'3.46; 9.02 4002..42. ..40t1.·4~·} 1.90 _ ,490.0~52~ 4002.:4'2' 9.63.:::. :·3990.89 .'. :4000.52, 1738.07 '. '2252.82 .. :39.90.89.' 9.50 :::.:'::22'43. 3("" : 22·S2:..Ø 21 5.65: '2237.67, ':2243,:32' . '. ..., ...,. "". .... . ." . SL74 ; . ·:2227·.93! '2237.67.' 5.65 2222;'2~' ·:"22~?:~93 9.56: 2~12. 72, '2222:..28, 2176.55 ·36.1.7. .:,,221:2.]2. 2.10 34.07 36.17 1.64 32.43 34.07 1.58 30.85 32.43 30.85 30.85. .. , .... 8 TREE = \ÑËLLHEAo = ACTUA TOR = KB, ELEV = BF, ELEV = ..-,----_.-..-.._-~..-.,--_.-..-_._'''_._--,- KOP = 4341' --.-..---.-----------------.-----. ,~~~_~~21.e =_______~~~_?2:. Datum Mo = 10057' Datum TV 0 = 8800' SS l' .~ crvv FMC BA KER C 53,5' 13-3/8" CSG, 68#, NT-80, 10 = 12.415" 1--1 3705' r-J Minimum ID = 4.455" @ 9960' OTIS XN NIPPLE 5-1/2" TBG, 17#, L-80, ,0232 bpf, 10 = 4,892" 1--1 9984' PERFORA TION SUMMA RY REF LOG: ATLAS olUGR ON 09/13/93 ANGLE AT TOP PERF: 43 @ 10126' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz oA TE 3-3/8" 6 10126 - 10410 0 01/27/94 I PBTo 1--1 10436' 9-5/8" CSG, 47#, NT-80, 10 = 8,681" l-i 10535' DATE 09/16/93 09/15/01 09/12/05 REV BY COMMENTS ORIGINAL COM PLETION RN/TP CORRECTIONS /TLH PXN PLUG SET (08/07/05) P2-16 o L I I :8: S I~I I ~ DATE REV BY COMMENTS ¡siÆTY NOTES: 2228' l-i 5-1/2" OTIS TRSV SSSV, 10 = 4,562" I ~ GA S LIFT MA NoRELS ST Mo TV 0 oEV TY PE LATCH PORT oA TE 1 4001 4000 5 OTIS-LBO T2 2 9848 8702 43 OTIS-LBO T2 9888' 1-i5-1/2" PARKER SWS NIP, 10 = 4,562" (ELMO) I 9905' l-i 9-5/8" X 5" TIW HBBP PKR (ELMO) I I 9943' l-i 5-1/2" PARKER SWS NIP, 10 = 4,562" (ELMO) I 19936' S LM 1--15-1/2" PXN PLUG SET IN SWS NIP (08/07/05) I 9960' l-i 5-1/2" OTIS XN NIP, 10 = 4.455" (ELMO) 9984' 1--1 5-1/2" TUBING TAIL, WLEG I 9984' l-i ELMO TT LOGGED 01/26/94 I POINT MClNTY RE UNIT WELL: P2-16 PERMIT No: 93-123 API No: 50-029-22397-00 SEC 14 T12N R14E 2202,55 FEL 1976,74 FNL BP Exploration (Alaska) P2-16 et al. ) ) p¡--õå1: ,Q3 -, Z3 Su bject: P2-16 et al. From: Winton Aubert <winton _aubert@admin.state.ak.us> Date: Wed, 27 Jul 2005 10:55 :23 -0800 To: "NSU, ADW Well futegrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> CC: James B Regg <jim_regg@admin.state.ak.us>, Catherine P Foerster <cathy _foerster@admin.state.ak.us> Joe, This is some clarification of AOGCC's position regarding injection wells with slow TxIA communication, similar to P2-16 (below). The Commission requires that injection wells with TxIA communication be reported. In cases where slow gas TxIA communication cannot be confirmed when tested with liquid, the Commission may approve continued well operation at reduced pressure, but only after following the administrative approval process. Please remind others in your organization of these continuing reporting requirements. Thank you, and I apologize for any misunderstanding. Winton Aubert AOGCC 793-1231 *From: * NSU, ADW Well Integrity Engineer *Sent: * Tuesday, April 26, 2005 9:24 AM *To: * GPB, LPC DS Ops Lead *Cc: * NSU, ADW Well Integrity Engineer; Winslow, Scott Wi Parker, R. Andrew *Subject: * RE: Well P2-16 (PTD #1931230) TxIA Comm Bill or Mark, I had a discussion with the AOGCC regarding slow TxIA communication on MI injectors. If we're able to back off the injection rate to stabilize the IA pressure under trigger pressures, the well does not need to be reported to the state nor will it require any paperwork. Before we come to secure the well, I'd like to attempt to stabilize the IA pressure. Do you want to take the lead on this or would you like DHD to assist? If you bleed, be sure to keep it in pipe given the potential of NGLs. Joe and I change out today but I'll brief him on this item. Thanks, Anna SCANNED ~UG 0 9 2005 1 of 1 7/28/2005 10:43 AM FW: Well P2-16 (PTD #1931230) TxIA Comm ) ~~i~~~·~~:··r-VY:.Well.·}'t~19...(PTII.#1931239)..Tx114GotiI~ ~f~W:ttÅ~<1~l"S, ~8~I1't...~.ªBq~f~22($B~.~Pl11?· Dáte:.Wed;.20 J'U1400516.:4ó:18>~0800· .. .. .}'i)!· ;~t~¡~·y,\ ') FYI Joe 1-907-659-51 02 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, April 26, 20059:24 AM To: GPB, LPC DS Ops Lead Cc: NSU, ADW Well Integrity Engineer; Winslow, Scott W; Parker, R. Andrew Subject: RE: Well P2-16 (PTD #1931230) TxIA Comm Bill or Mark, I had a discussion with the AOGCC regarding slow TxlA communication on MI injectors. If we're able to back off the injection rate to stabilize the IA pressure under trigger pressures, the well does not need to be reported to the state nor will it require any paperwork. Before we come to secure the well, I'd like to attempt to stabilize the IA pressure, Do you want to take the lead on this or would you like DHD to assist? If you bleed, be sure to keep it in pipe given the potential of NGLs. Joe and I change out today but I'll brief him on this item. Thanks, Anna From: GPB, LPC DS Ops Lead Sent: Friday, April 15, 2005 10:48 PM To: NSU, ADW Well Integrity Engineer Subject: RE: Well P2-16 (PTD #1931230) TxIA Comm Anna, We're on hold for now waiting to hear back from town which water injector to swap to MI. Should be swapping P2-16 to PWI sometime next week. Rob From: NSU, ADW Well Integrity Engineer Sent: Friday, April 15, 2005 7:29 AM To: AOGCC - Jim Regg (E-mail); AOGCC - Winton Aubert (E-mail) Cc: Rossberg, R Steven; GPB, GPMA Area Mgr; GPB, LPC DS Ops Lead; NSU, ADW Well Operations Supervisor; Parker, R. Andrew; NSU, ADW Well Integrity Engineer; Engel, Harry R; Reeves, Donald F; NSU, ADW WL & Completion Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr Su bject: Well P2-16 (PTD #1931230) TxIA Comm lof2 7/28/2005 10:46 AM FW: Well P2-16 (PTD #1931230) TxlA Comm Hello Jim & Winton. Well P2-16 (PTD #1931230) has TxlA communication. The IA pressure was bled from 2300 psi to 1820 psi and built back up to 2040 psi. ') ) The well is being swapped from MI to water injection. The plan will then be to secure the well, conduct an MITIA or obtain a leak rate, and evaluate the well for repair. I've attached a wellbore schematic for reference. « File: P2-16.pdf» Please give me a call if you have any questions. Thank you, }fnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 2of2 7/28/2005 10:46 AM Re: Well P2-16 (PTD #1931230) TxIA Comm - Update ) ~~~jec!:..R.e:.·~¢l~.. tg-~9Ç~Jfp#~93.1230).T~~Y()W~.·~···1Jpdat~· ... Ff~m;...J.~.~ê··.·l\eF~i$i~zr~~g@~d~itl··êtate·..~.l.lê.~ . I)~te: ··Mon~·.1·~·..Ju12Q9514;$3:44-08QO ) This well should be on the monthly injector waiver report based on the April 15 notice of TxIA communication (and confirmation that communication is evident even wi th PWI) . Please provide TIO plot for well since April 1; I'm curious why it took nearly 3 months injection (swapped from MI to PWI in early April) to consummate your plan for the well (secure, conduct MITIA/LLR, and evaluate for repair) . Also what is the timing for completion of MITs/LLRTs and repairs? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hi Jim & Winton, We swapped well P2-16 to PWI and determined the well has TxIA communication to Produced water as well as MI. The current plan is as follows: 1. WOE: Have well SI 2. SL: Set TTP 3. FB: MITIA to 2500 psi, LLR if fails. CMIT-TxIA to 2500 psi, LLR if fails. I've attached a wellbore schematic for reference. «P2-16.pdf» Please give me a call if you have any questions. Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, April 15, 2005 7:29 AM *To: * 'AOGCC - Jim Regg (E-mail)'; 'AOGCC - Winton Aubert (E-mail)' *Cc: * Rossberg, R Steven; GPB, GPMA Area Mgr; GPB, LPC DS Ops Lead; NSU, ADW Well Operations Supervisor; Parker, R. Andrew; NSU, ADW Well Integrity Engineer; Engel, Harry R; Reeves, Donald F; NSU, ADW WL & Completion Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr *Subject: * Well P2-16 (PTD #1931230) TxIA Comm Hello Jim & Winton. Well P2-16 (PTD #1931230) has TxIA communication. The IA pressure was bled from 2300 psi to 1820 psi and built back up to 2040 psi. The well is being swapped from MI to water injection. The plan will then be to secure the well, conduct an MITIA or obtain a leak rate, and evaluate the well for repair. I've attached a wellbore schematic for reference. Please give me a call if you have any questions. Thank you, *jAnna Dube/* *Well Integrity Coordinator* *GPB Wells Group* lof2 7/18/20052:54 PM Re: Well P2-16 (PTD #1931230) TxIA Comm - Update ) (907) 659-5102"" (907) 659-5100 xl154* 2of2 *Phone: *Pager: ) 7/18/20052:54 PM ,) TREE = W8.LHEAD = A CtiJi\'f OR; KB. ELEV = äF~mELË\Ï = KOP= "rv1~~,~~ ~m~ Datum MD = Datu m lVD = CIW FMC mmmm, BÄ'KEFfc 53.5' 4341' ,m "m~~~m~,gg,?,?:. 1 0057' 8800' SS 13-3/8" CSG, 68#, NT-80, 10 = 12.415" 1--1 3705' r-JI Minimum 10 = 4.455" @ 9960' OTIS XN NIPPLE 5-1/2" TBG, 17#, L-80, 0.0232 bpf, 10 = 4.892" 1-1 9984' ÆRFORA TON SUI\IIVIARY REF LOG: A TLA S OIUGR ON 09/13/93 ANGLE AT TOP PERF: 43 @ 10126' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz Dð.. TE 3-3/8" 6 10126-10410 0 01/27/94 1 PBID 1--1 10436' 9-5/8" CSG, 47#, NT-80, 10 = 8.681" 1--1 10535' ) P2-16 e 2228' 1--1 5-1/2" OTIS TRSV SSSV, 10 = 4.562" I ~ GAS LFT I'v\ð. NDRELS ST MD NO DEV TYÆ LATCH PORr DATE L 1 4001 4000 5 OllS-LBD T2 2 9848 8702 43 OllS-LBD T2 I . 9888' l-i 5-1/2" PARKER SWS NIP, 10 = 4.562" (ELIVD) 8: Z 9905' 1-1 9-5/8" X 5" TIW HBBP PKR (ELIIJ1D) 1 I I 9943' l-i 5-1/2" PARKER SWS NIp, 10 = 4.562" (ELIVÐ) ! 1 9960' 1--1 5-1/2" OTIS XN NP, 10 = 4.455" (ELMO) 9984' 1-1 5-1/2" 1UBING TAIL, VVLB3 1 9984' 1-1 ELMO Tf LOGGED 01/26/94 1 /' ~~ Dð..1E REV BY COMrvENTS DATE REV BY co MrvENTS 09/16/93 ORlGINA.L COMR.ET10N 11/21/00 S15-51 CONVERTED TO CANV AS 02/22/01 SIS-MD FINA. L 09/15/01 RNITP CORRECllONS PONT MCNTYRE UNIT WELL: P2-16 PERMIT t'o¥J: 93-123 API t'o¥J: 50-029-22397-00 SEC 14 T12N R14E2202.55 ÆL 1976.74 FNL 8P Exploration (Alaska) Well P2-16 (PTD #1931230) TxIA Comm ) ) Subject: Well P2~16 (PTD #1931230) TxIA Corom From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> Date: Fri, 15 Apr 2005 07:28:54 -0800 T~: "AOGCC - Jim Regg (E-mail)..<jim_regg@admin.state;ak.us>. "AOqCC - Winton 'Aubert (E:mail)" <winton_aubert@admin.state.ak.us> ' " , C¢: "Rossberg, R Steven" <RossbeRS@BP.com>, "GPB, GPMA'Area Mgr" , " ' , ,'. ": ",' .', '. <GPBGPMATL@BP~com>~ "GPB,LPC DSOpsLead"<GPJ.3LPCDSOpsLead@BP.com>-,I~~SU; ,., .' AfiJW Well 'Operations Supervisôr" <NSUADWWellÖperatÌonsSupe:rvisòr@BP.com.>,. nparker,·'R. ,.', · A1i.drew" <ParkerRA@BP.com>,I"NSU; ADWWeUInt~grityEhgineer'" '. ., <ijSUADWWèl1IntegrityEngineer<@BP .com>,"Erige~;HarryR".:<E~gelHR@BP . com> , ":Re~ves,. ", Dqnald, F" ,<ReevesDf@Bp.com>",'~NSÚ,ADW WL &Comp~etiQn Supervisor!" , ,.' , <~SUADWWL&Complt~tionSt1pervisot@BP.cöm>, nGPB~:WellSOpfErtg~~.:' . ...:':, ;..' <~PBWells0ptEng@BP.c()fl1>, "~GP:B,: Optiinlz ati on Engr":' <QPBOþtim:iiätlonEngr@J3P{c9m> Hello Jim & Winton. Well P2-16 (PTO #1931230) has TxlA communication. The IA pressure was bled from 2300 psi to 1820 psi and built back up to 2040 psi. The well is being swapped from MI to water injection. The plan will then be to secure the well, conduct an MITIA or obtain a leak rate, and evaluate the well for repair. I've attached a wellbore schematic for reference. «P2-16.pdf» Please give me a call if you have any questions. Thank you, jI nna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SC,ANNED JUt 0 71 2005 Content-Description: P2-16.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/1 0/2005 8: 18 AM ) ') TREE = W8..LHEAD = ïÙjfUi\'foR"';; , KB. ELEV = BF. ElËV"'= KOP;;;: ,~~" ~.~.~.k:! : DatumMD= Datu m TVD = CIW FMC ·...·8Ä··KEFf""(:; 53.5' P2-16 4341' ",.,...,..,...,...¥.,~.,~,~9.??'. 1 0057' 8800' SS e 2228' l-i 5-1/2" OTIS TRSV SSSV, 10 = 4.562" 1 13-3/8" CSG, 68#, NT-80, 10 = 12.415" 1-1 3705' ~ ~ Minimum 10 = 4.455" @ 9960' OTIS XN NIPPLE GAS LFT Mð.NDRELS ST MD lVD DEV TYÆ LATCH PORT DATE L 1 4001 4000 5 OllS-LBD T2 2 9848 8702 43 OllS-LBD T2 I I 9888' 1~5-1/2" PARKER sws NIP, 10= 4.562" (ELM:» :8: Z 9905' 1-1 9-5/8" x 5" TIW HBBP PKR (8..MJ) 1 I 9943' 1--15-1/2" PARKER SWS NIP, 10 = 4.562" (ELI'vD) ! 9960' 1-1 5-1/2" OTIS XN NP, 10 = 4.455" (ELMJ) 9984' 1-1 5-1/2" lUBING TAIL, WL83 1 9984' 1-1 ELMO TT LOGGED 01/26/94 1 5-1/2" TBG, 17#, L-80, 0.0232 bpf, 10 = 4.892" 1-1 9984' ÆRFORA TON SUIVIVIARY REF LOG: ATLAS DIUGR ON 09/13/93 ANGLE AT TOP PERF: 43 @ 10126' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz rnlE 3-3/8" 6 10126-10410 0 01/27/94 1 PBlD 1--1 10436' ~~ 9-5/8" CSG, 47#, NT-80, 10 = 8.681" 1-1 10535' rnTE RBI BY COMWENTS DATE REV BY COMWENTS 09/16/93 ORlGINA.L COMA-ErION 11/21/00 SIS-Isl CONVERlED TO CANV AS 02/22/01 SIS-M:> FINA. L 09115101 RNflP CORRECllONS PONT MCNTYRE UNIT WELL: P2-16 PERMT f\k:): 93-123 API 1\0: 50-029-22397-00 SEC14 T12N R14E2202.55 ÆL 1976.74 FNL 8P Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission P.I. Supervisor TO: Camille O. Taylor (p~ DATE: July 2, 2002 V Chair SUBJECT: Mechanical Integrity Tests BPX Pt. Maclntyre 2 P2-15, 16, 46 FROM: Jeff Jones PBU Petroleum Inspector Pt. Maclntyre Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI P2-15 JTypelnj. J S I T.V.D'. I 88701Tubingl 1200 1120014200 11190 I,nterva, I 4 P.T.D.I 1931540 ITypetestl P ITestpsiI 2218 I Casingl 80 I 23°°1 2290 I 2270 I P/F I P Notes: Pre-test pressures monitored 15 min. & stable. Held press, test extra 15 min. & stabilized @ 2270. WellI P2-16 }Typelnj.I S I T.V.D. 18744 I Tubi.g 11200 ]1200 I~00 I~00 I lntervall 4 P.T.D.I 1931230 Type testI P I Testpsil 2186 I CasingI 220 I 2260 I 2240 I 2240 I P/F I P Notes: Pre-test pressures monitored 15 min. & stable. WellI P2-46 I Typelnj. J S J T.V.D. J8286 I Tubing 14200 14200 I 4200 J4200 J lnterval! 4 P.T.D.I 1931320 Type testI P ]Test psiI 2072 I CasingI 50 I 22901 2260 I 22501 P/F I P Notes: Pre-test pressures monitored 15 min. & stable. F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details July 2, 2002: I traveled to BPX's PM-2 Pad to witness 4 year MIT's on water injection wells P2-15, P2-16 and P2-46 in the Pt. Maclntyre Field. Roland Johnson was the BPX representative in charge of testing today and he performed the task in a safe and proficient manner. The pre-test pressures were monitored for 15 min. and were found to be stable. The standard annulus pressure test was then performed on each well, with all three wells passing the MIT's. The pressure test on well P2-15 was held an additional 15 minutes to further demonstrate integrity, and the test pressure stabilized at 2270 PSI. Summary.: I witnessed successful MIT's on BPX's water injection wells P2-15, P2-16 and P2-46 in the Pt. Maclntyre Field, PBU. M.I.T.'s performed: 3 Number of Failures: 0_ Total Time during tests: 3 Attachments: cc: JUL 3 i 2002 MIT report form 5/12/00 L.G. MIT PBU Pt Mac 2-15,16,46 7-2-02 JJ.xls 7/18/2002 ON OR BEFORE 93 ..... i 23 93 ..... Geolog'~cal blat:-er"-~aJs Znvei"~tor",:/ DATA T DAT/~. .....PLL!S q 9 © ~,. t......T-~p 50 .-~ I n .5 ':'~ 0 '""',t't .... C, I F L · --., . 4.. ~ ......... ,~ ~ ~' .. 407 R ""r'"iqP DATE: 01/77,, DAILY .... WELL' ;'",F' ~~/0~?-16/93 S I,.,i R V E \" "--'"R'"'~. 78 .... 'J 0 a-90., A N A [.":, R I L. i... SURVEY ~78 J0a90: FINAl... i'4WD ~7 0 - i 05 i 6 C B T-- G R ~.8500 -.-- 10 tt 00 ,'-'ET. ......... ..... 3R ~ 00 --- i 0 z,. ~ 3:_ 9~ ..... i 23 P El c, 93 ~ ! 23 PERF 93 '" 'l~-.° .,~' $ S T V. D ~ 9 8 0 0 -'. 'i 0 Lt...,'.-" i ~'790,~ 1040 I I:' ,!t~ ti (.:: J D ,.:.;~ 't: e t [) !! ./' 20/" 95 I:;: U i"..Ii::, A T K..I-.:,' E ,:...: V D I 2/'0 (~/' 'i 9 93 02,,/26 / 19 94 0 2 / 2 ~ ,/" 'i 9 94 'i 'J/r'll/l°9 :~ ,. . :.1 ..... 'i © 06 "19n'" ~'~ 1'/I" . ,rJ i/ i ~':' "i9q3 .::., /,' ... j ';/'()6,' J /. .. ,, . . 'i ;-it/' 06 ,,,' 'l 992~ '1,,/19/" 1993 i 0fl //"'" q 9/ 'l c/4 ,,, . , ~:, 1 0 !!/" 'i 9/" 'l 994 '1 'J/'Jg/199 I '1/ Jg/i993 12/06/ 'I 99 '1 ,2 / 08/ i 9 g Ar"e ,Ji-"y,.d;i'r. ch sarHp les r'eqH-¥r'.ed©; ves~ _And i'"e~ d..:,, yes Was the we'1 1 (;oF'ed9. yes~ ] ys~:4 .x c~e:3cF'.~p'L"ion i"4{~ce'~ red? .","e we]'1 tests r'~qu'i" .... ' ~' ye ~ ,s~~ ,C 0 H H E i',! T S l'l ".) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate __ Plugging _ Perforate __ Pull tubing _ Alter casing __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 27' SNL, 1184' EWL, Sec. 14, T12N, R14E At top of production interval 3045' NSL, 2926' EWL, Sec. 11, T12N, R14E At effective depth 3045' NSL, 2926' EWL, Sec. 11, T12N, R14E At total depth 3300' NSL, 3072' EWL, Sec. 11, T12N, R14E Repair well __ Other X 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x 6. Datum elevation (DF or KB) RKB=51.5' 7. Unit or Property name Point Mclntyre 8. Well number P2-16 9. Permit number/approval number 93-123 /94-205 10. APl number 500292239700 11. Field/Pool Prudhoe Bay/Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: 1 0535 feet 9202 feet Plugs (measured) None. Effective Depth: measured: true vertical: Casing Length Conductor 80' 3655 Surface Intermediate 1O481' Size 20" 13-3/8 9-%" 10436 feet Junk (measured) None. 9130 feet Cemented Measured depth True vertical depth 280 cu ft Arcticset 80' 80' 2777 cuft PF"E"/406 cu 3692' 3691' 919 cu ct Class "G" 1051 8' 9190' Liner Perforation depth: measured 10126-104310' true vertical 8904-9111' Tubing (size, grade, and measured depth) 5-1/2" 17# L80 @ 9984' Packers and SSSV (type and measured depth) Pkr. @ 9906', TRSV SSSV @ 2228' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. 15. Prior to well operation Subsequent to operation Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Mil' 2553 1800 2283 158o n/a n/a 12149 0 16. Status of well classification as: Oil .. Gas k Suspended Tubing Pressure 799 1102 17. I hereby certify that the f,c.r-egging is t~rue,acd,/¢orrect to the best of my knowledge. Signed Even L. Raei[o.-¢_~__~.._.~.~- ~,,~,?.~(JTitle Engineer Form lO-4O4 Rev 06/15/88 Service x SWI Date September 22, 1994 SUBMIT IN DUPLICATE P2,16 Daily Report of Well Operations 06/23/94 P2-16 WIRELINE RAN STATIC BHP SURVEY. P = 4090 PSIA @ 8800' SS 08/27/94 08/28/94 P2-16 STATE WITNESSED MIT COMPLETED, PASSED. P2-16 STARTED WATER INJECTION. ~ ?' Gas Cons, C, or~in~issio.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS61ON Mechanical Integrity Test OPERATOR: Arco AMska thC. FIELD I UNIT I PAD: . ._ Pt.,~ / P2 DATE: P2- f 5 Brine ? 518"/29.7#1N195 COMMENTS: T/~ ~/s ~ commrted to an ~. At the t/me of/Ns rest the w~ was on o//produnlkm. Brine/n arima'us/s 8.5 ~1.44 i~:~,mt. '~ ICOMMENT$: Bt/ne/n Annulua is 8.5 PPO /. ~ gredieM. i I"! _ _P2~O i s_ I_N I. Mw ~l_~. e.~../~?~/N~__ ! ~S I. 2,07;...I ,,~0 l 2.~.00' ! '.~o~O ! 2,MO. t _,.:45_ i ~ I I lCOMMENTS: Brine In Anndu~ t~ fO. 5 ppg / , 5518(Mnt. COMMENTS: · TUBING INJECTION FLUID: P ~ PRODUCED WATER INJ. 8 ,, SALT WATER INJ M = MISCIBLE INd. I = INJECTION N - NOT INJECTING RECEIVED ANNULAR FUJI):, P.P,Q. Grad. WELL TEST: DIESEL 6.8 0.36 Initlad GLYCOL ' 0.00 ' 4 - YeM - · SALT WATER 0.00 WmkovM _ DRILLING MUD ...... 0.00 Other OTHER 0.00 X c- OpemlQr c. DiMbame c - Tffp Rpl Fill c. tnapecl~ .... ¢,~,.¢. Oit & Gas ~' Anchor~ ,~ ,. AOGCC REP SIGNATURE OPERATOR REP SIGNATURE J29HH1BD.XL8 _'~ ch~ .4uo.zo FI-051 (Rev: 3/93) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v~MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-123 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22397 4. Location of well at surface 9. Unit or Lease Name 27' SNL, 1184' EWL, SEC. 14, T12N, R14E Point Mclntyre At Top Producing Interval '~..~ 10. Well Number 3045'NSL, 2926'EWL, SEC. 11, T12N, R14E r v~F'f~- P2-16 fl. Field and Pool At Total Depth Su Point Mclntyre 3300' NSL, 3072' EWL, SEC. 11, T12N, R14E j ~. ~ 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 51.5' I ADL 365548 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 9/2/93 9/11/93 1/27/94I N/A feet MSL I Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10535'MD/9202' TVD 10436' MD/9130' TVD YES [] NO []I None feet MD I 1750' (Approx.) I 22. Type Electric or Other Logs Run CNL/CDL/DLI_/MLI_/GR/MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 280 cufl Arcticset (Approx) 13-3/8" 68# NT-80 37' 3692' 16" 2777 cu ft PF"E"/406 cu ft "G" 9-5/8" 47# NT80-S 37' 10518' 12-1/4" 919 cuft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI Gun Diameter 3-3/8", 6 spf 5-1/2", L-80 9984' 9906' MD TVD 10126'-10410' 8904'-9111' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protected w/131 bbls diesel 27. PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 7/17/94 I Flowing7 Date of Test Hours Tested PRODUC'rlONFOR OlL-BBL GAS-MCF ~/ATER-BBL CHOKESIZE IGAS-OIL RATIO I ]'EST PERIOD Flow Tubing Casing Pressure CALCULATED :31L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. - 1994 /~ska Oit & Gas Cons. Commission Anchora~je Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS fORMATION TESTS NAME Include inlerval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. HRZ 10040' 8841' Kalubik 10079' 8868' Kuparuk 10104' 8887' RECEIVED AUG - 5 1994 Alaska 0il & 6as ~ons. Commission Anch0ra~a0 31. LIST OF ATTACHMENTS 32. I hereby certify lhat the foregoing is true and correct to the best of my knowledge Signed ~~~ TitleOrJllJnclEn_oJneerSuoervJsor Date ~/~///~/~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in~situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspended __ Operation Shutdown __ Alter casing . Repair well __ Plugging ~ Chan~e approved pro~ram x Pull tubi Variance 2. Name of Operator . Type of Well: ARCO Alaska, Inc. Development ___ Exploratory 3. Address Stratigraphic P.O. Box 100360, Anchorage, AK 99510 Service Re-enter suspended well __ Time extension Stimulate Perforate Other 6. Datum elevation (DF or KB) RKB=51.5' 7. Unit or Property name Point Mclntyre 4. Location of well at surface 27' SNL, 1184' EWL, Sec. 14, T12N, R14E At top of production interval 3045' NSL, 2926' EWL, Sec. 11, T12N, R14E At effective depth 3045' NSL, 2926' EWL, Sec. 11, T12N, R14E At total depth 3300' NSL, 3072' EWL, Sec. 11, T12N, R14E ORIGINAL 8. Well number P2-16 9. Permit number 93-123 10. APl number 500292239700 11. Field/Pool Prudhoe Bay/Point Mclntyre feet 12. Present well condition summary Total Depth: measured: true vertical' 10535 feet Plugs 9202 feet (measured) None. Effective Depth: measured: true vertical: Casing Length Conductor 80' 3655 Surface Intermediate 1 0481' Size 20" 13-a/a'' 10436 feet 9130 feet Cemented 280 cu ft Arcticset 2777 cu ft PF"E"/406 cu 919 cu ct Class "G" Junk (measured) None. Measured depth 80' 3692' 10518' True vertical depth 80' 3691' 9190' Liner Perforation depth: measured 10126-104310' true vertical 8904-9111' Tubing (size, grade, and measured depth) 5-1/2" 17# L80 @ 9984' Packers and SSSV (type and measured depth) Pkr. @ 9906', TRSV SSSV @ 2228' RECEIVED JUL 2 8 1994 Alaska 0ii & Gas Cons, Commission Anchorage 13. Attachments Description summary of proposal x Convert well from Producer to Water Injection. Detailed operation program __ BOP sketch __ 14. Estimated date for commencing operation August 1, 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas Suspended Service Water Injector 17. I h,e~eby certify..tJ],a~ the foregoing is true and correct to the best of my knowledge. S ig~~lr''¢'~~ George K. Phillips Title GPMA Sr. Engineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP test Location clearance__ Mechanical Integrity Test/~ Subsequent for required 10- ! Original Signeo A[:)[:)roved bv order of the Commission r,,_..: ..... " -- u~vlu vv. Form 10-403 Rev 06/15/88 ComrfljssiorlCr Approved Copy Returned Date Approval No. SUBMIT IN TRIPLICATe Attachment 1 Conversion to Water Injection Point McIntyre P2-16 ARCO Alaska requests approval to convert Well P2-16 frown an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order 4A. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 10126' and 10410' measured depths This interval correlates with the strata found in ARCO's Point Mclntyre Well No. 11 between the measured depths of 9908' 10665' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED JUL 2 8 1994 Alaska 0il & 6as Cons. Commission Anchorage PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 05/03/94 RUN DATE_RECVD 93-123 DIFL/GR/CN/ZDL D 7350-10530 93-123 SURVEY D FINAL MWD 93-123 BHP 93 - 123 CBT-GR 93-123 CET-GR 93-123 DIFL/GR 93-123 PERF 93-123 PERF 93-123 SSTVD 93-123 ZDL/CNL/GR/CAL 93-123 407 93-123 DAILY WELL OP 93-123 SURVEY 93-123 SURVEY 93-123 5924 L 10070-10516 L 8500-10400 L 8500-10423 L 7350-10530 L 9790-10401 L 9800-10431 L 7350-10530 L 10070-10516 R COMP DATE: 01/27/94 R 9/03-16/93, 01/17-19/94 R 78-10490, ANADRILL R 78-10490, FINAL MWD T OH-DIFL,7350-10530 12/06/93 12/06/93 11/19/93 12/06/93 12/06/93 11/19/93 04/19/94 04/19/94 11/19/93 11/19/93 02/24/94 02/24/94 11/01/93 12/06/93 12/06/93 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial yes ho yes no Comments Date: Subject: From: To: "-~--'.4RCO Alaska Inc. Grear~-eoint McIntyre Engineering April 19, 1994 Transmittal Number ARCO Alaska, Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 720 The following and your cooperation in maintaining confidentiality is appreciated: NK-26 ~INAL DISKE~: MW w/Sub-Surface qq,~r~ Directional Survey P1-17 "/FINAL LOG: Production Profile 1 /FINAL LOG: Perf Record 3 3/8" HSD - 6 SPP 1 P1-21 P2-06 qB--lo P2-06 P2-06 P2-12 P2-12 P2-15 P2-15 P2-15 P2-15 Greater Point McIntyre Area data are enclosed. This information is confidential · '/~AL LOG: Perforation Record 2 1/8" Phased 1 Enerjet ~qAL LOG: Static Pressure Survey 1 Press-Temp-Gr/CCL F]2'4ALDISKETTE: GCT -Surface 1 w/Sug Directional Survey ~/~FINAL LOG: Perf Record 3 3/8" H~, 6 SPF 1 / "~FINAL LOG: Static Pressure Survey 1 Press-Temp-Gr/CCL v~'ZINAL TAPE: DIFL/CN/ZDL/GR w/LIS Ver I ~/FINAL LOG: Sub-Sea Vertical Depth (MWD 1 Directional Survey) INAL LOG: Borehole Profile 1 3-17-94 Anadrill 3-7-94 Schlumberger 2/5/94 Schlumberger 1130/94 1/31/94 Schlumberger Schlumberger 1-7-94 Schlumberger 1/29/94 1129194 Schlumberger Schlumberger INAL LOG: Z-Densilog Comp NEUTRON GR/Caliper 3-5-94 Atlas 3-5-94 Atlas 3-5-94 Atlas Wireline 1 3-5-94 Atlas Well ,Name P2-t5 P2-15 P2-15 P2-15 P2-15 P2-16 P2-16 P2-23 qq.'b2. P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 Data Description '~AL LOG: Dual Induction Focused Log GR/SP FINAL DISKETTE: MWD Survey w/LIS Ver V~FINAL LOG: Cement Evaluation (CET-GR) FINAL LOG: Cement Bond Log (CBT-GR) M~INAL DISKETTE: GCT w/Sub-surface Directional Survey LIS Ver FINAL LOG: Perforating Depth Control Powered Gun GR -~AL LOG: Perforation Record 3 3/8"HJ II, 6 SPF ~/FINAL DIS~K~MWD Survey w/LIS Ver "/FINAL TAPE: DIFL/CN/ZDL/GR w/LIS Ver 1 '/FINAL LOG: Borehole Profile v'~INAL LOG: Sub-Sea Vertical Depth (Directional Drillers Data) ,//FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper '/'FINAL LOG: Dual Induction Focused Log 1 GR/SP "~INAL DISKETTE:~, .MWD~ Survey w/LIS Ver 1 M~INAL DISKETTE: Electronic Multi-shot 1 ,Survey w/LIS Ver ~,/~,FINAL LOG: Cement Evaluation Log (CET-GR) 1 Run # Date Run 3-5-94 3-9-94 3-26-94 3-26-94 3-26-94 1/26/94 1/27/94 3-23-94 2/12/94 2-12-94 2-12-94 2-12-94 2-12-94 2-10-94 2-10-94 3-25-94 Company Atlas Sperry Sun Schlumberger Schlumberger Schlumberger Schlumberger ~Schlumberger ' Sperry-Sun ATLAS Atlas Atlas Atlas Atlas Sperry-Sun Sperry Sun Schlumberger Transmittal Nttmber: 720 Page: 2 o Well Name P2-29 P2-29 P2-30 P2-30 P2-30 Data Description v(" '~AL LOG: Cement Bond Log (CBT-GR) V/FINAL DISKETTE: _Sub_-S~rface Directional Survey (GCT) ~ ',/FINAL TAPE: CH Edit 3 Pass CNT-G with Average Pass w/Ver List dFINAL TAPE: CH Edit TDTP 3 Passes and Average w/Ver List LOG ' C.~'X'- C= ] ~C.. /FINAL LOG: TDTP Depth Corrected Run # 1 Date Run 3-25-94 3-20-94 1-8-94 1-8-94 12-8-93 Company Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P2-31 P2-31 P2-31 P2-31 P2-31 P2-31 P2-42 P2-42 P2-42 P2-42 P2-42 /FINAL DISKETTE: MWD w/Sub-Surface Directional Survey f-~ qFT~o~AL4..~D~TTE: Electronic MultiShot w/LIS v~FINAL LOG: Sub Sea VD (Multi-shot Directional Survey) ----/FINAL LOG: Dual katerolog/GR/SP FINALLOG: Borehole Profile ~//FINAL LOG: Z-Densilog/CompNeutron/GR/Caliper . '~AL LOG: Dual Induction FoCUSed Log/GR/SP "/'FINAL LOG: Formation Multi-Tester/GR V/FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) V/FINAL LOG: Z-Densilog/Compensated Neutron/GR/Caliper /FINAL LOG: Borehole Profile 04-O8-94 4-10-94 4-10-94 4-10-94 4-10-94 4-10-94 119194 1/9/94 1/9/94 1/9/94 1/9/94 Sperry Stm Sperry Sun Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Atlas Atlas Atlas Atlas Transmittal Number: 720 Page: 3 Well Name P2-42 P2-51 P2-51 P2-51 P2-57 P2-57 Data Description dlNAL DISKET~p:o~D Survey w/LIS Ver v/F~AL LOG: TDTP Depth Corrected L_t>~'. C~'I;-~ l 'M~INAL TAPE: CH Edit 3 Pass TDTP w/Average Pass w/Vet List ¢INAL TAPE: CH Edit 3 Pass CNTG and Average w/Ver List LOG: 2.5" CNT-~Depth Corrected FINAL TAPE: CH Edit 2.5 CNT-D 3 passes w/Average w/Ver List Run # Date Run Company 1/8/94 Sperry-Sun 1-11-94 1-11-94 1-11-94 11-14-93 11-14-93 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Please sign Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal Number: 720 Page: 4 STATE OF ALASKA - ALASKA UlL AND GAS CONSERVATION CO~viMISSlON WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classilication of Service Well OIL [] GAS [] ~ [] ABANDONED [] SERVICE E~ Water Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-123 3. Address 9. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 ? ........... .,~ 50- 029-22397 4. Location of well at surface ,~ ~._L~,.'..'7-~ ti; ~:¢~ i9. Unit or Lease Name ,, ~- .~ Point Mclntyre Well Number At Total Depth ............... ~:;~ Point Mclntyre 3300' NSL, 3072' EWL, SEC. 11, T12N, R14E 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. KBE = 51.5' I ADL 365548 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 9/2/93 9/11/93 1/27/94I N/A feet MSL ! Zero '~7. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost 10535'MD/9202' TVD 10436' MD/9130' TVD YES [] kO []! None feet MD ! 1750' (ADprox.~ 22. Type Electric or Other Logs Run CNL/CDI_/DLI_/MLL/GR/MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENT~qG RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 280 cuft Arcticset (Approx) 13-3/8" 68# NT-80 37' 3692' 16" 2777 cu ft PF "E"/4o6 cu ft "G" 9-5/8" 47# NT80-S 37' 10518' 12-1/4" 919 cuft C/ass '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 (MD) Gun Diameter 3-3/8; 6 spf 5-1/2; L-80 9984' 9906' MD TVD .. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED Freeze protected w/131 bbls diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not yet injecting N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MOF WATER-BBL CHOKESI ZE IGAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure 3ALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. -g,'~cSr~rag¢ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. , GEOLOGIC MARKERS F-~.~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. HRZ 10040' 8841' Kalubik 10079' 8868' Kuparuk 10104' 8887' 31. LIST OF A'I-rACHMENTS I hereby certify that the-fore.c~3ing is true and c~rrec~r' .to the best of my knowledge Signed- --' ' i~ Titl DrillinaEnaineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. R E 6 E IV E D Item 28: If no cores taken, indicate "none". Form 10-407 FEB 2 4 BP/~AI SHARED SERVICE WELL: P2-16 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 09/02/93 12:00 SPUD: 09/02/93 09:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 09/03/93 (1) TD: 925'( 0) 09/04/93 (2) TD: 3420' (2495) DRLG. MW: 8.8 VIS:217 MOVE RIG. RIG ACCEPTED @ 1200 HRS, 09.02/93. N/U DIVERTER. TEST SAME. P/U BHA. SPUD WELL @ 2100 HRS 09/02/93. DRIL TO 925'. DRILLED TO 3420' MW: 8.8 VIS: 0 DRILLED TO 2472'. CIRC. POOH. R.I.H. DRILLED TO 3420'. 09/05/93 (3) TD: 3705' ( 285) 09/06/93 (4) TD: 3715' ( 10) 09/07/93 (5) TD: 5345' (1630) 09/08/93 (6) TD: 6180'( 835) 09/09/93 (7) TD: 7740' (1560) N/D DIVERTER MW: 8.8 VIS: 0 DRILLED TO 3705' SHORT TR~P TO 2500'i CBU. POOHi STAND BACK BHA. R/U RIH W/13-3/8 CSG TO 3695'. cImc & COND MUD. CEMENT W/75 BBL. H20. 498 BBL LEAD 72 BBL TAIL DISPLACED W/536 MUD. RECOVERED 40 BBL CMT RETURNS @ SURFACE. CIP @ 8500 2000 PSI. N/D DIVERTER. DRILLING @ 3715' MW: 8.8 VIS: 0 N/D DIVERTER MOVE TO SIDE. TOP JOB W/140 SX. N/U WELLHEAD. N/U AND TEST COMPLETE BOPE/CHOKE/GAS DETECTION SYSTEM. SET WEAR RING. RIG UP DRILL PIPE HANDLING TOOLS, SET WEAR RING. P/U BHA. BHA COMPLETE @ 2430. L/D 5 JTS HWDP. RIH TO F/C @3605'. CIRC & CONDITION MUD. TEST CASING TO 3000 PSI. DRILLED F/C, CEMENT, F/S AND 10' NEW HOLE TO 3715'. DRILLING @ 5345' MW: 8.8 VIS: 0 CIRC BTM UP. FIT TEST TO 13.66 PPG. DRILLED & SURVEYED 3715' TO 4871' CBU. SHORT TRIP TO 3500' DRILLED & SURVEYED 4871' TO 5354' DRILLED TO 6180' MW: 8.8 VIS: 0 DRILLED TO 5523'. CIRC. POOH. CHANGE BHA. RIH. DRILLED TO 6180' DRILLED TO 7740' DRILLED TO 6735' MW: 8.8 VIS: 0 CIRC. POOH RIH. DRILLED TO 7740' 09/10/93 ( 8) TD: 8593' ( 853) DRILLED TO 8593' MW: 8.8 VIS: 0 DRILLED TO 8043'. ROP. CIRC. POOH. PULLED BHA. BOPE. MADE UP BHA. R.I.H. DRILLED TO 8593' RECEIVED WELL : P2-16 OPERATION: RIG : POOL 7 PAGE: 2 09/11/93 (9) TD:10120' (1527) 09/12/93 (10) TD:10490' ( 370) 09/13/93 (11) TD:10535' ( 45) 09/14/93 (12) TD:10535 PB: 0 DRLG TO 10120' MW: 8.8 VIS: 0 DRILLED TO 8972'. CIRC. SHORT TRIP 11 STDS. R.I.H. DRILLED TO 10001' CIRC. SHORT TRIP 11 STDS. R.I.H. DRILLED TO 10120' RAN ELECTRIC LOGS DRILLED TO 10490' R.I.H. TO 10490' MW: 8.8 VIS: 0 CIRC. TEST SURFACE EQUIPMENT. POOH. POOH. BHA LAID OUT. RAN ELECTRIC LOGS. RAN ELECTRIC LOGS MW: 8.8 VIS: 0 RAN ELECTRIC LOGS. MADE UP BHA. R.I.H. TO 3800'. SERVICED DRILLFLOOR/DERRICK. R.I.H. TO 9466'. REAMED TO 10490. DRILLED TO 10535'. CIRC. POOH. PULLED BHA. BHA STOOD BACK. RAN ELECTRIC LOGS. POOH. MW:10.3 WBM LOG RUN: RESIST/GR. LOG RUN: DENS/NEUT. R/D ATLAS. RIH W/ BHA. CIRC. SHORT TRIP 13 STDS. CBU. POOH. 09/15/93 (13) TD:10535 PB: 9202 TEST CASING MW:10.3 WBM POOH. PULLED BHA. TEST BOP. RUN CASING 9-5/8" IN O.D. CIRC. MIXED & PUMPED SLURRY 160.000 BBL. DISPLACED SLURRY - 764.000 BBL. PLUG BUMPED. TESTED CASING. 09/16/93 (14) TD: 0 PB: 0 MOVE RIG MW:10.3 WBM TEST CSG TO 4000 PSI. OK. ATTEMPT TO SET PACKOFF. N0 GO. RIH W/ RTTS PKR. SET @ 2200'. N/D BOPE. SET SEAL ASS'Y. N/U BOPE. POOH W/ RTTS RKR. DISP TOP 2200' W/ DIESEL. N/D BOPE. N/U TREE, HGR. 1 JT TBG. TEST TREE. OK. DISP HOLE W/ DIESEL. SECURE WELL. RIG RELEASED @ 0530 HRS., 09/16/93. MOVE RIG SIGNATURE: /: (dri'll~ng su-perintendent ) DATE: BP/2~AI SHARED SERVICE WELL: P2-16 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 01/16/93 02:00 SPUD: RELEASE: 01/18/94 12:01 OPERATION: DRLG RIG: WO/C RIG: DOYON 14 01/17/94 ( 1) TD:10536 PB:10436 01/18/94 ( 2) TD:10536 PB:10436 RUN COMPLETION MW: 0.0 ACCEPT RIG 1-16-94 @ 1400 HRS. ND, NU BOPE. PULL & LAND TBG, TEST BOPE. RIH, DISPLC DIESEL, POH. RU TO RUN COMPLETION. RUNNING COMPLETION MW: 0.0 CONT TO RUN COMPLETION. PULL & LD DAMAGED JTS. RE-RUN COMP STRING. 01/19/94 ( 3) TD:10536 PB:10436 RELEASE RIG MW: 0.0 CONT TO RE-RUN TBG. ND, NU & TEST CONTROL LINE. TEST TREE. PUMP CELLAR & INSTL BPV. RELEASE RIG 1-18-94 @ 2400 HRS. SIGNATURE: (drilling superintendent) DATE: RECEIVED PAGE NO, COmPAnY PRUDHOR BAY DR!LLIN~ W~ NAME P~-~6,~4 LOCAT!O~ ! POINT '~P^"Ow ~ H~Bi ALASEA ~A~H:TIC t0~ ~,i2 D£CLINAT ~' WELL HUMBER 0 WELL HEAD LOCATION: LAT(N/-S) 0,00 DEP(E/-~) 0,00 A7~'I~- ,n~ ~ _~,'~n FRm: ROTARY TABLE TO TARGE? IS =z,54 TIE tN POI~T{~ : MZA?URED DEPTH 0,00 T="'~ VE~T D~PTH 0.00 nU~ .. ~b~!N~.tO~ 0,00 LATiTUDE(~/-S) 0,0~ PAC. E HO, DEPTH DEPTH ~t ft 0.00 0,0 0,00 78.75 7~.8 78.74 148,04 69,3 148,02 241,50 93,5 297,60 56,1 2?7.54 38S,53 478,70 568,28 659,!3 745,07 836,11 925,8! 1018,08 1110,40 L203,00 1290,32 1383,70 !477,43 157!.09 !66S,79 i853,69 1947,!5 2036,83 2!27,57 22!7.57 2311,77 2405,0! 2673,22 2764,30 2856,12 £747, 3038,47 341i,35 3503,49 90.9 388.47 90.2 478.63 89.6 56~.20 90.9 659.06 85.9 744.96 91.0 835.94 89.7 92.3 10!7.81 92.3 !I!0.07 92,6 !202,59 87,3 93,4 1383,17 93,7 !476.84 93,7 !570,44 97,7 1668,11 o~ ~ !760.nA 92.9 !852.95 89.7 90,7 212~ 90,0 22!6,8i 94,2 23i!,00 93,2 2404,24 84,3 2488,5t 9!.0 2579,48 93,0 2672,43 9!,1 2763,51 9i,8 2855,32 93,3 2945.59 89,1 3037.67 95,5 3;J3,i7 89,8 3222,96 96,0 3319,00 91,. ~ 3410,54 92,1 35(!2,67 SUrVeY CALCLiLATID~S CIRCULAR ARC ~A~u~ A~IMu~H LATITUDE ft deg deg ft 0,00 0,00 0,00 0,00 -0,7I 1,31 250,00 -0,3! -1,93 !,38 255,39 -0,79 -3,39 1,!0 255,59 -!.30 -4 ^~ ~ ,73 ,~¢ 0,~ 264 z,47 -4,94 0,64 242,40 -1,78 -5,6! 0,61 271,64 -2,00 -5,90 0,18 280,t0 -i.96 -5,18 0,99 37,30 -1.3! -2,85 2,I7 44,35 0,44 , ~-!6114 ft ft 0,00 0,00 -0,85 -2,40 2,53 -4,36 4,55 -5,34 5,54 AZIMUTH 0.00 250,00 251~78 · 2J~,42 254.57 DLS deq/ iOOft 0,00 1.67 0,2! 0,39 ¢/,85 0,5! i~*~, 34. 23,88 33,43 41,09 54,46 0,19 37,29 0,48 I76,71 23,13 33,58 40,78 55,44 0,15 36,70 0,37 !77,67 22,42 33,62 36,16 0,50 !70,92 2!,74 33,69 40,10 57,/7 0,16 35,62 0,51 155,50 20,97 33,93 39,8E 59,28 0,15 3~,00 0,57 98,77 25,61 30,91 40,14 50,36 ©,24 3~,23 0,57 11~,00 ""~',36 31,77 ,,0,¢.¢ 5i,zl 3¢,30 0,24 !20,91 25,07 32,35 40,93 52,23 38,33 0,27 112,43 24,8? 32,72 41,11 52,74 0,04 98,25 0,40 143,49 24,56 32,10 41,21 53,43 0,25 34.74 0.61 77.05 24.6? 26.!~ 35.99 46.67 0.20 35.49 0.67 75.97 24.95 27.20 36.?! 47.47 0.06 36,20 0,54 75,73 25,!9 28,15 37,77 49.17 0,14 36.78 0.57 76,07 25,39 28,94 38,50 48,74 ¢,03 jy,4x v,6u 80,54 25,59 29,9i 3¥,36 49,45 0,14 29,44 1.65 53,86 21,52 2!,21 30,22 44,59 0,27 31,29 0,93 ~:4..,¢¢~ ~z,6.~ * 22,~ ........ ¢=, 24 ~,47,. o,. 83 32,51 0,74 37,57 23,39 24,04 33,54 45,79 0,49 .~q,46 v,¢:~ ~' 53,56 24,08 2~,72, :,.¢;~' "' 45 ,75 n~. 32 !6,41 2,i3 53,43 14,19 8,25 16,42 30,17 0,36 !9,45 !,92 56,!4 16,!0 !0,95 19,47 34,21 0,24 o: 2,07 62,92 ..~?,75 13,?A .. 22 , ~ ,. 37,79 . 0,25' 24,82 1,6! 68,45 ' 19,00 16,49 25,16 40,96 0,52 27,10 1,6i A?,99 ..... 20,14 :S,99 ~,6& 43,32 0,17 0,35 1,95 42,36 2,82 -3,92 4,83 305.66 0,26 3,22 1.82 45,79 4,94 -1,88 5,2~ 339,19 0,19 6,29 2,1I 45,72 7.!4 0,39 7,15 3,12 0.3! 9.63 2,17 45,89 9,54 2,86 9.96 16,67 0,06 i3,17 2,39 48,?8 12,03 5,57 I3,26 24,86 0,28 -6,54 6,7~ 254,80 0,48 -7,47 7,73 255,03 0,35 -8,09 8,32 256,39 -7,76 7,87 260,42 !,19 -6,17 6,19 274,10 1,39 MEASURED .iNTERVAL VERTICAL DEPTH DEPTH ~¥o.1i 94,~ 3597,2? ~ ~ 35 ' 3632,~4 3743,27 109,6 3742,43 3785,31 42,0 3754,47 ************* ANADRiLL **~*********** SURV~f ........... GR~uV~RI~U,~ ************* CIRCULA~ ARC TARGET STATION AZIMUTH LATITUDE SECTiO~ INCLN, N/-S ft ~mg deg ft 35,!i 0,85 145,5i 20,0! 34,69 0,?2 144.78 i9,56 34,33 0,75 13~,62 18,3! 34,17 0,85 !37,24 17,~7 34,5~ !,44 ~0,70 17,64 DEPARTURE DISPLACEMENT at AZIMUTH ft ft deg 34,8i 39,93 60,66 35,7? 40,20 62,91 36,16 40,36 63,71 39,35 41,30 64,71 DLS deg/ lOOft 0,38 0,20 0,17 0,24 1,~0 3~76,49 3?69 ~ 4!54,2~ 4246,17 4340,79 4617,3! 4711,58 24,5 3875,63 92,7 3965,20 94,! 4062,04 9!,(~ 41J~,s~ ~ ~ 424E,SA ?2,6 4336,~? 90,5 4514,49 94,5 4605,29 94,3 4695,!6 35,07 1,5! 56,72 17,fi7 37,92 41,92 64,77 2,51 38,94 3,45 3~,9! 20,65 40,73 45,6S 63,05 2,2! 46,!5 5,41 37.62 26,36 45 ~= 52,37 59,77 2.09 ,. 55,65 6,62 q~,04 3~,0o ~n,8° 61 ~ 56,20 1,36 6~,3I 8,~9 31,67 44,66 57,80 73,04 52,30 2,47 83,72 !0,26 32,27 57,73 ES,~E. 67,6~ t02,00 !2,82 28,74 73,50 75,22 !05,17 123,5~ 14,82 27,93 ?2,52 ~5,50 125,97 149,51 I7,!0 26,90 115,60 97,~5 151.20 177,85 I~.05 25,64 I41,13 110,07 175,9~. 4~,81 45,66 42,74 40,I3 37,95 !,4~ 2,8.9 2,23 2,44 1,0~ 4S97,34 4989,72 5052,90 94,8 47M,73 90,9 4869,02 92,4 4953,!7 93,2 5036,94 92,9 5t:o.~i ,~..- ~6,:.. .6~, i23,67 209,51 20~ ~ 20,28 ~ ~q i ,. i! 2~2,79 23,73 27,82 !97,44 139,1E 2~3,20 ,5, '~ 2~!,06 280 ~ 24.99 27,67 233,~3 ' ~ 321,55 26,95 29,0~ 'x~ 9~ Z.~, 17~ 321,69 3A~,37 ~e .~ 27,i0 307,74 !97,09 .- ~l ,~/ 36,16 34,91 33,95 33,26 32,64 2,36 3,86 1,36 2,1~ 2,89 J64,!4 5455,17 5544,08 5636,80 95,~ 5201 ~ · J£Y , , 9i,0 5354 ~" 88,9 5425,~2 92,7 s499 ~" 413,22 30,97 26,49 350,60 2!S,72 413,23 ,,'4,.~ 395,20 239,95 462,34 462,33 33,26 " 5!4,33 36,79 27,8.0 442,05 263,02 514,39 ~ ~ ~ . ... ..... 567,60 36,9~, ,'?,-.'..; 1 488,98 ·" ..... 536 6.,-~,A2 ":'-',58 .'-.:.,48 ,A? 3!4,53 623,77 31,96 31,26 30,75 30,S3 30,25 1,61 2,72 4,40 0,85 1,76 ~, .9 ~ 5~20,!7 60!3,23 oo,1 5573,,~ 96,1 5649,10 94,2 5723,i0 93,1 5795,87 680,28 37,~A 27 ~ ~A9,36 340,=~ 680,53 - 738,94 37,81 27,8? 641,48 367,50 739,29 797,i5 38,65 29,~2 692,62 395,45 797,56 855,10 3~,46 2~,06 743,22 423,7? 655,56 910,53 ~ 24 27,~9 792,12 4JO,~y g11,06 ~0,00 29,81 29,72 27,67 29,61 0,56 0,39 1,35 0~ !,I! 6!96,53 i~o 83 6384,0? 6475,07 93,8 5?39,80 93,3 6013,37 94,3 6087,26 9!,0 6157,53 93,5 6229,28 ?68 os 3~,12 ~/,21 476 9~o0C ,~. "' 843,61 ,79 ...... 1025,66 37,~2 29,=° 894,05 504,12 !026,3A i054,i2 36,93 28,42 945,17 532,5¢ 10.E, 4,6f 1i41,86 39,94 29,89 995,63 560,75 1142.68 _~,,7~ 37,80 25,57 1047,92 590,01 1202,A0 2?.47 29,42 29,40 29,39 0,23 !,75 1,50 :,51 0,72 6659,09 6757,48 6850,86 6944,63 7035,38 90,5 6298,72 98,4 6374,34 93,4 6446,53 93,$ '~s" .'.7, i4 90,8 6588,82 1259,77 40,02 30,01 1098,58 618,43 1260,68 lq~.~7 ~",~4 28,72 1153,44 649,30 1323,63 1381,82 39,20 28,32 !205,48 677,59 !382,86 144~,i0 37,31 30,25 ~' ^' * 1,~/,22 7vo,6! I442,19 ~9~,16 40,38 27,25 !308 20 734 =A lSO0 32 29,38 29,38 29,34 29,34 29,31 !,05 0,97 0,45 1,3! 2,43 PA~ NO. ~ASURED IH?ERVAL VER?iCAL DEPTH ~PTH 7128,76 ~,4 o66v,~ 722i,76 93,0 6730,89 7314.83 93,I 680i,~7 7407,65 92,~ 6~72.~8 7594,22 76~9,67 7779,~2 7876, * ~4 7970,09 8056.95 8!52,72 ~336,60 ~433,74 8523,99 8616,60 ~712.67 8~07,04 8995,15 9086,57 9177,89 9270,12 9363,7~ 9455,36 9554,09 9647,80 9742.69 9835,76 9928~27 !0!18 q~ 102!2,2i 10304,22 10399.33 10421,22 10490,00 ?ARGO? STATION AZ!MU?H SEC?ION !NCLN, ft deg deg I559,48 40,26 29,40 !6i~,J,~° 40,4~ .... 2~,8A 1679.69 40,i7 2~.32 !739,35 40,01 27,1i 179~,97 39,~4 28,4~ ¥o,s 701x,6x 1858 x~ ........ ,~ 3~,82 26,64 95,4 70~9.2! 19!9,60 40,1! 27,30 90,2 7155.32 1977,51 39,79 26,88 94,0 7303,08 2i00.80 40,85 30.52 8A,9. .~.~?~a~,93 ~.~157,45 40,56 jl,46_ 95,8 744i,50 22!9,93 40,89 3!,49 93,2 75~.vj 2280, 40,77 31,08 90,6 7580,53 2340,27 41.0~ 30,70 97,1 7653.74 2404,12 41,II 31,33 90,3 772!,63 2463,58 41,32 30,53 92,6 779!,09 2524,83 41,50 30,48 96,1 7863,1i 2588,40 4!,36 30,16 94,4 7933,85 2650,83 41,50 30,07 94,8 8004,72 2713,80 4i,75 30,64 93,3 8074,27 2775,97 4!,84 30,28 91,4 8142.34 2837,00 4!,92 3!,i2 9!,3 82i0,t5 289~,!5 42,19 30.64 92,2 ~o~ 12 , .. ~,o,45 2960, 42 25 30.4~ 93.7 8347.~ ~^~" ~v~,i~ 42,~1 30,6i 94.6 8417.37 95,7 8487,69 93,7 8556,27 94.9 8625.50 93,i 8693,34 92,5 6760,52 93,A v~ ~ 8966.~7 95,t 9103,33 ~,9 9119.32 6~,~ ~i69.60 r~'16/I4 LATiZUD£ D[PAR?UR~ DtSPLACE~E~? at AZIMU?H N/-S E/-W ft ft ft de5 !a6~,38 763,22 !560,72 29.28 I4!4,47 791,62 I.~u,92 2~,23 1467,59 ~19.97 !66!,I2 29,!9 1520,25 8~8,23 I740,8~ 29,16 1573,12 876,09 !800,62 2~,11 DLS ~e~/ lOOft i,77 1,72 i,54 0,96 1626,19 903,78 1860,46 29,06 1,26 i680,83 931,58 192!.72 29,00 0,54 1732.36 957,9~ 1979,5~ 28,94 0,46 1787,40 966,86 2041,74 28,90 1,40 1840,73 1017,08 2103,03 28,92 1,40 1889,30 1046,24 2159,65 28,98 1942,58 I078,87 2222,07 29,05 I994.68 1i10,52 2282,98 29,11 2045,65 1141.0~ 2342,3~ 29,15 2100,37 !!73,9t 2406,16 29,20 2151,38 1204,47 2465,60 29,24 2204,i6 1235,56 2526,84 29,27 2259,04 1267,66 2590,42 29,30 2313,07 1299,00 2652,86 29,32 2367,41 1330,83 2715,83 29,34 242!,01 1362,35 2778,00 29,37 2473,49 1393,51 2639,02 29,40 2525,99 1424.90 2900,16 29,43 2579,37 1456,39 29E2,13 29.45 2633,70 1488,43 3025,19 29,47 3152,07 42,77 30,17 2744,94 32!5,92 43,15 30.38 2800,09 3280,79 43,13 q' "~ ... 3344,~2 43,32 29,7~ 29il,33 3406,06 43,51 30,40 2966,35 3474,41 43,61 29,t8 3023,96 3538,94 43.43 29,47 3080,26 3603,!9 43,09 29,47 3!3~,24 3666,00 43,07 29,50 3190,95 0,78 0,34 0,32 0,44 0,43 0,62 0,20 0,26 0,14 0,46 0,28 0,62 0,46 O,!E 0,22 ~7J0,94 43,11 ~v,OJ 3247,35 37~5,89 43,05 30,27 3260,27 3792,60 43,00 30,30 3300,79 1841,65 3733,22 29,56 0,40 1849,16 374~,17 29,56 0,77 ~,~J,05' 29,57 0,0~ 1682,22 3410,!4 29,56 0,53 17!5,20 3476,52 2i,56 0,8~ 1746,83 35~1,10 29,56 0,29 177~,~ ~^~ . ..... ~,40 29,5~ O,°7 1809,39 3668,24 29,~5 0,03 1520,8~ 30~'i',14 ~,~ 49 0,3!. 1~ ~° ~54,10 29,51 0,14 15~5,7~ 32';~ 1618,~."~ 3282,A3. 29,54 0,11 PAgE NO~ ********* SCHLOMBERGER *********************************************************** SURVEY PRO~RAM *****~**** COMPANY PRUDHO~ BAY DR!LLINO WELL NAME ~ ~ LOOAT!O~ ! POINT ~CINTYRZ LOCATION 2 NSB~ ALASKA ~"~'~' O~ 30, WELL NUMBER 0 WELL HEAD.:or~xnN:~,:,...:. LAT(N/-S) O,^^vv DEP(TM., -~"' AZIMUTH PROM ROTARY TABLE TO TARGET IS 31,56 TIE IN POiNT(TiP) : ..~A~UK;~ DEPTH 0 TRUE UERT DEPTH 0,00 iNCL!NAT!OE 0,00 AZIMUTH 0,00 DEPARTURE(E/-W) 0,00 0o00 PAGE M~ASUR~D INTERVAL VERTICAL DEPTH ~r ....... ~ ~ ~t ~t 0,00 0,0 0,00 78,75 78,8 78,74 148,04 69 3 i48 n~ , 24!,50 93,5 241,45 297,60 56,i 297,54 ~,~ 90,9 388,47 478,70 90,2 478,63 568,28 89.6 568,20 659,!3 90,9 659.06 745,07 85,9 744,96 836,1I 925,8! 10!8,08 1110,40 1203,00 1290,32 !477,43 157!,09 1668~77 !853,69 203~-,83 2127 ~.? 2217,57 23!.1.77 24~?,27 25~0,27 2673,22 2764,30 2949,39 3038,47 3133,97 3223,77 3319.~I 341i,35 3503,49 91,0 835,94 89,7 925,59 92,3 I0!7,8I 92,3 !I!0,07 92,6 !202.59 87,3 12~?,84 93,4 1383,17 93,7 1476,~4 93,7 !570,44 97,7 1668,1i 92,0 1760.08 92,9 1852.95 93,5 1946,40 89,7 2036,07 90.7 2126,81 90,0 22!6,6i 94,2 23it,00 93,2 ~ ^' 84,3 2488,51 9!,0 257~,46 93,0 2~72.43 9!,8 2855,32 8~,1 3037.67 95,5 3133,i7 89,8 3222,96 96,0 3319,00 91,5 3410,54 92,1 3502.67 ~,,~°:~"~v. CALCULATIONS **~*******~ CiRCU~A~ ARC ~A~u.z ~.,,.e?6~TnU_~,, AZIMUTH LATITUDE ft deg deg ft 0,00 0,00 0,00 0,00 -0,7i 1,31 250,00 -0,3! -1,93 1,38 ~_.,~S~ 39 -0,79 -3,39 !,!0 255,57 -1,30 -4,05 0,95 264,73 -t,47 , ,'-!6/I4 ...... ;~,,~. DISPLACEMEHT at AZIMUTH ft ft deg 0,00 0,00 0,00 -0,85 u.90 2~,00 -2,40 2,53 251,78 -4,36 4,55 253,42 -5,34 5,54 254,57 deg/ 1OOft O,O0 1,67 0,30 0,39 -4,94 0.64 242.40 -1.78 -6,54 6,7~ 254,80 0,48 -5,6! 0,6! 271,64 -2,00 -7,47 7,73 255,03 0,35 -5,90 0,18 280,10 -I,96 -$,09 8,32 256,39 0,4~ -5,!0 0,99 37,30 -1,31 -7,76 7,87 260,42 !,19 -2,~ ~,17 ~,35 0,44 -~,17 6,1o ~J ..... 274,10 1,39 0,35 1,95 42,36 2,82 -3,92 4,83 305,66 0,26 3,22 1,62 45,7? 4,94 -t,88 5,2~ 339,17 0,19 6,29 2 ,l . ~ ~ ,~. 45,72 7,14 n,39 7,!5 J,12 0,3! 9,63 2,17 45,89 9,54 2,8~- 9,96 16,67 0,06 i3,i7 2,39 48,98 12,03 5,57 13,26 24,86 0,28 ~.~k,41 ~,i~ %,4~ I4,19 8,25 I6,42 30,17 0,3_x i9,45 1,92 56,14 I6,10 !0,95 19,47 34,21 0,24 22,q~ ~,07 x2,92. ..~7,7~. ~o'~,76 22,~~, ~7,7~. . 0,29 24,82 1,6! 68,45 19,00 16,49 25,/6 40,76 0,52 27,10 i,6~ 62,55 20,14 i~,97 27,6~ 43,32 0,17 29,44 1,65 53,86 21,52 21.2i 30.22 44,59 0,27 32,51 0,74 37,57 23,39 24,04 33,54 45,79 0,49 33,4x 0,51 ~3,% 24,0B ~J,72 ~" ~, 45 ......2~.i? n,45 68 =/~ 24,46 2s,38. 35,o~_. ~x....,¢~.q~0,15 34,74 0.6! 77.05 24,69 26,!~ 35,99 4~,67 0,20 35.49 0,67 75.37 24~95 27,20 36,91 47,47 0,06 36,20 0,54 75,73 25,!9 2~,15 37,77 4S,17 0,14 36,78 0,57 76,07 25,39 28,94 38,50 48,74 0,03 37,46 0,68 80,54 25,59 29,91 39,36 49,45 0,14 38,00 0,57 98,77 25,61 30,91 40,;4 50,36 36,23 0,57 !14,00 25,36 3!,77 40,~ 5!,4! 38,30 0,24 !20,9! 25,07 32,35 40,~3 52,23 ~ ~ 0 ~' 1i2,43 24,89 32,TM * ¢~ ..... ,~/ · 41,1, 52,74 38,25 0,40 143,49 24,56 33,10 41,21 53,43 0,24 0,16 0,36 0,04 0,25 3~ ~ 0,5! lt.I,34 23,88 33,43 41,09 54,46 0,19 37,29 0.48 176,71 23,I3 33,50 40,78 55.J4 0.15 36,70 0,37 177,67 22,42 33,62 40,41 56,30 0,11 36.i6 0,50 !70.92 2!,74 33,69 40,~0 57.:7 0,16 '~..J, 62 n,51. 155,5o. 20,97 33,9~ ~'~', 6E _s~=.26 Alaska Oil & C-'as Cons. Co~.-nmission Anchorage ..... ~!CAL MEASURED iNTERVAL vEm~ DEPTH DEPTM ft f~ ft 3598,!i ?4.6 9597.29 3633,67 35,6 3632,84 3743,27 109,6 3742.43 3785,31 42,0 3784.47 3~r~ .. · -~,96 AA,6 3851,!i ************* ANADRILL **~*********** SURVEY CALCULATIONS ************* CIRCULA?i AR5 METHOD******** ~A%~T STATION A~I~;~?H L~?iTUD~ SECTION !NCLN. N/-S ft deg deg ft 35,ii 0,85 145,51 20.0! 34.89 0,S2 144.78 19~56 34,33 0,75 138,62 18,31 34.17 0.~5 137,24 17.87 34,58 !,44 80.70 17,64 : .'-!6/14 DEPARTURE DISPLACEMENT at AZIMUTH DLS E/-W deg/ ft ft deg IOOft 34,50 39,8~ 59,~ 0,38 34.8i 39,93 60,.56 0,20 35,79 40,20 62,91 0,17 36,18 40,S6 63,71 0,24 ~.q~ ~,30 64,71 1,AO 4uo~,27 4!54,28 4248,17 4340,79 4432,26 4522,77 46!7,3! 47ii,5~ 24,5 3~75,63 92,7 3965,20 74,~ 4062,04 91.0 4 ~ 5~ 93,9 4245,56 92,6 ..,5 4426,51 90,5 45!~,40 94,5 4605,29 94,3 46~5,!6 35,07 1,51 56,72 17,87 38,9< 3,45 39,9! 20,68 46,!5 5,41 ~,~, ~:.z~ 26,36 55,65 6,62 35,04 34,06 68,31 8,89 31,67 44,66 8~,72 i0,26 ~ ~' s7 7~ t02,00 12,82 28,94 73,50 123 ~ 14,~ 27,~ q?,52 149,51 I7,i0 26,90 115,60 37,92 41,92 64,77 2,51 ~ '~ ,6~ 63,08 ,2! 4~,/~ 45 2 45 ~ ,, ,ao 52,27 59,?7 09 50,88 6:,23 56,20 1,36 57,80 73,04 52,30 2.47 65,96 87,6~ 48,81 1,4~ 75.22 105,L7 45,66 2,89 ~5,50 125,97 42,7~ 2,23 97,45 ~51,20 40,!3 2,44 l~b,OY 17~,9~. 37,95 t,0~ 4897,34 498.9,TM,. -'i; J ... 94,A 4784 ~ ~ . 90,9 4869,02 92,4 4952,!7 93,2 5036,9~ 92,9 51!~,~I 208,~q~..- 20,28 26 ,~'~ !6~ , I! 242,7? 23.73 27,62 !99,44 280,8! 24,99 27,67 233,13 32i,~ 26 ~ ~' 365,37 .,,~q ~ 27,1~. 307,74 !23,67 209,51 36,18 2,36 139,1E 2~3,20 34,91 3,66 156,98 28!.06 33,75 1,36 176,4~ ~' - ~,69 33,26 2,1~ !97,09 365,44 32,64 2,89 5364,14 dM2d+ 5544,08 5~ ~ .... 80 ~5,~ ~^~ 25 92,9 5279.96 9i,0 5354,52 88,? 5425,62 ?2,7 4~,2_ ,97 26,49 350,60 462,33 33,26 24,48 395,20 514,33 36,79 27,80 442,05 567,60 36,96 ~v,~."~ ^l 488~98 623,62 37,5~ ~' 4~ ~o, 53~,67 2i5,72 413,23 31,96 1.6! 239,95 462,34 31,26 2,72 263,02 5!4,39 30,75 4,40 288,40 567,69 30,53 0,85 3!~,~3~- ~23,77. 3n~,26 1,7B 5729,91 5825,97 5920,!7 60!3,23 6102,72 6!96,53 6384,09' 6475,07 93,1 5573,13 96,! 5649,10 94,2 s*~,iO 93,! 5795,87 89,5 5E66.06 93,8 5939,80 93,3 60!3,37 94,3 6087,26 91.0 6157.53 93,5 6229.28 680,.~°° 37,~8. 27,32 ~ ,36 738,94 37,81 c¢"~,89 641,48 797,'~,~ ~.~,~5_ 29,42 692 .62 8.~,~ 10 o~,46 29,06 743,22 910,53 38,24 27,49 792,12 ~,~ 38,!2 ~/,~; 843,6! I^'~,AA~. .. 37 ,ca~ 29,~2 89J,05, i054,i2 "'~,93 28,42 o.%,17 = 1141 "' ~.,,/; 29,~ 28,57 I047,9z ;ao.,.,z¢~. 6A0,~3. _ 30,00 0,56 367,~ =~ 739,2? 29,61 0,3? 395,4s ' ~ ~x _ / 9/,.. 29,72 I, 35 423,75' 855,56 29,69 0,32 450,09 911,06 29,51 476,73 969,0C 2~,47 0,23 504,12 i026,38 29,42 !,75 5o~,., 1084,8~ 29,40 ! 50 560,75 !142,68 29,39 1,51 590,0i 12C2,60 29,38 0,92 6659.09 6757,4~ 6850,~6 6~44,69 90,5 6298,72 98,4 6374,34 93,4 6446,53 93.~ .... i4 90,8 6588,~2 1259,77 40.02 30,01 1096,58 Iq~,67 %' ~. ,72 , ~.~ ~;-,.4 28 1153 44 , j C ,. I381 82 39,20 28,32 .20~,aA 1441,t0 39,31 30,25 i257,22 .... ,~6 ~'", 38 27,25 ! 308,20 618,43 I260,68 29,38 1,05 649,30 I323,63 29,38 0,97 677,59 1382,86 29,34 0,45 7o6,6i 14 ,19 2 ,34 !,31 734,56 1500~32 29,31 2,43 F' ii ,r Anchorage PA6~ NO, r~'i6/I4 ,~ASJRED INTERVAL VERTICAL ft ft ft 722i,7~ 93,0 8730,~9 ,3.4.~3 ~3,i ~801.87 7407,65 92,8 7500,75 ~'q,1 ************* ANADR!LL ************** Sn~,~v CALCULATIONS ************* CI~o~An~ METHOD******** TARGET STATION AZIMUTH S~CTION '~' ft deg deg t559,48 40,26 29,40 !6' ~o 46 26,8~ 1679,69 40,17 29.32 !73~,35 40,01. c.,1i 1798,97 39,84 28,4~ N/-S ft !361.38 I4!4,47 ~467,59 1520,25 1573.12 DEF'ARTUR~ DiSPLACEMeNT at AZIMUTH DLS E/-W deg/ ft ft de§ 10Oft 763,22 1560.72 29.28 1,50 79!,62 1620,92 2~,23 1,77 819,97 16~!,12 29,19 1,72 84~,2~ 1740,8~ 29,!6 1.54 876.09 !800.62 29,11 0.96 7594,22 7689,67 7779,82 7876,14 7970.09 OOJO.~ ~!52,72 ~2~5.95 8336,60 8433.74 93.5 70!6,06 1658,69 39,82 26,64 95.4 7089,2t 19!9,80 40.1! 27.30 90.2 7!5~.32 I977,51 39,79 26,8~ 96,3 723i.~9 2039,54 40.61 28,54 ?4,0 7303.0~ 2100,80 40.~5 30,52 ~'q 93 40,5A 31,~A 86,9 7.~,~, 2!57,45 . .. 95,~ 744i,50 2219,93 40,89 3i,49 93.2 75i2.05 2280,89 40,77 31,08 90,6 75~0,53 2340,27 41,0~ 30,70 97,1 7653,74 2404,12 41,1I 3!,33 1626,19 I732,36 !7~7,40 1840,73 !889,30 1942,58 1994,68 2045.65 2!00,37 903,7~ 1860,46 29,06 1.26 931,58 192!.Z2 29.00 0,54 957,9~ 1979,56 26,94 0,46 966.86 2041.74 26.90 1.40 lOiZ,O~ 2103,03 26.92 1,40 1046,24 2159.65 2(.98 0.76 1078,87 2222,07 29.05 0,34 1110,52 2282.96 29.11 0.32 1141.0~ 2342.3~ 29,15 0,44 !!73.91 2406.16 29,20 0,43 ~523.9~ 86!6.60 87!2~67 8901,85 90,3 772!,63 2463,5~ 4!,39 30,53 92,6 779!,09 2524,83 41,50 30,48 96.1 7863.11 258~,40 4!.3~ 30,16 94,4 7933,E5 2650,63 41,50 30,07 94,8 8004,72 2713,80 4i,75 30,64 2151.38 2204,16 2259.04 2313.07 2367,4I 1204.47 2465.60 2~.24 0,62 1235.56 2526.84 29,27 0,20 1267,66 2590,42 2~.30 0,26 1299.00 2652,86 29,32 0,14 1330,83 2715,83 29.34 0,4~ 8995,15 ~n~ 57 ?177,89 o27~ ,~ o~ 76 93.3 8074.27 2775.97 41,84 30.28 9i.4 8142,34 2837,00 4!,92 3i,t2 91,3 ~2t0.15 2898,!5 42,19 30,64 92,2 ~,o,~°~ z~,j2960,1~.~ ~2,25, 30,44 93,7 ~347,69 3023,i9 42,4I 30,6! ~4~,01 2473,49 2525,99 2579,37 1362,35 2778,00 29,37 0.2~ 1393,5! 2~39,02 29,40 0,62 1424.90 2900.16 29,4S 0,46 ....... z~:.~,13 2f,45 0,!~ ,. ~0~.,19 ~v,47 0,22 9~56,36 9554,09 9647,80 9742,69 9~35,76 9928.27 10024.60 !0!18,38 10212.2! .,. o4!7,37 95,7 93.7 8556.27 94,9 8625,50 93,i 92,5 8760.52 ,:. 8~'0,33 . ~. 70c, 3,~7 30~7,I3 42,69 30,33 26~8,82 3152,07 42,77 30,17 2744,94 ~, .... 30. 2800.09 32~0,79 43,13 30,23 2~56,11 33~4,52 43,32 29,74 29ii,33 3408,06 43,51 30,40 2966,35 ~2zT~,z~,., .. ~3. ,o~" 29,1~ 3023,96 .... ~ 29,47 qd~n,2A 3603,19 43,09 29,47 3136,24 3666,00 43,07 29,50 3190,95 J~v,o¢ 30~?,!4 29,49 O,3f 1553,58 3!54,10 29,51 0,!4 15~5.TM,.. 3217,95 2?,Js~" 0,4~. 16i~,52 3282,83 29,54 0,11 1.~,3~ 3345,5~ 29,5S 0,42 I682,22 3410,!4 29.56 0,53 17!5,20 3476,52 29,56 0,88 174J,83 3~41.I0 29.56 0.29 1776,46 3605,40 29,56 0,37 1809.39 366~.24 29.55 0.03 I0397,~oo 10421,22 t0490.^~_ vv 9 J.i 9103,33 21,9 9119,32 6~.6 9169.60 37J~,94 43,II J~,05 o~,,,~"~': ~ 37~5,89 43,05 30,27 3260,27 370¢,S0... 43,00 30,°'~ 3300,79 1841,65 ~70o,22 29,5~ 0,40 1849.16 374~.!7 29.56 0,77 1872.83 3795.09 29,57 0.0~ STATE OF ALASKA AI_~oI<,A OIL AND GAS CONSERVATION COMMIS5 .... APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging Time extension __ Stimulate __ Change approved program X Pull tubing__ Variance__ Perforate ~ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development__ KBE = 51.5' feet Exploratory 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 service x Point Mclntyre 4. Location of well at surface 8. Well number 27' SNL, 1184' EWL, SEC. 14, T12N, R14E At top of productive interval 3045' NSL, 2926' EWL, SEC. 11, T12N, R14E At effective depth 3242' NSL, 3038' EWL, SEC. 11, T12N, R14E At total depth 3300' NSL, 3072' EWL, SEC. 11, T12N, R14E P2-16 9. Permit number 93-123 10. APl number 50- 029-22397 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' S u rf ace 3655' Intermediate Production 10481' Liner Perforation depth: measured None 10535 feet 9202 feet 10436 feet 9130 feet Size 20" 13-3/8" 9-5/8" Plugs (measured) Junk (measured) Cemented 280 cu ft Arcticset 2777 cu ft PF "E" & 406 cu ft Class "G" 919 cu ft Class "G" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Measured depth 80' 3692' 10518' RECEIVED dAN --'3 1994 Description summary of proposal x True vertical depth 80' 3691' 9190' Oil & Gas Cons. Commission Anchorage Detailed operations program BOP sl~etch' 14. Estimated date for commencing operation 1/15/94 16. If proposal was verbally approved Name of al)prover Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended~ 17. I hereby certify that the foregoij~g is true and correct to the best of my knowledge. Signed .~.,~ ~ Title Drilling £ngineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify C.g~mission so representative may witness Plug integrity_ BOP Test~ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- Original Sigr~ed By Approved by order of the Commission David W. Form 10-403 Rev 06/15/88 J Approval No~:~.5,/.._0 0 ~ · Approved Copy Returned -- . . Commissioner Date //--./. ' SUBMIT IN TRIPLICATE , . . . . . . . , 10. . MIRU drilling rig. P2-16 Operations Summary Spud well and drill straight 16" hole to 3763' md. Set 13-3/8" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 12-1/4" BHA and drill 10' of new hole and perform leakoff test. Drill 12- 1/4" hole. Kick off at 3767' MD and build hole angle to 40°, 31° azimuth to TD at 10,473' md/9200' tvd brt. Run wireline open hole logs. Set 9 5/8" L-80 casing and cement same. RIH and test casing to 4000 psi f/30 min. LDDP. Displace with 10.5 ppg brine. POOH Run 5-1/2", 17#, NT-80, NSCC completion assembly. ND/NU. Freeze protect the annulus to 2000' md and leave tubing string full of diesel. Set packer. Test tubing/annulus. Secure well. Release rig. POST RI(~ WQRK Run cement bond Icg. RECEIVED JAN -'~ 1994 0il & Gas Cons. Commission Anchorage TREE: 6" 5M carbon P2 16 WELLHEAD: 13-5/8" universal == GL-SL = 12.1' !i~iii!i~i!!!!!i!!iii: :i:i:!:!:!:!:!:!:!:! i:!:i:!:i:i:i:iSi:i: i:i:i:i:;:::::;::::: :i:i:i:E:E:i:i:E :i:E:i:!:!:!:E:i :::::::::::::::::::::::::::::::...........,...,.... ..................... v.....-.......-..... ......-.,...,.-.-o. :.:,>:,:...........-. :::::::::::::::::::::: !i~ii:i:i:i:!:!:!:!: D I ESEL to 2200' - -- ' ............. ~ ......... 5-1/2" OTIS TR SSSV 2250' MD; 2250' TVD BTC ~ 10.5 ppg NaCI/NaBr GAS LIFT MANDRELS (Ot is 5.-1/2" x 1-1/2" LB w/dummy) KOP: 3815' ~N~ MD(BKB) TVD(BKB) Max angle: 43.6 degrees @ 10,02~ ,__ 1 4001' 4000' : 2 9880' 8725' ! i 5-1/2" 17 ppf L-80 NSCC TUBING ID: 4.892" ! ! CAPACITY: 0.02325 BBL/FT / I I ,~ 5-1/2 .... X" Nipple (4.562" ID) '~ 5-1/2 .... X" Nipple (4.562" ID)I 5-1/2 .... XN" Nipple (4.455" ID) 19983' MD .~..o.^T,o. sua.^.~: ---- ~-~" w.~ Ref Log: Size Interval' SPF Open/Sqzd! I i i PBTD I 10,436'1 ,,,,,,,,, JAiq --,5 % % % % % % % % % 9-5/8" 47 ppf NT- I 10~5191 ~ -'"x~'*~i"~"::"'~- ~ Oil & Gas 6ons. Commission 80S NSCC Anchorage WELL TD =10535' DATE REV. BY COMMENTS Point Mclntyre 11/9/93 DEC POST DRILLING WELL: P2-16 ~ I~'~~~~ APl NO-50-029-22397 ~~ Prudhoe Bay Drilling Size Interval' SPF Open/Sqzdl Date: Subject: From: ARCO Alaska, Inc. Lisburne/Point McIntyre Engineering December 2, 1993 Transmittal #367 ARCO Alaska Inc. To: Bob Crandall A~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point Mclntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. . Well Log ~0 ~,,~7 1 blueline 1 sepia l~:~ZO -- l.~?~ 5" '~~ P1-01 Perforation Record 2-1/8'' BH ENERJET 'q,5-'.~5'~ P1-05 -'Static Pressure Survey/PRESS/TEMP/GR/CCL) · ., ..%. /T4~~VLWD Ver~Enhanced Resistivity CDR ~qq~'~o~'%crr~" ~5-7~'4kPI~V'LWD True Vertical Depth CDR ~¢q- ~t ,~ 5 cmFst Pl-17 P1-17 P1-17 ~Perforation Record 33/8" HSD -4lB '~o0-to2-5o; $" 1 /Perforation Record 33/8"HSD-4lB fl~oo-.lo-~o; z" 1 ~,'Data Frac Log ~70o--t~z5o~ 5" 1 "Cement Evaluation Log (CET-GR) ~oo-lv42.b, ~" 1 ,'Cement Bond Log (CBT-GR) ~0-10q0o s,' 1 VCement Evaluation Log (CET-GR) ViTZ-~z~0~ ~" 1 P2-1 6 '~'~ IP2-16 Run # Run Date Company 1 11/3-4/93 1 ~z'~0~ 93 Schl~~ ni261 n/29/93 111o7193 to/24/93 :to/24/93 :to/24/93 IP2-46 '~ ~-~ P2-46 .~, t. 7~P2-57 P2-57 . /P2-60 F2-60 '1P2-60 \! · zCement Bond Log (CBT-GR) ~lVz-~z2~, s" 1 10/24/93 /P~atk Bottou&ole Sta-v~y (FRESS/TEi~/GR) ~m-,~o I, ~/~/93 wCompensated Neu~on Log (2.5" CNT-D/ ~Perforafion Record (~/~ G~ ~IB ~) zs[1~-1%ooo,11/14/935" ~ta~c Press~e s~ey ~SS/~~ / GR/CCL)' 11 / 18/ ~erfora~on Record ~/~ 41B ~ ltb~%d ~%~%~ s"l 11/14/93 PLEASE SIGN ONE COPY AND RETURN Transmittal ~367 (AOGCC) Page 2 Well Tape/Diskette w/verification o~ e 5q~'~%~t Run # Run Date Company P14~T#1 ~Data in 2 ST Bit Runs (w/Orig. Well) -~ ! 7/18/93. S<hlum~ Pl-16 Dual PropResis/Neu/Dens/GR-DePth Shifted P1-21 Dual PropResis/Neu/Dens/GR-Depth Shifte~ P2-12 Final MWD z¢r~vivck;-k~, - 8/31/93 Sd~u_m~ P2-16 DIFL/GR, CN/ZDL/GR (LDW~ Tape & Disk'~ette) - , 9/13/93 Atlas P2-16 Final M-WD ~r~{ ~cL~v_ oP~ ~u .e~zq 7~-1o5~_o 9/11/93 Schlum~ P2-46 0¢ DZFL/CN/ZDL/GR (LDWG Ta~e & Disk~tte) -eLI5 - 9/27/93 Atlas P2-46 Final MWD k"CSq2.,z, ~ctgS-qz~' - 9/26/93 Sd~l~~ Please sign $~o-~~ and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 .. Transmittal #367 PLEASE SIGN ONE COPY AND RETURN Date: Subject From: October 13, 1993 Transmittal #359 ARCO Alaska Inc. ARCO Alaska, Inc. L~,vurne/Point McIntyre Engineerin~ To: Bob CrandaH AOC~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title -' · P1-04 Comple 'o Record, Perforation HSD 6 sfp 33/8'' P1-05 Perforating Record 33/8'' HSD 41B HI T[ I~)X 5 , P1-05 P1-05 P1-05 P1-05 P1-08 P1-08 P1-08 P1-08 Perforating Record 3%" HSD 4lB HJ il RI)X- 5' Perforating Record 3%" HSD 4lB ~ ii RDX- 5", Perforating .Record 3%8".HSD 4lB t-If II RDX" $") Perforating Record 33/8'' HSD 4lB HJ II RDX Integrated Formation Log -~v' ~-~ooct{~" Integrated Formation Log.._~D., N6%z.--~772.'~ zz" - Engineering Parameters ~ 2.'; t~co- 1Oouo' - Pressure Data Log-MD i"~ ~ - ST~' - Run # 'Run Date Company I 8/19/93 Schlumberger. 1i z~-t~ 8/23/93 Schlumberger 1 ~'.5 8/30/93 Schlumberger 1~i-~8/31/93 Schlumberger 1~,.,J9/01/93 Schlumberger 1 ,,4~9/02/93 Schlumberger 7/19-24/93 7/19-24/93 7/19-24/93 7/19-24/93 Exlog Exlog Exlog Integrated Formation Log -~.~'~, e~Wo-to~oo' _ Integrated Formation Log ~b2'~ ~O.-%?~oz Engineering Parameters ~ ~"~ ~?~-' l~c~' Pressure Data Log-MD I% Ellz5 -~7~' - 7/25-31/93 7/25-31/93 7/25-31/93 7/25-31/93 Exlog Exlog Exlog Exlog Pl-13 Pl-13 Pl-13 Pl-13 Integrated Formation Log-~) 2", ~co- Il ~o5 _ Integrated Formation Log___~ ;-"~ tK~qO-T7q5 Parameters~ " Engineering 2- , coqc~- ii coo Pressure Data Log -MD ~" c0t~o - ~,-7 ~:~ - 6/1-11/93 6/1-11/93 6/1-11/93 6/1-11/93 Exlog Exlog Exlog Exlog Pl-17 Pl-17 Pl-17 Pl-17 Integrated Formation Log -~ ,~, 7~o-lo~SZ - Integrated Formation Log_z_..~.2'~ 7~o0-~o%3z Engineering Parameters ~ 2~, 7.a~x~-- ~o~za Pressure Data Log-MD ~" 4112-16/93 4112-16/93 4/12-16/93 4112-16193 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN Date: Subject: From: ARCO Alaska, Inc. ,,sburne/Point McIntyre Engineering November 17, 1993 Transmittal #36t ARCO Alaska Inc. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 Enclosed are sepias for the following Point McIntyre logs. These sepias were erroneously omitted from Transmittal #359, sent 10/13/93. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title Run # Run Date Company 1 ~epia ' P1-04 Completion Record, Perforation HSD 6 stp 33/8" 1 8/19/93 Schlumberger P1-05 ,/'Perforating Record 3%" HSD 4lB ~ li RDX 1 P1-05 v/Perforating Record 3%8" t-LSD 41B I-If II RDX t P1-05 -/Perforating-Record 3%8" HSD 4lB ~ II RDX 1 P1-05 vl~erforating Record 3%8" HSD 4lB ~ II RDX 1 P1-05 ,/Perforating Record 33/8" HSD 4lB ~ II RDX 1 8/23/93 8/30/93 8/31/93 9/01/93 9/02/93 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger ~P1-08 ,,/Integrated Formation Log-MD P1-08 v4ntegrated Formation Log-TVD P1-08 ,/'Engineering Parameters -MD P1-08 w'Pressure Data Log-MD - 7/19-24/93 - 7/19-24193 - 7/19-24/93 - 7/19-24193 Exlog Exlog Exlog Exlog !~'P1-08ST1 Integrated Formation Log -MD v'Fi-08ST1 Integrated Formation Log-TVD v'PI4)SST1 Engineering Parameters -MD ~/I~i-08ST1 Pressure Data Log-MD · - 7/25-31/93 - 7/25-31/93 - 7/25-31/93 - 7/25-31/93 Exlog Exlog Exlog Exlog P1-13 ,/'Integrated Formation Log-MD Pl-13 v' Integrated Formation Log -TVD Pl-13 ,./Engineering Parameters-MD 'Pl-13 v/Pressure Data Log-MD' 611-11193 611-11193 611-11193 611-11193 Exlog Erdog Exlog Exlog Pl-17 ,"'Integrated Formation Log-MD P1-17 v/integrated Formation Log-TVD Pl-17 ~' Engineering Parameters -MD Pl-17 v-q'-ressure Data Log-MD - 4/12-16/93 - 4/12-I6/93 - 4/12-16/93 - 4/12-16/93 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN Transmittal ~:359 (AOGCC) r~ Page 2 q'%-~5 P1-04 Fl-05 q5-%7 P1-05 Pi-05 [P1-08 IPl-13 ~'b-Tq IPl-13 q 3" 5t ! Pl-17 ! ~ Pl-17&, P2-06 %-~05 P2-06 P2-06 Log Well Title Run # Run Date Company 1blue line P1-21 Integrated Formation Log ~ 4/30-5/5/93 E,,dog ~0-- ~t %%5', Fl-21 Integrated Formation Log ~~"' '- 4/30-5/5/93 Exlog ~x:>o- I~ 52-5 ~ 22" P1-21 Engineering Parameters ~ - 4/3¢5/5/93 Exlog ~"; ¢~:~--- P1-21 Pressure Data Log -MD`,/- 4/30-5/5/93 Exlog I" ~z~_~ -- 'P2-06 Z-Densilog/Cmpnstd NEU'I~ON / GR/ Caliper ~'~ ~s'~ 11~4oo - 8/17/93 Atlas P2-06 Dual Laterolog/Gamma Ray/SP ' 1 8/17/93 Atlas ~55'~ P2-06 Sub-Sea Vertical Depth (Single Shot Data)-..xl 8/17/93 Atlas ,F2-06 Borehole Profile 1 8/I7/93 Atlas ~'-'5 14-1" ~ tq0~- P2-16 Z-Densilog/Cmpnstd NEUTRON/GR/Caliper~?; 'i~ 9/13/93 Atlas P2-16 Dual Induction Focused Log/Gamma Ray 1 9/13/93 Atlas P2-16 Sub-Sea Vertical Depth (Multi Shot Data) 1 9/13/93 Atlas 1',--2" '7'~t::, P2-16 Borehole Profile 1 9/13/93 Atlas P2-46 Z-Densilog/Cmpnstd NEUTRON/GR/Caliper a~l' 9/27/93 Atlas P2-46 Dual Induction Focused Log/Gamma Ray I 9/27/93 Atlas P2-46 Sub-Sea Vertical Depth (Directional Drlg Data) ~ 1 9/27/93 Atlas P2-46 Borehole Profile 1 9/27/93 Atlas ~->1+~"~ -. Diskette/Tape (w/verification listing) Well Title Run # Run Date Company GCT diskette-Complete Calc.,/ 1 7/28/93 Schlumberger GCT diskette-Complete Calc.,/ 1 8/12/p~ Schlumberger CDN/CDa MAD Data in ~ Bit Run (O._H Edit)~---~St~'~l ~k~¢)50c~/[~Schlumberger CDN/CDR in 3 Bit Runs (O_~H Edit),,' qq$~ttk~C-~ Final ~D w/lis~~ ~ - CDR/GR'Offiy m S Bit Rm (OH Du~ ~op Res~/DemiW/Neu~on/GR w/~s~g 5-7 F~M ~ w/Lis~g + ~ - F~M ~ w/Lisfing~~ - F~M ~ w/Lis~g ~ ~ ~ - CDN/CDR ~ 3 Bit R~s (O~ E~t)a~[ DLL/~/~L/GR ~ LDWG Fomat w/Hs~g 1 ~lq o~ ~q~-1178¢ 6/27/93 7/13/93 7/24/93 6/6/93 6/07/93 4/16/93 4/16/93 8/17/93 8/17/93 8/17/93 Schlumberger Schlumberger Schlumberger Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Schlumberger Atlas PLEASE SIGN ONE COPY AND RETURN Transmittal ~6I (AOGCC) Page 2 Log Well Title 1 sepia P1-21 v/Integrated Formation Log-MD P1-21 V' ,Integrated Formation Log-TVD P1-21 fEngineering Parameters -MD P1-21 ,/Pressure Data Log-MD P2-06 v'~Z-Densilog/Cmpnstd NEUTRON/GR/Caliper P2-06 ~/Dual Laterolog/Gamma Ray/SP P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) P2-06 ~fl3orehole Profile P2-16 P2-16 P2-16 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Catiper 1 v~/~Duai Induction Focused Log/Gamma Ray 1 ub-Sea Vertical Depth (Multi Shot Data) 1 ~/Borehole Profile 1 P2-46 P2-46 P2-46 P2-46 ~Z-Densilog/Cmpnstd NEUTRON/GR/Ca~per v/Dual Induction Focused Log/Gamma Ray ~"Sub-Sea Vertical Depth (Directional Drlg Data) d~Borehole Profile Run # Run Date - 4130-5/5/93 - 4t30-5/5/93 - 4t30-5/5/93 - 4130-515/93 8/17/93 8/t7/93 8/17/93 8/17/93 9/13/93 9/13/93 9/13/93 9/13/93 9/27/93 9/27/93 9/27/93 9/27/93 Company Exlog Exlog Exlog Exlog Arias Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. 'P.O, BOX 100360 ' Anchorage, Alaska 995/,0-0360 Transmittal #361 R'ECEIVED NOV 79 1993 'Alaska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #361 (AOGCC) Page 2 Log Well Title 1 sepia P1-21 v/Integrated Formation Log-MD P1-21 V' Integrated Formation Log -TVD P1-21 V/Engineering Parameters -MD P1-21 ,/Pressure Data Log-MD P2-06 v"Z-Densilog/Cmpnstd NELrrRON/GR/Caliper 1 P2-06 x/Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 v/Borehole Profile 1 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-16 v'Dual Induction Focused Log/Gamma Ray 1 P2-16 v/Sub-Sea Vertical Depth (Multi Shot Data) 1 P2-16 ,,/BorehOle Profile 1 P2-46 iP2-46 i P2-46 P2-46 d~Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 v/Dual Induction Focused Log/Gamma Ray 1 v"Sub-Sea Vertical Depth (Directional Drlg Data) 1 d13orehole Profile 1 Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9/13/93 9/13/93 9/13/93 9/27/93 9/27/93 9/27/93 9/27/93 Company Exlog Exlog Exlog Exlog Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Please .. and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #361 RECEIVED NOV 19 1993 'Alaska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #359 (AOGCC) Page 3 Report Well P1-04 Fl-05 P1-08 P1-13 P1-17 P1-21 Title Sub-Surface Directional Survey (2 copies)v' Sub-Surface Directional Survey (2 copies) Final Well Report ~" Final Well Report Final Well Report,'" Final Well Report~- Date 7/28/93 8/12/93 7/19-8/1/93 6/1-11/93 4/12-16/93 4/30-5/5/93 Company Schlumberger Schlumberger Exlog Exlog Exlog Exlog Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 ' Anchorage, Alaska 99510-0360 Please note: The Exlog blueline logs are located within the Final Well Report binders. Transmittal #359 PLEASE SiGN ONE COPY AND RETURN ALASKA OIL AND GAS CONSERVATION COMMISSION August 27, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Point McIntyre P2-16 ARCO Alaska, Inc. Permit No: 93-123 Sur. Loc. 27'SNL, l184'EWL, Sec. 14, T12N, R14E, UM Btmhole Loc. 2131'SNL, 2140'WEL, Sec. 11, T12N, R14E, UM WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Dear Mr. Zanghi: 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. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Q~.,(~. prinl~ed on recycled paper STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratory [-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenF'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 = 53.5' feet Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612. Anchora~Te. Alaska 99519-6612 ADL 365548 4. Location of well at surf-ace 7. Unit or property Name Ill. Type Bond(me 20 A^C 25.025) 27' SNL, 1184' EWL, SEC. 14, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 2373' SNL, 2288' WEL, SEC. 11, T12N, R14E P2-16 U-630610 At total depth 9. Approximate spud date Amount 2131' SNL, 2140' WEL, SEC. 11, T12N, R14E 9/3/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 34622-3138' feet P2-59-21' @ 2250' TVD feet 2560 10473' MD/9200' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~ 20 Mc 25.035 (8)(2)) Kickoff depth 3767, feet Maximum hole angle 40 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface 80' 80' 11 yds Arcticset (Approx.) 16" 13-3/8" 68~ NT-80 B TC 3662' 41' 41' 3703' 3703' 2777 cu ft "E"/4o6 cu ft "G'y235 cu ft "C" 12-1/4" 9-5/8" 47# VT80-S NSCC 10432' 41' 41' 10473' 9200' 919 cu fl 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 M~,~,a~r~. ~elt~ Structural E D True Vertical depth Conductor Surface Intermediate AU6 Production Alaska. Oil & Gas Cons. l;om~'tss'to~ Liner Anch0fage Perforation depth' measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I J3ereby certify that the foregoing is true and correct to the best of my knowledge igned Title Drilling Engineer Supervisor Commission Use Only Permit Number IAPI number IAppr..oval ~l. ate See cover letter · Z.~..~ IP7 I ,/~-' ~' ~'-~/"~ '"'~'~'~ for other requirements Conditions of alSproval Samples required [] Yes ~ No Mud log required []Yes [] No,,.~., ?:~,-~,,;,-~.,~,~ Copy Hydrogen sulfide measures [] Yes ~ No Directional survey requ~rec~ R1 Yes [] No Required working pressure for BOPE []2M; I-]3M; J~5M; []1OM; I-I15M; _ Other: Original Sicned ~Y by order of Approved by David W. Johnston Commissioner [ne commission Date~'/t-~//~ :orm 10-401 Rev. 12-1-85 Submit in triplicate J Well Name: I PM 2-16 Well Plan Summary IType°fwe~(pr°ducer°rinject°r): IWATERINJECToR I tSurface Location Target Location: IBottom Hole Location: · 27 FNL, 1184 FWL, SEC 14, T12N, R14E 2373 FNL, 2288 FEL, SEC 11, T12N, R14E 2131 FNL,2140 FEL,SEC 11, T12N, R14E AFE Number: 2C0040 IRi~I: I POOL #7 I Estimated Start Date: 19/3/93 I IOperating days to complete: 18 IMD: 110473 I ITvD: 1 9200 brt J KBE: J 53.5' IWell Design (conventional, slimhole, etc.)- IBIG BORE / LONGSTRING / NO COMPLETION Formation Markers: Formation Tops MD TVD (BKB) WEST SAK 7504 6934 K-10 9945 8796 TRUNCATED K-5 9945 8796 TRUNCATED HRZ 9945 8796 KALUBIK 10023 8856 KUPARUK 10034 8864 TD 10473 9200 Well Plan Summary P2-16 RECEIVED A U G 1 8 1993 Alaska Oil & Gas Cons. Commission Anchorage Page 1 Casinq/Tubinq Proqram: ~p. ,11, y Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVDbrt MD/'I'VDbrt 30" 20" 91.5# H-40 WLD 80' GL 80/80 16" 13-3/8" 68# NT-80 BTC 3662' 41' MD 3703/3703 12-1/4" 9-5/8" 47# NT-80S NSCC 10432' 41' MD 10473/9200 TBG NONE Logging Program: I open Hole Lo~s: SURFACE PRODUCTION ICased Hole Lo~s: NONE Atlas wireline GR/Resistivity/Neutron/Density (From top of K-10 to TD) No MWD logging. [MWD directional only] Cement Bond Log (After Rig Release) Mud Program: considerations I water injection wells) I Surface Mud Properties: I Spud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 Intermediate Mud Properties: J Fresh/lightly dispersed Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5 50 20-40 15-20 20-30 9-10 10-20 Production Mud Properties: I Fresh/lightly dispersed Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 9.5 8-15 25-30 5-15 10-20 9-10 10-15 10.0 15-30 25-30 8-12 <25 9-9.5 8-10 APl Well Plan Summary P2-16 RECEIVED Alaska Oil & Gas Cons. Comm[ss~o~ Anchorage Page 2 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 ddlling fluid system schematics on file with AOGCC. Directional: I KOP: 13767' Maximum Hole An~le: Close Approach Well' 40 o N31 E P2-59 @ 2250' tvd in P2-16 (21', Sep Factor = 0.9) P2-58 @ 2900' tvd in P2-16 (46', Sep Factor = 1.7) The above listed wells will be secured during the close approach. Well Plan Summary P2-16 RECEIVED AUG t 8 t9.9,~ Alaska 0il & Gas Cons. Commission Anchorage Page 3 SuHace Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: P2-16 Cement Volumes Surface String 3703 13 3/8 68 16 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1280 (2777 Cu. Ft.) TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 350 (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Production String 10473 9 5/8 47 9034 12 1/4 1.9 LEAD Yield 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.2 Density 15.8 # sacks 766 # bbls I 64 (0 Cu. Ft.) (919 Cu. Ft.) RECEIVED AU G 1 8 t99; Alaska Oil & Gas Cons. Commission Anchorage P udhoe Drillin Prudhoe Poin[ M¢In[yre P2-16 P2- 16WP ] HALLIBURTON DRILLING SYSTEH$ 04130/1993 1:48 pm HORIZONTAL VIEW SCALE 250 ft. / DIVISION SURVEY REF: WELLHEAD 350 4OOO 4500 561 6000 7500 8000 8797 8857 8865 VERTICAL VIEW SCALE 500 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD L 13.375 OD, e 3700 MD, 3700 TVD 0.00° e 3767 MD START OF BUILD @ 2.00 BEG/lO0 FT 2.00' ~ 3867 MD 4,00' ~ 3967 MD 6,00' ~ 4067 ND 8 00' @ 4167 NB 10 00' @ 4267 MD 12 00' ~ 4367 MD 14 00' ~ 4467 MD 16 00' ~ 4567 MD 18 00' ~ 4667 MD 20.00' @ 4767 MD 22 00' ~ 4867 MD 24.00' @ 4967 MD 26.00' ~ 5067 MD 28,00' e 5167 MD 000 0 350 750 500 250 000 z50 0 ~30.00' @ 5267 MD ~32.00' e 5367 MD ~34.00' ~ 5467 MD ~x36.00° ~ 5567 MD 250 0 250 500 750 100012501500175020002250 ~38.00' ~ 5667 MD ~ 40.00' ~ 5767 MD 697 X~0.25' ~ 5779 MD END'DF BUILD 'X / MD Ina Azl TVD North East ~ IR.K,B. ELEVATION 0 0.00 0.00 0 0 0 'x 1(53,5') ~ ISTART OF 373 0.00 0.00 373 0 0 ~ INUDGE ~ 1.5o ~k ]DEG/IO0 FT ~ lEND OF BUILD 573 3,00 63.43 573 2 5 %, ISTART OF 800 3.00 63.43 800 8 15 ~ JCURVE e 1.50 k, IDEG/iO0 FT ~ lEND OF NUDGE 1000 0.00 0.00 1000 10 20 ~ ISTART OF BUILD 3767 0,00 0,00 3766 10 20 ~ 2 O0 DEG/iO0 40.25' ~ 7504 MD WEST SAK~ I~T' ~ I END DF BUILD 5779 40.25 31.37 5617 589 373 1811 ~ IWEST SAK 7504 40,25 31.37 6934 1540 953 ~ IK-iO/K-5/HRZ 9945 40.25 31.37 8796 2887 1774 ~ IKALUBIK 10023 40.25 31.37 8856 2930 1801 ~ ,TARGET/KUPARUK 10034 40.25 31.37 8864 2936 1804 ~ ITARGET 10373 40.25 31.37 9124 3123 1918 /mTAL DEPTH 10473 40.e5 31:37 9200 3178 1952 L -- RECEIVED AU G 18 t 95 · ~ Alaska 0il & Gas Cons. Anchorage 40.25 ° @ 9945 MD K-iO/K-5/HRZ 40.25' ~ 10023 MD KALUBIK 3439 ~40.25' ~ 10034 MD TARGET/KUPARUK 3665 ~40.25' ~ 10373 MD TARGET 40.25' ~ 10473 MD TOTAL DEPTH 3730 9500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 VERTICAL SECTION PLANE: 31.56' CASING PDINT DATA DD MD Inc Azi TVD North East 13.375 in. 3700 0.00 0.00 3700 10 20 BHL DATA TVD 9199.82 MD 10473.13 VS 3729.99 North 3178.40 East 1952.08 Date PLotted Created By Checked By Approved By Date 4/30/93 PmUdhoe Bey PPudhoe Bey Poi n-t; McTn ±yp e PP-16 PP- 16WP Tnovellln9 Cyllnden - Leos± ]31s±once ReFenence ~/ell - PB-16WP TVD; 0 - 9200 F±, In±envoi, 50 Att D~ectlons Rel to T~ue ~No~±h 33O° 550 ~0o ) HALLIBURTON I~ILLINS SYSTEMS 04/30/1c)93 l:28 pm 300o 6~° 870o FgJ~-4g~CT 240° 120o 210° ~,150° RECEIVED AU G 1 8 199 Alaska Oil il, Gas Cons, Commt~lo[~ CL[~;~>EST P~IN'TS Bs~r. once Direction Re¢ MD ReP IYD Sep.Foc±o~ N/A N/A N/A N/A N/A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A ~A J 80.37 L:X:)~.L:::~ :~ 00.00 tO0.O0 76c).10 E56.33 J 29.54 350.00 350.00 t 23.50 399.3J J64.47 0.00 0.00 39:2.30 48845 J 66.97 L~-JO.O0 250.00 583.50 390.3~ :136.54 ! 650.49 1650.00 36.80 473.18 :17! .82 400,00 400,00 390,60 47.50 ~64.4] L:500.49 L::5~.CO ~.60 39P.36 ~1.64 2400.49 B400.O0 B6.00 ~67.81 ] 76.25 L~o0.O0 L:50.O0 403.60 46.45 g0.56 L:x:)O0.49 :g:::~30.00 ! .70 ~ .46 29448 L~.49 L:~-oO.~ 0.90 400.86 :~50.g7 ~100.49 a:lO0.O0 ~7.00 5].5.74 ] Cyp.gJ l CO,O0 JO0.O0 ~635. t0 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NVA N/A N/A N/A CR]TICAL POINT DATA MD ]nc Azi TVD Nor'.th Eos't TIE IN 0 0.00 0.00 0 0 0 START OF BUILD 373 0.00 0.00 373 0 0 8:1.50 DEG/i O0 FT END BF- BJILD 573 3.00 63.43 573 2 5 START OF 800 3,00 63.43 800 8 15 CURVE @ 1.50 DEG/1 O0 FT TARGET :1000 0,00 0.00 :~ 000 10 20 START DF BUILD 3767 0,00 0.00 3766 10 20 ~ 7.00 BEG/lO0 FT END EF BUILD 5779 40,25 3:1,37 56~7 589 373 TARC~T. START :10034 40,L::5 3:1.37 8864 2936 :1804 EF BUILD ~ 0.00 DEG/:100 FT TARGET :10373 40,L:~5 3:1,37 c)174 3173 1928 TARGET :10473 40,25 3:1,37 9700 3178 :1957 D~±e Ro.t.ted Cr'eo.ted By Checked By Approved By 4/30/93 BFL DATA TVD g~ 99.88 MD ! 0473,13 VS 847.87 Non~h 3:178.40 Eos± ~ 952,08 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE D~TE 2. ['2 thru 8~ 3. [23 thru Company~Kc_~ (5) BOPE [29 thru 31] (6) Other Is permit fee attached ............................................... Is well to be located in a defined pool .............................. . Is well located proper distance from property line ................... ~_ .. 4. Is well located proper distance from other wells ..................... '~ .. 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. ~--- 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14. 15. (7) Contact/~ [3 (8) Addl geology' encjineerinq' Mm RAD RP~ BEB~ JDH ~?~-~," TAB ~ rev 6/93 jo/6.011 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. NO REMARKS Does operator have a bond in force ................................... .~ Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... Does well have a unique name & nL~nber ................................ Is conductor string provided ......................................... ~' ,,, Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ -~ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~-'~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... 0 Z~Z ~0 Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE Additional remarks' MERIDIAN: UM 2<~ SM WELL TYPE' Exp/~ Redrill Inj X Rev 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 Su~file 2 is type: LIS TAPE HEADER POINT MCINTYRE UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN1 6040.00 J. DAHL HENTGES / PEAK P2 - 16 500292239700 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 23-SEP-93 REMARKS: RUN2 RUN3 14 12N 14E 27 1184 OPEN HOLE 53.50 10.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 3694.0 12.250 10536.0 DIFL/GR & CN/ZDL/GR CIRCULATION STOPPED: 21:00 12-SEP-93. DIFL/GR: LOG DATA SPLICED AT 9385' DUE TO UPPER & LOWER SECTIONS RECORDED ON DIFFERENT RUNS IN THE HOLE (HOLE CONDITIONS). THE DATA WAS SPLICED IN THE FIELD & IS NOT AVAILABLE IN INDIVIDUAL RUNS. CN/ZDL/GR: NEUTRON IS CALIPER CORRECTED, RECORDED ON A SANDSTONE MATRIX, & CHISM FILTERING IS NOT ACTIVE. NO REPEAT PASS RUN DUE TO TOOL FAILURE AFTER MAIN PASS. AFTER-LOG VERIFICATIONS WERE AVAILABLE DUE TO TOOL FAILURE ONLY WHILE MOVING. BARITE IN THE MUD SYSTEM (3.1%) CAN INFLUENCE THE PE RESPONSE. BOW SPRING NOT RUN ON NEUTRON DUE TO HOLE CONDITIONS. ZDL CALIPER PROVIDES DECENTRALIZATION FORCE. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings with depth shifted and clipped curves; (including cased hole). DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GR DIL GRZ 2435 SDN $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH STOP DEPTH 7350.0 10498.0 7350.0 10530.0 10065.0 10492.0 10065.0 10498.0 10065.0 10516.0 GR (MEASURED DEPTH) from DIFL/GR run. BASELINE DEPTH LL8 7338.0 7338.0 7362.0 7380.5 7381.0 7380.5 7482.5 7482.0 7482.0 7495.5 7495.0 7495.0 7549.5 7549.0 7550.0 7671.0 7670.5 7815.5 7814.5 7816.0 7816.5 7843.0 7843.0 7842.5 7883.0 7883.0 7884.0 7883.5 8033.5 8034.0 8185.5 8185.0 8353.0 8351.5 8371.0 8370.5 8369.5 8449.5 8449.5 8667.5 8668.0 8668.0 8741.5 8741.5 8740.5 9023.0 9022.5 9022.5 9246.0 9246.0 9246.0 9871.5 9871.0 10064.0 10063.5 10064.0 10080.5 10081.0 10080.0 10085.0 10088.5 10092.5 10093.0 10093.5 10102.5 10103.0 10118.5 10119.0 10117.5 10160.0 10159.5 10158.5 10162.5 10186.5 10216.0 10218.5 10218.5 10222.5 10278.0 10278.0 10277.5 10313.0 10312.0 all runs merged EQUIVALENT UNSHIFTED DEPTH -- ILM GRZ RHOB 7338.0 7338.0 7338.0 7362.0 7379.5 10081.5 10081.5 10086.0 10085.5 10088.5 10088.5 10092.0 10092.0 10102.5 10102.5 10162.5 10162.5 10186.0 10216.5 10278.0 10223.0 10278.0 10322.5 10352.0 10354.0 10354.5 10353.0 10372.5 10395.5 10396.0 10395.0 10467.5 10481.5 10481.5 10481.5 10554.0 10554.0 10554.0 $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. PASS NO. GR 1 3 GR 1 2 DIL 1 3 DIL 1 2 GRZ 1 1 2435 1 1 SDN 1 1 $ REMARKS: CN WN FN COUN STAT 10373.0 10395.5 10466.0 10554.0 10322.5 10352.0 10373.0 10396.0 10466.0 10554.0 MERGE TOP MERGE BASE 7350.0 9385.0 9385.0 10498.0 7350.0 9385.0 9385.0 10530.0 10065.0 10492.0 10065.0 10498.0 10065.0 10516.0 MERGED MAIN PASS. "GRZ" REFERS TO THE GAMMA RAY CURVE FROM THE CN/ZDL TOOL STRING. MTEM, TENS, & TEND (from DIFL tool string) WERE SHIFTED WITH LL8. ILD, SP, VILD, & VILM WERE SHIFTED WITH ILM. DRHO, PEF, CALl, MTEM, TENS, TEND (from CN/ZDL tool string), NPHI, FUCT & NUCT WERE ALL SHIFTED WITH RHOB $ : ARCO ALASKA INCORPORATED : P2 - 16 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: 1 2 3 4 5 6 7 8 9 10 11 Name Tool Code Samples Units GR DIL 68 1 GAPI LL8 DIL 68 1 OHMM ILM DIL 68 1 OHMM ILD DIL 68 1 OHMM SP DIL 68 1 MV VILM DIL 68 1 MV VILD DIL 68 1 MV MTEM DIL 68 1 DEGF TEND DIL 68 1 LB TENS DIL 68 1 LB GR 2435 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 55 965 57 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 98 211 23 1 12 NPHI 2435 68 1 PU-S 13 FUCT 2435 68 1 CPS 14 NUCT 2435 68 1 CPS 15 MTEM 2435 68 1 DEGF 16 TEND 2435 68 1 LB 17 TENS 2435 68 1 LB 18 RHOB SDN 68 1 G/C3 19 DRHO SDN 68 1 G/C3 20 PEF SDN 68 1 BN/E 21 CALl SDN 68 1 IN * DATA RECORD (TYPE# 0) Total Data Records: 585 974 BYTES * 4 98 211 23 4 98 211 23 4 98 211 23 4 98 211 23 4 98 211 23 4 98 211 23 4 22 779 91 4 22 779 91 4 22 779 91 4 22 779 91 84 Tape File Start Depth = 10554.000000 Tape File End Depth = 7338.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER ~*** LIS representation code decoding summary: Rep Code: 68 141527 datums Tape Subfile: 2 735 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7346.0 DIFL 7346.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10512.0 10544.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR MIS TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: 13-SEP-93 FSYS REV. J001 VER. 1.1 2100 12-SEP-93 350 13-SEP-93 10536.0 10533.0 7350.0 10530.0 3000.0 TOOL NUMBER 3974XA 3517XA 1309XA 3967XA 2806XA 3506XA 1503XA 12.250 3694.0 0.0 LO SOLIDS LITLY DISP 10.20 44.0 9.8 5.8 151.0 2.650 69.0 1.281 151.0 3.670 68.0 0.000 O.0 2.320 68.0 MUD CAKE AT BHT: 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): 1.5 REMARKS: DIFL/GR MAIN PASS. LOG DATA SPLICED AT 9385' DUE TO UPPER & LOWER SECTIONS RECORDED ON DIFFERENT RUNS IN THE HOLE (HOLE CONDITIONS). THE DATA WAS SPLICED IN THE FIELD & IS NOT AVAILABLE IN INDIVIDUAL RUNS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P2 - 16 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 SP DIFL 68 1 MV 6 VILM DIFL 68 1 MV 7 VILD DIFL 68 1 MV 8 CILD DIFL 68 1 MMHO 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 TEN DIFL 68 1 LB 13 SPD DIFL 68 1 F/MN 4 4 4 4 4 4 4 4 4 4 4 4 4 4 67 456 14 5 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 53 419 67 0 4 04 522 10 6 4 04 522 10 6 4 34 704 23 6 4 40 467 34 0 4 78 867 34 0 4 78 867 34 0 4 78 867 34 0 4 13 331 34 0 52 * DATA RECORD (TYPE# O) Total Data Records: 715 1014 BYTES * Tape File Start Depth = 10554.000000 Tape File End Depth = 7338.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 180111 datums Tape Subfile: 3 793 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 2 1 0.2500 VENDOR TOOL CODE START DEPTH GR 10062.0 2435 10062.0 ZDL 10062.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10514.0 10520.0 10538.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR 2435 PCM ZDL TEMP PCM CENT $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR Z-DENSITY TEMPERATURE PULSE CODE MODULATOR CENTRALI Z ER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): 13-SEP-93 FSYS REV. J001 VER. 1.1 2100 12-SEP-93 1001 13-SEP-93 10536.0 10529.0 10070.0 10516.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 3508EA 2222EA/2222MA 2806XA 3506XA 12.250 3694.0 0.0 LO SOLIDS LITLY DISP 10.20 44.0 9.8 5.8 158.0 2.650 69.0 1.219 158.0 MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 3.670 0.000 2.320 0.000 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN): 0.0 REMARKS: CN/ZDL/GR MAIN PASS. CN IS CALIPER CORRECTED & CHISM FILTERING IS NOT ACTIVE. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P2 - 16 : POINT MCINTYRE : NORTH SLOPE : ALASKA 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CNCF 2435 68 1 PU-S 4 4 CN 2435 68 1 PU-L 4 5 LSN 2435 68 1 CPS 4 6 SSN 2435 68 1 CPS 4 7 TEMP 2435 68 1 DEGF 4 8 CHT 2435 68 1 LB 4 9 TTEN 2435 68 1 LB 4 10 SPD 2435 68 1 F/MN 4 11 ZDEN ZDL 68 1 G/C3 4 12 PORZ ZDL 68 1 PU-S 4 13 ZCOR ZDL 68 1 G/C3 4 14 PE ZDL 68 1 BN/E 4 15 CAL ZDL 68 1 IN 4 16 HRD1 ZDL 68 1 CPS 4 17 HRD2 ZDL 68 1 CPS 4 18 SFT2 ZDL 68 1 CPS 4 19 SHR ZDL 68 1 4 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 52 443 33 1 4 46 370 25 1 4 09 884 61 1 4 76 731 33 1 4 37 715 66 1 4 15 242 69 1 4 14 587 33 1 4 78 812 61 1 4 37 715 66 1 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 161 Tape File Start Depth = 10542.000000 Tape File End Depth = 10062.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 179948 datums Tape Subfile: 4 240 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9868.0 DIFL 9868.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : STOP DEPTH 10512.0 10544.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR MIS TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 13-SEP-93 FSYS REV. J001 VER. 1.1 2100 12-SEP-93 709 13-SEP-93 10536.0 10533.0 7350.0 10530.0 3000.0 TOOL NUMBER 3974XA 3517XA 1309XA 3967XA 2806XA 3506XA 1503XA 12.250 3694.0 0.0 LO SOLIDS LITLY DISP 10.20 44.0 9.8 5.8 151.0 2.650 69.0 1.281 151.0 3.670 68.0 0.000 0.0 MUD CAKE AT MT: MUD CAKE AT BHT: 2.320 0.000 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): 1.5 REMARKS: DIFL/GR REPEAT PASS. NO REPEAT PASS WAS RECORDED FOR THE CN/ZDL/GR TOOL STRING. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P2 - 16 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 SP DIFL 68 1 MV 6 VILM DIFL 68 1 MV 7 VILD DIFL 68 1 MV 8 CILD DIFL 68 1 MMHO 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 TEN DIFL 68 1 LB 13 SPD DIFL 68 1 F/MN 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 53 419 67 0 4 4 04 522 10 6 4 4 04 522 10 6 4 4 34 704 23 6 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 52 * DATA RECORD (TYPE# 0) Total Data Records: 153 1014 BYTES * Tape File Start Depth = 10554.000000 Tape File End Depth = 9866.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 218654 datums Tape Subfile: 5 230 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 93/ 9/22 01 **** REEL TRAILER **** 93/ 9/27 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 27 SEP 93 10:33a Elapsed execution time = 51.96 seconds. SYSTEM RETURN CODE = 0