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177-007
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-12 PRUDHOE BAY UNIT 09-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 09-12 50-029-20239-00-00 177-007-0 W SPT 8265 1770070 2066 1895 1888 1887 1888 382 574 550 551 4YRTST P Guy Cook 4/13/2025 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-12 Inspection Date: Tubing OA Packer Depth 60 2708 2653 2644IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250412191300 BBL Pumped:6.5 BBL Returned:6.5 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 11:46:52 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Src: Inspector Reviewed By: P.I. Supry �jv2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-12 API Well Number 50-029-20239-00-00 Inspector Name: Bob Noble DATE: Monday, April 26, 2021 TO:Jim Regg P.I. Supervisor �[ �I /ern„ , SUBJECT: Mechanical Integrity Tests HJcorp North Slope, LLC 09-12 FROM: Bob Noble PRUDHOE BAY UNIT 09-12 Petroleum Inspector Well Src: Inspector Reviewed By: P.I. Supry �jv2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-12 API Well Number 50-029-20239-00-00 Inspector Name: Bob Noble Permit Number: 177-007-0 Inspection Date: 4/17/2021 IBsp Num: mitRCN210420095144 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-12 Type Inj ATVD 8265. Tubing 1662 1664 - 1665- 1669 - PTD 1770070'Type Test ser"Test psi 2066 - IA 663 2506 - 2463 - 2455 - BBL Pumped: 4.4 BBL Returned: 4.3- OA 444 582 569 _ 581 . Interval 4YRTS7 P/F P Notes: Monday, April 26, 2021 Page 1 of 1 0 MEMORANDUM TO: Jim Regg , eljj 5111 � i7 P.I. Supervisor l FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL Tate of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 03, 2017 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 09-12 PRUDHOE BAY UNIT 09-12 Src: Inspector Reviewed By: P.I. Supry Jl�— Comm Well Name PRUDHOE BAY UNIT 09-12 API Well Number 50-029-20239-00-00 Inspector Name: Bob Noble Permit Number: 177-007-0 Inspection Date: 4/30/2017 Insp Num: mitRCN170430134824 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-12 Type Inj W /TVD 8265 Tubing 1319 1321 - 1317 1317 ' PTD 1770070 ' Type Test SPT Test psi 2066 IA 43 2500 2486 - 2484 ' BBL Pumped: 5.6 - BBL Returned: 5.4 QA 19 32 35 41 Interval 4YRTST — P/F P Notes: scom Nov 2'i Wednesday, May 03, 2017 Page 1 of I ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other:Set Patch Ed 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 177-007 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20239-00-00 7. Property Designation(Lease Number): ADL 0028345 8. Well Name and Number: PRUDHOE BAY UNIT 09-12 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 12800 feet Plugs measured feet true vertical 9188 feet JunkAPR 1 2 2017 measured feet Effective Depth: measured 11371 feet Packer measured See Attachment feet true vertical 8188 feet Packer true vertical See Attachment feet A GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 35-115 35-115 1530 520 Surface 2678 13-3/8"72#MN-80 33-2711 33-2711 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment 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) 12.Stimulation or cement squeeze summary: Intervals treated(measured): /y Treatment descriptions including volumes used and final pressure: SCANNED MA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 5390 187 1782 Subsequent to operation: Shut-In 17 0 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service 1171 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 ❑ WINJ ® WAG 0 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: 317-089 Contact Catron,Garry R(Wipro) . Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 4/12/17 Form 10-404 Revised 5/2015 vrt S—j/o//V---j o4/R B D M S ` ,,,s APR 1 2 2017 Submit Original Only • • Packers and SSV's Attachment PRUDHOE BAY UNIT 09-12 SW Name Type MD TVD Depscription 09-12 TBG PACKER 11356.08 8179.38 5-1/2" Baker S-3 Packer 09-12 TBG PACKER 11509.88 8270.52 5-1/2" Baker SAB Packer 09-12 PACKER 12357 8853.95 4-1/2" NS Pack-Off Packer 09-12 PACKER 12406.28 8890.42 4-1/2" D&D Liner Top Packer 09-12 TBG PACKER 12420.6 8901.05 5-1/2" Baker FB-1 Packer 09-12 TBG PACKER 12583.49 9023.23 5-1/2" Baker FB-1 Packer • • m 0.az) CO co CO ON CA O M CO O co �6 CO O N- O O V N N CC) Lo VN V r Cn O (D N Or ilaa O O O o o o O O o o 7 co co M - CO v- co • N N- N. v N--- alr CO CO CO C0NN- N. 000 Lo r CO CO C7) N v CO O CO CO N-- r N 0 CO CO (A O CO CO O N N--- CL) O r CO CO N CO (D O N N CO CO C3) CO CO CO CO CA CI i i H CO Cfl N O CO Cfl M r N O N- LO CO Co CO CO O CO CO CO CC) C70 CV M N co C7) N CO CO CO CO CO co C N C • r N- CL) N CV r N- LC) O N I LO ErN N CY) CA r c) LO CO CO CO`- f_ C!') 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N0 ; m Q N v OJNN (NI O > W J22 >+ a Z cN- N I- in -0 (o 0 ; • 0 I i- §¢ 00 & 3 / / 0 2 2 ® r I CO I- / - / 6 z E � p- ^� o (6 i % m / ��= co \ % / �L /y 0 R 2 _ % O Cl) = 2 = ® 2 ± a 2 % \ G _1 co 02 cd) § ƒ o c / >@Z / (N° 11 - \ / \ II v- w , 0 ''t 2 & ± O L Q I -% 0z ; p / f _I < <- / 0 E tW � $ Oo) 0 O- R / o O _ƒ co e » u_ = I- 0.. aco_ co LL E \ / < IX a c � ° I E � W ? / / / \ \ / / b '® 11 H H a 0 < z Z a 2 0< Z < < ±arlL 0 mIE ± E % 0R � a / Et / E < » ° / ct \ ƒ LL z < 4Eu Eu ± 2� < _& 2L Z 0) ;.--• °- O 5 � / / D < \ < ui / $ Y - wEO \ � w2 ± / $ .9 « f m 0 Z m 7-m 2 0 m t 2 O 4 r- (7) CV mwr a) a \ TREE` C11N 4 -- WELLHEAD= FMC SAFETY NOTES: ""PWI ONLY-NO MI INJECTION ACTUATOR= BAKER C 1 2 ALLOWED"" OKB-E..EV= 54' BF.E_EV= I KOP= 2969 I 2100' H5-1/7 FES X NP,D=4.562" Max Angle= 63°@ 10212 20"CONDUCTOR — 111' Datum MD= 12357" 94#,µ44O Datum TVD- 8800'SS D=19.124" I 11325' -5-1/2"I-ES X NP,D=4.562" _ z [ 11346' I—9-5/8"X 5-1/2"BKR S-3 PKR,D=4.760" J 13-3/8"CSG,72#,MN-80 BTRS,D=12.347" --t 2708' I 11371' 1-15-1/2"HES X NP,ID=4.562" i 5-1/2"TBG,17#,L-80 TCI,.0232 bpf,D=4.892^ 11432" P . 11447' —1 9-5/8"X 5-112"UNIQUE OVERSHOT 5-1/2"TBG STUB(03/06/09) — 11440' I 111 11472' —15-1/2"BKR FSR ASSY,ID=4.750' Oi 11500' H9-5/8"X 5-1/2"BKR SAB PKR,D=4.750" Minimum ID =2.350" @ 12382' K,. (25' INSIDE NS STRADDLE PATCH) 11506' —{7"MLLOtJTEXiBNSICIN ID=6.00" 11612' —7"X5-1/2"XO,D=4.85" 5-1/2'TBG-PC, 17#,L-80 AB-M 8RD, — 11675' .0232 bpf,D=4.892' 11634' I-15-1/2"OTIS X NF D=4.562^ l [TOP OF 7"LNR J-1_ 11821' I2 NI 11675' —15-1/7"X 4-1/2"XO,D =3.958" J 12357'-12411' -12-7/8'NS STRADDLE PATCH, � 9-5/8"CSG,47#,N-80/S0095,ID=8.681" H 12129' D=2.35"(03/19/17) r:.'' 12406' J-14-1/2"AVA BPL NP D=3.759" I 1 CI ' 12411' I--H7"X4-1/2"BKR FB-1 PKR,ID=4.00' I 4-1/2"TBG, 12.6# L-80,.0152 bpf,D=3.958" .J—{ 12411' i 2cl. w/SNAP LATCH SEAL ASSY,ID=3.00" 11 12415' H5-1/7 MLLOUT EXTENSION,ID=4.50" PERF ORATION SUMMARY - I 12420' H5-1/2"X 3-1/2"XO,D=2.992" REF LOG:BHCS ON 06/02/77 , ANGLE AT TOP FERE:42°@ 12424' ' [ 12664' ,--{3-1/2'AVA BR.NP D=2.697" I Note:Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sqz SNOT SQZ ALI I 12664' I—I2 812"AVA BPC SLV ID=2 375"(03119/17) J 2-1/8" 4 12378- 12408 C 06/04/84 I , 12574' --7'X3-1/2'BKR FB-1 PKR,ID 4.00' 3-1/8" 4 12424-12457 0 09/07/77 ` w/SNAP LATCH SEAL ASSY ID 3.00 3-1/8" 4 12472-12479 0 09/07/77 Ml ►�� 3-1/8" 4 12491- 12498 0 09/07/77 12578' -15-1/2"MLLOUT EXTENSION,ID=4.50" 3-1/8" 4 12513- 12532 0 09/07/77 3-1/8" 4 12554-12570 0 09/07/77 12580' -5-1/2"X 3112"X0,D=2.992" 3-1/8" 4 12587- 12602 0 09/07/77 3-1/8" 4 12600-12620 0 04/07/95 12583' H3-1/2"CAMCX)DS NP,D=2.562" 3-1/8" 4 12612-12617 0 09/07/77 3-1/8" 4 12628-12645 0 09/07/77 12586' I-13-1/2"BKR SHEAROUT SUB I 12587' H3-1/2"WLEG,D=2.992" - I 3-112"TBG-PC,9.2# 3-55_0087 bpf,D=2.992" H 12687' f ' 12586' —ELMTT LOGGED 5/3/95 FBTD —{ 12706'j (7 L .29#,N•80/SOO-95,.0371 bpf,D=6.184' — 12790' ����������������� 11) - 12800' �tt....l.1... DATE REV BY CDM1ENTS DATE REV BY COMMENTS PRUDHOE BAY IHT 06/11/77 1ROWAN 34 ORIGINAL COMPLETION 02/01/17 DG/JMD FULL AVA BF-VBFC-SET AVA BR WELL: 09-12 10/24/86 WW1 RWI 03/20/17 GJB/JMD RESET AVA BR w/BPC&STRDL PATC PERMIT No: 1770070 03/09/09 N4ES RWO AR No: 50-029-20239-00 12/16/11 WEC'/PJC SET BFC&BR SLV'S(11/27!11) SEC 7, TION,R16E, 1346'FSL&75'FWL 02/20/14 JG/JMD SET PX PLUG(02/17/14) ' 03/14/14 RKT/JMD PULLED PX PLUG(03/11/14) — BP Exploration(Alaska) or 77,1� THE STATE I%/ � Alaska Oil and Gas �,�►."`S-���a O f�T AsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r,. (4' Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner FS2 Lead PE SCANNED MAR 2 0 2017, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU 09-12 Permit to Drill Number: 177-007 Sundry Number: 317-089 Dear Mr. Stechauner: 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, Cathy P Foerster Chair DATED this day of February, 2017. MINTS t ^ ? - , 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 • Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Changepro ed Program 0 Plug for Redrill 1:1 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Seyratch �7 RI • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 177-007 ' Exploratory 0 Development ❑ 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20239-00-00 • 99519-6612 Stratigraphic 0 Service 0• 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 0 PRUDHOE BAY UNIT 09-12 • 9. Property Designation(Lease Number): 10. Field/Pools: RECEIVED ADL 0028345 v PRUDHOE BAY.PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY n_-y 21 20`I� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): June® ` 12800 • 9188 • 11371 8188 IA Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 35-115 35-115 1530 520 Surface 2678 13-3/8"72#MN-80 33-2711 33-2711 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 968 7"29#N-80 11824-12792 8472-9182 8160 7020 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: 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 ❑ 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 Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.com Printed Name Stechauner,Bernhard Title FS2 Lead PE Signature Phone +1 907 564 4594 Date 272 o /I -7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ +'fi�8 14 Other: (iso Post Initial Injection MIT Req'd? Yes 0 No d Spacing Exception Required? Yes El No El Subsequent Form Required: /d r 4 0 Arips ;FctiL...... COMMISSIONER APPROVED BYTHE Approved by: COMMISSION Date:Z. �! ORIGINAL RBDMS ,R, 2017 z,/ / Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachnts in Duplicate 2.%• /7 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EA2,BPG 10/12/15) General Information Well Name: 09-12 Well Type: Water Injection Well API Number: 50-029-20239-00 Well Activity Conventional 4 Classification: Activity Description: IPROF Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory None requirements? Sundry Form 10-403 Required? No Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-7485 Well Intervention Engineer: Ryan Thompson Contact numbers: (907) 564-4535 (907)301-1240 Lead Engineer: Danielle Ohms Contact numbers: (907) 564-5759 (907)440-9082 Date Created: February 16, 2017 Revisions(date,who,what changed): Rev. 1 -Finalized patch design 2/16/17 Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 12/14/2016 4,929 1,301 Current Status: Operable Flowing Inclination>70°at Depth(ft) NA Maximum Deviation (Angle and Recent H2S (date,ppm) 12/22/1982 6 ppm Depth) 63° 10,212' MD _ Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 4° 3,076' MD Reservoir pressure(date, 10/21/2013 3,502 psi Minimum ID and Depth 2.375" 12,564' MD psig) Reservoir Temp,F 148° F Shut-in Wellhead Pressure 940 psi Known mech. integrity None problems(specifics) Last downhole operation (date, operation) 3/11/2014 Pull P-prong&5-1/2" PX plug from 11,371' MD post drill-by secure Most recent TD tag (date,depth, 3/25/2010 12,601' MD 1.9"cent, s. bailer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, Over the last 6 years we have set various combination of comingling and isolating sleeves in the two AVA background information, nipples in an attempt to reduce injection into Z2C. We also have 2 IPROFS showing anomalies around the etc: top AVA nipple and just below the first zonal isolation packer. In its current configuration,the well should inject into Z2A and Z2B only, however, no changes to injectivity nave peen seen since we first instanea me isolating sleeve in me top nipple. ivone of me hours snow any injection into the lower AVA profile,this could be due to a leak in the 3-1/2 pipe above the nipple. ,Plan is to patch over the top AVA, packer, and crossover to mitigate against all the anomalies we have observed in the injection logs.Also,to mitigate against potential crossflow behind the patch, we will set an isolating sleeve in the lower AVA profile. On 1/29/17 SL set the 3 1/2"BPI sleeve and pulled a caliper in preparation for setting the patch. Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Injection into unwanted zones Specific Intervention or Well Objectives: 1 Set patch over AVA BPL nipple @ 12,405' 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step# 1. Pull BPI Sleeve from 12,564' MD. 2. Set BPC Sleeve @ 12,564' MD. 1 S 3. RIH w/D&D packoff, no go on 3" ID snap latch seal assembly @-12,411, Set D&D packoff on no go. D&D packoff needs to be modified by removing the bottom STL pin prior to RIH. 4. RIH w/Northern Solutions LTP w/seal stinger per patch schematic. 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 4000 Expected Production Rates: FTP(psi): 1900 Choke setting: PI (bfpd/psi dp) Post job POP instructions: POI well on PWI, well should have significanity reduced infectivity after patching over thief zones. 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 Q Injector Minilog Last!PROF 08129110 LA Techlog Author a Protect PBU EWF Well: 09-12 LaurJ Larson Scale 1 700 Date 4/4,2016 fkon444.1 54 X 725402 02 a I rY411-03 000003 Cr* USA 1 1.44.24,544."Ka Y 91140350 93 op$710441000000 F.00 FAA**.04N ,',4 044,0,12100 t aroco.411235144 Uwe AMU ...Inlay Syster,NAM AFT 14444*,70341344 Cw'i*, WU Of N 3licuilki-RH":43- i AtmNW It t r9055 MO 0 r UtillP%233".1411W"Nok. VIM 1515 1 PE Notes OS_WO or tigl, ',Allred...MI i soo I no, ;, Z1 fAti 01r-• r w : i ' •_*** ',, vela/4.149.1r cllti"cakma2i/i311m5°W*Iirrir.PH7tIT 395t111014moss sppeg 2 Leakm4-4"tubing l ii at around 12395 MO. WU :- From 2011!PROF 4-1/2"AVA BPI sop 76% , IDL . 5 42400» Set 3/24/10 --- 11/27/11 Pkr 12411' - -; i 1 / ,„..4 Leak m 4r* 3;1" tubing at - around , 12430 MD. la From 2010 !PROF .. •. ---7---*1-' ' 12500 ..._ _ i . . ..... ..* 7.- t , 1. 3-1/2-AVA 111 I tritS0• , Be se 3/24/10 1:111 . -1 r ° - 1-Ji• _ 5PC set 11/27/11 Pkr 12574' 1, I ,e 1 22100 _ ION: 119% 2 , 7 Tag 12,636" :..,. on 8/29/10 ) 9050 42700- „• 4 ° 9100 4 MOO 1 i [ I ' - / I ,.., Local Knowledge for a Northern Sol utionsuc An Al.ikan t output) 450-372 Two Trip Straddle Global Industry 1 I _ NAW Q,,i' -r- Well No.: DS 09-12 Vendor: Drawn By:CWD FOR INFORMATION ONLY Requested By: Ryan T. 02-15-17 a Description OD ID Length -4 _a 1 rill 450-372 LIP 111Northern4S,o:,tuiti2o.n6:41.0inoeorpTsor PPacker 4"GS FN Up x 2-7,8"Pin Down 3.72" 2.38" 4.53' 11H Mechanical Set on Slick Line I Run 12 Includes patier,pup,and seal unit —1, I . , MI I MI I III 11BPXA 2.88" 2..141" "6.00 1 ' 2-7/8"6.5* ST1.B x P 11 , , 0840 Seal Stinger or OM 3.65" 2.38" "1.00' 2-7/8 511 Box 3.72" 0-..1 111 = 1 , D8x0 Pack-Oft ---, 4"GS FN X MEG ! IIIII , Rune 1 3.65" as ause the X-0 above the Ppacket nl 2.38" -3.00' 3.72" 3Seal Unst to Lowe and set against 1 1 i_...1 , H :' 1 i 1 Total Length TW: - -- ., tor information only.All feasibility and dimensional data should be vei died with the 1--- supplying vendor prior to installation. LOCO'KnJwieCiae!Or 0 Northern Soiutionst .,, GP.obui,.,41`.11,fly ko MAO",6.ofrr A,T, 4-31"D&D Packer NsAK Ref n465 . - Welt No. Vendor: Drawn By:CWD FOR INFORMATION ONLY Requested By: WLTB 10-02-2015 Description OD ID Length '(4* .....,s a Et•--4- rls -ropc, .5-,ri..poi) . ticrTzw.,ne. sri..F0 Pack Off 4GS FN:Up x 2-7/8"$T1.Pin On .r 312- 2.34. - '.1 s . ,(44 tie/g 1-'6, To?0 4'11-fig) 2:Az." Total Length TW. a) a0 0 0 0 0 0 0 0 0 0 c, N- CO (000NrCC) Cbo ,M — 10 CO O N- O O N N LO O O N LO V LO N- 10 Cfl CO U N o 0 0 0 0 0 0 o D o 0 i M C70 LO I— IC) CO M CO • in 00 r N m r LO CO CO CO CO h- C` CO •- CO CO C3) N CO O CO CO •- N O CO CO O M CO O N C` LC) V' CO r CO CV CO 0) O r N N 00 CO CA CO 00 CO 0) O CO N V O oo LO M r N 0 N- 00 O M 00 M oo LO N co (-N M O N CO CO CO CO CO � N a) r r - LO N N N- LC) O N- I LO r N N CO CA O LO CO CO co E r LC) r r N M V O V LO Q r N N N N r r N N - z < = N- LO O lO O r N N g 0 0 LO co co M M M LO N M N co N r r r r r I— O O LO LC) CO O) OCA CD CD c O ▪ _ � Z6coO000000 °J° cc? C)Q 200133c0 -1 -1Z y = U) ** U) ZJ *k *kC(p *k N *k N *k N• M � LCL▪ N g fn N V CT CO r CA (A - N v - _ N N N M LC') 00 Ch L[) CA U) LC) LC) r O) O) t � O m r- CO N in LC) N C 00 CO 0 C) N V M 't LO d N N CA (3) r N N- J r W W W Q Q Q C H W O O D cND <2 00000 OOLL. cQ ZZZZZ z CC w w w w COCOm m m 0U) ZZZ JHHHHH Cv U, co co CO COO N N CO CO CO CO p_ Co (X) M ti V 00 O a) a) co (NI a) LO CO co co 4 4 in CO O co o) co O) a) 0 0 0 0 0 0 0 CO CO CO a) C)) CS) a) a) a) a) 0 O N- CO N- a) a) 10 CO CO V N 10 LO CO LO O 0) CO N- N CO CO 0) CA I ai ri O O Cri Cri N- 4 cd CCi 0 O CO O CO in N O N Cr) co - LO w O co C)) a) a) a) OOOOOOO > O CO CO CO CO CO CA a) CS) a) a) a) O 0 > 2 cc F w o w Z w• w O w • H a g g Y Q 0 0 0 O W Y Y g -it El N- 0)) M � ooN � o � J J J as a cwn Z =▪ C O N N N N N N N CV N N N N 0 0 0 w W W J Q Q Q O p O a 0 pm.melom _ U U U W Z O a C.) Z 2 2 2 0 cn cn Qi) cJn cQn 4-0 Q Q = M = CSU (N N 0 CO 10N- O N N f— CO W O N.- N N.-- a) LO 00 O O N Q CV M LO LC) LO CO CO CO CO CO ▪ W O N N N N N N N (V N N N N S �_ Y U O Cl) O coc~n U)) v) co CD CL a ° U c ° 000000OCuuLu. uLOC m H H H H H H W a O a d W a 0 t m a H O• 0) 0) a) a) a) o) LC) LO LO LO LO N- a 0 00OCCCDa) 0) CD 0) co000cm rnrnrn z ow Q W 0 N N N N N N ` O W N W f0 a) 0) 0) 0) 0) C C C C C C d U CW W LL W • CO CO CO CO CO co 4 4 O Z J • p mo _1H --I WW < a cn w w u) o_ m E ca Z N N N N N N N N N N N N i i i i i i i i i i i LL d V) O LL N Q' W rn rn rni ch rn rn rn rn rn 0 rn rn m a d a 0 J O a w a O O O O O O C7 C7 CO O O O < < m m LL LL u) u) d CC Packers and SSV's Attachment PRUDHOE BAY UNIT 09-12 SW Name Type MD TVD Depscription 09-12 TBG PACKER 11356.08 8179.38 5-1/2" Baker S-3 Packer 09-12 TBG PACKER 11509.88 8270.52 5-1/2" Baker SAB Packer 09-12 TBG PACKER 12420.6 8901.05 5-1/2" Baker FB-1 Packer 09-12 TBG PACKER 12583.49 9023.23 5-1/2" Baker FB-1 Packer TREE= ,. CNV WE LHEAD= FMC 09-12 n12 SAFETY NOTES: ""PWI ONLY-NO MI INJECTION ACTUATOR= BAKER C ALLOWED"— OKB.ELEV= 54' BF.REl/_ ,KOP= 2100' —5-1/2"HES X NP,D=4.562" Max Ante= 63'Q 10 12' 20"CONDUCTOR, 111' t Datum MD= 1235T 94#,l4 40 Datum TVD= 8800•SS D=19.124" I 11325' --I5-1/2"HES X NP,D=4.562" g 11346' —i 9-5/8"X 5-1/2"BKR S-3 PKR,D=4.760" 13-3/8"CSG,72#,144-80 BTRS,D=12.347" --I 2708' J I 11371' —I 5-1/7 HES x NP,D=4.562" 5-1/2"TBG,17#,L-80 TCq.0232 bpf,D=4.897 --I 11432' 11447' —19-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG STUB(03/06/09) 11440' I 11472' H5-1/2"BKR FBRASSY,D=4-750" Minimum ID =2.375" @ 12564' �! 11500' —19-5/8"x 51/2"BKRSAB PFCR ID=4.750" 2.812" AVA BPI SLEEVE a 11506' 7"MILLOUT 1 XT�NSION,to=6.00' 1 11512' —7"x5-1/2'XO,D=4.85" 5-1/2"TBGPC,17#,L-80 AB-M 8RD, --I 11675' .0232 bpf,D=4.892" � 11634' —5-1/2"OTIS X NP,to=4.562" TOP OF 7'LNR H 11821' • J • 11675' H 5-1/T X 4-1/2"X0,D =3.958" 9-5/8"CSG,47#,N-80/S0095,D=8.681" —i 12129' I 12405',J-14-1/2"AVA BPL NP, 10=3.759" )tIA-L y i , 12411' —7'X4-1/2"BKR FB-1 PKR,ID=4.00" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" — 12411' F74 w/SNAP LATCH SEAL ASSY,ID=3.00" ,- It , 12415' `i5-1/2"MILLOUT EXTENSION,ID=4.50' 12420' —15-1/2"X 3-1/2"XO,D=2.992" PERFORATION SUMMARY REF LOG:BRCS ON 06/02/77 I ANGLE AT TOP PERF:42°Q 12378 I v' 12564' —i 3-1/2"AVA BR NP,D=2.697' Note:Refer to Production DB for historical pert data SIZE SPF NTBSVAL Opn/Sgz SHOT SOZ OF / -2.812"AVA BR SLV,D=2.375"(01/30/17) 2-1/8" 4 12378-12408 0 06/04/84 I `I 12574' —7'X3-1/2'BKR FB-1 PKR,ID=4.00' I 3-1/8' 4 12424-12457 0 09/07/77 w/SNAP LATCH SEAL ASSY,ID=3.00" iii I, 3-1/8" 4 12472-12479 0 09/07177 MI (►Mt 3-1/8" 4 12491-12498 0 09/07/77 12578' J-5-1/2"M11 LOUT EXTENSION,ID=4.50" 1 3-1/8' 4 12513 12532 0 09/07/77 12580' -I 5-112 X 3-1/2"X0,D=2.992" 3-1/8' 4 12554-12570 0 09/07177 3-1/8" 4 12587-12602 0 09/07117 12583' H 3-1/2"CAMCO DS NP,D=2.562' 3-118" 4 12600-12620 0 04/07/95 3-1/8" 4 12612 12617 0 09/07117 12586' 1---�3-1/2 BKR SHEAROUT SUB J I 3-1/8' 4 12628-12645 0 09/07/77 12587' ,-3-1/2'WLEG,D=2.992" 3-1/2"TBG-PC,9.2#,J-55,.0087 bpf,D=2.992" — 12587' ' 12586' ELMD TT LOGGED 5/3/95 PBTD --{ 12706' 11111111 111111111 7"LNR,29#,N-80/500-95,.0371 bpf,D=6.184" —i 12790' - 11111111 __ _._._ 1111111111111111 TD H 12800'---- DATE Fel/BY COP4U4TS DATE REV BY CONIVIENTS PRUDHOE BAY UNIT 06/11/77 FlOWAN 34 ORIGINAL COMPLETION 02/01/17 DG/JMD PULL AVA BRIBPC-SET AVA BR WELL: 09-12 10/24/86 WW1 RWI FERMI'No:'1770070 03/09/09 N4E?S RWO AR No: 50-029-20239-00 12/16/11 WE /PJC SET BPC&BR SLV'S(11/27/11) SEC 7,TION,R16E, 1346'FSL&75'FW. — 02/20/14 JG/JMD SET PX RUG(02/17/14) 03/14/14 RKT/JMD PULLED PJC RUG(03/11/14) BP Exploration(Alaska) bp RECEIVED 0 AUG 21 2014 AOGiiL' BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOG DATA) Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents SCANNED 1 CD-ROM Containing OPEN HOLE Digital Log Data: 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-031 B-111 B-241 B-251, C-10, L2 -07A, 0-02, M-041, M-05, U-14 The information on this CD ",*Nv, is to be used for BP Exploration (Alaska) nc. business only. If you are not the owner or licensed V// user of this CD, any disclosure, copying or use of the A nformation on this CD is prohibited. If you obtain this n eta K. �� CD by error, please return the CD to the address shown A g below. BP will pay the postage. Thank you. Please Sign and gancpdc@bp.com Doug Dortch Petrotechnical Attn: State of AlaskaV Attn: Makana Bender 333 W. 7th Ave, Suite 1 Anchorage, Alaska 99501 If found please return CD to: BP Exploration PO Box 196612 Anchorage, AK 99519-6612 CD1of1 by For External Distribution BPXA OH Log Data 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, r 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-181 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-24, B-25, C-10, L2 -07A, 1-3-02, M-04, M-05, U-14 18 -AUG -2014 Petrotechnical Data enter R2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 Brooks, Phoebe L (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, June 21, 2013 4:15 PM To: Brooks, Phoebe L (DOA) Cc: Climer, Laurie A Subject: RE: MIT PBU 09-12 04-01-13 Attachments: MIT PBU 09-10,12 05-05-13 Revised.xls; MIT PBU 09-12 04-01-13 Revised.xls; PBU 09-12 - PTD 1770070-directional survey.xls Hi Phoebe, Our system shows that the packer at 11500'MD is at 8265'TVD. I have included the directional survey for the well in addition to the updated tests. Thank you, Laurie Climer (,lierrncttc ,Jack L)ishro 1) BP Alaska - Well Integrity Coordinator SCANNED FEB 2 0 2014 WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks©alaska.gov] Sent: Friday, June 21, 2013 1:18 PM To: AK, D&C Well Integrity Coordinator Subject: RE: MIT PBU 09-12 04-01-13 Laurie, The MD/TVD we have in our database is 11500/8207 (I spoke with Jim and verified). Please send revised reports for PBU 09-12 04-01-13 and 05-05-13 correcting the packer tvd or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax:907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWellIntegrityCoordinatorCc�bp.com] Sent: Friday, June 21, 2013 11:44 AM 1 MD TVD Inclination Azimuth Dog Leg Geo X Geo Y 0.0 0.0 0.0 151.00 0.0 0 0 812.0 812.0 0.5 151.00 0.0 2 -3 1,511.0 1,511.0 0.8 171.00 0.1 4 -10 2,750.0 2,749.8 1.0 121.00 0.1 15 -23 2,800.0 2,799.8 1.8 93.00 2.0 16 -24 2,860.0 2,859.7 4.0 101.00 3.8 19 -24 2,923.0 2,922.5 6.3 101.00 3.6 25 -25 3,015.0 3,013.7 8.3 89.00 2.7 36 -25 3,076.0 3,073.9 10.5 93.00 3.8 46 -25 3,215.0 3,209.5 15.0 97.00 3.3 77 -27 3,432.0 3,416.5 19.8 102.00 2.3 141 -37 3,620.0 3,590.3 25.0 104.00 2.8 211 -51 3,806.0 3,756.4 28.5 106.00 1.9 292 -70 3,962.0 3,890.1 33.5 107.00 3.2 370 -91 4,150.0 4,042.1 38.5 109.00 2.7 476 -122 4,332.0 4,178.9 44.0 112.00 3.2 590 -161 4,520.0 4,305.8 51.0 114.00 3.8 718 -211 4,582.0 4,344.0 53.0 114.00 3.2 764 -230 4,747.0 4,441.0 55.0 113.00 1.3 888 -280 5,550.0 4,915.8 52.5 114.00 0.3 1,489 -520 5,800.0 5,068.0 52.5 115.50 0.5 1,671 -598 5,979.0 5,178.8 51.0 114.50 1.0 1,800 -654 6,095.0 5,252.6 50.0 114.00 0.9 1,883 -688 6,258.0 5,355.8 51.5 107.00 3.5 2,002 -729 6,321.0 5,394.1 53.5 107.00 3.2 2,050 -742 6,517.0 5,508.6 55.0 107.00 0.8 2,204 -784 6,889.0 5,720.7 55.5 108.00 0.3 2,498 -868 7,198.0 5,895.7 55.5 106.00 0.5 2,743 -935 7,690.0 6,179.7 54.0 106.00 0.3 3,133 -1,034 7,875.0 6,291.0 52.0 106.00 1.1 3,276 -1,071 8,030.0 6,385.9 52.5 107.00 0.6 3,394 -1,102 8,154.0 6,460.7 53.3 106.00 0.9 3,490 -1,128 8,303.0 6,550.1 53.0 106.00 0.2 3,605 -1,157 8,459.0 6,642.9 54.0 107.00 0.8 3,726 -1,189 8,607.0 6,729.7 54.3 107.00 0.2 3,842 -1,221 8,861.0 6,877.6 54.5 107.00 0.1 4,041 -1,276 9,141.0 7,037.2 56.0 108.00 0.6 4,263 -1,338 9,633.0 7,307.0 57.5 108.00 0.3 4,657 -1,454 10,212.0 7,595.3 62.8 111.00 1.0 5,135 -1,608 10,505.0 7,731.7 61.8 112.00 0.5 5,379 -1,696 10,882.0 7,918.8 58.8 114.00 0.9 5,684 -1,815 11,390.0 8,199.1 54.3 115.50 0.9 6,073 -1,981 11,539.0 8,288.3 52.3 116.00 1.4 6,182 -2,030 11,772.0 8,437.2 48.3 118.00 1.8 6,344 -2,107 12,040.0 8,623.0 44.0 121.00 1.8 6,515 -2,197 12,349.0 8,848.1 42.5 124.00 0.8 6,697 -2,305 12,594.0 9,031.2 40.8 124.00 0.7 6,834 -2,392 12,710.0 9,119.2 40.5 125.00 0.6 6,898 -2,433 12,800.0 9,187.8 40.3 125.00 0.3 6,946 -2,465 1 MEMORANDUM TO: Jim Regg I P.I. Supervisor r 2LI13 FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 24, 2013 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-12 PRUDHOE BAY UNIT 09-12 Src: Inspector Well Name PRUDHOE BAY UNIT 09-12 Insp Num: mitRCN130402161443 Rel Insp Num: API Well Number 50-029-20239-00-00 Permit Number: 177-007-0 Inspector Name: Bob Noble Inspection Date: 4/1/2013 Packer Depth Pretest Initial 15 Min 30M in 45 Min 60 Min Well ' 09-12 Type Inj W TVD 8265 - IA 733 2428 2409 2409 ' PTD 1770070 Type Test SPT Test psi 2066.25 OA 506 570 - 546 620 Interval Four Year Cycle P/Ii I Pass I Tubing 1 1544 1543 ' 1541 1532 Notes: Monday, June 24, 2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 24, 2013 TO: Jim Regg e—') P.I. Supervisor j 1 SUBJECT: Mechanical Integrity Tests 11 l BP EXPLORATION (ALASKA) INC 09-12 FROM: Jeff TUrkington PRUDHOE BAY UNIT 09-12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, �t� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-12 API Well Number 50-029-20239-00-00 Inspector Name: Jeff Turkington Permit Number: 177-007-0 Inspection Date: 5/5/2013 Insp Num: mitJAT130505154238 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 09-12 - _-t_ yp I W Well IT e In'� --L-1770070 J T�ID -- 8265 ' '��321 IA — 538 2492 -� 406 - 2479 453 2472 511 2467 542 2463 562' PTD , iType Test SPT F Test psi 2066 P OA 1201 1200 1199 1199 1196 Interval 4YRTST Tubing1202 Notes: 4.5 bbl to fill. After test bleed off casing IA was 566 psig and OA was 368. Well is under evaluation by operator due to IA/OA communication indicated on 4/1/13 test, torqued lock down screws on casing hanger on 4/10/13, but still seemed to indicate same on this test. Monday, June 24, 2013 Page 1 of 1 Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator [AKDCWellintegrityCoordinator@bp.com] Sent: Wednesday, May 15, 2013 8:31 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Clingingsmith, Mike J; Walker, Greg (D&C) Subject: OPERABLE: Injector 09-12 (PTD #1770070) Passing MIT -IA All, Injector 09-12 (PTD #1770070) passed a state witnessed MIT -IA on 05/05/2013. At this time the well is reclassified as Operable and may remain on injection. Regards, Laurie Climer (Alternate: Jack Disbrow) BPalaska - Well Integrity Coordinator V �+ �l Organ zat:on WIC Office: 907.659.5102 WIC Email: AKDCWeIIlnteerityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, April 12, 2013 9:59 AM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Clingingsmith, Mike J; Walker, Greg (D&C) Subject: UNDER EVALUATION: Injector 09-12 (PTD #1770070) Barriers Confirmed with Passing MITIA 0, Injector 09-12 (PTD #1770070) passed an MITIA on 04/10/2013 after reenergizing the inner casing pack off seals in the wellhead. The outer annulus did not show signs of repress urization during the test. The passing test confirms 2 competent barriers. The well is reclassified as Under Evaluation and placed on a 28 -day clock, and can be placed on injection for further evaluation and regulatory testing. Plan forward: 1. AOGCC MITIA to 2500 psi after well is on injection and thermally stable. A copy of the most recent MITIA is attached for reference. Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, April 12, 2013 9:59 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Clingingsmith, Mike J; Walker, Greg (D&C) Subject: UNDER EVALUATION: Injector 09-12 (PTD #1770070) Barriers Confirmed with Passing MITIA Attachments: MIT PBU 09-12 04-10-13.xls 0 Injector 09-12 (PTD #1770070) passed an MITIA on 04/10/2013 after reenergizing the inner casing pack off seals in the wellhead. The outer annulus did not show signs of repressurization during the test. The passing test confirms 2 competent barriers. The well is reclassified as Under Evaluation and placed on a 28 -day clock, and can be placed on injection for further evaluation and regulatory testing. Plan forward: 1. AOGCC MITIA to 2500 psi after well is on injection and thermally stable. A copy of the most recent MITIA is attached for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator Global Wells Organizatilor Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, April 09, 2013 3:31 PM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Arend, Jon Subject: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA All, Injector 09-12 (PTD #1770070) underwent a 4 year AOGCC MIT -IA on 04/01/2013. The MITIA was considered a pass, however, after further review the MITIA failed based on outer annulus pressure increase during the final 15 minutes of the test. The well is reclassified as Not Operable. Proposed plan forward: 1. Wellhead: PPPOT-IC 2. Fullbore: Pre AOGCC MITIA to 2500 psi 3. Fullbore: AOGCC MITIA to 2500 psi after well is on injection and thermally stable, depending on results from pretest A copy of the original MITIA test form is included for reference. Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie C(imerr BP Alaska - Well Integrity Coordinator Global Wells GW Organization Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com Wallace, Chris D (DOA) From: AK, OPS FS2 Facility OTL [AKOPSFS2FacilityOTL@bp.com] Sent: Tuesday, April 09, 2013 3:39 PM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Arend, Jon Subject: RE: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA Well 9-12 has been shut in. Erl, PaLwter FS2/COTU OTL 659-5492 / H-701 Pager 659-5272 - 1 1 15 Alt. Skip Desaulniers From: AK, D&C Well Integrity Coordinator Sent: Tuesday, April 09, 2013 3:31 PM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Arend, Jon Subject: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA All, Injector 09-12 (PTD #1770070) underwent a 4 year AOGCC MIT -IA on 04/01/2013. The MITIA was considered a pass, however, after further review the MITIA failed based on outer annulus pressure increase during the final 15 minutes of the test. The well is reclassified as Not Operable. Proposed plan forward: 1. Wellhead: PPPOT-IC 2. Fullbore: Pre AOGCC MITIA to 2500 psi 3. Fullbore: AOGCC MITIA to 2500 psi after well is on injection and thermally stable, depending on results from pretest A copy of the original MITIA test form is included for reference. Please call with any questions. Thank you, Jack Disbrow (Alteroz BP Alaska - Well Integrity Coordinator GW GI©bal WellsOrganization P ct v z M 17-7 Co -7o Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator(AKDCWelllntegrityCoordinator@bp.comj Sent: Monday, May 06, 2013 6:18 PM r To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Injector 09-12 (PTD #1770070) Inconclusive AOGCC MITIA Attachments: Injector 09-12 (PTD #1770070) TIO Plot.docx; Injector 09-12 (PTD #1770070) Wellbore Schematic.pdf; MIT PBU 09-12 5-5-13.xls Jim, Chris, Injector 09-12 (PTD #1770070) underwent an AOGCC MITIA on 05/05/2013. The AOGCC Inspector classified the test as inconclusive due to OA repressurization during the test. The well is currently classified as Under Evaluation, and is on injection. BP would like permission from the AOGCC to leave the well on injection and perform a 7 day outer annulus repressurization test to better quantify the repressurization and gather data for a possible administrative approval. Copies of the TIO plot, wellbore schematic, and most recent AOGCC MITIA form are attached. Please call with any questions. Thank you, Jack Disbrow SCANNED BP Alaska Well Integrity Coordinator Global Wells GW Organization Office: 907.659.5102 WIC Email: AKDCWelllntesritvCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, April 12, 2013 9:59 AM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Clingingsmith, Mike J; Walker, Greg (D&C) Subject: UNDER EVALUATION: Injector 09-12 (PTD #1770070) Barriers Confirmed with Passing MITIA All, Injector 09-12 (PTD #1770070) passed an MITIA on 04/10/2013 after reenergizing the inner casing pack off seals in the wellhead. The outer annulus did not show signs of repressurization during the test. The passing test confirms 2 competent barriers. The well is reclassified as Under Evaluation and placed on a 28 -day clock, and can be placed on injection for further evaluation and regulatory testing. Plan forward: 1. AOGCC MITIA to 2500 psi after well is on injection and thermally stable. A copy of the most recent MITIA is attached for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska Well Integrity Coordinator GWGlobal Wells ,,' Organization Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, April 09, 2013 3:31 PM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Arend, Jon Subject: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA on Injector 09-12 (PTD #1770070) underwent a 4 year AOGCC MIT -IA on 04/01/2013. The MITIA was considered a pass, however, after further review the MITIA failed based on outer annulus pressure increase during the final 15 minutes of the test. The well is reclassified as Not Operable. Proposed plan forward: 1. Wellhead: PPPOT-IC 2. Fullbore: Pre AOGCC MITIA to 2500 psi 3. Fullbore: AOGCC MITIA to 2500 psi after well is on injection and thermally stable, depending on results from pretest A copy of the original MITIA test form is included for reference. Please call with any questions. Thank you, Jack Disbrow !411ernate: him,11,(Yhnerj BP Alaska -Well Integrity Coordinator ,GWIGlobal �'1,`e1i Or anlzaliot Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(abalaska.gov doa.aogcc.prudhoe.bay(a)alaska.gov phoebe.brooks(a)alaska.gov; tom.maunderaalaska.gov OPERATOR: FIELD / UNIT / PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. � 5 I f [I,-;, Prudhoe Bay/PBU/DS-09 fq 05/05/13 Jack Disbrow Jeff Turkin TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) QU(Msr u . g-PxA- Aaroou Form 10-426 (Revised 06/2010) MIT Pau 09-12 5-5-13 As Sd- GLS OJ1- L ; tt Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-12 I Type Inj. I W TVD 8,174' Tubing 1,202 1,201 1,200 1,199 1,199 1,195 Inteval 4 P.T.D. 1 1770070 Type test I P Test psi 2043.5 Casing 538 2,492 2,479 2,472 2,467 2,463 P/F P Notes: Standard 4 year, post listing U.E. IA took 4.55 bbls MEOH to pressure up OA 321 406 453 511 542 562 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. I TVD Tubing Interval P.T.D. I Typetest I Test psi I Casing P/F Notes: OA Weil Type Inj. TVD Tubing Inteval P.T.D. I Type test I Test psi I Casing '/F Notes: OA Well I Type Inj. I TVD Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) QU(Msr u . g-PxA- Aaroou Form 10-426 (Revised 06/2010) MIT Pau 09-12 5-5-13 As Sd- GLS OJ1- L ; tt PBU 09-12 PTD #1770070 5/6/2013 TIO Pressures Plot Well: 09-12 Tb9 f IA — A OA OOA OOOA On TREE= _ WELLHEAD = FMC 09-12 SAFETY NOTES: —PWI ONLY - NO MI INJECTION ALLOWED' ACTUATOR = . BAKER C Opn/Sgz -- KB- ELEV = 54' 12378 - 12408 0 BF ELEV 2100' —jS-15 2" HH'ES�X NI'P, ID = 4.562' KOP 2� 20" CONDUCTOjilMax 09/07177 3-1/8" 4 Angie =63' @ 10212' 94#,K40 0 09/07/77 Datum MD= 12357' ID = 19.124"DatumTVD= .. 12491 - 12498 0 8800'SS 3-1/8" 4 12513- 12532 13-3/8" CSG, 72#, W80 BTRS, ID =12.347 11346'9-5/8" X 5-12' BKR S-3 PKR, ID - 4.760" 12554 - 12570 11371' —5-1/2" HES X NIP, ID = 4.562' 5-1/2" TBG, 17#, L-80 TGI, .0232 bpf, ID = 4.892' 11432' 11447' 9 518" X 5 1/2" UNQUE OVERSHOT 5-1/2" TBG STUB (03/06/09) 11440' I I 11472' 5-1 /2" BKR PER ASSY, ID = 4.750" Minimum ID = 2.376" @ 12664' 04/07/95 3-1/8" 4 12612- 12617 11soo' s -5/8"X512" BKR SAB PKR, ID=4.750 2.812" AVA BPC SLEEVE - 11 - 11 - - _ 506' -- 7" MILLUT EXTE, ID 6.t� ONSIONte" _ _ _a 09/07/77 11512' TBG -PC, 17#, L-80 AB -M 8RD, 11675' 15-112" .0232 bpf, !D = 4.892 11634' S 1/2" OT{S X NIP, ID = 4.562" TOP OF 7" LNR H 11821' 9-5/8" CSG, 47#, N -80/S0095, ID = 8.681" 1-1 12129' 4-1/2' TBG, 12.6#, L-80_0152 bpf, ID = 3.958" 1-j 1 PERFORATION SUW*RY REF LOG: BHCS ON 06102/77 ANGLE AT TOP PERF: 42° @ 12378' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-1/8" 4 12378 - 12408 0 06/04/84 3-1/8" 4 12424 - 12457 0 09/07177 3-1/8" 4 12472 - 12479 0 09/07/77 3-1/8" 4 12491 - 12498 0 09/07/77 3-1/8" 4 12513- 12532 0 09/07/77 3-1/8" 4 12554 - 12570 0 09/07/77 3-1/8" 4 12587 - 12602 0 09/07/77 3-1/8" 4 12600 - 12620 0 04/07/95 3-1/8" 4 12612- 12617 O 09/07/77 .3-1/8", 4 12628 - 12645 0 09/07/77 3-12" TBG -PC, 9.2#, J-55, .0087 bpf, ID = 2.992' 12587' PBm——C127o6' 7" LNR, 29#, N-80/SOO-95, .0371 bpf, ID = 6.184"12790' 'I D l 12800' 11675' 1--15-1/2'X4-1/2"X0,113=21.959' 12405' -14-12" AVA BPL NP, ID = 3.759" 12405' 1-j 3.812' AVA BPI SLV, ID = 3.35' (1127/11 12411' 7" X4-1/2" BKR FB -1 PKR, ID = 4.00" VWSNAP LATCH SEAL ASSY, ID = 3.00- 12416' S 1/2" MILLOUT EXTENSION, ID = 4.50' 12420' 5-1 rr x 3.1 rr' xo, ID = 2.992' 11 2564' —13-12" AVA BPL NIP, ID = 2.697" I 12564' 2.812' AVA BPC SLV, ID = 2.375" (1127/11 12574' 7" X3-1/2" BKR FB -1 PKR, ID = 4.00" DATE REV BY COMMENTS DATE REV BY CON viENTS w/SNAP LATCH SEAL ASSY, ID = 3.00" 061111`77 ROWAN 3A ORIGINAL COMPLETION 12678' 5-1/2" MILLOUT EXTENSION. ID = 4.50" 12580' 5-1/2" X 3-1/2" XO, ID = 2.992' 12583' 3-1a' CA MCO DS NP, ID -2.562' 125$6' -- 3-1l2" BKR SMEAROUT SUB 12587'-- 3-1/2" WLEG, ID = 2.99 12586' ELMD TT LOGGED 5/3/� PRUDHOE BAY UNIT WELL: 09-12 PERMMT No: '1770070 API No: 50-029-20239-00 SEC 7, TION, R16E, 1346' FSL & 75' FWL DATE REV BY COMMENTS DATE REV BY CON viENTS 061111`77 ROWAN 3A ORIGINAL COMPLETION 04/01/10 SWC/SV BPI CIO (03125/10) I 10/24/86 WW1 RWI 12/16/11 WEC/PJC SET BPC & BPI SLV'S (11/27/11) 03109109 NOES RWO 03/1009 PJC DRLG CORRECTIONS 04/30/091 DB I DRLG DRAFT CORR (07/10/09) BP Exploration (Alaska) 06/10/09 PP/JMD JPERFCORRECTIONS 11 Wallace, Chris D (DOA) From: Sent: To: Cc: Subject: Attachments: All, AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com) Friday, April 12, 2013 9:59 AM Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Clingingsmith, Mike J; Walker, Greg (D&C) UNDER EVALUATION: Injector 09-12 (PTD #1770070) Barriers Confirmed with Passing MITIA MIT PBU 09-12 04-10-13.xls Injector 09-12 (PTD #1770070) passed an MITIA on 04/10/2013 after reenergizing the inner casing pack off seals in the wellhead. The outer annulus did not show signs of repressurization during the test. The passing test confirms 2 competent barriers. The well is reclassified as Under Evaluation and placed on a 28 -day clock, and can be placed on injection for further evaluation and regulatory testing. Plan forward: 1. AOGCC MITIA to 2500 psi after well is on injection and thermally stable. A copy of the most recent MITIA is attached for reference. Please call with any questions. Thank you, Jack Disbrow (Alternate: Lauri(. BP Alaska - Well Integrity Coordinator Global Wells GW Qrganizatior Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com SCANNED OCT 0 9 2014 From: AK, D&C Well Integrity Coordinator Sent: Tuesday, April 09, 2013 3:31 PM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Arend, Jon Subject: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA All, Injector 09-12 (PTD #1770070) underwent a 4 year AOGCC MIT -IA on 04/01/2013. The MITIA was considered a pass, however, after further review the MITIA failed based on outer annulus pressure increase during the final 15 minutes of the test. The well is reclassified as Not Operable. Proposed plan forward: 1. Wellhead: PPPOT-IC 2. Fullbore: Pre AOGCC MITIA to 2500 psi 3. Fullbore: AOGCC MITIA to 2500 psi after well is on injection and thermally stable, depending on results from pretest A copy of the original MITIA test form is included for reference. Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie BP Alaska - Well Integrity Coordinator Global Wells GW Organizatior Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector Well Name PRUDHOE BAY UNIT 09-12 Insp Num: mitRCN130402161443 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 09,E 2013 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-12 1 PRUDHOE BAY UNIT 09-12 NON -CONFIDENTIAL API Well Number 50-029-20239-00-00 Permit Number: 177-007-0 Src: Inspector i Reviewed By..:��p? P.I. Supry IT&C— Comm Inspector Name: Bob Noble Inspection Date: 4/1/2013 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 09-12 Type Inj W TVD 8175 IA 733 2428 2409 2409 1770070 Type Test SPT Test psi 2043 OA 506 570 - 546 620 BI 4YRTST P/F P ✓Tubing 1544 - 1543 1541 1532 - Notes: ��e•0' ��- -iti S1�•��, �Svu�2 `'Icse w. oP� l�tsf 'E a- Ct t ( ( 3 SCANNED 0 ) 2014 Tuesday, April 09, 2013 Page 1 of 1 r6 6k C9 -1z P76 17700 -7 Regg, James B (DOA) From: AK, OPS FS2 Facility OTL [AKOPSFS2FacilityOTL@bp.com] Sent: Tuesday, April 09, 2013 3:39 PM �� To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Arend, Jon Subject: RE: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA Well 9-12 has been shut in. ✓ Erik Painter FS2/COTU OTL 659-5492 / H-701 Pager 659-5272 - 1 1 15 From: AK, D&C Well Integrity Coordinator Sent: Tuesday, April 09, 2013 3:31 PM To: 'Regg, James B (DOA)'; 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Arend, Jon Subject: NOT OPERABLE: Injector 09-12 (PTD #1770070) OA Pressurization During MITIA All, Injector 09-12 (PTD #1770070) underwent a 4 year AOGCC MIT -IA on 04/01/2013. The MITIA was considered a pass, however, after further review the MITIA failed based on outer annulus pressure increase during the final 15 minutes of the test. The well is reclassified as Not Operable. Proposed plan forward: 1. Wellhead: PPPOT-IC Fullbore: Pre AOGCC MITIA to 2500 psi Fullbore: AOGCC MITIA to 2500 psi after well is on injection and thermally stable, depending on results from pretest A copy of the original MITIA test form is included for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GW Global Wells Organization Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, April 09, 2013 9:39 AM 01` 4-1 0( �l 1; To: AK, D&C Well Integrity Coordinator L Cc: DOA AOGCC Prudhoe Bay Subject: FW: MIT PBU 09-12 04-01-13 (questioning the pressure spike) Attachments: MIT PBU 09-12 4-1-13.pdf Attached is Inspector's report for the MIT on PBU 09-12 (PTD 1770070). The significant OA pressure increase between 15 and 30 minute recordings is the basis for failing this MIT. At a minimum, the test should have been extended 15-30 minutes to determine if this was in fact an issue with the mechanical integrity, or if the pressure record can otherwise be explained. Please contact AOGCC Inspector to arrange for a witnessed retest. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Tuesday, April 09, 2013 8:18 AM To: Regg, James B (DOA) Subject: MIT PBU 09-12 04-01-13 (questioning the pressure spike) Hi Jim, I just talked with Jon (I believe he was the one who conducted the test for BP) and he confirmed the numbers are correct and asked if the test would now be considered a fail (he assumed so). He said that they were going to go out again to retest this well and was wondering if you could please send an email to Jack Disbrow the BP Well Integrity Coordinator @ AKDCWelllntegrityCoordinator@bp.com letting him know if you were going to fail this test? I revised Bob's report to show it as a failure (it's on your desk). Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 RECEIVED STATE OF ALASKA ALIRA OIL AND GAS CONSERVATION COMMI N AUG 2 9 2012 REPORT OF SUNDRY WELL OPERATIONS Plug Perforations Pe Other GCC 1. Operations Abandon U Repair Well U s U U Brightwater Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmert❑ Exploratory ❑ _ 177 -007 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20239 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: , ADL0028345 ` PBU 09 -12 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 12800 feet Plugs measured None feet true vertical 9187 feet Junk measured None feet Effective Depth measured 12706 feet Packer measured See Attachment feet true vertical 9116.18 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20" 96# H-40 31 - 115 31 - 115 0 0 Surface 2678 13 -3/8" 72# MN -80 30 - 2708 30 - 2707.83 5380 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 969 7" 29# N -80 11821 - 12790 8470.12 - 9180.15 8160 7020 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment 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): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 4799 0 1399 Subsequent to operation: 0 0 4001 0 1383 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator10 Development ❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: ,, Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG E 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: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature Phone 564 -4424 Date 8/28/2012 i f i '3.../L , f'M Form 10-404 Revised 10/2010 RSDMS AUG 3 0 2012 /I " - { Submit Original Only Packers and SSV's Attachment ADL0028345 SW Name Type MD TVD Depscription 09 -12 PACKER 11508 8215.38 5 -1/2" Baker SAB Packer 09 -12 PACKER 12419 8845.87 4 -1/2" Baker FB -1 Isolation Packer 09 -12 PACKER 12581 8967.34 5 -1/2" Baker FB -1 Packer • • Perforation Attachment ADL0028345 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 09 -12 3/9/2009 STC 12378 12408 8869.47 8891.7 09 -12 3/9/2009 STC 12424 12457 8903.58 8928.17 09 -12 3/9/2009 STC 12472 12479 8939.37 8944.6 09 -12 3/9/2009 STC 12491 12498 8953.59 8958.83 09 -12 3/9/2009 STC 12513 12532 8970.09 8984.37 09 -12 3/9/2009 STC 12554 12570 9000.95 9013.02 09 -12 4/7/1995 PER 12587 12600 9025.88 9035.73 • 09 -12 4/7/1995 RPF 12600 12602 9035.73 9037.24 09 -12 4/7/1995 APF 12602 12612 9037.24 9044.82 09 -12 4/7/1995 RPF 12612 12617 9044.82 9048.61 09 -12 4/7/1995 APF 12617 12620 9048.61 9050.89 09 -12 9/7/1977 PER 12628 12645 9056.95 9069.85 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • il Casing / Tubing Attachment ADL0028345 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" 96# H-40 31 - 115 31 - 115 LINER 969 7" 29# N -80 11821 - 12790 8470.12 - 9180.15 8160 7020 PRODUCTION 2870 9 -5/8" 47# SOO -95 28 - 2898 28 - 2897.6 8150 5080 PRODUCTION 9201 9 -5/8" 47# N -80 2898 - 12099 2897.6 - 8665.52 6870 4760 SURFACE 2678 13 -3/8" 72# MN -80 30 - 2708 30 - 2707.83 5380 2670 TUBING 11657 5 -1/2" 17# L -80 25 - 11682 25 - 8378.22 7740 6280 TUBING 737 4 -1/2" 12.6# L -80 11682 - 12419 8378.22 - 8899.87 8430 7500 • TUBING 161 3 -1/2" 9.3# N -80 12419 - 12580 8899.87 - 9020.59 10160 10530 TUBING 7 4 -1/2" 12.6# L -80 12580 - 12587 9020.59 - 9025.88 8430 7500 TUBING 7 3 -1/2" 9.3# N -80 12587 - 12594 9025.88 - 9031.18 10160 10530 1110 • • Daily Report of Well Operations ADL0028345 ACTIVMTYDATE 1 SUMMARY • _ • emp =' o :rig a er - eservoir weep ® o• Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 153 gal. EC9360A (Surfactant) Average of 23.5 gph for 6.5 hrs. Pumped a total of 153 gal. since start of project. Pumped 600 gal. EC9378A ( Polymer) Average of 100 gph for 6 hrs. Pumped a total of 600 gal. since start of project 7/12/2012 ** *Continued on WSR Ox/xx/2012 * ** I /I/O = 1450/520/340 ** *WSR continued from 07 -12- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @- 4000 bwpd. Pumped 497 gal. EC9360A (Surfactant) Average of 20.7 gph for 24 hrs. Pumped a total of 650 gal. since start of project. Pumped 2467 gal. EC9378A ( Polymer) Average of 102.7 gph for 24 hrs. Pumped a total of 3067 gal. since start of project 7/13/2012 ** *WSR continued on 07/13/2012 * ** T /1 /0 = 1450/520/340 ** *WSR continued from 07 -13- 2012 ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @- 4000 bwpd. Pumped 525 gal. EC9360A (Surfactant) Average of 21.8 gph for 24 hrs. Pumped a total of 1175 gal. since start of project. Pumped 2412 gal. EC9378A ( Polymer) Average of 101 gph for 24 hrs. Pumped a total of 5479 gal. since start of project 7/14/2012 ***WSR continued on 07/14/2012 * ** T /1 /0 = 1450/520/340 ** *WSR continued from 07 -14- 2012 ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @— 4000 bwpd. Pumped 494 gal. EC9360A (Surfactant) Average of 20.5 gph for 24 hrs. Pumped a total of 1669 gal. since start of project. Pumped 2522 gal. EC9378A ( Polymer) Average of 105 gph for 24 hrs. Pumped a total of 8001 gal. since start of project 7/15/2012 ***WSR continued on 07 -15- 2012 * ** • = • • 0 'S TT - con inue. rom 1 - - • emp ='o :rig a er Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @— 4000 bwpd. , Shut down for Pigging Operation and then resumed pumping Pumped 455 gal. EC9360A (Surfactant) Average of 25.2 gph for 18 hrs. Pumped a total of 2124 gal. since start of project. Pumped 1770 gal. EC9378A ( Polymer) Average of 104.1 gph for 17 hrs. Pumped a total of 9771 gal. since start of project 7/16/2012 ***WSR continued on 07 -16- 2012 * ** • • • Daily Report of Well Operations ADL0028345 T /1/0 = 1450/520/340 * * *1NSR continued from 0746- 2012 ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @— 4000 bwpd. , Shut down for Pigging Operation and then resumed pumping Pumped 550 gal. EC9360A (Surfactant) Average of 22.9 gph for 24 hrs. Pumped a total of 2674 gal. since start of project. Pumped 2474 gal. EC9378A ( Polymer) Average of 103 gph for 24 hrs. Pumped a total of 12245 gal. since start of project 7/17/2012 ***WSR continued on 07 -17- 2012 * ** 17i10 = 1450/520734 * continued from 07- 17- 2012** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @— 4000 bwpd. Pumped 547 gal. EC9360A (Surfactant) Average of 22.79 gph for 24 hrs. Pumped a total of 3221 gal. since start of project. Pumped 2597 gal. EC9378A ( Polymer) Average of 108.2 gph for 24 hrs. Pumped a total of 14842 gal. since start of project 7/18/2012 ***WSR continued on 07 -19- 2012 * ** 'T/I /O = 1428/500/280 ** *Continued WSR from 07- 18- 2072 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 462 gal. EC9360A (Surfactant) Average of 19.25 gph for 24 hrs. Pumped a total of 3686 gal. since start of project. Pumped 2568 gal. EC9378A ( Polymer) Average of 107 gph for 24 hrs. Pumped a total of 17410 gal. since start of project ** *Continued on WSR 07/20/2012 * ** 7/19/2012 T /l /0 = 1438/480/280 ** *Continued WSR from 07 -19- 2012 * ** Temp =Hot ( Brghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 508 gal. EC9360A (Surfactant) Average of 21.1 gph for 24 hrs. Pumped a total of 4191 gal. since start of project. Pumped 2432 gal. EC9378A ( Polymer) Average of 101.3 gph for 24 hrs. Pumped a total of 19842 gal. since start of project 7/20/2012 ** *Continued on WSR 07 -21- 2012 * ** 171/0 = 1437/500/300 ** *Continued WSR from 07-20-2012*** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 509 gal. EC9360A (Surfactant) Average of 21.2 gph for 24 hrs. Pumped a total of 4700 gal. since start of project. Pumped 2491 gal. EC9378A ( Polymer) Average of 103.7 gph for 24 hrs. Pumped a total of 22333 gal. since start of project ** *Continued on WSR 07 -22- 2012 * ** 7/21/2012 • • Daily Report of Well Operations ADL0028345 - T /1 /O = 14326 /420 /220 * * *ContinuedWSR from 07- 21- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 4000 bwpd. Pumped 511 gal. EC9360A (Surfactant) Average of 21.2 gph for 24 hrs. Pumped a total of 5211 gal. since start of project. Pumped 2626 gal. EC9378A ( Polymer) Average of 109 gph for 24 hrs. Pumped a total of 24959 gal. since start of project 7/22/2012 ** *WSR Continued on 07 -23- 2012 * ** ?/I/O = 1434/460/260 ** *Continued WSR from 07 -22- 2012 * ** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped a total of 5211 gal. of EC9360A Surfactant since start of project. Total job average = 21.6 gpd Pumped a total of 24959 gal.of EC9378A Polymer since start of project. Total job average = 104.4 gpd Job Complete 7/23/2012 FWHP = 1434/460/260 SV= CLOSED WV,SSV,MV =OPEN IA,OA =OTG . r ° TREE = CM/ • SAF TES: "*'PM ONLY - NO MI INJECTION W 09 -12 ELLHEAD= FMC ALLOWED"'" I ACTUATOR = BAKER C __ KB. ELEV = 54' BF. fl EV = 1 2100' H5-12" HES X NIP, ID = 4.562" I KOP = 2969' 20" CONDUCTOR, 111' Max Angle = 63° it 10212' 04# H-40 Datum MQ = 12357 I 11325' , - 15 - 112" HES X NIP, ID = 4.567' Datum 'Rib = 8800' SS 0 = 19.124" 113 -3/8" CSG, 72#, IM-80 BTRS, ID = 12.347' H 2708' I 11346' H 9-5/8" X 5-1/2" BKR S-3 FKR, ID = 4.760" I 11371' - 15-12" HES X NIP, ID = 4.567' I (5 12 TBG, 17 #, L -80 MI, .0232 bpf, ID = 4.897' H 11432' 11447' H 9 -5/8" X 5-1/2" UMQUE OVERSHOT 1 1 5 12 TBG STUB (03/06/09) H 11440' I I 11472' I BKR PBR ASSY, ID = 4.750" I Minimum ID = 2.376" @ 12664' _ 1 11500' j-I9 -5/8- x 5-1 /2' BKR SAB PKR 1D = 4.750" 2.812" AVA BPC SLEEVE ► ► a 11606' I-{7" MILLOUT EXTENSION, ID = 6.00" 11512' H7' x 5-1/2" XO, ID = 4.85' 5-1/2" TBG -PC, 17 #, L -80 AB-M SRD, 11675' .0232 bpf, 10 = 4.892' 11634' - - H5 -1/2" OTIS X NIP, ID = 4.562' ITOP OF 7" LNR H 11821' 1 I 11675' - 15-1/7 X 4-1/7' X0,10 = 3.958" I 1 19 -5/8" CSG, 47 #, N- 80/S0095, 0 = 8.681" H 12129' I 12405' H 4-1/2" AVA BPL MP, ID = 3.759" I IIII 12405' H 3.812" AVA BPI SLV, 10 = 3.35" (11/27/11)) I m 12411' -7" X4 -112" BKR FB -1 PKR, ID = 4.00" 14 -1/2" TBG, 12.6#, L -80, .0152 bpf, ID= 3.958" H 12411' 0 ' vv/SNAP LATCH SEAL ASSY, ID = 3.00" 1 12415' H5 -1/2" MILLOUT EXTENSION, ID= 4.50° 1 PERFORATION SUMMARY 12420' H 5.117' X 3- 12"x0, ID = 2.997' I REF LOG: BHCS ON 06/02/77 ANGLE AT TOP PERF: 42° @ 12378' ' 12564' H 3-12" AVA BR. NIP, ID = 2.697" I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE re 12564' I-I 2.812' AVA BPC SLV, ID= 2.375" (1127/11) I 2 -1 /8" 4 12378 - 12408 0 06/04/84 I 12574' I - 7' X3-1/2" BKR FBA PKR, ID = 4.00" 3-1/8" 4 12424 - 12457 0 09/07/77 3-1/8" 4 12472 - 12479 0 09/07/77 ►Z� ►�� wdSNAP LATCH SEAL ASSY, ID = 3.00" 3-1/8" 4 12491 - 12498 0 09/07/77 12678' - 15.1/2" MILLOUT EXTENSION, ID = 4.50" 1 3-1/8" 4 12513 - 12532 0 09V07/77 3-1/8" 4 12554 - 12570 0 09/07/77 12580' IH5 -12" X 3-12" XO, ID= 2.992"1 3-1/8" 4 12587- 12602 0 09/07/77 3-1/8" 4 12600 - 12620 0 04/07/95 12583' H 3.12" CAMCO DS MP, ID = 2.562' 1 3-1/8" 4 12612 - 12617 0 09/07/77 3-1/8" 4 12628 - 12645 0 09/07/77 I 12686' 1--13-1/2" BKR SHEAROUT SUB I 12587' - 13 -1/2" WLEG, ID = 2.992' I 1 3-1/2" TBG -PC, 9.2#, J -55, .0087 bpf, ID = 2.992' H 12587' ' 12586' I - IELMD TT LOGGED 5/3/95 IPBTD H 12706' 11111111 111111111 17" LNR, 29 #, N-80/500-95, .0371 bpf, ID = 6.184" H 12790' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 TD 12800' . 1 . 1.1.1.1.1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06111177 ROWAN 34 ORIGINAL COMPLETION 04/01/10 SWC/SV BPI C/O (03/25/10) WELL: 09-12 10/24186 WW1 RWI • 12/16/11 WEGPJC SET BPC & BPI SLV'S (1127/11) PERMIT No: 9770070 03109109 N4ES RWO API No: 50- 029 - 20239 -00 03/10/09 PJC DRLG CORRECTIONS SEC 7, TON, R16E, 1346' FSL & 75' RM. 04/30/09 DB DRLG DRAFT CORR (07/10/09) 06/10/09 PP/JMD PERF CORRECTIONS f BP Exploration (Alaska) 20- DEC -2011 • ����� F -05 5843 Alaska Data & C onsulting ServicBINeC -0s 0084 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 09 -18 BVYC -00017 SLIM CEMENT MAP TOOL 26- Nov -11 1 1 MPS -01A BY05 -00003 ISOLATION SCANNER 25- Nov -11 1 1 1 A LEAK DETECTION LOG 19- Nov -11 1 1 P1 -03 BINC -00082 PPROF W/ DEFT & GHOST 17- Nov -11 1 1 17 -19A BJGT -00082 SBHPS 17- Nov -11 1 1 09 -12 BD88 -00183 MEMORY LDL j 77 — 0 07 28- Nov -11 1 1 C -02 BYS4 -00005 PRIMARY DEPTH CONTROL 16- Nov -11 1 1 04 -350 BYS4 -00006 USIT 16- Nov -11 1 1 GC -2E BYS4 -00011 RST WATERFLOW 6- Dec -11 1 1 15 -09A BINC -00085 PRIMARY DEPTH CONTROL 8- Dec -11 1 1 09 -17 BAUJ -00104 MEMORY INJECTION PROFILE 30- Nov -11 1 1 MPE -12 BD88 -00185 MEMORY INJECTION PROFILE 14- Dec -11 1 1 16 -03 BG4H -00099 INJECTION PROFILE 28- Oct -11 1 1 MPL -24 BUTT -00004 MEMORY INJECTION PROFILE 6- Aug -11 1 1 2- 50/U -08 BD88 -00184 MEMORY IPROF W /DEFT GHOST 11- Dec -11 1 1 A -11 BSM4 -00018 INJECTION PROFILE 30- Oct -11 1 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 SCANNED MAR t 'Ii' schfunherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job N Log Description NO. 5600 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Shartzer 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date SL Color CD P1-1 f 05-31A ECRU -00047 PRODUCTION PROFILE B9RH-00032 RST GRAVEL PACK 08/23/10 08/12/10 1 1 1 1 1 Z3A BAUJ-00041 MEM INJECTION PROFILE 08/26/10 1 1 02 BBKA-00051 INJECTION PROFILE 08/30/10 1 1 NK -07A BBKA-00052 LDL Q Q 06131/10 1 1 Z -01B BCRD-00052 GLS 08/30/10 1 MOLD 1 Z-29 BCRD-00051 PRODUCTION PROFILE 08/29/10 1 1 Z-24 BCRD-00048 PRODUCTION PROFILE 08/26/10 1 1 E -02B BAUJ-00030 MCNL { 06/25/10 1 1 E-37AL1 r BDR-00028 MCNL07/10/10 1 { 1 P-28 t0AKA0133 OH MWD/LWD EDIT 06/12/10 2 1 BP Exploration (Alaska) Ina w"• V , J,�,,,'•� ^1'u nG 1 Vn""V v"c yvr r c�y� V- Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 It° `"� kN, ' 09/10/10 • • • • Page 1 of 2 Regg, James B (DOA) ~ ~~~_ pv~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, April 29, 2009 10:00 AM To: Regg, James B (DOA) Cc: robert.noble@alaska.gov; NSU, ADW Well Integrity Engineer Subject: UPDATE:09-12 Attachments: 09-12 TIO Plot 04-29-09.doc ~ Jim, 5T~-s ~ 1 ~:~ As seen in the attached TIO plot, the OA has remained stable at ~500 psi since it was bied on 04/21/09. / Please let me know if you feel further action is required on this weil. !~J 0 C~t'~~~ !~ , ~u ~ ~ , Thank you, ~ ~~o ~ ~_~,~ Andrea Hughes ~ ~~ , ~:~ . . ~ :h~ y a.... ~~~ ~i~t _ ... GD ~~ ... 'U "l ~ ~ U i:*a. From: NSU, ADW Well Integrity Engineer Sent: Sunday, April 19, 2009 8:28 PM To: Regg, James B (DOA) Cc: Noble, Robert C(DOA); NSU, ADW Well Integrity Engineer Subject: RE: MIT PBU 09-12 Hi Jim, As part of the pre-rig preparation, the OA is liquid packed and tested to ensure there are no unknown surface casing leaks and to remove as much gas (energized fluid) from the OA prior to moving the rig onto the well. The OA pressure increase seen during the test resulted from the balloning pressure from the IA imposed on to the OA. I've included a TIO plot for reference. As seen in the plot, there is a differential between the IA and OA pressures since the well was placed on line. Again, the OA pressure is high due to thermal effects on a liquid packed annulus. We will bleed the OA pressure and send another update next week. Thank you, Anna ~Du6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-51Q2 Pager: (907) 659-5100 x1'154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] 8/6/2009 PBU 09-12 PTD 177-007 4/29/2009 a.~~ 3,OOfJ I 2.~0 1,OOC1 TIO Plot -~ Tbg -f- L~ ~ OA OOA -+- OOOA ~- On ~ • 01J31i09 02l07J09 02?14J09 02l21J09 02i281~9 03l07103 Q~?14J09 03/21/09 L13128l09 04104J03 04!11109 0~%18I09 04l25i09 • ~ Page 2 of 2 Sent: Thursday, April 16, 2009 2:07 PM To: NSU, ADW Well Integrity Engineer Cc: Noble, Robert C (DOA) Subject: MIT PBU 09-12 Inspector witnessed MIT on 4/9; attached is copy of his report. There was a significant pressure increase in OA during MITIA; please review test results and respond with your findings. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 8/6/2009 MEMORANDUM To: Jim Regg ~~~~• !.~-~Z~~~~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Agri] 15, 2009 SU$JECT: Mechanical Integrity Tarts BP EXPLORATION (ALASKA) INC 09-12 PRUDHOE BAY UNIT 09-12 Src: Inspector ~vrnv_rnNFmFNTiAi, Reviewed By: P.I. Suprv )~~,- Comm Well Name: PRUDHOE BAY UNIT 09-12 API Well Number: 50-029-20239-00-00 Inspector Name: Bob Noble mitRCN090413052442 Insp Num: permit Number: 177-007-0 - Inspection Date: 4!9/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-12 Type ~~~ W TVD 8174 ~ 360 2500 2490 2490 p T 1770070 TypeTest sPT Test psi 25~ ~ ~A 645 825 905 945 Interval 1~T`u- P/F P % Tubing ~~ iooo Ioo° 1000 Notes: OA- ~S5i,1,~ R'~'c"-Se- cx~ bu~-ci i~ ~c l (~x~h~ ~,~~,~~~ p~ ssw~ ~~. ~ ~ ~ ~~a~ ~-- Sze e~.~c~-~A ~,r~ ~ ; ~ (1`t(ze~: t Y F y ~~i,.~f ,Pi ~ ,~ ~ ~ 1~ f/, ~5 Wednesday, April 15, 2009 Page 1 of 1 • • Page 1 of 1 Regg, James B (DOA) _... _ From: Sent: To: Cc: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sunday, April 19, 2009 8:28 PM K l t q~ Z~~Cr`~ Regg, James B (DOA) Noble, Robert C (DOA); NSU, ADW Well Integrity Engineer Subject: RE: MIT PBU 09-12 ~ ~ Attachments: 09-12 TIO plot.doc / ~ ?7-LtJ7 ~~ Hi Jim, As part of the pre-rig preparation, the OA is liquid packed and tested to ensure there are no unknown surface casing leaks and to remove as much gas (energized fluid) from the OA prior to moving the rig onto the well. The OA pressure increase seen during the test resulted from the balloning pressure from the IA imposed on to the OA. I've included a TIO plot for reference. As seen in the plot, there is a differential between the IA and OA pressures since the well was placed on line. Again, the OA ressure is high due to thermal effects on a li uid packed annulus. We will bleed the OA pressure and send another up ate next week. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (90?) 659-5100 x1154 ~~'~a~~ APB ~ ~: ~~~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, April 16, 2009 2:07 PM To: NSU, ADW Well Integrity Engineer Cc: Noble, Robert C (DOA) Subject: MIT PBU 09-12 Inspector witnessed MIT on 4/9; attached is copy of his report. There was a significant pressure increase in OA during MITIA; please review test results and respond with your findings. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 4/20/2009 RE: OPERABLE: MPJ-02 (PT~#1900960) IA x OA Differential Estab~ed Page 3 of 3 Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 4/20/2009 PBU 09-12 PTD #1770070 4/19/2009 TIO Pressures d n00 3,000 2A00 7,ano ~o~ ~ Tbg -! IA -~ OA OOA ~- OOOA -~ On _. STATE OF ALASKA APR ~ ~ 209 ~ _~ ALA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPE~TIONS~'~~~`a QII ~~'' a,~~, ~~~tii~la 1. Operations Performed: ^ Abandon ®Repair Well , ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 177-007 - 3. Address: ®Service - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20239-00-00_ 7. KB Elevation (ft): 54, _ 9. Well Name and Number: PBU 09-12 8. Property Designation: 10. Field /Pool(s): ADL 028345 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 12800' - feet true vertical 9188' ~ feet Plugs (measured) 11634' Effective depth: measured 12706' feet Junk (measured) None true vertical 9116' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1530 520 Surface 2708' 13-3/8" 2708' 2708' 4930 2670 Intermediate 12129' 9-5/8" 12129' 8687' 6870 4760 Production Liner 969' 7" 11821' - 12790' 8470' - 9180' 8160 7020 ~~~~ APR ~~ ~~~ Perforation Depth. MD (ft): Below Plug: 12378' - 12645' Perforation Depth TVD (ft): 8869' - 9070' T Si i bi d d d th d s-vz°, n# X a-~rz°, ~zsu X s-~n°, sz# L-80 / J-55 ~ 12587 u ze, gra ng ze (s e, an measure ep ): Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker'S-3' packer; 9-5/8" x 5-1/2" Baker'SAB' 11346'; 11500'; 12411'; ' " " ' " " ' ' packer; Baker FB-1 packer; 7 x 3-1/2 FB-1 7 x 4-1/2 Baker 12574' acker 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ®WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 308-445 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: ~ Signature Phone 564-4628 Date D7~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~ p~€~ ~ Submit Original Only d.,_, • 09-12, Well History (Pre Rig Workover) Date Summary 01/15/09 WELL S/I ON ARRIVAL. PULLED 5 1/2" WRP FROM 73' SLM. SET 5 1/2" JUNK CATCHER ON PX PLUG @ 11614' SLM. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 01/16/09 T/I/O = 300/350/VAC Temp = S/I CMIT-TxIA PASSED to 4000 psi. MIT-OA PASSED to 2000 psi --2nd attempt-- (Pre RWO). CMIT-TxIA: Pressured up TxIA with 12 bbls meth. TxIA lost 40/0 psi in 1st 15 min and 10/0 psi in 2nd 15 min for a total loss of 50/0 psi in 30 min test. Bled back to starting pressures. MIT- OA: Pressured up OA with 2.5 bbls crude. OA lost 80 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 120 psi in 30 min test. Bled pressures back. Final WHPs 250/300/0. SV, WV, SSV =Shut MV, IA, OA =Open. 01/30/09 T/I/0=350/450/0+, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS), pre RWO. PPPOT-T: Hoke valve installed in test port, AWGRS (1-10-03) indicates test void plastic packed. Functioned LDS, all moved freely (1.75"). Pressured up against plastic to 5000 psi for 30 min test (1/4 gal fluid), lost 0 psi in 30 min. Bled void to 0 psi. PPPOT-IC: Hoke valve installed in test port, AWGRS (1-10-03) indicates test void plastic packed. Functioned LDS, 2 were tight, 1 left ran out. 1 LDS is frozen to gland nut, unable to break free, this assembly should come out OK, will need to safe well out before removal. All but 3 LDS functioned normally. Pumped up against plastic in void, caught pressure immediatly. Pressured to 3500 psi for 30 min test, lost 0 psi in 30 min. Bled to 0 psi. 02/01/09 T/I/0= 350/450/20. Bleed IA & OA to 0 psi, pre LDS removal (RWO). OA & IA FL @ surface. Bled IAP from 450 psi to 0 psi in 4.5 hours. Bled OAP from 20 psi to 0 psi in 2 hours. During bleed TP decreased 190 psi. Monitored for 30 minutes, WHP's unchanged. Final WHP's = 160/0/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 02/02/09 T/I/0=350/0/0, Temp=S1. Repair damaged LDS. 1 LDS on casing head is corroded to gland nut. Attempts to separate failed, DHD maintaining open bleed on IA and OA. Removed LDS, installed new LDS/gland nut assembly. Test void is plastic packed, unable to get effective pressure test. 02/02/09 T/I/O = 160/10/5. Temp = SI. Monitor WHPs post bleed (pre RWO). IA & OA have integrals installed. TP unchanged, IAP increased 10 psi, OAP increased 5 psi overnight. Bled IAP & OAP to 0 psi. Monitored pressures for 30 min. IAP & OAP unchanged. Final WHPs = 160/0/0. SV, WV =closed. SSV, MV =open. IA, OA valves = OTG. 02/06/09 WELL S/I ON ARRIVAL. T=50 PSI, RU ELINE FOR 4.15" JET CUTTER. 02/07/09 WELL SHUT-IN ON ARRIVAL. T/I/O = 50/0/0 PSI. RU ELINE, 4.15" POWER CUTTER. POWER JET CUTTER DEPTH = 11445', CCL TO CUTTER = 14.3', CCL STOP DEPTH = 11430.7'. FINAL T/I/O = 200/100/0 PSI. FINAL VALVE POSITIONS, MASTER OPEN, SWAB CLOSED, SSV OPEN, I/O OTG. JOB COMPLETE. 02/14/09 T/I/O = 200/0/0 Temp = S/I Circ out TBG & IA, CMIT Tx IA to 2000 psi, MIT OA to 2000 psi. (Pre RWO) Prepare job site for circ-out. 02/15/09 Circ out TBG & IA, CMIT Tx IA to 2000 psi PASSED, MIT OA to 2000 psi. PASSED. (Pre RWO) Pumped 10 bbls of neat meth followed by 1194 bbls of 1 % KCL and a freeze protect of 135 bbls diesel down TBG taking returns up IA through hardline jumper to the flow line of 09-11. U-tubed diesel freeze protect between TBG and IA. Pumped 5.2 bbls DSL down TBG to pressure up the TBG and IA to 2000 psi. In 15 minutes TBG/ IA lost 50/30 psi. In second 15 minutes TBG/IA lost 10/10 psi for a total loss of 60/40 over 30 minutes. Bled TBG/IAP (6 bbls). Pumped .5 bbls crude down OA to pressure up to 2000 psi. OA lost 40 psi in 15 minutes and 20 bbls in second 15 minutes. Total pressure loss over 30 min was 60 psi. Bled OAP (.5 bbls). Valves left in following positions, SV & WV's left S/I. SSV, MV, IA & OA left OTG. Tags hung upon departure. FWP's = 0/0/0. Page 1 of 1 • BP EXPLORATION Operations Summary Report Legal Well Name: 09-12 Common Well Name: 09-12 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To ,Hours ', Task Code NPT ~, 2/28/2009 00:00 - 01:00 1.00 RIGD P 01:00 - 03:00 2.00 RIGD P 03:00 - 05:30 2.50 RIGD P 05:30 - 09:30 I 4.001 RIGD I P 09:30 - 11:00 1.50 RIGU P 11:00 - 13:30 2.50 RIGU P 13:30 - 15:30 I 2.001 WHSUB I P 15:30 - 15:45 0.25 PULL P 15:45 - 18:00 2.25 PULL P 18:00 - 18:30 0.50 PULL P 18:30 - 19:00 0.50 PULL P 19:00 - 20:00 1.00 WHSUB P 20:00 - 23:00 ~ 3.00 WHSUB P 23:00 - 00:00 1.00 BOPSU P 3/1/2009 00:00 - 01:30 1.50 BOPSU P 01:30 - 02:30 1.00 BOPSU P 02:30 - 10:30 8.00 BOPSU P 10:30 - 22:00 11.50 BOPSU N WAIT 22:00 - 22:30 0.50 BOPSU N 22:30 - 23:30 1.00 BOPSU N 23:30 - 00:00 0.501 BOPSUF{ N RREP Start: 2/16/2009 Rig Release: 3/9/2009 Rig Number: Page 1 of 6 Spud Date: 5/3/1977 End: 3/9/2009 Phase Description of Operations PRE R/D rig & equip from 9-34a well. PRE Scope down & lower derrick. Con't to R/D equip. PRE Con't to R/D. Pull rig off well. Spot up trucks & prep to move to 9-12i. PRE Move rig sub, pits, pipe shed & camp to 9-12i. Beging spotting in rig. Spot and center Sub Base over Well. Spot Pits and Pipe shed. Spot and set up Camp. PRE Raise and scope up Derrick. spot tiger Tank. PRE Rig up lines to Tiger Tank and Injection Tree. Take on first load of Sea Water. Accept rig at 1100-hrs on 2/28/2009. DECOMP Pick up Lubricator and test to 500 psi. Good test. Pull BPV and lay down lubricator. TP = 0, IA = 0, OAP = 0. DECOMP PJSM. Topic discussed, Well Kill. DECOMP Pressure test lines at 250/3,500 psi. Circulate Well with Hot Sea water at 5 BPM. 670 psi. Pumped total of 770 bbls. OAP increased to 670 psi. No gas to surface noted. DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. DECOMP Monitor well. Begin R/D lines. DECOMP Drain stack. Install TWC. Pressure test from below to 1000 si. Pressure test from above to 3500 psi. Charted testing. DECOMP Bleed off hanger void & control lines. N/D tree & adapter flange. Check LDS. Install ISA Blanking Plug. DECOMP Raise & level rig. N/U BOPE. DECOMP Finish raising & leveling rig. N/U BOPE. DECOMP Service choke manifold & mud cross. R/U test equip. DECOMP Pressure test BOPE. Test witnessed by John Crisp w/ AOGCC. LP 250 psi, HP 4000 psi. Having problems getting straight line test on Blowout Preventer. No visible leaks or fluid movement in the stack. No visible fluid movement coming from the Inter-Annulus. Call out FMC Tech to pull Blanking Plug from top of BPV. Inspect and found no real noticalbe problem. Re-build Blanking Plug and re-install. Double check Lock Down Screws and Packing Gland Nuts. No problems. Install Blanking Plug. Attempt BOPE test once again with some what better results. Abort BOPE testing for the time being as it appears that pressure is slightly seeping by the Tubing Hanger. Continue with testing just the Choke Manifold Valves. Good tests. Discussing options with the AOGCC Rep on location (J. Chrisp), he call his boss in Anchorage and they discussed a possible waiver to allow the pulling of the Tubing Hanger and the 5 1/2" Tubing. Then setting a test plug in the tubing spool so the test could be completed without any fluid or pressure seepage. Discussed options with anchorage Engineers. DECOMP Weather has continue to deterioate. Due to high winds and blowing snow we are now in Phase 3 conditions, Slope wide. Work has been suspended. Continue to maintain Rig in a safety stand-down mode. Went to Phase II @'2145 hrs. Wait on crew change. DECOMP Crew change. Srvice rig. Chack PVT alarms. Inspect derrick. DECOMP Con't to test BOPE. Test annular w/ 3 1/2" test jt. LP 250 psi, HP 3500 psi. Att4mpt to test VBRs w/ 5 1/2" test jt. VBRs leaking. Drain BOP stack. DECOMP Change out VBRs w/ 5 1/2" fixed rams. Printetl: 3/16/2009 1:47:36 PM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: 0 9-12 Common W ell Name: 0 9-12 Spud Date: 5/3/1977 Event Nam e: WORKO VER Start : 2/16/2009 End: 3/9/2009 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 3/9/2009 Rig Name: NABOB S 4ES Rig Number: Date From- To Hours I! Task Code NPT II Phase ! Description of Operations 3/2/2009 00:00 - 00:30 0.50 BOPSU N RREP DECOMP Finish changing out VBRs to 5 1/2" fixed bore rams. 00:30 - 01:30 1.00 BOPSU P DECOMP Pressure test 5 1/2" rams w/ test jt. LP 250 psi, HP 4000 psi. Pressure test ram doors LP 250 psi, HP 4000 psi. Perform Koomey test. 01:30 - 04:00 2.50 WHSUR P DECOMP R/U & pull ISA dart valve. R/U lubricator & test to 500 psi. Pull BPV & UD same. 04:00 - 06:00 2.00 PULL P DECOMP PJSM. P/U & M/U 5 1/2" 2x grapple spear & engage 5 1/2" tubing below hanger. BOLDS. Prep to Pull hanger to floor. 06:00 - 07:30 1.50 PULL P DECOMP Pulled Tubin Han er. Han er broke free at 125K. Pulled Tubing Hanger to floor at 160K with no problems. Lay down Spear assembly. Did not see the hole in any Pup Joints below the Tubing Hanger. Lay down Tubing Hanger and Pup Joint. 07:30 - 10:00 2.50 PULL P DECOMP Circulate Well at 6.0 bpm/260 psi total volume pumped, 770 bbls. Monitor Well dead. (Rigged up Spooling Unit while circulating). 10:00 - 14:00 4.00 PULL P DECOMP Sin le down 5 1/2", 17 Ib/ft L-80 LTC tubin in Pipe Shed. Spooled dual control line to SSSV. Recovered 54 Jts tbg, Dual Control Line complete, and all 31 Bands. Lay down SSSV Assembly. 14:00 - 14:45 0.75 PULL P DECOMP Rig down Spooling Unit. Rig down 5 1!2" handling equipment. Clear and clear floor. 14:45 - 18:00 3.25 DHB P DECOMP Pick u Halco 9 5/8" x 5 1/2" RTTS Storm Packer.. Had trouble getting Packer through Stack. However, it not the Packer. Tubing tagging down hole. Lay down Packer. Pull one more joint of 5 1/2". Run back in hole. Joint tagged with 20' ran back in, confiriming that the "Jet Cut" is tagging casing collars. Repeated same with a second joint with same results. Lay down joint. Pick up a joint of Drill Pipe tag and work "tag spot" until clean. Lay down Drill Pipe Joint. Pick-up Strorm Packer and run in hole with no further problems. Set Storm Packer at 34' 14' below wellhead . 18:00 - 18:30 0.50 PULL P DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 20:00 1.50 PULL P DECOMP Hold weekly safety meeting w/all hands. Discuss recent incidents, 5x5 program & rig safety issues. 20:00 - 21:00 1.00 BOPSU P DECOMP Drain & ND BOP stack. Set back BOP stack in cellar. Two barriers are 1) tested PX plug at 11.634' and 2) tested Storm packer at 34'. 21:00 - 22:30 1.50 WHSUR P DECOMP BOLDS. ND tubing spool. Remove secondary annulus valve. Attempt to pull free. Spool stuck. Apply steam to tubing spool. PU and Pull tubin s ool free. Packoff remained in wellhead. 22:30 - 23:30 1.00 BOPSU P DECOMP Hold PJSM. RILDS on packoff. PU BOP stack and MU on casing spool. RU BOP stack scaffolding. 23:30 - 00:00 0.50 BOPSU P DECOMP Change out 5" fixed rams to 3-1/2" x 6" VBRs. 3/3!2009 00:00 - 00:30 0.50 BOPSU P DECOMP Finish changing out 5-1/2" fixed rams to 3-1/2" x 6" VBRs. 00:30 - 01:30 1.00 BOPSU P DECOMP Remove Dutch system flange from BOP stack. Install annular lifting device on Hydril. 01:30 - 08:30 7.00 BOPSU P DECOMP Work on annular preventer -replacing damaged seals. 08:30 - 09:30 1.00 BOPSU P DECOMP Nipple down BOP and set stack back on stump. 09:30 - 11:30 2.00 WHSUR P DECOMP Attempt to pull 9-5/8" casing packoff. No go. Nipple down FMC 13-5/8" 5M tubing spoo . 11:30 - 12:30 1.00 WHSUR N WAIT DECOMP Wait on new casing packoff to arrive. 12:30 - 15:00 2.50 WHSUR P DECOMP Install new FMC 9-5/8" mandrel casing packoff and nipple up new 13-5/8" 5M tubing spool. Test casing packoff to 5000-psi Printed: 3/16/2009 7:47:36 PM • • BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: 09-12 .Common Well Name: 09-12 Spud Date: 5/3/1977 Event Name: WORKOVER Start: 2/16/2009 End: 3/9/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/9/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours ~ Task ;«~ Code NPT j Phase 3/3/2009 12:30 - 15:00 2.50 WHSUR P 15:00 - 18:00 3.00 BOPSU P 18:00 - 18:30 0.50 BOPSU P 18:30 - 20:30 I 2.001 BOPSUR P 20:30 - 00:00 I 3.501 BOPSUR P 3/4/2009 ~ 00:00 - 01:30 ~ 1.50 BOPSU Fj P 01:30 - 03:30 I 2.001 BOPSUR N 03:30 - 06:00 2.50 BOPSU N SFAL DECOMP 06:00 - 08:30 2.50 BOPSU P DECOMP 08:30 - 09:00 0.50 BOPSU P DECOMP 09:00 - 09:30 0.50 PULL P DECOMP 09:30 - 10:30 1.00 DHB P DECOMP 10:30 - 18:00 7.50 PULL P DECOMP 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 21:00 2.50 PULL P DECOMP Description of Operations DECOMP for 30-minutes. DECOMP Nipple up BOPE. DECOMP Crew Change. Service Rig. Inspect Derrick. Check PVT alarms. DECOMP RU BOP test equipment. Purge lines. Perform pre-test on newly installed VBRs with 3-1/2" testjt. Also, test annular and performed BOP body test. Notified AOGCC rep, John Crisp, that we were ready to continue initial BOP test. DECOMP Perform complete BOP test with AOGCC rep John Crisp witnessing tests. Low pressure to 250-psi, High pressure to 4000-psi. Tested choke manifold and had failure of valve #12 plus a second valve. Test Choke and Kill HCRs and manuals. Tested annular to 3500-psi high pressure with 3-1/2" testjt. Test VBRs with 3-1/2" testjt. DECOMP Continue to test BOP with AOGCC rep John Crisp. Perform Koomey test and inspect nitrogen bottles. Attempt to test VBRs with 5-1/2" test jt -failed. Discussed plan forward to isolate second leaking choke manifold valve and correct VBR leak. SFAL DECOMP Isolate second valve leak. Discover choke valve #8 is leaking. Drain stack. Open ram doors and inspect VBRs. VBRs appear "brand new". Close ram doors. RIH with 5-1/2" testjt and observe closure without fluid in stack. Appears that rams are not closing all of the way. PU 4-1/2" testjt, RIH and .observe VBR closure. VBRs appear to close more completely. Fill testjt and testjt. holding fluids. Attempt to test VBRs with ~, 4-1/2" testjt. Replace choke manifold valve #12. 'Test 3-1/2" x 6" VBR's with 4-1/2" test joint. Good test. Lay down 4-1/2" test joint. Pick up 5-1/2" test joint and test VBR's to 250-psi Lo/4000-psi Hi. VBR closure on 5-1/2" test joint appears normal. Good test. Lay down 5-1/2" test joint. Pick up kelly and test upper kelly valve to 250-psi Lo/4000-psi hi. Good test. Set back and blow down kelly. While testing upper kelly valve, redressed #8 valve. Tested #8 and #12 choke manifold valves to 250-psi Lo/4000-psi Hi. Notofied AOGCC - John Crisp of successful testing and received confirmation to proceed with RWO. Blew all lines down including kill line to ~~ pits to ensure no possibilty of freezeups. Rig down store test equipment. PJSM -review POH laying down Halco storm packer and production tubing procedure and assign tasks to individuals. Pickup joint of 3-1/2" DP w/running tool and closed TIW valve and sting into 9-5/8" Halco RTTS packer with storm valve. Open storm valve and check for pressure on DP. No pressure observed. POH UD acker. POH la in 5-1/2" 17# L-80 BTC-M tubin 1 x 1 through pipe shed. 137 jts. POH at 15:00-hrs. OOH w/ 205 jts C~3 18:00 hrs Crew change. Service rig. Check PVT alarms. Inspect derrick. Con't to POOH & UD 5 1/2" 17#, L-80, BTC-M completion. Recovered 288 full jts, + 1 Cut off jt (19.07'), +1 SSSV assy, + 8' Pup & 2-1' pups. Inspected cut off jt, was belled out to 6 3/8" & sent photos to town. Printetl: 3/16/2009 1:47:36 PM • BP EXPLORATION Page 4 of 6 .Operations Summary Report Legal Well Name: 09-12 Common Well Name: 09-12 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To I~, Hours Task Code NPT 3/4/2009 21:00 - 23:00 2.00 PULL P 23:00 - 23:30 0.50 WHSUR P 23:30 - 00:00 0.50 CLEAN P 3/5/2009 00:00 - 02:00 2.00 CLEAN P 02:00 - 06:00 I 4.001 CLEAN I P 06:00 - 07:30 1.50 CLEAN P 07:30 - 10:00 2.50 CLEAN P 10:00 - 15:00 ~ 5.00 ~ CLEAN ~ P 15:00 - 17:00 2.001 CLEAN P 17:00 - 20:00 I 3.001 CLEAN I P 20:00 - 00:00 4.00 CLEAN P 3/6/2009 00:00 - 01:30 1.50 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 03:30 1.00 CLEAN P 03:30 - 05:00 1.50 FISH P 05:00 - 09:30 4.50 FISH P 09:30 - 10:30 1.00 FISH P 10:30 - 11:30 I 1.001 FISH I P 11:30 - 20:30 9.00 FISH P 20:30 - 21:00 0.50 FISH P 21:00 - 00:00 3.00 BUNCO P Spud Date: 5/3/1977 Start: 2/16/2009 End: 3/9/2009 I Rig Release: 3/9/2009 Rig Number: Phase Description of Operations DECOMP R/D tubing tools, Clear & clean rig floor. R/U to P/U BHA. DECOMP P/U running tool & install Wear Bushing. Ran in 2 LDS. UD running tool. DECOMP Load, caliper & tally BHA. DECOMP P/U & M/U BHA #1 as follows: Shoe, 2-WP Ext, W/O Boot Basket, XO, Csg Scraper, Bit Sub, Bumper Sub, Jars, P/O Sub, 9 - 4 3/4" DCs. TL = 325.81' DECOMP P/U 3 1/2" DP 1x1 & RIH w/ BHA #1. P/U &RIH w/ 85 jts @ 0500 hrs. DECOMP Cont. P/U 3 1/2" DP 1x1 &RIH w/ BHA #1. DECOMP Slip and cut drilling line. Crew change. Service rig. Check PVT's and daily derrick inspection. DECOMP Cont. P/U 3 1/2" DP 1x1 &RIH w/ BHA #1. Reciprocated scraper across 10,350' 4 times. Tag tubing stub @ 10439' with jt. #357 + 1' on jt. #358. POH UD jt. #357 and jt. #358. P/U 24' pup and kelly up. DECOMP Establish milling parameters w/kelly: P/U wt. = 165K, S/O wt. _ 112K, Rot. Wt. = 131 K, Torque @ 61 RPM = 4500-9000 ft.-Ibs. Break circulation @ 3.0-bpm @ 550-psi. pumped 40-bbl. hi-vis EP Mud Lube pill around. Dress off 5-1/2" tubing stub to 1 440'. Work dress-off assy. on and off stub until able to slide on and off stub without rotating. DECOMP Circulate well clean. Mix & pump 40 BBI Hi-Vis pill & 1 drum of E-P Mud Lube. Pump 4 1/2 BPM @ 1000 psi. Pumped total of 823 bbls. DECOMP Blow down & set back kelly. POOH & stand back 3 1/2" DP. DECOMP Finish POOH & stand back 118 stands of 3 1/2" DP. DECOMP Stand back 3 stands of 4 3/4" DCs. Break out & UD BHA #1. Inner mill had good indication of wear from dressing casing. DECOMP Clear & clean rig floor. Empty Junk Basket. Recovered -3 gals of steel cuttings intermixed w/ V. fine sand. DECOMP P/U & M/U BHA #2 as follows: S ear, XO, 8 jts PAC DP, XO, Bumper Sub, Jars, Pump Out Sub, 9 - 4 /4" DCs. TL = 552.04'. DECOMP RIH w BHA #2 on 118 stands of 3 1/2" DP. DECOMP Tag top of 5-1/2" tubing stub at 11,440' with spear bullnose. Work pipe to enter stub with spear. RIH to 11,610'. Pick up joint 3-1/2" DP with TIW valve, headpin and circulating hose. Break circulation at 1.5-bpm at 550-psi and wash down to 11,614. Set down 11 K on junk catcher and did not note any pressure increase. Picked back up 15' and then went back down and set 11 K on fish. Did this 3 more times with noticeable pump pressure increase. DECOMP POH UD 8 jts. 3-1/2" DP to get fish/spear above tubing stub at 11,440'. DECOMP Shut down #2 generator engine and replace leaking engine oil gasket on fuel pump. Strapping and rabbiting 5-1/2" completion tubing and jewelry in pipe shed simultaneous to engine repairs. Columbia Systems also making repairs on pipe skate safety system. DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. RUNCMP Finish, loading, strapping and rabbiting 5-1/2" 17# L80 TCII tbg and completion jewelry in pipe shed. Printed: 3/16/2009 1:47:36 PM i • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 09-12 09-12 WORKOVER NABOBS ALASKA DRILLING I NABOBS 4ES Date From - To ,Hours Start: 2/16/2009 Rig Release: 3/9/2009 Rig Number: Page 5 of 6 Spud Date: 5/3/1977 End: 3/9/2009 Task ' Gode NPT Phase Description of Operations 3/7/2009 00:00 - 00:30 0.50 FISH ~P 00:30 - 06:00 5.50 FISH P 06:00 - 09:00 3.00 FISH P 09:00 - 11:30 2.50 FISH P 11:30 - 14:30 I 3.00 14:30 - 15:00 I 0.50 15:00 - 16:00 I 1.00 16:00 - 18:00 I 2. 18:00 - 18:30 0.50 18:30 - 00:00 5.50 3/8/2009 100:00 - 06:00 I 6.00 06:00 - 06:30 0.50 RU 06:30 - 17:30 11.00 RU 17:30 - 18:00 0.50 RUN 18:00 - 18:30 0.50 RUN 18:30 - 19:30 1.00 RUN 19:30 - 00:00 I 4.501 RUN DECOMP PJSM on laying down DP. Remove jewelry and pups from pipe shed. Prep to POH & LD DP. DECOMP LD 3-1/2" DP to pipe shed. 200-jts of DP LD at report time. DECOMP LD 3-1 2" DP to pipe shed. DECOMP PJSM -Review laying down BHA, identify hazards and mitigations._ L/D BHA #2. Did NOT recover junk catcher on spear. Spear grapple was in catch position and shear screw indicator was intact. Small amount of metal shavings on spear. RUNCMP Rig up floor with 5-1/2" pipe handling tools, single joint compensator, single joint elevators and torque turn equipment. RUNCMP PJSM -Reviewed running premium thread tubing procedure. Identified tasks and hazards with mitigations. Reviewed running order. RUNCMP PU and RIH w/completion BHA jewelry: 9-5/8" x 5-1/2" Unique Guided Overshot, 5-1/2" HES X Nipple w/RHC-M plug body (visually verified placement of RHC-M plug body by WSL, Driller, Baker Packer tech.), 9-5/8" x 5-1/2 Baker S-3 Packer and 5-1/2" HES X Nipple. Baker-Lok'd and torque turned all connection to 4,350 ft-Ibs. RUNCMP RIH w/5-1/2" 17#, L-80 completion tubing torque turning to 4,350 ft-Ibs. and using Seal Guard thread compound. BakerLok all connections below the packer. In hole w/ 32 jts. RUNCMP Crew change. Service rig. Inspect derrick. Check PVT alarms. RUNCMP Continue RIH with 5-1/2" 17# L-80 completion tubing. Utilize torque turn services and MU all connections to optimum torque of 4350-Ibs/ft of torque. Use Jet Lube Seal Guard thread compound. 113-jts RIH at 0000-hrs. RUNCMP RIH with 5-1/2" 17# L-80 TCII completion, torque turning each connection to 4350-Ibs/ft of torque. Use Jet Lube Seal Guard thread compound on all connections. Begin cleaning tubing collars at jt #115 to ensure proper MU. (At 0200-hrs, lose 1-hr of activity due to daylight savings time) 180-jts RIH at report time. RUNCMP Service rig, check PVT's, PTSM and crew change. RUNCMP Resume RIH w/5-1/2" completion tubing: Replaced jt. #172 due to failed makeup and bad coupling. Replaced jt. #182 due to 1-1/2" threads showing after makeup. Makeup torque was good on original joint #182, but replaced suspect joint anyway. Current ambient temperature = -40F. Instituted extreme cold weather operating precautions for personnel and equipment. Replaced jt. #190 due to repeated bad makeup. Replaced jt. #236 due to bad makeup. Tag tubing stump with jt. #274 at 11,433' with overshot guide. Swallowed stub and observed 1st and 2nd set of screws shearing with 6.5' of jt. #275. Set 15K on no-go. POH L/D jt. #275 and jt. #274. Spaced out string to land no-go 3' off of top of stub with pups as follows: 9.81', 7.79' & 4.42. Picked up pups, jt. #273 and tubing hanger. RUNCMP Land com letion. RILDS. P/U Wt = 157K. S/O Wt = 120K. RUNCMP Crew change. Service rig. Inspect derrick. Check PVT alarms. RUNCMP R/D 5-1/2" tubing handling and torque turn equipment. R/U lines to reverse circulate. RUNCMP Reverse in 265-bbls of 120-degree seawater followed by 500-bbls of 120-degree seawater treated with Corrosion Printed: 3/16/2009 1:47:36 PM • BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: 09-12 Common Well Name: 09-12 Spud Date: 5/3/1977 Event Name: WORKOVER Start: 2/16/2009 End: 3/9/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/9/2009 Rig Name: NABOBS 4ES Rig Number: I Date From - To Hours Task Code ~ NPT Phase Description of Operations 3/8/2009 19:30 - 00:00 4.50 BUNCO P RUNCMP Inhibitor. Circulate at 3-BPM with 330-psi. 3/9/2009 00:00 - 00:30 0.50 BUNCO P RUNCMP Finish Reversing 120 degree Inhibited seawater down IA. R/D surface lines. 00:30 - 02:00 1.50 BUNCO P RUNCMP Hold PJSM. R/U Hot Oilers & test lines to 3500 psi. Heat diesel to 80 degrees & pump 160 bbls of diesel, 2 BPM ~ 320 psi. 02:00 - 03:00 1.00 BUNCO P RUNCMP R/U lines & allow Freeze protection fluids to U-tube into tubing. Hold weekly safety meeting w/ all hands. Discussed recent incidences & safety bullitins. Discuss 4es safety policies & goals as well as reviewing STOP cards. 03:00 - 06:30 3.50 BUNCO P RUNCMP R/U & drop Rod/Ball, allow to fall. Pressure up on tubing to I psi & pressure uo on annulus to 4000 psi & hold for 30-charted 06:30 - 08:00 1.50 BUNCO P RUNCMP FMC dry rod set TWC. LRS pressure test TWC to 4000-psi for 10-charted minutes. RDMO LRS. 08:00 - 10:00 2.00 BOPSU P RUNCMP ND BOPE. 10:00 - 11:30 1.50 WHSUR P RUNCMP NU adapter flange and pressure test hanger void and seals to 5000-psi for 15-minutes. 11:30 - 13:30 2.00 WHSUR P RUNCMP NU injection tree and pressure test same to 5000-psi for 15-minutes. 13:30 - 16:00 2.50 WHSUR P RUNCMP Rig up valve shop lubricator to swab valve and ressure test to 500-psi for 5 minutes. Pull TWC. Set BPV. Rig down lubricator. 16:00 - 18:00 2.00 RIGD P RUNCMP Secure cellar. Closed and secured all valves on tree including SSV. RELEASE RIG AT 18:00-HRS. rnnieo: siiorzwa rai:~orm 09-12, Well History (Post Rig Workover) Date Summary 03/09/09 T/I/O = 0/0/0 Pullled 6 3/8" CIW "J" TWC # 423 thru tree C~ 108" 1-2' ext. used. Set 6 3/8" CIW BPV # 422 so 4ES can move off well. No problems. 03/30/09 WELL S/I ON ARRIVAL. MISU, RIG UP SWCP #2, FOR POST RWO. 03/31/09 PULL B&R FROM 11,372' SLM & 5-1/2" RHC PLUG BODY FROM 11,378' SLM. ATTEMPT TO PULL 5- 1/2" JUNK CATCHER, W/ 5-1/2" GS. REC. -1 GALL. OF SAND/METAL FROM 11,613' SLM W/ 10' x 3.00" P. BAILER. 03/31/09 T/I/O = 500/0/0 Pulled 6 3/8" CIW "J" BPV# 422 thru tree, tagged C~ 110" 1-2' ext. used. No problems. 04/01/09 PULL 5-1/2"JUNK CATCHER FROM 11614' SLM (filled with sand). PULL P-PRONG FROM 11,626' SLM and 5-1/2" PX PLUG BODY FROM 11,630' SLM. RAN 2.50" DRIFT TO TD C«~ 12,562' SLM. RECOVER -5 CUPS OF SCHMOO. 04/02/09 RIG DOWN SWCP #2, POST RWO COMPLETE. WELL LEFT S/I, PAD OP NOTIFIED ON DEP. 04/06/09 T/I/O = 950/240/480. Temp =Hot. IA FL. IA FL Q surface. OA FL Q surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. Page 1 of 1 rz~E = CP/`/ WELLHEAD = ACTUATOR = FMC BAKER C KB. ELEV = 54' BF. ELEV = KOP - 2969' Max Angle = 64° @ 10114' Datum MD = Datum TVD = 12357 8800' SS DRLG DRAFT ~ ~ ~ SAFEf' ~7TES: 2100' ~-{ 5-1 /2" HES X NIP, ID = 4.562" 20" CONDUCTOR, 94#, H-40, ID = 19.124" ~ 111' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2708' Minimum ID = 2.562" @ 12583' 3-112" CAMCO XN NIPPLE 5-1/2" TBG, 17#, L-80 TCB, .0232 bpf, ~ = 4.983" 11432' 5-1/2" TBG STUB (TAGG®03/06/09) 11440' 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 1167$' TOP OF 7" LNR 11821' 9-518" CSG, 47#, N-80/S00-95, ID = 8.681" I--,1 1 4-1/2" TBG-PC, 12.6#, L-80,.0152 bpf, ~ = 3.958" ~-~ 12408' PERFORATpN SUf~MMRY REf LOG: BRCS ON 06/02/77 ANGLE AT TOP PERP. 42 @ 12378' Note: Refer to Production DB for historical erf data S¢E SPF MTERVAL O nIS z DATE 2-1/8" 4 12378- 12408 C 06/04/84 3-1/8" 4 12424 - 12457 C 09/07/77 3-118" 4 12472 - 12479 C 09/07/77 3-1/8" 4 12491 - 12498 C 09/07/77 3-118" 4 12513- 12532 C 09/07/77 3-1/B" 4 12554- 12570 C 09/07/77 3-1/8" 4 12587 - 12602 C 09/07/77 3-1/8" 4 12600- 12620 C 04/07/95 3-i/8" 4 12612- 12617 C 09/07777 3-1/8" 4 12628-12645 C 09/07/77 3-1/2" TBG-PC, 9.2#, J-55, .0087 bpf, ID = 2.992" 7" LNR, 29#, N-80/S00-95, .0371 bpf, ID = 6.184" TD I 12790' I 11325' -15-1/2" HES X NIP, ID = 4.562" 11346' 9-5/8"x 5-1/2" BKR S-3 PKR, ID = 4.760" 11371' 5-1 /2" HES X NIP ID = 4 562" , . 11447' 9-518" X 5-1/2" UNIQUEOVERSHOT " ' 5-112 BAKER PBRASSY 11472 11500' 9-5/8" X 5-1/2" BKR SAB PKR, ID = ? 11634' S-1/2" OTIS X NIP, ID = 4.562" 11675' I->7 XO 5-1 /2" X 4-1 /2", ~ = 3.958" 12ao5, I~4-1/2" AVA BPL Nom, PORTED SLV ~ = 3.759" 12411' 7" X 4-112" BKR FB-1 PKR, ID = ? 12420' 4-1/2" X 3-1/2" XO, ID = 2.992" 12~ 3-112" AVA BPC N~ ID = 2.815" I(2-18/64" HOLES) I 17" X 3-1/2" BKR FB-1 PKR, ID = ? I 3-1/2" CAMCO XN NIP, ID = 2.562" 3-1/2" BKR SHEAROUT SUB 3-1/2" WLEG, ID = 2.992" ELMD TT LOGGED 5/3/95 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/11/77 OWAN3 ORIGINALCOMPLETION 10/24/86 WW1 RWI 03/09/09 NOES RWO 03/10/09 PJC DRLG CORRECTIONS PRUDHOE BAY UNfi- WELL: 09-12 PERMIT No:1770070 API No: 50-029-20239-00 SEC 1, TION, R15E, 1345' FSL & 76' FWL BP Exploration (Alaska) • • L>•i~Cli-7~ OIL L7•1~i1 l~-7 333 W. 7th AVENUE, SUITE 100 COI~TSERQAZ`IO1~T C011'II~iISSI01~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineer Team header BP Exploration Alaska Inc. ., r, ~t , ~ ~ e , PO Box 196612 ~~"'~~~~`~ ~~~4`? ~ `~~~~' Anchorage, AK 99519-6612 ~ ~ ~ ~ d Q Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-12 Sundry Number: 308-445 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. When providing notice for a representative of the Corrunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ ' Cathy P. Fcerster Commissioner ~- DATED this ~5 day of December, 2008 Encl. I ~~ STATE OF ALASKA ' ~ y ~ ,I ~ J ~ I ALA OIL AND GAS CONSERVATION COM~SION ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,~~~ ~-~~ ~ I 0 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~ r ~ ^ Alter Casing ®Repair Well • ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ ; ^ Change Approved Program ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class:. 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 177-007- 3. Address: ®Service , ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20239-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-12 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): - ADL 028345 ~ 54' ' Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12800' - 9188' 12706' 9116' 11634' None sin n i MD TVD Urst II ru r I r 11 1 11 1 rf ce 27 1 - / " 7 8' 27 4930 2 In r edia a 1 1 -/" 1 1 9' T 687 47 P in Liner 7" 11 1' - 1 79 ' 7 ' - 1 1 0 70 0 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 12378' - 12645' 8869' - 9070' s-~n~~, """4'n~~,'Z.sx"~-'n~~, s_~a L-80 / J-55 12587' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer; 7" x 4-1/2" Baker'FB Packers and SSSV MD (ft): 11500 ; 12411'; 12574' -1' packer; 7" x 3-1/2" Saker'FB-1' packer 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 20, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564-5683 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number. Signature „~ Phone 564-5743 Date >2 ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ~1A echanical Integrity Test ^ Location Clearance ` 'y~OC~~S~~ ¢-ar--~.~~~ Other: 3S'~0 ~,,~,c_ c~~~~~c`~~ Subsequent Form Required: y~ APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Z-' ~ Form 10-403 Revised 06/20 DIAL Submit In Duplicate by Glj,~firip 09-12 Expense Rig Workover • Scope of Work: Pull 5-'/z" L-80 completion, Replace Casing Pack-offs, run 5-1/2" L-80 "stacker-packer" completion. MASP: 2443psi Well Type: Injector Estimated Start Date: January 20, 2009 Production Engineer: Patti Phillips Intervention Engineer: David Bjork Pre-Rig Work Reauest: S 1 Drift tubin for 5-1/2" Power Jet cut. Set ~unk catcher on to of PX lu at 11,634' MD. F 2 Fluid-pack wellbore and CMIT TxIA to 4,000 psi, MIT-OA to 2,000psi record LLR as necessar. E 3 Power Jet cut 5-'/z" L-80 tubing at 11,445' MD, in the middle of the first full joint above the PBR. Reference tubin tall dated 10/22/1986. F 4 Circulate well with 8.6 seawater and freeze rotect to 2000'. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-'h" x 6" VBR pipe rams. Pressure test Blind Rams and VBR's to 4000psi, Annular to 3,500psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-'/z" tubing string to the cut. 3. Change 9-5/8" casing packoff. 4. RIH and dress tubing stub. 5. Run 5-'h" L-80 stacker packer completion with Baker S-3 packer. Position packer at11,350' MD. 6. Displace the IA to packer fluid and freeze protect to 2000' MD. 7. Set the Packer, test tubing and IA to 4,000 psi. 8. Set BPV. ND BOPE. NU and test tree. RDMO. KB. ELEV = 54' BF. ELEV =, ? KOP = ~ 2969' Max Angle = 64 @ 10014' Datum MD = 12357' Datum TV D= 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 2.562" @ 12583' 3-1 /2" CAMCO XN NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" H 11675' TOP OF 7" LNR 11821' 9-5/8" CSG, 47#, N-80/S0095, ID = 8.681" 12129' 4-1/2" TBG-PC, 12.6#, L-8Q, .0152 bpf, ID = 3.958" ~~ 12420' 3-1l2" TBG-PC, 9.2#, J-55, .0087 bpf, ID = 2.992" ~--1 12587' PERFORATION SUMMARY REF LOG: BRCS ON 06/02/77 ANGLE AT TOP PERF: 42 @ 12378' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 12378 - 12408 C 06/04/84 3-1/8" 4 12424 - 12457 C 09/07/77 3-118" 4 12472 - 12479 C 09/07/77 3-1/8" 4 12491 - 12498 C 09/07/77 3-1/8" 4 12513 - 12532 C 09/07/77 3-1/8" 4 12554- 12570 C 09/07/77 3-1/8" 4 12587 - 12602 C 09/07/77 3-1 /8" 4 12600 - 12620 C 04/07/95 3-1/8" 4 12612 - 12617 C 09/07/77 3-1/8" 4 12628 - 12645 C 09/07/77 7" LNR 29#, N-80/SOO-95, .0371 bpf, ID = 6.184^ 12790' ITD 1 SAF NOTES: *""PWI ONLY - NO M I INJECTION O ~ - ~ ~ ~?"TxIA LEAK FOUND AT BOTTOM OF TBG 68' ~~ 5-1/2" CAM WRDP-2 SSSV NIP, ID = 4.562" 11472' 11 5-1/2" BAKERPBRASSY 11500' 9-5/8" X 5-1/2" BKR SAB PKR ID = ? 11634' 11634' 5-112" OTIS X NIP, ID = 4.562" 5-1/2"? PX PLUG (01/22/08) 11675' XO 5-112" X 4-1/2", ID = 3.958" 12405' 11 4-1/2" AVA BPL NIP, PORTED SLV ID = 3.759" 12411' 7" X 4-1/2" BKR FB-1 PKR, ID = ? 12420' 4-1/2" X 3-1/2" XO, ID = 2.992" 12564' 3-1/2" AVA BPC NIP ID = 2.815" (2-18/64" HOLES) "ILA/4" I--~ /" X 3-l/Z° tSKK tC-l YKK, N = ! 12583' 3-1/2" CAMCO XN NIP, ID = 2.562" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/11/77 ORIGINAL COMPLETION 06/01/07 RDW/PA WANERSF?Y NOTE DELETED 10/22/86 LAST WORKOVER 03/15/08 JINVTLH PX PLUG SET (01/22/08) 12/28/05 TWS/TLH TTP PULLED 10/13/08 PJP/PJC PERF CORRECTION 01/06/06 RPWPJC WANER SFTY NOTE UPDATE 12/05/06 GJF/TLH PXX PLUG SET 01/04/07 GJF/TLH PXX PLUG PULLED 3-1/2" BKR SHEAROUT SUB 3-1/2" WLEG, ID = 2.992" ELMD TT LOGGED 5/3/95 PRUDHOE BAY UNfT' WELL: 09-12 PERMff No: 1770070 API No: 50-029-20239-00 SEC 7, TION, R16E, 1346' FSL & 74' FWL BP Exploration (Alaska) KB. ELEV = 54' BF. ELEV = ? KOP = ti 2969' Ma1~Angle = 64 @ 10014' Datum MD = 12357' Datum TV D= 8800' SS O ~ ~ ~ ~ SAF NOTES: Proposed 2100' S-1 /2" HES X NIP, ID = 4.562" 13-3/8" CSG, 72#, N-80, ID = 12.347" 2708' I 11335' S-1/2" HES X NIP, ID = 4.562" 5-112" 17#, L-80 TC-II 11445' 0.0232 bpf, ID=4.892" 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I TOP OF 7" LNR 11821' 9-5/8" CSG, 47#, N-80/S0095, ID = 8.681" 12129' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 12420' Minimum ID = 2.562" @ 12583' 3-1 /2" CAMCO XN NIPPLE 3-1/2" TBG-PC, 9.2#, J-55, .0087 bpf, ID = 2.992" 12587' PERFORATION SUMMARY REF LOG: BHCS ON 06/02/77 ANGLEAT TOP PERF: 42 @ 12378' Note: Refer to R'oduction DB for historical erf data SIZE SPF INTERVAL O n!S z DATE 2-1/8' 4 12378-12408 C 06/04/84 3-118' 4 12424 - 12457 C 09/07/77 3-1/8" 4 12472 - 12479 C 09/07/77 3-1/8" 4 12491 - 12498 C 09/07/77 3-1/8" 4 12513 • 12532 C 09/07/77 3-1/8" 4 12554 - 12570 C 09/07!77 3-1/8" 4 12587-12602 C 09/07/77 3-1/8" 4 12600 - 12620 C 04/07/95 3-1/8" 4 12612 - 12617 C 09/07/77 3-1/8" 4 12628-12645 C 09/07/77 3-1/2"AVA BPC NIP ID = 2.815" (2-18/64" HOLES) 12574' 7" X 3-1/2" BKR FB-1 PKR, ID = ? 12583' I~ 3-1 /2" CAMCO XN NIP, ID = 2.562" 12586' I-13-1/2" BKR SHEAROUT SUB 3-1/2" WLEG, ID = 2.992" ELMD TT LOGGED 5/3/95 7" LNR, 29#, N-80/SOO-95, .0371 bpf, ID = 6.184" TD I-~ 12800' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/11/77 ORIGINALCOMPLETION 06/01/07 RDW/PA WAIVERSFTYNOTEDELETED 10/22/86 LAST WORKOVER 03/15/08 JIMITLH PX PLUG SET (01/22/08) 12/28/05 TWS/TLH TTP PULLED 10/13/08 PJP/PJC PERF CORRECTION 01/06/06 RPH/PJC WANERSFTY NOTEUPDATE 12/05/06 GJF/TLH PXX PLUG SET 01/04/07 GJF/TLH PXX PLUG PULLED PRUDHOE BAY UNff WELL: 09-12 PERMff No: 1770070 API No: 50-029-20239-00 SEC 7, TION, R16E, 1346' FSL & 74' FWL BP Exploration (Alaska) - 11350' 9-5/8"x 5-1/2" BAKER S-3 PKR - 11375' 11440' 9-5/8" X 5-1/2" UNIQUE OVERSHOT 11472' S-1/2"BAKERPBRASSY 11500' 9-5/8" X 5-1/2" BKR SAB PKR, ID =? 11634' I~ 5-1 /2" OTIS X NIP, ID = 4.562" 15-1/2"? PX PLUG (01/22/081 11675' XO 5-1/2" X 4-1/2", ID = 3.958" 4-1/2" AVA BPL NIP, PORTED SLV ID = 3.759" 12411' 7" X 4-1/2" BKR FB-1 PKR, ID = ? 14-1/2" X 3-1/2" XO, ID = 2.992" I Page 1 of 1 • Maunder, Thomas E (DOA) From: Phillips, Patti J [Patti.PhiHips@bp.com] Sent: Monday, December 15, 2008 11:41 AM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (SA1C); Cooper, Katrina N Subject: RE: DS 09-12 (177-007), Sundry 307-365 Tom, No, Seal-tite has not been attempted on the well, yet. During the prep work for Seal-tite, the WRP failed and will have to be reset. Seal-tite will be returning the first week of Jan, 2009. We plan to try and fix the well with Seal- tite, but if it does not work, we plan to work the well over during the 2009 East of Sag River ice season window. Patti From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 15, 2008 11:27 AM To: Phillips, Patti J Cc: Preble, Gary B (SAIC) Subject: DS 09-12 (177-007), Sundry 307-365 Patti and Gary, 1 am working on a sundry to workover this well. Was the Seal-tite repair authorized by 307-365 ever attempted? Thanks in advance. Tom Maunder, PE AOGCC ,may ~,,~ ` ;- f< ~ ~ C~~ 12/15/2008 09-12 (PTD #1770070) Post-tubing repair testing • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, October 14, 2008 2:27 PM To: 'NSU, ADW Well Integrity Engineer' ~Q~ ~ ~~~~~~~ Subject: RE: 09-12 (PTD #1770070) Post-tubing repair testing yes, that is preferred approach. Jim Regg AOGCC , 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, October 14, 2008 2:23 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: 09-12 (PTD #1770070) Post-tubing repair testing Jim, Is it acceptable to apply for an AA after the initial tests post-treatment pass? Thanks, Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 14, 2008 2:03 PM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: 09-12 (PTD #1770070) Post-tubing repair testing Page 1 of 2 Rule 6 provides for approving an alternate approach to demonstrating mechanical integrity. Because the well has a known tubing leak, the temporary nature of SealTite repair, and apparent susceptibility to failure based on i testing approach, you should make the request for administrative approval Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 10/14/2008 09-12 (PTD #1770070) Post-tubing repair testing ~ Page 2 of 2 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, October 14, 2008 1:10 PM To: Regg, James B (DOA) Cc: NSU, ADW Weil Integrity Engineer Subject: 09-12 (PTD #1770070) Post-tubing repair testing Jim, _i We have planned aSeal-Tite tubing repair on well 09-12 (PTD #1770070). The procedure entails squeezing a liquid sealant from inside the tubing to repair a 4.75 gpm leak. After the repair is complete, we would like to establish integrity with an MIT-T and CMIT-TxIA r th r t n MIT-IA. It is thought that testing the seal from the IA side wi isengage the Seal-Tite material and seal. If the repair does in fact work, we would like use the MIT- T/CMIT-TxIA as our UIC compliance test on all future tests. Area Injection Order 4E does not specifically state that an MIT-IA is required to prove mechanical integrity, however it has been requested that MITs be performed while on injection. Is it acceptable to use an MIT-T/CMIT-TxIA combination to demonstrate tubing/casing integrity after the repair and for 4-year testing on this well? Thank you, Andrea Hughes Well Integrity Coordinator Office: (907} 659-5102 Pager: (907) 659-5100 x1154 10/ 14/2008 • • _ ~, a, { ~ Q F ; 1 ~ ~ ~ _ ) ~'~-~ '~ 4.t..~ ~~ i..} 1., SARAH PALIN, GOVERNOR ~~ C011~3EK~,1`I011~ ~ ~c I~ 333 W. 7th AVENUE, SUITE 100 j` A l.o~~`~~•~~~1~~•iiiiii----777 Qi` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Patti Phillips ~~ (so7) 27sa5a2 Pad Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 4~~~~ DEC ~ ~ ~~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-12 ?'~ ~ Sundry Number: 307-365 Dear Ms. Phillips: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of December, 2007 Encl. 12-~0-~~ ~~ RECEIVED . v ~ ~ iaia J ` STATE OF ALASKA • DES ~ ~ ZOO7 ~~ `~~ 1~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ -' "' ~~ APPLICATION FOR SUNDRY APPROVAL Alaska Qil & Gas Cons. Commissiol~ ~n anr. ~~ ~Rn Anchorage 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe Alter casing^ Repair well ^~ Plug Perforations^ Stimulate ^ Time Extension ^ Seal Tite Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 177-0070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-20239-00-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-12 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): _ ADLO-028345 ' 54 KB - 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): 12800 ~ 9187.78 12790 9180 NONE NONE Casing Length Size MD TVD Burst Collapse Surface 2676 13-3/8" 72# N-80 32 2708 32 2708 4930 2670 Production 12098 9-5/8" 47# N-80 31 12129 31 8687 6870 4760 Liner 979 7" 29# N-80 11821 12800 8470 9188 8160 7020 Conductor 80 20" 96# H-40 33 113 33 113 1530 520 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 5-1/2" 17# L-80 30 - 11675 - - 4-1/2" 12.6# L-80 11675 - 12420 - - 3-1/2" 9.2# J-55 12420 - 12587 Packers and SSSV Type: 5-1/2" Baker SAB Packer Packers and SSSV MD (ft): 11500 4-1/2" Baker FB-1 Isolation Packer 12411 3-1/2" Baker FB-1 Packer 12574 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/18/2007 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patti Phillips Printed Name Patti Phillips Title Pad Engineer Signature s A Phone 564-4578 Date 12/4/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~~~~-x„rJ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Loc ation Clearance ^ \ t Other: ~~~.~6~~~-~j~`~ ~~ h-i'}~ ."~ ~l~ 5~~ ~~.5- ~`'~SV~~~ t~~ ~~ Subsequent Form Required: \,~`r'~ ~ ~ ~ ~ i~~' ~ ~~ ~ 2~~/ APPROVED BY '~~/ Approved by: C S ONE THE COMMISSION Date: Form 10-403 Revised 0612006 v ~~ U ~, v f 1 V H ~ Submit in Duplicate • Perforation Depth MD (ft) 12378 12424 12472 12491 12513 12554 12587 12587 12612 12628 09-12 177-0070 Perforations Attachment • Opn/Sqz Perforation Depth TVD (ft) 12408 Opn 9001 9013 12457 Opn 8903.58 8928.17 12479 Opn 8939.37 8944.6 12498 Opn 8953.59 8958.83 12532 Opn 8970.09 8984.37 12570 Opn 9000.95 9013.02 12602 Opn 9025.88 9037.24 12600 Opn 9025.88 9035.73 12617 Opn 9044.82 9048.61 12645 Opn 9056.95 9069.85 • To: Jerry Bixby /Clark Olsen Well Operations Team Leader From: Patti Phillips DS 09 Drillsite Engineer Subject: 09-12i Tubing Hanger Sealtite Repair PBD09WL12-S Please erform the followin rocedure s Date: November 29, 2007 Est. Cost: $45M IOR: 200 Step Type Procedure 1. F Freeze protect well with diesel. 2. S Set WRP 3. O Sealtite Tubing Hanger Repair 4. S Pull WRP (post Sealtite Repair) 10-403 is required Status: Last injection: Max Deviation: Min ID: Last Tag: Last Downhole Op: Latest H2S Value: Tie in Logs: Obiective• SI due to failed MIT-IA on 7/20/07 4600 BWPD on 10/05/07 64° C~ 10,014' MD 2.562"@ 12,583', 3-1/2" CAMCO NO-GO NIPPLE 12,564' MD on 10/28/07 Caliper run on 10/28/07 No data available Jewelry log run 05/03/95, LDL run 10/20/07 The objective of this wellwork is to repair confirmed Tx IA Communication in the tubing hanger and restore well Integrity using Seal-Tite Sealants and Procedures. A video log run 10/28/98 found a leak at the bottom of the tubing hanger. A TecWel LDL was run on 10/20/07 and confirmed the leak =/- 2' below the tubing hanger. Recent Events• Well 09-12 is a produced water injector with TxIA communication that is currently shut- in. This well was completed in 6/11/77 and had a RWO on 11/22/86. This well has an FMC wellhead and both tubing and casing hangers are plastic packed. A video log in the tubing, run 10/28/98, found a leak at the bottom of the tubing hanger above the 1st pup joint. On 12/25/99, a PPPOT-T passed; the primary test port had • been sealant squeezed with WKM. The PPPOT-IC failed; the test port had been sealant squeezed with WKM sealant. On 12/26/99, Seal-Tite Tur-Flo sealant was injected into IC packoff and the IC hanger passed to 3000 psi in 1/08/00. FMC attempted to perform packoff tests on 1/10/03, but found the tubing hanger and casing hanger packoffs packed with plastic. A TecWel LDL confirmed the leak on 10/20/07. Please contact Patti Phillips at x-4578, 346-1755 (home) or 240-3742 (cell) or Jennifer Julian with any questions or comments. cc: Well File Mechanical Considerations This well has a leak in the 5'h" production tubing, identified via a TecWel log at +- 2' below the base of the tubing hanger. The recorded liquid leak rate from previous diagnostics ranges from 0.1 to 1 gpm at 3000 psi. The well is currently a PWI but may be used for MI service in the future. The tubing hanger void has been plastic packed and there was some concern that this hanger may have been the source of the communication. The objective of this procedure is to eliminate the tubing leak; any possible hanger leak will be addressed at a future date. 09-12i Procedure: Fullbore Procedure (pre-SEAL-TITE) 1. Take TxIAxOA pressures. 2. Freeze protect the well with diesel. Slickline Procedure (pre-SEAL-TITE) 3. Set a WRP at 46' at the mid point of the 40' joint (reference TecWel log 10/20/07) or as close as feasible below the leak location. NOTE (per D. Cismoski): Add a section of riser and second swab valve to the tree swab flange. R/U Slickline lubricator on top of this riser. The length of the riser/swab valve assembly shall be such that the wireline tool string does not extend above the wireline BOP's. 4. Set heater in wellhouse and make sure the tree is above freezing prior to the next step. ~ • SEAL-TITE Procedure 5. R/U pump on tree cap and fill tree with diesel. 6. Establish an injection rate with diesel and confirm the LLR at 1000, 2000 and 3000 psi. 7. Blend water based sealant and pump into the tree. The water-based sealant will fall through the diesel and fill up across the leak site. The volume of sealant pump is contingent on the setting depth of the WRP. 8. Increase squeeze pressure until a seal is obtained at 1000 psi. Monitor IA returns to ensure no further communication. Allow seal to cure for 1 hour. 9. Increase squeeze pressure to 1500 psi. Allow seal to cure for 1 hour. 10. Increase squeeze pressure to 2000 psi. Allow seal to cure for 1 hour. ~ 11. Increase squeeze pressure to 2000 psi. Allow seal to cure for 1 hour. ~ ~ ~~~ ~ 12. Increase squeeze pressure to 2500 psi. Allow seal to cure for 1 hour. ~~ ~~ 13. Increase squeeze pressure to 3000 psi. Allow seal to cure for 1 hour. Sc~ ~k~- 14. Increase squeeze pressure to 3500 psi. Allow seal to cure for 1 hour S~~"`5 ~~`~ 15. Allow seal to cure for 12 hours or overnight. ~v~~~~ ~~ 16. Reduce squeeze pressure to 2000 psi and lock in. Allow to cure for 5 days. ~~ 17. Bleed pressure to zero. ~l~ `~Cl~ Slickline Procedure (post SEAL-TITE) 18. Pull WRP 19. Return well to normal PWI. • ~ ` TecWel LDL 10/20/07 ~-1 Differential Temperature (degF) 1 I---------•--•---•------------•-------------------------- ~ i ,_ _ _ ~ _. L , ~ _. . r - _ - ' I -t- -- _ '- - - _ Wellhead===-) -~ - ~ _ _. - _ - -:- --- - '~• , , + _ r - • r ~_ --- i LEAK -- ~ - .~ . -- . -- - -- - - _ _ .. _ _ - =V .. '~ f _ i I - , ^ ~ --- t - - - - - - --{ --- --_~-- - - - - _ ---- - - - --~ ' -t-- - - ~ _ .... --- _- --- ---- - -t--- -- ' ---- - - '_._ - -' :- -' ~ - t -. - ! Set W R P of 46' _ _. --- - - - . --_~= - - -- , - ~. f the 40' iddl --- - -- - - ! -, - - - ---- ~ :j e o m joint or as close _ r -- ._. - _ - __ . - - I - - - ~~ as feasible . _ __ - ... ,. --- --~- - - --1 -, --, - - - ~ - - -~ -. ~ - _---~---, I e k below th ea - ._ _ ---~ -- ;---- , ~ _~ - _ ~ '-- - ---~ -~ ~ _ -- ~~..~ . ` ~-I location. _ .. ~ __ ~ -- -~ _ -. .... .. . _ 1... --___. - _ _~ __ _~ . I ! ._... _. ~ :- ~ _~ -_- _.J ~ .~.-1 -1- -.- - .--_- - -_ --.. I --_- ___- __ __ _ ~ - - -_. __ i ' I ~ ~ 1 ~_ I - I -.. - i I _, , - r -. r - ~ _ i I r _ - ' _ - _ -_ - - . , _ .~ _ ~ 1 } 300 Head Tension (Ib) 1300 ~0 AL DA 80000 0 ----.--Line Speed (ft/min) _- --200 G ALDB 80000' 5000 CCL -SOO T G ALDC 80000 G Temperature I:degF) 200, !-1 Differential Temperature (degF) ~ • ~~_ ~.~ W~LHEAD= FkC AcTUATaR= AxELSOri KB. ELE'J = 34' BF. ELEV = ? KOP= 29'98• Max A k = 94 .10014' Datum MD = 12357•. Datum TV O= 8800' SS Minimum IDs 2.562" ~ 12583' 3-1/2" CAAACO NO~O NIPPLE " 7'BG-PG.17it. l-9fl..0232 4of. D =4.992' ~ 9.518' CSG, 47M, N-80/50085, ~= 9.981" t 3-112" PERFORAT~t SI}tM7ARY REF LOO: HH^w" ON 09A2177 At~3LE AT TOP PERF: 42 {~ 12378' Hobe: Rderto Production DB for historical arf data 51ZE SPF NTERVAL O ISgz DATE 2-118" 4 12378- 12403 O 09/04184 3-1J~J" 4 12424- 12457 0 ~i07~ 3-1l8" 4 12472- 12479 0 00107177 3-7 t8" 4 12491- 12499 O 0810787 3114" 4 12513 - 12532 0 t19107r77 3-1IB" 4 12554- 12570 O D9107t77 3-118" 4 12587 - 12902 0 08177//77 3-118" 4 120- 12920 O 04107/95 3-118" 4 12912- 12917 0 ~1~D7{77 3-1t8" 4 12928- 1'1'843 0 09107177 7" LNR, 2911, N•80BOD95, -0371 bpf. ~= 9.184" . • SAFETY NDTE3: '"'PW I ONLY - NO MI iNJ~TIDN 4 9 ~ ~ ~ Hr* w TaIA tEAlt FOUL AT BOTTOM OF TH4 p: ~ 7 7634' ~-j 5-112" 0378 X NP, D = 4.592" I 17675' -[xo 5112" x4-117 12405` 4-112" A VA HPL Np PiJR3ED SLV Q = 3.789' 12471 ` -[7' X a• 912' HA KER FH-1 PICR~ 12420' 4-112" x 31.2" XO 72564' 3-12" AVA HPC f~ D=2.813"(2-18194" HDLG 12574` 7"X3.112" 84i~ B-1 PKR~ 12583` 3-112" CAM NO-GO NP, D ~ 2.892' 12587` 3-112"'nseac; TAL 12586' ELMTL8P1Ci TAL- t OGGE03At93 12586` 3112' HA K@2 SH6478?UTSLB PATE R>:V HY C.o11+9~EN]'S DATE R2J HY CC#4JElt75 06!11!!7 ORN3tNN. COMPLETION 09A1A7 /A4 WANt,~ t~lOTEDELETH3 10/22A6 tAST YVDfr1SOY9t 12"28A3 7WSITLH TIP PiH.1.® 01r'09A9 RPHtPJC WAN SFTY N07E LPOATE 12105A9 GJFI7LH PxX PLUG SET 01104A7 GJF(!LH PxX fUCa FULLED PRWHOEHAY L~3Tf WELL: 00-12 PBtA+if No: P1770470 AA Na 30-029-20239-00 S~ T, TqN, R19E, 1349 FSL 8 74' FWL BP Expicration {Alaska] MEMORANDUM To: Jim Regg ~~~~ ~' ~ ~ ~ (~~ D ~ P.I. Supervisor t~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 10, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-12 PRUDHOE BAY UNIT 09-12 Sre: Inspector NON-CONFIDENTIAL i~~~~°7 Reviewed By: P.I. Suprv ' }~lL Comm Well Name: PRUDHOE BAY UNIT 09-12 API Well Number: 50-029-20239-00-00 Inspector Name: Bob Nobte Insp Num: mitRCN071006t54544 Permit Number: 177-007-0 Inspection Date: 10/5/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 09-12 W Well iTYPe Inj. TVD g2yy ~ I~ e~ac~, 660 ~ 3000 '~ -_~ 2910 2820 i ^~ ~ ~ P.T. 1770070 TypeTest ~ SPT I TCS Pis 3000 ~ QA ' 240 ~' 440 ~ 420 ~~ 450 Interval OTHER P~F F ~ TUbing ~, 1400 1400 1400 1400 Notes' MIT-IA for an AA request ~ i' Cc~,~e.(E~^ ~~c 4~. eit t~ ~l `t'~z-o~7 s~c:-F,,U, {- C~li..`'C3~ vnC~J- ~~Llt',:G' -+z' C>'y2'..2:~ `~~~ ~~,~i5~-1_ r t,•.~.i~tc~~~t- {;~ i llC ICE.-- ~Y_ c.~ ~LC/t0 ~ti~' ~,UL ~ Z./C~I Z~1~ J Al'4- cA.~ St-i.,iGll?.l v.:C'~ trJ~2ic<.~z.~v.ts C ~t9,M~. !L -4Ci4-, ~G``'i,.-:v~ G~ dd't'_G~-zc Jvu~~ -xtfl.~'~.~ CYo~~~ ~~~8't~~~A.d IV~ V ~ ~ Z~U7 Wednesday, October 10, 2007 Page 1 of ] 09-12 (PTD # 1770070) Passing MI. Regg, James B (DOA) . Page 1 of 1 From: Regg, James B (DOA) Sent: Monday, September 24, 2007 7:45 AM To: 'NSU, ADW Well Integrity Engineer' Cc: Maunder, Thomas E (DOA) Subject: RE: 09-12 (PTD #1770070) Passing MITIA ~ê11 911Ato7 We'd like to see the TIO plot for the well after injecting produced water for 30 days. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWellIntegrityEngineer@BP.com] Sent: Friday, September 21, 2007 8:35 PM To: Regg, James B (DOA); Maunder, Thomas E (DDA); Fleckenstein, Robert J (DDA) Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R; Dube, Anna T Subject: 09-12 (PTD #1770070) Passing MmA 5!GANNED SEP 2 ?' 2007 Jim and Tom, /" Please see the attached MIT form for a passing MITIA on well 09-12 (PTD #1770070). The passing MITIA verifies the well can be operated under BP policy. However, the well had an AA, which was cancelled due to a failed MITIA in July, for TxlA communication. Our plan is to put the well on produced water injection and monitor for TxlA communication. If signs of TxlA communication still exist we will perform an AOGCC witnessed MITIA and reapply for an AA. ./ «MIT PBU 09-12 08-29-07.xls» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Page~(907)659-5100x1154 9/24/2007 . . Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS 09 08/29/07 Anna Dube '?-Qi' ~(LA (Q 7 Packer Depth Pretest Initial 15Min. 30 Min. Weill 09-12 I Type Inj. I N TVD I 8265 Tubing 0 0 0 0 Interval I 0 P.T.D.I 1770070 I Type test I P Test psil Aooo Casing 0 3000 2990 2990 P/FI P Notes: MIT-IA for eval TxlA communication. OA 0 0 0 0 Weill I Type Inj. ! I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill ! Type Inj. TVD I Tubing Interval I P.T.D.I I Type test I I Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type test! I Test psi! Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 ¡t."'"'-. (éA C~J {n~ !Z,/U/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) P~CIie)' TV£) - <ß'W~ * Û~(ÇS4-;", re t",<-\T(A. 5 I PÚ(Íf€r- ,A,1b C~l \ej(}(k)' (lh. ct lrt G~\v\?l SUV~0) MIT PBU 09-12 08-29-07.xls /" ~ to - f04- . . rage 1 or L Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Thursday, August 23, 20074:26 PM To: Regg, James B (DOA) Cc: NSU, ADWWelllntegrity Engineer Subject: RE: Verify Packer Depths <7 ~'lqlcì7 \<.. i11 Jim, I have verified the packer depths with the data manager of Petrotechnical Data Center. They are the group that manages our directional surveys as well as other data. They tested our system by running three types of depths through our depth converter (the tool that my group uses) and compared them to Finder (our database): our reported values, the MD of the packer from the wellbore schematics for the two wells, and random directional survey stations depths. The TVD and TVDSS results from the converter for the first two types of depths matched the calculated results from the database and the results for the random directional survey station depths were as expected. I have included a response from this group concerning R-13 and 09-12. "Some ideas to consider: The first pair of values you asked about (for well 09-12) differ by about the KB (operator or reference elevatiOn), so someone may have confused ìVD and TVDSS (whose delta IS KB). The discrepancy in the second pair (well R- 13) does not seem to be explained by the KB; could a transposing typo (8104 vs. 8140) be involved?" You mentioned that you have an individual performing QC work in your office and we may have more issues to address. I hope to find more information about the discrepancies in the interim. Please call with any questions or concerns. Thank you, SCANNED SEP 1 0 Z007 Andrea Hughes From: Regg, James B (DCA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 31, 2007 2:27 PM To: NSU, ADW Well Integrity Engineer Subject: Verify Packer Depths Please check packer TVD reported on MIT forms for PBU R-13 (PTD 1830440) and PBU 09-12 (PTD 177-007); based on most recent sundry and directional surveys, I calculate: PBU R-13 packer TVD - 8104 ft (BP reports 8140 ft) PBU 09-12 packer TVD - 8207 ft (BP reports 8265 ft) We have initiated work to verify the packer TVD when we receive MIT reports. We have found a few instances where there is confusing/conflicting info about depth on reports of sundry operations, well completion reports, well schematics, and MIT reports. Notice also that the only place we receive packer TVD is on the MIT form, every where else the value is reported in MD. Interesting since we set the test pressure by regulation as 0.25 x TVD packer. Any differences noted have not impacted the test pressure since you routinely test to a higher pressure than required by regulation. Thank you in advance for verifying these wells. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 8/29/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 'f~ rvlt-1/07 P.I. Supervisor { DATE: Monday, July 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC 09-12 PRUDHOE BAY UNIT 09-12 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: .-.-: P.I. Suprv,--Jß'Z.. Comm Well Name: PRUDHOE BAY UNIT 09-12 API Well Number: 50-029-20239-00-00 Inspector Name: John Crisp Insp Num: miÙCr070723075535 Permit Number: 177-007-0 Inspection Date: 7/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-12 Type Inj. w TVD 8265 IA 1260 2500 2450 2420 2390 P.T.D 1770070 TypeTest SPT Test psi 2066.25 OA 150 260 220 220 220 Interval REQVAR PIF F ..,/ Tubing 1220 1220 1220 1220 1220 Notes: PT showed steady pressure loss. Requested retest. 2.5 bbl's pumped for test. }tiCker ¡Vb Ûl'£C...JxJeS 73'2.01 ' r- ~ rea'A -/. 'Si/~'~:J 1'pf'r?;4.JL (to-fD3) cW oll1'e(~~~ "SUNf-L. ,,- NON-CONFIDENTIAL Monday, July 23, 2007 Page I of I MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 7<é4~r- éßIZ&l{Vl P.I. Supervisor ( I DATE: Monday, July 23,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-12 PRUDHOE BAY UNIT 09-12 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv-.:-t!:I'- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN1T 09-12 API Well Number: 50-029-20239-00-00 Inspector Name: John Crisp Insp Num: mitJCr070723080 I I3 Permit Number: 177-007-0 Inspection Date: 7/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-12 Type Inj. w TVD 8265 IA 2390 2510 2480 2450 2420 P.T.D 1770070 TypeTest SPT Test psi 2066.25 OA 220 220 220 220 220 " Interval REQVAR PIF F -/ Tubing 1220 1220 1220 1220 1220 Notes: Retest. MIT showed steady pressure loss. Failed, data reported to Supervisor for final pass fail determination. Pac/¡æ~ TV!) CLtck~ç <82D1' ~W\. QCê-td- S-v~Çt iì.pp-t\J<& (;O---t1ù~) Ct,..¿J, ck ¡(c.k~'NC( 'SìA rv~ 5CANNED SEP 1 02007 Monday, July 23, 2007 Page I of 1 MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~~ ;::;~isor 1< tit[ 1 ~{lci I ò 7 DATE: Monday, July 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-12 PRUDHOE BAY UNIT 09-12 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv""'-¡g 12- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 09-12 API Well Number: 50-029-20239-00-00 Inspector Name: John Crisp Insp Num: mitJCr070723080557 Permit Number: 177-007-0 Inspection Date: 7/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-12 Type Inj. w TVD 8265 IA 880 940 980 1020 P.T.D 1770070 TypeTest SPT Test psi 2066.25 OA 220 2500 2450 2450 Interval REQVAR PIF P / Tubing 1360 1360 1360 1360 Notes: .7 bbl's pumped for test. OA test for variance compliance. ¡~ JVIJ CttQ.~s I ~ ß207 RC~~ ~'~(j qqa.-o'J~ (ID·- 4tJ3) Q.yß o{lreGk~ '3W~ sCANNED SEP 1 0 Z007 Monday, July 23, 2007 Page I of 1 _ _ • - _ -, • t ,I r ~ ~ t ~~~ 1 _ ~ pit i ~ t` ii ~ ~ ~; t ' i ` ~ ~, SARAH PAUN, GOVERNOR ., ~5~~ Qj~ ~~ ~~ 333 W. 7th AVENUE, SUITE 100 COH-S~'IR~A~O~ CO~IIL+L+I®~ ANCHORAGE, ALASKA 99501-3539 ++~~a i i •s -7-7 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 4C.Oll Mr. Steve Rossberg, Wells Manager ~>~-~~`~~~~~~ ~~~ ~ ~ ~~~$ Attention: Weil Integrity Engineer, PRB-24 ~ ~ ~ 7 BP Exploration (Alaska) Inc. 11 P.O. Box 196612 1 Anchorage, AK 99~ 19-6612 RE: Cancellation of Administrative Approval AIO 04C.011 (Well PBU 09-12) Dear Mr. Rossberg: Pursuant to BPXA's request dated July 31, 2007 AOGCC hereby cancels Administrative Approval AIO 04C.011, which allows continued water injection. This well exhibited tubing by inner annulus pressure communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has shut in the well following a failed mechanical integrity test. BPXA states it does not intend to operate Well 09-12 without competent tubing. Consequently, Administrative Approval AIO 04C.011 no longer applies to operation of this well. Instead, injection in well PBU 09-12 will be governed by provisions of the underlying AIO No. 4E which supersedes and replaces AIO 4C. DONE at Anchorage, Alaska and dated August 8, 2007. The Alaska Oil and Gas Conservation Commission J J ~ 1111 /IV Uli_~1Q1S'~" ''~ hairman . i~ - g ~~ ~ ~ ~'' ,~~ ,~ ~- ~,~~~y Daniel T. Seamount, Jr Commissioner v~ Cathy P. oerster Commissioner ~_~ _ ~ _ y ~ _~. _ _ __ ~ __ ~ e_ _ „ J J FRAh1K H. MURKOWSKI, GOVERAIOR 17~~T~~~++~1 di~tri~-~t7~~t~T ~®v ~t~~a L~i~+l it~1-a7T 333 W. 7'" AVENUE, SUITE 100 ®d`s7a1i ~~~li®li l~®1~i1~~~7~`~®l~ ANCHORAGE, ALASKA 99501-3539 PHONE (,907j 279-1433 FAX (907) 276-7542 ADMIiVISTRATIVE APPR®VAL AI® ~4C.Oll Mr. Steve Rossberg, Fells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: PBU 09-12 (PTD 177-007} Request for Administrative Approval Dear tilr. Rossberg: Per Rule 9 of Area Injection Order 0040.000, the Alaska Oil and Gas Conservation Commission (`AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. (''BPXA"}'s November 17, 200 request for administrative approval to inject water in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 09-12. The Commission further finds that, based upon reported results of BPX.A's diag- nostic procedures, PBli 09-12 exhibits tw-o competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall w-el1 integrity so as to threaten the environment or human safety. AOGCC's administrative approval to inject water in PBU 09-12 is conditioned upon the following: 1, BPX~4 shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform an annual VIIT - OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform an annual OMIT - T x IA to 1.2 times the maximum antici- pated well pressure; ~. BPXA shall limit the well's OA pressure to 1000 psi; • Mr. Steve Rossberg Qecember li„ 200 Page 2 of 2 BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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. :a and dated December 13, 200. /: ~' , ~~ P Daniel T. Seamount, Jr. athy P Foerster, Commissioner Commissioner - - = ~ ~~~. =~~~ ~. ^, >`'~ ~r<:~:,~ .~ / i - ~ r - - a ~; -; 1 s °:,' ,e9~ ~; -~~:, .;Y Re: 09-12 (PTD #1770070) Internal Waiver Cancellation - Operabl... Our records show water injector PBU 09-12 has TxlA communication and is covered by Admin Approval AlO 4C.011 allowing it to continue injecting with certain conditions of approval. Conditions of AlO 4C.011 apply until canceled by the Commission. Jim Regg AOGCC sGANNEJD JUN 0 1 Z007 Dube, Anna T wrote, On 5/3112007 3:16 PM: All, An internal waiver was issued for TxlA communication on well 09-12 (PTD #1770070) on 01/06/06. The well passed an MITIA on 12/16/06 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well 02-16 will be Operable. The well is reclassified as an Operable well. Please remove all waivered well signs and the lamintaed copy of the waiver from the well house. Thank you - }lnna q)u6e, Œ'.f£. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Jim Regg <jim regg@2admin.state.ak.us> Petroleum Engineer AOGCC 1 of 1 6/1/2007 9:09 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I OS 09 12/22/06 Jack Winslow ~1 \Z-\~~~, Ðo1 Packer Depth Pretest Initial 15Min. 30 Min. Well 109-12 I Type Inj. I N TVD I 8,265' Tubing 0 0 0 0 Interval I V P.TD. 1770070 I Type test I P Test psil 2500 Casing 20 2,525 2,500 2,485 P/FI P Notes: AOGCC declined to witness MIT -IA for Waiver OA 0 0 0 0 Compliance. 3rd 15 minutes = 0/2480/0. Weill I Type Inj. TVD I Tubing I Interval I P.TD.I I Type test I Test psi I Casing I P/FI Notes: I OAI I Weill I Type Inj.1 I TVD Tubing Interval I P.TD. I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD ! Tubing I IntervaiT P.TD.I ! Type test I I Test psi! Casing P/FT Notes: OA We111 I Type Inj.! ! TVD I Tubing Interva¡r P.TD.I I Type testl ! Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 ./ TYPE TEST Codes M :::: Annulus Monitoring p :::: Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) SCANNED JAN 0 8 2007 MIT PBU 09-12 12-22-06.xls _ STATE OF ALASKA _ ALA. all AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS f,r.:r.E'VED DEC 1 6 ZOOS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 54 KB 8. Property Designation: ADL-028345 11. Present Well Condition Summary: Total Depth measured 12800 true vertical 9187.78 Effective Depth measured 12790 true vertical 9180.15 Casing Conductor Surface Production Liner Length 80 2676 12098 979 Size 20" 96# H-40 13-3/8" 72# N-80 9-5/8" 47# N-80 7" 29# N-80 Perforation depth: Measured depth: 12378 - 12408 12554 - 12570 True Vertical depth: 8869.47 - 8891.7 9000.95 - 9013.02 Tubing: (size. grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Printed Name Sharmaine Vestal Signat Form 10-404 Revised 04/2004 ¡¡ ) î Plug Perforations [2] Perforate New Pool D Perforate D 4. Current Well Class: Development Stratigraphic D feet feet feet feet MD 33 - 113 32 - 2708 31 - 12129 11821 - 12800 12424 - 12457 12587 - 12602 8903.58 - 8928.17 9025.88 - 9037.24 5-121" 17# 4-1/2" 12.6# 3-1/2" 9.2# Stimulate D O\\\SIS Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 177-0070 Service PI 6. API Number: 50-029-20239-00-00 issio 9. Well Name and Number: 09-12 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) 11634 XX None TVD Burst Collapse 33 - 113 1530 520 32 - 2707.83 4930 2670 31 - 8687.23 6870 4760 8470.12 - 9187.78 8160 7020 12472 - 12479 12600 - 12620 8939.37 - 8944.6 9035.73 - 9050.89 L-80 L-80 J-55 12491 - 12498 12612 - 12617 8953.59 - 8958.83 9044.82 - 9048.61 30 -11675 11675-12420 12420 - 12587 12513 - 12532 12628 - 12645 8970.09 - 8984.37 9056.95 - 9069.85 5-1/2" Baker SAB Packer 4-1/2" Baker FB-1 Isolation Packer 3-1/2" Baker FB-1 Packer 11500 12411 12574 SCANNEr: ,~ ·2~· -_¡ 2005 1...'_ Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure SHUT-IN SHUT-IN Tubing pressure Service PI 15. Well Class after Droposed work: Exploratory D Development 16. Well Status after proposed work: Oil Gas D WAG GINJ D WINJ PI WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my ~ 1@'(I.e1: g~S. .. Sundry Number or N/A if C.O. Exempt: ~riLJM: 8Fl DEC 1 9 200 /A Contact Sharmaine Vestal Title Data Mgmt Engr Phone 564-4454 Date 12/8/2005 Submit Original Only ..; e e , 09-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 11/3/2005 ** WELL SHUT IN UPON ARRIVAL** {reg camp} BRUSHED & FLUSHED TBG. DRIFTED TO 51/2" x 41/2" XO @ 11643'SLM. SET 51/2" XX PLUG @ 11610' SLM, 1100 PSI ON TUBING WHEN SET. CMIT Tx IA TO 2500 PSI, PASSED LRS TO M IT -OA TO 2500 ** TURNED WELL OVER TO DSO, LEFT SHUT IN** 11/3/2005 T/I/O=O/O/O Assist slickline with Brush & Flush. Pumped 231 bbls diesel @ 180*. SWS set TTP, CMIT Tbg x IA to 2500 psi. PASSED 1st Attempt, Loss 20 psi 1st 15 min, Loss 10 psi 2nd 15 min. Bled back well to bleed trailer, Rigged up to MIT OA, Continued to 11-04-05 11/4/2005 Continued WSR T/I/O=O/O/O MIT OA to 2500 psi. PASSED On 1st Attempt. Loss 50 psi 1st 15 min, Loss 20 psi 2nd 15 min. Pumped 2.7 bbls diesel to test. FWHP's=O/O/O 11/5/2005 T/I/0=0/40/20 CMIT TxlA PASSED @ 2500 psi. (Shut In)(AOGCC Witnessed by Chuck Sheve) TxlA Pressured up w/ 6.9 bbls Meth Pumped. TBG lost 80 psi and IA lost 0 psi in 15 min. w/ total TBG loss of 110 psi and IA loss of 0 psi in 30 min. DHD will bleed down~pres!)ures. 11/5/2005T/I/0=0/40/20. Temp=SI. CMIT-TxIA (for new waiver). PASSED. AOGCC State Witnessed by Chuck Scheve. Pumped 9 bbls meoh to CMIT-TxIA to 2500 psi. TP lost 80 psi, lAP lost 0 psi in 1st 15 minutes. TP lost 30 psi, lAP lost 0 psi in 2nd 15 minutes. Bled TP & lAP to 0 psi (7.8 bbls returns). Final T /1/0=0/0/20. FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 ) ) ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 November 17, 2005 Mr. Winton Aubert, P .E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 RECEIVED Subject: 09-12 (PTD 1770070) Application for Cancellation of Sundry #303-286 NOV 2 3 2005 Alaska Oil & Gas Cons. Commission \ '~"...... Anchorage Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 1 0-404 to cancel sundry number 303-286. The sundry was for continued water injection with slow TxlA communication. The well will remain shut-in in preparation of an administrative approval. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. pi;(L~ Joe Anders, P.E. Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 ~Neu NOV 2 9 2005 STATE OF ALASKA . ALA~ lOlL AND GAS CONSERVATION COMf'...110N REPORT OF SUNDRY WELL OPERATIONS D D D 1 . Operations Abandon D Repair Well D Periormed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 54 KB 8. Property Designation: ADL-028345 11. Present Well Condition Summary: Total Depth measured 12800 true vertical 9187.78 Effective Depth measured 12790 true vertical 9180.15 Casing Conductor Suriace Production Liner Length 80 2676 12098 979 Size 20" 96# H-40 13-3/8" 72# N-80 9-5/8" 47# N-80 7" 29# N-80 Perioration depth: Measured depth: 12378 - 12408 12554 - 12570 True Vertical depth: 8869.47 - 8891.7 9000.95 - 9013.02 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 000 15. Well Class after Droposed work: Exploratory r Development r 16. Well Status after proposed work: Oil r Gas r WAG r Plug Periorations Periorate New Pool Periorate 4. Current Well Class: Development rc: Stratigraphic (J feet feet feet feet MD 33 - 113 32 - 2708 31 - 12129 11 821 - 12800 12424 - 12457 12587 - 12602 8903.58 - 8928.17 9025.88 - 9037.24 5-1/2" 17# 4-1/2" 12.6# 3-1/2" 9.2# 5-1/2" Baker SAB Packer 4-1/2" Baker FB-1 Packer 3-1/2" Baker FB-1 Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders / Anna Dube Printed Name Joe Anders, P.E. Signature v(CL~ t-orm 10-4(4 Hevised 04/2004 StimulateD Other 0 Cancel Sundry WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory IC 177-0070 Service ~. 6. API Number: 50-029-20239-00-00 9. Well Name and Number: 09-12 10. Field/Pool(s): Field/ Pool Plugs (measured) Junk (measured) 11 634 None TVD Burst Collapse 33 - 113 32 - 2707.83 4930 2670 31 - 8687.23 6870 4760 8470.12 - 9187.78 8160 7020 12472 - 12479 12600 - 12620 8939.37 - 8944.6 9035.73 - 9050.89 12491 - 12498 12612 - 12617 8953.59 - 8958.83 9044.82 - 9048.61 12513 - 1 2532 12628 - 12645 8970.09 - 8984.37 9056.95 - 9069.85 L-80 N-80 J-55 30 - 11675 11675 - 12420 12420 - 12587 11500 12411 12574 Tubing pressure o o Service P'" GINJ r WDSPL r WINJ P"' Sundry Number or N/A if C.O. Exempt: 303-073 Title Well Integrity Coordinator Date 11/14/2005 Phone 907-659-5102 Submit Original Only MEMORANDUM TO: Jim Regg --;7 P.I. Supervisor l~e11' u(q 105 FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE BAY UNIT 09-12 Insp Num: mitCS051106171630 Rei Insp Num .Packer Well--T---Õ9-12 IType l~j~rÑ I TVD P.T. 11770070 ITYP~-Test i I Te~_e_~~__ Interva I REQV AR ___._______.J».Œ____ P Notes CMIT Tx IA Wednesday, November 09,2005 ') State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 09, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-12 PRUDHOE BA Y UNIT 09-12 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-20239-00-00 Permit Number: 177-007-0 Depth Pretest 8264 ________~~___t--=·-4Õ-·------ 2066 OA I 20 Tubing I 0 -_.._--,-~---~._--_.._-..~._,--- Initial ) \1'1-'b01 Reviewed By: P.I. Suprv ~:.fßL- Comm Inspector Name: Chuck Scheve Inspection Date: 1115/2005 II 2500 , 20 ··_-¡-·--2500 15 Min. 30 Min. 45 Min. 60 Min. --r---·- 2500 I. 2500 20 20 2420 r--Z39Õ----i----c- ~ÇANNf[ NOV 1. ? 2005 .--"--- Page I of 1 ) ) ¡11~OC)'7 I a/ ../ '¥-11. 1\l ( /)S Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / OS 09 07/18/05 Rob Mielke Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-12 Type Inj. F TVD 8,265' Tubing 1,800 1,800 1,800 1,800 Interval 0 P.T.D. 1770070 Type test P Test psi 3,000 Casing 1,430 3,030 2,980 2,940 P/F F Notes: MIT-IA I LLR for Waiver Compliance Well 09-12 Type Inj. F TVD 8,265' Tubing 1,800 1,800 1,800 1,800 Interval 0 P.T.D. 1770070 Type test P Test psi 3,000 Casing 2,940 3,000 2,970 2,930 P/F F Notes: MIT-IA I LLR for Waiver Compliance Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D, Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: LLR-IA = .1 gpm @ 3000 psi. AOGCC Rep. Jeff Jones declined to Witne,ss. L..U¿í - <M\.c ~.eJ -Þ", 2ð¡') 3> ~ 2M4 h\s :Steefl TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 8CANNEC AUG Ü 3 2005 2005-0718_MIT _PBU_09-12_MIT2.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) .... STATE OFALASKA ' r~ ALASL OIL AND GAS CONSERVATION co '''~ISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon [--] Suspend BI Operation Shutdown E] PerforateF~ Variance[] AnnuarDisposalFl Alter Casing r-] RepairWell r'-I Plug Perforations r-[ Stimulater-] Time Extensionr-] Otherr--] Change Approved Program r-] Pull Tubing ~--~ Perforate New Pool [--I Re-enter Suspended Well[--I H20 INJ VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development E] Expl°rat°ryE] 177-007 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 StratigraphicE] Service[] 50-029-20239-00-00/ 17. KB Elevation (ft): 9. Well Name and Number: RKB 54.00 09-12 / 8. Property Designation: 10. Field/Pool(s): ADL 028345 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY ,Total Depth MD (ff):12800 ITota' Depth Tva (ft': IEffect've Depth MD (ft): IEf ective Depth TVD (ft): IPlugs (measured): I'unk (measured):9'88 I 12590 (07~09~2003) 9028 None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 84 20" 29' - 113' 29' - 113' 40K 520 Surface 2771 13-3/8" 29' - 2708' 29' - 2708' 80K 2670 Production 12100 9-5/8" 29' - 12129' 29' - 8634' 80K 4760 Scab Liner 969 7" 11821' - 12790' 8417' - 9127' 80K 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12378' - 12645' 8870' - 9070' 5-1/2" 17#, 4-1/2" 12.6#, L-80 12587 3-1/2" 9.2# Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8" X 5-1/2" BKR SAD PKR, 7"x 4-1/2" BKR FB-1 PKR, PKR's @ 11500', 12411', 12574', SSSVLN @ 2168' 7"x 3-112" BKR FB-I PKR; 4-1/2" Otis BV N SSSVLN 12. Attachments: Description Summary of Proposal[] 13. Well Class after proposed work: Detailed Operations Program E] BOP Sketch E] ExploratoryE] DevelopmentE] service~[i~ 14. Estimated Date for|' 15. We/llSlatUSoiE] after proposed work: Commencin~l Operation: q II O O~ Gasp] Plugged[-] AbandonedE] 16. Verbal Approval: Date: WAGE] GINJE] WlNJ~ WDSPL BI Commission Representative: Prepared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders Printed Name Joe Anders Title GPB Well Inte~lrit¥ En~lineer Signature ~ (,k4 (~,,~¢..~¢ Phone 907~ 659-5102 Date 0911012003 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .~'~.~'- Plug Integrity B BOP TestD Mechancial Integrity TestB Location C earanceB ~',, ~,~.~. Other: ~ ' .('.,, ~ I, [ , ' .... Subsequent Form Required: Approved by: COMMISIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 SUBMIT IN DUPLICATE 09-12 Description Summary of Proposal 09/12/03 Problem Injector with Slow Tubing by IA communication. Current Sundry requirements are not aligned with Sundry Matrix. Well History and Status Well 09-12 (PTD 1770070) is an injector with Tubing by IA communication. CMIT TxIA's pass, demonstrating competent production casing. Current Sundry requirements are not aligned with the Sundry Matrix dated 5/13/03. This proposal updates the Conditions of Approval to the current requirements. Pertinent well events: > 02/04/03: SL set TTP > 02/05/03: CMIT T x IA Passed to 3000 psi, pull TTP > 03/11/03: AOGCC approved Sundry #303-073 > 06/26/03: LLR-IA .1 gpm @ 3000 psi This request is to cancel the existing Tubing by IA Sundry and issue a new Sundry for Tubing by IA communication using current Conditions of Approval. The following supports the request: · A CMIT-TxlA passed on 02/05/03 to 3000 psi, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · A CMIT-TxlA will be conducted every 4 years to confirm production casing integrity. · An annual LLRT will be conducted to evaluate if the leak rate has increased. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform an annual LLRT. 5. Perform CMIT-TxlA every 4 years. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. TREE = FMC WELLHEAD= FMC ACTUATOR= AXELSON KB. ELEV = , 54' BF. EI_EV = ? KOP = 2969' Max Angle = 64 @ 10014' Datum MD = 12357' Datum TV D= 8800' SS 09-12 SAFe" NOTES - T X IA COMM. PWI ONLY - T X IA LEAK FOUl[. ' BOTTOM OF TBG HANGER. ***SLOW TxlA COMM. OPERATING LIMITS: MAX lAP = 2500 PSI, MIN OAP = 1000 PSI (04/21/03) *** 216S' I--~5-1/2" CAMWRDP-2 SSSV NIP, ID=4.562" I I 13-3/8" CSG, 72#, N-80, ID = 12.347" I'-~ 2708' IMinimum ID = 2.562" @ 12583' 3-1/2" CAMCO NO-GO NIPPLE 11675' 11675'I ITOPOF 7"LNRI--~ 11821' 9-5/8" CSG, 47#, N-80/SOO95, ID = 8.681" Id [ 4-1/2" TBG-PC 12.6#, L-80, .0152 bpf, ID = 3.958" Id 12129' 12420' 12420' 3-1/2" TBG-PC, 9.2#, J-55, .0087 bpf, ID = 2.992" Id 12587' ~~ PERFORATION SUMMARY REF LOG: BHCS ON 06/02/77 ANGLEAT TOP PERF: 42 @ 12378' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 12378- 12408 O 06/04/84 3-1/8" 4 12424- 12457 O 09/07/77 3-1/8" 4 12472- 12479 O 09/07/77 3-1/8" 4 12491 - 12498 O 09/07/77 3-1/8" 4 12513- 12532 O 09/07/77 3-1/8" 4 12554- 12570 O 09/07/77 3-1/8". 4 12587- 12602 O 09/07/77 3-1/8" 4 12600- 12620 O 04/07/95 3-1/8" 4 12612- 12617 O 09/07/77 3-1/8 4 12628- 12645 O 09/07/77 7"LNR'29#'N-80/SOO95"0371bpf'ID=6'184" Id['~'~d 12800'12790' ~~--~~ 11472' 11500' 11634' Id5-1/2" BAKER PBRASSY I Id9-5/8" X 5-1/2" BAKER SAB PKR I ]d5-1/2" OTIS X NIP, ID = 4.562"I 11675' I--[xo5-1/2"X4-1/2"I 12405' Id4-1/2" AVA BPL NIP, PORTED SLV ID= 3.759" I 12411' Id7"X4-1/2"BAKERFB-1PKR I ×o I 12564' Id3-1/2" AVA BPCNIPID= 2.815" (2-18/64" HOLES)I 12574' 1~7"x 3-1/2" BAKERFB-1 PKR I 12583' Id3-1/2" CAM NO-GO NIP, ID= 2.562" 12587' Id3-1/2" TUBING TAILI 12586' I--IELMTUB,NGTA,L-LOGGED5/3/95 J I 12586' Id3-1/2" BAKER SHEAROUTSUB I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/11/77 ORIGINAL COMPLETION 02/28/03 JP/KAK DELETE WAIVER SAFETY NOTE 10/22/86 LAST WORKOV ER 04/28/03 ATD/TLH WAIV ER SA FETY NOTE 12/20/00 SIS-SLT CONVERTED TO CANVAS 01/10/01 SIS-LG REVISION 03/21/01 RN/TP CORRECTIONS "01/06/03 DRS/KK CORRECTIONS PRUDHOE BAY UNIT WELL: 09-12 PERMiT No: 1770070 APl No: 50-029-20239-00 SEC 7, TION, R16E, 1346' FSL & 74' FWL BP Exploration (Alas ka) · 09-12 TlO Plot 4,000 ® Tbg 3,000 2,000 1,ooo 0 9/9/2002 I1/9/2002 1/9/2003 3/9/2003 5/9/2003 7/9/2003 9/9/2003 OOA e OOOA BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: 09-12 (PTD 1770070) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 and Application for Sundry Approval form 10-403 for Well 09-12. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with known Tubing by IA communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, 3oe Anders, P.E. Well Integrity Coordinator Attachments A~aska Oit & Gas Cor~s. g~n'~m.issi~'~ ORIGINAL i' STATE OF ALASKA i'~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonJ--J SuspendD Operation ShutdownD PerforateJ-'J VarianceD Annuar DisposalJ--'J After Casin.cir-J RepairWellr-J Plug PerforationsJ--J Stimulater..j Time ExtensionJ--J OtherJJ Change Approved ProgramJ-'] Pull TubingJ-'J Perforate New PoolD Re-enter Suspended WellJ-'J CANCEL 10-403 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement E~ Exploratory[--I 177-007 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 995'19-66'12 Stratigraphici--I Service~l 50-029-20239-00-00 7. KB Elevation (ft): 9. Well Name and Number: 54.00 09-12 8. Property Designation: 10. Field/Pool(s): ADL 028345 Prudhoe Bay Field I Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12800 feet true vertical 9188 feet Plugs (measured) Tagged TD @ 12590' (07/09/2003) Effective Depth measured 12590 feet Junk(measured) true vertical 9028 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 113' 113' 40K 520 Surface 2771' 13-3/8" 2708' 2708' 80K 2670 Intermediate 12100' 9-5/8" 12129' 8634' 80K 4760 Liner 969' 7" 11821'-12790' 8417'-9127' 80K 7020 Perforation depth: Measured depth: Open Perfs 12378'-12408',12424'-12457', 12472'-12479', 12491'-12498', Open Perfs 12513'-12532', 12554'-12570', 12587'-12620', 12628'-12645'. True vertical depth: Open Perfs 8870'-8892', 8904'-8929', 8940'-8945', 8954'-8959' Open Perfs 8971'-8985', 9001'-9013', 9026'-9051', 9057'-9070'. Tubing: ( size, grade, and measured depth) 5-1/2" 17# L-80 TBG-PC @ 11675'. 5-1/2" XO 4-1/2" @ 11675'; 4-1/2" 12.6# L-80 TBG-PC @ 12420'. 4-1/2" XO 3-1/2" @ 12420'; 3-1/2" 9.2# J-55 @ 12587'. Packers& SSSV (type& measured depth) 9-5/8"x 5-1/2" Baker SAB PKR @11500', 7"x 4-1/2" BK~Is~~t~IiI~E.D~~ 7"x 3-1/2" BKR FB-1 PKR @ 12574'. 5-1/2" Camco WR SVN @ 2168'. 12. Stimulation or cement squeeze summary: ~ '=' ...... Intervals treated (measured): Alaska 0i~ & Gas Cons. Corem Treatment descriptions including volumes used and final pressure: j~nch01'a~l~ 13 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Exploratoryr-I DevelopmentF-I Service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: oilF'] Gasr-I WAG[--I GINJ[--I WINJJl WDSPL[--] Daily Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact Joe Anders I 303-073 Printed Name Jqe Anders Title GPB Well Integrity Engineer Signature 4(,'-~ ~,~,v-'~' ..,._ Phone 907/659-5102 Date Sept10,2003, / ' ! rZ_I lkl Form 10-404 Revised 2~2003 VD~ w~\\.7 l Summary of Sundry Changes 09/12/03 Well Request 1 0-403 10-404 04-45 Align Conditions of Approval with Sundry XX XX Matrix 09-12 Align Conditions of Approval with Sundry XX XX Matrix 11-10 Align Conditions of Approval with Sundry XX XX Matrix 11-29 Align Conditions of Approval with Sundry XX XX Matrix 14-21 Align Conditions of Approval with Sundry XX XX Matrix A-31 Align Conditions of Approval with Sundry XX XX Matrix P1-01 Align Conditions of Approval with Sundry XX XX Matrix P-14 Cancel Sundry XX Y -03 Cancel Sundry XX Contact Joe Anders or John Cubbon with questions. (907) 659-5102 l .I 77 -tJ() 7 Comments Well is L TSI Well isLTSI SCANNED OCT 10 2004 BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 6, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 09-12 (PTD 1770070) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for well 09-12. This request is for approval to continue produced water injection with known tubing by inner annulus j communication. A description summary of proposal and welibore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. · Sincerely, Joe Anders, P.E. Well Integrity Engineer Attachments SCANNEB MAR 1 3 2803 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: VARIANCE Abandon_ Suspend_ Operational shutdown_ AJter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator BP Ex Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development Exploratory __ Strafigraphic m Service_.X 4. Location of well at surface 3934' FNL, 5204' FEL, Sec. 01, T10N, R15E, UM At top of productive interval 1173' FNL, 3555' FEL, Sec. 07, T10N, R16E, UM At effective depth 1244' FNL, 3493' FEL, Sec. 07, T10N, R16E, UM At total depth 1319' FNL, 3382' FEL, Sec 07 T10N, R16E, UM (asp's 718457, 5942816) (asp's 725221, 5940496) (asp's 725285, 5940427) (asp's 725398, 5940355) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 84' 20" Surface 2771' 13-3/8" Intermediate 12100' 9-5/8!' Liner 969' 7" 1279O 9076 12584 9024 feet Plugs (measured) feet feet Junk (measured) feet Re-enter suspended well - Time extension _ Stimulate _ Variance_X Perforate _ 6. Datum elevati~)n (DF or KB feet) RKB 54.0 feet 7. Unit or Property name Other_ Prudhoe Bay Unit 8. Well number o -12 ' 9. Permit number/~pproval number 177-007 10. APl number 50-029-20239-00 11. Field I Pool Prudhoe Bay Oil Pool Cemented Measured Depth True vertical Depth 266 sx Arcticset 113' 113' 5300 sx Arcticset 2708' 2708' 1000 sx Class 'G', 3000 ~sx AS 12129' 8634' 400 sx Class 'G' 11821'- 12790' 84i7'- 912...7' . Perforation depth: (size, grade, and measured depth Packers & SSSV (type & measured depth) measured Open Perfs 12378'-12408', 12424'-12457', 12472'-12479', 1.2_4.9.-1~-.12498', 12513'-12532', Open Perfs (continued) 12554'-12570', 12587'-12620', 126~'§C~J~45' -' ..~..-i .;i ....... true Vertical Open Perfs 8870'-8892', 804'-8929', 8940'-8945', 8954'-8959', 8971'-8985', Open Perfs (continued) 9001'-9013', 9026'-9051', 9057'-9070' 5-1/2", 17#, L-80 TBG'-PC ~ 11675' MD. 5-1/2" XO 4-1/2" ~ 11675'; 4-1/2", 12.6~, L-80 TBG-PC ~ 12420'. 4-112" XO 3-112" ~ 12420'; 3-1/2", 9.2#, J-55 ~ 12587'. 9-5~8" x 5-112" Baker SAB PKR (~ 11500' MD. 7" x 4-1/2" Baker FB-1 PKR. 7"x 3-112" Baker FB-1 PKR ~ 12574'. 5-1/2" Camco WRDP-2 SSSV N!p, pie ~ 2168' MD. 13. Attachments Description summary of proposal ...~.X Detailed operations program BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service Water Injection Suspended__ 17. I hereby ~rtify th~t~f~.~true and correct to the best of my knowledge. Signedwe/n:e~E ~a~ne:rvv- Title: Well Integrity Engineer egri y ngine r FOR COMMISSION USE ONLY Questions? Call Well Integrity Engineer 9071659-5102. io' Preps, md by DeWayne R. $c,hnorr 584-5174 Conditions of approval: Notify Commission so representative may witness ~ Approval no. - ~ Plug integrity_ BOP Test_ Location clearance__ ' i '~/'~'~' &:)~'~/-- ~ I~ Mechanical Integrity Test .... Subsequent form required 10- . -_- ~U ~' ~' .~ ~...'~ ~ ~ Approved by oroer of the ~ommismon -~_-.~? ~ ...__~.~_ _..~.~, ~Commissioner Date, ,, ~/,~///~...~ 122003 : _1:1 2003 Pnrm 111-4r}3 Rev 06115188 · '~.. "-".. _ . .- . SUBMIT IN TRIPLICATE 09-12 DesCription Summary of Proposal O3/04/03' Problem: Injector with Slow TxlA Communication Well History and Status / Well 09-12 (PTD 177~0070) is an injector that failed an MIT-IA on 12/28/02. A LLR of 0.4 gpm ~ 3000 psi was established. Recent events: > 12/28/00: MIT IA Passed > 12/28/02: MITIA Failed, LLR 0.4 gpm ~ 3000 psi. > 02/04/03: TTP set > 02/05/03: CMIT T x IA Passed to 3000 psi, pulled TTP This sundry request is to allow for continued injection of water. The following supports the request: · A CMIT-TxlA passed on 2/5/03 to 3000 psi against a tubing plug, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · An annual IA leak rate test will be conducted to monitor the leak severity. · A CMIT-TxIA against a TTP will be conducted every 4 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. . 4. Perform an annual IA leak rate test. / 5. Perform combination MIT Tubing x IA against a plug everyr4 years. . j. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. 6C~NED MAR 1 3 2003 TREE = , FMC WF! LI-EAD= FMC ACTUATOR= AXELSON KB, ELEV = 54' BF. ELEV -- ? !KOP = '2969' I~ax Angle = 64 ~ 10014' Dalum MD = 12357' DalumTV D= 8800' SS 09-12 SAFETY NOTES - WAIVB~ED WB.L. T x IA Communication. FWl only- TxlA leak found at bottom of tubing hanger. ii 2168' 5-112" CAM WRDP-2 SSSV NP, ID = 4.562"I 1 13-~8" CSG, 72#, N-80, ID = 12.347" H 2708' Minimum ID = 2.562" ~ 12583' I 3-112" CAMCO NO-GO NIPPLE I 5-112" TBG~, 17#, L-80, .0232 bpf, ID =4.892' I-'1 11675" ['rOPOF 4-112" 'rBG-PCH !t67S" TOP OF 7" LIaR H 19-6/6- csG, 47#, N-80/SOO95, ID= 8.681" H' 11821" . 12129' 4-1/2" TBG-PC, 12.6~, L-80, .0152 bpf, ID = 3.958" 12420" ITOPOF 3-1/2" 'roG-PC I-I 12420' 11472' 11500" 11634' 11675' 1241)5' 12411' 12420' 12564' 12574' 12583' H5-1/2" BAKER PBR ASSY I H9-518"X 5-1/2" BAKERSAB PKR I 5-1/2" Ol18 X NE ID= XO 5-112" X 4-1/2" H4-1/2" AVA BR. NIP. POR'IED SLV ID = 3.759" 7"X 4-1/2" BAKER FB-1PKR ! XO 4-1/2" X 3-1/2" BFC MP D = 2.815" (2-18164" HOLES)I BAKER FB-1 PKR 3-1/2" 'rBG-PC, 9.2~, J-55, .0087 bpi', ID = Z992" H 12587" PERFORATION SUI~I~RY REF LOG: BHCS ON 06/02/77 ^NGLEATTOP FERR 42 ~ 12~78' Note:. Refer to Production DB for historical perf data ,.~IZ E SPF INTERVAL Opn/Sqz [~TE 2-1/8" 4 12378 - 12408 O 06/04184 3-118" 4 12424 - 12457 O 09/07/77 3-118" 4 12472 - 12479 O 09/07177 3-118" 4 12491 - 12498 O 09/07/77 3-118" 4 12513 - 12532 O 09/07/77 3-118" 4 12554 - 12570 O 09/07/77 3-118" 4 12587 - 12502 O 09/07177 3-118" 4 12600 - 12620 O 04/07/95 3-118" 4 12612 - 12617 O 09/07/77 3-118". 4 12628 - 12645 O 09/07/77 7" LNR, 29#, N-80/SOO95, .D371 b~, ID = 6.184" 12790' 12800' 12587' 12586' 12586' 3-112" CAM NO-GO NIP, ID= 2.562" 3-1/2" TUBING TAIL J ELMTLIBING TAIL- LOGGEDS/3/95 I H3-112" BAKER SHE~ROUTSI.~ I COMIVENTS ORIGNAL COMFLE'nON CORRECTIONS CX:)IVlVlENTS PRUDHOE BAY UNIT VVELL: 09-12 IF_RIVE No: 1770070 APl No: 50-029-20239-00 8EC7, TION, R16F.., 1346' PSL & 74' RNL Wavier Check List · . Pa'D: I 7 -/- O0 7 Sundry #: '~ O ~ '- O 7 5 Order(s): Item Y/N Comments 1. Notified of pressure communication or leahge? .~ 2. Diagnostics plmmed/~? Method?. q ~' . ..... 3. Form 10-403 submitted requesting waiver?' ~ . , , , S. E~llT Part II verified? How? ~ .~,~.~ ~V,~ .~~.~.. f 0. 6. Area or Review examined? ~j ~, . · . . · ,=,,,, , ,,, ~,, Date: Definition of Terms T · OA LLRT Tubing Inner Annulus (tbg x csg) · Outer Annulus (csg x osg) Mechanical Integrity Test 'Combined test of annular spaces Leak Loss'Rate Test Intepit~ # Bar;iers . ' ....Condition "' 'AOGCC Notification Enhanced' ' ..... Operational Re'fictions Cme~ory Affected Requiremen_tq Monit,0Fing Reqnir~ment~1 , Normal 0 Full wellbore integrity MIT-4 years Water, slurry, gas, MI upon approval' .. TxIA co~,. uuica.tion (tubing Next business day if 200 psig ' Annual Mf~:~T 3 1 leak; packer leak quantifiable) change'in romulus pressure CM1T TxiA- 2~yrs .Water only '~ ' ' IAx~)A communication ' Annual MITLA & CMIT IAxOA Water only; annulus PSV w/alarms & set points - 2 1 Production casing leak MIT Tubing - 2 yrs ' for ESD < M1YP of next outer casing TxIAxOA communication Kill well; submit Sundry (10-403) Outlining 1 >l Rele~e beyond wellbore Next business day Daily reports until well secured repairs. .... ,,,, to Monthly Repo~ of Daily Ope~ting Parameters; Annulus Pressure Monitoring Matrix applies to the following well configuration: 1. Conventional completion per reguhtions; monobore on case by case basis 2. Production casing designed .for shut-in tubing pressure 3. USDW exemption or finding of no aquifer Reviewing Engineer: Recommended Action: Integrity Category: Waiverichklst.doc: 8/2/2002 ~NNE~ MA~ 1 3 2003 RE: 09-12 failed MITIA (PTD 1770070) Subject: Date: From: To: CC: RE: 09-12 failed MITIA (PTD 1770070) Men, 6 Jan 2003 13:57:57 -0600 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegfityEngineer~BP.com> Jim Regg <jim_regg~admin.state.ak.us> "- Winton Aubert (E-mail) ' 'AOGCC (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "AOGCC Tom Maunder (E-mail)" <Tom, Maunder(&.~admin.state.ak.us> Hi Jim. Attached is the completed MIT form for well 09-12, in non-compressed format'. Note the well is currently scheduled for a CMIT TxlA against a TTP. Let me know if you have any questions. Joe 659-5102 ..... Original IVlessage ..... From: Jim Regg [mailto:jim_regg@admin.state.ak. us] Sent: Tuesday, December 31, 2002 11:08 AH To-' Cubbon, .lohn R Cc.' Tom Maunder (E-mail); NSU, ADW Well Integrity Engineer; Winton G Aubert Subject-' Re: 09-12 failed MITIA (PTD 1770070) John - Please submit the 12/28/02 tests on the standard MIT Test Form. You will also need to submit a sundry application requesting apProval to continue operating this well with known communication by January 27. Attached to the sundry should be the results from the proposed diagnostics tests (PPPOT-T; CMIT TxIA; LLRT); planned diagnostics appear to be appropriate. As stated, please include this well on the monthly injection report beginning with your next report. Thanks. Jim Regg "Cubbon, John R" wrote: Hi Tom and Jim, SCANNED P'II'2 8 20113 According to our records, this well was diagnosed with a slow leak across the tubing hanger in October 1998. At that time MITIA's were passing and the AOGCC was notified via e-mail about the slow leak. The well was then allowed ~:' to resume injection with the stipulation that it only be Used for PWI. As. part of our monitoring program for the well we performed an MITIA to 3000 psi on 12/28/02. A total of 3 tests were performed and they all failed on pressure stabilization (estimated LLR of 0.4 GPM). The results of the tests are as follows: 1/6/2003 11:39 AM R~: 09-12 failed MITIA (PTD 1770070) Test # Initial IA Pressure '15 min. 30 min. 1 3000 80 70 2 3000 70 60' 3 3000 80 70 With your approval, our action plan is as follows: 1. Restrict the well to PWI only. 2. Perform a PPPOT -T. 3. Perform a CMIT T x IA to confirm casing integrity ( repeat at 4 year intervals). 4. Perform annual LLRT (T x IA). 5. Include this well on the monthly injector report to the AOGCC. Please let me know if you have any questions or if you prefer a different monitoring or diagnostics plan. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5102, x. 1154 iMIT PBU 09-12 12-28-02.xls Name: MIT PBU 09-12 12-28-02.xls ' '-- j Type: Microsoft Excel Worksheet (application/vnd.msexcel)] Encoding: base64 APR 2 8 2D03 2 of 2 1/6/2003 11:39 AM STATE oF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder{~iadmin.state.ak. us; Bob_Fleckenstein~iadmin.state.ak.us; Jim,Regg~}admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay/PBU I 12/28102 John Cubbon ~ Packer Depths, (ff.) ,~ Pretest Initial' 15 Min. 30 Min. we111o9-12 I Typelnj. Is l a[~l 11,5001 8,2651 TubingI 19001 19001 19001 ~9001',nte~va~Io P'T'D'I1770070I Type'.est I P I Test psiI 20661 I Casingl 9801 30001 29201 .28501 PIF~ Notes: Test failed on pressure stabilization. LLR = 0.4 gpm ~-1100 psi Differential. we'II ITypelnj' I I~O~OI I ' I Tu~'"~I I I I I Interva!l P.T.D.I I Typetest I I Testpsil I I Casingl I I I I P/FI- Notes: P.T.D. Notes: P.T.D. Notes: Well P.T.D. Notes: Type 14. Type 14. Type 14. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test ' ' 4 = Four Year Cycle V ='Required by Variance T = Test during Wotkover O = Olher (describe in notes) ~NED ~P~ ~ ~ 2~13 MIT Report Form Revised: 06119102 MIT PBU 09-12 12-28-02 Re: 09-I 2 failed MITIA (PTD 1770070) Subject: Re: 09-12 failed MITIA (PTD 1770070) Date: Tue, 31 Dec 2002 11:08:29 -0900 From: Jim Regg <jim_regg~admin. state.ak.us> Organization: AOGCC To: "Cubbon, John R" <CubbonJR~BP.com> CC: "Tom Maunder (E-mail)" <tom_maunder~admin.state. ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com>, Winton G Aubert <winton_aubert~admin. state, ak.us> John - Please submit the 12/28/02 tests on the standard MIT Test Form. You will also need to submit a sundry application requesting approval to continue operating this well with known communication by January 27. Attached to the sundry should be the results from the proposed diagnostics tests (PPPOT-T; CMIT TxIA; LLRT); planned diagnostics appear to be appropriate. As stated, please include this well on the monthly injection report beginning with your next report. Jim Regg "Cubbon, John R" wrote: Hi Tom and Jim, According to our records, this well was diagnosed with a slow leak across the tubing hanger in October 1998. At that time MITIA's were passing and the AOGCC was notified via e-mail about the slow leak. The well was then allowed to resume injection with the stipulation that it only be used for PWI. As part of our monitoring program for the well we performed an MITIA to 3000 psi on 12/28/02. A total of 3 tests were performed and they all failed on pressure stabilization (estimated LLR of 0.4 GPM). The results of the tests are as follows: Test # Initial IA Pressure 15 min. 30 min. 1 3000 80 70 2 3000 70 60 3 3000 80 70 With your approval, our action plan is as follows: 1. Restrict the well to PWI only. 2. Perform a PPPOT -T. 3. Perform a CMIT T x IA to confirm casing integrity ( repeat at 4 year intervals). 4. Perform annual LLRT (T x IA). 5. Include this well on the monthly injector report to the AOGCC. 1 of 2 12/31/2002 3:05 PM Re: 09-12 failed MITIA (PTD 1770070) Please let me know if you have any questions or if you prefer a different monitoring or diagnostics plan. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5102, x. 1154 Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 2 of 2 12/31/2002 3:05 PM INJECTION WELLS WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD. Well Max. Injection Rate During Last 3 Months -p~ (BWPD) './ 3-11 /v~(-? 8000 3-12 /d~6 P 33000 3-17 p;~rc 19000 9-12 ?/~.. 16000 9-14 /ua~- f~ 36000. 9-17 /~ P 27000 9-19 /ve+P 28000 16-2 F/~,~ 7000 16-11 pl~,~,~_ 7000 I1,1N4/16 Surface Pressure at Maximum Rate (ps'ig) Tbg 9-5/8" Csg 13-3/8" Csg 1200 1200 0 1100 1100 400 8OO 8OO lO0 9OO 9OO 1300 1300 200 1100 1100 0 1200 1200 0 800 1200 1100' 1400 200 Probabi 1 i ty of Passing State Test ~/~Low ~qedium l~?Medium ~';>None (~Low m~ High .. · l~,~ed{um ? Commen ts 9-5/8" pressure responds immediately to changes in tubing pressures Bled 9-5/8" pressure from 875 to 455 pstg in 3 minutes, built up 80 psi in .( 1 hour, built back up to 860 psi in 20 hours. Bled 3 Bbls ot1 and gas from 9-5/8" in :,..., 10 minutes, pressure decreased from 1050 to 200 psi, built up 120 psi in 1 hour built back to 1000 psi in !8 hours· Bled 9-5/8" pressure frOm 795 to 350 psi, built up 200 psi in I hour, built back to 800 psi in 5-1/2 hours· Parted tubing at 13' ,.~/.. .... ~.i ,..,-.~-~ ~, ~'? · . ~,.,.;./,j ..... ~ ~ ,.)~,,, . j.,.., 't.,. Bled 9-5/8" pressure from 625 to 250 pstg, built back' to 625 psi in 1 hour· Bled 10 gals of H~O from 9-5/8", pressure decreaseU from 220 to 0 psig, built up 80 psig in 4 hours. · Bled 40 gals.diesel from 9-5/8", pres- sure decreased from 880 to 500 ps tg, butlt up 50 pst tn I hour, butlt back to 850 psig in 10 hours. Has' gas lift mandrels; 9-5/8" pressure responds immediately to changes in tubing pressure· [las gas lift mandrels. O ! SURFAC£ LOCATXON: TOP ALL OEP~S 9-12 SPUD 3A.'~.: 5/3i77 I34G' N & 7S' £ of SW ct. SeG. 1, :!ON, R!SE, UH ~30' S & ~7~8' E of NW Ct. Sec. ~, T10N, R~GE, ~ 12376' ~O HOL~ ~qG~ THR~ SAD~R~H~T: C~PLET~ON. ~g: 5/10/77 APZ ~ 50-029-ZOZ29 5~', I7t, N-80 PLASTIC COATED TUBING 5~,' x 9-5/8" Annulus Fluia: ].0.6 CaC12 & Diesel 2!98' Otts RQY SSSV Nipple [D 4.562' ~A,'dGE.~ ZS' ~0o ~Z708' 13-3/B', 7Z#, N-80 w/ 5300 'sx 11486' 11540' 11547' 11584' 11653' .~i11715' Otis XA S11dtng Sleeve Otis XN Landtng Ntpple BOT PBR Assembly Baker SAB Packer Otis Xg ~ipple ID 3.813' Baker Shear Out Sub Bott~ of ~", 12.6#, N-BO Tatlpipe Top of Liner 9-5/8', 47~, N-80 & S00-95 ~/ ~000 sx ~ ~EF :ONE FT. EPF ..~ 12378' - ~2~08' ~'~5 ~ 3--0- '~- 12424' - !2457' BHCS 2 33 ; 12472' - 12479' ~HCS 2 7 ~ ~2=91' - 1Z~gB' B~CS 2 ' ~ 12513' - 12532' BHCS 2 19 ~ 12554' - 12570' BHCS lS 16 ~ 12587' - 22602' SHeS IB 15 : 12612' - 12617' BHCS lB 5 ~ -i 12628' - 12645' BHCS lB 17 ~ 12706' PBTD 1279G' 7", 29~, N-80 w/ ~00 sx 12800' TD Perfec 6/-/~ ~e~ed ~y?.'~? Pe~fec ~/?/77 Perfed g/7/77 Perfed 9/7/77 ~erfeU 9/?/77 ~erfed 9/7/77 ~erfed 9/7!77 ~erfe~ ¢/7/7~.~/ / ~, 6/84 ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 March 16, 1999 Mr. Blair Wondz'ell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-0360 Re: MITIA information on DS 9-12 Injector Dear Mr. Wondzell: Attached please find the field test forms for MIT's on 9-12 WAG injector. The MIT's were performed while the well was on PWI injection service. The purpose of the MIT's was to try and pinpoint a communication problem the well had while on MI service. As I previously mentioned, we have no intent of resuming MI injection into this well. Should we want to do so, we believe some type of repair of the tubing hanger thread leak would be necessary. Please call Joe Anders or me at (907) 659-5102 if you have additional questions. Sincerely, Jerry Dethlefs Problem Well Specialist Annular Communicaion Testing Mechanical Integrity Test DATE: 10/15/98 TYPE MITIA to 3000 psi WELL: 9-12 hilT: PASS Well Status: Injection TBG: 1650 CONTROL: 2400 INITIAL PRESSURE DATA TYPE: Produced Water IA: 1530' OA: 650 BALANCE: PRE-TEST PREPARATIONS BLED IA. FRO 1530 SIT 300 TYPE OF FLUID AND VOLUMlg BLED: 2 bbls of fluid PSI IA FL HRS 5 surface MIN TEST PRESSURES TIME TBG IA OA COMMENTS 8:20 1650 300 650 START PUMPING TIME 9:04 1650 3000 770 START TEST 9:19 1650 2920 900 -130 9:34 1650 2840 80 980 -80 ,. START TEST START TEST START TEST TOTAL VOLUME PUMPED: 5 BBLs of methanol down the IA FINAL PRESSURES TBG: 1650 IA: 250 OA: 750 __ OBSERVATIONS / COMMENTS FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! X 1-- FLAG THE CASING VALVE WITH LOAD AND TEST INFORhlATION -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. -~ NOTIFY DRILL SITE OPERATOR OF TEST RESULTS~ VOLUMES PUMPED AND STATUS OF WELL Witness: Kevin Parks/RJ' ~a~NULAR COMMUNICATION TEsTI,,,G LIQUID LEAK RATE TEST DATE: 10/22/98 TESTED BY: KLM/RJ Well: 9-12 Well Status: Shut In TBG: 650 INITIAL PRESSURE DATA TYPE: Seawater IA: 30 CONTROL 1150 OA: 500 BALANCE 1050 PRE-TEST PREPARATIONS IA FL ~ SURFACE OA BLED FROM PSI TO TYPE OF FLUID AND VOLUME BLED: FL ~ SURFACE PSIIN MINS TEST PRESSURES TIB~IE TBG IA OA RATE INCHES BBLS GAL. 10:24 650 30 500 11'12 620 3000 520 9 3/4 158.9 11:42 600 2830 600 11:45 600 3000 630 0.5 9 142.8 12'15 ~ 600 2810 640 12'19 600 3000 650 0.5 8 1/4 126.1 12:49 600 2810 680 12:54 600 3000 690 0.5 7 1/2 108.8 Start pumping Start LRT TOTAL TEST VOLUME PUMPED: 50 GALS TOTAL TEST TIME: 102 LEAK RATE AT: 0.5 GPM ~ 3000 TOTAL VOLUME PUMPED 8 BBLS MINS FINAL PRESSURES TBG: 1640 IA: 100 OA: 820 OBSERVATIONS / COMMENTS Annular Communicaion Testing Mechanical Integrity Test DATE: 10/22/98 TYPE M1TIA to 3000 psi WELL: MIT: 9-12 PASS Well Status: Shut In TBG: 650 CONTROL: 1050 INITIAL PRESSURE DATA TYPE: Produced Water IA: 30 OA' 500 BALANCE: 1150 PRE-TEST PREPARATIONS BLED IA FROM 80 SI T 30 TYPE OF FLUID AND VOLUME BLED: PSI N/A HRS IA and OA FL Surface 10 MIN TEST PRESSURES TIME TBG lA OA COMMENTS 10:24 650 30 500 START PUMPING TIME ,,, 10:45 650 2050 520 START TEST 11:00 650 1955 95 520 11:12 620 3000 520 START TEST 11:27 620 2900 100 540 11:42 620 2830 70 560 11:45 600 3000 600 START TEST 12:00 600 2900 100 630 12:15 600 2810 90 640 12:19 600 3000 650 START TEST 12:34 600 2900 100 650 12:49 600 2810 90 690 TOTAL VOLUME PUMPED: 8 BBLs of diesel down the IA FINAL PRESSURES TBG: 1640 IA: 100 OA: 820 FINAL STEPS !x OBSERVATIONS / COMMENTS MUST BE COMPLETED AND CHECKED OFF!!! X -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. -- NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUBIPED AND STATUS OF WELL WitneSs: Kenny MorSe/iRotand Johnson annular Communicaion Testing Mechanical IntegritY Test DATE: 12/20/98 TYPE MITIA to 3000 psi WELL: 9-12 MIT: PASS Well Status: Iujection TBG: 1750 CONTROL: 2200 INITIAL PRESSURE DATA TYPE: Produced Water IA: 1350 OA: 850 BALANCE: PRE-TEST PREPARATIONS BLED IA FROM 1350 SI T 900 . TYPE OF FLUID AND VOLUM]g BLED: FLUID PSI HRS 5 MIN IA an d OA FL SURFACE TEST PRESSURES TIME TBG IA OA COMMENTS 13:40 1750 900 500 START PUMPING TIME 14:15 1750 3010 600 START TEST 14:30 1750 2930 80 690 "14:45 1750 2850 80 690 START TEST START TEST START TEST TOTAL VOLUME PUMPED: 5 BBLs of methanol down th IA FINAL PRESSURES TBG: 1750 IA: 600 OA: 400 OBSERVATIONS / COMMENTS FINAL STEPS 5IUST BE COMPLETED AND CHECKED OFF!!! 1' X 1-- FLAG THE cASING VALVE ~VITH LOAD AND TEST INFOR3~TION l" FLAG THE WING VALVE IF SI AT TIN[E OF LOADING AND TESTING. X ~ -- NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL Witness' KennyMorse/Roland JohnSon DS 9-12 Injector Subject: DS 9-12 Injector Date: Mon, 15 Mar 1999 15:30:20 -1000 From: "PRB Problem Wells" <P 1041 ~mail.aai.arco.com> To: Blair_Wondzell~admin.state.ak.us CC: "PRB Problem Wells" <P 1041 @mail.aai.arco.com> Blair: As per our conversation today regarding WAG injector 9-12 at Prudhoe Bay, this email summarizes the status of a known tubing by annulus leak. This well has had a problem when on MI service of requiring excessive bleeding of the inner annulus to maintain pressure below 2000 psi. There is no operational problem when the well is on PWI injection. The well passed an MITIA on 10/15/98, then again on 10/23/98. On 10/28/98 we ran a Video log, and found T x IA leak at the bottom of tubing hanger; it appears to be a thread leak. No other leaks were found. One final MITIA was ran 12/20/98, which passed @ 3000 psi. We have no intent of putting MI into this well in the future. Should we determine there is a need for MI, some kind of repair will be done before MI injection is allowed. Since the well passes MIT's we consider it to be competent for PWI injection. Jerry Dethlefs ARCO Problem Well Specialist 659-5102 1 ,.,~c 1 3116/09 8:1 6 AM · STATE OF ALASKA ALASK~'--"'L AND GAS CONSERVATION C MISSION REPORT SUNDRY WELL OPI=RATIONS 1. Operations performed: Operation shutdown Stimulate ,~ Plugging , Perforate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 4. Location of well at surface 5. Type of Well Development Exploratory Stratigraphic 99510-0360 Service X 1346' FSL, 75' FWL, Sec. 1, T10N, R15E, UM. At top of productive interval 1173' FNL, 1488' FWL, Sec. 7, T1 ON, R16E, UM. At effective depth At total depth 1330' FNL, 1718' FWL, Sec. 7, T10N, R16E, UM. Other 12. Present well condition summary Total depth: measured 12800 feet true vertical 9076 feet Effective depth: measured 12584 feet true vertical 9024 feet Junk(measured) Casing Length Size Cemented Conductor 84' 20" 266 Sx Arcticset Surface 2678' 13-3/8" 5300 Sx Arcticset Production 12075' 9-5/8" 1000 Sx CIG & 3000 Sx AS Liner 969' 7" 400 Sx CIG 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-12i 9. Permit number/approval number 77-7 10. APl number 50 - 029-20239 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) PBTD Tagged @ 12584' MD (10/31/96). feet Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ ,~. '~'I,1 · ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 ,-,~- P, AID Date //.-/~' ... ~(=, 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x Subsequent to operation 16. Status of well classification as: Oil Gas Suspended 26O66 -- 1743 14. Treatment description including volumes used and final pressure ~C 0 ~ 799~' Representative Daily Average Production or Injection D~-{~''~' u,~ ~ ~as Cons CD-- · OiI-Bbl Gas-M~ Water-Bbl Casing Press~"ChOra~u~[~l~ure Prior to well operation .... 11479 -- 1999 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached RECEIVED Perforation depth: measured 12378 - 12408'; 12424 - 12457'; 12472 - 12479'; 12491 - 12498'; 12513 - 12532'; 12554 - 12570'; 12587 - 12620'; 12628 - 12645' true vertical 8870 - 8892'; 8904 - 8929'; 8940 - 8945'; 8954 - 8959'; 8971 - 8985'; 9001 - 9013'; 9026 - 9050'; 9056 - 9069' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 11675' MD; 4-1/2", 12.6~, L-80, PCT@ 12417' MD; 3-1/2", 9.2#, J-55, PCT @ 12587' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 11500' MD; Baker FB-1 Packers @ 12411'& 12574' MD; Camco WRDP-2 SSSV @ 2168' MD. SUBMIT IN DUPLICATE Measured depth True ve~icalde~h 113' 113' 2708' 2708' 12129' 8634' 11821-12790' 8417-9127' 9-12i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE PERFORATION BREAKDOWN TREATMENT 10/14/96: MIRU & PT equipment to 6200 psi. Pumped a High Pressure Perforation Breakdown Treatment through the perforation intervals located at: 12378 - 12408' MD (Z2) 12424 - 12457' MD (Z2) 12472 - 12479' MD (Z2) 12491 - 12498' MD (Z2) 12513 - 12532' MD (Z2) 12554 - 12570' MD (Z2) 12587 - 12620' MD (Z2/1B) 12628 - 12645' MD (Z1B) Ref. Log: BHCS. Pumped Stage 1: a) 250 bbls Crosslinked 30# Gel @ 38 bpm, followed by b) 250 bbls Slick 1% KCL Water @ 42 - 53 bpm, followed by c) Shutdown. ISIP @ 1580. Resumed pumping Stage 2: d) 500 bbls Slick 1% KCL Water @ 60 bpm, followed by e) 100 bbls Slick 1% KCl Water w/4423 lbs of 20/40 proppant scour #1, followed by f) 75 bbls Crosslinked 30# Gel sweep @ 60 bpm, followed by g) 425 bbls Slick 1% KCL Water @ 60 bpm, followed by h) Shutdown. ISIP @ 1750. Resumed pumping Stage 3: i) 500 Slick 1% KCL Water @ 60 bpm, followed by j) Shutdown. Resumed pumping Stage 4: k) 500 bbls Slick 1% KCL Water @ 60 bpm, followed by I) 100 bbls Slick 1% KCl Water w/4400 lbs of 20/40 proppant scour #2, followed by m) 75 bbls Crosslinked 30# Gel sweep @ 60 bpm, followed by n) 425 bbls Slick 1% KCL Water @ 60 bpm, followed by o) Shutdown. Resumed pumping Stage 5: p) 1233 bbls Slick 1% KCL Water @ 60 bpm, followed by q) Shutdown. Rigged down. RECEIVED Returned the well to produced water injection & obtained a valid injection rate. · 5/23/95 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-rN: Sherrie NO. 9471 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D'S. 2-31 ~r/--- lO__~ TBG CUTTER RECORD 043095 1 1 ' D.S. 3-06 '~ (,¢-' ~ O M.I. INJEC LOG 0421 95 1 1 D.S. 3-31 ~ ~4,~ 2__ CNL 050295 I 1 D.S. 7-32 c~ ~_/5-O PERFRECORD 042895 I 1 D.S. 9-8 '~ Lc" '70 PERF RECORD 0 429 9 5 1 1 D.S. 9-12 ~-)-" '~ INJEC PROFILE 0503 95 I 1 D.S. 11-16 ST1 ~'~-'7~ PERFRECORD 042995 1 1 D.S. 11-23A c~ ~., ~ I PERF RECORD 0501 95 1 1 D.S. 11-28 . ~c~--'70 LEAK DETECTION 042895 1 1 D.S. 11-35 ~ ~"(¢~..~ CNL 050295 1 1 D.S. 11-36c~'~-~ DUAL BUST TDT-P 050195 I 1 D.S. 11-36 ~W"~ RST 042195 I 1 .D.S. 14-5A ~.~--" / PERFRECORD 042795 I 1 _D.S. 14-22A ~¢~ ¢-~,- / ~ PERF RECORD 0427 95 1 1 ._D.S. 14-28~,~-- ! ~ LEAK DETECTION 0429 95 1 1 ,D.S. 14-33 ~.~- /~_~ CNL 042795 1 1 D.S. 14-43 :~" ~0~ DUAL BURST TD~-P 042795 I 1 D.S. 16-12 ~ I'" ~,- ~ TBG CUTTER RECORD 043095 I 1 D.S. 18-02A ~0~5 -.~O PERFRECORD 050295 I 1 D.S. 15-19 95176 DUAL BURST TDT-P 050495 1 SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: ,, ,. ,, 2 1995 Alaska 0il & Gas 0ens. Commission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie APR 2 7 ~995 Alaska Oil & G~s Cons. Commission Anchorage NO. 9431 Company: 4/26/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Prudhoe Bay Floppy RF Sepia DIR MWD Disk D.S 2-24 ~'-"7 / CNT-D 040695 1 1 D.S. 3-13 ~ ~--// PERF RECORD 040795 I 1 D.S. 3-13 PERF RECORD 040895 I 1 D,S. 4-13 '7 ~'- =~ ~ INJECTION PROFILE 040795 I 1 D.S. 9-10 '7 ~' ~ 2._ PERFRECORD 040595 I 1 D.S. 9-12 '7'~ -'7 PERF RECORD 040795 I 1 D.S. 15-17 ~' CNT-G ,040595 I 1 D.S. 18-24 ~c~o (p.~ ;TBG. CU'I'rERRECORD 040695' I 1 .., .., SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: STATE OF ALASKA ALASI' :::)IL AND' GAS CONSERVATION t MMISSION REPORI' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARC© Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1346' FSL, 75' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1173' FNL, 1488' FWL, Sec. 7, T1 ON, R16E, UM At effective depth 1290' FNL, 1659' FWL, Sec. 7, T1 ON, R16E, UM At total depth 1330' FNL, 1718' FWL, Sec. 7, T10N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic Service APR 2 4 1995 Litt& ~a~ ConS, Oommissio~ Anch0r~," 6. Datum of elevation(DF or KB) 54' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-12i 9. Permit number/approval number 77-7 10. APl number 50 - 029-20239 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 84' Sudace 2678' Production 12129' Liner 969' 12800 feet 9135 feet Plugs(measured) PBTD Tag @ 12696' MD (3/27/95) 12696 feet ' 9108 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 266 sx Arctic Set 113' 113' 13-3/8" 5300 sx Arctic Set 2708' 2708' 9-5/8" 1000 sx Class G & 3000 sx Arctic Set 1 2129' 8634' 7" 400 SX Class G 11821 '-12790' 8417'-9127' Perforation depth: measured 12378-12408'; 12424-12457'; 12472-12479'; 12491-12498'; 12513-12532'; 12554-12570'; 12587-12620'; 12628-12645' true vertical 8870-8892'; 8904-8929'; 8940-8945'; 8954-8959'; 8971-8985'; 9001-9013'; 9026-9050'; 9056-9069' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 11675' MD; 4-1/2", 12.6#, L-80, PCT @ 12417' MD; 3-1/2", 9.2#, J-55, PCT@ 12587' MD. Packers and SSSV (type and measured depth) Baker SAB pkr @ 11500', Baker FB-1 pkrs @ 12411' & 12574', Camco WRDP-2 SSSV @ 2168' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4303 Tubing Pressure 1912 Subsequent to operation 4374 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 1940 Injector Signed _~_,,{,~ .'~, Form 10-404 Rev 06/15/88 Title Engineering Supervisor Date /-7/-/~" ?,~ SUBMIT IN DUPLICATE 9-12i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/27/95' RIH & tagged PBTD at 12696' MD. 4/7/95' MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 20' of perforations as follows: 12600 - 12602' MD (ZIB) 12612 - 12617' MD (ZIB) Added Perforations: Ref. Log: BHCS 6/2/77. Ref. Log: BHCS 6/2/77. 12602 - 12612' MD (ZIB) 12617 - 12620' MD (ZlB) Used 2-1/8" strip carrier & shot 4 spf at 0 degree phasing. overbalanced. POOH w/perf gun. Noted all shots fired. Shot perforations while well was Rigged down. Returned the well to produced water injection & obtained a valid injection rate. 8/3/94 NO. 8832 600 W. International Airport Road Anchorage, AK 9<)618-1199 ATTN: Sherfie Company: Alaska Oil & Gas Cons Comn , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar 1~.~. 5-5 -~ ~ ~ ~ TUBING CUTTER RECORD (7-18-94) 1 1 I~S~. 12-6A d~ ~;~._.- .%'/-~ PERF RECORD (7-17-94) 1 1 D~. 9-12 '7 '7-- 0-"7 ' INJECTION PROFILE (7-15-94) 1 1 DT~. 17.6 ~'C3 "'1 _~ Z-- INJECTION PROFILE-STATIC SURVEY (7.19.94) 1 1 t~.S. 7-30 ~-~-~-.-/~ PRODUCTION pROFILE (7-13-94) 1 1 D75~.$.33 '"-~J---(~'..,~ TDT-P BORAX (7-17-94) 1 1 D~.'18-29A' ~ .-o VO PRODUCTION PROFILE (7-14-94)' 1 1 D.S. 16-25 ~ 3- -.~'l PRODUCTION PROFILE (7-16-94) 1 1 SI PI urn one copy of this transmittal to Sherrie at the above address. Thank you. DATE: l:;.: iii: !::' iii: i:;: iii: i"-..! t.; ~,ii: ' (:'~ F;:. E: CJ E: ~.":~ $ E)L) H C.,' I... Iii: J::' i: i",! (:~ L.. ;?; F' E i:;..' F' L. E t::'~ I..'.: ii:: iii: f iii: '..:i: 'f' .[ 0 N C 0 !... L../:'~ :[ N ...! iii: C; 'f' :I7 (:)i'.i C C)L.. L.. r:'-', R ..-"" J::' ii:: F.: F: (:.;. (:'~ ;5." L..L F' '¥' i'i f::'~ ,".,,: J.)i:;..' t:i.',... ,~:,, ..... ,.:' o"t,., ,",'. r",.... i::' E F..' F' !:;~ C t..~ L. L.. ,":'-"~ t:;.: /t::' l:i; t".: F' :t: i'.-I '~:: "': 'v i. t:;' f"i · .,... ~... ~..... *'"Q ~ :':' I:':" i::' :.,,..., ........ ..,', :.... ~..~ I:" F.'. C~ F' F..' t) J;) t..1 C 'i" 2!: (.:~ N C C I... F:' 1:;..' (7) :O t.J C"f' 2[ L) N' E: ~;::.' k.. F' F;:. (:) ]) U C '¥ I: (:) N C ;,.') L.. I... r:':~ i:;.:/F:' Iii: I:;: F:' F:' Ii" F',' F I:;.'. E L'. F' iii: F.: F' f;.'. Iii: C r)F; ~;' :[ iq J f.'"' C T :[ t:) N ;!: N,J E C 'f' !::'; E (':~ ;!;' Iii: ;? :I: (::, N ~'.'".'~ N 5': I:;.: Iii: T LJ I:;,' N F,'~::'~" Iii: ]: ~.;' fii: ;0 /..';':",," · -I (:~".." J:.:; (:i N 'r f". I::' ;"' (:i "f' ~ .*, ,,..' i .... ..:' C C)F:' Y (:'~ S' I:;..' li.'i C Iii: .[ F:"f' fL !::' ARCO ALASKA, INC~ F'.O. BOX 100560 ANCHORAGE, Ai_A~KA 995 ~ 0 DATE' 8-29-89 REFERENCE' ARC(] CASED HOLE FINALS t-t t 8-'i 2-89 PRODUCTION F'ROFILE 3-t ;3 8'-7-89 INJECTION F'ROFII_F: 4-`5 8-t 9-89 TUBING CUTTER 5-,5 8-i 2--89 PITS 7-8 8-t 0-89 F'RODUCTION PROFILE 7-,5,5 '7-2.G-89 PERF RECORD 9-4 7-t9-89 PERF RECORD 9-t2 8-S-89 INJECTION PROFILE 9-28 7-t 9-89 F'ERF RECORD ti-5 7-2,5-89 F'ERF RECORD tl-t7 8-tt-89 LEAK DETECTION t ,..-,;.3 8-7--89 INJECTION F'ROFII..E t 4-i 2 8-t 6-89 COLLAR/F'ERF t 6-t 8 8-2t -89 TEHP/CAF'/GR/SPINNER t?--9 8-9-89 PRODUCTION F'ROFILE t8-20 8-tt-89 FLUID ID/PITS/LEAK PLEASE SIGN AND RETURN THE ATTACHED COPY DETECTION RUN t , 5' RUN i, .5' RUN i , 5' RUN i , 5' RUN t , 5" RUN i , 5' RUN t , 5' RUN 4, 5' RUN t , 5' i;.'UNt, ~' RUN t, .5" RUN t , 5' RUN t , 5" RUN,~ I&'2, RUN t , 5' [;:UN t , 5" AS RECEIF'T OF DA'FA · CAMCO CAHCO A'f'LA,~' C A iq C 0 CAMCO HL2' I'-lL_~ CAMCO HL;~' HL~ CAMCO CAMCO ATLAS' HR,~ CAMCO CAHCO HAVE A NICE DAY'! '~ Anchorage DISTRIBUTION · ,."" CENTRAL FILE;~ -,-"'F'HILLIF'..~ · .-~CHEVRON F'B WELL FILES D & M R & D .~ EXTENSION EXPLORATION ~ BF'X ~ EXXON .." 3'TATE OF ALASKA MARATHON ~ TEXACO · ~ HOBIL . THE CORRECT AF'I$ FOR THE CORRECT AF'I~ FOR 50-0~9 9-4 I$ ' tt-5 Iff 50-029-20670. ARCO ~-~L.A~KA, INC F'.O. BO]( ~0(:)360 ANCHORAGE, ALASKA DATE' 8-i 6-88 REFERENCE' AR[;O CASED HOL_F FINAL. S-' '~.- i -'~ -,.=b-~:8"-' "" LEAK DETECTION HPF'h~ S-24 7--28-88 LEAK DETECTION TEMP S--24 7-3~-88 LEAK DETECTION 7--~9 7-29-88 RRODUCTION F'ROFILE 7'-~_~ 7-29-88 PRODUCTION PRC]FILE 9--~2 7-2'? , 28-88 INJECTION I='ROF][LI~ ~ ~ -& 6-27-88 COL_L. AR/F'ERF ~ ~ -~ 2 7-3G'-88 COLLAR ~4-'25: 7-~-'88 DATA FRAC TEHP '-.~.4-88 ~ ~- ~ 2 6 o- . C 0 L L A R / F:' E R F- ~6-'~ 8-~-'88 INJECTI()N PROFILE TEMF' PLEASE SI R E C: E I V E D HAVE ANI ;],'ALLY HOF'F'ECK ER A T 0 - t.~,.":" '" "-,- RLJN i, RUN i , RUN t, .5' .F:,'UN i , RUN i , I:~'. U N 4, RLJN i, I:;,' U I'".~ RUN 1:;: U N 'i , I:;.'.UN t, 5" GN AND F(E'T'URN j'HI:j_.~'qS¥}"/~I.~IFD CUF'Y AS I;.'.ECEiI::'i" OF' DA'FA.' CE 'm~'r ~ AI~.~DII & 6as Cons. Commlsslon ~ '' N~chorage _ ~ CE:NTRAL. F ]: L.F';~' · .-"'CHEVRON. . D & M "~ EX'FEN:};' '[ F~N EXt':'LORA'i" I ON °1¢ EL ¥ X 0 N ~"i A tR A "1" i- -t 0 ~'q · "' i',iO B I L '11' .. '"' P H I I.. L. I F:'$ ,.~. ' F' B W F' I_ I.. F' .[ L. i::',S' F;: & i) · .-;~' A F' C "- S:i"ATI.': OF-' AL.A,':_..:KA -.- 'i' IF, X A C 0 (;ANCO CAMCO CAMCO CAM(.;(] CAMCO C A M C' 0 [,EAR CAPiC[J CAHCO b E A R CAriCO P. fl.. RI3. X t t3(~.~At3 . . R'F'FFRF'i~I/':F: ~Rr.'.O r.'..~,.~ED HFII Ic.. F'TN~I F: ~':~ H F: Fi C.. ~':~ M F: f'l 1;:,-.'% M f': f'! m F~ ~.~ H ('; f'~ F': r.".'~ N f'; FI ...... ,, 1~ T .~ T RI: ia I ,I :1' T I:ll'J, '"'...C ..... F N T I:~. A L F T ... F..~, :~ . ~×TEN.~.T.I.1N EXF'I. (:]R~TT(:)N · ,,.'"' EXX'()N HAI:;:~TH('IN ~ H .E)EI.T I.. .p PH T I...I....[ · ,~ PR: ,tJ,FI.. :,ti, F T 1. I~S R & l). ARCO ALASKA, ANCHORAGEs, AI,..A~A REFERENCF: .ARCO PRE~$1,1RF l')nT~, 9-?.-¢-R7 ~I!!'~FA'£.'.F F'E'F'.~.?!!I;,'.F' Tf;:~.~.,tq:~l'F'.NT Pl."f':'-.'' 9:::Z(L') ' ?- 'i/;:- RR RHF'-::,~'¥AT'T Ft.' F;l~'~-hn IF'- NT q.,,.;j~zi '2- ::)f~.,, F4f:~, 'f:[ !..t P.-::,? ;T ~a T T f": · ,-: !" . .I" , 'T' F'I F','~?.FI ~"'I'F,N ~-~.~,J~"~ ::,Y ~:.~,.?. r','"r .... ~'F' , E ~,M~r't.n - ARCO ALaska, Inc~ P,O. Box ~J-OS6(.) Anchorage, A Lms'km 995~0 DATE: 'l 0-6-'87 REFE:RE:NCE: ARCO Ca.s'ed Hole F'inal. 9-~ ''~ re-2S-87 FI. opetro/ Product ion I...ogging RLI'q -?, ..~" Ptea..~e sign Received By HAVE A NIC[~. Record.s F'ro ATO-~ 529 and return the a'ttac'.hed/:opy a.s',,~>e..c:eipt ..................... .~W~-7''': ..... ",~ ----*-Z~'~ '- TRAN,? $875i5 Approvecl ............................................................. D I ,STR I BL!'/T. ON of da~a ,~ Cen'l'ra[ Fi les $ F'hi [[ip..~ Chevron F'B Wet. t. D & M R & I) ExTen.s i on Exp l. ora'~ i on ~ ,~AF'C Exxon ~ Sta~e of Marathon $ Texaco Mob i I. Fi[es AI. aska ARCO Al.a.~:;ka, Inc, P~O. Box '10~36~ A'ncl'~orage, A[ask~ DATE]' Apri I. t, t98'? R E I:r F.:.: R E N C E ' A R C'- 0 Cas'ed HoLe F'inaL :. ,-~ o 5 ' """"" 9 .... t 2 t ~.)-,~. :.) --- c. 6 ('.; F.'. / C C: L. T i e i n I... o g R u n 4, ~9-t2. ~g-~5--.86 Dep'th De't'erminatiir.,n Run 3, 5' ,,,i 9 .... 'i 2 1 ~')- 2 (:) - 86 F:' a c k e r & ,J B / fi; I:;.'. R u_ nz,' I:;.'. t~ 'n 3, 5;" "~ 9-t"2 t(.) .... t3-.86 Fiul.'~'J F'Jngered C:al. Jper Run 'l, 5" D I ;:':-' T R I B tJ '1" I (:.1 N ARCO ALaska, InC.' P,.O. Box t00S60; Anchormge, A la~k'm DATE' March t2, t987 REFERENCE' ARCO Ca~'ed HoLe Final 9-t_;~ .7-1 .... 87 Injec!'io'n P¥'ofi Le Ru'n t, ..,"~'" 9. .... ID S-4--'87 Ir, jecfion erofi Le R~.~ f, ..,':'-"" q ~ ..... t c. --- ? ::.r,... 4'-- 8 ,'L~ a m m a !:;.'. a y F;.'. ~ ~-~ t , 5" F'Lea~e sign and retur~ the atta...c:hed copy/'~'J~ receipt of data, Ro~¥~ne Peek ATO-.- i 529 "f'RAN$ ~:87t 60 /L~ Approved .........................................................................i.~L. D t ;~ T R I B U T I 0 N C 61 I~l C 0 C8fllco ARCO Alaska, Anchorage, Ala.s:ka. 995J0 DATE February 2 5, t987 REFERENCE' ARCO Cased Hole Final 3-14 8-23-86 CET Rug t, 5· ~"ch 4-t7 6-6-86 Perf. Record Run t, 5" $ch 4-t8 6-6-86 Perf, & CCL Run t, 5" ~;ch 4-2t 6-1t-86 F'erf, & CCL Run t, 5" .~ch 4-~2 6-5-86 Perf Record Run ~, 5" ~ch 4-24 6-6-86 Perf~ Record Run J, 5' 3ch 4-27 6-4-86 F'erf~ Record Run J, 5' Sch 4-28 6-4-86 Perf~ Record Run J, 5' 3ch 9-~ ~ 8-7-86 CET Run i , 5" ~ch J4-4 8-J4-86 Repe.rf. Record Run ~, 5' ~ch J6-24 8-2t-86 Perf~ Record Rui~ t, 5' 3ch JT-J~ 5-J~-86 CompLe¢ion Record Run ~, 5' ~ch J7-~4 8-29-86 Add-Perf~ Record Rul~ J, 5' ~ch Please sign and return fhe attached copy as receipt of data. ATO-t 529 ~ ~ G~s Gon~ GommJssion / ~ Anchorage TRANS ~87t27 ~/ / .~ ~RIBUTION . Ceotral Fi les: Chevron D & M Ex tension Explora$~on Exxon Marm Short Mob i k · "- Phi llips *ir F'B Well F'i les: R & D m_ ,1 * ~,.~w~ . '%"i~ ]l';:-~:~ -, :~ ~:~t.-, $ ~ a t e.::, o f Alaska ~ Texaco STATE OF ALASKA ; -- ALASKA u~L AND GAS CONSERVATION CL~MMISSION W =LL COMPLETION OR RECOMPLETION REPORT AND LOG · 1. Status of Well Classification of Service Well OIL Eq GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ Water I nj.e.ctor ... , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-7 3. Address 8. APl Number P. 0. Box 100360, Anchorage~ AK 99510-0360 50- 029-202~%9 4. Location of well at surface 9. Unit or Lease Name 1346' FSL, 75' FWL, Sec. 1, T10N, R15E, UM Prudhoe B~y Unit At Top Producing Interval 10. Well Number 1173' FNL, 1488' FWL, Sec. 7, T10N, R16E, UM 9-12 At Total Depth i 1. Field and Pool 1330' FNL~ 1718' FWL, Sec. 7, T10N, R16E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.)1 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 54' RKBI ADL 28345 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp, orAband. I 15. Water Depth, if offshore 116'No'ofC°mpIeti°ns 5/03/77 6/03/77 5/11/77'I N/A feet MSLI . 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. DepthwhereSSSVset I21.Thickness°fPermafr°st 12800'MD~9135'TVD 12706'MD,9063'TVD... YESx[~] NO [] 2168 feetMD 190~' 22. Type Electric or Other Logs Run D-IL/SP~ BHCS/GR, FDC/GR/CAL_. CNL/CCL/GR: Gyro: CAL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE!WT. PER FT. GRADE TOP BOTTOM . HO. LESIZE CEMENTING RECORD AMOUNT PULLED 20" 96.0# H-40 Surf 113' 32" 266 sx Arcticset cmt 13-3/8" 72.0# N-80 Surf 2708' 17-1/2" 5300 sx Arcticset cmt 9-5/8" 47.0# N-80/S00-!)SSurf 12129' 12-1/4" 1000 sx Class G cmt & 3(J00 sx Arcticset cmt 7" 29.0# N-80 11821' 12790.' R-l/?" a. 00 s× C~.ass G cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) *12378'-12408'MD 12554'-12570'MD ";-!/2" ~' 11500' ~ .... I' & "~"74 -- ._~, ~ i ~--"T S I~.--~ 1 2424 '-1 2457 'MD 1 2587 ' -1 2602 'MD . 12472'-12479'MD 12612'-12617'MD 261 ACID, FRAcTuRE, cEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 1 2491 ' -1 2498 'MD 1 2628 ' -1 2645 'MD . . 12513 ' -12537 'MD N/A .. W/4 SPF .. *Added on 6/04/84 TVD of perfs: 8817'-9017' , , 27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) 9/27/77I Flowing , Date of Test Hours Tested PRODUCTION FOR oIL-BBL GA's-MCF WAT~:'R-BBL CHOKE SIZE IGAS'OILRATIO 10/04/77 4.1 TEST PERIOD $ 1707 1324 0 69/64J 775 Flow Tubing Casing Pressure CALCULATI~D' 'OIL-BBL GAs-MCF WATER-BB'L QIL GRAVITY-APl (co, r) Press. -- . . .-- 24-HOUR RATE ~ 9992 7748 0 -- 28. COP E DATA , , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A * NOTE: Well worked over 10/23/86. (DAM) WC1/151 Submit in duplicate Form 10-407 CONTINUED ON REVERSE SIDE ~ Rev. 7-1-80 29. {, ? 30.. GEOLOGIC MARKEF~s ~ : ~ F~ORMATION TESTS . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad]erochit 12376' 8868' Base .Sad] erochi t 1 2687 ' 91 02 ' · I 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~ ~~/ ~~'~L.~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In~ jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~--' STATE OF ALASKA ALASKi ,L AND GAS CONSERVATION COMM,_ ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging L: Perforate ~ Pull tubing Alter Casing Fq Other ~,X W0RKOVER 2. Name of Operator ARCO Alaska~ Inc, 3. Address P.0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1346' FSL, 75' FWL, Sec.1, TION, R15E, UN At top of productive interval 1173' FNL, 1488' FWL, Sec.7, TION, R16E, UPI At effective depth 1290' FNL, 1659' FWL, Sec.7, TION, R16E, UM At total depth 1330' FNL, 1718' FWL, Sec.7, T10N, R16E, UH 5. Datum elevation (DF or KB) RKB 25 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 9-17 8. Approval number 408 9. APl number 50-- 029-20239 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical feet 1 2800 'MD feet 9135'TVD Plugs (measured) None Effective depth: measured feet Junk (measured) true vertical 1 2692 'MD feet None 9053 ' TVD Casing Length Size Cemented Measured depth Conductor 84 ' 20" 113 'MD Surface 2678 ' 13-3/8" 2708 'MD Producti on 1 21 29 ' 9-5/8" 1 21 29 'MD 266 sx Arctic Set 5200 sx Arctic Set 1000 sx Class G & 3000 sx Arctic Set Liner 969' 7" 400 sx Class G 11821'-12790' Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade and measured depth) 5-1/2"/4-1/2"/3-1/2", L-80/L-80/N-80, tbg w/tail ~ 12587' Packers and SSSV (type and measured depth) SAB pkr ~ 11500', FB-1 pkrs @ 12411 ' & 12574', WRDP-2 SSSV ~ 21 68' 12. Stimulation or cement squeeze summary InteNrv/aAIs treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation Feet Rue Verticaldepth 113'TVD 2708'TVD 8634'TVD 8417'-9127' Tubing Pressure 14. Attachments (Workover Well Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ..% 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Associate Engineer Form 10-404 Rev. 12-1-85 ~ Title Date 11-17-,~ Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS DRILL SITE 9-12 Perforation Depths MD 12378' 12424' 1 2472 ' 12491 ' 1 2513 ' 12554' I 2587 ' 1 2612 ' 12628' - 1 - 1 - 1 - 1 - 1 - 1 - 1 - 1 - 1 2408 ' 2457 ' 2479' 2498' 2532 ' 2570' 2602 ' 2617' 2645 ' TVD 8817' - 8840 8852' - 8876 8888' - 8893 8902' - 8907 8918' - 8933 8949' - 8961 8974' - 8985 8993' - 8996 9005' - 9017 SWO/122a:dmr 11-04-86 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty. parish or borough North Slope Borough ILoaseorUnit ADL #28345 ITitle Recompletion Prudhoe Bay Auth, or W.O, no. ASl185 IState Alaska lWe" --°'12 W/O WWS #1 AP1 50-029-20239 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover ARCO W.,. 21.66% IDate IHour Pr or status if a W.O, 10/6/86 I 0800 Hrs. Date and depth as of 8:00 a.m. 10/07/86 lO/O8/86 10/09/86 lO/lO/86 lO/11/86 thru 10/13/86 10/14/86 Complete record for each day reported 7" f/11,821'-12,790' 12,706' PBTD, Fill ann Accept rig @ 0800 hfs, 10/06/86. equalize tbg & ann fluids. 7" f/11,821'-12,790' 12,706' PBTD, LD tbg Fill hole & stabilize well. ND tree. NU & Cst BOPE. Fill ann & i, ~. ~..~ .... : TOH, LD S½" Cbg. ::' ': i!ii,..: 7" f/11,821'-12,790' .............. :~ i,.::~,!:.~; 12,706' PBTD, Fill @ 12,684', RIH w/OS Instl 3½" pipe rams & tst to 5000 psi. RIH w/BHA, tag top of PBR @ 11,556', rotate over PBR, POH; no rec'y. RIH w/OS to fsh K-anchor & PBR. 7" f/11,821'-12,790' 12,706' PBTD, ?OH w/fsh RIH w/6" tel bskt grapple, tag top of PBR @ 11,556' w/OS, tag PBR, release K-anchor, POH w/fsh. , POH; no rec'y. RIH 7" f/11,821'-12,790' 12,706' PBTD, POH w/BP POH w/PBR & K-Anchor. RIH w/pkr mill, tag pkr @ 11,596', mill, CBU, POH w/pkr. RIH w/BP, set @ 2540', press tst 9-5/8" csg to 3000 psi; OK. RIH w/BP to 11,650', tst csg; no tst. POH to 11,547', set BP, press tst csg to 3000 psi; OK. RIH to top of 7" lnr, retry BP, POH & set BP @ 11,475'. Tst csg to 3000 psi; OK. PU RTTS, set @ 35'. ND BOPE. Att to pull 9-5/8" packoff. ND tbg hgr, 9-5/8" packoff parted. Retry btm of pack-off f/csg head. NU new tbg head, instl 9-5/8" packoff, NU & tst BOPE. Rel RTTS, POH & LD. RIH, rel BP. RIH to 11,679', set BP & att to tst 9-5/8" csg; no tst. POH w/BP. 7" f/11,821'-12,790' 12,706' PBTD, Milling on 7" EZSV Treated sea wtr POH, LD retry BP. RU Schl, rn CAL log f/12,325'-7550'. RIH w/7" EZSV & set @ 11,970', press tst 9-5/8" x 7" csg to 3000 psi. RIH, tag & mill EZSV. The~ab~ove is correct ~ ,~ For f~rm preparation and distribution see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 11/03/86 ITM Drilling Supervisor ARCO Oil and Gas Company ~aily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I State Alaska North Slope Boroush Field ~Lease or Unit Prudhoe Bay I ADL #28345 Date and deptl~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. lO/15/86 10/16/86 10/17/86 10/18/86 thru 10/20/86 10/21/86 10/22/86 ,!he above is correct ~,~\ "~ Alaska Well no. 9-12 W/O 7" f/11,821'-12,790' 12,706' PBTD, Fill @ 12,705', POH 8.5 ppg treated sea wtr Mill 7" EZSV @ 11,970'. RIH to 12,402', rm to 12,474' rm to 12,678'. Mill fill f/12,678'-12,705', CBU, POH. · RIH to 12,497', 7" f/11,821'-12,790' 12,706' PBTD, Rn'g gage ring 8.5 ppg treated sea wtr TOH w/mill. RIH w/Champ III pkr, set @ 12,335', tst csg to 3000 psi. to 12,430', RU Schl, rn gage ring/CCL, RD Schl. POH 17', set Champ III pkr @ 12,416', pmp into ann, TOH, LD pkr. RU Schl, RIH w/JB & 8.5" gage ring, POH. Rn 8.425" gage ring. 7" f/11,821'-12,790' 12,706' PBTD, Rm w/bladed mill 8.5 ppg treated sea wtr POH w/8.425" gage ring/JB. Rn 6" gage ring, stopped @ 11,835'. Rn 5.90" gage ring/JB, stopped @ 12,446'. Rn 5.875" gage ring/JB, stopped @ 12,446', RD Schl. RIH to 12,382', rm to 12,514', torquing up. Pull back thru 12,382', TIH to 12,514' & cont milling. 7" f/11,821'-12,790' 12,706' PBTD, TIH w/pkr #2 on DP 8.5 ppg treated sea wtr Rm f/12,514'-12,690', POH. RU Schl, rn 5.875" gage ring/JB; would not go past 12,521', RD Schl. Rn 6" bladed mill, rm f/12,393'-12,690', POH. RU Schl, rn 5.878" gage ring/JB to 12,694'. Rn FB-1 pkr; would not go past 12,461', POH,. RD Schl. TIH w/mill, rm f/12,367'-12,690', 4 std wiper trip, POH, LD mill. RU Schl, rn gage ring/JB to 12,696', POH. PU new FB-1 pkr, set @ 12,574', RD Schl. TIH w/FB-I pkr on DP. (Accum fluid loss = 6520 bbls) 7" f/11,821'-12,790' 12,706' PBTD, LD DP 8.5 ppg treated sea wtr RIH w/FB-1 pkr, set @ 12,411', RD Schl. Drop ball, set pkr, TOH, LD DP. (Pkr A: FB-1 @ 12,574', Pkr B: FB-1Pkr @ 12,411') 7" f/11,821'-12,790' 12,706' PBTD, Rn'g 5½" tbg 8.5 ppg treated sea wtr RU & begin rn'g 5½" tbg. Date ITitle 11/03/86 Drilling Supervisor RIH For forr~ preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish I State Alaska North Slope Borough I Alaska Field Lease or Unit lWell no. Prudhoe Bay ADL #28345 I 9-12 W/O Auth, or W.O. no. T t e AS 1185 Recompletion WWS #1 API 50-029-20239 Operator ARCO Alaska, Inc. Spudded or W.O, begun IA.R.Co. W.l. 21.66% IDate 10/6/86 Workover Date and depth as of 8:00 a.m. 10/23/86 10/24/86 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. I 0800 Hrs. 7" f/11,821'-12,790' 12,706' PBTD, Set BPV 8.5 ppg treated sea wtr w/diesel cap Rn 288 its, 5½", 17#, L-80 AB Mod 8RD tbg w/SSSV @ 2168', SAB Pkr @ 11,500', FB-1Pkr @ 12,574', FB-1Pkr @ 12,411' & TT @ 12,587' 7" f/11,821'-12,790' 12,706' PBTD, RR 8.5 ppg treated sea wtr w/diesel cap - ND BOPE, NU & tst tree to 5000 psi. RR @ 1100 hrs, 10/23/86. Old TD Released rig 1100 Hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD PB Depth 12,706 ' Date K nd of rig 10/23/86 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % iGOR Gravity Allowable Effective date corrected The above m ...... t ~ Sign Date · 11/03/86 Drillin~ Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Correspondence To i? Company/Ioca' Subject Message Date AR3B-1389-C 9 9 !!!~ ~ (~) a _'=.: i" e c: F.-.', i 1::' -I.. (:) 1= 'J:) t 5' 'l" F:.: :{: B U T ]: 0 i'...! A £ a ,s k Box r age, A ol . I)AI'E: September R E FEE R F N C E ' A R C C) ~ ,-t-..t 0 9-i 8-86 ~4-..t 9-2t -86 '~-4--. 9 9-.t O-E)6 "~4-'9 9-.t 5--86 ~4-.i C) 9-.i 0-.86 ~"4.-- t ~ 9-t 5-86 ~9-.t 2 9-t t/t 2.-..86 ~-.t 2 9-t t/t 2--86 ~9-..t 2 9-.i S--.86 "'"'"'~- ;~- t '? 9--t I -86 ~9--.t 7 9.-1 t -.86 "~ 9-t -.,:.0 2-86 --~~'-?-25 9-20-86 I i --2 9-t 4-86 t-.t0 9-20/2t--86 t -t t 9-t S/i 4-.86 26, t986 Cas'ed HoLe Fi)')aL ~ .5 ' C a m c o Step Rate Inj Profi Le/GR Run t, P)"oduciion P)"ofi ke Run i, 5" Camco Temp, Log/Inj, Profi Le Run i, 5' Camco Inj. F'rofi Le Run t, 5" Came:(:) m 'Femp~ Log Run t, 5' Camco , 5" C a m (:: o Inj Profi [e Run i, Ypinner/Inj. F:'rofi Le Run S, 5' Camco Temp. I. og Rtxn ;~, ~" Cam(::o Temp. L. og Run t, 5' Camc:o "~" C a Ii) C: 0 Inj~ Prof'i ~e ~un i, .., l'emp~ L. og Run t, 5" Camco I n j . F'r o f i k e R u n i , 5" C a m c: (:) Inj F:'rofi Le Run t, 5" Camco .S'pinner/Temp. ~'ui"vey Run i, 5" Camco Spinne¥' Log Run t, 5' Camco .S:pinner/F'roduciion F'rofi Le Run ':~ 5" Camco Temp, Log Leak De'~eciion Run t, 5' Camc:o F:' I. em .Se ."; i gn a n clr ¢~ t h ¢.,~t~' a c I')/~ d c o p y,,~)s' r ec: e iF) t' o f da ia, Received By ............ 7- -. ( ) HAVE n ........ / ~ Rlaska Oil & Bas Cons. uummissioil ....... ' ' a8 F;: o s; a n n e/'F:' AT8-. t 'FRANS ~:86597 I) I$1'RIBUI'ION · "'... Ceni'ra L F:'i Le.~ .r"''Chevron ~= Extension Exp~oratior, '"',.Exxon Marathon ~ Mob i t · ~' . ~-.- Phi LLips- F'B WeLL F'i Les R & D '"~-,,- $oh i o ~ State of ALa_~ka ~'"' Texaco STATE Of ALASKA ALASK.~ OIL AND GAS CONSERVATION COMN,._,olON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -' Operation Shutdown ~ Re-enter suspended well - Alter casing - Time extension ~ Change approved program ~ Plugging ~ Stimulate :- Pull tubing ~Amend order-' Perforate ' Other" 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchoraqe, AK 99510 4. Location of well at surface 1346' FSL, 75' FWL, Sec. 1, TION, R15E, UM At top of productive interval 1173' FNL, 1488' FWL, Sec. 7, TION, R16E, UM At effective depth 1290' FNL, 1659' FWL, Sec. 7, TION, R16E, UM At total depth 1330' FNL, 1718' FWL, Sec. 7, TION, R16E, UM 5. Datum elevation (DF or KB) 25 ' RKB 6. Unit or Property name Pr,,rlhn~ Ray IJnif 7. Well number 9-12 8. Permit number 77 -7 9. AP! number 50-- 029-20239 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12800 'MD 9135 'TVD 1 2692 'MD 9053 ' TVD Casing Length Size Conductor 84' 20" Surface 2678' 13-3/8" Intermediate 12129' 9-5/8" Liner 969 ' 7" feet feet feet feet Plugs (measured) None Junk (measured) Cemented None Measured d~) True V~I depth 266 sx Arctic set 113'MD 113'TVD 5300 sx Arctic set 2708'MD 2708'TVD 1000 sx Class G & 3000 sx Arctic set 12129'MD 8634'TVD 400 sx Class G 11821'-12790'MD 8417'-9127'TVI Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade and measured depth) 5-1/2", 17#, L-80 4-1/2", 12.6#, L-80 Packers and SSSV (type and measured depth) 9-5/8" Baker SAD packer ~ 11584'ND 5-1/2" Otis Rq¥ SSSV nipple 8 2198'MD 12.Attachments ::'P I 9 1986 (11584' to surface), ~.la~,Uo Oil & (i~,% CuIK~ ..... ;,:iii!:;:! (11715' to 11584 )"~"~"-'~ F.,~,,.,.~,Or.~,~ Description summary of proposal ~ Detailed operations program BOP sketch 13. Estimated date for commencing operation October 10, 1986 14. If proPosal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~~ Title Associate Engineer Date Commission Use Only (GDH) SA/114 Conditions of approval Notify commission so representative may witness I~,uv~, "~. r~,~Approval No ~ Plug integrity ,~'BOP 3~e~t. ~© ~ocation clearance[ ~pproved Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicato WELL 9-12 PERFORATION INTERVALS MD 12378 12424 12472 12491 12513 12554 12587 12612 - 12408 - 12457 - 12479 - 12498 - 12532 - 12570 - 12602 - 12617 12628 - 12645 TVD 8817 - 8840 8852 - 8876 8888 - 8893 8902 - 8907 8918 - 8933 8949 - 8961 8974 - 8985 8993 - 8996 9005 - 9017 Note- Bottom hole pressure = 3950 psi @ 8800'SS Workover fluid will be NaC1 brine weighted to keep the well overbalanced. NaC1 kill pills will be used as necessary. SA/114a:dmr 9-16-86 DS 9-12 Proposed Workover Procedure PRIOR TO RIG UP 1. Set BPV. 2. Prepare 'location for' rig. ND flow line. WITH RIG- 1. MIRU w°rkover~rig. me 3, . e e ND tree. NU BOPE and test same. Pull BPV, Inspect tree for corrosion. PU landing joint. Stab into tUbing hanger and pU same. Kill'well. Note tubing t° annUlus Communication exists on this well. POH with tubing. LD tubing and inSpec-~ same. RIH with DP and retrieve packer. POH. 7o RIH with bit and scraper on DP. Clean out 7" liner to 12,706' PBTDo 8. Test casing with RTTS tool. 9. PU lower packer and tailpipe on WL. 10. Set packer at ±. 12,575' MD. 11o PU isolation assembly with flow control equipment and packer on DP. 12. TIH and locate in lower packer. Set packer at ± 12,415' MD. 13. PU 4½" tailpipe, 9-5/8" packer, and 5-1/2" tubing and RIH. 14o Locate in packer at ±12415' and set production packer at ±11,600' MD. 15o Pressure test tubing and annulus, 16. Set BPV. ND BOPE. NU tree. 17. Release rig. Pull'BPV. CMH2/32 ANNULAR PREVENTER 6 BLIND RAMS 5 PIPE RAMS 4 TUBING HEAD 2 ; i~. -z ,o.,, CASING HEAD 2, 9-5/'8" CAS NG HEAD ? 5000 PSi ~"~'~' ''~ H~AD 4 I~-F~15" - 5000 pc.~ p~c,E mAt,4,- 13-5/~" - 5000 PS! ~,L!ND ~:AMS . ,o-o~d 5000 ~'~ - ~ ~! ANNUL.AP ACCUMULATOR CAPACITY TEST CHECK AHD FILL ACCUMULATOR RESERVOIR TO P~OPER LEVEL W!TH HYDRAULIC' FLUID. 2 Aoc, uR~ THAT ACCUMULATOR PRESSURE iS 3000 PSt WITH !500 PSi DOWNSTREAM OF THE REGULATOR, 3. OBo:RVE TIME, THEN CLOSE ALL LINiTS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTE~ ALL UNI7S ARE CLOSED WiTH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT ~:!:.~:<a BOP STACK TEST I FILL BOP STACK AND MANIFOLD WiTH ARCTIC DIESEL. 2 r~F~ ~ ,_ .... u., %,A~ ALL HOLD-DOW~ SCPEWS ARE FULLY PET~ACTED, PREDETERMINE DEPTH THAT 7EST PLUG WILL SEAT AND SEAT ~N WELLHEAD. ~UN IN LOCK-DOWN SCREWS IN HEAD. 5 CLOSE ANNULAR PREVENTER AND CHOKES AND ~YPASS VALVES aN ~E ~AN~FOL~ 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR t0 MINUTES. _. , ~S_,UR~ TO 1800 Po, AND HOLD FOR I0 MINU,' '~'-' BLEED TO ZERO PSt. 5 OPEN ANNULAR PREVEN~ AND C' nSE TOP SET r,~ P~PE ~A 7 .... ~NCREASE PRESSURE TQ ._: " a nv ,. .. PSi ~.ND HOLD FOP 10 ~., NUTES. n._ ,~:,.,..,~ vAlVES ,D~~''~,, ,,., ,Y ,_.~ C'c~:Ah!.,,...~.. _ CHOKES. ~,L~ED ~.~, ~ . F~:ESSIJRE ~U~uPSJTOE~b~ VAL'TES ~o~ PEMAINiNG UNTESTED ~.~;..,,,,~r~,..~ ~,~ VA~ .... VE:S. iF ANY, ~,~'~ T~" .3'.)C'0 .... nc~ : ..... nc-r,-~ ~.~Af ,~' O~ VAi ~,'~. ..... WiTH ZERO PSi DOWNSTREAM. ELEED SYSTEM TO ZERO PS',. 9 r"o~N,,... ~ OIDF, ~ RAMS.. BACKOFF RilNNiNG_ ._,,T~ AND PULL 0LIT OF CLOSE 5LtND RAMS AND TEST TO 3000 PSi FOR 10 MINUTES, - -u,: . Ap4r . . . lO OPEH E:.~ ~ND R .... :, AND PECO'./EP, TEST PLUG MAKE 'SURE ~'iANiFOLD L'''='* i;,F FULL,,,'"¢ ARCTIC D'~cc~ ' --- ,' ~' :¢.. ::,~: ...... :_,~. ANDAL~',./A;~*"cS_ APESc~ N .~ ! !. TEST STANDPIPE VALVES TO 3000 i2. ~' K~f .... ~ ~.:,T ,~LY COCK'S AND INSIDE BOP TO 3(:,00 PSi WiTH KOO!"~E'Y !3, hECO~D TEST JNFO~?IATiON ON 5LOWOUT PoEV'ENTE~ ~EST AhD SEND TO DRILLING SUPE;tViSOP. -4 ~k'., L)k~r'~ .:'-Oh!oi ;~ ~,OPE TE~,~ ONCE A. WEEk( AND CUNC,~iONALL'''~ OPERATE ....~ ¢' ' buW~ uA~LY, JG dUI'.4E 1 6, I c. u6 ° RECEIVED AUG- 5 1986 Alaska 011 & Gas Cons. Commission Anchorags Max. Injection Rate During Well Last 3 Months (BWPD) J3-11 8000 INJECTION WELLS WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD Surface Pressure at Maximum Rate (psig) Tbg 9-5/8" Cs9 13-3/8" Cs9 Probability of Passing State Test 1200 1200 0 Low Comments 9-5/8" pressure responds immediately to changes in tubing pressures 3-12 33000 1100 1100 400 Medium Bled 9-5/8" pressure from 875 to 455 psig in 3 minutes, built up 80 psi in 1 hour, built back up to 860 psi in 20 hours. 3-17 19000 800 800 100 Medium Bled 3 Bbls oil and gas from 9-5/8" in 10 minutes, pressure decreased from 1050 to 200 psi, built up 120 psi in I hour built back to 1000 psi in 18 hours. 9-12 16000 ///9-14 9-17 36000 27000 900 900 0 Low 1300 1300 200 1100 1100 0 None Low Bled 9-5/8" pressure from 795 to 350 psi, built up 200 psi in 1 hour, built back to 800 psi in 5-1/2 hours. Parted tubing at 13'. Bled 9-5/8" pressure from 625 to 250 psig, built back to 625 psi in I hour. 9-19 28000 1200 1200 0 High Bled 10 gals of HpO from 9-5/8" pressure decreased from 220 to ~ psig, built up 80 psig in 4 hours. 16-2 7000 /16-11 7000 800 1200 0 Medium 1100 1400 : 200 Low Bled 40 gals diesel from 9-5/8", pres- sure decreased from 880 to 500 psig, built up 50 psi in I hour, built back to 850 psig in 10 hours. Has gas lift mandrels. 9-5/8" pressure responds immediately to changes in tubing pressure. Has gas lift mandrels. SURFACE LOCAT~0N: BOTTON HOLE LOCATION: ORigINAL RK8: 54 ' TOP OF SADL-~.q0CH[T: 12376' ALL DEPTHS ARE RKB MD Depths a?e to TOP of equipment 9-12 SPUD DATE: 5/3/77 1346' N & 75' E of SW cr. Sec. 1, TION, R15E, UM 1330' S & 1718' E of NW cr. Sec. 7, TION, R16E, UM RKB TO OCT HOL~ ANGLE THROUGH SADL[ROCHIT: COMPLETION.RUN: 6/10/77 API ~ 50-029-20239 HANGER 25' 400 5~t", 17#, N-80 PLASTIC COATED TUBING 5¥ x 9-5/B" Annulus Fluid: 10.6 C~C12 & Diesel 2198' Otis RQY SSSV Nipple ID 4.562" ~2708' 13-3/8", 72#, N-BO w/ 5300 sx J 11486' 11540' 11547' 11584' 11653' 11712' 11715' _~i1821' ~12129' Otis XA Sliding Sleeve Otis XN Landing Nipple BOT PBR Assembly Baker SAB Packer Otis XN Nipple ID 3.813" Baker Shear Out Sub Bottom of 4¥, 12.6#, N-80 Tailpipe Top of Liner 9-5/8", 47#, N-80 & S00-95 w/ 4000 sx 12378 12424 12472 12491 12513 12554 12587 12612 12628 - 12408 - 12457 - 12479 - 12498 - 12532 - 12570 - 12602 - 12617 - 12645 REF ZONE FT. SPF COMMENTS BH-'~i~S ~ 3--0- --J-- Perfed 6/J/84 BHCS 2 33 ~ Per~ed 9/7,/?7 BHCS 2 7 4 PerFed 9/7177 BHCS 2 ~ Perfed 9/7/77 BHCS 2 19 4 Perfed 9/7/77 BHCS lB 16 ~ PerFed 9/7/77 BHCS iB 15 4 PerFed 9/7/77 BHCS lB 5 ¢ Perfed 9/7/77 BHCS lB 17 4 Perfeo 9/7/77 RECEIVcu AUG 5 1986 127O6' PBTD ~6 84 12790' 7", 29#, N-80 w/ ¢00 sx A~a~ka Oi~ & Gas Oons. OommmJmn 12800' TD ~Anchora§e INJECTION WELLS WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD. Well Max. Injection Rate During Last 3 Months -/-~ (BWPD) '.1 3-11 AY~ ? 8000 3-12 ~ P 33000 3-17 ?)~t,'c 19000 9-12 ?/~s'/-~v.. 16000 9-14 ~a~-/~ 36000 q-17 /~ P 27000 9-19 mvf P 28000 16-2 p/o~ 7000 16-11 pl~,~,~ 7000 R,1N4/]6 Surface Pressure at Maximum Rate (psig) Tbg 9-5/8" Csg 13-3/8" Cs9 1200 1200 0 1100 1100 400 800 800 100 900 900 0 1300 1300 200 1100 1100 0 1200 1200 0 800 1200 0 1100 1400 200 Probabi 1 i ty of Passing State Test ~Low ~4edium i~.?Medium v':~one ~Low High l~4edium OW Comments 9-5/8" pressure responds immediately ~'~/'~,'-, to changes in tubing pressures Bled 9-5/8" pressure from 875 to 455 pstg in 3 minutes, built up 80 psi in 1 hour, built back up to 860 pst in 20 hours. Bled 3 Bbls oil and gas from 9-5/8" in 10 minutes, pressure decreased from 1050 to 200 psi, built up 120 psi in I hour built back to 1000 psi in 18 hours. Bled 9-5/8" pressure from 795 to 350 1,~~' psi, built up 200 psi in I hour, built back to 800 psi in 5-1/2 hours· Parted tubing at 13' ~,.,~ .... ~.-~ ...... ~.~ Bled 9-5/8" pressure from 625 to 250 pstg, built back to 625 psi in 1 hour. Bled 10 gals of H~O from 9-5/8" pressure decreaseU from 220 to ~ pstg, built up 80 psig in 4 hours. Bled 40 gals diesel from 9-5/8", pres- sure decreased from 880 to 500 pstg, built up 50 psi in I hour, butlt back to 850 psig in 10 hours. Has' gas lift mandrels. 9-5/8" pressure responds immediately to changes in tubtng pressure. Has gas lift mandrels. 0 (b ..j ;dE'.:: 9-12 SURFACE LOCATION: ~OTTOM HOLE TOP OF SAOL~OCHZT: __ ALL 0EPTHS ARE RKi) HO ~el)th$ ~re to TOP of equtl~ent SPUO ~A,'E: Z3~6' N & 75' E of Sw ct. Sec. I, 1330' $ & 1718' £ of NW Ct. Sec. 7, TION. R16E, 5A ' RK8 TO OCT 4A,4GE.~ m 12376' .MO MOL£ A,4G~ THROUGH SADL~ROCHIT: ~0° im COMPLETION. RUN: 6/10/77 25' AP! ~ 50-029-2023g · S~', 17#, N-80 PLASTIC COATED TUBING 5~" x g-S/B" Annulus Fluia ' I0.6 CaCl2 & Diesel 2198' Otis ROY SSSV Nipple ID 4.562' 2708' 13-3/8', 72f, N-80 w/ 5300 'SX ! 11486' 11540' 11547' 11584' 11653' I1712' 11715' i1821' 1212g' Otis XA Sliding Sleeve Otis XN Landing Nipple BOT PBR Assembly Baker SAB Packer Otis XN ~ipple ID 3.813' Baker Shear Out Sub Botto~ of mi", 12.6#, N-80 Tailpipe Top of Liner g-5/8', 47#, N-80 & S00-95 w/ 4000 sx -,m 12)78 12424 12472 "! 12Cgl ~ 12513 '- 12554 .~ 12587 12612 12628 kEF ZONE FT. SP; - 12408' ~-~'6s -'Z6- ~ -~- 12457' BHCS 2 ~t ~ - 12479' BHCS 2 7 : - 12498' BHCS 2 - ~ - 12532' BHCS 2 I9 4 - 12570' BHCS lB 16 ~ - 12602' BHCS IB I5 : - 12617' BHCS lB 5 .~ - 12645' BHCS lB 17 4 12706' PBTD 12?gO' 7", 29#, N-80 w/ ~00 sx 12800' TD CO,MEN'S Per~ec ~er~ed ~i 7.'~? Oe:~e-. Perfed g/7/77 Perf~ 9/7/77 Perfed 9/7/77 Perfed 9/7/77 Perf~ 9/7~77 Per fea 9/7/77 ' 6/84 ARCO A:.a:ka, ir,.c. !:'~ C:: ?c::,: t; '.'~) ":-.::' .}: 6 C:' ['..:':'~ (!'.'. :]: C.'" !"] a ~r... c .: f'.: ,:.~ ~ r,, c c. !..; a ?, c ': !-.... ~ [fi c' o C a [r~c o O± i.~ ,--a iflC 0 Ca l;ic C., I)A / ARCO Alaska, Inc. ~.~? Post Office Box 100360 i! Anchorage. Alaska 99510 Telephone 907 276 1215 DAte: August 21, 1985 REference: ARCO CH Finals 1-8 J Spinner ~- 9 ~ Temp - ~9-8-- Spinner ~39-12/Spinner %~"'3~~...~~ ~ii n n e r nner ~15-20~Spinner ~15- 20 ~ollar ~'~ !6-10'Spinner 8-15-85 Run 1 5" Camco 7-31-85 1 5" GO 8-8-85 1 5" Otis 8-8-85 1 5" Otis 8-8-85 1 5" Otis 8-7-85 1 5" Otis 7-26-85 1 5" Otis 7-15-85 1 5" GO 7-25-85 1 5"- GO Please sign as receipt of data. Received by 2 ? Pam Lambert ATO 1429C O,~s Cons. Commission Anchorage Trans 282 Chevron D&M Expl. Services Ext. Exploracion Exxon Marathon Mobil Phillips PB Well Files R&D Sohio stat~'~f- Alaska Texa co ARCO Alaska, inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' February 18, 1985 Reference' ARCO Pressure Reports ~3-13 Pressure Data 12-14-84 GO f.9-12 Pressure Data 12-17-84 GO /9-14' Pressure Data 12-19-84 GO f16-3 Pressure Data 12-12-84 GO Please sign and return the attached copy as receipt of data. Received by Pam Lambert ATO 1429C Trans# ~ Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. $cheve Regional Operations Engineer February 14, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-3 DS 2-6 DS 2-7 DS 2-11 DS 6-5 DS ~9~'~2 DS 9-15 Permit No. 70-41 Permit No. 70-61 Permit No. 74-62 Permit No. 77-63 Permit No. 78-20 Permit No. 77-7 Permit No. 77-36 Dear Mr. Chatterton: Attached are Well Completion reports for the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company File Pi(DS 2-3)W4-3 File Pi(DS 2-6)W4-3 File Pi(DS 2-7)W4-3 File PI(DS 2-11)W4-3 File Pi(DS 6-5)W4-3 File PI(DS 9-12)W4-3 File PI(DS 9-15)W4-3 Alaska Oil ~A Gas COns. C°mrniSsion nChorage '" ..... STATE OF ALASKA ...... ALASKA' ._AND GAS CONSERVATION C~. MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ Water Tnjector ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-7 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20239 4. Location of well at surface 9. Unit or Lease Name 1346' N & 75' E of SW cr Sec. 1, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1173' S & 1488' E of NW cr Sec. 7, T10N, R16E, UM 9-]2 ... At Total Depth 11. Field and Pool 1330'S & 1718' E of NW cr Sec. 7, T10N~ R16E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 54' RKBI ADL 28345 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/03/77 06/03/77I N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 12,800'MD,9135'TVD 12706'MD, 9063'TVD YE~ [] NO [] 2198 feet MD ].9Od' (A.nprnw) 22. Type Electric or Other Logs Run DIL/SP; BHCS/GR; FDC/OR/CAL; CNL/CCL/OR · 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 96~ H-40 1'1 ~' 32" 266 -"x Arcticsct Cat 13-3/8" 72~ Butt N-80 ?.708' 17-1/9- ~nn ~x Arctic_~et Cat ,, 9-5/8" 74~ Butt N-80 17179' 17-17." !000 sx C!a~ C cat; e & S00-95 '~OOO ~w Ar~ticset C_.m_t 7" liner 11821' 12790' 40A ~w ~.!ass G cat 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) *12378-12408' MD 12628-12645 'MD 5-1/?" l171h ' 11559' 12424-12457 ' MD 12472-12479' MD *Added on 6-04-84 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12491-12498' MD w/4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12513-12537' MD TVD of Perfs: 8870-9070' N/A 12554-12570 ' MD 12587-I2602' MD 12612-] ?.61 7' MD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR. OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c~orr) Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Sadlerochit Base Sadlerochit · GEOLOGIC MARKERS MEAS. DEPTH 12376' 12687 TRUE VERT. DEPTH 8868' 9102 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NONg 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title R~g-~ on.~ 1 Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this welt is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item :28' If no cores taken, indicate "none". Form 10-4C)7 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 14, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 2-3 DS 2-6 DS 2-7 DS 2-11 DS 6-5 DS9-12 DS 9-15 Permit No. 70-41 Permit No. 70-61 Permit No. 74-62 Permit No. 77-63 Permit No. 78-20 Permit No. 77-7 Permit No. 77-36 Dear Mr. Chatterton: Attached are Sundry Notices for the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company File PI(DS 2-3)Wl-3 File PI(DS 2-6)W1-3 File Pi(DS 2-7)W1-3 File PI(DS 2-11)Wl-3 File Pi(DS 6-5)W1-3 File Pi(DS 9-12)W1-3 File Pi(DS 9-15)W1-3 ---, STATE OF ALASKA .... . ALASKA _AND GAS CONSERVATION C VIlSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL OTHER [] Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 1346' N & 75' E of SW cr Sec. 1, T10N, R15E, UM (Producing Interval) 1173' S & 1488' E of NW cr Sec. 7, T10N, R16E, UM (Total Depth) 1330' S & 1718' E of NW cr Sec. 7, T10N, R16E, UM 5. Elevation in feet (indiCate KB, DF, etc.) 6. Lease Designation and Serial No. 54' RKB ADL 28345 7. Permit No. 77-7 8. APl Number 50-- 029-20239 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~: Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note' Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 6-04-84. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 12388-12408' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 12378-12388' MD (4 SPF). Shut-in well, ]POOH, all shots fired. Secured well, RD. 8-24-84 Ref: BHCS 6-2-77 RECEIVED i~` ~. ~ ~ Alaska 0it & Gas guns. Commission Anchor~,ge 14. I hereby C,~Ttify that the f,~regoing is true and correct to the best of my knowledge. Signed Title Regional Operations Engineer The space below for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date . ................. Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Prudhoe Bay [ neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. $cheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil 'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 Permit # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS 17-10 Permit # 81-97 Dear Hr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. $cheYe DFS/JEB/mjb R E C E i V E O At t a chment s JAN 2 5 cc: Sohio Alaska ?etroleum Company Alaska Oil & Gas Cons. C0mmlssl0r~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of AflantlcRIchfleldCompany STATE OF ALASKA ALASKA (J~L AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL~3 OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 1346'N & 75'E of SW cr Sec. 1, T10N, R15E, UM ].173'S & 1488'E of NW cr Sec. 7, T10N,R16E, UM 1330'S & 1718'E of A~4 cr Sec. 7, T10N,. R16E, ~ 5. Elevation in feet (indicate KB, DF, etc,) I 6. Lease Designation and Serial No. 54' ~P/<B I ADL 28345 12. 7. Permit No. 77-7 8. APl Number 50- 029-20239 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-12 11. Field and Pool Prudhoe Bay Field Prudhoe. Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 9-12 to water injection service. The well is part of the Flow Station 2 waterf!ood project. 9~e %~ell began receiving water on June 14, 1984. , ,or'fY that the fore~oing is true and correct to the best of my knowledge. 14. I hereby The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 R~_v 7-1-R0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 3OOl PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 December 27, 1984. ~ TELEPHONE (907) 279-1433 A D M I N I S T R A T I V E A P P R O V A L N O. 192.9. Re: Substitution of pressure fall-off surveys in five injection wells for transient pressure surveys in producing wells as required by Rule 6(d) of Conservation Order No. 165. Mr. D. F. S cheve Regional Operations Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Dear Mr. Scheve: On December 6, 1984 ARCO Alaska, Inc. requested pressure fall-off surveys in Prudhoe_Bay Unit water injection wells DS 3-13, DS 9-12, DS 9-14, DS 16-3, and DS 17-8 be accepted to satisfy requirements of Conservation Order No. 165, Rule 6(d). At a meeting with ARCO representatives, December 26, 1984, data were submitted which demonstrate that appropriate reservoir pressure data for reservoir management can be obtained from a four hour minimum pressure fall-off survey in injection wells. The Alaska Oil and Gas Conservation Commission hereby approves the substitution~of four hour minimum pressure fall-off surveys in Prudhoe Bay Unit water injection wells DS 3-13, DS 9-12, DS 9-14, DS 16-3, and DS 17-8 to satisfy requirements of Conservation Order No. 165, Rule 6(d). This action is taken pursuant to Rule 2 of Conservation Order No. 192. Yours very truly, Ku g 1 ~r Commis s loner BY ORDER OF THE COMMISSION HWK/RAD:be:I.AA 192 ARC:O A l.a:'.-::ka , F:' .: O, ~'.'-,'o x i ,"3~360 A'ncho'r'age, Al.a.s'ka 99~0 · ii.'.:, .. ;!i'.... '7'---4 ~,. :i ':.:.) .... 4"'-84 /ii:F:' i 'F~'ne'r' Log D ... ::?~'::~.. '-' 8 i '.:,.":' .... ._.':' .... :.,'":) -~ ''~ C F:' ,!i: /,? F:' i 'F, n e 'F lC) .. ;i{:. '9-i.....'.:'"/' i ,":',-A-:::~.'.':'... , ..... , C: F:' .? / }T F' i 'n'ne'r r.,, 2{: ? ..... 2 ,":; / .... ~ 9 .... :iii: 4- "f' e m p ~.':, 'F .:':', i- ,, 'r' ,':" l...,"', :,: .: ~ :,. f;-" , ........... .. "'" ,? i 2'"-2~':'" "" ' ' ,., ..... 'J ,":",.. --- (~. "--8 4 .,.,'r" i .r.'... I:' T e.. m F:' i.')., ,~¢~ ~ 'i. 2 .... 2 () ~ i ~:~., - ...... 6 .:::.:'" ..-':i. C F' :5: / ~.7 t::~ i 'n 'n ~.'.'~... 'F ...r'J ., :ii: ,. '~" J,-' ..... i ~' / i ~.".:)., ..- :!3 ..:.lii: 4 F'_. ~'''r. ~:'.,"~ ,,'~ ,::.'"" F"' i 'n 'ne 'r i) :. ,? :. i -4 .... 2 iii: / 9 --.- 2,5"-- 8 4 '0 i T' '~: -'r e mi::' · ! ! D., :ii: :. ~ 6 .... 3"."; ,'~' ~.i:..': .... ~ i "- ,.,° ,-'~,. f"-..: ,...~::' "r, }...~ o ::.:j · i'>. ,. ~? ... i ":", .... _.-"" ~ ? '"' 2! 6 -' 8 .-., :''~ T e mi::, e 'r' a '~ t~ ......... 'F e 1. n g D ~? ~ '7 ..... 'i q:,-~' 9 .... 2:i .... ii!: ~;~ ~"I ....'i "' '"' .~ ... '"r i" ii i . ~.J e ]"i .? I ~. '? I::,', I::' Ii I::.' H I::' II I:.' II I::' 11 1::' Il I%' II ...:' I::' ti I;." ii .:, 'T' F:'.: A N ;:::: ,. .,."z o o 'il' ,,,,i i,.,i I Ch ev'F on D & M [-"xp Lorai: i o'n ,~e'r'v i ce.-:.~ Ii:_' x i: e n s' i o n E x p I. o i" @ i: i o n [...'. x x on (.~ e i.. t' y H ...':'~ 'r' a 't' {",, o n Hob i I. H,:.::,l:) i I.~::.'"' & F:' F:'hi I. L ip.s' F:"F u. ct h ,::.', e B a ¥' W e I. I. R & g S' o h i o State of ALas'ka j:r i }. e.'i!: ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9 Water Injectors Permit Nos: 76-70, 76-82, 77-7~ 77-25, 77-36, 77-37, 77-38, 77-39, 77-40, 77-41 Enclosed are the Sundry Notices for Change of Well Status for the proposed Drill Site 9 Water Injectors. Very truly yours, D. F. Scheve DFS:SDC:kg Enclosures cc: SOHIO Alaska Petroleum Co. RECEIVED Alaska 0[[ & Gas C0rts. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfieldCompany ..... STATE OF ALASKA -- ALASKA , _ AND GAS CONSERVATION C~. AISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL[] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-7 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20239 4. Location of Well :L346'N & 75'E of SW cr Sec. 1, T10N, R15E, UM 1173'S & 1488'E of NW cr Sec. 7, T10N,R16E, UM 1330'S & 1718'E of NW cr Sec. 7, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. 54' RKB [ ADL 28345 9. Unit or Lease Name Prudhoe Bay Unit lO. WellNumber DS 9-12 12. 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to change Well 9-12 status from oil producer to water injector. It will be operated as part of the Prudhoe Bay Waterflood Project. Subsequent Worlx Repo~e~ RECEIVED J u N 1 4 1984 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~¢'~ ¢:~,~' 3~ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: O~'~GINAL SI~II£D BY LOt~i[ C. SMITIt Approved by COMMISSIONER Approved Copy By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 19, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 Permit No. 75-76 DS 9-12 DS 9-2 Permit No. 76-16 DS 9-13 DS 9-3 Permit No. 76-35 DS 9-14 DS 9-4 Permit No. 76-40 DS 9-15 DS 9-5 Permit No. 76-47 DS 9-16 DS 9-6 Permit No. 76-48 DS 9-17 DS 9-7 Permit No. 76-58 DS 9-18 DS 9-8 Permit No~ 76-70 DS 9-19 DS 9-11 Permit No. 76-84 DS 9-20 Permit No. 77-7 Permit No. 77-8 Permit No. 77-25 Permit No. 77-36 Permit No. 77-37 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File PI(DS as above)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AllanllcRIchfleldCompany STATE OF ALASKA '-' ALASK, ~L AND GAS CONSERVATION C 4MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-7 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20239 4. Location of Well 1346'N & 75'E of SW cr Sec. l, TZON, R15E, gM 1173'S & 1488'E of NW cr Sec. 7, T10N,R16E, UM 1330'S & 1718'E of NW cr Sec. 7, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF, etc.) 54' RKB 12. I 6. Lease Designation and Serial .No. ADL 28345 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate E~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 9-12 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 12378-12408' MD Ref: BHCS 6/2/77 0il & Gas C0zls. C0mn~iss/olt A~'iuh0rag~t 14. I hereby certify that the foregoing is true and correct to the bes;[ of my knowledge. Signed ~, ~~~~ Title Reg±onal ~,ng-irte er The space below for Commission use Date Conditions of Approval, if any: Approved Copy Returned ':. By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 17, 1983 Reference: Arco Pressure Data D.So 9-4 2-23-83 2-23-83 D.S. 9-12~ 2-24-83 2-24-83 D.S. 13-17/ 2-17-83 D.S. 14-22 1-24-83 D.S. 14-28-- 1-23-83 D.S. 1~5-11 9-17-82 9-17-83 D.S.'~PS'-ll 2-26-83 2-26-83 Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up Canlco Pressure Build-up Survey Report Pressure Fall-Off Survey Sch Static Survey GO Static Survey Camco Pressure Build-up Otis Pressure Build-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report Pleasesign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 219 DISTRIBUTION~ ~.....~/ ~:. ,--.. . NORTH GEOLOGY EXXO[¢: R & B MOBIL ~..., .,...,':,,', ~.: .... _.,~.,,, ~,;,: ,.,',,.,. PH[LLZPS D & H SOHIO STATE OF ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH ARCO Alaska, inc. Post Office ', 360 Anchorage, ,,~aska 99510 Telephone 907 277 5637 February 18, 1982 Reference: ARCO PRESSURE DATA D.S.9-12 2~3/82 D.S.2-17 1/17-20/81 Pressure Survey Pressure Survey Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 971 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO A~as~,e ~oc ~s a :;oc~,,.:,ary el ,~:',InhCJ~lchfle!dCo:t~pan¥ ARCO Alaska, Inc. Post Olfice .B~--'-3,60 Anchorage, A ,a 99510 Telephone 907 277 5637 January 21, 1982 Reference: ARCO PRESSURE DATA :S D .9-3 11/20/81 · D.S.3-4 11/20/81 " D.S.17-6 11/15/81 " D.S.3-2 11/19/81 " D.S.17-1 11/15/81 " D.S.9-1 11/21/81 " D.S. 16-16 11./15/81 " D.S'. 16-1 11/14/81 " D.S.4-7 12/2/81 " D.S.9-8 11/15/81 " D.S.16-11 11/14/81 " D.S.9-5 11/22/81 " D.S.9-15 11/24/81 " D.S.4-6 11/25/81 " D.S.9-6 11/16/81 " D.S.3-18 11/19/81 " D.S.9-4 11/21/81 " D.S.9-12 11/20/81 " D.S.9-10 11/20/81 " D.S.3-6 11/18/81 " D.S.3-7 11/18/81 " Pressure Surve~ DISTRIBUTION e'~se sign and return the attachedNORTH GEOLOGY R&D copy as receipt of DRILLING data. PHILLIPS D.S.9-6 9-6 D.S.9-6' 12/9/81 D.S.9-6 1/1/81 D.S.9-17 12/10/81 12/23/81 11/30/81 D.-S.-9.-,.6._ 11/23/81 D.S.4-1 .~2/2/81 D.S.12-9 1/4/82 D.S.12-10 1/3/82 D.S.12-12 1/2/82 D.S.12-11 1/2/82 D.S.16-9 1/8/82 EXXON MOBIL GETTY D&M Pressure Survey I! II II I! II II I1 I! I! !1 II Mary F, Kellis North Engineering SOHIO MARATHON CHEVRON GEOLOGY STATE OF ALASKA Transmittal #902 .ARCO Alaska. inc. is a SaC,'~td~ary of All3nl~cRichhe~dCo,"npany ARCO Oil and Gas Company North Post Office . ..)x 350 Anchorage, Alaska 99510 Telephone 907 ,,.~7 5637 Jerry A. Rochon District Operations Engineer March 19, 1981 Reference: ARCO PRESSURE DATA D.S.3-4 2-7/8-81 PressUre Survey D.S.4-7 3/11/81 Il 11 D.S. 9-'6 2-25/26-81 " " 2-15/16-81 " " Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #130 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company :s a Div;s,on Ol AllanticRich~ieldCompany ARCO Oil and Gas Company North Ala~ District Post Olfi ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer NOvember 4, 1980 Reference: Arco Pressure Buildup Data p.s. 9-8 5/2/80 Pressure Survey Pressure Survey sign .and return the attached copy as receipt of data. Mary' Kellis North Engineering TRANSMITTAL #775 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON tiDy 6 13 .9 Alaska 0il & gas Cons. C0mmissi0r] Anchorag~ ARCO Oil and Gas Company is a Division of AllanticRichlieldCompany December 18, 1979 Reference' EncloSed are Pressure Surveys :for the following /LRCO wells- D.S. !-10 8/7-8/79 Camco s-2 11/2-s/79 D,S, 4-6 11/19/79 Gearhart-~ren D.S. 5-2 8/27-28/79 Camco D.S. 7-2 - 11/4/79 Gearhart-G~en D.S. 7-14 11/10/79 " D,S, 9-3 10/27'-28/79 Camco ~ 10/24-25/79 Camco / /"~lease sign and return the attached copy as rec~:i.pt ~' of data. K, J. Sahlstrom North Engineering Getty Ph i. ]. 1 .i 1-,s So]~io ,.a ?_'~ L l!Oil Ct~evro;~ ,, North Alask~J District Posl Ofiic ,x 330 Anchorage, ska 93510 Telephone 907 277 5637 September 25, 1979 COM,Vv~_ COMM IL- .T'~_i S'r,,:', 'r 'r - c _ _ CONFFR' Reference' FILF: j Enclosed are Pre$$uze ~eports £or the follo%'i]'~g ARCO' weli $' / / D.S. 7-4 6/27-28/79 24 Hr HP Analysis D.S. 7-5-- 6/24-26/79 " D.S. 7-7 ~' 7/1-2/79 " D.S. 7-8 ~'' 6/29-30/79 " D.S. 7-9 / 7/14-15/79 " D.S. 7-10/ 7/16-17/79 " D,S. 9='l'Z~/5/11/79 Pressure Data D.S. 4-9/ 9/6/79 " D.S. 13-4~' 8/16/79 Pressure Buildup se sign and return the attached copy as receipt of data. C&II1CO Il I! II Otis Ge arh a r t - Ow'eh Dresser Atlas Very truly yours, K. J. Sahlstrom North Engineering 'I'}L&NSitI[TTJ\L # 363 D] S'l']tI l~[i'I' Po:;t O~tice Box 3:50 Anchora3 ,la" ~, ~,.-.~ ~ ,J i ~lep::on~ 7 277 :,637 August 10, 1979 Reference' Enclosed are Blip Buildup and Flow Profile Surveys/ Pressure Buildup Test Analysis Results for the following ARCO wells' P.S. 9-20 S 9-12 S 9-15 -... iz/4/TS ~/' ii/z9/78' i0/z2/78 i: 5/13/79 ~ ~o/zo/7s ~ 5/16/79 Please sign: return the attached copy as receipt of data. L/ Very truly yours, ~ .: ,"Z~ ~2-'." R. A. Bellinger North Eng ineering I cot~ COMM RES ['.Nw ' 1 ENG 1 GEOL STAT T'''r __~ 261 DiSTt{ II~[JTJ. ON No:th Geology DrJ. llin: I!ns.. M;u~ager Geology State of Alaska June 19, 1979 Reference' Enclosed are the following pressure surveys' 5/ii/7~ 4/28/79 4/~o/79 5/4/79 5/6/79 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMI2T. AL #186 DISTI~IBUTION Nor'th Geology ]')ri].l ing Eng. Mm¢,.oer Geology St. ate of Alaska AtlanticRichfieldCompany North Arneri?--~n Producing Division Alaska Post Offic6~w'~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 15, 1978 Reference: HKVp Enclosed are copies of the following Transient Pressure Buildup Surveys: .S. #4~6~ 10/2-3/78 Camco .S. #4-7 10/4-5/78 Camco .S. #4-8 10-03-78 Camco .S. #4-10 10/6-7/78 Camco .S. #9-3 10/12-13/78 Camco .S. #9-4 10/14-15/78 Camco .S. #9-8 10/18-19/78 Camco .S. #9-10 10/16-17/78 Camco .S. #9-12 10/20-21/78 Camco .S. #9-15 10/22-23/78 iCamco Please sign and return the attached copy of the transmittal letter as receipt of data. Very truly yours, R.A. Logue North Operations Engineering Transmittal #615 DISTRIBUTION North Geology Drilling Eng. Manager Dallas Geology State of Alaska D & M R & D Exxon Sohio Mobil Marathon Phillips Chevron Getty Deciliter 5, 1978 ~,,~r. Do~v~n Jac-~kson Nort~h A!a~{~a Engir~ering At!~ntic P£ckfield Co. P.O. P~x 360 Anc/%sra~ ~ 2~l~s]~ 99510 Dear ~ tran~itta! records show tl~%t we did not re~ive ~)~ies of '~e -- fo!~g ~eli l~s f~ ~~ ~ L~it we~s~ at ~e ~s;~ ~ orig~ i~ ~n~t~ ~ p~. Pi~ ~~t ~ foll~mg l~s at y~ ~!y ~~~. PBU DS 5-10 Cc~p. Neutron Formation Eensi~ Log 5'~ sepia PBU L~ 5-12 Du~ILnductice. Lat~_rolc~ DS 9-12~ Ce.~p. Fom~,aticn Density DS 9-20 C~. }~u~'~n Fo~a'~% De~sity I~x~.~ sepia sepia s?pia blue line print you for your atte_n~'~ to tP~s ~ Sin .-~e!y yo%~rs, Jo!m A. IPsvorse~n Petroie~m Ceologise AtlanticRichfieldCompany North Ar,"~e;~'~ F, roducing Divi-aion Alaska Post Office Sox 36;0 Anchorage, Alaska 99510 Telephone 307 277 5037 August 29, 1978 HKVP Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 In compliance to your request for data regarding reservoir surveillance, enclosed are copies of all initial surveys and pressure time data plus rate data per your letter of August 22, 1978. Rate Data is as follows' ~IELL TEST DATE CUMMULATIVE/BBLS RATE PER DAY 4-8 1 1/2/77 513,812 9666 5-3 01/13/78 1,244,283 8325 9-1 11/14/77 884,392 12500 9-3 11/24/77 1,066,628 10200 9-10 12/13/77 536,509 5072 9-12 12/21/77 436,223 6630 '1-13 04/27/78 Water Well 9-3 05/4/78 478,967 8660 If any other information is needed, please do not hesitate to make the request. Very truly yours, ', / ,-'~ / 4_,,- ..S~ ,,.~_-~---~'~ · "0"i ~. 'Rochon ., ..~" JAR/RAL/er F 3'01 t I ' J. A. P, ocho~/R. A. van.-;~] t~t¢:d herc~-:it~ are the follo~,Jng for t}te subject well.' Xerox Sepia 'BL Line Acid or Fracture Treatntent Log - BI.IP Buildup ~ Flo¥~ Profile Survey 1;orehole Geomet'or Log Carbon Oxygen Log Cas.~ng Collar Log Cement Bond Log Compensated Neutron Log- Cased ltole Core Analysis - Interval Core No. Core Description (&qC)- Interval Core DescriptiOn (Corer.) - Core No. Directional Surv.ey- Gyro .. - Single Shot -. ~'Mltishot 'Engineering Production' Log Fluid Analysis .Fluid Density Gan'una' Ray Location Plat ~'lonthly 17ell Te~t Data Nud Log Perforating Record . State Reservoir Pressure Report Surveillance Reports Temperature Log __7~ Transient Pressure- ' Surveys ~/7~ TFD Logs -. II, el Induction I,aterolog - Compensated Fo~ation Density Log - Compensated Neutron-Formation Density Log ' Boreho].e Compensated Soni6 Log - Porosity l_.og :~cei. pt Ackno~,q edged ].case Ret:urn ReceS. pt.To' Ns. R. A. I,ogue At]antic ' -'- t Rmhf~.c].c C:oinpany P. O. Box 360 Anchorage, Alaska 9951 To' North Alaska District Engineering T RAN S M I T TA L ~rOlll ' J. A. Rochon/D. R. Jackson Date' March 3, 1978 Well Narae' D.S. 9-12 Transmitted herewith' are..the following for the subject well' Run No. Scale Xerox sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Ganmta Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density- Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.)- Core No, Directional Survey - 6¥ro Single Shot F[~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog ~crolog ~dlog - Interval Sample Log (A.R. C0.) - Interval Synergetic Log ~iYD-DIL TVD-Porosity Log Receipt Acknowledged For: __ Date' Attn: ~r. Donovan Jackson Please retm~ receipt to: ^tlantic Richfield Company North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 #793 r) - ~ North Alaska District Enginec ,o T RAN S?,I I T TA L From ' .. J. A. Rochon/R. A. LogUe ~Fransmitted herewith are the following for the subject well' Run No. Scale. Xerox Sepia BL Line Engineering Production Log Acid or Fracture Treatment Log - BHP Buildup 6 Ftmv Profile Survey Borehole Geometxn/Log Carbon Oxygen Log Casing Collar Log .Cement Bon~ Log Compensated Neutron Log - Cased ttole Core Analysis - Interval Core No. Core Description (~'IC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro - Single Shot ~ ~'~ltishot Fluid ~alysis FlUid Density Gamma Ray Location Plat ........ MonthlyWell TeSt Data' Mud Log Perforating Record State Reservoir Pressure Report Surveillance Reports Temperature Log Transient Pressure'Surveys ]\~ Logs - [k~el Induction Laterolog - C~npensated Formation Density Log - Compensated Neutron-Formation Density Log - Borehole Compensated Sonic Log - Porosity Log ! ~eceipt Acknowledged By' !~lease Return Receipt To: Ms. R. A. Logue Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 A~ia~ti,C},!ich h eld Corn pany North American Producing Division Alaska Regi Post Office L ,. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 "" January 13,1978 Reference: Dear Gentleman: The ~llowing material is being submitted he~wit]l. Please acknowledge receipt by signing a copy of this letter and returning it to this office. D.S. 9-1 D.S. 9-2 D.S. 9-3 D.S. 9 5 D.S. 9-6 D.S. 9-7 D.S. 9-8 D.S. 9-9 D.S. 9-11 Initial Transient Pressure Survey Nov.14/77 Nov.27/77 Nov. 24/77 Nov.21/77 Nov.18/77 Dec.18/77 D~c.6/77 Dsc. 10/77 Dec.17/77 Dec.21/77 Initial Static Gradient Pressure Survey D.S. 9-13 Nov.20/77 D.S. 9-14 Nov.18/77 D.S. 9-16 Nov.21/77 ~,Truly Yours; ~ Donovan Jackson ~/ \ ' No~th Alaska Dist~<~ Engineering AtlantiCR ichfieldCompany North Arner~'~-~n Producing Division North Alask ~istrict Pos~ Office Box 360 Ancho~'age, A~aska 99510 Telephone 907 277 5637 October 13, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 9-12 (11-7-10-16) Permit No. 77-7 Dear Sir- Enclosed please find our Sundry Notice of Subsequent Report along with the Well Completion Report detailing the work done on the above-mentioned well. Very truly yours, F. M. Brown District Drilli~ng Engineer /kb Enclosures Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to clrlll or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. OW~LLLrl~WELL GAS [--"] OTHER 2. NAME OF_OP_ERATOR ' Atlantic Richfield Company ADDRESS OF OPERATOR P.O. Box 360; Anchorage, AlaSka 99510 4. LOCATION OF WELL At SU trace 1346'N & 75'E of SW cr Sec. 1, TION, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20239 6. LEASE DESIGNATION AND SERIAL NO, ADL 28345 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 9-12 (11-7-10-16) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, TiON, R16E, UM 12. PERMIT NO. 77-7 )orr, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF'. WATER SHUT-OFF ~]~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR AClDIZING I I ABANDONMENT* (ot,,n P e r fbT"at e (NOTE.' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations 9/4/77. Tstd tree, csg & wireline BOP's. Perf'd intervals 12,6233L~_12_,6JS.!., 12612'-12,617', 12,587'-12,602", 12,554'-12,570', 12,513'-12537', 12,491!-12,4~8',~"~1:~-~-~2;~'~-i'~2'~79', 12,424'-12,444', 12,444'-12,~57' w/4 shots per ft. Retrieved ball valve asbly. Ran Amerada press bombs. Flowed well. SI well. Ran ball valve. Purged control & bal line. Landed valve & profile. Sheared off. Control line would not press tst. Retrieved ball valve. Redressed ball valve. Landed ball valve. Press control line to 5000 psi. Could not shear off valve. Pulled ball out of profile. POH, removed oil jars, MU mechanical jars. Redress ball valve. RIH, purged control & bal lines, landed ball valve, press control valve to 5000 psi. Sheared off, POH, tstd bal lines to 5000 psi OK. Att to tst ball valve. Would not tst, WIH w/retrieving tool. Found ball valve @ 2217' & hung up. Jarred loose, POH w/tools. Retrieved ball valve. Top packing bad. Redress ball valve w/new packing. Set ball valve. Tstd bal & control lines to 5000 psi OK. Tstd ball valve. SI well. Released well to Production Dept 9/6/77. 16. I herebYsiGNED _,~certify th~,~Zr~g~j.oilg..c~,..,,~if..,., is true and correct TITLE Di stri ct Dri 11 ing En§inee...r DATE . 10/5/77 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side SUBMIT IN DL ,;CATE* STATE OF ALASKA :Se,,,.,th,,r m- st ru(,t ions on OIL AND GAS CONSERVATION COMMITTEE i WELk cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OiLWELi, ~ ~SwELL ~ DRY ~ Other b. TYPE OF COMPLE~ON: WELI, OVER EN BACK gESVR, Other 2. NAME OF OPERATOR ^tl anti c Ri chfi el d Company ~. ADDRESSOF oPERATOR P. 0. Box 360, ^nchorage, AK 99510 4. ~,OCA'rION OF Wm, C (Report location clearly and in accordance with any State requirements) At surface 1346'N & 75'E of SW cr Sec l, TlON, R15E, UM At top prod. interval reported below l173'S & 1488'E of NW cr Sec 7, T1ON, R16E, UM At total depth 1330'S & 1718'E of NW cr Sec 7, TION, R16E, UM 5. AP1 NUI~IE1LICAL CODE 50-029-20239 '6. LF~SE DF~SIGNAT1ON A_ND SERI2kL NO. ADL 28345 7, 1F iNDIA.N, ALLOT'FEE Oil 'I'}~[1BE NAi~LE 18. UNIT,FAII2~I Oil LEASE NAME Prudhoe Bay Unit 9. WE, LL NO. DS 9-12 (11-7-10-16) Prudhoe ~a - _ Pr~dhn~ fli~ Ponl :~. tOTAL DEPTH, NLD & TVD~9. PLUG, BACK MD & TVDr. IF lVrULTIPLE COiVI~L., 21. 12,800'MO, 9135' TVD|12,706'MD, 9063'TVq =~v~.ngle ,OT*R, TOO,..~All 22.PRODUCING INTERVAL(S), OF THIS COMPLETION--TO,I:', BOTTOM, NAME (MD AND Top Sadlerochit ~ 12,376' MD 8815' TVD Base Sadlerochit 12,648' MD 9019' TVD 11. SEC., T., R., M., (BOTTOM HOLE OBdECTIVE) Sec. 7, TION, R16E, UM 12. PER3/IIT NO. 77-7 5/3/77 6/3/77 6/11/77 541 RKB , ~. INTERVALS I)RILI,ED BY l CABI,E TOOI,S 23. ~VAS Dr.f;LECTIONAL , SUL' VEY MADE Yes I 24. TYPE ELECTi%IC AND OTItEI~ LOGS RUN DIL/SP, BHCS/GR, F. DC/GR/CAL, CNL/CCL/GR ~i ...... -- CASING RECORD (Report all strings set i:x we'll') " ' IVEIGHT LB FT ' GRADE ' CEMLNTING RECOt~ AMOUNT PULLED 20" 96~ H-40 [ ll3.'. . 32" 266 sx Arct. ic~ot Cmt _ 13-3/8" 72~ Butt[N-80 [ 2708.' 17-1/24 5gO0 ~x Arctic~ot Cmt _~ 9-5/8" 74g Butt IN-80 [ 12129_' 12.1)d'l ~nnn qx nl,~ ~ rmf_ qor~nd stage ~oo-951 - ' [ 3000 Sx ArCti~s;'t-~m~--I''- ... i .mm ,~ ., 26 LINER R~CO~ ] 27. TUBING --7"--".~ ~ .} ')1,821',..~, . 12,790' 1400 sx Cllss B:[ [ 5-1/2". 1. i:714I ' :),,c ,S-T-. 2~. ~RAq'J:~NS~P~ TO PRODUC~ON (interval, size and number) 29. ACID, Si:O37, I:;~AC'I GRn2, C~,IENT SQUE'rZ'~ ,' ' . /:~, 5~:2 ~- I:2. G~ ~'~ 12,554'-12,570', 02,424'-12,444' :12,513'-12,537', '.5~2,q44'-12,457' ,~-- :~12,491 '-12,498' ~ :: .... 2~' 4 shots per foot iii ' ii ii i i 30. PI~ODUCTION DA't~E FIRST PIIODLrCTION I P:F~ODUCT1ON MEI[{OD (Flowh*g, [:as iff[, purnping~size and type of pump~ 'V, ELL [fI:ATUS t Producing or 9/27/77 ) Flowinq Producing , DATE OF T~ST, ~0U~S 2"EST~ 'ICI!OXE SiZE [PROD'N FO'~ OI~BEL. G-AS--lkiCF. VCA'J.'EIK--BBL. I GAS-OIL IIA.TIO 0/4/77 I 9/64I 707 324 I 0 775 FLOXV, TUBING ~ZNG PRESSUR~ ICALC~T~ OI~BBL. GAS--~[CF. W~Y~BBL. [ O1L Gt~AVITY-~I (CORR.) 1 ~ 9992 I 7748 I 0 - 3]. DISPOSITION OF 6&S (SOlg~ ~sed I0r lue~' ven'teg, etc.)' ' ' ' I TEST WITNESSND BY Relnjected 32. LIST OF tTT~CHMENTS Brilllng History,'Directional Survey '33."I hereby certify tha~heforegoing and attached information t~ complete and correct as determined from all-available recurds s,c,~~~ T,T~, Dist. Dr illin<;ngineer ~,,T,,: __~~.. : *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: indicate which elevation is used as reference (where not otherwise shown) for depth measure- meats given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prc, duction from more thar~ one i~terval zone (multiple completion), so state ~n item 20, and in ite,-~ 22 show the p~cJucir~,g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv,~l ref}orted in iter~ 30. ,Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produce,d, show- ing the ackJitionat data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: ,Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34, SUMMARY Ol~ PO{{MATI(.)N TESTS 'INt'LUI)IN(; INTERVAL TF. STED, PHE:~kSURE DATA ~ ~OVERI~ OF OIL GAS, 35 G~GIC MARK~ WAT~ AND MUD i , . i i. ~6 CO~E. DATA. A'I~FACll AN~:D~I'EC~'EI) Silo. S OF OIL, GAS Oil WAT~{ ' . North Alaska District Engineering TRANSMITTAL 2'0' From: Date' 9- 27 - 77 Well Name' J. A. Rochon/D. R, Jackson D.s. 9-].2 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gmmna Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Fm~ation Density Log Compensated Neutron-Formation Densit. y Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot b'Mltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gmara Ray Gmara Ray/CCL Laterolog Location Plat Microlaterolog Microlog b~dlog - Interval Smnple Log (A.R. C6.') - Intmwai S~ergetic Log T~q3-DIL TVD-Porosity Log Collar Log Fluia- -Density Pressure ,qurvey:: =_9,,5-77...Camco,,. Receipt AcImowledged For' / 1)lease retm-n receipt to' Atlantic Richfield Company North Maska Engineering Manager P. O. Box 360 ~chorage, Alaska 99510 Xerox Sepia BL Line ~ e'a I e 'a. · I e-a- I ea ~ca #504 02~01B ~ STATE of ALASKA DEP~ ~F NATURAL !~_S~ORCES Division of Oil and C~s Cc~m~rvation TO, J-- FROM: O. K. Gilbreth, Jr. Director Hoyle H. ttamilton /~'~ f2~ef Petrole~ Engineer~ DATE SUBJECT: ~~0er 12, 1977 Surface Ccntroll~l Subsurface Safety Valve a~/ Surface Sa~_~ty Valve Tests Arco's DS 9-11 and~ Sunday, .Se.ptember 4, 1977 - I departed my bare at 4:00 PM for a 4:30 ~ and 5:30 PM departure via Wien Flight #19' for Prudhoe Bay, arriv~ there via Fairbanks at 8:00 t~4. I arrived at Drill Site 95 at 8:30 whe~re Kelly C~ff, drill~3 fore,an, advi~ B(ZVE tests had been ccncl~ cn DS 5-16. I h~ att~upted to reach ~ Bay on Sep. te~er 3rd but the returned to Anchorage. Kirk ~b_tte contacted me Shortly after arrival at Drill Site #5 and ~rtvised SSSV's and SCSV's on 9-11 and 9-12 ~ald be tested the following, day. M~nday, se~~ 5, 1977 - M/nos Hebert picked me up at 9:30 PM and t~2~s on SSSV and' SC~ b~gan at 10:-00 PM with ball valve c~ with 3500 psi on t2~ control line. ~he %~_ll ~as flowed for two ndnut~s and then shut in. Shut in tub~ pressure .was 1250 psig. Pressure above the SSSV, set at 2254', was then bled to 1000 psig and monitored for fifteen minutes. Pressure was tbmn bled to 700 psig ar~l mcnitcre~ for fifteen minutes. Xmas tree and tubing were then repressured to 1250 psig and SC, SV'. closed. Pressure downstream of the SCS~ was bled to zero and ~onitnred for five minutes. Tests ware ooncl~ at 11:45 PM. A field inspection report v~s prepared with the original given to ~4nos Hebert, a copy mailed to Bob Hines, and a copy attached to this report. _T~day,...Sep~ 6, 1977 -'bthnos JJebert and I arrived at DS 9-12, ~ ~ '~ at 9:05 AM and shut in tubing pressure ~s 1300 psig. F~qV was then closed. Pressure above ~%e SSSV, set at 2204', ~uq then bled to 1050 psig and n~m%itored for five minutes. Pressure was then ble~ to 700 psig and moni~ed for five m/nutes. The SSSV was then reo~ and shut in tubing pressure returned to 1300 psig. SCo~; was then closed and pressure dfma%stream bled to 150 psig and mc~i~~ for five minutes. Tests w~re concluded at 9:50 AM a~l a field inspection report cc~pleted with the original given to Minos I~bert, a copy ~%iled to P~b l~ines, and a copy attached to this report. I d~ Arco's Prudhoe strip at 4:20 PM via BP chnrter, arriving in Anchorage at 5:50 PM and at r~y h~ne at 6:30 PM. In ~: I witnessed sucoessful SSSV and SCSV tests cn Arco's DS 9-11 and 9-12. Attachment !orth Alaska District Engineer. ,_ TRANSMITTAL CONFIDENTIAL To: From: ~ TO; t'LACLO' I-IUNT l)ate: ~~7 7 Well Name: J, A. Rochon/D. R. Jackson 9=12 Transmitted herewith are the following for the subject we].l: Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - G~ma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/FDL Cor~)ensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Inte~al Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. D.irectional Survey- Gyro Single Shot ~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Ga]tuna Ray/CCL Laterolog Location Plat Microlaterolog Microlog Mud.log- Interval ........... Sample Log (A.R. Co~) - Interval · Synergetic Log . TVD-DII, TVO-Porosity Log ----Casing collar _Log~ _~ea Receipt Ac]mowledged For: Please return; receipt to: Atl~mtic Richfield Company North Alaska Engineering Manager P. O. Box 360 Anchorage, Al. asia 99510 #556 CONdDENTIA. D/STBIBUTED TO: North A_laska DistzS. ct EngS.neering STA. TE O15' ALASKA D!VI£;.i. ON OF OIL &GAS T R A N S M I T T A L To: From: J. A. Roc:hon/D. P,. Jackson I la-Ce: July_29, 1977 Well Name: Transmitted herewith are the following for the subject well: Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gan~na Ray Log BHC Sonic/gamma Ray Log Caliper/CCL Cement Bond Log/VDL ..~.!__~ Compensated Formation Density Log Compensated Neutron-Fo~nation Density ..... ~ .... Compensated Neutron Log _~, Core ~mlysis - Intetaral Core No. · Core Description (Si?C) --.Interval Core l)ascriptJ_on (Conv.) - Core No. Directional Survey- 6~ro Single Shot Nultishot Dri].l Stem Test - Test No. ])~al Induction Laterolog Formation Density Log Formation Density Log/gamma Ray Cantina Ray/CCL Laterolog Location Plat Microlaterolog ?4icrolog ........... Mudlog - Integral Sample Log (A.R.C~) - Interval Synergetic Log TVD-Porosity Log 11 D.S. #9-12 Xerox Sepia BL Line ea. Receipt Acknow].edged For: PJ. ease return ,'receipt to' Atlrm~t~.c R-i. chfield Company ' ,, ~,:~ North Alaska Engineering blanager ' ~ ?~" } ~ P.O. Box 360 Anchorage, Alaska 99510 #535 Ala. Oil and Gas Conservation Commit ~ Fi eld Inspection Report ..~ Oper:ator Repres Satisfactory yes No ( ) ( ) l, Well Si! ",i~r' ( ) ()i 2. ~.~() (, .... () () on ,Genera l )open( )filled I Valve Tests I1'~' Wells lTest Data ( ) (.) 7, Well. NOs., , , ( ) ( ) ...18..Hrs., obSe~----, , , () () 9, 'BS&W , , ,-- ( ) ( ) 10. Gr. BblS. , , , () () Satisfactory Type Inspection Yes No Item ( ) BOPE Tests ( ) ( ) 15. "Casing set @ ( ) ( ) 16. ~L fluid.( )wt,)mud ( ) oil I ) ( ) 17. Master Hyd. Control Sys.-___._psig ) { i) 18. N2~ btls.,__,__, ~ pslg ~'-' ' ( ) ( ) 19. Remote Controls ( ) ( ) 20; Drilling spool- "outlets .( ) ( ) 21. Kill Li.ne-( ) Check valve (.) ()i '22. Choke Flowline ( ) HCR <yalve ( ) ( ) 23. Choke Manifold No. valvs flgs ( ) ( ) 24..Chokes-( )Remote( )poS.(-~dj. (') ( ! 2.6. Test PlU.~:,:'( )W~l'.lhd( )csg( )]none (.) (~ 26. AnnUlar Preventer, psia () (-'.) · . '(~) (,,) .. (:) (') 12; 11,( )caPped'( )Plugg~ed ( ) ( ) .... psi:g ,',~;;:: (.:' i:;).".;:' ' 30;:' :LOWer Ke 11 ob:servation time JBy~l/hrs TOtal . : .: . ~ . number leaks and/or equip failures Remarks . Notify in days or wh. en ,[e'ad'y' _ Inspected by JJj~ ~/~Date Atlantic~ichfieldCompany North Ame.d.c~-~-. ProdUcing Division North Alas triCt Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 20, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 1-5 (23-9-10-15) Permit No. DS 1-7~(13-7-10-15) Permit No. DS 2-6 (23-35-11-15) Permit No. ~'-~§]~11-7-1 O-16)Permit 7O-40 75-17 70-61 77-7 Dear Sir- Enclosed please find our Sundry Notices outlining our plans for each of the above-mentioned wells. Very trUly yours, Frank M. Brown District Drilling Engineer /jw Encl osur'es ,,) , Form ~. 0-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA · . OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form fOr proposals to drill or to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) O,L I-F1 GAS r'-I WELL~ WELLI I OTHER NAME OF OPERATOR Atlantic Richfield Company ADDR~S OF OPERATOR P. 0. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At surface 1346'N & 75'E of SW cr, Sec l, T10N, R15E, UM ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 5. APl NUMERICAL CODE 50-029-20239 6. LEASE DESIGNATION AND SERIAL NO. ADL 28345 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 9-12 (11-7-10-16) 10. FIELD AND POOL, OR WILDCAT Prudh0e Bay - Prudh0e 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, T10N, R16E, UM 12. PERMIT NO. 77-7 14. Check Appropriate Box To Indicate Nature of Notice, Re }ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT ~.~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON* REPAIR WELL L.__a CHANGE PLANS (Other) Perforate SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAI RING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDITING ABANDONMENT* (Other) (NOTE.. Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Comp. any proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for dispOsal. Any produced gas will be vented to the atmosphere during perforating operations. The downhole safety valve will be installed and tested upon conclusion of job. Estimated start date: August 1, 1977. 16. I hereby ce(tlfy that the foregoJJng is true and correct TITLE Di stri ct Dri 11 i n9 Engineer DATE - Julv 20:1977 (This space'for State office use) APPaOYED BY CONDITIONs o~-PpRo~AL, IF AN 4: - See Instructions On Reverse Side Cop? North Alaska D:istrict Eng.[neering T RAN S ~.l I T TAL Date' Ju._ly 18, 1977 l?ell Nmi~e' D.S. #9-12 Transmitted herewith are the following for the subjec[ well' Scale Xerox Sepia BL Line Run No. BHC Sonic/Caliper Log ...1 __ BHC Sonic/Calliper - Ganm~a Ray Log BHC Sonic/Ga~r~na Ray Log Caliper/CCL Cement Bond Log/VDL -- Compensated Fox, nation Density Log 1 Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Inte~wal Core No. Core Description (S~&C) - Interval. ---- Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot b~ltishot D~i11 Stem Test - Test No. -1 & 2 l~aal Induction Laterolog Fo~ation Density Log Fo~ation Density Log/Ga~una Ray Gam~na Ray/CCL Laterolog Location Plat Microlatero]og Microlog '5" ./ ea. _ L ea. 5" [ ea. / ea. b'~adlog- Inte~wal Sample Log (A.R. C6:) Interva~- Synergetic Log 'IYD- DI L TVD-Porosit)' Log ea. / ea. Receipt Acku~o,,qledged For' Date' ~x~~~_~_. ' i/~~VV Please retu~ receipt to: A~].a~i~£ie-~/~o:np~nY / ~o~h AlasFka :ngineer'~ng Manager ~f. O. Box 360 Anchorage, Alaska 99510 #499 AtlanticRichfieldCompany North Ame~~'~-~- Producing Division North Alas, ~rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Mr. Hoyle ~3milton I S~te of ~as~ / ~~~t of ~t~al ~~ces / ~s~on o~ 0~z ~a ~s /~~ ~chorage, aaska 99501 S~j~t: Drill Site 9-12 (11-7-10-16) P~t No. 77-7 Enclosed please finn a Completion Report along with the Drilling History and Multi-shot Directional Survey for the above mentioned well. / Very truly yours, District Drilling Engineer Enclosure SUBMIT IN L STATE OF ALASKA .qt I'llC t IO rl.q OD OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* -la. TYPE OF WELL: on, [] I~-~ t[--]Other WELl, WELL ~ DRY b. TYPE OF COMPLE~ON: xv RI.I. OVER EN ~ BACK EESVR. Other 2. NAME OF OPERATOR Atlantic Ric~ield Company 3. ADDRESS OF OPERATOR P.O. Box 360, AnchoraDet Alaska 99510 4. LOCATION OF WELL ('Report location clearly and in accordance with any State requirements)* At surface 1346' N & 75' E of SW cr Sec 1, T10N, R15E, UM At top prod. interval reported below 1173' S & 1488' E of NW cr Sec 7, T10N, R16E, UM At total depth 1330' S a 1718' E of NW cr Sec 7, T10N, R16E, UM 5. AP1 NUM_EltlCAL CODE 50-029-20239 6. LEASE DESiGNATiON A_ND SERIAL NO. ADL 28345 7. 1F iNDIAxN, AJ~LO'I'%~EE O}[ TIIlBE NA_SLE 8. UNIT,FAit2VI OR LrcGkSE NAME Prudhoe Bay DS 9-12 {11-7-10-16) r~.~F,~ A~ND ~POOL, Ot1 WILDCAT Prudhoe Field - Prudhoe ~{ Pool 11. SEC., T., R., M., (BOTTOM HOLE OiLJ ECq'IVE) Sec. 7, T10N, R16E, UM IS. tOTAL DEPTIZi, NLD & TVD[19. PLUG, BACK MD & TVDp. IF 1VIULTLFLE COMPL./''~ ...... 21. 12,800'MD, 9135' TV~2,706'MD, 9063'TVD~ aow~N¥.single .OTAR~All ~o0~s 22.Pt%ODUCING INTERVAL(S), OF THIS COIVlPLETION--TO,P, BOTTOM, NAME (MD AND TVD)~ Top Sadlerochit 12,376' MD 8815'TVD Base Sadlerochit 12,648 ' MD 9019' TVD INTER'VAI,S I)R[I,I.ED BY i ..... CABI,E TOOLS 23. WAS D!tlECTIONAL ! SUHVEY MADE I Yes 1 24. TYPE ELECTRIC AND OTHEI% LOGS RUN D~L/SP' B~CS/~R,. ~DC/~R/CAL, CNL/CCL/~ 25. CASING RECORD (Report all strings set in well) C~SI2~CiSIZE \VEIGHT, LB/FT. DEPTH SET (MD) HOLE sIZE -- 20" 96# 113 1-323/8" 72# Butt 17,½" ~9-5/8" 47 # Butt CISMLNTING I%ECOILD 5300sx PULLED 300sx Arct5, cset 26. .L, INEi{ iq~ECOIXLO 27. TUBING lqECONJ) SIZE TOP (A,ID~ EOTTOA.'I CT,ID)SACKS CEAIEN~T* SCi'tEEN (JiD) SIZE DEP'I.'II SET (MD}~ PACi,iER SET (.),iD) 7" Clas: G ' ' 28. PERFORATIONS OPW'-Mq TO (intcrval, size and number) 29. DEPI'Ii iN'I'E2iVAL (MD)/ ACID. Si:OT, ivii,'kC'I ~3t{E, CE.lENT SQU~I!'_.'Z~, ETC. PP~OD UCTION 30, DATE FIRST PI%ODUCTION [ PI%ODUCTION N£E;I[{OD (Fl h*g $ lifL P Ping--si d type °f pump'NA .... .... ~, .... ..... [ V/I, ILI., ~G'FAT US ( Pro ducing or :;iltl L-itl} ~6~V] TUBING ]CA~4G PRESSURE [CALC~T~ OI~BBL. GAS--I~CF. -- gl.-D~sPos~viox or n,s (Sold, used ~or ~uel, yen ed, e c.) jV~/~rI'Ei~--r~BL. [ GAS-OII~ ll.'~TIO WATER--BBL. ] OIL GRAVIT¥-A_PI (CORR.) I I . t TEST WITNESSED BY 32.LIST OF ATTACHMENTS Dri!l,ing History, Directional Survey 33.I hereby cer.tl~ that the foregoing an.~attached information is complete and correct as determined frum all-available ri~curds // ~~ ~ ~ .~ / Dis~ict Drill~g mgine~ ,),,, ~~ *(See ]nstrucfions OLd Sp~ces [or A~itio.~[ D~Io on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repor, t end Io9 on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in c, ther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone (mulliple completion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, show- ing the ac:kJitional data pertinent to such interval. ...... 3'4. SUMMAH.¥ OF' ~'ORM~T"ION V]F2g'l','6 I'N('LUI)IN(; IN~:'~VA~ T'Kg'r~D. t'tm~SU~ DA:TA.~'~COVDRIF~g O~ OIL. GAS, ' ........ WAT~ AND MUD : : _ . , ,.,, Item26: "Sacks Cement": .Attached supplemental records for thi. s well shoulJ shew'the details Of any mul- tiple stage cementing and the location of the .cementing tool. Item 28: Submit a separate completion report on this form for .each interval to be seParately produced. (See instruction for items 20 and 22 above). DRILLING HISTORY DS 9-12 (11-7-10-16) API 50-029-20239 ADL 28345 Permit No. 77-7 Accepted rig@. 0500'hrs 'on '5/3/77. Drld 17-½" hole to 2750'. RU & ran 13-3/8" csg· w/shoe· @ 2708' , FC @ 2631' . Mxd & pmpd 5300 sx Arcticset cmt. Floats held OK. Inst & tstd pkoff to 2000 psi. NU & tstd csg head & BOP. Tstd csg 1500 psi. Drld FS & 10' new form.' Tstd to 12.5 ~ equiv. Drld 12-¼ hole 12,150'. Ran SP/DIL to 10,500'. Circ & cond hole. RU & ran 9-5/8~'~4~%--N2'80 & s00-95 butt csg w/shoe @ 12,129', FC @ 12,044', lwr FO @ 2502', upper FO @ 2379'. Mxd 1000 sx Class G cmt w/0.75% D65 & 0.03% D13R slurry wt 15.8 ppg. Float shoe held OK. Installed& tstd csg pkoff to 5000 psi. Opened lower FO. Pmpd in 300 sx 16 ppg Arcticset .cmt, 0.2% D13R & 0.2% D59. Closed lower FO & tstd to 3000 psi Opened upper' FO,'ran Arctic Pack job. Closed & tstd upper FO to 3000 psi. Tagged cmt @ 11,730'. Tstd csg. Drld FC & cmt to 12,119. Tstd csg to 3000 psi OK..Dr~~s._hoe_fm_L0_'_.~.~9~i~9~_.~,~!~0'. Tstd form equiv 11.3 ppg mud. Drld from 1.2,160' to 12,800'. Dropped multishot. Ran DIL/SP, BHCS/GR, FDC/CNL/GR/CAL from 12,800' to 12',120'. RU & ran 7" lnr w/shoe @ 12,790', FC @ 12,706,, top of lnr @ 11,821', .Cmtd lnr w/400 sx Class G cmt w/0.75% D65, 0.2% D46, 18% D44 & 0.3% D13R, slurry wt 16.0 - 16.2 ppg. Displ cmt w/243 bbls mud. Tagged cmt @ 11,320'. Drld cmt to lnr top. Tstd csg to 3000 psi OK. Drld 45' cmt in top of lnr. Drld cmt inside lnr from 12,590' -12,706'. Circ & cond mud. Tstd csg to 3000 psi OK. Set pkr @ 11,771'. Tstd lnr lap. Ran GR1CNL/CCL from 12,703' - 10,200'. Ran junk bskt & gauge ring. Ran 5-½" tbg w/shear sub' @ 11,414', Baker SAB pkr @ 11',589', BPR asbly @ 11,577', sliding sleeve @ 11,490' & ball valve nipple @ 2204'. Tstd hgr & control lines to 5000 psi OK. Displ tbg w/diesel set& tstd pkr, Installed & tstd xmas tree to 5000 psi OK. Pulled dunmy valve. Ran collar log & dun~ny gun. Reran dummy valve. Tstd balance & control lines' to .5000 .psi OK. Press tbg & anul for long term bug tst. Released rig '& 1100 hrs 6/11/77. l Eastman l A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY Atlantic Richfield COMPANY D. S. 9-12 WELL NAME Prudhoe LOCATION JOB NUMBER A677 /S001 TYPE OF SURVEY Multi-shot DATE 6-29-77 SURVEY BY Terry Henderson OFFICE Alaska . ,"O','~Plf:TION ........ RFDORT · jUNF 29,,'lg'"/'J '-' '" ·-."" '- - .... :.. ,~. - . ........... .. . ...~--.,.',-,--'.-_ ;..- ..... : , AX. LL'qI_.I_C_.~LCHFIELD CO............. ', m DRILL' SITE 9-i2 "' ': '. ""'""'"" -?.ULT!RMOT stjI~vEY ; !).ECLIk'.AT.ION 9~ :OEGR.EES EAST· ... .. · .. . .. F) I~VATIII~F rv'.l:TlA6r3 o~ (~F}f./DI-IT'/~If(IN.C, .. i~' t~. FI FV. R/. FT, '- -' . "'. - ' ..... FOR I:' A ¢ TM,AN ~ECO.R,,D OF _~LJR'VEY .... _ ,, j~' r - '" ! ............. ALL CALCULATIOi'~$ p..,~FORf~E.O 'BY I 8 t,4 ELECTF.~CNIC COIViPUT[R .. 'mUF fJF_PT)' AbtC, l F [~'PTH .qEA .. _. . . · . .. . ......... . .... ~.." r , n ) "l' ~' ?. c iL.'"~c ~.. V.E..~ II..AL ..... Ig..~6~.f .... ~:~.T ........................... _ 263L o O_ 260'O,00 26~6.00 1'~!8~..OOE ..'1.~.~:3~35 .N':" .7~7.o2 E __._Z_~2 _5 ~5 2781..71' ~727,7~ 588.00.E ...~.7~, 7 45 2875,05 Z821.05 5~3.00-E ._~jj.~.~ 1'0 0 2.966.94 2912,94 586,0-0E . · ~-. . ~ . .. .. f '~. ~ .. . ?l:;O2 12 30 3058.14 300~+.14 ~ ~ ~ ~ . ~ ~ I NII3IO I l__~ ~ I0 [ I l~:'~l~ ' ll~[]7'~ ] I : 150-9.,-30.N 3~.' 9' 37 E 2,42"~'.. ~.~5-9~ [. ~5.~,.~,,98 N".3~'~6 58 E .2,7'00 - '557,7~ '"t. ........ . ~... ...... ., .... . ,. ,__ . - ......... . .......... _ ~ -3~:'&~) '~7 Jo 3~8.72 3~'8~.72 -57~.00.E";~"[.~'7'7.~5'"~,~ ~4:5.~ E ..... ~5.3.2',25 .N 33 3.0:17 E' 2.73Z.'"' ~05."" ....................... . . .. ~ ';;~.~ 2~~ ~5 3327.52 327-3.52 57~.00E .126.8.39 [~ 875.1e E ~5~.1..'02 .N- 3~' 36 '1~9 '{..." -3.~8'1' 636' 1 llll l'6 1 '3 I I I 7;,'4.69 . . ____l~l~]]j~(' 0 3620.37 3757 Z% 5 3704.-09 3650.09 572,00E 1220.~2 i . 3.~:Ai. 31 15 3785,'75 3731,7.5 572,00E 1206,04 1084.00 E t6';2:,1,',.961 ''N' 41< ~16ll 518 3864.07 3810.07 ST0.OOE" 1189.72 N 1131,'~1 E ''[ '3;.032 ~02.60 . 41~1 ;5 15 4015.93 3961.9~ 568.00E .1150.(~, *' .12~,3,20 .E I I 16.86t,63 N.46.59'' t '.[ 3,,.25.2 1009.?i __z+22% 41 15 4087.42 4033.42 431641535 4155'68 4101.68 "4~.11 4~ 5 4k19.'29 4~'.05 ~1 0 4280,2B 4226.28 5~7.00E. 1127.~7 ~I .. 1.~.q.·7';·.59· :E ' [7.~i.·~1 N :50 ~2 ~3·2· :E . ~,·6;L·7· .. ~.~.:~C.eO '' ~ Il I . . L . - I . { ' , .... I l[ Ill I I Ill il I ~ . : I I Ill , . . I . . .~ . I . . · · '~ l · · ~ l I . · I I . l · . (; , . . · . . [ i i · i i i i i Il t ' i 'llfl' i RECORD OF:' ,SURVEY '."' ' ALI. CALCULATIONS PEf~FOF~MED BY :.! B r4 E.LECTRO!NIC ·COMPUTER , TRUE " ,DOG L,EG ............. MgAS. DRIFT VERTICAL SUB DRIFT. TOTAL COORD[.NATE. S .C L' 0 ,5 'U R g & SEVERITY DEPTH A,'tGLE DEPT~ ,. SEA D[REC . · , ~TA:t~CE .. ANGLE ... ~EG/looFT D H DEG. -- D N' $ - ... ,,59:~ 55 2.5 z+335o95 428.1.95 S66.OOk 1016.76 N ::L543o~0 '5 .... 1~G8.22 N 56 '37'25 E ~.76;~ , -, 1_3~~i~". 4690 55 ]5 4~88.27 4~1+.27 S65.50E 985.68 N 162.2.40:E' . 4784 ~5 0 4442.02 438'8.02 $65.0'0E 953.~0 N. 1682'43-'E 1933.79 N'60 27 38.E' 0.445 le86..'[~ ....... 4~76 5~ 45 449~,95 4440.95 $65.002 9~1,60 N. 175.0,6~ E 1978,~0..-"N 62 1~ 9 E 0,272 4967 55 0 .4547.31 4493.31 S65.50~. 8.9-0.~ N 1818.22.5 2024.55 N '.$~ 5~ ~7. E '...O.~O ' _1.9.~.1..~,~.~ .... . ~159 5~1'5 4656.32 4602.32 565.50E' 826.92 N_ 1957.60. E 2125.09'N'67, 6 0 g..,.'.0.26~. , N 20'94.16' E 2229.03 N 6.9 57 58 E .0.978 19~.D?~4_:.... 5258 54 15 4710,65 ~656,65 .S65,002 795.32 53~1 53 20 476~'58 4711,58 S65.0'05 763.60 5435 53 45 4BZ. 1:44 ~767.~4 $65.002, 731.~5 N 2162..68 E 22~'t:".C9 N 71 1~} :~i E '.O./+~e 552~ 5~ 25__'4B76.64 4822.64 .$~5.00E 7u(~.~2 N 22~0'.91 ~- 2337.78 N"72 5620 52 50 4931.~%3 /+877.83 S65.002 668.-91 N 2.297.22.,E , 2392:.6~ N 7~ /.5' D/+' E "... 'p.,641 21/+2.27 ...... 5712 52 50 /+987.40 4933.40 564,005 637,35 N' 236.~./+0. E 24/+7,8~. N'" 7/+ 5/+ 27'E 0,866 221~,~0 5806 52 50 5044.18 4990,18 5898 51 15 5100.77 90/+6.77 60~.~0 N. 2~3-0.87'E. · 2504.98 N'.76 .1 /+1E 0,42~ 22~5,17 574.44 N 2/+96,'7/+ E 2561,97 N 77 2 ~5 E %,993 2~55,38 5991 51 ~0 515[~...~2 5104.82 $67.005 545.~+6 N 2563.37.5 2620.77 6084 49 55 5217,70 Di6S'.70 576,665 ' 519,09 i~ 26~.',~/~..5 '2681.07 N.77 99 13 .E N' 7.8 50 10. E 6177 50 0...,,::5277.53 5223.53 $73.00E 496.50 N ~697,8'6 g 27~3.16 N"':79 3~ 20 g .. 6~7~ 53 15'...'9~35.~7 b2~1.87 ~73.00~ ~7/+.95 N 276'8,92.E "0.71i 2426.0V Z808..77 N.80 15 52 b364 56 10' -5389,60 5335.60 574.002 453.40 N 2841,09 E 2877.05' N 80 5-5 58 E ~.226 271b,7./+ ... 6457 55 25 ~4~1,87 5387,87 $74,0.05 4.~2.19 N 2915,03 .5 29/+6.90 N 81 33 59. E .. 0,79~ 2792.2~ 6551 55 0 5495,50 ~1.50 S74.002. 410.91 N- 2989.2'4.5 3017.~6 N 82 10 22 E "0,457 2~69.o7 6645 55 15 5549,24 5/+95.24 S7~,OOg 3'89,66 N 306.'~.,37 ................. 6738 55 0 ~02.~2 5548,42 &74.OOE ~6~.63 N 3136,72 E 3158,30~N 83:17 50 ~ .' 0,269 3~21.7~ 6924 56 0 5707,10 5.653,1<0 573.50E 325,93 N ...~8~,41 5 3300,54 7016 55 45 5758.~1 ~704,71 S7%,002 304,62 N' .~397,53'.5 ~'71.32 7109 ~5 0 ~811.55 D797,5~ S73,502 283,20 N, $~3::~.~00' E - 3~42,67 N- N 8~ 19 57 ,¢.., 1.075 E . '. .'0.446 N 84 48 57 E "0.460 N' 8~' 16 5g E' · "0.883 3097.95 3260.36 ~3~6.47 7202 ~5 30 ~864.56 58~0.56 674.002 261.82 N · . . . 3514.1~ 'N 85 ~3 ~7 · · mu JL .'. · o '. ALL CALCULATIONS PE.R, FORHED BY ! B iv. LLLCT.'-qO/',:IC COi',.'tPUT, ER..., .. .. TRUFZ DOG. LEG 'DRIFT VERTICAL SUB DP, IFT TOTAL COORDINATES C L 0 $' U R E $ SEVERITY 5gCl'IO."~' D!ZPTH ANGLE DEPTH SEA DIREC , . . , DISTA~N,,CE.' .,,., Ai'~G.L.E DEG. D M 5 DEG/iOOFT DISTANCg D M 7295 55 20 5917.35 5863,35 573.50E 240.39 !'4' 3577,87 E' 3585,93 N 86 9 21 5. 0.402 3~+7u'-.~0 7.387 55 0 5969.89 5915.89 57a.OOE 219,26 t~ 3650.~7' ~ -365.6,95 iv 86' 7479 55 0 6022.66 5968.66 ST~.OOE 198,49 ,'4. 3722.81 f 3728,10 N 86 ....................... 7571 5~ ~5 5075.59 6021,59 575.00E 17B,38 N 3795,32' E 3799.5'1' N 87 lB ~2 E 0,774 3705.06 7664 54 0 612~t7G 6075,76 $75,00E 158,81 N 3~6B,34 [" 3871,60 N'87 38 56 E 9.S06 ..____7757 .53 45_____6...18~._,...-_.13..c.) 6130,59 S75o00E 139,37 N '3940,90 F. 3943,36 N 87 58. 2'8 E 0,269 ~853,77 ........ 7C51 53 0 6240.&7 6186.67 574,00E 119,21 i~i 4013.59 E 4015.36 N 88 17 D5 E 1,047 392 ii., 9C 7943 53 15 6295,48 8335 53 0 6351.8~ ~128 53 30 6406.73 6241,88 573,00E 98,31F¢ 4.084,16 f 4085,34 N 8B 37 i5 E 0,749 6297.08 574,00E 77,41 N 4154,72 5 4155.4~ N 88 55 57 E 0,745 6352,73 S74.0'05 .55,87 N 4226.35 E 4226.73 N 89 13 ~4 E 0.538 8220 52 55 6461.82 ~407,82 573.50E 36.25 ?4 ' ~297.09 [ 4Z97.24 N 89 50 59' E 0.710 4Z'2",61~ 831¢ 53 40 6~i7.°9.. , 6463.99. 8407 .-~4 15 5'572.71 6518.71 $74.00E " .15.16 !'i 4369,44 E 4369,47 I'l 89 48 4 L~ 574,00E 5,56 5 444i.73 E 4441.7'3 S.89 5.5 .0,~60 0.624 4297.~6 4~7ge~8 .500 10 .... 573.1o 8593 '5"- 45 665:-.i6 6627,16 86~5 -r""5 lO 6733.9~ 6679.98 574,00E 573,00E 573,00'[ 26,35 S 4514,25 E 45.14.*32 $ B9 39" 55'.~ 0,066 ;47.54 5' 4586.60 ~ ~567,05 S 89 24 B E 0,95'0 69.87,$ 4658.84 E 4659,36 S 89 8. 26 E 0,457 4~47.,43 8779."~15 15 6787.61 6733,61 ~7] 55 0 6140.12 6786.22 ~964% .5'5 45 6873.6~ 6H~;e6~ 905° .56 15 6945.&3 ~891.63 573,50~ 92,11 S 47-32.76 573,50E 1.13,55 S 480.5,13 573,'00E 1'35,84 5 4879.20 ~73~,'65 S 88 4806,47 $ 88 53 5 ~' 0,~69 .. 3~ ~6 E 0,17~ 24 1~ ~ 0.877 573,00E %58,39 S 4952,~3 E 49~5,46 5 8b 10 6 ~ .. 0.538 9152 ~7 0 6997.3~ 6943.34 S73,00E I81.~ $ 5027.99' E 5031.26 S 37 56 4 E 0,798 9244 57 0 7047.45 6993.45 572.005 20405~ $ 5101.58 E 5i05,58 5 87 42 i4 g 'O,glZ 5057.0~ '. L "- 9358 56 20 7110,09 7056,09 571,50E 234.37 S 5192,'04' E 5197,3R 5.67 24 55 E 0.654 5151,36 9/+51 :~--30 7162.20 7108.20 572.00E' 258.49 5 5265.19 E 52.71.53 'S 87 ll Z1 E ""'O.W7~ .__ 9545 '.56____~15 7214.93 7160,93 571.50E 282.86 $ 5339,09. E 5346*58 5 86' 58 2 '~ 0,~79 9639 57 35 7266.24 7212.24 973~ -~7~-10 7315,52 7261,52 $71,00E 306,i7 S 5413,67 E 5422,44 S ~6 44 30 E 1,~7'.~ STI,OOE 334.23 $ 5489,35 E 5499.52 S 86 30 56 E 1.6~.1 5461,67 9~27 60 30 7362,75 7308.75 S70.OOE 9920' ' .~Z 35 7407,06 7353,06 361,36 5 5565,96 E 5577,68 5 569,5QE 389,66 $ 5642,67 5 565'6,10 5 86 2 58 E 2,287 RECORD OF":$URVE'Y" ALL CALCULATIONS PERFORMED BY I. B t,i E~ECTRO.N'IC, C, OMPUT~R'. TRUE .. · ' -' DOt kg~ . DRIFT VERTICAL SUB DRIFT TOTAL COO'RD INATE5 C'L. 0 5"U R E -5 SEVER!I;Y . SECTION DEPTH a .... ,~ ~,~.- DEPTH 5EA 'DIREC DIS'TANCE D M DEG, . ANG-Lg" DEG/iOOFT DISTANCE , D -.M.... s -m 10014 64 5 7449,24 7395,24 569,00E 4I:9,42 .5 5721,22 E !013d 63 50 7490,50 '7436,50 569,00E 449,69 S 5800,07 E !~02 6~ 30 7532,19 7478,19 5~9,00E ~7'9.88 5 5878,72 E 10297 63 0 7574,95 7520,95 $69,00E 510,28 $ 5957.,92 E 5979,74 $ 65 · 6' .16 E. 5736,'57 S 85 48 25 58.17.48 5.85"3'3 59 5896,28 .5. 85 t9 59 .I ,,1,653 , 570a.~ J 0.266 5787.9/~ 0.;~62 5870,70 0.5~6 5954,03 ... -~ 0,702 6036...06 · ~. 10391 62 20 7618.10 7564.10 S69.00E 540.21 S 60.35.88 E 6060,0'1 S 104~F ~2 0 7661,99 7607,99 569,00E 570,00 '5 6113,49 E 6.140,00 '5 84..-~0"23 E 0,362 '61~7,72 !' 1057~ 61 10 7706,24 7652,24 568,50E 599,6~ 5 6189,72 E 6218,70 S 84 2'7 5.9 E 0.983 ' .6'19~. O0 i 0.~19 62'-7~,4Z , 1,250 6~58,00 643,5,76 10672 60 30 7752.05 7698.0b 568.'00E 630.06 S 6265.96 E 62.97.56 'S 84 15'28_E 10766 59 35 7798,99 7744.99 567.00E 661.23 S .6341,20 .E 6375,58 5.~4 2 49. E i0559 58 ~0 78~6,70 '7792,70 566,50E 692,74'5 6414.54 E 6~51'.,-8.4 5 83 DO '10 .E ~,064 __1.__0~__5]___98 0 789~.05 7842.05 566.50E 11u47 5v 20 7946.32 7892,32' 566,00E 11141 56 15 7997,'80 7943,80 724,64 £ 6487,91 E 6528,26'5 83'37 37. g ' , 0.,,713 756,~3 S 6560,62 E 6&04.10 S 83 25 ~6 E 0,797 566.00E 7B8.62' $ 6632.~7 E 6679,19 S :83 11234 55 45 8049.80 7995.80 565.50E B20.28 S 6702.76'E '6752.77 .S- 83. 1:3 9. -1 22 ..6513.62 65'90.84 E 1 160 6667.23 ; 'E 0,651 . 6742,02 r 1].32~ 54' 30 8104,12 6050.12 565,00E 85.2,91S 6773,54 E 6827,-03 'S 82. 49'2.3 E 1,~61 i'422 53"10 8159.00 8105.00 564..50E 884.94 S 5841,45 E '6@'96.44 S- 82 37 46 'E 1.w7i .68.8.9,97 i i1513 51 40 8214.49 8160.49 563,50E -91i6.55 S 6906.26 E 6'9.66.'.82 S 82. 26.'24 E i.7~2 6'-9'59.1 ,~" 11608 49 45 8274,65 8220,65 563,00E 94'9,64 S .6971,92' E '7036',29 S 8'2 '1.4.' 36 E . 2',04.~+ 7:029'~" 11703 48 45 8336,66 8282,66 562,00E 98.2,88 S 7035,75' .E ".7104,07 $ 82 2 50 '.E 1.209 7:0'98,56' .... 11797 47 10 8399,61 8345,61 562,00E 1015,65 S 7097,39 E .7169.69 S. 81 51'22 .E..' 1,681 ""'7165,03 11890 45':.-45 8463.67 8409,67 S61'.OOE 1047...,8'2 S 7156,63 E .7'232,93 S 1.623 t 7.229 72.92 · 14 I -.~ 'I1964 44 55 8529.74 8475.74 S60.OOE 1.080.74 12015 44 20 8551,80 8497.80 S60.,OOE 1091,63 S 7'2.14,82 'E' ". 7295.,32' 5 81 26 50'..'.'.E. '1.,021 S. '7233..~9 'E 7315'59 S 81 2'5 '5.E..'. -1'903 '7312.64 .....-:-:'. '~23~-6. . . w4.. 0 8581,21 .~527,21 559,0052 1106.3~3 S' 7258,30-.. E 7342.10 S 61'20 .6.E..'. 1',440. 7339,43 .~!:].: ~..:;21 ~3 ....0 8700,89 8646,89 $57,00E 1166..,31 5- '735~,62 E 7~6,52 S 80 59 20 E' 0,828 7444.89 ~-']~_2314 ~2'"45 8769,05 8715,05 555,005 120'1,69 S 7407,07 E 7503,92 S 80 ~7 .5 .E 1,027 7502,79__~ :"' 12407 42..' 0 8837,75 87~3,75 555.00E 1237,65 S.- 7458,42 E 7560,~t 'S 80 34 41 .E 0,806. 7559,69 ................. 12500 ~1'...30 8907,13 8853,13 556,00E 1272'72 $ 7509,~5 E 7616,54 5 80 22 '50' E' 0,71~ -7o'16.1& i~"~~'.::~ .... ... ......... z.r":-'45:.~ 8977,19 89~3.19 557,00E 1306,~ S '7560,46 E 7672,51 5 ~0 ll 4~. E 0,928 767Z.32 , . ,. . ... ,, RECORD OF SURVEY ...... . ;. A~.L CALCULAT~.ON$ P'ERFORNED BY I B. N EL.ECTRONI'C CONpU.TEE,',.. ' ' ":.' . . TRUE :..-. · - FiEAS. DRIFT' VERTICAL SUB DRIFT TOTAL COORDINATES C L O.S.U-.'R E '& 5EV.ERITY SE£TION DEPTH ANGLE -DEPTH SEA DIREC D H DEG.' ..,.D.i,5'[',ANCE ... ... ANGL.~ .DEG/3,0OFT DISTANCE , ." .' D'.N · . --~$6 /'+0 3,5 '9047.91 8993.93, $55.00E 1340.25 S 7610'53 E 7727.64 ,5 8'0 O. 44 ~ 12800 mO 3,5 913~.91 9080.91 555'.00E I382.50 5 7670.86 E 7'79~.~5 .$ 7'9'47 0 E . ..O~,O'O0 BOTTOH ~OLE CLOSURE 7794.45 FEET AT.S 79 47 0 E , il i 11 n - Ii, ¢OORD'INATEiS' AND CLOSURE~ F. OR G~VEN .DEPTHS '.',:".;'""'." i iii n ' i i i ii i ii i l' iii "'1i . . t , , i. i . , , i . - .. , -~'-" ......' ..... TRUE ' - .....' ' ' '" · . · . CODE MEASURED VERTICAL TOTAL COORDI.NATES C- L O..$ U R E ""~ ,, ,SUB ~NTERPOLATED TRUE VERTICAL DEPTHS, NANE DEPTH DEPTH -DISTANCE , , . '-ANGLE"': ..... " '~gA ' D' M "$.' ' -f'O ~"'--g'A- 6-,- .............. i'}-a 7 6 ..... ~"e' ~ 4.7 6 1225.72'5 7441.38 E 7541.66, S 80 ~8"47.:':E 8760.76 ..BASE SAD. 126/+8 9018.95 1326,28 S 7590.27 E 7705.28. $ 80 5"18 E 8964.95 · ..... . . . , .. t , , i MEAS[JRED DEPTH AND OTHE~ DATA FOR EVERY . . EVEN. IOO':FEET OF j~'~,~'r.S-~'i ~"~H.',' TRUE MEASURED VERTICAL SUB 'MD-TVD DEPTH VERTICAL · TOTAL.. 'COORD'INATE5 .. DEPTH SEA DIFFERENCE CORRECTION' . . . 3700 3654, 3600 E' ... 3814 3754, 3700 60 14-. ..~ 121'1'-87' N 1.066,08 E ~' 3932 3854, 3800 77 17' 4O53 ,l,:.l 9 ~,. 99 N . . .i i · 1167.88 N 3954. 3900 99 22' 4180, 4054, 4000 126 27.' 1138,93 N 4315 4154. 4100 161 35 ..'1193.46 N 4464 4254, 4200 209 48 105.9,61N . 4629 4354, 4300 275 66 1006',32 N 1566'.68 E' .. 4804 4454. 4400 350 75 .. 4978 4554, 4500 424 74 5151 4654, 4600 497 73 5321 4754. 4700 567 70 946,48 N .,'!697'.28 E, "' 886,.63 N 1826:.,.39 E · 827.68 N 1954,3'8 .E.' .... ' ' 770'.39 N · 2079.99 5490 4854. 4800 636 69 " .... 712.96. N 22'02.77 5656 4954. 4900 702 66 656-70 N. .2323..18.E 5822 5054. 5000 768. 66 ... '599.20 N 2442.46 E " 5983 5154, 5100 829 61 .547,92. N ' "... 6140 5254. 5200 88'6 57' '505,. 07 2557,.6! E..' N 2670,84 'E' 6302 5354, 5300 947 61 ...... 467,71N . 2792,25"E '.". 6'478 5454. 540.0 1024 77 '427.43 N 2931,6'4 E' 6'653 5554, 5500 1099 75 38'7,65 N 306'9.69 g. .. 6829 5654. 5600 1175 76 .3~7,96 N 3208.80'E.. : .. ' 7007 5754. 5700 ~253 78 '3'06,36 N 3350,28 E · 7183 5854, 5800' 1329 76 26.5,84 N 3489,23 E 7.359 5954, 5900 1405 76 22'5.33 Iq 3628-23 'E,. 186,53' 7'533 6054, 6000 1479 74 N 3'765,36 E' 7~05 6154. .6100 1551 72 "15'0:'23 .N 3900.36 E' '. 7873 6254, 6200 1619 68 !14'.'33' N., 4030.,'.48 E 8040 6354. 6300 1685 66. 4158.44 E" ., · .76~ 3./-, N .,, "i .! /! ! 8.207 645~. 6.40.0 1753 68 8.3'75 . ,. 6554. 6500 1821 6'8 8546 6654, 6600 1892 7~ . 8720 6754, 6700 .1966-.- - .-.. 7~'" '.. .... 88,95 ,. 90'73 · 9~.'56 ':,~ :. 6854' 6954. ' ,6800 '69.00 7054, ' 7000. .... 2.202' .'-- ' - · ' 7 51/' ' .l'" :: .... : .... . · .' .. . . -..:....:..:'..: : .... ... .. .. · :, .: . , Iii , ' ,]~r; - ''. , ill ' Ill,I . 'i '.f:' il,i"~ 'il"' ""l ii'ii 'l I'".. "' ' ' 'i i 'It i ..I. 'j,~ Jlii" ii' I'. · .. .. ... .... . · . . · .. . ,,,"~', ' ,".', ,~ ~ ...... .-:, . ,;;~.' ~'~;:i',,: · 38,9'7:. N4287,06 E . . .......................................................... : · 1.. ;'5 ~;.," ,',~ 4'416.,,... ~.O ~:' · 36:,.8z.. ~ ,.4.5,,.5,o,. ,,i.~ g:,..'" :. · . . . . '.."7.8,27, ~..r...-A, 686'.'31'"F-' '...::....'"" ..-Z'.,:t.9.,,,,-3 :L.,. ~.'.,. ·..':4 SZ 3.9 5: .E'.:...'.'::::'.:'-":', .,,. ,,'.'.:',. -....., . .' '-.. ~6'2.o3... $" '4'~'64..,..s6,,..,E.:.'..... :-::'...:-.::: ..- MEASURED VERTZCAL SUB MD-'TVD V E, RT',I ,C,,A, L,,." .... DEPTH DEPTH SEA DIFFERENCE CORRECTION.'. .. TOTAL· '.'COORD,,INATE~,'.' '. ~::'' :: "':"" · . . 254,96.'S '' 5253'32 'E'. ."' 9436 7154. 7100 2282 . . 9616 7254. 7200 2362 80 '.-'.-" ' 302.19 $ '.. '5395..'24 .'-E ..... ':' ... 9809 7354. 7300 2455 10024 7454, 7400 2570 ;115"' ..... '.. '" '~ 5 m 7554 · ................... l...u.~ .... ,.... ................................... !u~ 7 7654· 7500 2696 7600 2~13 10675 7754, 7700 2921 10873 7854, 7800 3019 11061 7954., 7900 3107 11241' 8054, 8000 3187 126 :' 117 · '108 'r: · ...98' !- 88,' 'i;· '· 80-·. 72 :.::- 356.04 ~ ...... -,'55..51..'2.5" g'. '" 422,64 S ...... 5729,62 E'". 495.26 5'"~.-5'918.78. "E"':.'. 564'.30 '$ '~'" 6'098..6.~ ~'': ''~ 631.04 ..5 .-./.-" 6268,38 ,' E'/"'. 6.97.60. 761,42'" 822.73 11413 8154. 8100 3259 8.72 '$' 6949 78 .. ,... · . 2.0 7053.0,7 "E.:..' .' . 7147.'90 .'E "' 11576 8254, 882.08'..5' ''683~,:82.':':E.:"':".' ,8200 3322 : 63-."-' 11729 8354. 8300 · 3375 53 ' 99 8 ............ !.~7~ 8454. 8400 3422 ''47 10~2.99 $'" 1Z,",l_.~_.. 8554. 8500 3'464 " .42' ..... _1_~_196,. ~65~. .~600 3~02 · · .. '3..~ ~42,..33..~'.. .... 122~3 8754. 8700 3539 " '.-.3-7 ' 1193','56 .$ ~_~4'~9 ' ,. 8854. 8800 3~75 · . ..... 36 '-, 12562 8954. 8900 3608 33.. .. 73..:1.7,,1~...'~ "' ' . · .' . -7395.,.3'5 E' ..'." '" 7470'39"E: · .... 75'43.47" E .. , . . . 12694 9054. 9000 .3640 ... '." 32' 1343.21' $:' 7'614,7.5 E' · · .. ... .... ..- , . ... '..... ...... . . t, . , · . ... , , . . . . , , ,,,, , . . . .,' , . , , . , ,,i .. ~, il, i., . . ... ' 4.'.'. ~. ~ i Ju -., 7.,.~. % ........ 21.i i3 · . i i . ]ri. ii'ii" ':~. ~.: ~1.11 i' , ;J. ,., ~, . i'i' ':'" : ' '" 'f' r31 IE / r% %,/~..~' ... ;' '-..- :. ' .' - 5 E . . . . . .: . · · . . . . !':I~A_UR_D'. VE. RT _ ~AL SUB ,. :, ,, ...',, ,~.. . ., . ... . DEP..T,H DE.P'T,'H ' ' SEA 'TOTAL COOR'DI.NA.?.E,.$::.. "" ':.. - · . .... ....... i . ;' ,. . .i '., .r. i , il'Il ' '~1 ,~ 11 ' illi, ' ' i 'l i! r - . ' 10..00. 10:0,.0...., 2000 ' 2000,, '. 19~&, '- 3~0,00 2997'.~ 2.943 ... ": t+O00 ~9..1-0'. " .3856. .... , 5.900.".,'''' ,... ~.566. "' 4.5.12. $000.- ' '.""' 51:6~... 51 70'00,. ' "' 5'7':49"-.,, ,' ' 5695.. '63'30... 1' 2..91.0.7:.. t~, ".:.-"7,8~:;,.:.55..' E :~. ' 1:178 ,,.7:5:. Ni' ':'-' I!.1;6/~:',.~0-6'. E:'. ~ '...-. ~ ~.z .'.. 73:::~:, ~..~ :.::.: .z ~ ~'~.':'~:~.:~ .-....~ .' ' 3q.7.9.~.:;.'.~,.......,~..3~:-,7z:'-~:~'~.- ..'.,.... ,, , a., .. 8 5 '. 2;!j'..,N:.. "" 4'.1. Z7~-¢8 6':.. E:,~ ';,',r,:,' .' l,~4..3.r...s: ' ~9O.6~.~8.9:..E'-. :'.....'~, 7'~ 0...8 2, ~ S"....~..:.'.:..'6:SZ'~,'.,,A 6' E ~:/. - I o'8 6. :3 7. s"" ~" ~.:".~?2:-~&.':5-a:.-'.'E-: '~ .. · ' ,.' · . . . ~' . -.'..'t'. , ~ : , . ,. f · .¢,' ..· ~ ....~, .'.. .: -..1;.. ... . . . , '6', ,' . .t.. ~' ." ;' , ,' ,, ',.,. .. ' . . . .. · . · .'.. ... .'. ... :. · ....' , ' ' ' " . .. ................ '" ............. '~7 ·" '"'-" .... '~ 'i' ".','i' i : . ....... :"' ~'' - ' '~. ,~, ,..' :. :. , .'ri' ..... ,,"? " ,.." --' -'-:;;.','"~;.'.:~': " ' ' · ' ~ ' :, :::'i'"":'.i.'.":'. .... ; · -' .'.,~..- . -, ": ' .-,..i ........... - '.. . · . ...... ; :- · .. ..... : ..~ .......... .:.:: ................ ,... ~, .. . ,, --..: ,..'.,;..,'~ ..,~., ~;;',", ..... ' ' '" '" ' :- .' { ' '- -" ..... ,,,'r., ,. .. ' ' '~--" .':" :' ~." " ........................................................... HORJ ZONTAL_V_IEW ' ' .... ~ " ' ........ ~ ..... : .... SCALE I = I000 : ....... 'ATLANTIC RICHFIELD CO. "' ' : .- ........ RADIUS.OF CURVATURE .. - ~- .*~~ ~ ........... *MAGNETIC MUUTI-SHOT -[ .... ~ ...... , ............ r ........... f ............. ~ ....... t ............... ~ .......... ~ ........... ~ ........ ~ ...... ; ......... ; ~ · ; { ~ , . ~-~ .... ~ ......... o ...... ~ ............... : ................................ . ..................... .~ 0 ..... ~ ..... ' .... " o _ ~o ~ o mo ....................... ~ .......; .......... , ' ' I . i , ~ . ....... ....................... i .............. _~ .... "~'2_ ..... '2;__, .............................................. ALL DEPTHS SHOWN . - ................ ARE ~VO ......... ~ .... ~ . - s 80o 4~ .................... VERTICAL_ SECTION SCALE I"in¢,n ATLANTIC RICHFIELD CO.- WELL ..NO. _9-i2 RADIUS OF CURVATURE MULT I-SHOT ...... AtlanticRichfieldCompany North American Producing Division North Alas~? ..... 'rict Post Office ,__ .,60 Anchorage, Alaska 99510 Telephone 907 277 5637 June 13, 1977 Mr... Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 DIE - 2ENG G~ Dai~ Subject: D.S. 5-7 (22-5-10-15) Permit No. 77-13 D.S. 5-]_2_[41-31-11 15) Permit No. 77-14 ~~1-7-10-~6) Permit No. 77-7 Dear Si r' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned wells. Sincerely, F. M. Brown District Drilling Engineer FMB/kb Enclosures lmo~n No. P--4 l~g'd'. STATE OF ALASKA suB~,¢rr OIL AND GAS CONSERVATION COAAAAII-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER oPERATIONS WELL wELL OTHER 2. NAME OF OP]~%ATOR Atlantic Richfield Company 3. ADSAESS OF oPE~ATOB P. O. Box 360, Anchorage, Alaska 4. LOCATION O,F WE3.3~ 99510 1346'N & 75'E of SW cr Sec. l, T1ON, R15E, UM ~'AlmI NL~IERiCAL CODE 50-029-20239 6 LEASE DESIGI~tAT'ION AND $EHIAL NO. ADL 28345 7, IF INDIA}~, ALOI l.k.~ OR TI~IlBE NAI~IE 8, UNIT,F.~iM OR LEASE NAME Prudhoe Bay g. WELL NO D.S. 9-12 (11-7-10-15) FIELD AND POOL. OR WILDCAT Pw,,rihn~ Ray Fimld-Pr~Jdhn~ Nil 11. SI~-C., T., R., M.. (qE~DTTOM HOI..E Pool Sec. 7, TION, R16E, UM 1~., PEP.MIT NO. 77-7 REPORT TOTAL DEPTH AT END OF MONTH,CHA-NGES IN I-IOLE SIZE, CASING AND C~WiENTING JOBS INCLUDING DEPTH SET AND VOLLrlVIES USED, PERFORATIONS, TESTS A3qDP..E.~ULTS. FISHING JOB~. JLrNK I_N HOLE A.ND SIDE-TR~CKED HOLE A. NDA3qY OTI-iER SIGNIFICANT CI-I~G~ IN HOL~ CONDITIONS. Accepted rig @ 0500 hrs on 5/3/77. Drld 17½" hole to 2750'. RU & ran 13-3/8" csg w/shoe @ 2708', FC @ 2631'. Mxd & pmpd 5300 sx Arcticset cmt. Floats held OK. Inst &tst pkoff to 2000 psi. NU & tstd csg head & BOP. Tstd csg 1500 psi. Drld FS & 10' new form. TStd to 12.5 MW equiv. Drld 12¼" hole 12,150'. Ran SP/DIL to 10,500'. Circ & cond hole. RU & ran 9-5/8" 47# N-80 & S00-95 butt csg w/shoe @ 12,129', FC @ 12,044', lwr FO @ 2502', upper FO @ 2379'. Mxd 1000 sx Class G cmt w/0.75% D65 & 0.03% D13R slurry wt 15.8 ppg. Float shoe held OK'. Installed & tstd csg.pkoff to 5000 psi. Opened lower FO. Pmpd in 300 sx 16 ppg Arcticset cmt, 0.2% D13R & 0.2% D59. Closed lower FO & tstd to 3000 psi. Opened upper FO, ran Arctic Pack job. Closed & tstd upper FO to 3000 psi. Tagged cmt @ 11,730'. Tstd csg. Drld FC & cmt to 12,119. Tstd csg to 3000 psi OK. Drld shoe & 10' new form to 12,160'. Tstd form to:equiv 11,3 ppg mud. As of May 31 began drlg @ 12,160'. 14. 1 herebycerttfy~at th~rue and col'rec~ sm~D /'~,'~'~~.._ _ :~u~ --District Drilling Fn9~_ DA~ ~ NOTE --Report on this form is required for each calendar ~nth~ regardless of the status of operations~ and must ~ flied in duplicate with the oil and gas conBervation commi~ee by the 15~ of the suec~din9 mon~, ~le~ otherwise direcfed. STATE of ~ALASKA~ . DEPAR~T OF NARTrRAL P.~SC%/HIES Division of Oil and Gas Conservation TO: ~- FROM: Chief Petroleum Eng~ Harold R. t~wkins j~z~ / Petrole~ Inst~r DA'rE : _~'~y 25, 1977 SUBJECT: TO Witness BOP Test .Arco DS 9-12 Sec. 1, Ti~], R15E, I~I~it }~. 77-7 __Sa~y~.. May 7,_ 1977.- 1%~as picked up by S.hor~f Allen, supervisor for kr--c~/at 8:00 PM at DS 9 canlo %~%ere I ~as staying. ~ arrived at the, Rowan rig where I was to witness a BOP test c~ DS 9-12. The test plug was set and annular preventer was closed and the test pressure was 3000 psi. The annular preventer t~ld OK. ~ ~ pipe rams w~re closed and the check valv~ on the kill 1/ne ~ the outside choke valve w~re tested to 5000 psi. The outside choke which was a l-~lliburtcn ic~ to ~.~nTae wing valve le~3'..ed. With the top pipe r~ns still closed the outside kill and inside choke w~re ~sted to 5000 psi. ~xt ~he inside kill valve w~s tested to 5000 psi OK. the lower pipe rams v~re closed and tested to 5000 psi OK. ~e test stun was pulled and the blind rams %~re tested to 5000 psi. With the blind rams still closed, 6 ~R~ll~ 1(~ tcr _cue ~ valves away fr~n the stack in the cellar were testsd to 5000 psi CK. The manifold. ~ms tested next. There w~re 7 lc~ torque }~11~ wing valves and 22 flanges that tested to 5000 psi C%J,. The °~co super choke %ms also tek, ced to 5000 .psi. ~ere is also a manually operated choke that operates freely. The spool on the stack has 3" outlets. There w~s a ball va~ve and~ a dart valve on the floor that were C~(. The upper and lc~_r kel~Y"~was tested to 5000 psi OK. The nitrc~3en backup_ bottles had 1900, 2000, '2000 psi. %The master gauge on ~ a~tor sh~,~d 2500 .psi. '~ %~11 sign w~ ~ and all loca~on data CE. I checked- out the location and the mud pit %~s ¢~n, but ~_ll ~. They .have a steel tank not ~. The location in %,~eral was level and cl~n of debris. Tests took frcm 8:00 I~4 5/7/77 to 6:00 In_~: I witnessed Arco's DS 9-12 BOP tests %~"~J. ch ~_re. satisfactory.. ~ the outside dxgxe, valve~ ~r~l ~llen, s~0ervisor for ~co, is to call %~ by 5/11/77 %~en repaired. Oil and Gas Conservation Commi~ Field Inspection Report ~P' ~tfm Re'presented b Satisfactory Yes (X) ( )--I. Well Sign. 0()( ) 2, ~General Reserve '.Pit 4',, Ri.;g fil.led Satisfactory Type Inspection Yes No Item (~) BOPE Tests (X) ( ) 15. i set (X) () ' ( oil (X) () 17. Master Hyd. Control Sys.- ( ) Safety Valve Tests ( ) '( ) 5. SUrfa'c~"-NO. Wells 'i11' s ( ) (') 6. Subsurface-No. Wells i' 21. Kill ( ) Well Test Data ()~) (') 22'. Choke FtOwline ~) HCR val~ve ( ) (i) 7. Well NoS, , , , (~) ( ) 23. Choke Manifold No. valvs_Z,flgs~ I ) ( ) °bse~-----,' , , !( )Pos. ) ( ) I thcl( )csg( )none ( ) (;) 10. Gr. )) ,~ps~g ( 'q () (.!) 11. () () ( ) ( ) 1'4., Pad 1.eve.led . ).V (~).D.8?t ~'~'""'. TOtal inspe.ctiO'~' Obs'~r~m~{~"~~i'me ']~~/~a'ys T'o'tal".'~'~ber' leaks(~'"~"'";": ('~''' ')'~ and/or equip.Val ves'-fa ures;. '~'~' Remarks 0 ~ 7'..s-.~: :Z.~.~z-~ L ~m.~ ./~ /~''' ~') ~~_~ -~ ,..~m "~'~ ' '~" ~' ...... ~ "~ ' 'w'~'~=~. ~~ ~'. . ~.. :., ~ -',~ ~.-~ ' ,: ~"~ ~-'. ~...'~..'.~ ~-..~,~ '.~Z~ ~ · z. /~ e · :.. . . .. . . .' .. ,..... . . · . . .... . ,?... ..... .. ~ · ~ .. . · · , ,. -' . . · .. . .... ._ . .. ·. . · . , ... ~....:,, cc.: ~,~f ~z~4~;,~ No.,t~f~ .~n ~d~ .or .when~...ne. ady;-.....~~ I. nspected b~A~K/~.~ ~:~..,:,.. ::.~..~..:,:.;..;...::...:.,~..:....?,~::....~,.,~::,~:~:,:,:~;~...:~..~.....~,~,~.:~.~ ......... :~:~`.~..:~`~:~:~;?.;~.~::~.~.`::~...~.~:~..:.~~:~:~.~:;:.~;~;::`:~:~.~'~.~`:~;~:~;~;~`~`~:~?:~:~..~`~.~.:~ ...:,... ?.;.,.:: t.. ;;.:.,.'.? .~.:, ,~.:...:~..:.,: .... ...... ,::. ....... , ~...~.: .,.,~f,~;...~:~:..~.~t~,,.,,~::~.:~.~:: ~ ' · . '..: .:. . . .' .... .......' . ' . ~..'. ' . · . · · · ~.~?.,:'... ..... ... .... .. :.. . ·....... ,'....... .. . .... . . .... ..... . .'::.....::..:..,..',:.. .......... . . .~.. ~ . .....:"... . "~A~," .... '..' ." .- :'.'..'.'-. ' ..... '.~'.~-.::.....:.,-..: ............ ' ..... · ;'.:".",' ~:."~ .... '.~';~-.:,,,~,.~i:,'..:'~...;..,.:.. :~.'..')'~;-::.:L'.?~:.~.;.;<~..','.,:..;.~o.:.,:'.., ~.~.~...;..~.;;~.`~;....:~`~.~.~;~.::.~.~..;~:~.~:)~.i~:.~*:.~::~..:.~.~;~..~.. ..t;.'~ .' '.. ,,.,,'.'.%L.:L'.~,'C. '~,.~-:.'~-.,..:': .. '.~ '.:-..,... ;t~;.<.'...' '. ~:,;t~.J~;Jf~.-:',.,*4~;~,.~:;~.'.' ~:f~'~., .- Conservation March 2, 1977 Re: Pn~hoe Bay DS g-12 (11-7-10-16) Atlantic Richfield Company State Permit Ne. 77-7 Frank ~4. Brown Oistrict Dril 1 tng Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99§10 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 7, Township lON, Range 16E, U.M. t~e!l sa~ples, core chips and a mud Iog are not required. A directional survey is required. Many rivers in Alaska and their drainage systems have been classified as important for the sp~Ing or migration of anadromous fish. Operations in these areas are subject to AS !6.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code), Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- ~ent of Fish and Gan. Pollution of any waters of the State is' prohibited by.AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Deparbnent of Environmental Conservation. Pursuant to AS 38.4~3, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the ~ell is spudded, We would also like to be notified so that a representative of the Division ~ay be p. resent to witness testing of blowout preventer equipment before surface casing shoe is drilled. Frank )4. ~)rown -2- ~arch 2, 1977 In the event of suspension or abandonment please give this office adequate advance notification so that we My have a witness present. Very truly yours, Chai~n Alaska Oil and Gas C~servation C~ittee Enclosure CC: Department of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor Law Compliance Division ~/o encl. ~ AtlanjicRichfieldCompany North Amerir"~'-Producing Division North Alask, trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 1 7, 1977 Mr. Hoyl e Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 9-12 Dear Mr. Hamilton: Enclosed herewith is our Application for Permit to Drill DS 9-12 a $100.00 filing fee, and the required survey plat. Very truly yours, Frank Brown District Drilling Engineer /jw Enclosures Form 10-40!' f{£V. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN SUIIMI'I' IN {Other in,stt u'- ',n la. TYPE OF WORK DRILL b. TYPE OF WELL Ol L GAS ~-~LL [~ WELL 2. N.&.ME OFOPERATOR OTIIER DEEPEN r-] ZO,~E L~L ZONE L~L k?,,EC,-::-- , t:IV c D , Atlantic Richfield Company ,. P. O. Box 360, Anchorage, Alaska 99510 ; ' 4. L~ATION OF %~LL *"~46'Na 75'E of SW cr Sec l, TION, Rl5~.:'~4~ ' 1320 & 1250 E of NW'cr Sec 7, TION, R16E, UM DISTANCE IN MILES AND DIREC'IION FROM NEAREST TOWN OR POST OFFICE* Approximately 6-1/2 miles Northeast of Deadhorse, Alaska : 14. BOND INFORMATION: ~Statewide Surm,.nd/o,~o. Federal Insurance Co. 8011-38-40 AP I No. 50-029-20239 . · 6. LEASE I)k'SIGNATION AND SERIAL NO. ADL 28345 ?.IF INDIAN. ALLO'UI'EE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 9-12 (11-7-10-16) I0. FIELD AND POOL, OR WILDCAT ati~rudhoe Bay-Sadlerochit Poc 11.SEC.. T.. R.. M.. (BOTTOM HOLE OBJEC'flVE) Sec 7, TION, R16E, UM 12. Mo.., 100,000 ' 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FI'. (Also to nearest drig. uMt. finny) 1250 i8. DISTANCE FRO.M PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2496 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Pad Elevation (Gravel) 16. No. OF ACRES IN LEASE 2560 9524'TVD 17. NO.ACRES ASSIGNED '[O 'l'illS WELL · 320 20. ROTARY OR CABLE Rotary 22. APPROX. DATE WORK WII-L START March 20~ 1977 PROPOSED CASING AND CLM_ENTING PROGRAM ' :S[Z~ OF ttOLE SIZEO'=C*" O' 'I ~,~,~,,-,-:,.,.~ m, t GRADE., ~%~DE~H ~ntity o,';.mcn, .... . 20" 94~., 'H-40 lO0'+ Circ.'tO surf approx 500~.sx .. m17~ 13--3/8 7.2~. ,. N--80 2700'~. Circ to surf approx 5500.sx 12~ _ g-fi/8 47~ N-RO 17044~ 25~'+ Cmt COl,mn on 1st Staoe lC , . ~ 8k. 7" 2g~ N-80 1.3~42 . 1.200' thru LAP ,,O0~sx+ - - OOsx Atlantic Richfield Company proposes to dir~ctionally drill this well to 13492'+M~-,:_ 9524'+TVD to produce the Sadlerochit Zone. Logs will be run across selected intervals. A 20-3-/4" 2000 psi Hydril will be used on the 20" conductor. A 13-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# N-80 tubing, packer and necessary 'provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. The well will not be perforated at this time. A non-freeZing fluid will be left in all uncemented annuli within the permafrost interval. [bi ABO'%~ SPACE DESCRIBE PROPOSED PROGRAM: If proposal is~edeepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen dixecfionally, g~v¢ilettinent data on subs~face Iocation~ and measmed and true vertical depths. Give blowout preventer pro.am. DATE, r"trhis sp,:-- for State office use) j SAMPLES AND CORECIIIPS REQUIRED '; J' I~'P'EcTIo~AL suRVEy REQUIRED CONDITIONS OF APPKO(~AL, IF ANY: MUD LOG D VEs ~ so OTI{ E R R EQ',,.,IJB!ENTS: . A.P.i. NUMEI~I~dkL CODE 50-029-20239 PERMITNO._ 77~7 AI~'ROVALDATE... March ?: 1977 _ ~AP~VEDBY. ' TITLE DATE : March' 2; lq77 *See Instruction On Reverse Side · Well 12 Well · Well 14 -~'-~UILT WELL LOCATIONS .... L No. 12 LAT. 70° 14' 46.858"Y 5 94.2 815.87 LONG. 148° 14' 06.527"X 718 4.56.54- WELL No. 13 LAT. 70°14' 4.5.684.'Y 5 94-2 699.30 LONG. 148°14' 05.804"X 718 484.81 WELL No. 14 LAT. 70°1 4' 44.532"Y 5 942 582.98 LONG. 148o14.' 05.075"X 718 51=3.32 SEC. 2 SEC. I S El;. I I SEC. 12 · EXISTING WELL OR CONDUCTOR PIPE, RECEIVED D:vJsion of Oil ~nd Gas Conservation Anchorage CERTIFICATE OF SURVEYOR I HERE BY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION AND ALL DIMENSIONS AND. OTHER DETAILS ARE CORRECT. Feb'.77 ", :, .... ' .,,~;--. ' ' ,..:~,.,~;,?. ~, :;,.-. .... :~ / Surveyor ~: ARCO No. "'HVL~Io 39-DS9-77 ATLANTIC RICHFIELD CO. AS BUILT DRILL SITE No. 9 WELLS No. 12,13 t~ 14 LOCATED IN PROTRACTED SECTION I ,l'. I0 N., R.I 5 E.,U.M. PREPAEED BY HEWITT V. LOUNSBURY & ASSOC. 723 W. 6th AVENUE ANCHORAGE IALASKA DATE FEB. 1977 SCALE I" = 200' CHKD BY PC FIELD BK. CHECK LIST FOR NEW WELL PERMITS Company Yes No Remarks 1. Is the permit fee attached ..................... _ 2. Is well to be located in a defined pool .............. ~4~ 3. Is a registered survey plat attached . 4. Is well located proper distance from property line ........ ~ 5. Is well located pFoper distance from other wells ....... 6. Is sufficient undedicated acreage available in this pool ...... ~ 7 Is well to be deviated ...................... ~/~u~ ~ Is operator the only affected party ................ ~1~ 9. Can permit be approved before ten-day wait .......... 10. Does operator have a bond in force ............... ~)~ ll. Is a conservation order needed .................. 12. Is administrative approval needed .............. 13. Is conductor string provided . . ...... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings ~ Will cement cover all known productive horizons ......... 17. Will surface casing protect fresh water zones .......... 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~.~dZm..Z__psig . · 20. Has DMEM approved Plan of Operation ............... Additional Requirements' Approval Recommended' Geology.: Engi neeri TRM JAL tiHH JCM HWK >~4~ LCS?~?:,. RAD Revised 11/17/76
