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Home My WebLink About196-043MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, November 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-02A PRUDHOE BAY UNIT Z-02A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/26/2025 Z-02A 50-029-21814-01-00 196-043-0 W SPT 8539 1960430 2135 617 623 619 619 49 94 99 99 4YRTST P Bob Noble 11/2/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT Z-02A Inspection Date: Tubing OA Packer Depth 8 2372 2302 2288IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN251103155044 BBL Pumped:4.8 BBL Returned:3.9 Wednesday, November 26, 2025 Page 1 of 1           MEMORANDUM TO: Jim Regg P.1. Supervisor V - I z'(j -q-7in l FROM: Austin McLeod Petroleum Inspector I Well Name PRUDHOE BAY UNITZ-02A IInsp Num: mitSAM211108195243 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 23, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC Z -02A PRUDHOE BAY UNIT Z -02A Src: Inspector Reviewed By: P.I. Supry 113F - Comm API Well Number 50-029-21814-01-00 Inspector Name' Austin McLeod Permit Number: 196-043-0 Inspection Date: 11/7/2021 Packer Depth Well Z -02A Type Inj w 'TVD 8539 - Tubing PTD 1960430 ":Type Test SPT ,Test psi 2135 IA BBL Pumped: 3.7 ' ',BBL Returned: 3.7 OA Interval-. - - ---- - - _ , -- - -- -i -- - aYRTST P/F P ✓, Notes: MITIA. Ran out to 60min due to inj psi fluctuations. Pretest Initial 15 Min 30 Min 45 Min 60 Min 1296 1270 1300 - 1259 1245' 1251 87 2377 ' 2340 - 2326 2307 ' 2298 ' 50 235 242 246 242 239 Tuesday, November 23, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jjtp ROgg C2 DATE: Wednesday,November 08,2017 P.I.Supervisor l � « v`(7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. Z-02A FROM: Brian Bixby PRUDHOE BAY UNIT Z-02A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z-02A API Well Number 50-029-21814-01-00 Inspector Name: Brian Bixby Permit Number: 196-043-0 Inspection Date: 11/8/2017 Insp Num: mitBDB171108133646 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-02A Type Inj W. TVD 8539 1 Tubing 1491 1493 1497 1496 PTD 1960430 Type Test SPT Test psi 2135 IA ' 47 2498 2479 - 2473 BBL Pumped: 3.6 BBL Returned: 3.6 - OA 56 154 156 . 155 - Interval 4YRTST P/F P ,/ —Notes: sumo FEB Wednesday,November 08,2017 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program ❑,/ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:lj•rf he_X J)J( "Q 1(1-1— 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 196-043 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-21814-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU Z-02A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9879 feet Plugs measured 9645 feet true vertical 9242 feet Junk measured 9702 feet JAN 1 1 2016 Effective Depth: measured 9645 feet Packer measured See Attachment feet true vertical 9012 feet Packer true vertical See Attachment feet OGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 33-113 33-113 Surface 2634 13-3/8"68#L-80 33-2667 33-2667 5020 2260 Intermediate 7254 9-5/8"47#L-80 29-7283 29-6881 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9506-9528 feet 9548-9600 feet 9612-9638 feet 9662-9690 feet True vertical depth: 8876-8898 feet 8917-8968 feet 8980-9005 feet 9029-9056 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSSV 2090 2090 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 2 BANNED - r4 `r�U'!L 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 7241 0 2270 Subsequent to operation: 8510 0 2417 14.Attachments:(required per 20 AAc 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service Ed Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG RI GINJ 0 SUSP 0 SPLUG 0 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: 315-712 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wi✓pro)) Title PDC Principal Engineer Signature12:6 (�t/�—� Phone +1 907 564 4424 Date 1/11/16 Form 10-404 Revised 5/2015 ISL //3/U., RBDMS� IAN 1 2 2016 Submit Original Only • • a) a 0 0 0 0 0 0 C/3 CO (OI� O O N O N U) IC) O N V I- N- N- I- U w 0 0 0 0 0 L N N CO CO CO CO O CO r- V Cr CO Ln CO CO CO CO CO N- V CO O M CO 00 O O 00 CO (O CO Ln N CO CO CA CO 00 H N CO N CO Cr) CA CO 0) f— O CO CO N V CO N Cn CO CO CO 41 G) CONCONNwM E COCO Cr) M N O) CO N O 00 co N N- 0) 0) CO O) V i i i i I i Q Cr) CO CA CO O- N- 0) C) C Ch CO N CO O N O N (O N- = rn CO � 0- 0 CD 00 moo O CO oo ao CO J J J = N 0c0 J CO C.0•(/) N O 4 N N 0 0 _ N __ U - M N = N N co I N- 4 V V L 4 4 O N N O M 10 O) co O ()) C 00 O N N N 00 C)) N N N N W C W W ' U U u a c Z Z Z D W W W m Cm O D H Z Z : : U CnF- 0 1110 Packers and SSV's Attachment PBU Z-02A SW Name Type MD TVD Depscription Z-02A SSSV 2090 2089.98 4-1/2" MCX I-SSV Z-02A TBG PACKER 6730.33 6393.05 4-1/2" Baker S-3 Perm Packer Z-02A PACKER 6806.46 6461.69 7" Baker ZXP Top Packer Z-02A TBG PACKER 9135.86 8538.48 4-1/2" Baker S-3 Perm Packer IIIVVELLFERD= MCEVOY NOTES: H2S REAi71NGS AV8 AGE 125 ppm 0 2 A ON MI.WELL REQUIRES A SSSV WHEN ON ACTUATOR= OTIS ' MI. OLD WELLBORE NOT SHOWN BELOW MILLOUT KB.ELEV= 91.76' BF. EV= 55.46' WINDOW. REV KOP= 3100' Max Angie= 31°@ 8285' Datum MD= 9514' ] J ( 2090' —14-1/2"HES X NP,ID=3.813" Datum TVD= 8800'SS 13-3/8"CSG,68#,L-80,D=12.415J—{ 2675' Minimum ID = 3"625" @ 8983' 6693' —4-1/2"HESX MP,D=3.813" 14-112" MILLED LANDING COLLAR _.._ / 0 6724' —19-5/8"X 4-1/2"BKR S-3 PKR,D=3.958" 6761' —4-1/2"HES X NN?D=3.813" 6800' F-9-518'X 7"BKR ZXP C2 LNR TOP PKR, D=4.87" 1.1 ►�/ 6817' —9-518"X 7"BKR HMC LNR HGR D=6.25- 4-1/2"TBG,12.6#L-80 TCN,.0152 bpf,D=3.958' H 6822' m,, '4* 4'41 6822' --14-1/2"WLEG,D=3.958" 11.1 0.1.1 111 011 6823' —17'X 4-1/2"XO,13=3.92' ,1/11 111 11111 111 111 �4� 7071' - 49-5/8"X 7"BKR ZXP PKR WfTBK,ID=6.31" N 11 �1 7085' 9-5/8'X 7"BKR IA4C LNR FiGR,D=6.25" // ,44 .� •, 8983' 1—4-1/2"LANO14G COLLAR,MLLED 13=3.625" 1 .�� 8994' —14-1/2'FLOAT COLLAR,MLLE)D=3.625 9-5/8"MLLOUT VVI DOW 7284'-7334' 11 II��i 9045' —4-1/2""PORTE D E JOINT,D=3.958' 4 J Nt ►� 4• 40 .j', 9090' I—7"X 4-1/2"UNIQUE OVERSHOT 0%* 9097' —TBG STUB(10/19/05) •\\•• NHD k• 9127' 4-1/2"HES NP, =3.813" ••••�•�•j•�•j .► 9137' F-7"x 4-112"BKR S-3 PKR,D=3.875" ►�•�•�•�•�•�••• ♦••••••♦ ••••••••• •••• 9160' —14-112"FSS X NP,D=3.813" l •• ••••••••••••••44,• 9-5/8"CSG,47#L-80 BTRS,D=8.681" — 9259' •� ....�� 9182' 4 1/2"HES XN NN?D=3.725" 9195' 4-1/2'WLEG 4-1/2"LNR,12.6#,L-80 TCN,.0152 bpf,13=1958" —1 9088' ` 9183' H Et-MO 4-1/7 TBG,12.6#,L-80 BTC-M.0152 bpf,ID=3.958" H 9193' ` _ 9645' 1'11 NE1 FERFORA TION SUMMARY ' 350-700 R8 LOG:SONIC ON 04/15/96 HEX PLUG ANGLE AT TOP PERF: 15'@ 9506' (12/14/15) Note:Refer to FYoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ /` 2-7/8" 6 9506-9528 0 01/03/13 FISH: TS ATTACF-ED TO 3"BP PUSHED —19702' ELM 3-3/8" 2 9506-9528 S 09/04/96 1k TO BTM(32')(NEW TAG 01/02/13) \ \ 3-3/8" 2 9548-9600 0 09/03/96 \ 14 3-3/8" 2 9612-9638 0 09/03/96 pBTD ---1 9747' �'�\\1\%0 2-78" 6 9662-9690 C 01/02/13 \`1`'p 7"LNR,29#,L-80 BTC-M,.0371 bpf,1)=6.184" —1 9833' , DATE REV BY COMMENTS . DATE REV BY COMMENTS FRUDHOEBAY INT 06/28/88 ORIGINAL COMPLETION 09/13/12 WEGJMD FISH CORRECTION(10/04/05) WELL: Z-02A 04/19/96 CHH RIG SIDETRACK(Z-02A) 01/17/13 JJUJMD ACPff2F/F 'EF /FESH RETAG(01/C PERI1 T No: 1960430 10/14/05 N4ES RWO 12/15/15 DHS/JMD SET HEX PLUG(12/14/15) API No: 50-029-21814-01 12/05/05 DAV/TLH DLG DRAFT CORRECTIONSL _ SEC 19,TiT11N,R12E,4303'FSL&3492'F 02/16/11 Mi3/JMD ADDEDSSSV SAFt1Y NOTE 01/23/12 TMNOMD ADDED H2S SAFETY NOTE V BP Exploration(Alaska) ' OF Ty, • • �w��\,„„-. THE STATE Alaska Oil and Gas ----- s off/� , _� , i.'9TSs�=_= _- -cLAsKA. Conservation Commission Witt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov SCANNECI DEC 0 32015 Kaity Burton Pad Engineer j3_6:12L____. 3 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-02A Sundry Number: 315-712 Dear Ms. Burton: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, a/6 /a9xe,11.--- Cathy P. Foerster Chair DATED this day of November, 2015 Encl. & RBDMS) DEC 012015 RECEIVED STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMc� ON N O V 2 0 2015 APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 A G C 1. Type of Request: Abandon 0 Plug Perforations 0 t Fracture Stimulate 0 Repair Well ❑ perations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc • 4. Current Well Class: 5. Permit to Drill Number: 196-043, 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21814-01-00 , 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 13/ PBU Z-02A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028262 , PRUDHOE BAY,PRUDHOE OIL S 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9879 ` 9242 • 9748 " 9113 • 9702 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 33-113 33-113 Surface 2634 13-3/8"68#L-80 33-2667 33-2667 5020 2260 Intermediate 7254 9-5/8"47#L-80 29-7283 29-6881 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment / See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 12/10/15 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature '1,r Phone +1 907 564 5554 Date1(i20/2-06 vI COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315 — 712_ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0/ Spacing Exception Required? Yes 0 No I3" Subsequent Form Required: `0 "-LIM '/ APPROVED BYTHE � ` Approved by .t,y,F-t�� COMMISSIONER COMMISSION Date:4'� W ./s ?A /I/Z3/Ar- c� ,(R�C� ORIGINAL 1/3/s— 1Azy., r AY/A,0 RBDMS'' DEC 01 15 Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. S a0 0 0 0 0 0 c6 O M O N O O N U w . . . . . . N N M (O M M 7O oD m Lom O M M M M O w . m .0 m N (O CO O) (O M • i i l i l II NM N M M O) (O O) N- O M M N d- (O N M M O M M r— M ,_ N M M CO cO O) M N O7 M N O O M N N- O) O) (O O) • p 44g:4 Q O Lo M M o O r- I- m • • M M N 00 O N O = N M D = 1:10 H a O o O O O m00 mm = N D c (D J y O O V *k N N U _ N U M N N N d) 44 M LO O) (OO O M O O) C 00 (O N N r` O O) J N N- N N M w C0 wH '47) 0 ° O O Z Z ZUJWLU O D H Z_ Z_ D D • • a) N L6 m V CO CO Ln L N- O N CO a I— 00 Ln c0 m a) co O in O co a) O O CI co co a) 0) > I- a_ 0 I- a) — 0) « CO N N- CO Q (0 N- 0) 0 0 O CO a) a) O > O CO CO CO 0) 0 > 1- w cc 0 0 o w z LU w 0 w o H H J a W dg Y U O > m 0 O O w Y Y F- w 2 ui t CO O CO O J J J Q Q (/) W a 41 ti CV CD CO CY) ZUJCN Lo 0 0 0 U < W W o 03 0) CD 0) _ _ _ J JO a ii i W pt E U U 0 id Z z W w w a F- F- Q J Q V Q 2 2 O (n u) (n (n co C N Q I a N I- C . ..c Ca 0 N N Q O 0 O W 0) a) a0) a0) co CL L a) O E � Q) 0 J = 0 (/) t 2 2 O (n (n (n (n Ln a) a 0 0 c 2 LL C CC L. id 0_ a_ a. 0. O t 0) 0- a) I- is n • N- co co 2 D D• 0O O W O a) a) O Z W 1 1 < W r r N O W M coo co N p a O L J O N W N N- - r • 0 0. Q a J H J J W 0 Et a O CO OEDEW J J Q O W W < < T) a 30 V) LL LL LL co 0_ CL a) E m z Q Q Q Q N N N N (n O O O O m a a a OU J WU' NU' w U- K., N N.! N a a s m m a a own_a w • • Packers and SSV's Attachment PBU Z-02A SW Name Type MD TVD Depscription Z-02A TBG PACKER 6730.33 6393.05 4-1/2" Baker S-3 Perm Packer Z-02A PACKER 6806.46 6461.69 7" Baker ZXP Top Packer Z-02A TBG PACKER 9135.86 8538.48 4-1/2" Baker S-3 Perm Packer • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: Z-02A Well Type: WAG Injection Well API Number: 50-029-21814-01 Well Activity Conventional 4 Classification: Activity Description: Profile modification Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, 20 bopd: Estimated Cost, Job Type: Profile Modification $K. AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None Sundry Form 10-403 requirements? Required? Yes Sundry Form 10-404 Yes PrimarySecondary Required? Engineer: Kaity Burton Contact numbers: (907)564-5554 (907)360-6002 Well Intervention Engineer: Ryan Thompson Contact numbers: 907-564-4535 907-301-1240 Lead Engineer: Laurie Derrick Contact numbers: (907)564-5952 (720)308-3386 Date Created: November 4,2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate lnj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 11/3/2015 0 13,039 2,291 Current Status: Operable Flowing Inclination>70°at Depth(ft) NA NA 125 Maximum Deviation(Angle and Recent H2S (date, ppm) ppm Depth) 31° 8,285' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 11° 7,688' MD Reservoir pressure(date, 9/4/2014 3379 @ Z-40 Minimum ID and Depth 3.625"@ 8983' milled landing collar psig) Reservoir Temp,F 135(on injection on water) Shut-in Wellhead Pressure Known mech.integrity problems(specifics) Last downhole operation(date, 10/13/2014 SL set new MCX operation) Most recent TD tag(date,depth, 1/2/2013 9,699'MD CT FCO,addperfs toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, Z-02Ai is a WAG injector under the gas cap in the Highland State FB of EWE.The well was drilled in 1988 background information, and sidetracked in 1996.The well was worked over in 2005 to repair a tubing and PC leak.The well has etc: injected one full WAG cycle and is currently MI cycle 2. Z-02Ai supports offset producers Z-03a,Z-40,Z- 65,Z-50,Z-34,and Z-11 a.This area of the Highland State FB was very actively developed over the course of 2011-2012 and 5 new production wells were drilled here. Many of these new wells produced thousands of bbls of fluid daily and with only two pattern injectors,Z-02A and Z-12,in the area,so in 2013 addperfs were added in Z-02A for better pattern conformance as well as to inject more water into the pattern after a failed attempt to increase injectivity with DAD acid pumped in 2012. The addperfs were initially very successful at increasing iniection and pressure has been stable in the • i pattern. Over the last two years the injectivity of Z-02A has continued to increase,as if a thief zone is developing. It is suspected,based on permeability differences,that the 41 P is becoming the thief zone, and MI is slipping below the 41 N shale. There is no IPROf to prove this. The purpose of this job is to bypass the need for an(PROF and set a plug,using injectivity to gauge if the thief was indeed the 41 P perfs shot in 2013. There is a chance that the increasing injectivity is a product of the 46P becoming a thief but rock quality cannot explain this,and if this is the thief we are still in good conformance. ,/ Well Z-40 is the biggest producer in pattern and saw significant MI response to other pattern injector Z-12, but has yet to see noticeable response to Z-02A injection. This is suspected to be due to the vertical perm barrier(the 41 N shale)providing a baffle between where MI is thought to be injecting and where Z-40 produces. The aim of this procedure is to isolate the 41 P perfs and bring Z-02A injection back in conformance with the pattern./A retrievable plug will be set in the case that injectivity change is not seen and pllug pull is desired. Voidage is no longer a significant concern with many wells in pattern SI on marginal sorts and Z-67 coming on injection this fall. This job aims to decrease injection rates but should be valued on the conformance it brings within pattern. Well Intervention Details Suspected Well Problem: Injection is out of conformance Specific Intervention or Well Objectives: 1 Force MI injection into zones above the 41 N shale 2 3 Key risks,critical issues: Mitigation plan: Plug set and pull is cheap on slickline/eline and if no 1 no(PROF,plug does not change injectivity change in injectivity is seen then injection is in conformance(unless chanelling occurs) 2 3 Summary Service Line Activity Step# 1 S SL pull MCX @ 2090' MD. Drift and tag with 350-700 HEX plug drift and TEL. Run 40 arm caliper from TD to surface. Minimum caliper depth 9700'MD. 2 E Set Interwell HEX plug(350-700)at target set depth of 9650' MD. Avoid setting slips/element within 2'of collars. 3 S Set MCX @ 2090' MD. MI Target is 8mmscf Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: NA MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Place well back on MI injection once plug set is complete Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • 0 IRE*= 4'ON SA 1 L I Y NOT ES: 14L.S REA DINGS AVERAGE 126 ppm W1-11 HE-A 0- MCEVOY ACTUATOR- ORS Z-02 Awin4 ON MI.WELL RCQUIRFS A sssv wurm cm KB FIB/ 91 , .f!, 01 prat t mow pc 1:worm ti ow mit I OM = NV ; 14414XAN. BF R EV, 53 48' KOP- 3100 Mu Angle- 31'CS 878f7 Dal km IC- 9514' I '', 2090j-t4LIL2•149 X INV,0=3 1113"j MC-S. 041.40!VD- 8800 SS ..„.., 13 3,Fr -CSC 'E1Ril i PO,ID .-T71 -1 -10it. -, L Minimum ID to 3.626"(el 8983' I ii 1etsr }-14-wr 14:8 X MP,0•3 413' 4-112" MILLED LANDING COLLAR 0 CEll - 5724' ) it"SW X 4-Ur OCR*7 • 1 39M j I 63-X'1 41 6800' - < :-1 . •< *(7 It, , 681/ 14-10'TE1G,1281 LBOTC* 0152W„4).3.9511” 114122' •,,,.r ft at 6 5 7.1 '4 4 1,1 75'4 5973' j-.47*X 4-1/2"X0,0.•312" 1 4 4 441 .01 '.. .. 11.1 0.1 •4) t1 0.1 a'01 7071' 149-51e X 7'13KR ziepiiiilt ves,,,,D=41,1:.]•r • 4' 7065. 1-ir x r macNtallC UR PER.CP•6 25* I 1 4 :. 44 11 4 • new j--E1-10'LA14340 CIMLAR LOLLED ID-3 425' i ° 0 . $119C 4-1f2'FLOAT COLLAR.14L-LED 0.3625' p*I 9-5d8 14..L01J11111.001N 7264'.7334 .0. iodic , 4- RIRTMIPUP KIM:0-3 nit.-- se I I •• b. -4,,‘.• '0 IV 4 -, 9090' ,--fr X 4-1/2-urwovutst-or 1 909T ma site t tam%) :•:+•;,..:f. • .4 ., in TT 4-1/2•14M X NP, .3 111 3- I i•.::::.: .o. "' ' 10 177 , :::::.:::::.:.•1111ir,iiiiio, 0••••••••••••••.• iiii-01r7 111:3 X'il I'..U 3 13'j t:•••••••:•:+:44,'I ..0 i:•:•:*[ ,..4:40:441:44 NET1'1872"--1-FF2"FE5 X N MP 0-31 9-smr CSG,411 L-410 1311S,I).&eel-J-L 9259' I ......... , Iiii• )-j4 1,2'WIG 14-1/2"044,128. L-80 TCA 0152 441.O.3,954. 9088' j , ----' ... 9183' -1 Et- rt"2"113G.,1284.1 80 MON C.152 Opt.ID-3.1ma- Ff wei• \ , • n4 0 RM-CRATON SUINIARY , REY LOG,S.3PIC ON 04/15195 ANCIE AT TCP F471 15**3505' Nob Role,to Roduebon DB for Paolo mai pod dab SIZE SFr INTERVAL %NSW SLUT . SCE 2-Mr 8 9508.9528 0 01433713 1 . REIN TS A TTA10.0)TO 3"BR RAPID —{-foii 3-11Ir 2 9600-9528 S j0904/98 TO 811A(32)(PEW TAG 01432/13) I -44414 3-343" 2 9548 9803 0 090&98 ! 3-3.43' 2 9612 9635 0 09,33.096..L._............-.. 14111111k4,.t11%.‘. FOTO 9747' j Niit471,11. 2-titf 0 9002-3090 0 0102113 IJ"tHR,294,L-40 13TC-111,.0371 L...4„0-010.4' 1-E 9933' 1 DATE-1 R-E--C/ 3Y 00034:NM DA TE REV BY 004.46414TS FRLONIDE BAY UPC 0612111115, 0400114AL COUR.ET1ON 0013712 IAECIJIAD FISH CC14E1190/4(10,04705) 161aL Z-02A 041194.0, C144 140 SIDETRACK(Z-024) '01117713_MUM.) ACIFERF7RFEERFIFISH 8E74010147 RE341.4T Pb 1960430 10/1406 PRI33 WOO - MI F 50 029 21814 01 ..- - 1270605 I 01‘vrru1-ct0 cRkr—r CORRECTIONS — SEC 19,71114.R12E.' 4303'FSL 53497 FEL 02/16/11 M&J10 ADDED SS-SV SAFETY PC1TE 1 01/73/12 i DAVAO AIXID PDS SA1-14Y WTI, EPP Et ploratio n(Alaska) ... • 0 Wen:2-02A bP I , 1 KIVU/6 i SEST GP , 0E5,,DEEP CALC MAD XGE000 0 API ISO 001ST 000 000 " 10000 1 1101A4 W000 CALC WURD.KGE050 , , — ,s, cs,Lc*up c, .- 1 4000 FEET 0000 001 10000 3 0 ,, CALCw" 01PD NET 20 50 0 210 03 001 10000 1, 000030000 0 % 100 0 Vi, I d ENNFEir...PAW torptp....4kh, eA"C 7N"50"T* ..-'”"....,, ,,,-.,,.,,. 3 CMG WURD.P141 fatortir rariNti* bESTCAU (1,111T) WES?) 4.'7 EtE5;11C0 0 VES,SKAL k . ROT 44,Pulc • * BES,••tt SRAX • 'A pg IA 0:200 1,200 ,Iir u5dr 55 a 1 oNAINI 1000 0 ,. 00 R,3 1 DI) 1---"1 C."',17,\j,RD'SW ' '''Ho DOW 0 I : 1 8760 • , , • I. ; I I:94801 I. • II I ; .1 `8780! I- 1 t 9500-i 8800 I , ' 2 . , 8820 ' „.. ., .f.. 9540 , .. i ;8O 9560 ', <,.. 0 0 0 5---> ----1-I &- • ....— 4 0 0 + •8860• 14 0 0 I 1 . , ,""8880: , 8900 , ; ; 5) 9620: i t , S--"? 600 „., i. (8920 9640 ' tI t , • 1 ; ,-8940 ' ---;.> 1 , , I 9660 1;"60 e I !' , , , ,.,,• I 8980 ! + . , I ...„.,.., ; A0002. . 1 . --- LI, ,........ ,.,„ • • FILE COPY r.ca WESTERN DIGITAL ARRAY ACOUSTILOGs" ATLAS FILE NO-6654.00 COMPANY P EXP OR(4T ON (A AKA) INC. WELL Z-02A _. API NO F I ELD °Ri.JDHa.. BAY .02)--21t4.4-Zi COUNTY NORTH SLOPE STATE ALASKA LOCAT ION: OTHER SERV ICES 4323' F5t.. & 381W FEL J IFL 04 FMT FINAL PQM SEC 19 TKP RCE j ELEVAT IONS PERMANENT DATUM ri L ELEVATION FT KB 85. F T LOC MEASURED FROM RK 9 95 16 ABOVE P D DE 34.28 7T DRILL. KEAS. FROM R K Q. 53.94 FT DATE I 5-APR-95 RUN ONE SERV ICE ORDER 182593 DEPTH,DR I LLER 9885 FT DEPTH LOCCER 9818 FT BOTTOM LOWED INTERVAL 9160 FT TOP LOCCED INTERVAL, 9208 FT CAS I NG DR I LLER .9.625 _IN .7294 CASING LOGGER T • HIT SI/F. :) ' TYPE OF FLUID IN HOLE 1 DENSITY / VISCOSITY :AVG !.• H c3 SOURCE OF SAMPLE. RR AT MEAS. TEMP 8 74 CPtII 4V4 RMF AT MEAS TEMP. IV 91 oHrr 71 6F RMC AT NEAR TEMP, 54 o.r •58 DEGF SOURCE OF RMF . ASURED IF4F ASuRED RN AT BHT IV 25 ORM, DEGF • TIME SINCE CIRCULATION 4 1025 MAX, RECORDED TEM'. ?0! DEGF EQUIP. NO / LOCATION HI. 6577 IN. SLOPE ii frf WITNESSED RY DANSCN • • _ : m ` 111 €iter , .... :rteiw WINNarmass a. a iameraticaa 44fii . rgcti. w, 3 in 4 P r i I1! !_ Tr�M i i'ii _.ii PO 4_ r . .mss _. -1 arra':- - i: :; a lin. t ,. r t ! o fi} s (am am NM I( II' -=ii ni Illarill as iiiillifol, = _riita ,,„ : , ,may, j_. . - r m. ...... ____. a 40,0*.i. ... moNigisa. „„,„„sionalin,_ 11.. iiiiiiiiamare 4, 4t,r� WIrma ,� Immo i i " �t W 11 - 4b3 4 'i'1itfl _.. w. _..r P , i .. .nig! ra�rr iloop 2 , ' Main , 4. matli , ' inivalair-111.1aleintilmisamillili ..,,i,,,„.4,,ii ' t 1 ., . .--a-, p.._. y. _.. _ I._.. : . ... (1. a ; 1 t .. . _.. F1i! .. ..... a .... ,+...r. s.�{,RLJ� .,..,.�.,• true . _'� ,; •_ + . �. a s.„._ ,... . ... ....r..,, ._...»_. i r-. i ,},, asmos amiat. »_,,, .J...I .. • 350-700 HEX E4_ite N2 Castomer 6FxA Date 8t17t2015 Freie&'.b' i! Prudhoe Bay Rev.:0 Addrtioral Project no..: 15-273124 00 'r.i O r:ri Lerzr ;'i; Asse,-b y 'J.€-ign•i is Oescrpt:or Supear ty Cat,*nea3 CCL 7C t,.'A C 43 2 2 E-Ure avec I 11"GO Pin 000 u s i nte-*& 13=16`GO W,Y t 3 80 %'A 81.57 N Claryr to a ei� dew 43�t6't.ClDoi� + 3 6e R'A 4? 171.e8 36-ttyvostatc e'erq Toe i to wel^ wart!net r 3 2C �'A CO g e ErcaraE-,kr:a^c • . me we!' 11111 Fri 1111 3`,C r‘r,A . 200.62 3E0-70c HEX Irae*weil mart I 1 � Assy.Ler+gth:{ft) 24.92 43f C' er'cat on i^;fed t 0ate& Ser interwell STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COMMON JAN 2 4 2013 REPORT OF SUNDRY WELL OPERATIONS A°GGo 1. Operations Abandon U Repair Well U Plug Perforations U Perforate l✓] Other U Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ - 196 -043 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029- 21814 -01 -00 1 7. Property Designation (Lease Number): 8. Well Name and Number: . ADL0028262 PBU Z -02A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted - PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9879 feet Plugs measured None feet true vertical 9242.24 feet Junk measured See Attachment feet Effective Depth measured 9747 feet Packer measured See Attachment feet true vertical 9112.4 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor None None None None None None Surface 2646 13 -3/8" 68# L -80 29 - 2675 29 - 2674.98 5020 2260 Intermediate None None None None None None Production 7306 9 -5/8" 47# L -80 28 - 7334 28 - 6926.58 6870 4760 Liner 2762 7" 29# L -80 7071 - 9833 6696.94 - 9196.99 8160 7020 Perforation depth Measured depth 9506 - 9528 feet 9548 - 9600 feet 9612 - 9638 feet 9662 - 9690 feet True Vertical depth 8876.39 - 8897.74 feet 8917.21 - 8968.03 feet 8979.79 - 9005.28 feet 9028.84 - 9056.35 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 9195 27 - 8590.82 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 213 NEp MAR Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1298 18164 0 0 911 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator10 Developmer Service Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . Gas WDSPLf GSTOR ❑ WINJ ❑ WAG x GINJ LJ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays((�bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Air Signature Mill_ r /O � ,`„�. Phone 564 -4035 Date 1/23/2013 RBDMS JAN 2 8 21 . / Y �, 2/0 iVl 2 / 1 113 Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028262 * * SUMMARY CTU #9 1.75" CT. Job Scope: •, . "e 1/1/2013 MIRU. « <In Progress »> CTU #9 1.75" CT. Job Scope: FCO, AdPerf « <Job Continued from 1/1/13 »> Finished rigging up, RIH w/ slim 1.75" JSN. Stopped at tubing tail, shut well in, and freeze protected flow line. Continued in hole and tagged at 9630'CTM, 9624'CTM up depth. Jetted in a little bit to make sure we could jet and we could. Cleaned down to 9703'CTM, 9696'CTM up depth, taking three total bites and a final gel sweep, chased out at 80% to surface. FP backside w/ 24 bbls 60/40. RIH w/ PDS MEM GR /CCL in 2 -7/8" carrier w/ 3.25" JSN drift. Tag TD at 9699'CTM. Flag pipe at 9570'CTM. Log up from TD to 8850'CTM at 40 fpm. POOH. Good PDS GR /CCL data. Tied into Tie in Log: SLB IPROF dated 14- March -2011 (Ref Log: Atlas DA dated 15- APR -96) , +6' correction. Corr tag depth 9,702'ELM. RIH w/ 28'x 2.875" PJ Omega Perf Guns. At flag 9,593'CTM. Correct depth to 9,575.8'ELM. RIH to TD. PU to top shot at 9,662'ELM. Drop 1/2" steel ball and perforate 9,662- 9,690'ELM. POOH. Confirmed guns fired. RIH 1/2/2013 w/ 22'x 2.875" PJ Omega Perf Guns. « <Job in Progress »> T /I/0= 1600/600/400 Freeze Protect FL with 5 bbls neat meth CTU on well 1/2/2013 has control (annulus valves open to gauges) FWHP= 1600/600/400 CTU #9 1.75" CT. Job Scope: FCO, AdPerf « <Job Continued from 1/2/13>>> RIH w/ 22'x 2.875" PJ Omega Perf Guns. At flag 9,588.9'CTM. Correct depth to 9,576.8'ELM. PU to top shot at 9,506'ELM. Drop 1/2" steel ball and perforate 9,506- 9,528'ELM. POOH. Confirmed guns fired. Finish RD. 1/3/2013 « <Job Complete »> FLUIDS PUMPED BBLS 5 METH 158 60/40 METH 442 1% SLICK KCL 39 POWER VIS 644 TOTAL • • Packers and SSV's Attachment ADL0028262 SW Name Type MD TVD Depscription Z -02A PACKER 6724 6303.09 4 -1/2" BAKER S -3 PERM PACKER Z -02A PACKER 6800 6371.64 7" BAKER ZXP PACKER Z -02A PACKER 7071 6612.7 7" BAKER ZXP PACKER Z -02A PACKER 9137 8455.25 4 -1/2" Baker S -3 Perm Packer • • Z -02A 196 -043 -0 Junk Attachment SW Name MD Date Description Z -02A 9680 37633 Z -02A 9702 1/2/2013 0:00 NEW TAG IBP PUSH TO BOTTOM TREE= 4 " CNV W • aUEAD= MCE1/OY S�Y NOTE3: H2S READINGS AVERAGE 125 ppm K B. a TOR = 1.76 Z -O A MOLD WB- NOT SHOWN BELOW M K B. H 91.76' BE BEV = 55.46' WINDOW. KOP= 3100' Max Angle = 31° , 8285' Datum M)= 9514' I 2090' H4 -1/2" HES X NP, D= 3.813" I Datum TVD = - 1800' SS I] J 113 -3/8" CSG, 68#, L -80, D = 12.415' H 2675' Minimum ID = 3.625" @ 8983' 1 6693' H4 -1/2" HES X NP, D= 3.813' I 4 -1/2" MILLED LANDING COLLAR 0 6724' H9 -5/8" X 4-1/Z' BKR S-3 RCR, D = 3.958" I I 6761' H4 -1/2' FES X NP, D = 3.813' I I 6800' H9-5/8" X 7' BKR ZXP C2 LNR TOP PICK, D = 4.87" 1 e 6817' H9-5/8" X 7" BKR HMC LNR HGR, D = 6.25' I 4-1/2 12.6#, L -80 7'C .0152 bpf, D = 3.958' H 6822' I i ,1'• 4 ',,' 6822' H4-112- WLEG, D = 3.9518' I ■ � ' . ' 1 ' . • 6823' H7" X 4-1/2' X0, D = 3.92" I ■ . 1 'i 7071' H9 -5/8' X 7' BKR ZXP RtR WTBK, D = 6.31" I • I I ' I 7086' H9-5/8" X 7" BKR HMC LNR HGR, D = 6.25" I t 1� • 8983' H4 -1/2" LANDING COLLAR PALLED D = 3.625" I A 8964' H4-1/2* FLOAT COLLAR ® D MLL = 3.625" I 9-5/8' MLLCN l7' M'1)OW 7284' -7334' 1 �� ■ , I 9045' H4 -1/2' PORTED PUP JOINT, D = 3.958" I x. ■ • 9090' H7"X4- 1/7 UNIQUE OVERSHOT I 4,.. ♦ • 9097' I-�TBG STUB (10/19/05) I ►iiii`..•♦ ES 9127' H4- 1/2'FXNP,D =3.813" I ►�. *. 4424:•♦ `I 9137' H7'x4- 1/2 " BKR S- 3PKR,D= 3.875' ► �.....♦ ► ∎ 5160' H4 -1/2' HES X NP, D = 3.813" I V4Vit4VAN 4: ` [9 -5/8 CSG, 47# L-80 BTRS, D = 8.681" H 9269' I 1. &`'W � & � � � A � A � ( 9182' H4'1/2" HES XN NP, D = 3.725' 9196' 4-1/2" MEG 4-1/2' OR 12.6#, L -80 TCN, .0152 bpf, 13= 3.958' 9088' 9183' B-MD I4 -1/2' TBG, 12.6#, L -80 BTC-M, .0152 bpf, D= 3.958' 9193' ` PERFORATION SUMMARY ` REF LOG: SONG ON 04/15/96 ANGLEAT TOP FE RE: 15 9506' ` Note: Refer to Production DB for historical pert data Gi ilat -Am . t1:... '-" . >� SQZ 4 Oa 11111 9506 - 9528 0 01/03/13 F1SIt TS ATTACH TO 3' BP RUSHED —I 9702' ELM I 9548 -9600 0 09/04/96 TO BTM (32') (NEW TAG 01/02/13) \ a ;`k 874T I N, ■ _9612 - -9638 • +' ,ox 0, :. R3TD '�� ' 9862 - 9690 0 01/02/13 \4 4► 7" LNR, 29#, L-80 BTC-M, .0371 bpf, D = 8.184" 9833' • DATE REV BY CX)MM34TS DATE REV BY MOMENTS PRUDHOE BAY MT 06/28/88 ORIGINAL COMPLETION ; 09/13/12 WEC/JM) FISH CORRH.'T ON (10/04/05) WB.L• Z -02A 04/19196 CHI RIG SIDETRACK (Z -02A) 01/17/13 JJUJM) ADPBRF/FEPE RF/F1SH RETAG (01/0 FBRIAT No: 1960430 10/14/05 N4ES RWO AR No: 50- 029 - 21814-01 12/05/05 DAV/TLH DLG DRAFT CORRECTIONS SEC 19, T11 N, R12E, 4303' FSL & 3492' FEL 02/16/11 111/JM) ADDED SSSV SAFETY NOTE 01/23/12 TM'YJM) ADDED H2S SAFETY NOTE BP Exploration (Alaska) ' STATE OF ALASKA w ALASKA. AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIO S `.w } 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ imiilaglifilsai f - ct y „ i . (, ,, Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter S spended Well 1=1110 02i,-. , 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: _ Name: Development ❑ Exploratory ❑ - 196 -0430 3. Address: P.O. Box 196612 Stratigraphic❑ Service 12 6. API Number: Anchorage, AK 99519 -6612 r 50- 029 - 21814 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028262 PBU Z -02A 10. Field /Pool(s): - PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 9879 feet Plugs (measured) None feet true vertical 9242.24 feet Junk (measured) 9680 feet Effective Depth measured 9747 feet Packer (measured) SEE BELOW feet true vertical 9112.4 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" X 30" 30 - 110 30 - 110 Surface 2646' 13 -3/8" 68# L -80 29 - 2675 29 - 2675 4930 2270 Production 7306" 9 -5/8" 47# L -80 28 - 7334 28 - 6927 6870 4760 Liner 2762' 7" 29# L -80 7071 - 9833 6697 - 9197 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - - True Vertical depth: _ _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 9195 27 - 8591 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 6724 6387 7" Baker ZXP Packer 6800 6456 7" Baker ZXP Packer 7071 6697 4 -1/2" Baker S -3 Perm Packer 9137 8539 12. Stimulation or cement squeeze summary: Intervals treated (measured): MAR (11 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 1673 1288 Subsequent to operation: 2357 1430 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service ~ IO Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: - Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG Ell GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Nita Summerhays Printed Name Nita S merh. Title Data Manager drArAir Signat • Vin, vi � i Phone 564 -4035 Date 2/28/2012 p obt, 9, ' 6 Z Submit Original Only Form 10 -404 Revised 10/201d�3DMS FEB 2 I Oil Z -02A . 196 -043 PERF ATTACHMENT Sw Name Operation Date Pelf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z -02A 4/25/96 PER 9,506. 9,528. 8,876.39 8,897.74 Z -02A 4/25/96 PER 9,548. 9,600. 8,917.21 8,968.03 Z -02A 4/25/96 , PER 9,612. 9,638. 8,979.79 9,005.28 Z -02A 9/3/96 SPS 9,533.1 9,638. 8,902.6 9,005.28 Z -02A 9/4/96 SQZ 9,506. 9,528. 8,876.39 8,897.74 Z-02A 9/8/96 SPR 9,533.1 9,638. 8,902.6 9,005.28 Z -02A 8/30/01 BPS 9,270. 9,280. 8,657.92 8,666.92 Z -02A 9/4/01 MLK I 7,071. 7,072. 6,696.94 6,697.82 Z -02A 2122103 SPS 7,231. 9,270. 6,836.24 8,657.92 Z -02A 10/4/05 BPP 9,270. 9,280. 8,657.92 8,666.92 Z-02A 10/4/05 SPR 7,231.1 9,270. 6,836.24 8,657.92 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 1 SL SLOTTED LINER _ BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FIL I FCO ' FILL CLEAN OUT 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 1 • • . 03 -11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY $N A - : :4 Z itY ;7 :: -tea 1/28/2012 TWO = 1120/720/300. Temp. = 142 °. IA FL (Pre- acid). PW. IA FL @ surface. SV = C. WV, SSV, MV = O. IA & OA = OTG. NOVP. 12:30 2/19/2012T/I/O = 1100/830/310. Temp = SI. IA FL (Pre- Acid). IA FL @ surface. Choke SI itemperarly for pigging SV = Closed. WV, SSV, MV = Open. IA & OA = OTG. NOVP. 12:30 2/20/2012,T/I/0= 720/820/300, Temp =lnj, Pump Acid treatment (Acid) Pumped 3 bbls meth 'spear followed by a total of 68 bbls of 1%KCL to achieve an injectivity test of .5 BPM @ 920 psi, 1 BPM @ 1020 psi, 2 BPM @ 1230 psi, 3 BPM @ 1300 psi, 4 BPM @ 1420 psi, 5 BPM @ 1500 psi. Pumped 141 bbls of acid followed by 3 bbls meth flush and 52 bbls of 1 %KCL. Soak for 1 hr. Pumped 40 bbls of 1 %KCL. Soak; for 1 hr. Perform post Acid treatment Injectivity test at 1 BPM @ 1180 psi, 2 BPM @ 1250 psi, 3 BPM @ 1310 psi, 4 BPM @ 1380, 5 BPM @ 1450 psi. Freeze protect hardline with 5 bbls meth. FWHP 1150/340/40 Notify Pad OP well is ready to put on injection. FLUIDS PUMPED BBLS 10 METH 141 7.5% Dad Acid 367 1% KCL 518 TOTAL • ' TREE= 4" CtW SAFET ES: H2S READINGS AVERAGE 125 ppm WELLHEAD = MCEVOY WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR = OT1S1 Z -, 321k MI. OLD WELLBORE NOT SHOWN BELOW MILLOUT KB. ELEV bi:6.1 WINDOW. BF. ELEV = 55.46' KOP= 3100' Max Angle = 31° • 8285' Datum P/6= 9 I 2090' H4-1/2" HES X NIP, ID = 3.813" I Datum TVD = 8800' SS 113 -3/8" CSG, 68#, L-80,10 = 12.415" -1 2675' Minimum ID = 3.626" @ 8983' 1 6693' H41 /2' HES X NIP, ID = 3.813" 4 -112" MILLED LANDING COLLAR ►mot 0 6724' H9 -5/8" X 4-1/2" BKR S -3 PKR, ID = 3.958" 1 6761' H 41 /7' HES X NIP, ID = 3.813" 1 6800' 1-19-5/8" X 7" BKR ZXP C2 LNR TOP PKR, ID = 4.87" 1� � �.1 6817' H9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.25" I [4-1/2" TBG, 12.6#, L -80 TCII, .0152 bpf, ID = 3.958" H 6822' 4 , I , � ' #1 ' V; 6822' H4-1/2" WLEG, ID = 3.958" ! • 41 ∎j�• 6823' --17" X 4 -1 /7' XO, ID = 3.92" I t /•1 . 0 .. ' 1 4 � 7071' 1+5/8" X 7 BKR ZXP PKR W/T1B ID = 6.31" 1 1 # 1 ∎ 4 I 7085' H 9 -51 X 7" BKR HMC LNR HGR, ID = 6.25" I 1 .1 � 1 1 *1 • ; 8983' 1-14-1/T LANDING COLLAR, MILLED ID = 3.625" ► • j 1 + 8994' H4-1/2" FLOAT COLLAR, MILLED ID = 3.625" j 9 -5/8" MILLOUT WINDOW 7284' - 7334' 1�1 v. ` • • 4• , ,, I 9045' H 4-1/2" PORTED PUP JOINT, D = 3.958" ■ • 4 4, � s 9090' H7" X 4-1/2' UNIQUE OVERSHOT I ►.% '. , ■ 4 `, 8097' _ I TBG STUB (10/19/05) I ► i i i * i i i`. N g. - 9127' H4.1/2" HES X NIP, ID = 3.813" j ►�i - It. •••••• N. I 9137' H 7" x 4-1/2" BKR S -3 PKR, ID = 3.875" ••••••••• •••••••••• 1 9160' 4-1/2" HES X NIP, ID =3.813" ■•••••••• I9 -518" CSG, 47# L -80 BTRS, ID = 8.661" 9259' I 9182' H4 -1/2" HES XN NIP, ID = 3.725" OEM 4-1/2" WLEG 14-1/2" LNR, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" I 9088' I 9183' I-{ ELMD 1 14.1/2" TBG, 12.6 #, L -80 BTC -IVI, .0152 bpf, ID = 3.958" I 9193' ' PERFORATION SUMMARY ` REF LOG: SONIC ON 04/15/96 ` ANGLE AT TOP PERF: 15 9506' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 O 09/03/96 1 FISH: 3" IBP PUSHED TO BTM (10/04/05) 9680' • 14 al; . ftic . 3-3/8" 2 9612 - 9638 0 09/03/96 �441\`�,� PBTD --I 9747' 1 ♦ �� ` V N 17" LNR, 29#, L -80 BTC-M, .0371 bpf, ID = 6.184" H 9833' �` DATE REV BY ' COMMENTS BATE REV BY ' COMMENTS PRUDHOE BAY UNIT 06/28/88 ORIGINAL COMPLETION WELL: Z -02A 04/19/96 CHH RIG SIDETRACK (Z -02A) PERMIT No: '1960430 10114/05 N4ES RWO API No: 50- 029 - 21814-01 12/05/05 DAV/TLH DLG DRAFT CORRECTIONS SEC 19. T11 N, R12E, 4303' FSL & 3492' FEL 02/16/11 MB/JMD ADDED SSSV SAFETY NOTE 01/23/12 TM■JMD ADDED I-12S SAFETY NOTE BP Exploration (Alaska) • • scgo[E 0[F A[LtmA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Carolyn Kirchner Petroleum Engineer BP Exploration (Alaska), Inc. 0 43 P.O. Box 196612 ` Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z -02A Sundry Number: 311 -194 Dear Mr. Kirchner: JUN tv 9 2U U 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 % day of June, 2011. Encl. STATE OF ALASKA Y �� , .) r: _ ■ � // ALASKA, AND GAS CONSERVATION COMMISSIO ''"" """ APPLICATION FOR SUNDRY APPROVALS iIN 9 2 'tii 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New P0010 Repair Well ❑ r r Suspend ❑ Plug Perforations ❑ Perforate0 Pull Tubing ❑ Time Extension • x SCt l dj 4Cle Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate el - Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 196 -0430- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service o _ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21814 -01 -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: Spacing Exception Required? Yes ❑ No ❑ PBU Z -02A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028262 - PRUDHOE BAY Field / PRUDHOE BAY 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): 9879 - 9242.24 _ 9747 9112.4 NONE 9680 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20 "X30" 30 110 30 110 Surface 2646' 13 -3/8" 68# L -80 29 2675 29 2675 4930 2270 Production 7306' 9 -5/8" 47# L -80 28 7334 28 6927 6870 4760 Liner 2762' 7" 29# L -80 7071 9833 6697 9197 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 28 9195 Packers and SSSV Tvoe: 4 -1/2" Baker S -3 Perm Packer Packers and SSSV MD and TVD (ft): 6724 6387 7" Baker ZXP Packer 6800 6456 7" Baker ZXP Packer 7071 6697 4 -1/2" Baker S -3 Perm Packer 9137 8539 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/15/2011 011 ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ _ GI J ❑ WAG M Abandoned ❑ Commission Representative: 6j••// GSTOR SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Carolyn Kirchner Printed Name Carolyn Kirchner Title PE Signature / /// 1 Phone Date 62 ;,;� i'�.t. 1 ' 6/1/2011 Prepared by Joe Lastufka 564 -4091 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I I P4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / b L' QLi APPROVED BY j I Approved by: COMMISSIONER THE COMMISSION Date: 4, / 7/ RBDMS MAY o 9 BM ORIGINAL / 6.70 i 0 w /if Form 10 -403 Revised 1/2010 Submit in Duplicate Z-02A 196 -043 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z -02A 4/25/96 PER 9,506. 9,528. 8,876.39 8,897.74 Z -02A 4/25/96 PER 9,548. 9,600. 8,917.21 8,968.03 Z -02A 4/25/96 PER 9,612. 9,638. 8,979.79 9,005.28 Z -02A 9/3/96 SPS 9,533. 9,638. 8,902.6 9,005.28 Z -02A 9/4/96 SQZ 9,506. 9,528. 8,876.39 8,897.74 Z -02A 9/8/96 SPR 9,533. 9,638. 8,902.6 9,005.28 Z -02A 8/30/01 BPS 9,270. 9,280. 8,657.92 8,666.92 Z -02A 9/4/01 MLK 7,071. 7,072. 6,696.94 6,697.82 Z -02A 2/22/03 SPS 7,231. 9,270. 6,836.24 8,657.92 Z -02A 10/4/05 BPP 9,270. 9,280. 8,657.92 8,666.92 Z -02A 10/4/05 SPR 7,231. 9,270. 6,836.24 8,657.92 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 • Memorandum To: Tyler Norene /Clark Olsen Date: June 26, 2011 GPB Well Ops Team Leaders From: Carolyn Kirchner Code: APBZPDWL02 Petroleum Engineer Subject: Z -02ai Bullhead Acid Stimluation AAIOR: 75 Est. Cost: Sundry approval #: Please perform the following procedure: 1 F Bullhead Acid stimulation Current Status: WAG injector — currently PWI Last Test: 04/25/11 2600 BWPD, 1600 psi WHIP Max Deviation: 31 deg © 8285' MD Perf Deviation: 15 deg @ 9506' MD Minimum ID: 3.625" @ 8983' 4 -1/2" milled landing collar Last Downhole Op: 03/14/11 IPROF Last Drift: 03/11/11 Tagged sticky bottom at 9644' SLM — all perfs clear Latest H Value: N/A SBHP /SBHT: 01/11/03 3787 psi, 230 degF at 8800 TVDss, currently estimated at 3660 psi Reference Log: 04/15/96 Sonic log Program Objectives: Following a drift and tag that showed all perfs to be uncovered and an IPROF showing nice distribution, it ,/ has been decided that an acid stimulation would be valuable to improve the injectivity of this well. Well History: Z -02ai is a WAG injector under the gas cap in the Highland State FB of EWE. The well was drilled in 1988 and sidetracked in 1996. The well was worked over in 2005 to repair a tubing and PC leak. The well has injected one full WAG cycle and is currently injecting water. Z -02ai supports offset producers Z -03a and Z- 11a. An MI response has not been seen in Z -39a, likely due to faulting. Please contact Carolyn Kirchner at 564 -4190 (W), 227 -6169 (C) with any questions or comments. cc: Well File Ann Comm: Problem Status RWO 10/05 fixed tubing leak, RWO 10/05 fixed tubing leak, ran liner to fix PC leak ran liner to fix PC leak > 09/28/03: MIT -OA to 3000 psi Passed Conductor treated w/ 3.4 gal > 10/13/05: Rig tested MITIA Passed to 4000 psi RG2401 - 07/24/09 > 10/14/05: RWO fixed tubing leak, installed liner over PC leak > 11/25/05: Injectivity test • • > 12/13/05: AOGCC MITIA Passed to 1900 psi > 01/16/07: IA & OA FL's @ surface > 07/24/09: Conductor treated w/ 3.4 gal RG2401 > 11/27/09: MITIA Passed to 4000 psi > 11/30/09: AOGCC MITIA Passed to 2000 psi Risks & Discussion • A sundry will be required for the stimulation of this injector. • Maximum pressure throughout the job corresponds to a 0.65 psi /ft frac gradient with water in the wellbore. It is ok to exceed this if needed i.e. if the perfs become plugged and it is necessary to go to higher pressure to displace the acid out of the tubulars. Maximum pressure in this case is 4000 psi. • MCX is out of well. / oN wk"raK Z N S. • Estimated Fluid Summary — Confirm by Slope for Order Form o 125 bbls 7.5% HCL with 20% xylene and additives as per SLB o - 500 bbls of 1% KCL, Acid recipe: 120 bbls 7.5% HCI + 20% xylene 4 gal /Mgal A264 ACI Corrosion Inhibitor 2 gal /Mgal F103 Flowback Aid, Surfactant 20 Ib /Mgal L058 Iron Control 5 gal /Mgal W054 AntiEmulsifier Notes: L -80 tubing and liner. Acceptable acid concentrations are +/-1% for HCI. BHT is 125 °F. PROCEDURE Pre job 1. IA FL shot to confirm loaded to near surface with liquid. Fullbore Acid Stimulation No GLVs in well. NOTE: Contact the facility ahead of the job to ensure acid can be taken to the plant as a contingency if injectivity is lost. 2. Stage transports and necessary equipment and tanks to pump job. 3. MIRU Fullbore. Ensure well is SI. Monitor and record IA and OA pressures throughout job. 4. Open well and line up down the production tubing with 1% KCL. Perform an injectivity test at 1.0, 2.0, 3.0, and 4.0 BPM. Make last rate at maximum pump rate. Do not exceed 1700 psi WHP. Note results in WSR. 5. Pump the following down the tubing at max rate, 1700 psi maximum pressure: Stage Fluid Volume (bbls) Comments 1 HCL 125 2 1% KCL 52 SD 1 hour (25 bbls through perfs) 3 1% KCL 40 SD 1 hour (65 bbls through perfs) 4 1% KCL 40 SD 1 hour (105 bbls through perfs) 5 1% KCL 20 6. Perform final injectivity test as before at 1.0, 2.0, 3.0, and 4.0 BPM. Make last rate at maximum pump rate. Do not exceed 1700 psi WHP. This is the final maximum rate injectivity test to evaluate the entire job. Note results in WSR. 7. Place well on injection if possible. If it was necessary to load the IA, notify operator that the IA is fluid packed and monitor for thermal expansion. TREE = 4" CM/ • SAFETY : WELL REQUIRES A SSSV WHEN WELLHEAD UATOR = � OS Z �O z a M ILOUT WINDOW. � �� NOT SHOWN BELOW A KB. ELEV = 91.76' QF. ELEV = 55.46' KOP = 3100' Max Angle = 31 @ 8285' Datum MD = 9514' I 2090' H4-1/2'' HES X NIP, ID = 3.813" I Datum ND = 8800' SS 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 1 - 1 267 5' I I 6693' H4 -1/2" HES X NIP, ID = 3.813" I Minimum ID = 3.625" @ 8983' 4 -1/2" MILLED LANDING COLLAR I ►Z1 ►�I 6724' 9- 5/8"X4 -1/2" BKRS -3 PKR, ID= 3.958" I 1 I 6761' H4-1/2" HES X NIP, ID = 3.813" 6800' H 9 -5/8" X 7" BKR ZXP C2 LNR TOP PKR, ID = 4.87" I III 6817' f X 7" BKR HMC LNR HGR, ID = 6.25" I 4 -1/2" TBG, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" 6822' 6822' H4 -1/2" WLEG, ID = 3.958" I 0.1 .• 0+1 • • 6823' I-17" X 4-1/2" XO, ID = 3.92" I •• 0.1 � 1//1 • 11 j 7071' H9-5/8" X 7" BKR ZXP PKR W/TIBK, ID = 6.31" I 1 ! 1 . 1 I 7085' H9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" I 1 .1 t ' • • 8983' H4 -1/2" LANDING COLLAR, MILLED ID = 3.625" I 11 • & 8994' H4 -1/2" FLOAT COLLAR, MILLED ID = 3.625" 1 • 9-5/8" MILLOUT WINDOW 7284' - 7334' 1� •* ■ 4 1 9045' H4-1/2" PORTED PUP JOINT, ID = 3.958" I �♦♦ 4 ♦ `t i 'N 9090' HT X 4-1/2" UNIQUE OVERSHOT 1 ► • ♦ ♦ ♦�� %, 9097' HTBG STUB (10/19/05)J ♦♦♦∎ ♦♦ ► ♦ ♦ ♦ ♦ ♦ ` . ■# 9127' N4 -1/2" HES X NIP, ID = 3.813" 1 ■•••♦ ♦\ ■♦ •♦••♦ •♦ •, �' I lk •••••• • ' 9137' J x 4-1/2" BKR S -3 PKR, ID = 3.875" I ► ♦♦♦ •♦♦ ••••♦••• ■••••••• •••••••• 1.•••••••• 9160' 4- 1 /2 " HES X NIP, ID= 3.813" I ♦ •♦ ♦ ♦ ♦ ♦ ► ♦ ♦ ♦ :****:+:::::+.:41 ♦ ♦ ♦ � 4� I9 -5/8" CSG, 47# L -80 BTRS, ID = 8.681" H 9259' I ` ♦•♦� ♦ : ♦ : ♦ : ♦• ♦• 9182' H4 -1/2" HES XN NIP, ID = 3.725" 9195' 4 -1/2" WLEG I4 -1/2" LNR, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" I--I 9088' I 9183' I - I ELMD 1 I4 -1/2" TBG, 12.6 #, L -80 BTC-M, .0152 bpf, ID = 3.958" I 9193' PERFORATION SUMMARY ` REF LOG: SONIC ON 04/15/96 ` ANGLE AT TOP PERF: 15 @ 9506' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 2 9506 - 9528 S 09/04/96 3 -3/8" 2 9548 - 9600 0 09/03/96 FISH: 3" IBP PUSHED TO BTM (10/04/05) I 9680' Nip. � 1 3-3/8" 2 9612 - 9638 0 09/03/96 I PBTD I - I 9747' I �i� --- -- .1144 \ 1 7" LNR, 29 #, L -80 BTC-M, .0371 bpf, ID = 6.184" ( - I 9833' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/88 ORIGINAL COMPLETION WELL: Z -02A 04/19/96 CHH RIG SIDETRACK (Z -02A) PERMIT No: "1960430 10/14/05 N4ES RWO API No: 50- 029 - 21814 -01 12/05/05 DAV/TLH DLG DRAFT CORRECTIONS SEC 19, T11N, R12E, 4303' FSL & 3492' FEL 02/16/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) � 04/18/11 ScWide er NO. 5719 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -16 BCRD -00092 PRODUCTION PROFILE ( co 03/11/11 1 • • /� 1 14 -12 BBKA -00091 PRODUCTION PROFILE / (5 9 03/05/11 1 _ i' ! 1 Z -02A BJOH -00013 INJECTION PROFILE l) �' ,Q. I .— /`1 /3 03/14/11 1 _ • • / 1 13 -09 BDAD -00038 LDL UT Ml 03/19/11 1 • , • / 1 L5-36 BJOH -00014 PRODUCTION PROFILE — C. 03/16/11 1 - • • / 1 L4 -15 BBSK -00059 PRODUCTION PROFILE — •n 03/16/11 1 •_ �� /, 1 03 -25A BG4H -00042 PRODUCTION PROFILE — • _ 03/18/11 1 1 Z -112 BL65 -00021 MEM PROD PROFILE • =6 S!' - 1 1 F -35 BG4H -00037 RST / . - — • • / 02/23/11 1 /1 .. ( 1 J -17C BAUJ -00061 MCNL ■ • .—/ . 02/09/11 1 . p • ' 1 • 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 • ■ 4j \ t _ 2 ,0 , 1 APR 19 nil 'ssion MEMORANDUM To~ Jim Regg ~ r P.I. Supervisor I `~~t +~1 ~'l ~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 03, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Z-02A PRUDHOE BAY UNIT Z-02A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~~-- Comm Well Name: PRUDHOE BAY UNIT Z-02A API Well Number: 50-029-21814-01-00 Inspector Name: Bob Noble Insp Num: mitRCN091201053547 permit Number: 196-043-0 Inspection Date: 11/30/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ ~-02AType Inj. ~ ~' i 'I'VD ~ ---F---- - - -~ rt~---- P.T.D~ 1960430 ?T~,p SPT' i eTest i ~ Test pst ~ = ~ ~ 1 63a~ ~ IA ~ 0 ~- 2ptp ~~ QA~40 --- -- 2010 40 ~ I96o 1960 -~- 40 40 ~ _ - - - --_ _- - - --- InteCVal 4YRTST ~ p~F - P ; -- ~ Tubing ~ 310 ~ ~ 310 ~ 3]310 Notes: Thursday, December 03, 2009 Page 1 of 1 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~'4:D;~'i'»:UG~~ty r; • ~, R LU~L ._ ti ~ ~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, U bp : ~~~~~~~ OCT 0 ~ 2009 ~I~sk~ Dil Sa Gas Cons. GOIi~1-RR1An Anchorag~ 6~.0~.3 ~' ,(~, ~,~ Qa~`Y t" Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator I ~ • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/i 3/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 500292t9900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-08A 1931280 50029217870100 NA 02 NA 2.55 7l24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-t1A 20503t0 SQ029220530100 NA 0.2 NA 1.70 7l26/2009 Z-12 1891020 50029219770000 NA 1.2 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-146 2060990 50029218440200 NA 02 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 02 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 500292t9380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7l23l2~09 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 18901$0 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020~00 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50929218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 500292t9540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-32BL1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25l20Q9 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 IVA 1 NA 10.20 7/23l2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-108 20520t0 50029232920000 NA 1.5 NA 11.90 7/24/2009 z-112 2071720 5002s23380000o NA surface NA Well Job# Loa DescriDtion Date BL Color CD C-11A 11225983 LDL 07/02/06 1 B-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G·18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 B-28 11221590 LDL 07/04/06 1 B-01 11211508 PROD LOG W/DEFT 06/23/06 1 W·39A 11216197 MEM PROD PROFILE OS/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02106 1 G-03A 11211493 LDL OS/24/06 1 C·26A 11225979 LDL 06/07/06 1 F-26B N/A MEM PROD & INJECTION 06/06/06 1 F-26B N/A MEM BORAX LOG 06/06/06 1 W-39A 11216197 MEM BORAX LOG OS/29/06 1 F-04A 11221602 SCMT 08/18/06 1 Y -08A 11221604 SCMT 08/20/06 1 C-06B 11212883 USIT 08/15/06 1 X-27 11217274 USIT 08/26/06 1 K-07D 10942217 MEMORY SCMT 06/15/05 1 Y-10A 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 SBHP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15/04 1 A-30A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17-04B 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 I \N\{ V vz.:)JJþ,! V\^ 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04B PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth tC1 G?- 043 SCANNED SEP 1 4~ 2005 U'Xc, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 R·· -~- r:-'l-" r:-. '. .. - , "2 - :.. r....· ,; ¡) ~Lr 1 ~ 08/28/06 "\J00 NO. 3941 ~ÐiJ & Gas Cons. Co~ Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: Field: Prudhoe Bay . . Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth _ STATE OF ALASKA _ AlA~ Oil AND GAS CONSERVATION COMrWslON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Convert to Inj Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 11/27/2005 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 196-0430 3. Address: P.O. Box 196612 Stratigraphic D Service M 6. API Number: Anchorage, AK 99519-6612 50-029-21814-01-00 7. KB Elevation (ft): 9. Well Name and Number: 84.24 KB Z-02A 8. Property Designation: 10. Field/Pool{s): ADL-028262 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9879 feet Plugs (measured) None true vertical 9242.24 feet Junk (measured) 9680 Effective Depth measured 9747 feet true vertical 9112.4 feet Casing Length Size MD TVD Burst Collapse Surface 2646 13-3/8" 68# L-80 29 - 2675 29 - 2674.98 4930 2270 Production 7256 9-5/8" 47# L-80 28 - 7284 28 - 6882.25 6870 4760 Liner 2762 7" 29# L-80 7071 - 9833 6696.94 - 9196.99 8160 7020 "t'" ~)§-'.f if ~ ( i} .",',1\' ',' ,-; , ""' IV. , ',' . , ........ t) '..; L. ,l.J (J Perforation depth: Measured depth: 9548 - 9600 9612 - 9638 True Vertical depth: 8917.21 - 8968.03 8979.79 - 9005.28 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 28-9195 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 6724 7" Baker ZXP Packer 6800 7" Baker ZXP Packer 7071 4-1/2" Baker S-3 Perm Packer 9137 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:R81Jt4S BFl JUL 2 7 Z006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 1048 150 1100 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service M Daily Report of Well Operations 16. Well Status after proposed work: Oil D Gas D WAG D GINJ WINJ M WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 305-334 Contact Sharmaine Vestal Printed Name Sharmaine Vestal ~ Title Data Mgmt Engr Signat~ ~ Phone 564-4424 Date 7/27/2006 Form 10-404 Revised 04/2004 Submit Original Only MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission FROM: Jeff Jones Petroleum Inspector DATE: Thursday, December 15,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Z-02A PRUDHOE BAY UNIT Z-02A TO: Jim Regg ?é'4 IZj¡c;IAŠ P.I. Supervisor' '\ (1 ¡v Src: Inspector \ /' Q\.{-:) \~\() NON-CONFIDENTIAL Reviewed By: P.I. SlIprv ,Tb"'''-- Comm Well Name: PRUDHOE SAY UNIT Z-02A API Well Number 50-029-21814-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ051213 172259 Permit Number: 196-043-0 Inspection Date: 12/13/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~~~II T-Z=o~~~1~i~~i;fLW1_!V~~___I---6387--rJA-r~:~__1--l90ó . 1860 ]850 " l I ' ~~~~~ª]1960:~~y~~!e;;~~::=~~=E~=_~__~=~=5 i"-~~~t;~oo____' -.-.~:~-. 620 630 1200 1200 Notes 2.7 BBLS 60/40 methanol pumped. I wel! house inspected; no exceptions noted. (, Thursday, December 15,2005 Page I of I TREE" e 4"CIW WELLHEAD = MCEVOY A CTUA TOR" OTIS KS. ELEV = 91.76' -~ SF. ELEV " 55.46' KOP= 3100' -- Max Angle = 31 @ 8285' ---~-~- Datum MD = 9514' Datum TVD = 8800' SS Z-02A NOTES: OLD WELLBORE NOT SHOWN BELOW MILLOUTWINDOW. 2090' 14-1/2" HES X NIP, ID = 3.813" I 113-3/8" CSG, 68#, L-80, ID= 12.415" H 2675' Minimum ID = 3.625" @ 8983' 4-1/2" MILLED LANDING COLLAR 6761' 6800' 6817' 6822' 6823' 6693' 6724' 14-1/2" TSG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" I 6822' I 9-5/8" MILLOUT WINDOW 7284' - 7334' 19-5/8" CSG, 47# L-80 STRS, ID = 8.681" H 9259' 14-1/2" LNR, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 14-1/2" TBG, 12.6#, L-80 BTC-M, .0152 bpf, ID" 3.958" PERFORA TION SUMMA RY REF LOG: SONIC ON 04/15/96 ANGLE AT TOP PERF: 15 @ 9506' Note: Refer to Production DS for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 0 09/03/96 3-3/8" 2 9612 - 9638 0 09/03/96 I FISH: 3" ISP PUSHED TO STM (10/04/05) I 4-1/2"HESXNIP,ID=3.813" I I 9-5/8" X 4-1/2" BKR S·3 PKR, ID = 3.958" 14-1/2" HES X NIP, ID = 3.813" I 19-5/8" X 7" BKR ZXP C2 LNR TOP PKR, ID = 4.87" 1 19.5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 14-1/2" WLEG, ID = 3958" I 17" X 4-1/2" XO, ID = 3.92" I 19-5/8" X 7" BKR ZXP PKR W/TIBK, ID = 6.31" 19-5/8" X 7" BKR HMC LNR HGR, ID = 6,25" I 14-1/2" LANDING COLLAR, MILLED ID = 3.625" I 14-1/2" FLOAT COLLAR, MILLED ID = 3.625" I I 17" X 4-1/2" UNIQUE OVERSHOT 1 ITBG STUB (10/19/05) I 14-1/2" HES X NIP, ID = 3.813" I I 7" LNR, 29#, L-80 BTC-M, .0371 bpI, ID = 6.184" I 9747' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/88 ORIGINAL COMPLETION 04/19/96 CHH RIG SIDETRACK (Z-02A) 10/14/05 N4ES RWO 12/05/05 DAV/TLH DLG DRAFT CORRECTIONS PRUDHOE BA Y UNIT WELL: Z-02A ÆRMIT No: "1960430 API No: 50-029·21814-01 SEC 19, T11 N, R12E, 4303' FSL & 3492' FEL BP Exploration (Alaska) 11/28/05 Schlumberger C~\,1~r':1 .~=»< ~ ":J &- V NO. 3613 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '2 j: 20t]5 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 '. j\ , ' ~~;~ ., ,.....,"'"";.,.ti.~." cüne.. 1~;,;;!~~~üW~1~ I ÙJjthi)íage Field: Prudhoe Bay, Milne Pt. WII b# BL e Jo Log Description Date Color CD PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT '/9/0- 0.4-3 10/06/05 1 S-14A 10987547 USIT 09/13/05 1 Y-1OA 10889216 SCMT 02/21/05 1 D.S. 03-33A 10893093 SCMT 03/05/05 1 C-19B 10928633 SCMT 05/15/05 1 09-20 10889215 SCMT 02/18/05 1 D.S.09-31C N/A SCMT 11/05/05 1 P-06A 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT 07/04/05 1 D.S. 06-20 11062630 USIT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: \ \ I if~'\ \ 06 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R".;~d b,fu~(j G ~ ~ÇANNEf..J DEG 1 6 2005 , I 10-404, Z-02A e e Subject: 10-404, Z-02A From: "Huhble, Terrie L" <HubblcTL@BP.com> Date: Wed, 16 Nov 2005 10:33:14 -0900 To: bob _ ncckcnstein(~i}admin.state.ak.us Hi Bob, You called yesterday in regards to this 10-404 for Z-02A. Permit to Drilt#196-043.' The 10-403 (prior to the workover) indicated that we would Plug Perforations, Pull Tubing, Repair Well. Apparently that was only partly true. We planned on Pulling the Tubing and Repairing the Well, but not to Plug Perforations. So, on the resulting 10-404, I did not check the box for Plug Perforations. Thanks for bringing the earlier error to my attention. Terrie ~ÇANNEt.J DEG 1 {) 2005 RBDMS BFL NOV I 7 2005 ~ 1 of 1 11/16/2005 12:37 PM STATE OF ALASKA RECEIVED ALAS~L AND GAS CONSERVATION Ccel1lSS10N NOV 14 2005 REPORT OF SUNDRY WELL OPERATI91;i~j&Ga$con.. ··C.·O'-"t.' · ..nil .8Ion A. .._ 1. Operations Performed: -'" o Abandon o Suspend o Operation Shutdown o Perforate o Other o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory ...~, > 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21814-01-00 7. KB Elevation (ft): 84.24' 9. Well Name and Number: PBU Z-02A 8. Property Designation: 10. Field / Pool(s): ADL 028262 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9879 feet true vertical 9242 feet Plugs (measured) None Effective depth: measured 9680 feet Junk (measured) 9680 true vertical 9047 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2675' 13-3/8" 2675' 2675' 4930 2270 Intermediate 7284' 9-5/8" 7284' 6882' 6870 4760 Production 2762' 7" 7071' - 9833' 6697' - 9197' 8160 7020 Liner Liner Tieback 2290' 4-1/2" 6800' - 9090' 6456' - 8498' 8430 7500 (into old tubing tail) 107' 4-1/2" 9088' - 9195' 8497' - 8591' 8430 7500 Perforation Depth MD (ft): 9548' - 9638' Perforation Depth TVD (ft): 8917' - 9005' 4-1/2", 12.6# L-80 Surface to 6822' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer; 7" x 9-5/8" 'C-2' ZXP Liner 9137'; 6800'; 6724' Top packer; 9-5/8" x 4-1/2" Baker 'S-3' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft NOV 1 5 2005 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 181 Well Schematic Diagram 16. Well Status after proposed work: 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that tne foregoing IS true ana correct to tne best Of my knowledge. I Sundry Number or N/A If C.O. Exempt: Contact David Reem, 564-5743 305-269 Printed Name Terrie Hubble Title Technical Assistant ~¡\^; ()~ ~ / Mfp Ph~ne \\J'O/n <; Prepared By Name/Number: Signature . . , ,., 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04i2004 ., ì \ Submit Ori Inal Onl 9 Y · .. - Page 1 of 13 BP Exploration Operations Summary Report Description of OperationsLI ..__ _____. ____.__ _...__._. __. .__ _u_.........±Jilli PJSM. Scope down & layover derrick. Rig down rig components. PJSM. Move rig & rig components from MP L pad to GPB Z pad. 24 mile move. While moving rig sub, driver of sow saw what he thought was a board in the road, moved over to the side & stopped. Rig sub module subsequently sank down & became stuck. Driver attempted to pull sub out & snapped driveline. Call for mechanic & plywood. Continue to repair driveline & plywood up rig sub. Continue moving rig from MP L pad to GPB Z pad. Continue moving rig from MP L pad to GPB Z pad. MIRU Primary Unit Accept Rig @ 19:00 hrs R/U Lines to Tree and Tiger Tank Hold Safety Meeting Test Lines 250 psi low 3500 psi high. Tubing = 0 psi, IIA = 60 psi, OIA = 0 psi. DECOMP Circulate 529 bbls of 120' Hot Seawater at 4.5 bblslmin @ 60 psi getting till returns of Seawater. Pumped (52) bbls before hitting fluid in tubing. Estimate fluid level in tubing @ 3452'. DECOMP Circulating 529 bbls of 120' Hot Seawater, around Shut in and monitor well. Tbg went on Vaccum. Monitor well. Well static. Set TWC and Test 3500 psi RID lines and Blow down N/D tree PJSM. N/U 135/8" x 5M BOPE. PJSM. Conduct full test on BOPE, 350 14000 psi. Witnessing of test waived by State AOGCC inspector Jeff Jones. Test wtinessed by Nabors Toolpusher & BP rep. DECOMP PJSM. Pick up lubricator & pull BPV. LID lubricator. DECOMP PJSM. Pick up landing joint. BOLD's. Straight pull, see hanger come free @ 90K. Pull to 125K, pipe not free. Bring on pump @ 4 bpm 1125 psi, 14 bbls to fill tubing. See clean seawater returns. Pull to 205K & see pipe pull free. New up wt = 88K. Pull hanger to floor. PJSM. Circulate @ 4 1/2 bpm 1125 psi, bottoms up. Pull hanger & landing jt. LID same. R/U control line spooling unit. Pull & LID 11 jts 4 1 2/" tubing & SSSV assy. Recovered 15 bands, 100% recovery, RID spooling unit. Lost 8 bbls of fluid while on continuous fill. DECOMP Con't to POOH & LID 4 1/2" completion. DECOMP Con't to POOH & LID 41/2" completion. Recovered 166 jts of tubing, 3 GLM Assys, SSSV Assy & 8.56' parted jt of tubing. Clear & clean rig floor. RID tubing handling equip. R/U to P/U 3 1/2" DP. Install Wear Bushing. Load, tally & M/U BHA to polish Tie-Back recepticle. BHA # 1 as follows: 7.44" Polish Mill, XO, Spacer Sub, Top Dressing Mill, 1 jt DP, XO, 3·Boot Baskets, XO, XO, 95/8" Csg Scraper, Bit Sub, Bumper Sub, Oil Jars, 12 . 4 3/4" DCs. DECOMP PJSM. Slip & cut drilling line. Estimate top of tubing stub wI Nabors 4ES RKB difference figured in @ 7088'. (19 jts plus 8.56' of cutoff jt below last GLM recovered)..., (3) GLMs recovered. Estimate top of tie back @ 7071'. Discuss wI town. Opt to Stand back collars, LID polishing BHA & pick up BHA to Legal Well Name: Z-02A Common Well Name: Z-02A Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date ~ From - To ¡Hours l Task I Code' .. -~..- . . .-..-- ..-r--..... 9/18/2005 15:00 - 19:00 4.00 RIGD P NPT ¡ Phase I _._n__i__ PRE 19:00 - 22:00 3.00 MOB P PRE 22:00 - 00:00 2.00 MOB N HMAN PRE 9/19/2005 00:00 - 03:00 3.00 MOB N HMAN 03:00 - 06:00 3.00 MOB P 06:00 - 18:00 12.00 MOB P 18:00·21:00 3.00 RIGU P 21 :00 - 22:00 1.00 RIGU P 22:00 - 23:30 1.50 KILL P 23:30 - 00:00 0.50 KILL P I 9/20/2005 00:00 - 02:30 2.50 KILL P 02:30 - 03:00 0.50 KILL P 03:00 - 03:30 0.50 WHSUR P 03:30 - 05:30 2.00 WHSUR P 05:30 - 10:30 5.00 BOPSUF P 10:30 . 14:30 4.00 BOPSUF P 14:30 . 15:30 1.00 BOPSUF P 15:30 . 16:30 1.00 PULL P PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 16:30 - 18:30 2.00 PULL P 18:30 - 19:00 0.50 PULL P 19:00 - 20:30 1.50 PULL P 20:30 - 00:00 3.50 PULL P 9/21/2005 00:00 . 02:00 2.00 PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 04:00 1.00 CLEAN P 04:00 - 06:30 2.50 CLEAN P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 06:30 - 08:00 1.50 CLEAN P Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: Spud Date: 3/29/1996 End: 10/14/2005 Printed: 10/17/2005 7:36:17 AM BP Exploration Operations Summary Report Legal Well Name: Z-02A Common Well Name: Z-02A Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES ]·1 I ! From - To ' Hours: Task ; ! Date __i 9/21/2005 06:30 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 16:00 16:00 - 17:30 17:30 - 20:00 20:00 - 22:30 22:30 - 00:00 9/22/2005 00:00 - 00:30 00:30 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 10:00 10:00 - 12:30 Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: ¡Code 1 NPT I Ph:se : P DECOMP P DECOMP P DECOMP P DECOMP P DECOMP 1.50 CLEAN 1.50 CLEAN 1.00 CLEAN 5.50 CLEAN 1.50 CLEAN 2.50 CLEAN P DECOMP 2.50 CLEAN P 1,50 CLEAN P DECOMP DECOMP 0.50 FISH 2.50 FISH P P DECOMP DECOMP 1.00 FISH P DECOMP 2.00 FISH P 4.00 I FISH P 2.50 FISH P DECOMP DECOMP DECOMP 12:30 - 15:30 3.00 CLEAN P DECOMP 15:30 - 19:00 3.50 CLEAN P DECOMP 19:00 - 21 :30 2.50 CLEAN P DECOMP 21 :30 - 00:00 2.50 CLEAN P DECOMP 9/23/2005 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 06:00 5.50 CLEAN P DECOMP 06:00 - 11 :00 5.00 CLEAN P DECOMP 11 :00 - 18:00 7.00 CLEAN P DECOMP Page 2 of 13 Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations -...----.-.-.... .._.____n_ mill tubing to chemical cut. POOH, stand back collars, UD BHA#1. Pick up tubing dress off BHA#1. RIH wI milling assembly on 3 1/2" DP, picking up 1x1. Kelly up on jt # 213 & establish parameters. 111 K up wt, 101 K down wt, 105K rotating wt. 3 BPM @ 330 psi. See top of liner @ 7073' & tag top of tubing stub @ 7079' DPM. Mill (2') off tubing stub. Mix up 20 bbl. viscosified brine sweep and circulate around to clean hole. Sweep recipe - 3 sks. N-Vis, 1 cup PH6 & 1.5 cups caustic soda. POH wltubing BHA#1 standing DP back in derrick. UD BHA#1 Load, tally and MU BHA#2. BHA#2 as follows: 1 x 5.875" cut lip guide, 1 x 5.875" OS, 1 x 5.875" extension, 1 x 5.875" top sub,1 x 4.750" BS, 1x 4.750" oil jars, 9 x 4.625" DC & 1 x 4.750" Accelerator. Continue to M/U BHA#2. RIH w/BHA#2 and 3.5" DP. Kelly up. Up wt = 110K, down wt = 100K, rotating wt = 105K. Engage top of fish @ 7092'. Circulate at 3 bpm @ 270 psi. Jar and work pipe at 85K over string weight. Pulled free. String weight increased by 5K#. Attempted circulate long way. No-go. Pulled 3 jts. DP. Broke reverse circulation. Circ. BU @ 5-6 bpm at 700 psi. Recovered sand and parrafin. RBIH, tag 10' high @ 7080', wash down to 7090' & reverse circulate hole clean @ 5 bpm I 850 psi. Recovered abundant sand, a few rocks, (1" x 3/4" x 1/2") and some metal shavings. PJSM. POOH w/3 1/2" DP fishing BHA. PJSM. UD fish. 91.62' OAL. Bottom cut off joint = 19.42'. New tubing top estimated to be 7183'. Milled off top of fish very smooth & pretty. Chemical cut on bottom of fish was also very pretty. PJSM. Pick up clean out BHA including muleshoe, (66) jts of 2 7/8" PAC, bumper sub, jars & DCs. RIH wI cleanout BHA on 3 1/2" DP. Vis up surface volume to 60 LSRV. TOH LDDP 41 its. RIH 50 std. from derrick to top of tubing stub @ 7183'. Reverse circulate 290 bbls. 40 vis fluid @ 3 bpm @ 550 psi to clean returns, some sand back. Circulate and condition hole to 60 LSRV viscosified brine. Condition complete fluid volume in pits to 60 LSRV. PU DP 1x1 - in 3 jt. groups and circulate bottoms up after 3rd. jt. and clean out 4.5" completion from 7126' to 7823'. Reverse circulating at 3 bpm @ 500 psi. Establish parameters. Up wt = 96K, down wt = 87K. WI 172 jts DP in hole, cleaning out 1/7823', reverse circulating each joint down, continuing to pump 17 - 20 bbls @ 4 bpm 1700 psi, making connections thusly, and completely reverse circulating every third connection to clean returns. LSRV = 40 - 50. Much fine 20/40 riversand back wI some thick asphaltine I parrafin like substance. Continue to clean out well bore as above, increasing pump rate to 4 bpm I 700 - 800 psi, reverse circulating 25 bbls between Printed: 10/17/2005 7:36: 17 AM Date 9/23/2005 Page 3 of 13 BP Exploration Operations Summary Report Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: Phase I DECOMP 18:00 - 19:30 1.50 CLEAN P DECOMP 19:30 - 23:00 3.50 CLEAN P DECaMP 23:00 - 00:00 1.00 CLEAN P DECOMP 9/24/2005 00:00 - 07:30 7.50 FISH P DECOMP 07:30 - 10:30 3.00 FISH N RREP DECOMP 10:30 - 12:00 1.50 I FISH P DECOMP 12:00 - 14:30 2.50 FISH P DECOMP Legal Well Name: Z-02A Common Well Name: Z-02A Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES í I: I I From - To : Hours I Task 'Code NPT - ------1 - 11 :00 - 18:00 7.00 CLEAN P 9/25/2005 14:30 - 15:30 1.00 FISH P DECOMP 15:30 - 16:00 0.50 FISH P DECOMP 16:00 - 18:00 2.00 FISH P DECOMP 18:00 - 23:00 5.00 FISH P DECOMP 23:00 - 00:00 00:00 - 02:30 1.00 FISH 2.50 FISH DECOMP DECOMP P P 02:30 - 06:00 3.50 FISH P DECOMP Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations ---. .. --.-- ---.. -... --- connections, & rev circulating bottoms up to clean returns every 3rd connection. Something hard @ 8606', got through OK, nothing unusual back over shaker. Continue to 9195', WLEG depth. Reverse circulate to clean returns, 4 bpm I 850 psi. Reverse circulate hole clean to prep to POH. POH UD 66 jts. 2 7/8" PAC DP. UD BHA#3. Rack and tally 177 jts. Range 3,4 1/2" BTC tubing. Rack and tally Range 2, 4 1/2" BTC tubing. M/U BHA#4 consisting of cut lip guide, OS w/4 1/2" basket grapple, extension and top sub. RIH to top of tubing stub @ 7183' picking up 4 1/2" BTC tubing 1 x1. Electrical problem. Unable to operate draw works. Shut down operation, troubleshoot problem. Continue to RIH w/4 1/2" 12.6# BTC tubing & overshot. M/U (9') space out pup on jt # 176, mlu jt # 177, see top of tubing stub 38' in @ 7185'. 84K up wt, 74K down. PJSM. Close bag & reverse circulate @ 5 1/2 bpm 1500 psi, easing down, see guide go over tbg stump, ease on down to just above pack off going over tubing stub & reverse circulate to clean returns. Pump (4) tbg volumes, still seeing light amount of fine sand coming back. Circulate long way @ 5 1/2 bpm 1500 psi to clear tubing of all sand, (1) tbg volume. PJSM. slack off to latch up fish, swallow 2-3'. Pull to 1S0K, (66K over up wt) & 50K over projected up wt to cutting depth. Set rotary slips & mlu collar clamp. NOTE: 54" of stretch wI 66K overpull. Estimated freepoint using (2) seperate formalas == 7350' & 76S0·...area of top GLM in hole. Safety meeting wI Schlumberger & rig crew with regard to operation at hand, rigging up pressure control equipment & cutting operations. Rig up Schlumberger E - line. PT to pressure control equipment to 500 psi. OK. RIH w/jet cutter. Correlate depth to jewelry. Jet cut tbg. @ 9095' wlm. No noticeable tubing movement. POH wljet cutter tool string. line up manifold and attempt to break circulation long way. Pressured up to 2500 psi. and bled off to zero psi two times. No circulation noted. lined up manifold to reverse circulate. Pressured up to 1200 psi at 2 bpm. Losing fluid @ 2 bpm at 1200 psi with no returns to surface. SID pump, bled off pressure to zero. SWS reload jet cutter and RIH wltool string to cut tbg. @ 7466'. RIH w/jet cutter. Correlate depth to jewelry. Jet cut tbg. @ 7466' wlm. No noticeable tubing movement. POH w/jet cutter tool string. line up manifold and attempt to break circulation long way. Pressured up to 2500 psi. and bled off to zero psi two times. No circulation noted. lined up manifold to reverse circulate. Pressured up to 1200 psi at 2 bpm. Losing fluid @ 2 bpm at 1200 psi with no returns to surface. SID pump, bled off pressure to zero. RIH wljet cutter. Correlate depth to jewelry. Jet cut tbg. @ 7400' wlm. No noticeable tubing movement. POH w/jet cutter tool string. Printed: 10/17/2005 7:36:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 4 of 13 BP Exploration Operations Summary Report Start: Rig Release: Rig Number: : Code I NPT! Phase P DECOMP P DECOMP Z -02A Z -02A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To , Hours; Task -"..--.-" 9/25/2005 06:00 - 08:00 08:00 - 1 0:00 2.00 FISH 2.00 FISH 1 0:00 - 15:30 5.50 FISH P DECOMP 15:30 - 16:30 1.00 FISH P DECOMP 16:30 - 17:00 0.50 FISH P DECOMP 17:00 - 18:30 1.50 FISH P DECOMP 18:30 - 20:00 1.50 FISH P DECOMP 20:00 - 23:30 3.50 FISH P DECOMP 23:30 - 00:00 0.50 FISH P DECOMP 9/26/2005 00:00 - 02:00 2.00 FISH P DECOMP 02:00 - 03:00 1.00 FISH P DECOMP 03:00 - 08:30 5.50 FISH P DECOMP 08:30 - 10:00 1.50 FISH P DECOMP 10:00 - 14:00 4.00 CLEAN P DECOMP 14:00 - 17:00 3.00 CLEAN P DECOMP 17:00 - 19:00 19:00 - 00:00 2.00 CLEAN N RREP DECOMP 5.00 CLEAN N DECOMP 9/18/2005 10/14/2005 Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations ________.._0. -..- .--- PJSM. Rig down E-Line. PJSM. Rig up circulating hose I headpin. Change out elevators. 84K up wt. 74K down. Slack off to 70K & attempt to break circulation.....pumping 1 3/4 bpm @ 1500 psi. seeing partial returns....pump 25 bbls. no decrease in pressure ..... believe pack off leaking by. Pick up to 100K. (16K over up wt). while continuing to pump @ 1 3/4 bpm. see pressure climb to 2500 psi. Shut down pump. pressure holding. indicating pack off sealed up.... unable to circulate around cut @ 7400'. Attempt to reverse circulate. pumping 1 3/4 bpm 11500 psi...partial returns. Leaking by packoff .... pack off not designed to hold pressure while reverse circulating. Work pipe a few times up to 190K max with pressure on tubing & bled off. Unable to free pipe. Slack off to neutral wt & attempt to release overshot ...unable to release overshot ...max torque applied to work string = 4000 ft Ilbs. Call for E line to perform chemical cut just below overshot @ 7190' . (estimated depth of overshot guide @ 7187' (+ -i. PJSM. Pull 35k over up wt to 119K. set pipe in slips & attach collar clamp. Wait on E-line & load pipeshed w. 4 1/2" TC II completion string. PJSM. Spot Schlumberger E-line unit. Pre job with respect to rigging up pressure control equipment & handling of E line tools. Rig up E -line pressure control equipment. RIH w/wireline tool string and string shot. Fired string shot top at 7181'. Good firing indication. POH wlstring shot tools. P/U chemical cutter tool string and RIH. Correlate depth to completion jewelry and bottom of OS. Fired chemical cuttter at 7194' wlm. Noted tubing tension release. POH wlwireline tool string. POH wI wireline tools. Rig down lubricator and associated pressure control equipment. Release SWS E-line. Work tubing to establish tubing movement. Pulled 175K#. No-go. Circulate long way. Pressure up to 500 psi with 175K# tension. Tubing movement noted. Reverse circulate 1.5 bottoms up at 5-6 bpm at 400-500 psi. Approx. 3/4 bbl. river sand recovered. Clean returns at 1.5 BU. Rig up floor to POH. POH laying down 4 1/2" 12.6# L80 BTC tubing work string and BHA #4. PJSM. UD overhsot assembly. Recovered 5.5' of 4 1/2" tbg. PIU milling BHA. RIH wI milling BHA on 31/2" DP. Vis up pit system to around a 50 funnel vis. M/U kelly on jt# 216. Establish parameters. 11 OK up wt. 102K down wt, 106K rotating wt. 80 - 100 RPM. Off bottom torque = 2500 ftllbs on bottom torque = 4000 ftllbs. Pumping 6 bpm I 750 psi. Tag up @ 7191'. milling w/3 - 5K WOB. Mill to 7208'. Detected short in electrical system. Shut down milling operation. Pull (2) stands to 7010' (+ -i. Repair short in rig electrical system. TIH w/2 stands. break circulation. Resume milling operations from 7208'. Milling w/8K to 9K Printed: 10/17/2005 7:36:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/26/2005 9/27/2005 9/28/2005 9/29/2005 BP Exploration Operations Summary Report Page 5 of 13 Z -02A Z -02A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Spud Date: 3/29/1996 End: 10/14/2005 Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: Code I NPT I Phase . __...L.--_. . . 19:00 - 00:00 From - To Hours ¡ Task 5.00 CLEAN N DECOMP WOB, 5 bpm @ 550 psi, 6 bpm @ 750 psi. Change hole over to Flo-Pro at 7206'. Milling at -6 ft./hr. Good cuttings return after hole swapped to Flo-Pro. Fluid loss = 4-5 bbls/hr. DECOMP Milling operations ongoing. Pump rate - 5-6 bpm @ 800-900 psi. - WOB 8-9K. RPM - 100. Torque - 4000 ft.lbs. SFAL DECOMP Fluid losses increased from 5 bbls./hr. to 16 bbls./hr. Reason for fluid loss - rig flowline partially plugged with milling cuttings and bell nipple overflowed. Commenced cleanup operations and removing obstruction from rig flowline. DECOMP Resume milling operations at 7228'. Pump rate - 5-6 bpm @ 800-900 psi., WOB 8K-12K. RPM - 100. Torque - 2500-4000 ft.lbs. DECOMP Continue milling. ROP slowed down @ 7250', (collar). Will mill to 7255', circulate hole clean & POOH f/ weekly BOPE test. Chuck Sheve given (24) hr notice & waived witnessing test. DECOMP Pump 20 bbl High Vis-Pill around @ 6 bpm total 623 bbls DECOMP TOH with BHA # 5 stand back 3-/12" DP DECOMP SIB Collars UD BHA #5, Clean Junk Baskets òf 3 gals metal, Mill 1 0% worn DECOMP Pull Wear Ring and install Test Plug DECOMP Test BOPE as per BP and AOGCC requirements 250 psi low, 4000 psi high charted, Test wirnessed by Nabors Tool Pusher Henderson and BP Rep. Felder. Mr C Sheve with AOGCC waived right to witness DECOMP Pull Test Plug and Install Wear Ring DECOMP M/U BHA #6; Cut lip guide, Overshot bowl, Extention, Top sub, Bumper sub, Oil jar, 9 Drill collars, Accelerator jar DECOMP TIH with BHA #6 on 3.5" DP DECOMP TIH BHA #6 to top of liner @ 7071' on 3.5" DP DECOMP Reverse Circulate from top of liner, first returns where sand a plenty with metal Mill cuttings. Reverrsed three Dril Pipe vols before returns were clean. Continue to reverse circulate down to top of Fish at 7252' when metal cuttings a plenty came around. 25 gallons of cutting blinded off shaker screean and plugged Piping. Changed out hose. Checking down hole DP to be clear, plug in plumming in derrick. Continue to clear piping. DECOMP Un-able to clear 2" Stand-Pipe for the time being. Re-route choke manifold and continue to reverse. Returns clean. DECOMP Lay down Jt #219. Pick-up Kelly. PUW = 100K/SOW = 90K. Enguage Fish at 7,252'. Jar from 175K - 200k and work Fish up to 230K. Also attemt to break circulations and jar on Fish with Pump pressure on Drill Pipe (500 - 1000 psi). (Ordered out Wash-Pipe). After 628 jar licks Fish came free (?) with 1SK over pull P/U to above liner with overshot DECOMP Perform derrick inspection, Reverse Circulate wash to 7232' Pipe stuck and plugged DECOMP Jar and rotate pipe to work free from 7232' PUW 115K DECOMP POH3SWs~1n"DP DECOMP Cut and Slip Drill Line DECOMP POH 3-1/2" DP racked back with BHA #6 DECOMP POH with BHA #6 on 3-1/2" DP racked back DECOMP UD BHA #6 Fish not attached DECOMP Overshot inspected found grapple worn. Redress overshot 00:00 - 01 :00 01 :00 - 02:30 02:30 - 06:00 06:00 - 09:00 09:00 - 11 :00 11 :00 - 15:30 15:30 - 17:30 17:30 - 18:00 18:00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01 :00 01 :00 - 06:00 06:00 - 06:30 06:30 - 18:30 18:30 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 Description of Operations _n___.________n _____n 1.00 CLEAN P 1.50 CLEAN N 3.50 CLEAN P 3.00 CLEAN P 2.00 CLEAN P 4.50 CLEAN P 2.00 CLEAN P 0.50 BOPSU 3.50 BOPSU 0.50 BOPSU 0.50 CLEAN 1.50 CLEAN P 1.00 CLEAN P 5.00 CLEAN P 0.50 CLEAN P 12.00 FISH P 2.50 FISH P 0.50 FISH P 0.50 FISH P 1.00 FISH P 1.00 FISH P 1.00 FISH P 0.50 FISH P 0.50 FISH P Printed: 10/17/2005 7:36:17 AM BP Exploration Operations Summary Report Page 6 of 13 legal Well Name: Z -02A Common Well Name: Z -02A Spud Date: 3/29/1996 Event Name: WORKOVER Start: 9/18/2005 End: 10/14/2005 Contractor Name: NABORS ALASKA DRilLING I Rig Release: 10/14/2005 Rig Name: NABORS 4ES Rig Number: Date I From - To I Hours I Task Icode NPT' Phase ¡ Description of Operations I : .------ ___..._n____ --.------.. 9/29/2005 02:00 - 03:00 1.00 FISH P DECOMP P/U BHA #7 Cut lip guide, Overshot bowl, Extention, Top sub, Bumper sub, Jar, 9 x Drill Collars, Accelerator 03:00 - 03:30 0.50 FISH P DECOMP Clear and clean Floor. 03:30 - 07:00 3.50 FISH P DECOMP TIH with BHA #7 and 3 1/2" Drill Pipe to top of Fish at 7,232'. 07:00 - 07:30 0.50 FISH P DECOMP Reverse circulated at 6.0 bpm/850 psi. Small amount of sand recovered. 07:30 - 08:00 0.50 FISH P DECOMP Pick-up Kelly. 08:00 - 12:00 4.00 FISH P DECOMP Latch Fish at 7,232'. Jarlworklattempt to circulate stuck 4 1/2" ProductionTubing. No progress made. 12:00 - 15:30 3.50 FISH P DECOMP Jars quit. Release Overshot. Pump dry job. Perform Derrick inspection. Trip out with 3 1/2" Drill Pipe. 15:30 - 16:30 1.00 FISH P DECOMP Lay down BHA #7. 16:30 - 17:00 0.50 FISH P DECOMP Clear and Clean Floor. 17:00 - 18:00 1.00 FISH P DECOMP M/U BHA #8 Shoe,S x Jts Wash pipe, Boot basket, Bumper sub, Jar, & 9 x Drill collars 18:00 - 21 :00 3.00 FISH P DECOMP TIH BHA #8 on 3-1/2" DP to 7222 21 :00 - 00:00 3.00 FISH P DECOMP Wash over Fish with no indication of fill to collar @7259' Bottoms up no sand found 9/30/2005 00:00 - 03:30 3.50 FISH P DECOMP Milling through collars (7,290', 7,332', and 7,374') at 4-6 BPM I 500-900 PSI I 80-110 RPM I 2-3K on Mill from 7259' to 7414' with no problems, getting back some cuttinngs strung out. Make short trips back to top of Liner as needed. Indications show Fish droped back down 20'. Length wash pipe 163'1 Last top of fish 7232' I (7232' + 163'= 7395') add 20' = 7414' makes top of fish now @ 7252' original fish depth. 03:30 - 06:00 2.50 FISH P DECOMP Circulate to string cuttings up hole.. Pulled up to Liner top at 7,091 '. Reverse circulat hole clean at 5 bpm/625 psi. 06:00 - 08:30 2.50 FISH P DECOMP Trip out with 3 1/2" Drill Pipe and Drill Collars. 08:30 - 10:30 2.00 FISH P DECOMP BHA #8 at surface. Start to lay down Wash Pipe. Discovered that Fish is inside of remaining Wash Pipe with much joy (friction bite). Lay down Fish #1. Total length recovered = 144.62'. Lay down remaining BHA. 10:30 - 11 :00 0.50 FISH P DECOMP Clear and Clean Floor. 11 :00 - 11 :30 0.50 FISH P DECOMP Make up BHA #9 as follows" Shoe, Bushing, Overshot, Extention, Top Sub, Bumper Jar, Oil Jar, Drill collars, Accelerator Jar. 11.30 - 14:30 3.00 FISH P DECOMP TIH with BHA #9 and 31/2" Drill Pipe to top of Fish #2. 14:30 - 15:00 0.50 FISH P DECOMP Reverse circulate Drill Pipe volume x 3. Recovered some Sand. 15:00 - 17:00 2.00 FISH P DECOMP Pick-up Kelly and tag top of Fish at 7,396'. Mill over latch and pull 17:00 - 19:00 2.00 FISH P DECOMP POOH with Fish on BHA #9. 19:00 - 20:00 1.00 FISH P DECOMP UD BHA #9 with Cut 4-1/2" Jt. 19.56', GLM assembly 26.82', Cut 4-1/2" Jt. 19.90' Toatl Fish 66.28' 20:00 - 21 :00 1.00 FISH P DECOMP Clear and Clean Rig Floor 21 :00 - 22:00 1.00 FISH P DECOMP P/U BHA #10; Shoe, Bushing, Overshot bowl, Extention, Top sub, Bumper sub, Jar, Pump out sub, 9 x Drill Collars, Accelerator 22:00 - 00:00 2.00 FISH P DECOMP TIH BHA #10 on 3-1/2" DP 1 0/1/2005 00:00 - 01 :00 1.00 FISH P DECOMP Continue TIH BHA #10 on 3-1/2" DP to 7430' 01 :00 - 06:00 5.00 FISH P DECOMP P/U Kelly establish parameters Mill over flared jet cut 4-1/2" Tbg. and latch with overshot Jar on fish with 80K over. Tbg not free. Confer with Eng. and call out Schlumberger to find Printed: 10/17/2005 7:36:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ...----... 10/1/2005 10/2/2005 10/3/2005 BP Exploration Operations Summary Report Z-02A Z -02A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To I Hours Task I 01 :00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 12:00 12:00 - 13:00 13:00 - 18:00 18:00 - 19:30 19:30 - 21 :00 21 :00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 09:30 09:30 - 12:00 12:00 - 14:30 14:30 - 15:30 15:30 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 02:30 02:30 - 05:30 -_.~_.. 5.00 FISH 0.50 FISH 1.50 FISH 4.00 FISH 1.00 FISH 5.00 FISH 1.50 FISH 1.50 FISH 1.50 FISH 0.50 1.00 1.50 4.50 FISH FISH FISH FISH 0.50 FISH 1.00 FISH 2.00 FISH 2.50 FISH 2.50 FISH 1.00 FISH 3.50 FISH 0.50 FISH 1.00 FISH 3.50 FISH 1.50 FISH 0.50 FISH 0.50 FISH 3.00 FISH Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: , 1 ' 'Code NPT I Phase ____ n_ L________ P DECOMP P DECOMP P DECOMP DECOMP POOH with E-Line. Rig down SWS. Nipple Down Shooting Flange. Clear and Clean Floor. DECOMP Make up BHA #11 as follows: Cut-Lip Guide, Overshot, Extention, Top Sub, Bumper Sub, Oil Jar, Pump-Out Sub, 9 ea Drill Collars, Accelerator Jar. DECOMP Expected TOF #5 = 8,357'. TIH with BHA #11 and 3 1/2" Drill Pipe. DECOMP P/U Kelly Engage fish 8354' Jar 30K over to free DECOMP Circulate Bottoms Up at 6 BPM 1900 psi I No recovery of fill DECOMP POH with BHA and Fish on 3-1/2" DP. DECOMP Lay Down BHA #11 and Fish #5 = 4-1/2" GLM Assy, 14 Jts, and 10" stub 616'. Second Jt below GLM assembly had 3 dime size holes along with many small corrosion pits. DECOMP Clear and Clean Rig Floor DECOMP Make Up BHA #12, Shoe, Bushing, Ocershot Bowl, Extention, Top Sub, Bumper Sub, Jaar, Pump out Sub, 9 x Drill Collars, Accelerators DECOMP Expected TOF #6 = 8,976' elm. TIH with BHA #12 and 3 1/2" Drill Pipe. P DECOMP P P DECOMP DECOMP P P DECOMP DECOMP P DECOMP P P P P DECOMP DECOMP DECOMP DECOMP P P P DECOMP DECOMP DECOMP P DECOMP P P P P P P P P P P Page 7 of 13 Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations .....-..-----... ----.. "___0." freepoint and free pipe. Continue jaring on fish. Lub Rig. Inspect Derrick. Continue to attempt to Jar stuck Fish #4 free. Continue to wait on Schlumberger E-Line Unit to arrive on Location. PJSM with All. Rig up SWS E-Line for Free-Point Operations. RIH with FPIT through 3 1/2" Drill Pipe and BHA with no problems. Tagged fill inside of 4 1/2" Tubing at 9,010' (Note: Tag is 48' above lower GLM and 85' above a Jet cut made at 9,095' made on 09/24/2005). Log 41/2" Collars. Calibrate FPIT. Stop at 8,475'. Log pipe streatch from 120K to 240K to 120K. Pipe is 80% free. Drop back down hole to 8,970'. Attempt to log pipe stretch but FPIT quit. POOH to troubleshoot FPIT. RIH SWS for Free- Point log at 8990' is 70% free; 8700' is 83% free; 8475' is 80% free PJSM with all. Rig up String Shot RIH with 6' String Shot to 8357' WLM top collar first Jt above GLM and with tension in string fire string shot POOH Work left hand tourqe in pipe and back off with 10 K gained in wieght Circulate full Tbg volume POH BHA #10 with Fish Continue POOH with BHA #10 with fish Lay Down BHA #10 with Fish #4 = 872' of 4-1/2" Tubing with collar on bottom. ( Pin end looking up downhole). Lub Rig. Inspect Derrick. Install Shooting Flange and prep to Rig-up SWS E-Line. Wait on SWS to arrive on Location. (Crew was sent to Camp for proper amount of rest). Maintain Rig. PJSM with All. Rig-up SWS E-Line for Jet Cutting Operations. RIH with Jet Cutter. Log 4 1/2" Tubing collars. Tag fill inside Tubing at 9,006'. Position Cutter to cut at 8,976' (10' below Collar at 8,966'). Fire Cutter. Good indications in Logging Unit. Printed: 10/17/2005 7:36:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date n___ 10/3/2005 10/4/2005 1 0/5/2005 ; ! From - To .--- 05:30 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 12:00 12:00 - 13:00 13:00 - 18:00 18:00 - 19:30 19:30 - 20:30 20:30 - 21 :30 21 :30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 06:00 06:00 - 12:30 12:30 - 15:30 15:30 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 09:00 Page 8 of 13 BP Exploration Operations Summary Report I ; I I Code! NPT I L__ 0.50 FISH P 0.50 FISH P 1.50 FISH P 4.00 FISH P 1.00 FISH P 5.00 FISH P 1.50 FISH P 1.00 FISH P 1.00 FISH P 2.50 FISH P 1.50 FISH P 1.50 FISH P 3.00 FISH P 6.50 FISH P 3.00 FISH P 4.50 FISH P 1.00 FISH P 1.00 FISH P 2.00 FISH P 0.50 FISH P 1.00 FISH P 2.50 FISH P 0.50 FISH P 1.00 FISH P 0.50 FISH P 0.50 EV AL P 2.50 EV AL P Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: Spud Date: 3/29/1996 End: 10/14/2005 Z -02A Z -02A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours I Task ___-----1...--__. __ _. i Phase ! Description of Operations ... -....-.---------.- --.--.- --.----.-- DECOMP Stop to Cut and Slip Drilling Line. DECOMP Finish Cut and Slip Drilling Line. Lub Rig. Inspect Derrick. DECOMP Finish TIH with 3 1/2" Drill Pipe from Derrick. Pick-up single Drill Pipe from Pipe Shed. Pick-up Kelly. PUW = 140K. SOW = 120K. Tagged TOF at 8,969'. Dress off 41/2" Jut Cut Stump. Latch Fish. Jar and work pipe to free Fish. DECOMP Continue to Jar on Fish. Making some progress. Fish free. DECOMP Set back Kelly. Drop Dart. Pressure up on Drill Pipe and attempt to shear Pump-Out-Sub. Unable to shear. Wait on Dart. Attempt again. No-Joy. DECOMP TOH with 31/2" Drill Pipe and BHA #12. Pulling wet. Stop to pressure up again on POS. Dart finally on seat. This time POS sheared. Mix and pump Dry Job. Continue TOH. Drill Pipe pulling dry. DECOMP Lay Down BHA #12 with Fish 2 Jts Tbg, GLM assembly, Cut end of Tbg Total 118.54' of Fish. DECOMP Clean and Clear Rig floor DECOMP PJSM BHA #13; P/U Mule shoe, 678' of 2-7/8" PAC, 2-7/8" PAC x 3-1/2" IF X/O, 9 x Drill Collars, Circ. Sub DECOMP TIH BHA #13 on 3-1/2" DP by stands DECOMP TIH BHA #13 on 3-1/2" DP DECOMP Tagging up on 41/2" Tubing Stump at 9088' and had to work to get inside. DECOMP Through 4-1/2" Stump at 9088' and wash short way getting back metal cuttings, sand and piece of band from IBP. DECOMP Continue to reverse out 20/40 Mesh Sand from 41/2" Tubing Tail to 9,195'. Continue to reverse out Sand from 7" Liner with good returns. Recovering much Sand. Found IBP at -9,452'. Continue to reverse circulate at 5.0 bpm/1500 psi while pushing IBP down hole. Start to loose Flopro at 3/4 bpm. Push IBP to top Perforations at 9,506'. Flopro losses now 1.0 bpm. IBP hung up at 9,552'. Work IBP free. Unable to make further progress by Reversing. Circulate the long way and start to push IBP down hole again. IBP stopped at 9,680' 4es KB. ( -42' below bottom Perforation at 9,638'). Attempt to beat and circulate deeper. No-Joy. Pump 40 bbl Sweep. DECOMP Pump 40 bbl Sweep to clean-up Well. Pump Dry Job. DECOMP POOH with 31/2" Drill Pipe and BHA #13. DECOMP LID 22 jts 2 7/8" PAC DP & BHA # 1. Clear & clean rig floor. DECOMP M/U BHA # 14 to scrape casing as follows: 81/2' Bit, 95/8" Scraper, PxP, XO, 3 boot Baskets, Bit Sub, Bumper Sub, Jars, P/O Sub, 9 . 4 3/4" DCs, Accel. TL = 332.86'. DECOMP RIH wI BHA #14 on 3 1/2" DP. DECOMP Con't to RIH wI BHA #14. P/U kelly & break circulation. Tag up on TOL @ 7071'. DECOMP Close annular & reverse circulate. Pumped 5 BPM @ 900 psi. losses were 8 BPH. Circulated 540 bbls. DECOMP Set back kelly & blow down lines. POOH wI BHA # 14. DECOMP Lay down BHA #14. DECOMP Clear and Clean Rig floor. DECOMP Lub Rig. DECOMP Make-up Halco 9 5/8" RTTS Packer. DECOMP TIH with Packer and 3 1/2" Drill Pipe. Set Packer at 6,885'. Printed: 10/17/2005 7:36:17 AM BP Exploration Operations Summary Report Page 9 of 13 Legal Well Name: Z-02A Common Well Name: Z-02A Event Name: WORKOVER Start: 9/18/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/14/2005 Rig Name: NABORS 4ES Rig Number: Date i From - To ' Hours I Task : Code I NPT : Phase i L..--__ - _ __ _ !__-----L-____J _ __ _____ Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations --.--.-.-.... 1 0/5/2005 09:00 - 10:30 1.50 EVAL P 10:30 - 14:00 3.50 EVAL P 14:00 - 15:00 1.00 FISH P 15:00 - 18:30 3.50 BOPSU DECOMP Rig-up Test Equipment. Test 9 518" Casing to 4,000 psi/30 min. Good. Recorded on Chart. Rig-down Test Equipment. DECOMP Release Packer. POOH with 3 1/2" Drill pipe and Packer. Lay down Packer. DECOMP Pick-up Kelly and install "Jet Sub". Jet out inside of BOP Stack. DECOMP Pull Wear Bushing. Rig up test Equipment. Perform Weekly BOP Test per BP/AOGCC requirements at 250/4,000 psi. The State's right to witness Test was waived by J. Chrisp. Annular test failed. DECOMP N/D flow nipple & adapter. P/U kelly & M/U adapter. Remove & change out element in annular preventer. N/U equip back up & install flow nipple. DECOMP Rlu test equip & can't to BOP test. DECOMP Can't to Test BOPE as per BP/AOGCC requirements. Tested annular to 3500 psi, Good test. P/U & test kelly & valves, LP 250 psi, HP 4000 psi. Test good. DECOMP Blow down lines. Set back kelly. RID test equip. Install Wear bushing. DECOMP M/U BHA # 15 to dress off tubing stub as follows: Mill shoe, 2 . 5 3/4" Extensions, Triple Connection, PxP Sub, 7" casing Scraper, 3 Boot Baskets, Bit sub, Bumper Sub, Jars, Pump out sub, 9' 4 3/4" Dcs, Accelerator. TL = 347.11 '. DECOMP RIH wI BHA # 15 on 31/2" DP. DECOMP Pick-up Kelly. PUW = 14SK. SOW = 125K. Tag top of 41/2" Jet Cut Tubing Stump at 9082'. Circulate at 3.0 bpm/675 psi. DECOMP Mill-Off -2' of Tubing with a 4.875" x 3.800" Dressing Mill. Dress-off Outside of Tubing Stump with a 4.500" Shoe. Tubing Stump swallowed = 12.7'. ShortTrip Stump several times. DECOMP Pick-up off of Stump and continued to circulate with Sea Water and recover Flopro for disposal. DECOMP TOH with 31/2" Drill Pipe and BHA #15. DECOMP Lay down BHA #15. Empty Boot Baskets (full of metal cuttings and some sand). DECOMP Clear and Clean Rig Floor. DECOMP Install Shooting Flange. SWS arrive on Location. DECOMP Hold PJSM. R/U Schlumberger E-line equip. DECOMP Test lubricator to 500 psi, Ok. RIH wI USIT I Gr I CCI & log from 9050'. DECOMP Can't to log wI US IT I GR I CCL from 9050 to 1500 '. POOH wI logging tool. Found Top of Cement @ 1950'. Heavy corrosion indication & possible holes @ 7275' & 7510'. DECOMP RID Schlumberger & logging equip. N/D shooting flange & NU flow nipple. DECOMP M/U RBP on 3 1/2" Drill Pipe and RIH. Stop just above 7" Liner top. Discuss Log results and plan forward with Anch Eng. Continue RIH. Had to "bobble" through Line Top. Continue down to 9,020'. Attempted several time to set RBP. No-Joy. Lay down 2 Jts. Got RBP to set at 8,980'. DECOMP POOH with Running Tool. Ud running tool. DECOMP Clear & clean rig floor. M/U RTTS. DECOMP RIH w/4 3/4" DCS & 31/2" DP. DECOMP Space out & set RTTS @ 7104' w/20K down wt. 71 stands + a 18:30 - 23:30 5.00 BOPSU P 23:30 - 00:00 0.50 BOPSU 1 0/6/2005 00:00 - 01 :30 1.50 BOPSU 01 :30 - 02:00 0.50 BOPSU 02:00 - 03:00 1.00 FISH P 03:00 - 07:00 4.00 FISH P 07:00 - 08:00 1.00 FISH P 08:00 - 09:30 1.50 FISH P 09:30 - 12:30 3.00 FISH P 12:30 - 15:30 3.00 FISH P 15:30 - 16:30 1.00 FISH P 16:30 - 17:30 1.00 FISH P 17:30 - 18:00 0.50 EV AL P 18:00 - 19:30 1.50 EVAL P 19:30 - 00:00 4.50 EV AL P 10/7/2005 00:00 - 02:00 2.00 EVAL P 02:00 - 04:00 2.00 EVAL P 04:00 - 10:30 6.50 EVAL P 10:30 - 14:00 14:00 - 14:30 14:30 - 18:00 18:00 - 19:30 3.50 EV AL P 0.50 EV AL 3.50 EV AL 1.50 EVAL P Printed: 10/17/2005 7:36:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/7/2005 1 0/8/2005 1 0/9/2005 BP Exploration Operations Summary Report Page 10 of 13 Z -02A Z -02A WORKOVER Start: 9/18/2005 NABORS ALASKA DRILLING I Rig Release: 10/14/2005 NABORS 4ES Rig Number: From - To I Hours Task Code NPT· Phase .----. 18:00 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 06:00 06:00 - 10:30 10:30 - 13:30 13:30 - 14:00 14:00 - 18:00 18:00 - 19:00 19:00 - 21:00 21 :00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 04:30 04:30 - 10:00 10:00 - 10:30 10:30 - 11:00 11 :00 - 12:30 12:30 - 15:30 15:30 - 18:30 Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations _._--~._.... . .. __n. 1.50 EVAL P DECOMP double. Pressure up to to 4000 psi, Pressure bled off & test failed. DECOMP Unset RTTS & RIH w/19 more stands of 31/2" DP. DECOMP Space out & set RTTS @ 8849' wI 20 K down wt. Pressure up to 4000 psi, pressure bled off & test failed. DECOMP Reset RTTS @ 8911 '. Pressure up to 4000 psi. Test failed. DECOMP Release RTTS. RIH & engauge RBP wI Retrieving tool. Unset RBP. DECOMP POOH wI RTTS & RBP on 31/2" DP. DECOMP Cut & slip 84' of drilling line. Lube rig. DECOMP Con't to POOH. Stand back Drill Pipe and Drill Collars. DECOMP Inspect RTTS & RBP. RRTS looked fine. RBP had both rubber elements completely gone. Ud RTTS & RBP. DECOMP Clear & clean rig floor. Sent RBP into shop. WIO 2nd redressed RBP. Had to scavage parts from 1st RBP to finish rebuild on 2nd RBP. DECOMP RIH with Halco 7" RBP. Work throught 7" Liner top at 7,071 '. Continue RIH to 9,020'. Set RBP with no problems. DECOMP POOH with Running Tool. DECOMP Clear and clean Rig Floor. DECOMP Pick-up Halco 7" RTTS Packer. RIH to 7,104'. Set Packer with no problems. DECOMP Pressure up & test 7" liner to 3800 psi, Bled off 600 psi in 10 min. No Test. DECOMP Call little Red to do pressure testing. Wait on unit to arrive. R/U & test lines to 4000 psi. Pressure up & bled off 500 psi in 10 min. No test. DECOMP Unset RTTS & RIH to 8943'. Set RTTS. Pressure up to 4000 psi & held for 30 min. Test good. DECOMP Release RTTS. POOH to 7899'. Set RTTS. Pressure up & test 7" liner to 4000 psi for 30 min. Tested Good. DECOMP Release RTTS. POOH to 7511'. Set RTTS. Pressure up & test 7" liner to 4000 psi for 30 min. Tested Good. DECOMP Release RTTS. POOH to 7133'. Set RTTS. Pressure up & test 7" liner to 4000 psi. Pressure dropped 500 psi in 1 st 10min. Pressure dropped addtional 200 psi in the next 20 min. Pressure started to flatline @ 3200 psi. Then continued to fall an additional 100 psi. DECOMP Release RTTS, RIH & retreive RBP from 7103'. POOH wI same. DECOMP Break apart and lay down BHA, one rubber element missing from RBP. DECOMP Clean and clear rig floor. DECOMP Assemble BHA #16 as follows: Mill Shoe, 2 * 5.75" Washpipe Ext., 5.75" Boot Basket triple conn. bushing, PxP XO, 7" Csg Scraper, 2 Boot Baskets, Bit Sub, Bumper Jars, Super Jar, Pump-out Sub and 9 * 4.75" DC's. TL= 332.28' DECOMP RIH with BHA and 3.5" IF drill pipe. Pick-up Kelly. Tag top of 4 1/2" Tubing Stump at 9,090'. Rotate and wash down over Stump. Encounter Rubber at 9,093'. Worked through and continue to swallow Stump down to 9,103 (13'). Short Trip Stump several times with no problems DECOMP Circulate and condition Well at 3112 bpm/800 psi. 1.00 EVAL P 0.50 EV AL P 0.50 EV AL P 0.50 EV AL P 2.00 EVAL P 1.00 EVAL P 1.50 EVAL P 0.50 EV AL P 3.00 EV AL P 4.50 EV AL P 3.00 EV AL P 0.50 EVAL P 4.00 EVAL P 1.00 EVAL P 2.00 EV AL P 3.00 EVAL P 1.50 EVAL P 1.00 EVAL P 2.00 EVAL P 5.50 EVAL P 0.50 EV AL P 0.50 EV AL P 1.50 CLEAN P 3.00 CLEAN P 3.00 CLEAN P Printed: 10/17/2005 7:36:17 AM BP Exploration Operations Summary Report Page 11 of 13 Legal Well Name: Z-02A Common Well Name: Z-02A Event Name: WORKOVER Start: 9/18/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/14/2005 Rig Name: NABORS 4ES Rig Number: Date I From-To! H~urs ! Ta~?Ode I N~~ I Ph~Se 1m Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations -.-----.... ".----------. 10/9/2005 18:30 - 20:00 1.50 CLEAN P DECOMP POOH & UD 60 jts of excess 31/2" DP. 20:00 - 22:30 2.50 CLEAN P DECOMP Con't to POOH & stand back 31/2" DP. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH & UD BHA #16. 10/10/2005 00:00 - 00:30 0.50 CLEAN P DECOMP Finish UD BHA #16. 00:30 - 01 :30 1.00 CLEAN P DECOMP Clear & clean rig floor. R/U to run 4 1/2" liner. 01 :30 - 02:00 0.50 CASRE P INTERV Hold PJSM wI all hands. Review 4 1/2" Liner running order. 02:00 - 03:00 1.00 CASRE P INTERV P/U & M/U Overshot Assy, Ball Seat I Ported Assy, 1 Jt 4 1/2" liner & Landing Collar I Float Collar Assy. Baker-Lok Same. 03:00 - 06:00 3.00 CASRE INTERV Con'tto RIH w/41/2" 12.6#, L-80, IBT liner. Installed a total of 5041/2" x 7" centralizers. 06:00 - 12:30 6.50 CASRE INTERV PU and install packer assembly as follows: 4.5",12.6# L-80 IBT liner pup, 7" XO bushing, 7" x 9.65" HMC liner hanger, 'C-2' ZXP liner top packer, 7" hydraulic setting tool, 4.5" IF DP pup jnt, 4.5" x 3.5" IF XO sub. Continue to RIH with 71 stands of 3.5" IF DP from derrick. PU tag jnt and tag 4.5" Tbg stump at 9090'. PU and locate stump again, break circ. & slide over stump for depth verification, noticed pressure increase. Seen locating pins shear at 11 K, bottom out and pick up sting 2'. 12:30 - 13:30 1.00 CASRE P INTERV RU circ. equipment. Reverse circ. hole using 8 bbls of sea water. Hold PJSM. 13:30 - 15:30 2.00 CASRE P INTERV Forward circ. 5 bbls of fresh water, shut in and PIT surface treating lines to 4500psi - test held 100%. Resume treatment and pump another 10 bbls for a total of 15bbls of lead fresh water at 1 050psi 11.7bpm. Start cement, pumping at 4.7 to 4.9 bpm and 9S0-650psi. Pumped a total of 60 bbls of class 'G' cement at 15.8ppg. Shut down pump and drop dart, displacing with 5 bbls of fresh water followed by seawater (8.S4ppg) at 5 bpm and 2S0psi, slowed rate to 2.5bpm and seen darts tag with 40bbls away I 1800psi. Pumped a total of 78.9 bbls for displacement. Pressure up to 2600psi and seen liner hanger set ( 6817'). Bled off pressure to verify floats were holding - pressure remained at 0, slack off on string to verify liner is set. Pressure up to 4000psi, noticing packer set at 3600psi (6800'). Rotated string to right and mechanically verified that packer was set. Pressure up to 1000psi on Tbg and pick-up on string, seen pressure bleed off. Good set on both tools. 15:30 - 16:30 INTERV Reverse circ. hole using 85 deg. seawater (8.54ppg). Pumped 2 DP volumes, recovering an est. 10bbls of cement (25% excess). Circ. till clean returns. 16:30 - 17:00 0.50 CASRE INTERV Rig out cementing head and line. Ready equip. to POOH with 3.5" IF DP. 17:00 - 19:00 2.00 CASRE INTERV Layout tag jnt. POOH and stand 213 (71 stands) of 3.5" IF DP. 19:00 - 19:30 0.50 CASRE INTERV Break out & UD liner running tools. 19:30 - 20:30 1.00 CASRE INTERV Clear & clean rig floor. 20:30 - 00:00 3.50 CASRE INTERV P/U, Tally & M/U BHA #17 to clean out liner as follows: 35/8" MM Mill, Bit Sub, 80 Jts 2 7/8" PAC DP, X-Over, Bumper Sub, Jars, Pump Out Sub. TL = 2516.22'. 10/11/2005 00:00 - 01 :00 1.00 CASRE INTERV Con't to P/U 2 7/8" Pac DP & RIH. 01 :00 - 03:30 2.50 CASRE INTERV Con't to RIH wI BHA # 17 on stands of 31/2" DP. Tagged Top of liner @ 6802'. 03:30 - 04:00 0.50 CASRE INTERV Tagged up @ 8868'. P/U kelly, break circulation. 66 stands + double + 8'. 04:00 - 06:00 2.00 CASRE INTERV Establish drilling parameters as follows: P/U Wt = 123K, S/O Printed: 10/17/2005 7:36:17 AM Page 12 of 13 BP Exploration Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-02A Z -02A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: I Phase INTERV Wt = 11 OK, Rot Wt = 11SK. 3 BPM # 850 psi. 60-65 RPMs, WOB 2-4K, Torq = 1.9- 3K. Drill cement stringer from 8868 to 8912'. Cmt hard @ 8912'. Con't drilling to 8930'. INTERV Drill out cement I stringers toward landing collar, pulled up and reverse circulate hole clean after each connection. Drilling progressed slowed near landing collar, thru OK. INTERV Milling on Float Collar @ 8986' DPM. UD 2 jts. 3 1/2" DP. Reverse circulation and pressured up to 2700 psi wI no returns. Pressured up through DP to 3500 psi wI no returns. Drop ball to shear pump out sub. Attempt to reverse circulate and pressured up to 2700 psi wIno returns. Pressured up through DP to 3500 psi wIno returns. Drop ball to shear pump out sub. TOH w/BHA #17 on 3 1/2" DP. Con't to POOH & stand back 2 7/8" PAC DP. Flush cement & junk frorn DP. Clear & clean rig floor. Change out rnill & RIH wI BHA#18. Left out pump out sub. Kelly up, break circulation. Milling on Float Collar @ 8988' DPM. Continue milling through float collar, mill down to ported pup joint at 9045.46'. Pick up 10' from bottom. Mix sweep and circulate hole clean, pumping at 5 bpm I 900 psi. Pressure test 4.5" liner to 3,000 psi for 30min. and record on chart. Test held 100%. Circulate out sand and mill through ball I seat at 9064.98'. Continued to RIH to WLEG and 2 joints out of Tbg end at 9195', final depth of 9255' RKB. Circulate hole clean from 9255' using 30 bbl sweep at 5 bpm I 1700 psi. Rack kelly, POH and LD 3.5" IF DP. Pulled heavy (40K over) with Tbg end at 6899'. Circulate 200 bbls, string free. Reverse circ. to clean annulus of cuttings I debris. Clear and clean rig floor. POH UD 3 1/2" DP, 27/8" PAC DP and BHA. Lay kelly down. Load pipe shed with completion jewelry and confirm tally. Rig up casing tools. P/U and M/U 9 5/8" Baker S-3 perrnanent packer assembly per specified running order. Torque-turn and Baker-Lok all connections below packer. RIH w/4 1/2" L80 TCII tubing 1x1 and drifting each joint and torque turning all connections to specified torque value for 4 11 2" L80 TC-II tubing. PJSM. Continue running 41/2" L-80, TC II, 12.6# tbg, torque turning each connection to 3850 fVlbs. RIH, tag xJover in 41/2" liner 27' in on jt # 164. 84K up wt, 76K down wt. UD jt #164 & mlu tubing hanger. PJSM. Line up & reverse circulate heated seawater wI corrosion inhibitor @ 3 bbllmin @ 125 psi, 500 bbls total pumped. Land hanger. R/U Little Red and pump 140 bbls. diesel down IA @ 1.5 bpm @ 300 psi to freeze protect well. Date , , i From - To ; Hours Task --- 10/11/2005 04:00 - 06:00 2.00 CASRE 06:00 - 15:00 9.00 CASRE P 15:00 - 17:30 2.50 CASRE P 17:30 - 19:00 DPRB INTERV 19:00 - 22:30 3.50 CASRE DPRB INTERV 22:30 - 00:00 1.50 CASRE DPRB INTERV 1 0/12/2005 00:00 - 01 :00 1.00 CASRE DPRB INTERV 01 :00 - 05:30 4.50 CASRE DPRB INTERV 05:30 - 06:00 0.50 CASRE INTERV 06:00 - 07:30 1.50 CASRE INTERV 07:30 - 09:30 2.00 CASRE INTERV 09:30 - 10:00 0.50 CASRE INTERV 10:00 - 12:00 2.00 CASRE INTERV 12:00 - 15:00 3.00 CASRE INTERV 15:00 - 16:00 1.00 CASRE INTERV 16:00 - 19:00 3.00 CASRE INTERV 19:00 - 00:00 5.00 CASRE INTERV 10/13/2005 00:00 - 04:00 4.00 CASRE INTERV 04:00 - 05:00 1.00 RUNCMP 05:00 - 06:00 RUNCMP 06:00 - 13:00 7.00 RUNCMP 13:00 - 14:30 1.50 RUNCMP 14:30 - 18:00 3.50 RUNCMP 18:00 - 20:00 RUNCMP 9/18/2005 1 0/14/2005 Spud Date: 3/29/1996 End: 10/14/2005 Description of Operations --~... ----._---- Printed: 10/17/2005 7:36:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ....--..-- -- 10/13/2005 21 :00 - 23:30 23:30 - 00:00 10/14/2005 00:00 - 05:00 05:00 - 09:00 /~ Page 13 of 13 BP Exploration Operations Summary Report Z-02A Z-02A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 0.50 5.00 4.00 Start: 9/18/2005 Rig Release: 10/14/2005 Rig Number: Spud Date: 3/29/1996 End: 10/14/2005 Phase Description of Operations --" ---.--- __0. ___ ._____." __ ._._ __ _____ RUNCMP R/U lines and U-Tube diesel from IA to 41/2" tbg. to freeze protect tbg. RUNCMP Drop ball & rod. Allow to fall on seat. Pressured up tubing and set packer. Test tubing to 4000 psi. Bleed tubing to 1500 psi. Pressure up annulus to 4000 psi & test for 30 minutes. Tubing and IA tests charted. Bleed off annulus and tubing to 0 psi. RUNCMP RD/MO Little Red. Prep to N/D BOPE. RUNCMP N/D BOPE. Remove pipe rams. RUNCMP N/U adapter flange & test void @ 5000 psi, OK. N/U & test tree @ 5000 psi, OK. Set BPV. Secure well. Rig released @ 09:00 hrs, 10/14/2005. Printed: 10/17/2005 7:36:17 AM , TREE:' 4"CNV 9-5/8" MILLOUT WINDOW 1284' . 1334' ÆRFOAA TON SUMMARY REF LOG: SONIC ON 04/15/96 ANGLEA T TOP PERF: 15 @ 9505' Nole: Refer to 9333' mUOHOE SAY UNIT waL: Z-02A PERMIT No: 1960430 API No: 50-029-21814-01 see 19, T1iN, Ri2E, 8. 3492' Fa e ~lr~lJŒ (ID~ L%~L%~[ß~ e AIiASIiA. OIL AlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Daniel Robertson Sr. Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~ Re: PBU Z-02A Sundry Number: 305-334 i\II..\f.\I!!:X··' nC f: ~ 9 20D5 5Cn~'tI~":1e¡¡.v tH;, L ~, Dear Mr. Robertson: 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, DATED thisL day of November, 2005 Encl. ~ 1. Type of Request: Cf} (( ~ (~0'5 _ STATE OF ALASKA _ A~ Oil AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development ø / Exploratory W G I\- It I Iz.oos- RECEIVED OCT 2 6 Z005 Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Suspend Repair well 0 Pull Tubing 0 Co7T\lWf: .j Stimulate 0 Time Extension ~'h~Prod to Inj ~.~~.,t.r~~ Re-enter Suspended Well 0 5. Permit to Drill Number: ................/..../\#.,.. r~"""+·· .~ 6. API Number: o o 50-029-21814-01-00 ./ Anchorage, AK 99519-6612 7. KB Elevation (ft): Stratig raphic 0 Se rvice 9. Well Name and Number: 84.24 KB Z-02A / 8. Property Designation: ADL-028262 11. Total Depth MD (ft): 9879 Total Depth TVD (ft): 9242.24 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9747 9112.4 Plugs (measured): Junk (measured): None 9680 Burst Collapse 110 2675 4930 2270 6882 6870 4760 9197 8160 7020 Casing Conductor Surface Production Liner Length Size I TVD 80 20"x30" 30 110 30 2646 13-3/8" 68# L -80 29 2675 29 7256 9-5/8" 47# L-80 28 7284 28 2762 7" 29# L-80 7071 9833 6696.94 Perforation Depth MD (ft): 9506 - 9528 Sqz'd 9548 - 9600 9612 - 9638 Packers and SSSV Type: /' Perforation Depth TVD (ft): 8876.39 - 8897.74 8917.21 - 8968.03 8979.79 - 9005.28 4-1/2" Baker S-3 Perm Packer 7" Baker ZXP Packer 7" Baker ZXP Packer 4-1/2" Baker S-3 Perm Packer Tubing Size: 4-1/2" 12.6# Tubing Grade: L-80 Tubing MD (ft): 28 - 9195 Packers and SSSV MD (ft): 6724 6800 7071 9137 12. Attachments: Descriptive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG ø GINJ 0 WINJ 0 Service ø / Commencing Operations: 16. Verbal Approval: Commission Representative: 11/7/2005 Abandoned 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Contact Daniel Robertson Signature Phone 564-5546 COMMISSION USE ONLY Sr. Petroleum Engineer Date 10/24/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 305-:.:::?3c.¡::: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test [!( Location Clearance 0 Other: AI\.. I T' ~ 1 ÍÑt'~~ J . Pe1l" '2,0 A-A-L -Z -.41 ¿ (b) I pfi'..l.iLe ý ck1Y¡'¿~ Vtt"y,'(tov(c,.( i S c~)¡JJrJ ved, RBDMS 8Ft NOV () 2 2005 MISSION Date: APPROVED BY , TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4" CrN MCEVOY OTIS 91.76' 55.46' 3100' 31 @ 8285' 9514' 8800' SS e Z-02A 9-5/8" X 7" BKR ZXP PKR W/TIBK. 10 = 6.31" I 9-5/8" X 7" BKR HMC LNR HGR, 10 = 6.25" 9-5/8" X 7" BKR ZXP PKR W/TIBK. ID = 6,31" 1-1 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" I 7071' 7085' Minimum ID = 3.725" @ 9182' 4-1/2" HES XN NIPPLE 9-5/8" CSG, 47# L-80 BTRS. ID = 8.681" 1 9259' I 4-112" TBG. 12.6#, L-80 BTC-M, ,0152 bpf, 10 = 3.958" H PERFORA TION SUMMARY REF LOG: SONIC ON 04/15/96 A NGLE AT TOP PERF: 15 @ 9506' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 C 09/03/96 3-3/8" 2 9612 - 9638 C 09/03/96 DATE 06/28/88 04/19/96 10/14/05 01/11/03 02/22/03 09/29/03 2090' 1-14-1/2" X NIP. ID = 3.813" I I I I I J 4-1 12" WLEG 6825' IJ7" x 4-1/2" X-OVER 9-5/8" MILLOUT WINDOW 7284' - 7334' 8983' 8993' IJ4-1/2" Lndg Collar (milled to 3.625") !J4-1/2" Float Collar (milled to 3.625") 9193' I I IJ4-1/2" Ported Pup with 4 x 1" holes 1 IJ Unique Overshot (Tbg stub @ 9097') I 4-1/2" HES X NIP, ID = 3,813" 7" x 4-1/2" BKR S-3 PKR. ID = 3875" 1-14-1/2" HES X NIP. ID = 3.813" I 1~4-1/2" HES XN NIP. ID = 3.725" I I 9195' IJ4-1/2" WLEG I I 9183' H ELMD I FISH (3" IBP PUSHED TO BOTTOM) H 9680' ! I PBTD H 9147' I 7" LNR. 29#. L-80 BTC-M. .0371 bpf, ID = 6.184" l-i 9833' REV BY COMMENTS ORIGINAL COMPLETION CHH RIG SIDETRACK (Z-02A) RWO JBM/TLH IBP FISH DDW/KK SAND DUMP MJAITLH CHEM CUT DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: Z-02A PERMIT No: 1960430 API No: 50-029-21814-01 SEC 19. T11 N. R12E. 4303' FSL & 3492' FEL BP Exploration (Alaska) bp e e "tl" ~~~ ~ ~ -~. -¡.~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519·6612 (907) 561·5111 October 24, 2005 R'r= ~' .6.- Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Oì"'1 ? i: l..'M~} t~¡a!;!Œ t.' '\Jt Re: Sundry Notice for Z-02A RWO and Conversion from Producer to Injector \ct£,r-&~~ A RWO was recently performed to convert well 2-02a (PTD# 1960430) from a producer to a WAG injection well under sundry # 305-269, approved 9/16/05. An error was recently discovered on this sundry application. The well status after proposed work was incorrectly noted as an oil producer. The correct well status post RWO is WAG injector. A corrected sundry application is attached. An area of review for well 2-02a indicates there are no penetrations in the Ivishak reservoir within % mile of the 2-02a penetration. A USIT cement evaluation log was run in the 9 5/8" casing in well 2-02a 10/6/05 and indicated good cement above the Ivishak reservoir with a top of cement at 1950 MD. The USIT and pressure testing also indicated a lack of integrity of the 7" liner above the packer. A 4.5" tieback was run and cemented inside the 7" liner above the packer to restore integrity. Well 2-02a has been shut in since 1998 due to mechanical integrity problems including a liner lap and tubing leak. WAG injection into 2-02a will provide pressure support and improved recovery for offset producers 2-03, 2-04a, 2-06 and Z-39. Please contact Dan Robertson at 564-5546 with any questions. Sincerely, ~~ Daniel B. Robertson, PE \\~AL A RAN I CAL INTEGRITY' REPORT. E?UD IìÞ.:Z: 4Itf/¿r;¡1Ú -' ?~G REI..E;_~E: .111~ /¡qq¿p OPER & FIELD B P P ~u. 'W"ELL NUMJ3ER i - o-¿It- ¡Q(g-04š 7,-1 r,.LL DATA TD: ~ fÎ~ .MD. 9242 TVD¡ :?ETD: 9747 HD qJl2. TVD CasiDg: 9 ~ <SIt' Shoe: 7284 l1D Co t¡ z TVD¡ DV: HI) ·T\1) _:..:-.e;:: 7" Shoe: q8~~ 11]) 9/97 TVDj :CP: 707/ HD fø &,97 ::~rD 4 - í'z II q¡c¡ç HI) C¡/~7 1/l (h) :~Di:;g: Packer TVTI í Set: êt: ::ole Size ana t- '/, ./ Perfs t¡')4f to q (p <;.g :-:EC?.AliIC;'.L INTEGRITY - PART ¡ 1 Annulus Press Test: ~p 15 m~n 30 min Comments: 111. r:T r tt"lA' Y v& . ,.- ME CHJL1IiI CÞ..L INTEGR TTY - PART J 2 'J Cemenc Volumes :'. Þ-...mt. Liner ¡q5 .ct ; Csg j DV Cült -"01 to cover perfs /12 s./L +- SOc;/ @ ~ t?~ ~UÇ.L Theore cical TOC -iLP 40,' ¡,J I ;;'0 ~~ e.¡¿c..ec.5' Cement Bond Log (Yes or No) r ; In AOGCC File . ......... CBL t:valuation, zone aDove perfs u.ç IT I~~~-µ'S ~d.eD~u -þcv~~p¡ cPt 7 I' Ct'J{l cJ,) Ov'~ ~? &tf ì,¡;C~vÇvI, Pro¿u~tion Log: Type ¡Evaluation .. CONC;LUSIONS: ? ar; t 1 : -1fj L I V'ðq 1M' v...e..d ' J' ?art f2: CWL-t VIJ/. p~CtUd) USr.-r:- Jk~CA.,þ Wte4.. (~t;.d~i-S ¡-.J'J' wi ,;;J,...~IL" (µ..ti{(.. tMA+0v- M f2, A-py}O"~{ ~ /A^-fI^-~&-d ' lll'l Z-OO,S-. - -- -- 1¡J6~ 1320 ft adiu Top of Ivish k e tqte,- ~o4~ e Subject: Z-02A Workover Update From: "Reem, David C" <ReemDC@BP.com> Date: Mon, 10 Oct 2005 09:17:35 -0800 To: winton_aubert@admin.state.ak.us CC: "Robertson, Daniel B (Alaska)" <RobertDB@BP.com> Winton, as we discussed on the phone, here is a synapsis of where we have gotten to on the Z-02A workover. 1) 10/7/2005 Ran a USIT log across the existing 7" liner and across the 9-5/8" casing above the 7" to assess cement bond quality AND corrosion. Log indicated very good bonding in the 9-5/8" with the cement top above 2000'md. The corrosion log showed 2 possible "hot-spots" up high in the 7" liner. 2) We then set a 7" plug just above our 4.5" tubing stub, and pressure tested the 7" liner from the 1 st full joint below the 7" liner hanger equipment. This presure test failed with a consistent leak-off of -800 psi over 10-15 minutes. We confirmed the competency of the deep-set plug with passing pressure tests to 4000 psi using a test packer set just above the plug and a 2nd set mid-way up in the 7" liner. Evidently, the corrosion hot-spots are not pressure competent, thus the leak-off. 3) We have run and are in the process of fully cementing in a 4.5" scab liner that will cover the existing 7" liner and 7" liner-top equipment (see attached diagram). «Ver2, Z-02Aproposed.CNV» Please call should further clarifiaction be necessary. We hope to be running completion Wednesday and moving off this well by Thursday 10/13/2005. Thanks. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) 5CÁNNEI¡ NOV Ü 9 2005 Ver2, Z-02Aproposed.CNV Content-Description: Ver2, Z-02Aproposed.CNV Content-Type: application/octet-stream Content-Encoding: base64 ~._J-.1!!10~2ººº 09: 46 FAX 907 564 5 0 TREE = · WELLHEAD = ACTUATOR = KB.àEV = BF.ELEV = KOP= Max Angle = · Datum MD = · Datum TVD = 4" CWoJ MCEVOY OTIS 91.76' 55.46' 3100' 31 @ 8285' 9514' 8800' SS bp 141 002 '~.:r.·;, "r.;"....::(.....~i ~·:~:;·~~,.~.~4n... 2- "., f ~t". ....~ U .I)r'-"~ ".<..,.it ~,;~ -I:..øø_~. Z-02AProposed 13-3/8" CSG, 68#, L-80, ID = 12.415" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID - 3.958" . I 9-5/8" X 7" BKR ZXP PKR WITIBK, ID = 6.31" I -6800' I 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" H -6815 9-5/8" X 7" BKR ZXP PKR W/TIBK, ID = 6.31" I 7071' I 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" I 7085' 4-1/2", 12.6#, L-80, 1ST LINER (CEMENTED) MinimumlD = 3.725" @ 9182' 4-1/2" HES XN NIPPLE I 9-5/8" CSG, 47# L-80 BTRS.ID = 8.681" 9259' ~ .i :/ >ti.~ (~& Ga CßîI. ~~.,1 . ......:~.,'W~ I -2100' 1~4-1/2"XNIP,U~)=3.813" -6700' ~4-1/2"X NIP,ID:; 3.813" -6730' -/9-5/8" x 4-1/2" BKR 8-3 PKR -6765' 1~4-1/2" X NIP, 10;' 3.813" I I I I I -6815' I~WLEG -6821' I~ 7" x 4-1/2" X-O,:'ER 9-"'" MLLOUT WNDOW 7284' - 7334' I -EU2" Landing Collar 1..../I:1/2" Float Collar -E::1/2" Ported Pup with 4 x 1" holes I UI:lique Overshot (Tbg stub @ 9097') I 4..1/2" HES X NIP, 10 = 3.813" 9137' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9160' ]-14-1/2" HES X NIP, ID = 3.813" I 9182' ]~4-1/2" HESXNNIP,ID= 3.725" I ·1 9195' IJ4-1/2" WLEG I I 9183' H ELMD I I 4-1/2" TBG, 12.6#, L-80 BTC-M, .0152 bpf, ID = 3.958" I ÆRFORA TION SUMMARY REF LOG: SONIC ON 04/15/96 ANGLE AT TOP ÆRF: 15 @9506' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 C 09/03/96 3-3/8" 2 9612 - 9638 C 09/03/96 9193' ~ 9747' f- 7" LNR, 29#, L-80 BTC-M. .0371 bpf. ID = 6.184" H 9833' 1- DATE REV BY COMMENTS 06/28/88 ORIGINAL COMPLETION 04/19/96 CHH RIG SIDETRACK (Z-02A) 03/14/01 SI8-MD FINAL 06/23/01 CHlTP CORRECTIONS 09/11/01 CWS/TL SEnBP 01/11103 JBM/TLH IBP FISH DA TE REV BY COMMENTS 02/22/03 OOW/KK SANO DUMP 09/29/03 MJAlTLH CHEM CUT PHUDHOE BA Y UNrr WELL: Z-02A PERV1rr No: 1960430 API No: 50-029-21814-01 SEC 19, T11 N, R12E, 4303' FSL & 3492' FEL BP i:xploration (Alaska) e ftr+;' ",':- .,.." '-"ø4- . -'3- - ' - ~.", -~,' <-jitII!f"':;;';', -~»'---i~'>¡,,:tJ " :' ,'t1l:'>~' "",' ,. - - " ',- ",-''it:> e Subject: Z-02A revised strategy From: "Bartel, Paul" <BarteIP@BP.com> Date: Wed, 05 Oct 2005 15:23:22 -0800 To: Winton Aubert <winton}áubert@admin.state.ak.us> Winton, After our conversation earlier, I've revised our strategy for Z-02A. 1. Run a USIT in the corrosion/cement mode in the 7" liner from the top of the tubing stub at 9095' to the liner top at 7071'. Run a USIT in the 9-5/8" to 5000'. 2. Isolate and pressure test the 7" liner. 3. If the 7" shows extensive damage or fails the pressure test we will suspend operations. (I'll file a suspension notice if this happens). A proposed completion will then be submitted in conjunction with the sundry application to convert to injection. 4. If the 7" tests OK then we will proceed with the original proposed completion as per Sundry number 305-269. Please let me know if you have any questions or concerns. Thanks, Paul 564-5402 From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Wednesday, October OS, 2005 9:59 AM To: Bartel, Paul Subject: Re: Z-02A completion revision ~ÇANNfD NO\! f¡) 9 2005 Paul, I am unable to open the attachment. Please resend in another format (doc, xis, pdt). Thanks, Winton Aubert AOGCC 793-1231 Bartel, Paul wrote: Winton, My name is Paul Bartel, and I'm filling in for Dave Reem while he's on vacation. We would like to change our completion strategy for the Z-02A RWO (Sundry number 305-269). We suspect there is damage to the 7" liner at approximately 8500' based on external corrosion we encountered while fishing the 4-1/2" tubing. All of the tubing has been recovered down to the original production packer at 9137'. We would like to cement a 4-1/2" scab liner across the 7" liner as per the attached schematic. The injection packer would moved up to approximately 6700'. Please let me know if you have any concerns. Do I need to revise the sundry application? Thanks, '~' ~' Ü:;:'7JI /'7'\\' ~ ¡-I¡-d i, ~ W,',' [¡ ,"/, ,:i~ ;~'" ! !.' i,' In ',' ,,'ll :,1 'I, ,......, "\, \, ¡: ¿';W \~ i" ! [~ Û" II' ',: ¡I \ I,: I' ¡In, 'I :1 , " I" ',I lit , Œ -,,' ,,.~ '''"' ",...:;::J l----n' ;-:::¡ : ¡ I I' I il !:¡:: ¡~ i·~1U U ) ¿;'":ï! '~~ ]j(\"'-""I ïl~7' ~,:, ~ 'ß" ',) : 'i I'~, " ,( ,oj , r! ,Ai\, 1/1 ,\ i ¡ ,; .I~ \ I, \\ ¡ I / i ,: 'I ;' i I 'I, : i /U \ Ïi~\"~ i i '\ )/ \ \ mt !-, .¿'j @ '.J Ü Lr~ ) AIßASKA OIL AlWD GAS CONSERVATION COMMISSION / / ¡ FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 , '~.7~()Cf3 Re: PBU Z-02A Sundry Number: 305-269 p Dear Mr. Reem: 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, Jq(!z~¡v Chairman . J/Jt.- DATED thlSí!L day of September, 2005 Enel. \¡.jGt\- q 1/(,/2-005- 'I'" ) STATE OF ALASKA ) Þ"\:r ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO'VAb . 1,( 20 MC 25.280 ,1: 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing II Repair Well II Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ,.'pR'~SE;~~IW'E;~l1!.cqNPI~IQN,S.UMMÅ~YI,.., .'.,1..'...',:1 Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9242 7231 6836 7231 Lehgth, Size MD ' TVP · Burs\ 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name(ìpavid ~eem Title Drilling Engineer Signature If~ ~.. ~ Phone 564-5743 Commission Use Only 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 84.24' 8. Property Designation: ADL 028262 .,~,~.,:, Total Depth MD (ft): 9879 Casing Structural Conductor Surface Intermediate Production Liner 110' 2675' 7284' 2762' 20" 13-3/8" 9-5/8" 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): All Below Sand Plug & IBP All Below Sand Plug & IBP Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'HXO' SSSV Nipple 12. Attachments: 181 Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch September 19, 2005 Date: 4. Current Well Class: ./ 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 196-043 / 6. API Number: 50-029-21814-01-00 /' 9. Well Name and Number: PBU Z-02A / Junk (measured): None ICollapse 110' 2675' 7284' 7071' - 9833' 110' 2675' 6882' 6697' - 9197' 4930 6870 8160 2270 4760 7020 Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 9137' 501' Tubing MD (ft): 9195' 13. Well Class after proposed work: o Exploratory B DevéÍopment 0 Service 15. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL Contact David Ream, 564-5743 Date Prepared By Name/Number: Terrie Hubble, 564-4628 Sundry Number: ?iñ ' é}[ rf>I Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Other: T( çt go P E Þo 4000 pç,,! · Subsequent Form Required: \ 0 - 4 ð 4. . RBDMS BFL SEP 1.9 2005 APPROVED BY THE COMMISSION Approved By: ()j&/ ~'A/14--,_ _. COMMISSIONER Form 10-403 Revised 11 0;6; / ~ (, ~ f..) I (=~ ~ l\ '4,' L \....1 II \ ¡ "" II, "I ' " . ~ \:...../ i ¡ \1 ð Date 7 -/ú ~éJ5 Submit In Duplicate ) ) Well Status: Shut-in Ivishak producer. Well has confirmed tubing x inner annulus communication. The existing 7" scab liner top is leaking and there is a large hole in the tubing across from this leaking liner lap. The well is secured with a very large sand plug. --- Project: Retrieve existing 4.5" L-80 tubing down to the pre-RWO cut. Install and fully cement a short 7" scab liner to repair leaking lap. Cleanout the excess sand in the 4.5" tubing. Cut and retrieve 4.5" tubing to just above existing packer. Cleanout liner. Run new 4.5", 12.6#/ft, L-80 TC-II stacker-packer completion. Provide ÀOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. /- PRE-RWO · Secure well with sand plug (DONE). · Cut 4.5" tubing just above sand piug (DONE). · Circulate the well over to 9.8 ppg brine with diesel freeze protect. (DONE) · De-mob wellhouse and flowline. Install BPV in tubing hanger (DONE). /' 1. MIRU. (high). the cut. 2. Pull and LD 4-1/2" tubing string to the cut at +/- 7220' MD. 3. RIH with a casing scraper and tie-back polish mill, dress tie-back and circulate the hole clean. 4. RIH with RBP and set at 7210' MD. Spot 25' of sand on RBP. 5. RIH with RTTS. Pressure test 9 5/8" casing from 200' above liner top to surface at 4000 psi. 6. RIH with dummy seal assembly and sting into 7" tieback receptacle. Test seal. If good seal test, proceed with step 7. If seal test fails, establish injection rate and prepare for cement squeeze. 7. RIH with 7" x 9-5/8" SLZXP liner top packer/hanger, 240' of 7" 26# L-80 TC-II casing, 6' ported seal stem. 8. Cement in +/-240' scab liner and land seal st~m in existing tie-back extension. WOC. 9. Weld bradenhead while WOC. ~/~ 10. RIH and tag cement in 7" scab liner, PT t 40, 0 psi, mill cement to sand top. PT again to 4000 psi.- 11. RIH, wash sand and pull RBP. 12. RIH w/2-7/8" PAC work string and reverse out sand from inside 4-1/2" tubing to +/- 9200' MD. 13. RIH with 4-1/2" work string and over-shot grapple. Swallow tbg stub and pull up 25K tension. 14. RU E-line, string-shot and chemical cut the tubing at +/- 9070' MD. (middle of 1 sl full joint above the packer). 15. Pull work string and remaining 4-1/2" L-80 tubing to the cut at 9070' MD. If solids in the 4.5" x 7" annulus prevent pulling tubing, cut just below glm #1 at 9059 MD. If still unable to pull // tubing, cut just below GLM #2 at 8411 MD. If still unable to pull tubing, cut below GLM #3. 16. Washover and fish tubing/ glms as required. 17. Run 7" scraper to top of tubing stub. ~/'\ 18. Pressure test casing with 7" RTTS to O~ psi f/30-min charted. 19. Clean out liner and recover IBP and stting tool fish at +/- 9550 MD. Clean out to a minimum of 9650 MD, or as deep as possible if cleanout is going well. POOH and LOOP. 20. Run 4-1/2" L-80 TC-II premium connection completion with 7" x 4-1/2" packer and stacker- packer tailpipe. 21. Displace the IA to packer fluid and set the packer. 22. Test tubing to 4000 psi, test annulus to 4000 psi. Freeze protect to 2200' MD. 23. Set BPV. NO BOPE. NU and test tree. RDMO. '<, \ð ~ 0 ~" ~. ~~ 'yJGk- N D tree. N U and test BOPE to 250 psi (low)/4000 psi (high) - annu lar to~ -- Circulate out freeze protection fluid and circulate well to clean kill weight ~~~~U9h RWO ---' /" .../ .... ') ) POST-RWO · Pull ball&rod from RHC sleeve. Pull RHC sleeve. · Set MCX injection valve in upper 4.5" "X" landing nipple. · Tie-in injection lines, re-set wellhouse and instrumentation. · POI. MIT-IA w/AOGCC witness. -.---.-.------.--- T.8EE : . WELLHEAD: __.._N·,' ...~. V '" v ACTUATOR: 'KB." ELË\/;" BF. ELEV : KOF> : Max Angle: Datum MD : Datum TV D = 4" crw MCEVOY OTIS 91.76' 55.46' 31ÒO" 31 @ 8285' " '9514' 8800' SS ') Z-02A ~ -\ETY NOTES: BEFORE RUNNING 1" GlV'S IN . ,10LD STYLE KBG-2LS GlM'S, THE NO-GO ON RUNNING HEAD NEEDS TO BE MOVED UP 1/2". OLD WELLBORE NOT SHOWN BELOW MILLOUT WINDOW. e 501' 1-14-1/2" HES HXO SSSV NIP, ID = 3.813" 13-3/8" CSG, 68#, L-80. ID = 12.415" 1--1 2675' ~ Minimum ID = 3.725" @ 9182' 4-1/2" HES XN NIPPLE L ~ ST MD TVD DEV 6 2994 2993 0 5 4944 4789 28 4 6275 5979 26 3 7429 7016 15 2 8411 7913 31 1 9059 8471 28 GA S LIFT rv1A NDRELS iYÆ VLV LATCH MMG DOME RK MMG SO RK MMG DMY RK KBG-2LS DMY BTM KBG-2LS DMY BTM KBG-2LS DMY BTM PORT DATE 09/09/96 09/09/96 09/09/96 09/09/96 09/09/96 09/09/96 "- ~ ) ~ 7071' 7085' 1-19-5/8" X 7" BKR ZXP PKR WITIBK, ID = 6.31" 1 1-19-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 1 9-5/8" MILLOUT WINDOW 7284' - 7334' ÆRFORATION SUMrv1ARY REF LOG: SONIC ON 04/15/96 ANGLE AT TOP ÆRF: 15 @ 9506' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 C 09/03/96 3-3/8" 2 9612 - 9638 C 09/03/96 ^-f"/\ 7190' I-ICHEMCUTTBG (09/29/03) 1 7231' I-ITOPOFSANO(02/22/03) 1 I 4-1/2" TBG, 12.6#, L-80 BTC-M, .0152 bpf, 10: 3.958" 1--1 9193' -I 9127' H4-1/2" HES X NIP, ID = 3.813" 1 9137' I-IT' x 4-1/2" BKR S-3 PKR, 10 = 3.875" I 9160' 1-14-1/2" HES X NIP, 10 = 3.813" I 9182' 1-14-1/2" HES XN NIP, 10 = 3.725" I 9195' 1-14-1/2" WLEG I 9183' 1--1 ELMO I 9270' 1-13" IBP SET 08/03/01 I 9-5/8" CSG, 47# L-80 BTRS, 10 = 8.681" 1-1 9259' I PBTD 1--1 9747' 7" LNR, 29#, L-80 BTC-M, .0371 bpf, 10: 6,184" 1--1 9833' OA TE REV BY COMMENTS 06/28/88 ORIGINAL COM PLETION 04/19/96 CHH RIG SIDETRACK (Z-02A) 06/23/01 CI-VTP CORRECTIONS 09/11/01 CWSffiH SET IBP 01/11/03 JBM'TLH IBP FISH 02/22/03 DDW/KK SAND DUMP DA TE REV BY COMMENTS 09/29/03 MJAITLH CHEM CUT PRUDHOE BAY UNIT WELL: Z-02A ÆRMIT No: 1960430 API No: 50-029-21814-01 SEC 19, T11 N, R12E. 4303' FSL & 3492' FEL BP Exploration (Alaska) 'rREE :' · WELLHEAD = ACTUA TOR = KB. äèi:: BF. ELEV = KOP= . ."".."".."..". ~~,~I\~gle= " m Datum MD = DatumlVD= 4" CrN MCEVOY OTIS 91.76' 55.46' 3100' . , , . . . . , , , . . . . , . , . , . . , , . , , , . , , . , , , , . 31, @ 8285' 9514' 8800' SS ) 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 2675' ¡---J 9-5/8" X 7" BKR ZXP PKR W /TIBK, ID = 6.31" 1-1 -6800' 1 1 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 1-1 -6815 1 I 1 9-5/8" X 7" BKR ZXP PKR W/TIBK, ID = 6.31" 1-1 1 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 1-1 7071' 7085' ÆRFORA TION SUMMARY REF LOG: SONIC ON 04/15/96 A NGLE AT TOP ÆRF: 15 @ 9506' Note: Refer to Production DB for historical perf data SIZE SPF INTER V AL Opn/Sqz DA TE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 C 09/03/96 3-3/8" 2 9612 - 9638 C 09/03/96 9-5/8" CSG, 47# L-80 BTRS, 10 = 8.681" 1-1 9259' ') Z-02A Proposed I I -2100' Ij4-1/2" HES X NIP, ID = 3.813" 1 ... ~ Minimum IC = 3.725" @ 9182' 4-1/2" HES XN NIPPLE .. ~ ) r / .... ~ ) ~ 9-5/8" MILLOUT WINDOW 7284' - 7334' -9045' Ij4-1/2" HESX NIP, ID = 3.813" 1 I' -9065' IJ 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 1 -9080' _ 4-1/2" HES X NIP, ID = 3.813" -9100' _ Unique Overshot 9127' _ 4-1/2" HES X NIP, ID = 3.813" 1 9137' _ 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 1 9160' Ij4-1/2" HES X NIP, ID = 3.813" I 9182' Ij4-1/2" HES XN NIP, ID = 3.725" I I 9195' 1-14-1/2" WLEG 1 I 9183' 1-1 ELMD 1 4-1/2" TBG, 12.6#, L-80 BTG-M, .0152 bpf, ID = 3.958" 1-1 9193' 7" LNR, 29#, L-80 BTG-M, .0371 bpf, ID = 6.184" 1-1 9833' I PBTD 1-1 9747' DA TE REV BY COMMENTS 02/22/03 DDW/KK SAND DUMP 09/29/03 MJA/TLH CHEM CUT PRUDHOE BA Y UNIT WELL: Z-02A ÆRMIT No: 1960430 API No: 50-029-21814-01 SEC 19, T11 N, R12E, 4303' FSL & 3492' FEL DA TE REV BY COMMENTS 06/28/88 ORIGINAL COMPlETION 04/19/96 CHH RIG SIDETRACK (Z-02A) 03/14/01 SIS-MD FINAL 06/23/01 CI-VTP CORRECTIONS 09/11/01 CWS/TU- SET IBP 01/11/03 JBM/TLH IBP FISH BP Exploration (Alaska) ) r t k January 24, 2005 To: Dan Robertson From: Dave Reem Subject: Z-02A RWO Scope of Work Draft Scope of Work The scope of this workover is to remove the damaged 4-1/2", L-80 tubing string above the 7" liner, repair the 7" x 9-5/8" liner-lap, recover +/-2000' of tubing in the 7" liner, cleanout the sand and fish in the liner, and re-complete the well with 4-1/2" L-80 TC-II premium tubing. The estimated cost of this workover is $1824M and should take approximately 16 days to complete. Pre-Ria Work o 1. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT tbg and IC. (completed 11/5/03, all LOS free to move, PPPOT-T and PPOT IC passed, well shut in since then) String shot & chemical cut the tubing at +/- 7220, in the middle of the first full joint above the current sand-top. (done 9/30/03) Tubing and IA Fluid levels and pressures to estimate required brine weight Static pressure survey above tubing cut depending on results from step 3 Circulate gas and hydrocarbons to the cut point from the well with 9.8 ppg NaCL. Freeze protect tubing and casing with 10 bbls diesel. (done 10/24/03, top off with additional brine as required) Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the rig. E 2. 0 3. SP 4. 0 5. 0 6. 0 7. Proposed Ria Workover Procedure 1. MIRU. ND tree. NU and test BOPE. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 4-1/2" tubing string to the cut at +/- 7220' MD. 3. RIH with a casing scraper and tie-back polish mill, dress tie-back and circulate the hole clean. 4. RIH with RBP and set at 7210' MD. Spot 25' of sand on RBP. 5. RIH with RTTS. Pressure test 9 5/8" casing from 200' above liner top to surface at 4000 psi. 6. RIH with dummy seal assembly and sting into 7" tieback receptacle. Test seal. If good seal test, proceed with step 7. If seal test fails, establish injection rate and prepare for cement squeeze. 7. RIH with 7" x 9-5/8" SLZXP liner top packer/hanger, 240' of 7" 26# L-80 TC-II casing, 6' ported seal stem. 8. Cement in +/-240' scab liner and land seal stem in existing tie-back extension. WOC. 9. Weld bradenhead while WOC. 10. RIH and tag cement in 7" scab liner, PT to 4000 psi, mill cement to sand top. PT again to 4000 psi. 11. RIH, wash sand and pull RBP. ) 12. RIH w/2-7/8" PAC work string and reverse out sand from inside 4-1/2" tubing to +/- 9200' MD. 13. RIH with 4-1/2" work string and over-shot grapple. Swallow tbg stub and pull up 25K tension. 14. RU E-line, string-shot and chemical cut the tubing at +/- 9070' MD. (middle of 1 st full joint above the packer). 15. Pull work string and remaining 4-1/2" L-80 tubing to the cut at 9070' MD. If solids in the 4.5" x 7" annulus prevent pulling tubing, cut just below glm #1 at 9059 MD. If still unable to pull tubing, cut just below GLM #2 at 8411 MD. If still unable to pull tubing, cut below GLM #3. 16. Washover and fish tubing/ glms as required. 17. Run 7" scraper to top of tubing stub. 18. Pressure test casing with 7" RTTS to 4000 psi f/30-min charted. 19. Clean out liner and recover ISP and setting tool fish at +/- 9550 MD. Clean out to a minimum of 9650 MD, or as deep as possible if cleanout is going well. POOH and LOOP. 20. Run 4-1/2" L-80 TC-II premium connection completion with 7" x 4-1/2" packer and stacker-packer tailpipe. 21. Displace the IA to packer fluid and set the packer. 22. Test tubing to 4000 psi, test annulus to 4000 psi. Freeze protect to 2200' MD. 23. Set SPY. NO SOPE. NU and test tree. RDMO. Post-RiQ Work o 1. Re-set the well house & tie in the flow line. Pull the SPY. S 2. Retrieve the ball&rod, RHC plug body, drift for eline log E 3. Run USIT or SCMT to above Sag river formation F 4. Step rate test to confirm ìnjectivity, establish frac gradient o 5. Commence water injection o 6. MITIA w/ AOGCC witness after stabilized water injection S 7. Install injection valve in upper "X" nipple. o 8. Swap to MI injection vJ L1Å- 4: /7- "7) I z...:.Y'4,- ( STATE OF ALASKA ( DTj 6 JC3/ -1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROWU;;(~~i~:~ [) 20 AAC 25.280 JUN 2 2 ')004 1. Type of Request: . ~ .' Ii Abandon / 0 Suspend 0 Operation Shutdown 0 Perforate 0 Na&'ës 0¡1 Eo '2:::1[J~,l;Ü:i~::¡iS:.>lU'; 0 Alter Casing 0 Repair Well B Plug Perforations 0 Stimulate 0 Time Extensio~H::";'I':Ja::''"'"~ 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 10. Field / Pool(s): ADL 028262 Prudhoe Bay Field / Prudhoe Bay Pool , PRESENT WELL ,CONDITION SUMMARY Tot"a" 'I, D"e, "P" th, TV, 0 (ft),: IE. ,ff"" ect"ive, Depth MD (ft), :" ) Effect, ive Depth TVD (ft): Plugs (measured): 9242 7231 6836 7231 Length' , ' Size" ' " , ' ,MD, ' 12. Attachments: iii Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name B11Isaacson Title Senior Drilling Engineer ~ig~~~~~~L.t).I~~ ..~h?~~ ..... .5~~521 " ' "" """"" """""" "", """" "",',"","" ""', ", " .,""', CQmm¡s!;iønLs~,.anly 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 84.24' 8. Property Designation: 11. Total Depth MD (ft): 9879 Casing Structural Conductor Surface Intermediate Production Liner 20" 13-3/8" 9-5/8" 110' 2675' 7284' 2762' 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): All Below Sand Plug & IBP All Below Sand Plug & IBP Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'HXO' SSSV Nipple July 8, 2004 Date: 4. Current Well Class: B Development (' D Exploratory D Stratigraphic Test D Service 5. Permit To Drill Number 196-043 /' 6. API Number: / 50-029-21814-01-00 9. Well Name and Number: PBU Z-02A / Junk (measured): None " ,'CollapSe 110' 2675' 7284' 7071' - 9833' 110' 2675' 6882' 6697' - 9197' 4930 6870 8160 2270 4760 7020 Tubing Size: 4-1/2", 12.6# Tubing MD (ft): 9195' Tubing Grade: L-80 Packers and SSSV MD (ft): 9137' 501' 13. Well Class after proposed work: / /' D Exploratory iii Development 0 Service 15. Well Status after proposed work: DOil DGas 0 WAG D GINJ D Plugged DWINJ ,/ B Abandoned D WDSPL Contact Neil Magee, 564-5119 Date ~l2Z/0w... Prepared By Name/Number: Terrie Hubble, 564-4628 I Sundry Number: 3/Jt.f - d2 =' g- Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance If ~ t ß 0 ¡J E -j-v 4.o0() rJs.l. Other: - f þ- t j J ApptvveJ 1--£1 Y 7'J 10 . 40 I re3~(.( N' J /..D y ç ¡áf fYNk --8ft f,ÞLl'i/ l-c:!Z8! 'ø a 3 1\\~' COMMISSIONER ~~~RDER OF # ~ COMMISSION D t L' ae o~~3 ð 0 RIG I N A L s mil ,n0~le bp CIJI.Jl8IIrAjr To: Winton Aubert - AOGCC Date: June 22, 2004 From: Neil Magee - BPXA GPB Rotary Drilling Subject: Z-02A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well Z-02A. Z-02A is cur'?:'tly shut-in due to high /' GaR. The production interval was secured with a sand plug in February 2003.A horizontal sidetrack is seen as the most viable option to restore wellbore integrity, access additional reserves, and maximize value. P and A of the original well bore will be accomplished by recov~ing the tubing from above the production. packer, setting a bridge plug just inside the 7" leaking liner lap, setting a second bridge plug in the 9-5/8" ..,/ casing above the liner lap. Afterwards the upper bridge plug will be pressure tested to 4000 psi. Additional isolation will be provided by 150' of cement in the 7" x 9-~~ annulus above this point during the cementation of the drilling liner during the re-drill stage. The Z-02A sidetrack is currently scheduled for Doyon 16 beginning around 7/15/04. Please contact me directly should any additional information be required. Neil Magee Prudhoe Bay Drilling Engineer 564-5119 Scope Pre-Ria Operations: Well Condition (6/9/2004): 9-5/8" pack-off and tubing hanger passed pressure test on 11/5/2003. Well was killed and freeze protected with 60/40 methanol on 10/24/2003. A chemical cut was made in the production tubing on 9/30/2003. Production tubing has 2 very large holes identified 7087' and 7427' from a corrosion log run on 7/8/2001 The liner top packer a 7071 is leaking. ---// Description of pre-ria work: 1. Drift for 3-5/8" chemical cutter. Tag sand top in tubing. (DONE 9/29/03 2. Chemical cut the 4-1/2" tubing in the middle of the first full jt above the sand top. (DONE) 3. Circulate gas and hydrocarbons from the well with 9.8 ppg brine. Freeze protect tubing and casing with 20 bbls diesel. (DONE) Z-02A Application for Sundry 4. PPPOT-IC and PPPOT-T. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time) (DONE -7 both pack-offs passed). 5. Prior to rig arrival remove well house and flowlines. If necessary level the pad and dig out the cellar. l\ Summary of RiQ Operations: 1. MIRU Doyon 16. Circulate out freeze protection and displace well to 9.8 ppg brine. Set TWC. 2. Nipple down tree. Nipple up and test BOPE to 4000 psi. /'" 3. Pull and lay down 4-1/2" tubing from cut. 4. RIH with 8-1/2" milling BHA with 100' 6-1/8" cleanout BHA below. 5. RU e-line and run GR/JB to liner top. RIH with 7" EZSV and set at approximately ~j70'. RIH with 9- 5/8" EZSV on wireline and set at approximately 7040'. Pressure test to 4000 psi. /'" RIH with 9-5/8" (47 Ib/tt) Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Change well over to 9.8 ppg LSND milling/drilling mud. Mill window in 9-5/8" casing at -7,020' MD. Prior to POH, perform FIT to 12.0 ppg EMW. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag @ :!:9,148' MD (8692' TVD). (Mud weight prior to entering Kingak will be increased to 10.0 ppg) 8. Run and cement 7", 26# intermediate drilling liner to -200' back into window. POH. 9. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/ABI). Pressure test casing to 4000 psi. Drill landing collar and clean out shoe track. Swap mud over to 8.7 ppg FloPro drill in fluid. 10. Drill 20' of new formation. Conduct FIT to 10.0 ppg EMW. 11. Drill 6-1/8" production section as per directional plan to an estimated TD of 9,522' MD (9032' TVD). 12. Run 4 %", 12.6# L-80 cemented production liner throughout the 6-1/8" wellbore. After setting liner top packer displace to clean seawater above liner top. 13. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 min. POH LD excess drill pipe. 14. MU TCP assembly and perforate select intervals. POOH and LD remaining drill pipe and guns. 15. Run a 4-1/2", 12.6# L-80 IBTM completion tying into the 4-1/2" liner top. 16. Set packer and test the tubing and annulus to 3500 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' TVD and secure the well. 19. Rig down and move off. ~Lù s \0 - 48'5 :~') p }"() V cd . 7. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below production packer. Install gas lift valves. Z-02A Application for Sundry I 4-1/2" TBG, 12.6#, L-80 BTC-M, .0152 bpf, 10 = 3.958" 1-1 9193' (' TREE = WH.LHEAD = ACTUATOR = KB. H.EV = BF. H.EV = KOP= Max Angle = Datum MD = Datum lVD = 4" CrN MCEV OY OTIS 91.76' 55.46' 3100' 31 @ 8285' 9514' 8800' SS 13-3/8" CSG, 68#, L-80, 10 = 12.415" 1-1 2675' Minimum ID = 3.725" @ 9182' 4-1/2" HES XN NIPPLE I 9-5/8" X 7" BKR ZXP PKR wmBK, 10 = 6.31" 1-1 7071' I 9-5/8" X 7" BKR HMC LNR HGR, 10 = 6.25" 1-1 7085' ÆRFORA TION SUMMARY REF LOG: SONIC ON 04/15/96 ANGLE AT TOP ÆRF: 15 @ 9506' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 2 9506 - 9528 S 09/04/96 3-3/8" 2 9548 - 9600 C 09/03/96 3-3/8" 2 9612 - 9638 C 09/03/96 I 9-5/8" CSG, 47# L-80 STRS, 10 = 8.681" 1-1 9259' DA TE REV BY COMMENTS 06/28/88 ORIGINAL COMPLETION 04/19/96 CHH RIG SIDETRACK (Z-02A) 03/14/01 SIS-MD FINAL 06/23/01 CHfTP CORRECTIONS 09/11/01 CWSfTLH SET IBP 01/11/03 JBM/TLH IBP FISH ( Z-02A / SAFETY NOTES: BEFORE RUNNING 1" GL V'S IN THE OLD STYLE KBG-2LS GLM'S, THE NO-GO ON RUNNING HEAD NEEDS TO BE MOVED UP 112". OLD WB...LBORE NOT SHOWN BELOW M ILLOUT WINDOW. 8 501' U4-1/2" HES HXO SSSV NIP, 10 = 3.813" 1 r--.JI , GAS LIFT MANDRH.S TYPE VLV LATCH MMG DOME RK MMG SO RK MMG DMY RK KBG-2LS DMY BTM KBG-2LS DMY BTM KBG-2LS DMY BTM PORT DATE 09/09/96 09/09/96 09/09/96 09/09/96 09/09/96 09/09/96 L ... ~ 'I , ST MD lVD DEV 6 2994 2902 0 5 4944 4698 28 4 6275 5888 26 3 7429 6925 15 2 8411 7821 31 1 9059 8379 28 J 9-5/8" MILLOUT WINDOW 7284' - 7334' ^f'/\ 7190' ,I-ICHEM CUT TBG (09/29/03) 1 7231' 1-1 TOP OF SAND (02/22/03) 1 9127' J-I4-1/2" HES X NIP, 10 = 3,813" 1 9137' 1-17" x 4-1/2" BKRS-3 PKR, 10 = 3.875" 1 9160' 1-14-1/2" HES X NIP, ID = 3.813" 1 9182' 1-14-1/2" HES XN NIP, 10 = 3.725" 1 9195' 1-14-1/2" WLEG 1 9183' 1'1 H.MD 1 9270' 1-13" IBP SET 08/03/01 I I PBTD 1-1 9747' 7" LNR, 29#, L-80 BTC-M, .0371 bpf, 10 = 6.184" 1-1 9833' DA TE REV BY COMMENTS 02/22/03 DDW/KK SAND DUMP 09/29/03 MJAfTLH CHEM CUT PRUDHOE BA Y UNIT WELL: Z-02A ÆRMIT No: 1960430 API No: 50-029-21814-01 SEC 19, T11N, R12E, 4303' FSL & 3492' FEL BP Exploration (Alaska) Z-02A Abandonn1ent ~ ~ 13-3/8",68#, L-80 TREE = WELLHEAD = A'CTUA TOR = 'h, ,",,"-'" . ,-. ,~~",_.....,-,-,. KB. ELEV = BF~"a.EV';"^' KOP= ~~,J\_~~~~=" , Datum MD = õãi'û'm'iV5";;;" '^'S8ÒÒ' 55 4" CMf McEvoy Otis ," ''''91': 76 ""'55.46 3100 .. "'" 31@8285 Abandonment Details: The well has been sanded back to 7214' isolating the existing perforations An EZSV will be set at approx.7043'. After sidetracking the well above the EZSV the new production liner will be cemented to approx. 200' above the EZSV. EZSV @ 7043' ~ ~ II I.' II 9-5/8" X 7" HMC Liner Hanger with ZXP Liner Top Packer @ 7071' - "Leak" EZSV @ 7170' /~ ~ Top of Chemical cut @ 7190'WLM . .) Top of Sand at @ 7214' WLM ("/ 9-5/847#, L-80, BTC-M @ 9259' PERFORA TION SUMMA RY REF LOG: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4SPF 9506-9528 sand 09/04/96 3-3/8" 4SPF 9548-9600 sand 09/04/96 3-3/8" 4SPF 9612-9638 sand 09/04/96 Â 7" 29#, L-80, BTC-M @ 9833' Date 6/3/04 Rev By NM Comments Proposed Z-02A abandonment PRUDHOE BAY UNIT WELL: Z-02A API NO:50-029-21814-01 Permit NO:1960430 BP Exploration Z-02B P~oposed COfllpletion // I I 'X' Nipple @ 2200' MD TREE = 4" CrN WELLHEAD = McEvoy . . .. . ACTUATOR = Otis ., " .. ,.". ~.." '"' . . ,,~. .- .~. -" ~,- " ". -., KS. ELEV = 91.76 > ,n" ~'.~~ ,. y.. """ ",. .".~."" '". ,,,.,,,,.,. SF. ELEV = 55.46 , , KOP = 3100 '~~' Ängle'~'30@7Õ45' Datum MD = . '" , Datum 1VD = 8800' SS ~ ~ 13-3/8" 68#, L-80 BTC 9-5/8",47#, L-80, BTC Casing 9-5/8" X 7" HMC Liner Hanger with ZXP Liner Top Packer @ 6870' Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG I sand KOP in KUPARUK at 7020' Production Tbg. 4-1/2", 12.6#, L-80, TCII 7" X 4-1/2" Packer @ 8750' EZSV @7043' ~' EZSV @7170' II - ) 8 7" X 5" HMC Liner Hanger with ZXP Liner Top Packer @ 9000' 7" 26#, L-80, BTC-M @ 9148' 4-1/2" 12.6#, L-80, IBT-M @ 9523' ~ Da~ 6/3/04 Rev By NM Comments Proposed Z-02B sidetrack PRUDHOE BAY UNIT WELL: Z-02B API NO: Permit NO: GPB Rotary Drilling STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Conversion Genre rsion from Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ f/Prod to Inject Prod to Inject Well Change approved program _ Pull tubing _ Variance _ Perlorate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 84.0 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 976' FNL, 1461' FWL, Sec. 19, TllN, R12E, UM (asp's 599185, 5959099) Z-02A . At top of productive interval 9. Permit number J.-approval number 2429' FNL, 1746' FWL, SEC 19, T11 N, R12E, UM (asp's n/a) ~ / At effective depth 10. ,a~l number 24i2' FNL, 1789' FWL, Sec. 19, T11 N, R12E, UM (asp's 599532, 5957668) .//50-029-21/814-01 At total depth y. Field / Pool 2401' FNL, 1812' FWL, Sec 19 T11 N, R12E, UM (asp's 599555, 5957679) //Prudhoe Bay Oil Pool 12. Present well condition summary / Total depth: measured 9879 feet Plugs (measure~l;r true vertical 9242 feet Effective depth: measured 9724 feet Junk (meyured) TD Tag @ 9724' (03/02/1998) true vertical 9090 feet Casing Length Size Cemented ~ Measured Depth True vertical Depth ,, Conductor 110' 20" 72 cfi. cor~rete 146' 146 Surface 2639' 13-3/8" ~ 3~ cJPermafrost 2675' 2675; Intermediate 7248' 9-5/8" 186..~.f. Class 'G' 7284' 6882 Liner 2762' 7" ~, , [~.f. Class 'G' 7071' - 9833' 6697' - 9197' ¥/ Perforation depth: measured Sqzd Perfs 9506'~/9528', Open Perfs 9548' - 9600', 9612'- 9638' ~ / '' w true vertical Sqzd Perfs 8j~76' - 8898', Open Perfs 8917': 8968', 8980' - 9005' ~' s' UJ iTubing (size, grade, and measured depth 4-1/2", 12~6#, L-8~7' MD. Tubing Tail @ 9183'. (' '~ ....I 'Packers & SSSV (type & measured depth) 9-5/8" ~7" ZXP Packer @ 7071' MD. 7" Baker S-3 Packer @ 9137' MD ~ 4-1/2" J~ES HXO SSSVLN @ 501' MD. ~ 13. Attachments Description summary of p.~posal __X Detailed operations program__ BOP sketch__ 14. Estimated date for commencing operation 15. Status of well classification as: 'July 1,2001 16. If proposal was verbally approved Oil __ X Gas __ Suspended __ Name of approver Date approved Service 17.1herebycertifythat~,egoingistr~/~.~co~.~7~ynowledge........ Questions? Call Beverly Luedl(e-Chan @ 564-519§. Signed : Prudhoe Bay Petroleum Engineer Date July 19, 2001 Beverly Luedke-Chan /' Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tify Commission so representative may witneSSintegrity__ BOP Test __ Location clearance __ I Approval no. Mechanical Integrity Test _ Subsequent form required lO- Approved by order of the Commission co. I ED JUL %~ 2002 ,,, , ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 20, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re' Sundry Notice for Z-02A Conversion from Producer to Injector BP Exploration Alaska, Inc. proposes to convert well Z-02A from a shut-in producer to an active injector as part of the Eileen West End (EWE) Flood Development project. Well Z-02A was drilled in April of 1996 as a conventional rig sidetrack. The structure came in high, the well came on at high GOR and a squeeze attempt was very short lived. It has remained shut-in for high GOR since October of 1998. As part of the EWE Flood Development project, dry gas cap injection has been shut down in EWE and is being replaced by a water and miscible injectant flood. The objectives of this project are to reduce produced gas by injecting water to sweep out the expanded gas cap and gas underruns, provide additional oil recover through flood displacement, and access additional reserves through MI injection. Well Z-02A currently does not exhibit full mechanical integrity. The plan to prepare for injection is attached. Water injection is scheduled to begin at EWE in July of 2001. MI injection will commence in mid 2002 at the earliest. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5196 or e-mail me at luedkeb @ bp.com. Sincerely, Beverly K. Luedke-Chan Greater Prudhoe Bay Production Engineer, W and Z Pads SCANNED JUL 3 1_ 2002 Well Z-02A Current Status: TIFL failed on 7/7/01. All gas lift valves have been replaced with dummy valves. Leak detection log run on 7/8/01 showed a hole in the tubing at 7060'. A cement bond log attempt on 7/16/01 failed due to asphaltene build-up in the toolstring. Plan Forward: 1. Perform a coiled tubing cleanout to clear up asphaltenes. 2. Run a caliper survey of the tubing to determine the overall condition of the tubing, and specifically the condition surrounding the hole in the tubing to determine the feasibility of setting a tubing patch. 3. Set a mechanical plug in the tubing tail (TTP). 4. MIT tbg. CMIT TxlA. MITOA. Obtain State witness of CMIT and MITOA. If the MITOA and the combined tubing by inner annulus MIT pass, request a variance for water injection only. 5. Pull plug from tailpipe. 6. Obtain a cement bond log (SCMT) to show adequate cement coverage between the top Sag River and the next highest hydrocarbon zone (Kuparuk). 7. Put the well on water injection and perform the first 6 months of scheduled surveillance logging. Monitor the IA and wellhead pressures. 8. Once the initial surveillance logging is done, set a patch across the hole in the tubing and perform a full MIT (State witnessed) in order to prepare the well for MI injection. SCANNED JUL ! 2002 TREE= 4" OW SAFETY NOTES: BEFORE RUNNING 1" GLV'S IN THEOLD ' Z 02A WELLHEAD = MCEVOY = STYLEKBG-2LS GLIVI'S, THE NO-GO ON RUNNING HEAD ACTUATOR = OTIS ~' NEEDS TO BE MOVED UP 1/Z'. OLD WFI LBORE NOT KB. ELEV = 91.76' SHOWN ON DIAGRAM BI=IOW MLLOUT WINDOW. BF. REV = 55.46' KOP= 3100' IVlax A~le = 31 @ 8285' O Datum IVD = 9514' i 501' 4-1/2" HES HXO SSSV NIP, D = 3.813" Datum TVD = 8800' SS I 13-3/8"CSO, 68#,L-80,1D=12.415"H 2675' ~ [ GAS LIFT MANDRELS ST MO TVD DEV TYPE VLV LATCH SIZE DATE 6 2994! 2902 0 MMG DOIVE la~ 1.5" 09/09/96 ~ L 5 4944; 4698 28 MMG S/O F~ 1.5" 09/09/96 ',..,.,.,,.~,,,~Ainir~'m ID = 3.725" r~_. 9182'_ 4 6275 5888 26 MMG DV I~( 1.5" 09~09~96 4-1/2"HESXNNIPPLE I 3 7429 6925 15 KBG-2LS DV BTM 1" 09~09~96 2 8411 7821 31 KBG-2LS DV BTM 1" 09~09~96 1 9059 8379 28 KBG-2LS DV BTM 1" 09~09~96 I 9-5/8" X 7" BKR ZXP PKR W/TIBK, D = 6.31" 7071' ~ 9-5/8" X 7" BKR HMC LNR HGR, D = 6.25" H 7085' 9.5/8" MLLOUT WINDOW FERFORATION SUMMA RY 7284' - 7334' Ri~ LOG: SONIC ON 04/15~96 ANGLEATTOP PERF: 15 @ 9506' Note: Refer b3 Production DB for historical perf data SIZE SPF INI'ERV AL Opn/Sqz i DATE s 3-3/8" 2 9548'-9600' O 09/03/96 9127' 4-1/2" HESX NIP, ID= 3.813" 3-3/8" 2 9612' -9638' O 09/0:3/96 ~%% %~///J 9160 H4-1'2" HES X NIP, ID = 3.813" I J 4-1/2" TBG, 12.B#, L-80 BTO-IVI, .0152 BPF, ID = 3.9 I""~ H9747'I I~"'~. ~, ~-~° ~*°-~, °-°~ ~', '~ = ~.'~'' I--I J DATE RL:V BY COMMENTS DATE REV BY COIVIVIE~ITS PRUDHOEBAY UNIT 06/28/88 ORIGNAL COMPLETION WELL: Z-02A 04/19/96 CI-H RIG SIDETRACK PERIVIT No: 196-0430 03/12/01 SIS-QAA CONVERTEDTOCANVAS , APl No: 50-029-21814-01 03/14/01 SIS-MD FINAL i~,,~C~NN~Jgj34.~jj~,jljFi ,~e~l~jtjrjl~i, R125 06/23/01 CHfI'P CORRECTIONS BP Expl0r~ion (Ala~lEa-)- SIZE SPF INI'ERV AL Opn/Sqz DATE 3-3/8" 2 9506' -9528' S 09104/96 3-3/8" 2 9548' -9600' O 09/03/96 3-3/8" 2 9612' -9638' O 09/0:3/96 DATE RL:V BY COMMENTS DATE REV BY COIVIVIENTS 06/28/88 ORIGNAL COMPLETION 04/19/96 CI-I-I RIG SIDETRACK 03/12/01 SIS-QAA CONVERTED TO CANVAS 03/14/01 SIS-MD FINAL 06/23/01 CH/I'P CORRECTIONS THE MATERIAL UNDER THIS COVER HAS BEEN MICROF'ILMED ON BEFORE JANUARY 03 2001 PL M A'T E W IA L UNDER T H IS M A R K E R AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 04/20/98 PERMIT DATA 96-043 7223 96-043 GR/CCL/PERF 96 - 043 GR/CCL / JEWELRY 96-043 DIFL T DATA PLUS T DIFL/DAC/CN/GR L SEPIA L SEPIA L SEPIA 96-043 DAC L SEPIA 96-043 CN L SEPIA 96-043 SSVD L SEPIA 96-043 FMT L SEPIA 96-043 PLS (SPIN) L SEPIA 9300-9700 96-043 LEAK DETECT L 20-9200 96-043 PLS - LEAK L 1040-9250 RUN RECVD 05/21/96 1 05/21/96 1 05/21/96 1 05/03/96 1 05/03/96 1 05/03/96 1 05/03/96 1 05/03/96 1 06/21/96 FINAL 09/10/96 FINAL 09/11/96 10-407 R COMPLETION DATE / / / DAILY WELL OPS R / / / TO / / / 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 COMMENTS / / / / / / yes no yes no HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL C-21 (32-19-11-14) P-01 (33-27-'11-13) -13 DESCRIPTION 1 PFC/PERF FIELD BL+RF i CN FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF i PLS FINAL BL+RF 1 PDK FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 4352.05 Run # i 5789.02 Run # 1 5851.03 Run # 1 5863.07 Run # 1 6054.08 Run # 1 6619.01 Run # i 6625.01 Run # 1 6631.02 Run # 1 6654.06 Run # 1 6679.01 Run # 1 6721.07 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 4 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL D-c8 # DESCRIPTION 1 CN FINAL BL+RF 1 CN FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 5637.05 Run # 1 6107.05 Run # 1 6654.05 Please sign. and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 $£P 77. 7996 Alaska Oit & Cas Cons. Commission /m~ora3e HOWARD OKLAND Attn. ALASKA OiL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 '~-" ! "~l 996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described WELL ~ DESCRIPTION ~'/-/,17 A-19 - 1PFC/PERF FINAL BL+RF R-ii ! PLS FINAL BL+RF ql-~73R-25~32-3!-ll-13) 1 PLS FINAL BL+RF x-os x-e8 1 PFC/PERF FINAL BL+RF 1 CCL FINAL BL+RF i PLS FINAL BL+RF 1PFC/PERF FINAL BL+RF 1 GR/CCL FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. !130.09 3924.04 4589.03 5778.04 6234.06 6234.07 6654.04 6682.00 Please sign and return to: Attn. Rodney D. Pau!son Western Atlas Lcccinc Services 5600 B Stree~ Suite 201 Received by: Anchorage, AK 99518 /:/ ,~r FAXito (9~7) 563-7803 .... . , Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE ' : AK, 99501. Date: 7 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL Z-02A DESCRIPTION PFC/PERF FINAL BL*RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 2384.03 Run # 1 4468.05 Run #' 1 4912.06 Run # 1 6053.02 Run # 1 6225.02 Run # 1 6654.02 Run # 1 6654.03 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. Run ~ 1 4041.04 Run # 1 6654.00 , _ . Please sign and return:t0? Attn. Rodney D. Paulson ., Western Atlas Logging Services 5600 B Street Suite 201 -Anchorage, AK 99518 Received by: Date: -.~'-~'"' STATE OF ALASKA f:,...~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging X Time extension ~ Stimulate ~ Change approved program ~ Pull tubing ~" Vadance~ Perforate ~ Other Plugback for redrill 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic Service __ 4. Location of well at surface 976' SNL, 1462' EWL, SEC. 19, T11N, R12E At top of productive interval 1720'NSL, 515' EWL, SEC. 19, T11N, R12E At effective depth 1877' NSL, 460' EWL, SEC. 19, T11N, R12E At total depth RECEIVED APR 1 2 1995 Naska Oil & Gas Cons. Cj;ll:l~:iISSl0ll Anchora.j~ ~-" 6. Datum elevation (DF or KB) KBE = 91.76 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-02 (13-19-11-12) 9. Permit number 88-54 10. APl number 50- 029-21814 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9900 feet Plugs (measured) 9225 feet 9854 feet Junk (measured) 9182 feet Length Size Cemented Measured depth 110' 30" 8 cu yds 147' 2638' 13-3/8" 3580 cu ft 2675' 9222' 9-5/8" 1865 cuft 9259' 901' 7" 325 cuft 8999'-9900' measured 9600'-9615', 9634'-9656', 9660'-9667', 9672'-9682', 9686'-9698', 9702'-9708' True vertical depth 147' 2675' 8634' 8396'-9225' true vertical 8947'-8896' (six intervals) Subsea Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing w/4-1/2" tailpipe to 9040' MD Packers and SSSV (type and measured depth) 9-5/8" TIW Packer @ 8939' MD; 4-1/2" Camco SSSV @ 2111'MD 13. Attachments Description summary of proposal × Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 4/2O/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended__ Service 17. I hereby~ that the~e Signed and correct to the best of my knowledge. Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity -~'"' BOP Test Location clearance__ Mechanical Integdfy Test __ Subsequent form required 10- /--/d~' ORIGiI~L SIGNED BY Approved by order of the Commission .RUSSELL A. DOUGLASS I Approval No.~;$__ 0,7"// Approved Copy .:. Returned Commissioner Date/../t. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE · Z-02 P&A SUMMARY PROCEDURE Pre-rig work: Complete pre-rig annular communications diagnostics and packoff test to evaluate the presence or absence of annular communication. Cut tubing. Kill well. Freeze protect. 2. MIRU rig. . Pull BPV. Circulate out freeze protection fluid. Insure packoff has been tested. if not, have Drill Site Maintenance test packoff. 4. Set two-way check. ND tree and tubing head adapter. . . . . NU BOP's. Test BOP's to 5000 psi. Test annular to 250/2500 psi. Pull two-way check. Note AOGCC witness or waiver on the morning report. Pull and lay down 4-1/2" tubing. Note on the morning report the visual condition of the tubing, it is intended to reuse as much as possible. TIH w/EZSV & set same above stub at approximately 8890'. Anticipated tubing cut is 8900'. Squeeze perfs (9600-9708') w/160 sx (1.15 yield) mixed at 15.8 ppg below retainer. Cement volume is calculated as follows: Retainer @ 8890' 4-1/2" tubing stub @ 8900' Cement 100' past btm perf 9-5/8" 47# 8890'-8900' 4-1/2" 12.6# 8900'-9041' 7" 26# 9041 '-9808' (ft)(ft3/ft) (ft3) (10')(0.4110) = 4.11 (141)(0.08544) = 12.05 (767)(0.2148) = 164.75 Total: 180.91 Sx Cmt = 180.91/1.15 = 157 sx Test the 9-5/8" casing to 3500 psi for ten minutes. Replace packoff if pre-rig PPPOT failed. RECEIVED APR 1 2 1995 Aiaska 0il & Gas Cons. Commission Anch0ra,.? Redrill Plan Summary Page 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 96-43 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 9951~9-__6_._6.1._~. ....... -. 50-029-21814-01 4. Location of well at surface 976' SNL, 1462' EWL, SEC. 19, T11 N, R12~ r-~'ri~ ! ~~i ~,~..,;~;'r~ . 9. UnitprudhoeOr LeaSeBay Nameunit At top of productive interval 2429' SNL, 1746' EWL, SEC. 19, T11N, R12E ~r~;;~ i Z-02A At total depth i ~ "-'~-~"' .... ,~-. --~ 11 Field and Pool 2400' SNL, 1813' EWL, SEC. 19, T11N, R12E Prudhoe Bay Field/Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 84.24I ADL 028262 12. Date Spudded04/10/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 16' N°' °f C°mpleti°ns04/14/96 04/26/96 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosl 9879 9242' FTI 9748 9113 F~ I~Yes []No I 501' MD! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, CNL, BHCS, RES, NEU, Sonic, DIFL, AC, FMT 23. CASING, LINER AND CEMENTING RECORD CASING SE'FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FFOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 8 cu yds Concrete 13-3/8" 68# L-80 Surface 2675' 17-1/2" 3580 cuft Permafrost 9-5/8" 47# L-80 Surface 7284' 12-1/4" 1865 cu ft Class 'G' 7" 29# L-80 7071' 9833' 8-1/2" 195 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 2 spf 4-1/2" 9195' 9137' MD TVD MD TVD 9506'- 9528' 8876' - 8898' 9548' - 9600' 8917' - 9600' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 9612' 9638' 8980' - 9005' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/160 Bbls Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) April 26, 1996 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BEE GAS-MCF WATER-BEE CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED ~ OIL-DEL GAS-MCF WATER-DEL 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. ORIGINALRECEIVED MAY 0 8 t996 Alaska 011 & 6as (;0ns, Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Dupplicate 29. Geologic Markers 30. Formation Tests Measured True Vedical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 9320' 8703' Shublik 9351' 8731' Top of Zone 4 9504' 8874' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. l hereby certify that~.f/o,o~going~'/~,e ~;:~correct to the best of my knowledge ~ ~"~'~i~, Signed DanStoltz ,/(/~"'4¢¢¢.4~/ ¢ ~,~~~ Title Senior Drilling Engineer Date ~',~- ¢~ Prepared By Name/Number Terrie Hubble, 564-4628 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED MAY 0 R 199(; Form 10-407 Rev. 07-01-80 Oil & Gat~ O~ms, commission Anchorage SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: Z-02A Rig Name: Nabors 18E AFE: 4P0797 Accept Date: 04/03/96 Spud Date: 04/1 0/96 Release Date: 04/1 9/96 Apr 3 1996 (1) Rig moved 0 %. Rig moved 100 %. Circulated at 0 ft. Apr 4 1996 (2) Removed Hanger plug. Circulated at 8900 ft. Circulated at 8900ft. Installed Hanger plug. Removed Xmas tree. Rigged up BOPstack. Tested BOP stack. Retrieved Hanger plug. InstalledHanger plug. Tested BOP stack. Apr 5 1996 (3) Retrieved Hanger plug. Installed Hanger plug. Tested BOP stack. Rigged down BOP stack. Rigged up BOP stack. Tested Tubinghanger. Rigged down BOP stack. Rigged up BOP stack. TestedChoke manifold. Repaired Choke manifold. Tested BOP stack. Re-trieved Hanger plug. Retrieved Tubing hanger. Circulated at 8900 ft. Laid down 3000 ft of Tubing. Apr 6 1996 (4) Laid down 8900 ft of Tubing. Rigged up Top ram. Removed Sealassembly. Set Retrievable packer at 81 ft with 0 psi. Riggeddown BOP stack. Installed Seal assembly. Tested BOP stack. Pulled Drillpipe in stands to 1395 ft. Installed Wear bushing. Ran Drillpipe to 7534 ft (5 in OD). Circulated at 7534 ft. Apr 7 1996 (5) Circulated at 7534 ft. Injectivitytest- 50 bbl injected at1320 psi. Mixed and pumped slurry - 30 bbl. Circulated at 7534ft. Pulled Drillpipe in stands to 0 ft. Made up BHA no. 1 .R.I.H. to 7534 ft. Circulated at 7534 ft. Pulled out of hole to7284 ft. Circulated at 7284 ft. Milled Casing at 7302 ft. Apr 8 1996 (6) Milled Casing at 7334 ft. Circulated at 7334 ft. Pulled out ofhole to 685 ft. Pulled BHA. Made up BHA no. 1 . R.I.H. to 7284ft. Milled Casing at 7334 ft. Circulated at 7334 ft. Workedtoolstring at 7284 ft. Pulled out of hole to 3000 ft. Operations Summary for: Z-02A Apr 9 1996 (7) Pulled out of hole to 685 ft. Pulled BHA. Removed Wear bushing. Installed Wear bushing. Ran Drillpipe in stands to 7328 fi. Washed to 7434 fi. Circulated at 7434 ft. Displaced slurry - 31bbl. Pulled Drillpipe in stands to 6342 fi. Circulated at 6342ft. Injectivity test - 3 bbl injected at 1300 psi. Pulled outof hole to 0 ft. Made up BHA no. 2. R.I.H. to 7320 ft. Circu-lated at 7320 fi. Drilled cement to 7347 fi. Circulated at 7347ft. Pulled out of hole to 600 ft. Pulled BHA. Ran Drillpipe instands to 5000 fi. Apr 10 1996 (8 ) Ran Drillpipe in stands to 7320 fi. Washed to 7343 fi. Circu-lated at 7343 fi. Mixed and pumped slurry- 31 bbl. PulledDrillpipe in stands to 6227 ft. Circulated at 6227 fi. Injec-tivity test - 4 bbl injected at 1500 psi. Pulled out of hole toO fi. Made up BHA no. 3. R.I.H. to 7287 ft. Circulated at7284 fi. Pulled out of hole to 600 ft. Pulled BHA. RetrievedWear bushing. Tested BOP stack. Installed Wear bushing. Madeup BHA no. 4. R.I.H. to 7287 fi. Apr 11 1996 (9) Circulated at 7286 ft. Drilled to 7594 ft. Circulated at 7594ft. Pulled out of hole to 629 fi. Pulled BHA. Made up BHA no.5. R.I.H. to 7000 ft. Apr 12 1996 (10) R.I.H. to 7594 ft. Drilled to 8003 ft. Circulated at 8003 fi. Pulled out of hole to 629 fi. Pulled BHA. Made up BHA no. 6 .R.I.H. to 7568 fi. Took MWD survey at 7568 ft. Drilled to 8110ft. Apr 13 1996 (11) Drilled to 9388 ft. Circulated at 9388 ft. Pulled out of holeto 7950 fi. R.I.H. to 9388 ft. Drilled to 9419 fi. Apr 14 1996 (12) Drilled to 9856 fi. Apr 15 1996 (13) Drilled to 9879 fi. Circulated at 9879 ft. Pulled out of holeto 7280 fi. R.I.H. to 9800 ft. Reamed to 9879 ft. Circulatedat 9879 ft. Pulled out of hole to 8950 ft. R.I.H. to 9879 fi. Circulated at 9879 fi. Pulled out of hole to 635 ft. PulledBHA. Rigged up Logging/braided cable equipment. Ran electriclogs. Ran electric logs. R£C[IV D Page 2 M.~V 0 ~ 1996 Anchorage Operations Summary for: Z-02A Apr 16 1996 (14) Ran electric logs. Rigged down Logging/braided cable equipment. Made up BHA no. 7. R.I.H. to 9785 ft. Reamed to 9879 ft. Circulated at 9879 ft. Pulled out of hole to 2644 ft. Pulled BHA.Rigged up Top ram. Rigged up Casing handling equipment. Heldsafety meeting. Ran Casing to 2774 ft (7 in OD). Ran Drillpipein stands to 4000 ff. Apr 17 1996 (15) Ran Drillpipe in stands to 9814 ft. Washed to 9835 ft. Circulated at 9835 ft. Mixed and pumped slurry - 113 bbl. Set Linerhanger at 7085 ft with 4500 psi. Reverse circulated at 7055 ft. Circulated at 7055 ft. Pulled Drillpipe in stands to 0 ft. Rigged up Top ram. Tested Top ram. Made up BHA no. 8 . Ser-viced Block line. R.I.H. to 9609 ft. Apr 18 1996 (16) Drilled cement to 9747 ft. Tested Casing - Via annulus andstring. Circulated at 9747 ft. Tested Casing - Via annulus andstring. Laid down 9700 ft of 5 in OD drill pipe. Pulled BHA. Retrieved Bore protector. Rigged up Completion string handlingequipment. Ran Tubing to 8694 ft (4.5 in OD). Apr 19 1996 (17) Ran Tubing to 9194 ft (4.5 in OD). Circulated at 9191 ft. Spaceout tubulars. Set packer at 9137 ft with 4000 psi. Rigged downAII functions. Installed Xmas tree primary components. RemovedHanger plug. Freeze protect well - 160 bbl of Diesel. InstalledHanger plug. April 26, 1996 A total of 100' of initial perforations were shot. The well was underbalance while perforating. Reservoir pressure at 3900 psi from RFT. The intervals were perforated with Atlas Wireline Services, 3-3/8" Deep Penetrating charges via E-line. They were shot at 2 spf (6" between perfs), 60 degree phasing and random orientation. Perf Interval 9506'- 9528' 9600'- 9548' 9638'- 9612' Total Feet Perfs 22' 52' 28' 100' Page 3 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/Z-02A 500292181401 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 041496 MWD SURVEY JOB NUMBER: AK-MW-60040 KELLY BUSHING ELEV. = 84.24 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7195.37 6805.33 6721.09 7287.37 6885.17 6800.93 7437.29 7023.61 6939.37 7468.57 7054.06 6969.82 7499.45 7084.39 7000.15 29 52 29 42 14 40 11 46 10 3 S 27.30 W .00 S 27.60 W .24 S 19.80 W 10.20 S 8.80 W 12.24 S 3.50 E 9.37 1685.78S 444.38W -1176.62 1726.34S 465.45W -1214.12 1777.44S 489.24W -1258.93 1784.33S 491.07W -1263.75 1790.13S 491.39W -1266.73 7532.87 7117.31 7033.07 7562.97 7146.99 7062.75 7595.65 7179.19 7094.95 7626.43 7209.45 7125.21 7657.86 7240.29 7156.05 9 48 S 18.70 E 7.85 9 32 S 28.00 E 5.26 10 15 S 49.40 E 11.40 10 48 S 61.00 E 7.09 11 30 S 73.10 E 7.75 1795.74S 490.30W -1268.37 1800.37S 488.30W -1268.75 1804.66S 484.82W -1267.66 1807.84S 480.22W -1265.06 1810.18S 474.65W -1261.21 7688.26 7270.01 7185.77 7719.54 7300.36 7216.12 7753.39 7332.85 7248.61 7784.20 7362.11 7277.87 7814.93 7391.03 7306.79 12 51 S 88.00 E 11.23 15 7 S 89.80 E 7.36 17 30 N 80.00 E 10.98 18 56 N 79.80 E 4.68 20 39 N 73.60 E 8.83 1811.17S 468.36W -1256.11 1811.31S 460.80W -1249.48 1810.44S 451.37W -1240.73 1808.75S 441.89W -1231.54 1806.34S 431.78W -1221.47 7847.61 7421.51 7337.27 7878.45 7450.07 7365.83 7908.35 7477.46 7393.21 7939.10 7505.37 7421.13 7969.53 7532.63 7448.39 21 32 N 75.00 E 3.13 22 51 N 72.20 E 5.46 24 24 N 69.00 E 6.73 25 14 N 62.60 E 9.14 27 34 N 56.00 E 12.31 1803.16S 420.45W 1799.86S 409.28W 1795.87S 397.98W 1790.57S 386.23W 1783.65S 374.62W -1209.96 -1198.53 -1186.68 -1173.81 -1160.31 8001.38 7560.53 7476.29 8093.61 7640.34 7556.10 8191.25 7724.53 7640.29 8285.16 7804.96 7720.72 8377.12 7883.79 7799.55 30 7 N 53.20 E 9.06 30 1 N 53.80 E .34 30 52 N 59.00 E 2.83 31 17 N 63.10 E 2.30 30 42 N 63.10 E .64 1774.74S 362.11W 1747.25S 324.96W 1719.92S 283.77W 1696.48S 241.38W 1675.05S 199.14W -1145.09 -1099.43 -1050.26 -1001.82 -954.47 8474.99 7968.29 7884.05 8569.20 8050.18 7965.94 8660.07 8129.19 8044.95 8752.70 8209.21 8124.97 8846.59 8289.26 8205.02 8941.75 8370.16 8285.92 9034.89 8450.30 8366.06 9128.41 8531.87 8447.63 9224.02 8616.63 8532.39 9312.34 8696.03 8611.79 29 53 N 63.40 E .84 29 22 N 65.70 E 1.32 29 49 N 67.00 E .86 30 40 N 65.60 E 1.19 32 19 N 65.60 E 1.76 31 13 N 65.40 E 1.16 30 2 N 65.00 E 1.29 28 29 N 64.40 E 1.69 26 37 N 66.60 E 2.23 25 17 N 65.80 E 1.56 1652.83S 155.06W 1632.81S l13.01W 1614.81S 71.89W 1596.05S 29.18W 1575.79S 15.49E -905.11 -858.57 -813.80 -767.26 -718.29 1555.01S 61.08E -668.27 1535.11S 104.15E -620.88 1515.58S 145.48E -575.20 1497.22S 185.71E -531.06 1481.63S 221.07E -492.49 RECEIVED MAY 0 8 1996 011 & G~e Oon~. commission Anchorage ~{RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHA~RED SERVICES DRILLING PBU/Z-02A 500292181401 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 041496 MWD SURVEY JOB NUMBER: AK-MW-60040 KELLY BUSHING ELEV. = 84.24 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9408.50 8783.92 8699.68 22 33 N 64.90 E 2.86 1465.38S 256.52E -453.56 9439.27 8812.60 8728.36 19 53 N 64.90 E 8.64 1460.66S 266.61E -442.43 9471.67 8843.31 8759.07 17 18 N 65.80 E 8.04 1456.34S 276.00E -432.11 9503.04 8873.46 8789.22 14 41 N 66.50 E 8.37 1452.84S 283.90E -423.48 9534.79 8904.27 8820.03 13 13 N 66.60 E 4.60 1449.79S 290.93E -415.84 9565.68 8934.39 8850.15 12 27 N 68.30 E 2.78 1447.16S 297.27E -409.00 9597.39 8965.40 8881.16 11 36 N 66.60 E 2.90 1444.62S 303.38E -402.42 9690.33 9056.60 8972.36 10 33 N 67.80 E 1.17 1437.70S 319.84E -384.62 9785.25 9149.94 9065.70 10 22 N 66.10 E .37 1430.95S 335.70E -367.44 9807.62 9171.95 9087.71 10 21 N 65.80 E .27 1429.31S 339.38E -363.42 9879.00 9242.16 9157.92 10 21 N 65.80 E .03 1424.04S 351.09E -350.61 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1466.69 FEET AT SOUTH 13 DEG. 50 MIN. EAST AT MD = 9879 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 62.32 DEG. TIE IN POINT 7195.37 WINDOW POINT 7287.37 INTERPOLATED DEPTH q879' %RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/Z-02A 500292181401 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 041496 JOB NUMBER: AK-MW-60040 KELLY BUSHING ELEV. = 84.24 OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7195.37 6805.33 6721.09 1685.78 S 444.38 W 8195.37 7728.07 7643.83 1718.83 S 281.96 W 9195.37 8591.01 8506.77 1502.32 S 173.92 E 9879.00 9242.16 9157.92 1424.04 S 351.09 E 390.04 467.30 77.26 604.36 137.06 636.84 32.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RECEIVED °tRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/Z-02A 500292181401 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 041496 JOB NUMBER: AK-MW-60040 KELLY BUSHING ELEV. = 84.24 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7195.37 6805.33 6721.09 1685.78 S 444.38 W 390.04 7286.28 6884.24 6800.00 1725.84 S 465.18 W 402.04 12.00 7396.17 6984.24 6900.00 1766.44 S 484.87 W 411.93 9.89 7499.30 7084.24 7000.00 1790.09 S 491.35 W 415.06 3.13 7600.78 7184.24 7100.00 1805.22 S 484.09 W 416.54 1.49 7702.90 7284.24 7200.00 1811.26 S 464.94 W 418.66 2.11 7807.70 7384.24 7300.00 1806.96 S 434.18 W 423.46 4.81 7915.81 7484.24 7400.00 1794.72 S 395.11 W 431.57 8.10 8028.80 7584.24 7500.00 1766.50 S 351.10 W 444.56 12.99 8144.42 7684.24 7600.00 1732.66 S 303.95 W 460.18 15.62 8260.91 7784.24 7700.00 1702.17 S 252.61 W 476.67 16.49 8377.64 7884.24 7800.00 1674.93 S 198.91 W 493.40 16.73 8493.38 7984.24 7900.00 1648.72 S 146.86 W 509.14 15.74 8608.29 8084.24 8000.00 1624.92 S 95.52 W 524.05 14.91 8723.67 8184.24 8100.00 1602.17 S 42.66 W 539.43 15.38 8840.65 8284.24 8200.00 1577.10 S 12.59 E 556.41 16.98 8958.22 8384.24 8300.00 1551.46 S 68.84 E 573.98 17.57 9074.10 8484.24 8400.00 1526.82 S 121.94 E 589.86 15.88 9187.79 8584.24 8500.00 1503.68 S 170.80 E 603.55 13.69 9299.30 8684.24 8600.00 1483.91 S 215.99 E 615.06 11.51 9408.83 8784.24 8700.00 1465.34 S 256.60 E 624.59 9.53 9514.18 8884.24 8800.00 1451.72 S 286.49 E 629.94 5.36 9616.63 8984.24 8900.00 1443.09 S 306.93 E 632.39 2.44 9718.44 9084.24 9000.00 1435.75 S 324.60 E 634.20 1.82 9820.12 9184.24 9100.00 1428.39 S 341.43 E 635.88 1.67 9879.00 9242.16 9157.92 1424.04 S 351.09 E 636.84 .96 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED MAY 0 ~ 1991~ Alaska Oil & G~ Cons. Commission Anchorage U £'--'~,U Du.,-_ ALASKA OIL AND GAS CONSERVATION COMMISSION / ! .i TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 275-7542 April 4, 1996 Dan Stoltz, Sr. Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, ?aK 99519-6612 Re: Pmdhoe Bay Unit Z-02A Revised BP Exploration (Alaska), Inc. Perm/t No: 9643 Sur Loc 4303~SL, 3492'WEL, Sec. 19, T1 IN, R12E, UM Btmhole Loc 29082qSL, 3116'WEL, Sec. 19, T1 IN, R12E, UM Dear Stoltz: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated February 28, 1996 are in effect for this revision. Sincerelw David W. Jo~ Chairman BY ORDER OF THE COM3/II$SION dlf/Enclosures CC: Department ofFish & Game, Habitat Section W/o encl Department of Env/ronmental Conservation w/o encl LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 April 1996 RE: Transmittal of Data ECC #: 6654.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: BP Z-02A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 DIFL FINAL BL+RF Run # 1 1 CN FINAL BL+RF Run # 1 1 DAC FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 Received by: ~ Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 (907) 563-7803 Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 19 April 1996 Transmittal of Data ECC #: 6654.01 Sent by: HAND CARRY Data: FMT Dear Sir/Madam, Reference: BP Z-02A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 FMT FINAL BL+RF Run # 1 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Date: STATE OF ALASKA Revised 3/28/96 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillClllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []l Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc Plan RTE = 83.61 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchora~Te, Alaska 99519-6612 ADL 028262 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 4303' NSL, 3492' WEL, SEC. 19, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2864' NSL, 3162' WEL, SEC. 19, T11N, R12E Z-O2A 2S100302630-277 At total depth 9. Approximate spud date Amount 2908' NSL, 3116' WEL, SEC. 19, T11N, R12E 04/01/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property,15. Proposed depth(UDandTVD) property line ADL 028245 1845 feet No Close Approach feet 2560 9885' MD/9222' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 7284 feet Maximum hole angle28.7 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 Btc-Mod 2751' 7134' 6744' 9885' 9222' 295 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True~Ve~di~.al depth Structural p~FC Conductor .... !~ t ~']v~-; [~ D Surface Intermediate !'".,/'IA~! '~_ O Production Liner ^lr.s!-'.~ Oi~ ,.'._, G?..~ ..... ,%n,~n,o.,,o.,, Perforation depth: measured true vertical ~ t:?~ ~¢~('; .~X~,,'~[ I~!~,~r-~ .5'~.$~, 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21 I hereby c?~fy that thee ff~re, goj~g, i~rego' g is true and correct to the best of my knowledge c,~,~,~.4-~,~.,~-; l~,v¢~ Signed ?'~/~.~.~b~ ~'~~ Title Senior Drifting Engineer Date ~ Commission Use Only Permit Number APl number IApproval date See cover letter 96-43 5 0-029.21814.01 J102/28/96 for other requirements Conditions of approval Samples required [] Yes J~No Mud log required []Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; []3M; 1~5M; I-I10M; [-115M; Other: Original Signed By by order of ../~.,/., Approved by David W. Johnston Commissioner Tne comm,ssion Date Form 10-401 Rev. 12-1-85 Submit libate I Well Name: I Z-02A I Redrill Plan Summary Revision Type of Well (producer or injector): I Oil Producer Surface Location: 4303' FSL 3492' FEL Sec 19 T11N R12E Target Location: 2884' FSL 3162' FEL Sec 19 T11N R12E Bottom Hole Location: 2908' FSL 3116' FEL Sec 19 T11N R12E AFE Number: I 4P0797 I I Rig: I Nabors 18-E Estimated Start Date: I April 1, 1996 I I Operating days to complete: I 15 uD: 19885' I I TVD= I e222' I IRT-GL I KBE: Well Design (conventional, slimhole, etc.) 29.7' 83.91' Conventional Sidetrack IObjective: I well should have a Iow GOR (-1500 scf/stb). I I Zone 4 corner producer in a EWE waterflood/EOR pattern sufficiently downdip that the Casinc/Tubinq Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8-1/2" 7" 29# L-80 BTC- 2751' 7134'/6744' 9885'/9222' MOD Tubing 4-1/2" 12.6# L-80 BTC- 9328' 26'/26' 9354'/8711' MOD Logging Program: I Logs: l 8-1/2" Hole GR/Resistivity/Sonic/Neutron and RFT Cased Hole: None Mud Program: 9.8 - 10.0 ppg fresh water based mud will be used I Special d~,i'gn considerations I None Depth Density ' Fann Yield 10 sec 10 Tin pH HTHP (PPG) Viscosity Point ~lel gel 7284' 9.8 40 10 4 6 9.0 15 to to to to to to to to 9885' 10.5 50 12 10 12 9.0 15 Directional: I KOP: 17284' MD I aximum Hole Angle: Close Approach Well: 29.7 No Close Approach Wells Z-02A Redrill Revision Page 1 Cement calculations: I Liner Size: I 9-5/8" liner P&A Kickoff Plug IBasis:I 30% open hole excess, 100' below window to 200' above window Total Cement Volume: ! 1801 sxs of 17.0 ppg Class G Blend @ 0.982 ft3/sx I Liner Size: I 7' liner IBasis:I 50% open hole excess, 80' shoe joint and cement to liner top Total Cement Volume: I 100 / 195 I sxs of 11.0 / 15.7 ppg Class G Blend Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Hazards · Sadlerochit pressure is @ 3900 psi at @ 8800' TVDss or EMW of 8.50 ppg · Sag River pressure at 8671' TVDss is same as Sadlerochit Pressure. EMW will be 8.64 ppg. · Eileen formation pressure at @ 8800' TVDss is same as Sadlerochit Pressure. EMW = 8.5 ppg The Kuparuk interval in this area warrants attention. This zone typically has required mud weights in excess of 10.5 ppg. The planned window at 7284' MD is 130' TVD below the Kuparuk and the Top of Cement behind the 9-5/8" casing is calculated to be between 3448' MD (gauge hole) and 5384' MD (50% washout over gauge hole). Since cement behind the 9-5/8" casing extends past the Kuparuk, the overpressure hazard is not expected. However, the Kuparuk overpressure hazard should be noted. Z-02A Redrill Revision Page 2 Operations Summary: Pre Rig Work: 1. Complete pre-rig annular communication diagnostics and pack-off test to evaluate the presence or absence of annular communication. Cut tubing at 8900' MD. 2. Displace the tubing and wellbore to 9.0 ppg brine/seawater. Freeze protect top 2200' MD with diesel (overbalance of 100 psi). Bleed tubing and annuli pressures to zero. Set BPV in the tubing hanger and test from below to 1000 psi. Secure well. Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Rig-Work: . . 1. MIRU Nabors 18E. . . . . . . Pull BPV. Circulate out freeze protection from inner and outer annuli and recover for future use. Test 9-5/8" mandrel packoff to 5000 psi. If pack-off fails, change out packoff in Step 5 prior to cutting the section. Install a TWC and test from below to 1000 psi. N/D the production tree. N/U BOP. Test BOP to 250/5000 psi against TWC. Test annular preventer to 250/2500 psi. Remove TWC. Send adapter flange and tree to DSM for inspection and repair. Pull and unseat tubing hanger. CBU. Pull and lay down the 4-1/2" tubing. (Tubing should be chemical cut at 8900' MD. Check the location and exact depth of the cut on production handover form) Inspect for NORM. Label tubing as it is laid down with well name and joint number. Install thread protectors on pipe which upon visual inspection appears to be re- usable. If tubing is salvageable, send tubing to Tuboscpoe for inspection. If 9-5/8" mandrel packoff did not test in Step 2, pull and replace packoff through the BOP stack. P/U bridge plug ( EZSV ) and RIH to set it at @ 7434' MD. The tubing was cut at 8900' MD. Stay stung in and P & A well in the following manner: Establish an injection rate. Bullhead and squeeze perforations at 9600' - 9708' MD Displace to leave the top of cement inside of 7" liner @ no lower than 9500' MD ( 100' above the top of perforations ). Pressure test as per AOGCC requirements. Total volume of cement should be as follows: 13.2 bbls to fill inside of 7" liner from PBTD at 9853' to 9500' MD plus 5 bbls will be squeezed away for the total volume of ~19 bbls of cement slurry. POOH. Pump 30 bbls of cement for extra assurance per conversation with Bair Wondzell with AOGCC. Please hook up pressure recorder to record pressures and send the chart to town. Pressure chart should indicate a pressure increase as cement is being pumped into open perfs from 9600' - 9708'. The pressure chart will be sent to the AOGCC. P/U9-5/8" section mill on 5" drill pipe and RIH to EZSV at 7434' MD. Spot 18 ppg mud pill. Displace well to milling fluid. Z-02A Redrill Revision Page 3 , . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Note: If ( Office Cut window from 7284' to 7334' MD. Keep flowrate between 600 - 700 gpm while milling casing. POOH after ensuring the hole is clean and free of metal cuttings. RIH open ended and spot a kick-off plug from 100' below the base of the section at 7434' MD to 200' above the top of section at 7084'. Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve a 1000-2000 psi squeeze but do not displace TOC below 100' above section top. Run in with an 8-1/2" steerable assembly (MWD - directional) and dress the cement to 5' below the section top to 7289' MD. Circulate hole clean. Kickoff and directionally drill to TD at ~ 9885' MD. ( Directional plan #9). RU Atlas. Log well with GR / Resistvity / Sonic/Neutron and RFTs. RIH with 8-1/2" hole opener make a conditioning trip for the open hole section Rabbit the drill string. Run a 7", 29#, L-80, BTC-MOD liner with 9-5/8 x 7" packer / hanger to bottom in the 8-1/2" hole and space out for about 150' of lap. Refer to Standard Recommended practices for liner running procedure. Reciprocrate liner 20-30' during circulation and cementaiton. Cement the liner in place with the total cement volume based upon 50% open-hole enlargement plus the 80' shoe volume, with top of cement up to 7134'. ( 100 sxs Lead / 195 sxs Tail ) Set liner hanger / packer with 4200 psi. Reverse out clean. P/U 6" clean out bit on 4.5 DP. RIH and clean out 7" liner to landing collar. Circulate hole clean. Pressure test the liner lap to 3500 psi for 10 min. Displace the hole with filtered seawater with corrosion inhibitor. Test liner lap/casing to 3500 psi for 30 minutes. POOH. RIH with 4-1/2", 12.6#, L-80 BTC-MOD completion with SSSV, GLMs, and 7" x 4-1/2" packer and tailpipe. Set packer and test tubing to 4000 psi. Space out, test the SSSV and land hanger. Install a TWC, and test to 1000 psi. Remove BOP's. Install and test the production tree to 5000 psi. Pull the TWC valve. Drop ball and set the packer. Test tubing to 4000 psi and hold for 30 minutes. While holding the 1500 psi on the tubing, pressure test the annulus to 3500 psi for 30 minutes. First bleed off the annulus, then the tubing to 0 psi. Shear the RP on the upper GLM with 2900 psi annulus pressure. Bleed off pressure and freeze protect with diesel to 2200' MD. Set a BPV. Close the SSSV and secure the well. Release rig. Complete appropriate documentation and hand-over to Production. there are any questions regarding this permit please feel free to call David Nakamura at 564-5606 ) or 275-1834 ( digital beeper ) Z-02A Redrill Revision Page 4 SHARED SERVTCES DR]: Z-02A (Pg) VERT]'CAL SECT]'0N VIEW Section at: 62.32 ~ TVD Scale · ~ inch =. 400 feet Dep Scale - 1 inch = 400 feet DraNn .... ' 03/20/96' . TO AZ e2.32', FRM ~ TVD TO 7492, TVD.,.: DRILL TANGENT. ~'' ~- ' '.': HOLD INC 31.09', ON AZ 62.32', FRM __~88~_...:1'VD TO 870g' TVD DROP ~'/'10O' DI.,To TAROC~I" - Ru, mCHS.0f'TO mc SO.O0';H°LD AZ FRM 81'0m:.m'VD 1'0 8S~7' mVD (884a' SS) umu. m'ANG~rr:,rom. D. ' · -: HOCU mc' ':so.0o.,. ON AZ ~,.,m~,, . ~qM 8re'Z1" TVO 'to S~'?'.mVD (~60, MD.PAST OOWC) · . -~00 -:1800 -1600 -t400 -1000 -800 -600 Sect ion Oeparture -400 0 400 600 800 SHARED ! SERV ICES-' ' DRI LL ING · i i z-OeA (P9) PLAN VTEH i i i i i i cLoSURE · ~447 feet at Azimuth ~64.72 DECLINATION' +28.~7~ (E) SCALE ...... · ~ inch: 200 feet DRA~ ..... '' 03/20/96 ! .4fladr J l l Schlumberger Narker Identification lid A) TIE-IN SIJRVEY .7192 J686 S B} TOP OF NINDOW 7284 t726 S C) KOP / CURVE 9/100 7289 ]728 S O) ENO CURVE 9/t00 7931 t798 S E) DROP 9/~00 9351 1458 S F) ENO DROP 9/I00 9586 t420 S G) TARGET 9586 . 1420 S H} 7' CASING PT 9885 1395 S Z) TO 9885 .~395 S 444 ~ 387 ~ 263 E 335 E 335 E 38! E 38! E 800 700 600 500 400 300 200 tOO 0 tO0 200 300 <- WEST ' EAST -> 400 50O 600 Anadri11 Schlumberger Alaska District 1111 EaSt 80th Avenue AnchOrage, AK 99518 (907) 349-4511 Fax 344-2160. DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLIN~ Well ......... : Z-02A (Pg) Field ........ : PRUDHOE. BAY Z-PAD Computation..: Minimum Curvature Units ........ : FEET Sur "~e Lat..: 70.29769941 N , Suz. Je Long.: 149.19677558 W LOCATIONS - ALASKA Zone: Legal Description x-coord surface ...... = 4303 FSL 3492 FEL S19 T11N R12E UM Tie-in Survey=',2617 FsL 3943 FEL S19 T11N R12E UM TARGET ....... : 2884 FSL 3162 FEL 'S19 T11N R12E %TM BHL .......... : 2908 FSL 31i6 FEL S19 T11N R12E UM 4 Y;Coord 599186.05 5959099.95 598763.99 5957408.60 599540.00 5957685,00 599585,69 5957~09.75 PROPOSED WELL PROFILE ~mm##mmmmm#mmmmmmmmm,.m.m~mm STATION' MEAS iDENTiFiCATION .DEPTH , TIE-IN SURVEY 7192 TOP OF WINDOW 7284 KOP('-,'~IRVE 9/100 7289 7300 7500 ~ ?, .~, .~,~ 7600 ~'~".,c\:~', '~ 9 iJ3~ 7700 INCLN . . . 29.87 29.71 29.71 28.78 20.61 13.46 9.92 13.26 20.34 28.49 ~ND CURVE 9/100 7931 31.09 DIRECTION VERT-DEPTHS AZIMUTH TVD 'SUB-S 207.30 6802 671'9 .. 207.60 6882 6798 20?.62 '6887 6803 206.90 6896 6812 197176 6987 6903 mmmmm BECT DIS? ~m~ -X214 -1216 -1221 -1253 178.57 7083 6999 -1271 136.36 7181 7097 -1273 93.36 7279 7195 -1261 73.60 7375 7291 -1234 64.25' 7466 7382 -1193 62.32 '7492 7408 -1178 ."COORDINATES-FROM Wellhead 1685.78 S 444.38 1726.28,S 465.42 1728.47 S 466.57 1733.25 S ,469.03 1771.55 S 485.32 1800.01 S 490.41 W 1817.91 S 484.16 W 1824.83 S 466.73 W 1820.59 S 438.56 W 1805.29 S 400.33 W 1798.41 S .386.67 W .. · ANADRILL AKA. DPC APPROVED MAE 2 0 1996 INITIAL_ ,~':~ C~>' Prepared ..... : 03/20/96 Vert sect az.: 62,32 KB elevation,= 8~.91 Et Magnetic Dcln: +28.191 (E) Scale Factor.: 0.99991118 Convergence..: +0.75620690 STATE-PLANE X .Y ~{~m~m~m~ ~mmmmmmmmm 598?63.99 595?408.60 598?43.50 595736?.84 598742.38 5957365.63 598739.98 5957360.82 598724.19 5957322.31 TOO~ n~/ ~ACB 100 136R .<TZB 136R 0.24 160L 0.24 159L 9.00 151L 9.00 598719.48 5957293.79 132L 9.00 598725.97 5957275.97 91L 9.00 598743.48 5957269.28 49L 9.00 598771.59 595?273.89 30L 9.00 598809.62 5957289.69 21L 9.00 598823.18 5957296.76 9.00 · . Anadrill (c)96 Z02AP9 3.0b.03 11,32 AM P) Z-02A (Pg) , 'PROPOSED WELL PROFILE 0'3/20/96 Page '2 STATION MEAS INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH TOP KINGAK .7933 31.09 62.32 TJF 8330 31.09 62.32 TJE 8598 31.09 62.32 TJD 8820 31.09 62.32 TJC 9077 31.09 62.32 TJr "9241 D~. ~/1.o°, 9351, 9400' SAG RIVER (OIL, GA~) :../~9404 SET. TBLIK 9435 9500 PRESENT GOC 9545. EILEEN .. 9548 END DROP 9/100 9586 TARGET' 9586 31.09 31.09 26.7~ 23.5? 17.70 10.00 lO.O0 62.32 62.32 62',32 62,32 62.32 62.32 62.32 62.32 62.32 62.32 VERT-DEPTHS TVD SUB-S 7494 7410 7834 7750 '8064 7980 8254 8170 8474 8390 '8614 8530 8.709' 8625 8751 8667 8755 '..'8671 · .. 8783 8699 8844 8760 888'7 8803 8890..· 8806 8927 8843 8927 8843 SECT DIST -1177 -972 -833 -719 -586 -502 -444 -421 '~419 -406 COORDiNATES-FROM wellhead , 1797.95 S 1702.70 S 1638.26 S 1585.03 S 1523.405 1484.185 .1457.62 S 385,80 W' 204.25 W 81.44 W ,. .20.01. E ' 137.48 E 212;24 ~: '1446.'68 'S' "283'.'71 ",1448.86 ~'s, ,,7288.27' - 1439.8o s '296.81' E" .-383 1429.14 S'." 317.14 E ~371.. 14'23.52 s":.32V,:ss E .-370 1423.18 S 3'28.49 l -363 1419.62 S 335.27 E -363 1419.62 S 335~27 E #mmmmmmmmmmm~mm~mm STATE- PLANE X Y 598824.05 5957297.22 599004.31 5957394.86 599126.24 5957460.90 599226.98 5957515.46 599343.61 5957578.63 TOOL FACE 599417.84.5957618.83 599468.10 5957646.06 LS 599488.80 5957657.27 LS 599490.35 5957658.11 LS 599501.,81 5957664.32 LS 599521.99 5957675.25 LS 599532.63 5957681.01 LS 599533.26 5957681.35 LS 599540.00 5957685.00 599540.00 5957685.00 ~m DL/ 100 0.00 0.00 0.00 0..00 0.00 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 TOP SAD / IVISHAX ., 9586 ZONR 4/4B 9586 ZONE' 4A/X- RAY 9690 TOP HO/T 9722 ORIGINAL OWC 9735 · o. 10.oo ..lo.dO 10.00 10.00 62.32 8927 8843 62.32 8927 8843 62.32 .9'030 8946 62.32 9061 8977 62.32 9074 8990 -363 1419.62 S -363 1419.62 S -345 1411.19 S -339 1408.65 S "337 1407.58 S 335.27 'E 335.27 E 351.36 E 356.20 E 358.23 E 599540.00- 5957685.00 599540.00 5957685.00 599555.97 5957693.65 599560.77 5957696.25 599562.79 5957697.34 9.00 9.00 0.00 0.00 0.00 PRES--~T OWC 9735 10.00 zo~ s 9V89 lO.O8 ZONE 2 / 2C 9845 10. Od 7" CASING PT 9'885 10.0O TD 9885 10.00 62.32 62.32 62.32 62.32 62.32 9074 8990 9127 9043 9182 9098 9222 9138 9222 9138 -337 1407.58 S -327 1403.24 'S -318 1398.73 s -311 1395.48 S -311 1395.48 S 358.23 E 366.50 E 375.09 E 381.29 E 381129 E 599562.79 5957697.34 599571.01 5957701.79 599579.53 5957706.41 599585.69 5957709.75 599585.69 5957709.75 0.00 0.00 0.00 0.00 0.00 (Anadrill (e)9~ Z02AP9 3.'0b.03 ~1,32'AM P) .. ANADRILL AKA-DPC APPROVED I~R 2 O, 1996 INITIAI.="~'.3'lc% ~_ WELL PERMIT CHECKLIST GEOL AREA ~ _ ..~ ~ P~OG~: exp [] dev ~ redrll ~ serv [] ON/OFF SHORE ADMINISTRATION ENGINEERING GEOLOGY 1. erm t fee attached ................... 2. Lease number appropriate ............... 3. Unique well name and number .............. /~ N 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included .......... 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order ..... ~ N 12. Permit can be issued without administrative approval...~ N 13. Can permit be approved before 15-day wait ........ Y~ N N N N N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... ~] N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... ~] N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~)~ N 25. BOPEs adequate ..................... ~) N 26. BOPE press rating adequate; test to ~d~ psig.~) N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N 30. Permit can be issued w/o hydrogen sulfide me~- N 31. Data presented on potential ~s . .... Y N 32. Seismic analys~a_s~ zones ......... Y N 33. Seabed co ' on survey (if off-shore) ......... Y N ~CS~name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ~c ~ ENGINEERING: COMMISSION: Comments/Instructions: AIASK~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 28, 1996 Terry Jordan, Sr. Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit Z-02A BP Exploration (Alaska), Inc. Permit No 96-043 Surf Loc. 976'SNL, 1462'EWL, Sec. 19, T11N, R12E, UM Btmhole Loc. 2868'NSL, 3102'WEL, Sec. 19, T11N, R12E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to re-ddil the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until ali other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed pdor to ddiling a new hole. Notice' may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. avid W. Johnston Chairman -~ BY ORDER OF THE COMMISSION dlf/encl. c: Dept of Fish & Game, Habitat Section -w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill 1-111b. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration Plan RTE = 83.61 f e et Prudhoe Bay FieldYPrudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorac/e. Alaska 99519-6612 ADL 028262 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 976' SNL, 1462' EWL, SEC. 19, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2884' NSL, 3162' WEL, SEC. 19, T11N, R12E Z-O2A 2S100302630-277 At total depth 9. Approximate spud date Amount 2868' NSL, 3102' WEL, SEC. 19, T11N, R12E 03/10/96 $200,000.00 ;12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TV[~) property line ADL 028245 1859 feet No Close Approach feet 2560 9572' MD/9220' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 6ooo feet Maximum hole angle 9o o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth raze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 NSCC 3727' 5845' 5700' 9572' 9220' 285 sx Class 'G' 19. To be completed for Redriil, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~O ~,.tV ED Surface Intermediate ~CL,.8 '~ 6 Production Liner Perforation depth: measured AJas~,a Oil & G~s Cons. Cornmissio~ true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements ['-I 21. I hereby certify that th¢, foregoing is true and correct to the best of my knowledge Signed ,~¢~ I~ Title SeniorDrillin~lEn~lineer Date Commission Use Only Permit Number APl number Approval crate_/ See cover letter · ~ ¢~-¢,,~ 50- 0 z_-'~- ~_/'¢//~ - 42 / r.~._c;~.~/q"~¢' for other requirements Condit~o'n-~ o~-apProval Samples required [] Yes ~ No Mud Icg required []Yes ,]~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required '[~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; []5M; I--IIOM; I-I15M; Other:Approved by David0riginal~W. Signed By Commissioner by order of Johnstorl tne commission Date Form 10-401 Rev. 12-1-85 Submit ir~ [WeH Name: I Z-02A Redrill Plan Summary I Type of Redrill (producer or injector): ] Shut In Producer Surface Location: 976' FNL, 1462' EWL, S19, T11N, R12E, UM Target Location: 2884' FSL, 3162' FEL, S19, T11N, R12E, UM Bottom Hole Location: 2868'FSL, 3102' FEL, S19, TllN, R12E, UM I AFENumber: I Unknown I I Rig: I Nabors 2ES I I Estimated Start Date: [ March 10, 961 I Operating days to complete: 1 25 I IMD: 19572, I ITVD: 19220' I IKB Elv. 183.61 I ] Well Design (conventional, slimhole, etc.): I Horizontal Sidetrack Objective: 1. Distance/Direction from original TSAD to proposed TSAD:~1750' N 2. NLOC at new location: -94 feet 3. COWC at new location' 8995' ss 4. Top Kingak: 7410' TVD ss Thickness of Kingak: 1261' TVT 5. Top Sag River: 8671'TVD ss (along wellbore path) 6. Current well: Azimuth' 201° Hole angle thru perfs 2--3° Proposed well:Azimuth: 125° Hole angle thru perfs: 1_1° 7. Anticipated reservoir benefit: 1,000 MSTB 8. Anticipated rate: Qo - 2,000 BOPDWC - 10% GOR = 1500 scf/stb (1st 6 month avg - assuming successful frac) IOR = 1500 BOPD Mud Program: A 9.8 - 10.20 ppg Biozan polymer / KC1 water based mud will be used. ISpecial design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.8 10 15 5 10 10 0 5 to to to to to to to to to Target 10.2 18 30 15 29 5 0 8 Directional: FEB '1 6 1996 ,qaska Oil & Gas Cons. Commission Anchorage Z-02A Redrill Plan Summary Page 1 I KOP: 1 6000' MD [ Maximum Hole Angle: 1 90° Close Approach Well: none Casing/Tubing Program: Hole Size Csg/ Wt.fFt Grade Conn Length Top Btm Tbg O.D. MD/TVDss MD/TVDss 8.5" 7" liner 29# L-80 NSCC 3727 5845/5700 9572/9220 N/A 4.5" tbg 12.6g L-80 Butt/ 9271 Surface 9271/8927 Mod- Used Cement Calculations: [ Liner Size: [ 7" drilling liner [ Basis:[ 50% open hole excess, from TD up to 6541' ( 500' above the top of Kuparuk I Total Cement VolUme: [ 285[ 90 sks Lead Slurry / 285 sks tail Slurry ( Both class G ) [ 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 mud fluid system schematics on file with AOGCC. Hazards · Sadlerochit pressure is @ 3900 psi at @ 8800' TVDss or EMW of 8.50 ppg Sag River pressure at 8671' TVDss is same as Sadlerochit Pressure. EMW will be 8.64 ppg. Eileen formation pressure at @ 8800' TVDss is same as Sadlerochit Pressure. EMW = 8.5 ppg ~[~.~~V ~D Z-02A Redrill Plan Summary FEB '1 6 ]996 0il & Gas Cons. Commissio~. Page 2 Operations Summary: Pre Rig Work: 1. Complete pre-rig annular communication diagnostics and pack-off test to evaluate the presence or absence of annular communication. Cut tubing at 8900' MD. Kill well. Freeze protect. Rig-Work: 1. Move in drilling rig. 2. Pull BPV. Circulate out freeze protection cap from inner and outer annuli and recover for future use. 3. Install a TWC and test from below to 1000 psi. ND the production tree. 4. N/U BOP's. Test BOP's to 500 / 5000 psi against TVVC. Test annular to 500 /3000 psi. Remove the test plug. , Pull and lay down the 4-1/2" tubing. Number all joints and write well number on each. Inspect for NORM. ( Check the location and depth of the cut on production handover form ) NOTE: It is not clear as to what the running threads are on this hanger thus it is recommended that spear be used ) 6. P/U bridge plug ( EZSV ) and RIH to set it at @ 6245' MD. The tubing was cut at 8900' MD. Stay stung in and P & A well in the following manner: , Establish an injection rate. Bullhead and squeeze perforations at 9600' - 9708' MD Displace to leave the top of cement inside of 7" liner @ no lower than 9500' MD ( 100' above the top of perforations ). Pressure test as per AOGCC requirements. Total volume of cement should be as follows: 13.2 bbls to fill inside of 7" liner from PBTD at 9853' to 9500' MD plus 5 bbls will be squeezed away for the total volume of ~~9'bbls of cement slurry. POOH. P/U Section Mill on 4-1/2" DP & RIH. Displace to milling fluid after spotting 18 ppg pill. Cut section from 5995-6045. POOH after ensuring that the hole is free of metal cuttings. , RIH open ended and spot a kick-off plug from 100' below the base of the section at 6145' MD to 200' above the top of section at 5795' Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve 'a 1000-2000 psi squeeze but do not displace TOC below 100' above section top. Z-02A Redrill Plan Summary ~aska Oil & Gas Cons. Commission Anchorage Page 3 10. 11. 12. 13. Note: 14. 15. 16. Run in with an 8.5" steerable assembly (MWD - directional) and dress the cement to 5' below the section top to 6000' MD. Circulate hole clean. Kickoff and directionally drill to TD at --- 9572' MD. ( Directional plan #8 ) After E-Line logs ( logging program is GR / Res / Sonic ) make a conditioning trip with a 8.5" hole-opener for the open hole section Rabbit the drill string. Run a 7" 29#, L-80, NSCC liner with 9-5/8 x 7" packer / hanger to bottom in the 8.5" hole and space out for about 150' of lap. Refer to Standard Recommended practices for liner running procedure. Reciprocrate liner 20- 30' during circulation and cementaiton. Cement the liner in place with the total cement volume based upon 50% open-hole enlargement plus the 80' shoe volume, with top of cement up to 6541'. ( 90 sks Lead / 195 sks Tail ) Set liner hanger / packer with 4200 psi. Reverse out clean. P/U 6" clean out bit on 4.5 DP. RIH and clean out 7" liner to landing collar. Circulate hole clean. Pressure test the liner lap to 3500 psi for 10 min. Displace the hole with filtered seawater with corrosion inhibitor. Test liner lap/casing to 3500 psi for 30 minutes. POOH. Refer to Standard Completion Running Procedure as well as Proposed completion diagram for more details. Run the 4-1/2", L-80, Butt-Mod ( USED ) completion assembly spaced out to place end of tail pipe above the TSAD. ( TT tb be spaced out @ 9271' MD ) Tubing detail as follows: ( Refer to Proposed Completion Diagram for more details ) · 4 · 4 · 4 · 4 · 4 · 4 · 4 · 4 · 4 · 4 · 4 1/2" WLEG 1/2", 12.6#, 1/2", 12.6#, 1/2", 12.6#, 1/2", 12.6#, 1/2", 12.6#, L-80, Butt-Mod 10 ft pup joint Otis "XN" Nipple (3.725" ID) L-80, Butt-Mod 10 ft pup joint Otis "X" Nipple (3.813" ID) L-80 Butt-Mod full joint 1/2", 1 1/2" X 1/2", 1 1/2", 1 1/2", 41/2", GLM's 41/2", 2.6#, L-80 Butt-Mod 10 ft pup joint 7" Packer 2.6#, L-80 Butt-Mod 10 ft pup joint 2.6#, L-80 Butt-Mod tubing joint 12.6#, Otis "X" Nipple (3.813" ID) 12.6#, L-80 Butt-Mod tubing with GLM's Depths to be determined later. L-80 Tubing Retrievable SSSV @ 2,200' MD 4 1/2", 12.6#, L-80 Butt-Mod tubing to surface 4 1/2" tubing hanger Space out, test the SSSV and land hanger. Install a TWC, and test to 1000 psi. Remove BOP's. FEB 1 6 1~96 /~aska Oil & Gas Cons, Ooramissio~. Anchorage Z-02A Redrill Plan Summary Page 4 17. Install and test the production tree to 5000 psi. Pull the TWC valve. 18. Drop ball and set the packer. Test tubing to 4000 psi and hold for 30 minutes. While holding the 1500 psi on the tubing, pressure test the annulus to 3500 psi for 30 minutes. First bleed off the annulus, then the tubing to 0 psi. 19. Shear the RP on the upper GLM with 2900 psi annulus pressure. Bleed off pressure and freeze protect with diesel to 2200' MD. 20. Set a BPV. Close the SSSV and secure the well. Release rig. 21. Complete appropriate documentation and hand-over to Production. Note: If there are any questions regarding this permit please feel free to call Zeljko Runje at 564- 4825 ( Office ) or 275-4281 ( digital beeper ) FEB 1 6 1996 o~ & Cas Cons. Cornrni,sion ~qch,.or~ge Z-02A Redrill Plan Summary Page 5 J6 1 6: 33 Anadr~,i i 1 DPC t~ 344 2 160 P. · ",. ' _ '" E'R~'I.iCE ' ... ..... ,. i _ I .. SHAR'ED S . __S D~IILLIN'G '). i i m i i mi I i mi I II , mm <,,> o - " Z-O2A (P8) V[RTICAL SECTION VIEW mmm i I m 6DO ................ , Section at: ~04.73 ~ TVD Scale.' ~ ~nch = t200 feet ~oo-- i ....... I Dep Scale.' ~ inch = ~200' feet Drawn' '02/02/96 1800 ........ , ............... :_ ,4nadrY]] Sch]umbenger 2400 ..... Marker Identification HO BKB SECTN INCLN A) TIE-IN SURVEY 5992 5723 40 25.BPt' I .B) TOP OF. WINDOW 5995 5726 40 25,69- C) KOP CURVE ~0/~00 '6000 5730 40 25.59 3000 .................. O) END ~0/~00 CURVE 6276 5995 75 ]1.B3 'u~A''3'sLq ..... E) TARGET-J50 FT RADIUS -g27~ 8927 6B5 ~.B3 B F) 7" LINER POINT 9572 9220 747 l~.B3 K 3600=- ' G) ID 9572 9220 747 ~1.83 4200-~_-+ ....... I ,~oo-- i - , , '~3' -scar ..... " ~ANADRILL AKA-DI°C, ,,-- ........ 5400'~ ---~-~-Ii .......... - -,~,--,~-... ;_. ] -' B400~ ~' l~r! ._ - ..... - .... 'r~:' ~')4' ' ' ' ~ .... '" ' ..... ' ' - ',~' ~,r~,,,~., ............... :=..:. '~,~ ----- ~ooo- ~: _-'~:- .................... " . 7ZSSZ~.'-.''"-~ '~-''._, ,-:,_-i' ).' _ _' _. ' .... ~'~i~ ..... "G~:::::::::,:::::: '::::: :'- o F , F E 9600-- I i i ,~ :hora9e 10200 ........ I tOBO0 } -t200 -600 0 600 $200 ia00 2400 3000 3600 4~00 ,4800 5400 6000 6600 7200 Section Departure (~'i]~ (c)~ ZO2APO 2.50.03 3:17 P~ P) 16:34 Anadrill DPC 90~_344 2160 P., I · SHARED SERVICES Harker Identification MD A) TIE-IN SURVEY 5992 8) TOP OF WINDDW 5995 C) KOP CURVE JO/tO0 6000 D) END 10/~00 CURVE 6276 E) TARGET-t50 FT RADIUS -9271 F) 7' LINER POINT 9572 G) TD ~ "9572 N/S 1~93 273 ~195 273 ~197 273 ~263 259 ~420 335 ~435 395 ~435 395 'DRILLING · i · Z-O2A (P8) PLAN VIEW CLOSURE ..... : 1489 feet at Azimuth 164.62 DECLINATION.: +28.~74 (E) SCALE .......: ! inch = 500 feet DRAWN .......: 02/02/96 ~nadr~ 1] Sch]umberger m im (A~Or~11 (c)96 ZO2AP8 2.50.03 3:19 ~ PJ $250 ~000 750 500 250 0 250 500 750 J000 1250 1500 1750 <- WEST · EAST -> m · Anadrill Schlumberger .Alaska District 1111 East 80th Avenue Anchorage, AK 99518 · (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : Z-02A (PS) Field ........ : PRUDHOE BAY, Z-PAD Computation..: Minimum CurvatUre Units ........ : FEET Surface Lat..: 70.29769941 N Surface Lon~.: 149.19677558 W LOCATIONS .- ALASKA Zone: 4 X-Coord Y-Coord Legal Description Surface ...... : 4303 FSL 3492 FEL S19 T11N'R12E,UM' 599186.05 5959099.95 Tie-in/KOP...: 3110 FSL 3769 FEL S19 TllN R12E DM 598929.18 5957903.24 TARGET ....... : 2884 FSL 3162 FEL S19 TllN R12E UM 599540.00 5957685.00 BHL .......... : 2868 FSL 3102 FEL S19 TllN R12E UM 599599.73 5957670.14 Prepared ...... : 02/02/96 Vert sect az.: 104.73 KB elevation.: 83.61 ft Magnetic Dcln: +28.174 (E) Scale Factor.: 0.99991118 Convergence..: +0.75620690 ANADRILL AKA-DPC APPRO /ED, FEB 0 Z 1996 PROPOSED WELL PROFILE INITIAL STATION IDENTIFICATION TIE-IN SURVEY TOP OF WINDOW K0P CURVE 10/100 END 10/100 CUaVE HRZ KUPARUK LCU TOP OF KINGAK MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTH ANGLE AZIMUTH TVD SUB-S DIST 5992 25.62 5995 25.61 6000 25.59 6100 17.16 6200 11.47 6276 11.83 6806 11.83 7041 11.83 7082 11.83 7807 11.83 COORDINATES-FROM STATE-PLANE TOOL DL/ WELLHEAD X Y FACE 100 192.57 5723 5639 40 1193.32 S 272.66 W 598929.18 5957903.24 162R <TIE 192.58 5726 5642 40 1194.65 S 272.96 W 598928.90 5957901.91 162R, 0.42 192.59 5730 5647 40 1196.76 S 273.43 W 598928.46 5957899.79 154L 0.42 177.51 5823 5740 45 1232.66 S 277.51 W 598924.86 5957863.84 140L 10.00 143.10 5920 5837 57 1255.41 S 270.88 W 598931.78 5957841.19 106L 10.00 TJF 8155 11.83 104.73 5995 5911 104.73' 6514 6430 104.73 6744 6660 104.73 6784 6700 104.73 7494 7410 104.73 7834 7750 71 1263.46 S 258.76 W 598944.01 5957833.30 180 1291.08 S 153.69 W 599049.43 5957807.07 228 1303.34 S 107.08 W 599096.19 5957795.43 236 1305.47 S 98.98 W 599104.32 5957793.41 385 1343.29 S 44.90 E 599248.67 5957757.49 456 1361.40 S 113.79 E 599317.79 5957740.29 10.00 0.00 0.00 0.00 0.00 0.00 0 o (;u:adrill (c) 96 Z02AP8 2.5b.04 3:17 PM P) 02/02/96 Page 2 PROPOSED WELL PROFILE STATION MEAS ,INCLN DIRECTION VERTiDEPTHS SECT COORDINATES-FROM STATE-PLANE . · . IDENTIFICATION DEPTH ANGLE AZIMUTH .TVD SUB-8 DIST WELLHEAD' ' X ¥ ,. 504 1373.65 S 544 1383.77 S 590 1395.49 S 620 1402.95 S 649,' 1410.46 S 655 1411.95 S 677 1417'.49 S '677 1417.65 S 685 1419.62 S 685 . 1419.62 S 160~40 E 599364.55 5957728.66 198.90 E 599403.18 5957719.04 243.48 E 599447 90 5957~07.92 271.85 E 599476.37 5957700.83 300.42 E '599505.03 5957693.70 , . 306.10 E 5.99510.72 '5957692.28 327.17 E 599531.87 5957687.02 327.?8 E' ,599532.48 5957686.87 335~27,.E .'599540.00 5957685.00 335.27 E ' 599540.00 5957685.00 TJE 8390 11.83 .104.73 8064 7980 TJD 8584 11.83 104.73 8254 8170 TJC 8809 11.83 104.73 8474 8390 TJB 8952 11.83 104.73 8614 8530 TOP SAG RIVER 9096 11.83 104.73 8755 8671 SHUBLIK 9124 11.83 104.73 8783 8699 PGOC 9231 11.83 104.73 8887 8803, EILEEN 9234 11.83 104.73 8890 8806 TARGET-150 FT RADIUS 9271 11.83 104.73 8927 8843 TSAD/IVISHAK / 4/4B 9271 11.83 104.73 8927 8843 TOOL FACE 100 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TOP ZONE 4A/X-RAY 9377 11.83 104.73 9030 8946 707 TOP HOT 9408 11.83 104.73 9061 8977 713 POWC / OOWC 9422 11.83 104.73 9074 8990 716 TOP ZONE 3 9476 11.83 104.73 9127 9043' 727 TOP ZONE 2/2C 9532 11.83 104.73 ' 9182 9098 739 1425.11 S 356.15 E 599560.94 5957679.79 1426.76 S 362.43 E ,$99567.24 5957678.22 1427~45 S 365.06 E 599569.89 5957677.56 1430.28 S 375~80 E 599580.66 5957674.88 1433.21 S 386.95 E 399591.84 5957672.10 0.00 0.00 0.00 0. O0~ 0.00 7" LINER POINT 9572 11.83 104.73 9220 9137 747 TD 9572 11.83 104.73 9220 9137 '747 1435.28 S 1435.28 S 394.81 E 599599.73 5957670.14 394.81 E 599599.73 5957670.14 0.00 0.00 (Anadrill (c)96 Z02AP8 2.5b.04 3:17 PM P) ANADRILL AKA-DPC APPRv; '.' FEB 0 g 1-398 !NITu~. ~_.~_.. ...... eared rvlces ,rilling BP Exploration/Arco To: Alaska Oil & Gas Conservation Commission Date: March 1, 1996 From: Subject: Terrie Hubble Technical Assistant Permit #96-043, Z-02A This memo is to inform you that Z-02A, which was originally scheduled to be drilled by Nabors 2ES, will now be drilled by Nabors 18E. No other changes are being made to the program at this time. /tlh I',,4AR 0 1 1996 Alaska. Oil & Gas Cons. Commission Anchora~le WELL PERMIT CHECKLIST dev~ PROGRAM: exp [] redrll~ serv ADMINISTRATION ;D~TE ; 1. Permit fee attached .................. <Y~ N 2. Lease number appropriate ............... '2 N~ 3. Uniquewellnameandn~tmber .............. i~~ 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included ........ ~ Y_~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval. .~ N 13. Can permit be approved before 15-day wait ....... N ENGINEERING REMARKS 14. Conductor string provided ................ Y N ~ f~_ 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N ~ 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... ~ N ~ 24. i ~u~q 2c m ~ ulp'lls~ ~d~q~a~e'. 25. BOPEs adequate ............. ~ ....... ~/ N 26. BOPE press rating adequate; test to 5~ psig.~ N ^~ 27. Choke manifold complies w/API RP-53 (May 84) ...... .-~-~N-'~[~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ '~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N /_ 31. Data presented on potential overpressure zones ..... Y N/ 32. Seismic analysis of shallow gas zones .......... ~///~ ~~/~o g3. Seabed condition surve7 (~f off-shore) ......... ~/ N 34. Contact name/phone for weekly progress reports .... ~Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~/ JDN Comments/Instructions: HOW/lib - A:%FORMS\cheklist rev 11/95 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, informati;:)n 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. Z - 02A PRUDHOE 9200 Run 1' 15 - April - 1996 DIFL/DAC/CN/GR 9808 MAY 2 1 1996 WESTERN ATLAS Cons. Oo~n~ior~ o _ .~o,o,,.~, L~gg~ng Services · ape Subfile 2 fs ty~e: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6654.00 R. ECK B. DAWSON REMARKS: Z-02A 500292181401 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 29-APR-96 OPEN HOLE RUN 2 RUN 3 19 liN 12E 4303 3818 85.76 84.26 53.94 CAS ING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7284.0 8.500 9885.0 DIFL/DAC/CN/GR. STOPPED CIRCULATION AT 1500 HRS, 14-APR-96. CASING DEPTH WAS FOUND AT 7278 FT. WHILE PULLING OUT OF HOLE. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR AN 8.5" BOREHOLE. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, BOREHOLE CORRECTION = 8.50", CASING CORRECTIONS OFF, SALINITY = 0.0 PPM. FILE HEADER FILE NI/MBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9200 . 0 9746 . 0 DAS 9200 . 0 9760 . 0 DIL 9200.0 9808 . 0 2446 9200 . 0 9752 . 0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LL8 ILD DT NPHI 9229.0 9229.0 9229.5 9230.0 9232.5 9232.5 9277.0 9277.5 9280.0 9280.5 9280.5 9289.5 9289 . 0 9289 . 0 9289 . 5 9294.5 9295.5 9309.5 9309.0 9318.0 9316.5 9321.5 9321.0 9342.5 9342.5 9346.0 9345 . 5 9345.5 9346 . 5 9346 . 0 9349.0 9348.5 9349.5 9349.5 9354.5 9355.0 9354 . 5 9354 . 0 9355.0 9354.5 9363 . 5 9363 . 5 9363 . 5 9363 . 0 9366.5 9366.0 9372.5 9372.5 9374.0 9374.5 9374.5 9378 . 5 9378 . 0 9378 . 0 9379 . 0 9378 . 5 9383.0 9383.0 9385.5 9385.5 9388.5 9388.5 9389.0 9388.5 9390.5 9390.5 9391.5 9391.5 9391.5 9394.0 9394.5 9395.0 9394.5 9401.0 9401.0 9404.5 9405.5 9405.5 9406.0 9406.0 9406.5 9406.5 9413.0 9413.5 9424.5 9425.0 9425.5 9425.0 9428.5 9428.5 9431.0 9431.0 9437.5 9438.0 9438.0 9438.5 9439.0 all runs merged; no case 9449.0 94 54.0 9454.5 9465.5 9466.0 9467.0 9468.0 9475.5 9479.0 9484.0 9490.0 9493.0 9493.5 9496.5 9501.0 9507.0 9508.5 9522.0 9528.0 9532.0 9538.0 9541.0 9545.0 9562.0 9573.5 9574.0 9578.0 9597.0 9597.5 9605.0 9607.0 9609.5 9610.0 9613.0 9614.0 9620.0 9620.5 9625.0 9631.0 9631.5 9643.0 9646.0 9646.5 9648.0 9651.5 9656.5 9661.0 9670.0 9675.5 9681.0 9692.5 9694.0 9705.0 9708.0 9710.5 9723.0 9724.0 9736.0 9742.0 $ 9455.0 9466.5 9476.0 9479.0 9483.5 9490 · 0 94 94.0 9497.0 9508.5 9522.0 9531.5 9538.0 9541.0 9544.5 9573.0 9577.5 9612.5 9619.5 9625.5 9647.0 9661.5 9692.0 9694.0 9710.0 9455.0 9466.5 9476.0 9479.0 9483.5 9490.0 9494.0 9497.0 9508.5 9522.0 9531.5 9538.0 9541.0 9544.5 9573.0 9577.5 9597.5 9605.5 9614.5 9620.5 9625.5 9647.0 9661.5 9692.0 9694.0 9710.0 9722.5 9741.5 9450.0 9455.0 9465.0 9467.5 9478.5 9494.0 9497.0 9528.0 9531.5 9541.0 9562.0 9574.0 9577.5 9597.0 9604.5 9607.5 9609.0 9631.5 9642.0 9647.0 9660.0 9670.0 9704.5 9707.5 9454.0 9468.5 9479.0 9493.5 9496.5 9501.5 9507.0 9531.5 9544.5 9574.0 9578.0 9610.5 9631.0 9645.5 9650.5 9655.0 9676.0 9682.0 9694.5 9723.5 9736.5 E6 :sp~oDaE ~ IW~O~ 996 (0 #MdA~) (I~{ODMM ~~ ~ 9S 66 S66 LP P 66 §66 LP P 66 g66 AP P 66 ~66 80 ~ 66 ~66 80 P 66 ~66 80 P 66 S66 80 9 66 966 80 f 66 966 80 P 66 966 80 P 66 ~66 6S P 66 g66 6~ P 9I 0£~ 6S P I0 0I£ 6~ P SdD I S-~d P AX I P NI I P ~I4HO I P ~0 I P P~HO I P ~E{O I ~ Id~fD I 89 9PPg IDFIN 89 9PPg IDeM 89 9PPE IHdN 89 ~IG dS 0I 89 ~I~ IG 6 89 %IQ £M 8 89 ~IQ ~qI t 89 ~I~ 8~q 89 S%f~ GNmA 89 S~f~ i~ 89 S~Q HD pox SlO d/~ dA& qqBuaq aZlS Id~f Id~ Id~f Id~f sqTu~ saIdm~S ~poo IOOl amen :saAmnD fi ~ :GI qqdop ~H~ H.~d HAd.~G ~/~O (99 #~dAi) GHODMH Ikrk~o~ ~ Hd07S H.I.HON : N/IOD A~f~ HOHfLrlHd : ~fg0-Z : NM NOI.f.krHoqdxH ~ : ND &no- pHOm~a z / &nO' £HO.I.~4Z & / &nO' gHO.~,~6 & / J/10' IHO,T,%f~6 & / 0'ESL6 0'8086 0'09L6 0'9PL6 MSiM MDHM~ 0'00E6 S I 0'00E6 S 0'00E6 S I 0'00~6 S I dOi MDHMN 'ON SS~d 'ON N/IM S~ Tape File Start Depth = 9844.000000 Tape File End Depth = 9111.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 22006 datums Tape Subfile: 2 292 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RI/NNIIMBER: 1 TOOL STRING NIIMBER: 1 PASS NIIMBER: DEPTH INCREMENT: FILE SUMMARY 5 .2500 VENDOR TOOL CODE START DEPTH GR 9200.0 DAC 9200.0 DIFL 9200.0 2446 9200.0 $ 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 9778.0 9793.0 9820.0 9785.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP COMR GR CN KNJT KNJT DAC SLAM DIFL $ CABLEHEAD TEMPERATURE COMMON REMOTE GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT DIGITAL ACOUSTILOG SLAM ADAPTER 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) : 15-APR-96 ECLIPS 2.1 1500 14-APR-96 0 9885.0 9810.0 9200.0 9808.0 1800.0 TOOL NI3MBER CABL338 3981XA 3510XA 1329XA 2446XA 3923XA 3923XA 1667EA/1680MA 3516XA 1503XA 8.500 7284.0 7278.0 LSND-HT 10.20 50.0 9.0 4.8 200.0 RESISTIVIT~Y (Ot~) 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: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : Z-02A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA .740 .260 .910 .000 1.540 .000 THERMAL SANDSTONE .00 8.500 1.5 70.0 200.0 71.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DAC 68 1 GAPI 4 2 DT24 DAC 68 1 US/F 4 3 CHT DAC 68 1 LB 4 4 TTEN DAC 68 1 LB 4 5 TEN DAC 68 1 LB 4 6 SPD DAC 68 1 F/MN 4 7 RFOC DIFL 68 1 OHMM 4 8 RILM DIFL 68 1 OHMM 4 9 RILD DIFL 68 1 OHMM 4 10 RT DIFL 68 1 OHMM 4 11 DI DIFL 68 1 IN 4 12 SP DIFL 68 1 MV 4 13 WTBH DIFL 68 1 DEGF 4 14 CNC 2446 68 1 PU-S 4 15 CNCF 2446 68 1 PU-S 4 16 CN 2446 68 1 PU-L 4 17 LSN 2446 68 1 CPS 4 18 SSN 2446 68 1 CPS 4 4 56 310 01 1 4 56 520 99 1 4 56 635 99 1 4 56 635 99 1 4 56 635 99 1 4 56 636 99 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 890 01 1 4 47 334 31 1 4 47 334 30 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data RecOrds: 226 Tape File Start Depth = 9844.000000 Tape File End Depth = 9111.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55728 datums Tape Subfile: 3 306 records... Minimum record length: Maximum record length: 62 bytes 994 bytes O'OL O~L ' 0'00~ 8'~ 0'6 0'0S 0E'0I J.H- CLMS~I O'8L[L 0 ' 00S'8 : (J.~) H.T.d,wG ONIStO S : (,T.4) HJ.d,~G ONISIfD S : (NI),~ZIS J.I~ .q~IOH tgT,tfG ONISIfD C[NIf ~I.~ICI k~IS J~ON~ ND ~HD (NOJ,J,O~ O,T, dO.t) ONI%Id]S ~IOO,T, 0'008I 0'8086 0'00E6 0'0186 0'S886 0 96-~d~-9I 00SI I'E SdI~O~ 96-~d~-SI : (%tHd.~) G.~.qdS DMI~DO~I : (J..4) ~l~fAH.qJ~NI DO~I ~40J. J.O~t : (J,M) q~AM.~J2~II 00~I : (.t,~) M.~ODO~I : (J.~) %t.~I~II%{(I : ~OJ,J,08 NO %t,~DDO~I : ~.~flN,q NOIJ,I~iflD%IID :NOIS%{~A : GMDDO~I %fJ.~f(/ %{M~H DO~I 0' 9PA6 0' 00E6 91~Pg 0' I086 0 ' 99E6 rl,4IG 0' 9SL6 S' 8IE6 0 ' 0PA6 0' 00E6 H,td,W~ dOJ. S HJ.d.W~ J.h~fJ.S ~GOD ~lO0.t %{OflN~tA OOSE' L I I :M~W/1N SS~fd :HMMWIlbl DNIM~S ~00~ 'S~IT~ ~wx~das uT unx pu~ 'BuT~s IOO~ 'ss~d qo~ xo~ w~wp x~pwaq 6oI pu~ S~A~nO S~SS~fd ~%f~d~ ~OH N~dO M~ £ :M~LQ/q MqI~ SIq :~clK~ s! ~ ~iT~qns ~dwl MUD AT ~BOTT~M HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : Z-02A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT ~ ALASKA .260 .910 .000 1.540 .000 THERMAL SANDSTONE .00 8.500 1.5 200.0 71.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Lo9 Crv Crv Size Length Typ Typ Cls Mod 1 GR DAC 68 1 GAPI 2 DT24 DAC 68 1 US/F 3 CHT DAC 68 1 LB 4 TTEN DAC 68 1 LB 5 TEN DAC 68 1 LB 6 SPD DAC 68 1 F/MN 7 RFOC DIFL 68 1 0H594 8 RILM DIFL 68 1 OHMM 9 RILD DIFL 68 1 OHMM 10 RT DIFL 68 1 OHMM 11 DI DIFL 68 1 IN 12 SP DIFL 68 1 MV 13 WTBH DIFL 68 1 DEGF 14 CNC 2446 68 1 PU-S 15 CNCF 2446 68 1 PU-S 16 CN 2446 68 1 PU-L 17 LSN 2446 68 1 CPS 18 SSN 2446 68 1 CPS 4 4 56 310 01 1 4 4 56 520 99 1 4 4 56 635 99 1 4 4 56 635 99 1 4 4 56 635 99 1 4 4 56 636 99 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 995 99 1 4 4 47 995 99 1 4 4 47 995 99 1 4 4 47 890 01 1 4 4 47 334 31 1 4 4 47 334 30 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 197 Tape File Start Depth = 9806.000000 Tape File End Depth = 9166.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70666 datums Tape Subfile: 4 275 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS 96/ 4/29 01 **** REEL TRAILER **** 96/ 4/30 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 30 APR 96 7:58a Elapsed execution time = 3.74 seconds. SYSTEM RETURN CODE = 0