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193-016
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P1-14 PRUDHOE BAY UN PTM P1-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 P1-14 50-029-22338-00-00 193-016-0 G SPT 8231 1930160 2058 2957 2958 2959 2957 225 406 408 411 4YRTST P Kam StJohn 3/1/2024 4 Year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P1-14 Inspection Date: Tubing OA Packer Depth 110 2344 2327 2326IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240301110445 BBL Pumped:1.5 BBL Returned:1.4 Thursday, April 11, 2024 Page 1 of 1 101D10 l ' ,_►U lu TO: Jim Regg P.I. Supervisor 1�ef G, �i'�fi3l aQj.PJ FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 7, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. P1-14 PRUDHOE BAY ON PTM P1-14 Src: Inspector Reviewed By: P.L Sop" �- Comm Well Name PRUDHOE BAY UN PTM PI -14 API Well Number 50-029-22338-00-00 Inspector Name: Jeff Jones InSp Num: miUJ200406082124 Permit Number: 193-01" Inspection Date: 3/21/2020 Rel Insp Num: Well P1-14 PTD F 1930160 Packer Depth w TVD 8231 SPT Test psi 2058 BBL Pumped: 2.2 ]BBL Returned: 1 6 Interval .. 4YRTST P/F N i Notes: I well inspected, no exceptions noted. Pretest Initial t5 Min 30 Min 45 Min 60 Min Tubing] 1944 1944 1924 2007 1870 1900 IA 345 2903 2871 -I 2874 28iI 2834 OA L 265 506 500 497 492 484 Tuesday, April 7, 2020 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS nl. 1. Operations Performed ML V [ _ZUU_ Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate Z V, Alter Casing 11C GG4 pk�oram Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: DAD Acid Stimulation ❑ 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Cless Before Work Development ❑ Exploratory ❑ 5. Permit to Dnll Number: 193-016 3. Address: P.O. Box 195612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 1 6. API Number: 60-029-22338-00-00 7 Property Designation (Lease Number): ADL 028297 8 034622 8. Well Name and Number: PBU P7-14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PT MCINTYRE OIL 11. Present Well Condition Summary: Total Depth: measured 11768 feet Plugs measured None feet true vertical 9189 feet Junk measured Unknown,11370 feet Effective Depth: measured 11680 feet Packer measured 10186 feet true vertical 9127 feet Packer true vertical 8065 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 39-117 39-117 2300 520 Surface 3875 10-3/4" 39-3914 39-3552 5210 2480 Intermediate Production 11724 7-5/8" 37-11761 37 - 9184 8180 5120 Liner 6183 5-1/2" x 4-1/2" 4376-10559 3890-8331 7740/8430 6280 / 7500 Perforation Depth: Measured depth: 11120 - 11574 feet True vertical depth: 8731 -9052 feet Tubing (size, grace, measured and true vertical depth) 5-1/2" 17# x 3-1/2" 9.2#, L-80 35-10332 35-8169 3-1/2" HES TNT Packer 10186 8065 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 10427 8238 true vertical depth) 4-1/2" Baker SABL-3 Packer 10554 8328 No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11120'. 111574' Treatment descriptions including volumes used and final pressure: Pumped 284.7 We DAD Acid Final Pressures: OA = 210 psi, IA = 340 psi, TBG = 1784 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 11707 73 2070 Subsequent to operation: 11709 340 1764 14. Attachments: (required per 20 Aec 25.070.25.07[, &25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:. 319-039 Authorized Name: Wages, David Contact Name: Wages, David Authorized Title: Well Interventions Engineer Contact Email: David.WagesObp.com Authorized Signature: ,� Date: I2 /I Contact Phone: 907.564.5669 Form 10.404 Revisetl 04/2017 ww/ b X2 k4=Iw- 3 RBDMS-L�'0DEC 1 Z 2019 Submit Original Onry Daily Report of Well Operations PBU P1-14 ACTI V ITV DATF m un�e n ov 11/13/2019 T/1/0= 1945/76/88 Temp= 150* (LRS Unit 70: Pre -Acid MIT -IA 3000 psi) MIT -IA to 3230 psi ***PASSED***Target Pressure= 3000 psi Max Applied Pressure= 3250 psi Pumped a total of 3 bbls of Methanol down IA to achieve a test pressure of 3245 psi. 1 st 15 minute loss of 9 psi, 2nd 15 minute loss of 6 psi, for a total loss of 15 psi in 30 minutes. Bled IAP to 100 psi. Bled back —2.5 bbls. Tag Hung. Valve Positions: SV= closed; WV,SSV,MV= open, Casing Valves OTG's. FWHP's 1947/76/87 T/1/0= 2000/180/120 Temp= 135* (LRS Unit 42 - DAD Acid) Loaded TBG with the following Fluid for Acid job: 25 bbls 12% HCL 213 bbls 2% KCI 153.6 bbls DAD Acid 10 bbls 2% KCI 10 bbls Oil Seeker Diversion 132 bbls 2% KCI Spacer ***Shut down for 15 min to let Oil Seeker Viscosity*** 10 bbls 2% KCI 82.9 bbls DAD Acid 10 bbls 2% KCI 5.5 bbls Oil Seeker Diversion 110 bbls 2% KCI ***Shut down for 15 min to let Oil Seeker Viscosity*** 10 bbls 2% KCI 48.2 bbls DAD Acid 4 bbls Neat 145.5 bbls 2% KCI 29.5 bbls Crude Freeze Protect 4 bbls Neat Valve Positions - SV= Closed - WV, SSV, MV= Open - CVs OTG - Choke Trailer= SI - DSO will POI after rig down 11/18/2019 Final WHP= 1250/10/25 TREE= 6-318" CNV WELLHEAD = FMC ACR.IATOR= BAKERC OI(B _tEw - 50' BF. EL2V= - - 20' COPOl1CiOR 11T KOP= ' 7289' ',, Max Angle = 48° 6106''LE, Ditum M)= __ 11288' 1=19.124' D3tun TVD = 8800'SS 10-3/4" CSG, 45.5#, hR'-80,D = 9.953'391 5-12' TBG, 17#, L -BO Tat .0232 bpf, D-4-892" 428 Minimum ID =2.750" @ 10289' 3-1/2" HES XN NIPPLE P1-14 SAFETY MI�WELD READINGERAGE 125 ppm S MH "' FMC TBG HGR IS 11" X 6-1/2" 5" "H" SME BPVG 2228' 4-12' HES X NP, ID GAS LFT MANDRELS 5-1/2'X3-12'X0,1D=2.992' 7-518' X 5-12' BKR ZXP LTP w BKR FLEXLOCK HGR D=4.780" 2' HIES X NP, D = 2.813' 10186' —j 5-12"x3-12' 1 -ES TNT aKR 10222' 312'HESX NP D=2.813^ SEE SPF N ERVAL Opn/Sgz SHOT SOZ 10289' 3-12' HES XN NP, D = 2.750' 'TBG, 92#, L-80 TCR .0067 bpf, D= 2.99Y H 10337 10332' 312' WLEG, D=2.8 5-12" SCAB LNR, 17#, L-80 TCR D = 4.892" 10399' 10399' 572' X 472• XO, D 4-12^ TBG STUB (12/19/15) --r 1040T� t 10416'7-518^ X 4-1/2 LML 4-12- T130,12.6#, L-80,.0152 bpf , D = 3.958^ 10610' 4-12^ TLBNG STUB (TAGGES 08/04105) 10.515' 4-12^ TBG, 12B#, L-80, .0152 bpf , D = 3.958' 10660 PERFORATK)4 SUMMARY REF LOG_ DLLIM-L ON 0316/93 ANGLE AT TOP PERF: 45' @ 11120' Note: Refer to Roduction DB for historical perf data SEE SPF N ERVAL Opn/Sgz SHOT SOZ 2-78' 6 11120-11150 O 03/31/07 3-38' 4 11162-11172 O 05/15/93 2-7/8' 6 11180-11200 O 03/31/07 338' 4 11210-11296 O 05/15/93 33/8' 4 11313 - 11343 O 05/1583 3-3/8' 4 11359 -11574 O 05/1583 ITD(11/13106)—t I PBTD 29.7#, NT95, D=6.875^ J 1 U414" 7-5/8" X 4-112' BKR S-3 PKR D= 3.87 00418' ELM JEWLRY LOG 1111310E 1044T 4-12" HESS X NP, D = 3.813' 05115193 POOL 07 INITIAL COM PLEnON 00452' ELMO JEWLRY LOG 11113/0( 10519' 7- lr X 4-1/2" L#dODE OV ERSHOT 10554' 7-5/8^ X 4-12' BKR SABL-3 FK R, D = 0184/15 JIYD DRLG HO CORRE= S (10544' ELMO JEWLRY LOG 11113!0( 11370' ELM TAG TOP OF TBG TAL (0823/06) 11399'4-12" PARKER SM NP, D = 3.813' (11/13/06) 11416' 4-12^ OTlS XN NP, D= 3725^ (11113!06) 11436' 4-1/2'77, WLCG,D=4.00'(11/13/06) DATE REV BY COM E?ITS DATE REV BY I COMMINTS 05115193 POOL 07 INITIAL COM PLEnON 03/17/16 JMG-dJMC GLV GO (03115116) 0885105 GJBHTL RWO 1227115 D-14 RWO 0184/15 JIYD DRLG HO CORRE= S 01/04/15 SMJM) ITNALODEAPPROVAL 0185/15 SMJM) MNOR®RS PONT MCNHY RE LINT WBL.: Pt -14 FEIWT W-- '1930160 AH No: 50-02322338-00 16, T12K R14F 1413' FSL 8 823' FE - BP Exploration (Ataska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY David Wages Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P1-14 Permit to Drill Number: 193-016 Sundry Number: 319-439 Dear Mr. Wages: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Www. a o g c c. a l a s k a. g o v Enclosed is the approved application for the 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, cv� Daniel T. Seamount, Jr. Commissioner DATED this Z qday of September, 2019. RBDMS J C OCf 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 . Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number 193-016 r 3, Address: P.O. Box 196612 Anchorage, AK 99519-8812 Stretigrephic ❑ Service 0 6. API Number: 50-029-22338-00-00 r 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 ❑ No 0 PBU Pt -14 t 9. Property Designation (Lease Number). 1 10. Field/Pools: ADL 028297 5 034622' PRUDHOE BAY. PT MCINTYRE OIL I 11. PRESENT WELL CONDITION SUMMARY Total Depth MD In): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (ps0: Plugs (MD): Junk (MD): 11768 9189 10476 8272 None Unknown,11370 Casing Length Size MD TVD Buret Collapse Structural Conductor 78 20" 39-117 39-117 2300 520 Surface 3875 10-3/4" 39-3914 39-3552 5210 2480 Intermediate Production 11724 7-5/8" 37-11761 37-9184 8180 5120 Liner 6183 5-1/2" x 4-1/2" 4376-10559 3890-8331 7740 / 8430 1 6280 / 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 11120- 11574 8731 - 9052 5-1/2" 17# x 3-1/2" 9.2# L-80 35-8169 Packers and SSSV Type: 3-1/2" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): 10186/8065 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: October 11, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages, David be deviated from without prior written approval. Contact Email: David.Wagesabp.com Authorized Name: Wages, David Contact Phone907 564.5669 Authorized Title: Well Int rve do Engineer rn �7 Authorized Signature: Date. `/(- 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3tG- �3�1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No IR/ Subsequent Form Required:/9�/c,X APPROVED BYTHE �r /Z7 Approved by: COMMISSIONER COMMISSION Date: 5 ll / Form 10-403 Revised 04/2017 ORIGINAL -IBDMS -)� OCT 012019 •. /� Submit Form and P4'V-� Approved application is valid for 12 months from the date of approval. Attachments in D plicate �rM11q 10-403 Sundry Application for Well PBU P1-14 PTD #193-016 Expected Start Date: October 11, 2019 Current condition of well: WAG Injection Well, Operable, Online: Water Injection Rate: 13622 bw d Gas Injection Rate: 0 Mscf/Da Injection Pressure: 2061 psi Reservoir Pressure: 3878 psi Program Objective(s): The objective of this program is to Perform fullbore acid stimulation to increase injectivity. Proposed Program: 1. Perform MITIA to confirm tubing integrity prior to acid. 2. Pump FB acid job per pump schedule. 3. Record pre and post acid injectivity. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Pump Schedule: Tubing Slmc Depth BPF Volume Volume ( al) 430 10559 0.0087 91.82 1350 7,625" 1105 1 0.04591 50.73 W70 2%KG 25433 Total 142.55 Fluid Volume Pickle 0.1 gal/ft DAO 30 gal/ft Diversion 2 gal/ft Interval Depth spf Bioballs DAD(gal) 11359-11574 215 4 880 6450 11313-11343 3D 4 120 900 11210-11296 86 4 344 2580 11180-112W 20 6 120 600 11162-11172 10 4 40 300 11120-11150 30 6 180 900 Total 1664 11730 Chemical Total H036 3450 (gal) BOSS 0 (gal) A026 1172 (gal) U074 0 (gal) A201 158 (gal) A255 0 (gal) A264A 4 (gal) F103 160 (gall L066 0 (gal) U067 0 (gal) W054 58 (gall WO60 0 (gal) A153 105 (Ibm) 1041 0 Obm) L056 0 (Ibm) LOSS 232 (Ibm) Oil Seeker 32.5 (gal) F103 57.59 (gal) Diversion(gal) Space, Rate (b m) Time (min( Volume ( al) 430 9675 Volume( el) Volume(bbl) 60 1350 Piddle 1050 25 172 W70 2%KG 25433 606 5.0 900 8,946 11730 279 injectivity is confumee, proceed w next stage 450 Ogte" 650 IS 6,450 1350 391.6 Spacer _ 662 17595 2.0 420 10.0 50 gpt on the Oilseek , stage 2gpt on KCL stage Pump Schedule Sta Descri Ion Fluida yP Rate (b m) Time (min( Volume ( al) Volume bbl) Co.. Volume (bbl( Comment Pickle 12%Hcl 5.0 5.0 1,050 25.0 25.0 Fill Wellbore 2%KCI 5.0 42.6 8,946 213.0 2380 injectivity is confumee, proceed w next stage Acid Stage DAD 5.0 30.7 6,450 153.6 391.6 Spacer _ 2%KCI 5.0 2.0 420 10.0 4016 Diversion 011seeker 5.0 2.0 420 10.0 631.6 Spacer 2%KCI 5.0 26.4 1 5,599 1 132.0 1 543.6 1 need to pump diversion through wellbore Shutdown to let 011seekervlsoc iy(15 minutes) Pre flush 2%KCI 1 5.0 2.0 420.0 10A 543.6 oncelnjectivity is confirmed, proceed to next stage Add Stap DAD 1 5.0 16.6 3,480 819 626.4 Spacer 2% KCI 50 2.0 420 10.0 636.4 Dlversio_n_ 'I'- Is, 5.0 1.1 230 5.5 601.9 Spacer 2%KCI 50 22A 4,620 110.0 751.9 need to pump diversion through wellbore Shutdown to let 011seeker vl-Ify (15 minutes) Pro- Flush 2%KCL 5.0 2.0 420.0 10.0 )61.9 onc_ ,activity Is confirmed, proceed to next stage Acid Stage DAD 5.0 8.6 1,800 _ 42.9 804.8 Flush _ 2%KCI 5.0 24.1 5,063 j 120.5 925.3 Freeze Protect FP 5.0 4.4 924 1 22.0 1 942.3 FP to 2500' Totals j 191.46 1 40,207 1 99.3 1 947.3 No bioballs needed. well shut in pressure 2000 psi, 3.69 hours 10-403 Sundry Application for Well PBU P1-14 PTD #193-016 Wellbore Schematic: T(EE _ 48• @61W I 190, N160LE, tt231T D- 19.124' Minimum ID =2.750"110289' 3-111" HES XN NIPPLE 0- FT3+FORATFON SUlAARI FIB LOG: DLIAIL CN034193 ANCIEATTOPPEIV 45.011120 NDY: 1Mer b Rodwicn DB fa kebdcal pelf dab SIZE SPF I N19TVAL I OPn/S4z SHOT SOZ 2-79' 6 11120- 11150 O 0313LD7 3-3/8' 4 11162- 11172 O 05/1IS93 2-7/6• 6 11180- 11200 O 0307A0 3-W 4 11210- 11286 O 05/15083 3-318' 4 11313- 11343 0 05/1593 3-31' 4 11359- 11574 O 05/1593 26 pm P1-14 SAFETY WHEN ON MI WIELLREQUIRESASSSSVWGE IHENON NH — FMC TBG HGR IS t I - 1t 6-V2' 5' -"'STYLE TTS BPVG 4 760' —} to332• f-{a-Irrv�Aw.D=zass•I 103W 512'x4-1re XO.D=4.692' NP, fiQE.L7 1137W ELm TAGTOPoE- TAL (08125N 11399• 4-12•PARKMSMNF-.D=3.813•(11 1141Y 4 -II< VIA IW NY,Ua,I_/LD (Y IIIJNp 11439' 4-I/Y TT, VILEG,D=4.00'(11/13A18) DATE FE1/ BY OOWANM DATE FFV BY COk#43M n9HWlP Valla] rrlMAl w VIT/tA 11fJ. lSVr/rl(nV1Vtf4 09=05 GJEVTLJI RNO 12127115 D14 FIND 019V75 J►D DFLGHOCORRBCIDFG 01F04115 S~ g4ALODEAPRDVAL 01105015 SNMIM MNORBTI S BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 PONT NICem FE UNIT K I - M-14 P4"1 W-. 59301W AH W 50.02912733800 Sec 16,T12NR14F 1413'FSL8823'F2 EIP Ezpbratbn (AFnka) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,April 11,2016 TO: Jim Regg (3� P.I.Supervisor `� 11- l� SUBJECT:Mechanical Integrity Tests ` BP EXPLORATION(ALASKA)INC. P1-14 FROM: Bob Noble PRUDHOE BAY UN PTM P1-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ/3i= NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P1-14 API Well Number 50-029-22338-00-00 Inspector Name: Bob Noble Permit Number: 193-016-0 Inspection Date: 3/24/2016 Insp Num: mitRCN160324152319 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -_ -- - --- W� 8231 ]171 •� 1155 - 1182 1181 - 1176 Well� P1-14 Type Inj TVD Tubing PTD' 1930160 Type Test SPT Test psi 2058 IA 717 2501 . I 2507 - 2496 - 2495 Interval INITAL P/F P t/i OA 434 600 606 . 603 - 598 - Notes: Sap*E° SEP 2 1 2016 Monday,April 11,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, March 24, 2016 7:13 PM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G;Igbokwe, Chidiebere; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; Morrison, Spencer; Munk, Corey; Regg, James B (DOA) Subject: OPERABLE:Injector P1-14 (PTD #1930160) AOGCC MIT-IA Passed Attachments: P1-14 wellbore.pdf; WAG Injector P1-14 TIO.docx All, Injector P1-14 (PTD#1930160) passed an AOGCC witnessed MIT-IA on March 24, 2016.This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells �/Y Organlzatlor Office: 907.659.5102 SCANNED JUN 2 8 2016 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, March 17, 2016 4:39 PM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G; Igbokwe, Chidiebere; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; Morrison, Spencer; Munk, Corey; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Injector P1-14 (PTD #1930160) Ready to be placed on Injection All, Injector P1-14 (PTD#1930160) passed a MIT-IA and MIT-T on December 27, 2015 pos ' work over. However, a downhole valve was sheered after the passing pressure tests were obtained. The downho valve was replaced and a non AOGCC MIT-IA passed on March 15, 2016. The well is ready to be placed on injection to fact 'tate compliance testing.The well has been reclassified as Under Evaluation. Please use caution when bringing the well online as the annuli are fluid packed. 1 \\ • • • WAG Injector P1-14(PTD#1930160)TIO Plot Well Pyle G-900 •—N • 0* O011 00 it--000A • 0211212 027012 311011 0124'2 0011112 042112 059011 00'16'12 O60211 061012 001111 077191 070/012 011172 061097 000617 00121 4412 102712 110171 1111712 120712 120512 121791 012213 042613 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, March 17, 2016 4:39 PM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G;Igbokwe, Chidiebere; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; Morrison, Spencer; Munk, Corey; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector P1-14 (PTD #1930160) Ready to be placed on Injection Attachments: P1-14 wellbore.pdf; WAG Injector P1-14 TIO.docx All, Injector P1-14 (PTD#1930160) passed a MIT-IA and MIT-T on December 27, 2015 post rig work over. However, a downhole valve was sheered after the passing pressure tests were obtained. The downhole valve was replaced and a non AOGCC MIT-IA passed on March 15, 2016. The well is ready to be placed on injection to facilitate compliance testing.The well has been reclassified as Under Evaluation. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Kevin Parks Nip APR 0 4 rul5 (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator 3 A l Ci°obal Wells '7a V Organizatior Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK,D&C Well Integrity Coordinator Sent: Wednesday, March 02, 2016 9:58 PM To: AK, OPS GPMA OSM;A-OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, DdUg-A;oDaniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RESEast Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G; Igbokwe, Chidiebere; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; 'Regg, James B (DOA) (jim.regq@alaska.gov)'; Pettus, Whitney; Odom, Kristine; Munk, Corey Subject: NOT OPERABLE: Injector P1-14 (PTD #1930160)TxIA communication d to downhole valve 1 • • WAG Injector P1-14(PTD#1930160)TIO Plot Well PI 14 I komer.....11111/%11nrwomor • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, March 02, 2016 9:58 PM To: AK, OPS GPMA OSM;AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G;Igbokwe, Chidiebere; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; Regg, James B (DOA); Pettus, Whitney; Odom, Kristine; Munk, Corey Subject: NOT OPERABLE:Injector P1-14 (PTD #1930160)TxIA communication due to downhole valve Attachments: P1-14 wellbore.pdf;WAG Injector P1-14 TIO.docx All, Injector P1-14 (PTD#1930160) passed a MIT-IA and MIT-T on December 27, 2015 post rig work over. However, a downhole valve was sheered after the passing pressure tests were obtained. The well has been reclassified as Not Operable until tubing integrity can be restored and has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, AAA�1G 0 42,0a Whitney Pettus SW'u��� (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator &CA:10911 V. Ofaantutw, WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinatorPBP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, February 28, 2016 5:12 PM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent;-ALK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G; Igbokwe, Chidiebere; Sauve, Mark A; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUTION: WAG Injector P1-14 (PTD #1930160) MIT--IA Passed Post Rig Work Over All, Injector P1-14 (PTD#1930160) is reclassified as UNDER EVALUATION not Operable. Sorry for the confusion. 1 • WAG Injector P1-14(PTD#1930160)TIO Plot '4121!P114 111- -11.- -A.- -t OA ow -+aaa On ?21112 2215"2 01'h...2 0214,2 M.0':12 32112 O51%.12 401412 342212 0616,2 063(03 2'412 2'2612 40! 2 0625,2 194'2 f92111 120511 132611!t 2212 1117.2'.22 12 12 1512 2'+1211 2126'11 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, February 28, 2016 5:12 PM To: AK, OPS GPMA OSM;AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G;Igbokwe, Chidiebere; Sauve, Mark A; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Sternicki, Oliver R; Regg, James B (DOA) Subject: UNDER EVALUTION:WAG Injector P1-14 (PTD #1930160) MIT-IA Passed Post Rig Work Over Attachments: P1-14 wellbore.pdf;WAG Injector P1-14 TIO.docx All, Injector P1-14 (PTD#1930160) is reclassified as UNDER EVALUATION not Operable. Sorry for the confusion. Kevin Parks (Alternates Whitney Pettus' BP Alaska -Well Integrity Coordinator tiVGlobal Weals Organizatior SCANNED MAR i 7 22016 Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, February 28, 2016 3:39 PM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G; Igbokwe, Chidiebere; Sauve, Mark A; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Sternicki, Oliver R; Regg, James B (DOA) (jim.re•g(aalaska.gov) Subject: OPERABLE: WAG Injector P1-14 (PTD #1930160) MIT-IA Passed Post Rig Work Over All, Injector P1-14 (PTD#1930160) underwent a Rig Work Over that was completed on December 27, 2015 to repair Tubing x Inner Annulus communication. A passing MIT-IA was performed by the rig on December 27, 2015, demonstrating competent downhole barriers. The well is now available post surface work to be put on injection and undergo a AOGCC witnessed test.The well has been reclassified as Under Evaluation to facilitate this compliance testing. Please use caution while placing the well on injection due to fluid packed annuli and the likelihood of annular fluid expansion.. Plan forward: • • 1. Operations: Put well on injection 2. DHD: Once thermally stable, perform AOGCC witnessed testing Please call with any questions. Thank you, Kevin Parks (Alternate. Whitney Pettus BP Alaska-`Well Integrity Coordinator E1 v,tit, ii 1'1t^ i 0rganizatior Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, February 01, 2013 7:41 PM To: 'Regg, James B (DOA)'; Wallace, Chris D (DOA); 'Schwartz, Guy L (DOA)'; AK, D&C Well Integrity Coordinator; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Gerik, Bob G; Warner, Ross L Cc: AK, D&C DHD Well Integrity Engineer; Climer, Laurie A Subject: NOT OPERABLE: WAG Injector P1-14 FAILED MIT-IA All, WAG Injector P1-14 (PTD# 1930160) failed a MIT-IA on 02/01/2013.The failed test indicates a lack of two competent barriers. The well has been shut in and freeze protected. It has be reclassified Not Operable and will be added to the Quarterly Injection Report as a Not Operable Injector. Attached are the schematic of P1-14's wellbore and a recent TIO plot for reference: Regards, Laurie Climer BPXA Well Integrity Engineer 907-659-5102 2 • • WAG Injector P1-14(PTD#1930160)TIO Plot Well PI 11 Tby • OA ••••••••••••.••••••=•••••••••••••••••••••• •-...••••• • 00CA Or k"" 11 it STATE OF ALASKA IONLASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI S 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing lI Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing lI Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Scab Liner LZ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-016 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service Q 6. API Number: 50-029-22338-00-00 7. Property Designation(Lease Number): ADL 028298&034622 8. Well Name and Number: PBU P1-14 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL ez_ �® 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11768 feet Plugs measured None feet JAN 1 9 2016 true vertical 9189 feet Junk measured Unknown,11370 feet Effective Depth: measured 10476 feet Packer measured 10186 feet .A OG C true vertical 8272 feet Packer true vertical 8065 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 42-117 42-117 2300 520 Surface 3873 10-3/4" 41-3914 41 -3552 , .... ., ._.521.Q, 2480 Intermediate Production 11724 7-5/8" 37-11761 37-9184 8180 5120 Liner 6183 5-1/2"x 4-1/2" 4376-10559 3900-8331 7740/8430 6280/7500 Perforation Depth: Measured depth: 11120 11574 feet True vertical depth: 8731 -9052 feet Tubing(size,grade,measured and true vertical depth) 5-1/2,17#x 3-1/2",9.2#,L-80 35-10332 35-8169 Packers and SSSV(type,measured and 3-1/2"HES TNT Packer 10186 8065 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: Cut and Pull 5-1/2",17#,L-80 Tubing from 10407'.Run 5-1/2",17#,L-80 Scab Liner from 4376'-10416'.Cement w/120 Bbls,1.31 yield(515 sx)Class'G'.Run 5-1/2",17#x 3-1/2",9.2#L- 80 Tubing to 10332'. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 600 0 Subsequent to operation: 0 0 0 20 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service II 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 0 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: 315-565 Contact Laplante,Jamin Email Jamin.Laplante@bp.com Printed Name Joe Lastufk Title Drilling Technologist Signature kWL. Phone +1 907 564 4091 Date 4 /1-F if 6 Form 10-404 Revised 5/2015 V-n 0-4 q 0 L RBDMS LL JAN 2 1 2016 Submit Original Only ?%� i • P1-14 Well History (Pre-Rig Workover) CTIVfTYDATE 'R ***WELL SHUT IN ON ARRIVAL*** T/I/O = 500/600/100 CUT TUBING AT 10396'. CCL TO CUTTER = 10.67'. CCL STOP DEPTH = 10385.33'. LOG CORRELATED TO TUBING TALLY DATED 05-AUG-2005. IA DROPPED 50 PSI AND TUBING CAME UP 100 PSI AFTER CUT. POOH. RDMO. FINAL T/I/O = 1000/550/100 9/13/2015 ***JOB COMPLETE. WELL SHUT IN UPON DEPARTURE*** 9/17/2015 Load diesel for Circ.out and travel to location. T/I/O= 1025/610/125 Temp= S/I (PRE-RWO CIRC. OUT) Pumped 5 bbls meth followed by 628 bbls of 85*F 9.8 brine down Tbg, up IA, taking returns to well P1-08's flowline for well circ out. Pumped 12 bbls diesel down Tbg still taking returns up IA and out P1-08's flowline for Tbg freeze protect. Pumped/bullhead 8 bbls diesel down IA for freeze protect. No diesel U- Tube due to production casing leak. Pumped 5 bbls of meth down P1-08's flowline for freeze protect. SV,WV,SSV=closed MV=open IA,OA=otg. All hardline valves=closed. FWHP=300/330/500. Tags and fluid packed annulus sign hung. DSO notified of well status 9/18/2015 on departure. T/I/O =Vac/Vac/100. Set 5" H BPV#DSM-03 . @112"W/2' Ext. Through tree. Installed tree 12/10/2015 cap and PT'd to 500 Psi. (PASS) RDMO. ***Job Complete*** FWHP = BPV/Vac/100. T/I/O = BPV/VAC/140. N/D 6-3/8"x 7-1/16" upper tree w/Baker actuator. N/U 6-3/8"x 7- 1/16"Temp#22. N/U Piggyback Temp#36 on I/A. N/U Piggyback Temp#03 on 0/A. See 12/11/2015 log for details. ***Job incomplete*** FWHP's = BPV/VAC/140. T/I/O = BPV/VAC/20. Pt'd dry hole tree. Verified VR plugs on Comp side IA and OA. Torqued 12/12/2015 flanges and Pt'd VR plugs. RDMO (see log). ***Job complete*** T/I/O = BPV/0/5. Temp = SI. Bleed WHPs to 0 psi (pre RIG). Well house, flowline removed. Dry hole tree installed. Cellar is covered with herculite and heaters installed working properly. OA FL near surface. Bled OAP to slop trailer from 5 psi to 0 psi in 1 minute(all gas). Monitor for 30 min. OAP @ 0 psi. Job complete. See log for details. Final WHPs = BPV/0/0. 12/13/2015 SV = ?. MV= O. IA, OA=OTG. 10:00 S • North America-ALASKA-BP Page 1 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UW:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 12/14/2015 12:00 - 15:30 3.50 MOB P PRE RIG DOWN MOVE OFF L2 WELL 8 11 -PREP TO SKID RIG FLOOR INTO MOVING POSITION -PJSM ON PREPPING RIG FLOOR FOR SKIDDING -CHECK WHEEL DRIP PANS FOR FLUID/LEAKS -CLEAN OUT RIG WASHER -RIG DOWN TRAILERS FOR MOVING SKID RIG FLOOR INTO MOVING POSITION -PJSM -SKID RIG FLOOR INTO MOVING POSITION 15:30 - 16:30 1.00 MOB P PRE MOVE RIG OFF OF WELL -PJSM -CHECK RADIO COMMUNICATIONS -VERIFIED STOP SIGNAL AND COMMANDS -TEST MOVING SYSTEM ESD -NOTIFIED PAD OPERATOR OF MOVING OFF OF WELL -VERIFY NO PRESSURE ON WELL TBG/IA/ OA=0/0/0 PSI 16:30 - 19:30 3.00 MOS P PRE INSTALL REAR BOOSTERS -PJSM -CLEAR OUT RIG MATS FROM IN BACK OF RIG -INSTALL REAR BOOSTER ASSEMBLY 19:30 - 22:30 3.00 MOB P PRE PJSM ON RIG MOVE -REVIEW STOP SIGNALS AND COMMANDS -CHECK RADIO COMMUNICATIONS PJSM ON RIG MOVE -MOBILIZE RIG FROM L2-PAD TO THE L2/ WEST DOCK INTERSECTION 22:30 - 00:00 1.50 MOB P PRE MOBILIZE RIG ON WEST DOCK ROAD -MOVE FROM L2/WEST DOCK INTERSECTION TO CCP -PULL OVER AND ALLOW FOR RIG CREW CHANGE OUT. 12/15/2015 00:00 - 08:30 8.50 MOB P PRE MOBILIZE RIG FROM L2 TO PM1 -MOVE RIG DOWN WEST DOCK ROAD TO PM1 ACCESS ROAD,TO THE PAD -RIG ON LOCATION AT 08:30 AM 08:30 - 14:00 5.50 RIGU P PRE REMOVE BOOSTER WHEELS FROM RIG -INSTALL NEW LANDING IN THE CELLAR -SPOT RIG MATS AROUND THE WELL -LOCATE AND SPOT OTHER RIG EQUIPMENT Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 2 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING©50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 14:00 - 20:00 6.00 RIGU P PRE SPOT RIG OVER WELL#14 -PJSM FOR SPOTTING RIG OVER WELL: CLOSE PROXIMITY TO OTHER WELLS DISCUSSED AND REVIEW PROCEDURES VERIFY PM1-WELL#13 IS OFFLINE FOR SPOTTING RIG -NOTIFY PAD OPERATOR PRIOR TO SPOT -VERIFY E-STOP FOR RIG IS OPERATIONAL PRIOR TO SPOTTING -BP WSL WITNESS RIG SPOTTING OVER WELL -MAKE ATTEMT TO SPOT OVER WELL, DISCOVERED THE RIG CANTALEVER HEIGHT IS NOT HIGH ENOUGH TO CLEAR ONE WELL HOUSE -MOVE RIG BACK AND DOUBLE THE RIG MATS UNDER THE RIG 20:00 - 21:00 1.00 RIGU P PRE SPOT RIG OVER WELL -PJSM FOR SPOTTING OVER WELLL: VERIFY E-STOP PROPER FUNCTION.REVIEW CLOSE PROXIMITY -WSL WITNESS SPOTTING OVER WELL -ENSURE RIG IS PROPERLY CENTERED, SHIM AND SET RIG IN FINAL PLACE 21:00 - 00:00 3.00 RIGU P PRE SKID RIG FLOOR -PJSM -SKID RIG FLOOR. -SPOT MATS FOR ROCK WASHER -SLIDE CONVEYOR OUT FOR ROCK WASHER RIG UP RIG FLOOR -PJSM -HOOK UP ALL LINES TO RIG FLOOR. -ENSURE RIG COMMUNICATIONS TO THE WSL OFFICE ARE OPERATIONAL. 12/16/2015 00:00 - 06:30 6.50 MOB P PRE RIG UP -PJSM. -TAKE ON 290 BBLS 9.8 PPG FLUID INTO PITS. -SLIDE CONVEYOR INTO PLACE. -RIG UP AND TEST HARD LINE FROM CHOKE SKID TO FLOWBACK TANK. -SPOT ROCK WASHER IN PLACE. -RIG UP LINES FOR RIG FLOOR. -EXTEND BEAVER SLIDE. -SECURE CELLAR AROUND WELLHEAD. -RIG UP CHOKE MANIFOLD LINES TO CELLAR. *RIG ACCEPTED AT 0400 HOURS ON 12/16/2015 *RIG EVAC(H2S)WITH AAR WITH WSL AND DDI TOURPUSHER. **PRE SPUD WITH DDI CREWS 06:30 - 09:30 3.00 RIGU P PRE PULL BPV -PJSM WITH DRILL SITE MAINTENANCE REPS. -RIG UP AND TEST LUBRICATOR TO 300/ 3500 PSI-GOOD TEST. -PULL BACK PRESSURE VALVE-0 PSI ON TUBING-0 ON IA. -RD LUBRICATOR. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 3 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 13:00 3.50 RIGU P PRE RIG UP CIRCULATE OUT FREEZE PROTECT -PJSM. -RU CIRC LINES/CHOKE SKID/FLOWBACK TANK. -PT LINES W/DIESEL 300 PSI/3500 PSI FOR 5 MIN EACH—GOOD TEST. **OA PRESSURE AT 1200=0 PSI 13:00 - 15:00 2.00 RIGU P PRE CIRCULATE OUT FREEZE PROTECT- -PJSM. -PUMP 57 BBLS OF 9.8 PPG BRINE DOWN IA TAKING RETURNS OUT TUBING TO FLOW BACK TANK. -TOOK 12 BBLS TO CATCH FLUID LEVEL,GOT RETURNS AT 17 BBLS AWAY. -3 BPM=270 PSI,12 BBLS AWAY,3BPM=370 PSI,17 BBLS AWAY 3BPM=540 PSI,FCP=3 BPM= 580 PSI. -LINED UP TO CIRC 97 BBLS DOWN THE TUBING AND OUT THE IA -ICP 2 BPM=190 PSI 3 BPM=410 PSI,4 BPM =710 PSI,5 BPM=1180 PSI,FCP=1210 PSI. -TOTAL AMOUNT OF DIESEL CIRCULATED OUT.-20 BBLS TAKE ON 290 BBLS OF 9.8 PPG VISCOUS BRINE 15:00 - 10:30 3.50 BOPSUR P PRE INSTALLTWC -PJSM WITH FMC REP -PU LUBRICATOR AND MU TWC,INSTALL TWC. -PERFORM ROLLING PT 500 PSI FROM BELOW. • -PERFORM PT FROM ABOVE 300 PSI/4000 PSI 5 MIN EACH. -RIG DOWN LUBRICATOR AND CLEAR OF RIG FLOOR. WELL ON SLIGHT LOSS,AVG 1 BPH STATIC, CONTINUOUS HOLE FILL WITH HIGH VIS 9.8 PPG BRINE. *OA PRESSURE @ 1800 HRS=0 PSI. 18:30 - 20:00 1.50 BOPSUR P PRE NIPPLE DOWN DRY TREE AND ADAPTER FLANGE -PJSM,REVIEW DOYON AND FMC PROCEDURE. -BLEED OFF HANGER VOID. -NIPPLE DOWN TREE AND ADAPTER FLANGE. -INSPECT HANGER THREADS-THREADS LOOK GOOD. -INSTALL 5.5"TCII BY 3-1/25"IF(XO)INTO HANGER, 6-1/2 TURNS TO MU. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 4 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UW1:500292233800 Active datum:ORIG KELLY BUSHING(d150.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 BOPSUR P PRE NIPPLE UP BOPE -PJSM -NIPPLE 11"X 13-5/8"ADAPTER FLANGE. -NIPPLE UP BOPE TO ADAPTER FLANGE. -BOPE STACK CONFIGURED WITH 13-5/8" ANNULAR PREVENTER,3-1/2"X 6"VBRs, BLIND/SHEARS,3-1/2"X 6"VBRs. **FLUID LOSS FROM NOON TO MIDNIGHT= 26 BBLS. **CURRENT STATIC LOSS RATE--1 BPH **OS PRESSURE AT MIDNIGHT-0 PSI. 12/17/2015 00:00 - 01:30 1.50 BOPSUR P PRE RIG UP TO TEST BOPE -PJSM -RIG UP BOPE TESTING EQUIPMENT -FILL IA WITH 9.8 VISCOUS BRINE -INSPECT TOP DRIVE AND PERFORM PRE-SPUD DERRICK INSPECTION -TAKE RKB MEASUREMENTS FROM RIG FLOOR WITH STACK IN PLACE *TABLE TOP H2S RIG EVAC:REVIEW DDI PROCEDURE FOR RIG EVAC Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 5 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011 M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING(g)50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 15:30 14.00 BOPSUR P PRE PRESSURE TEST ALL BOPE AS PER AOGCC REGS,SUNDRY#315-565,AND GP 10-45. -PJSM,REVIEW DDI SOP AND PRESSURE CROSSCHECK WITH CONFIRMATION OF CORRECT RESPONSES. -VERIFY LINE UP AND FILL STACK AND CHOKE MANIFOLD. -TEST BOPE TO 300/4000 PSI FOR 5/5 CHARTED MIN. -TEST ANNULAR TO 300/3500 PSI FOR 5/5 CHARTED MIN. -TEST BLOWOUT PREVENTERS AND ALL ASSOCIATED BOPE. -UPPER 3-1/2"X 6"VBR'S TESTED WITH 4" AND 5-1/2"TEST JOINT. -LOWER 3-1/2"X 6"VBR'S TESTED WITH 4" AND 5-1/2"TEST JOINT. -ANNULAR PREVENTER TESTED WTI-14" TEST JOINT. . INSTALL 4"DOUGHNUT TEST-PRESSURE TEST 300 PSI LOW,4000 PSI HIGH-GOOD TEST -SHELL TEST BOP,LOOK FOR LEAKS -BLIND/SHEAR RAMS TESTED. -TEST CHOKE MANIFOLD VALVES,CHOKE AND KILL NCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES. -TEST MANUAL AND HYDRAULIC IBOP'S ON TOP DRIVE. -TEST FLOOR AND DART VALVES. -TEST MAN ADJ/SUPER CHOKE=1500 PSI/ 5 MIN -PERFORM DRAW DOWN TEST OF ACCUMULATOR. -FUNCTION BOPE FROM REMOTE PANEL AND MAIN UNIT. -ALL TESTS WITNESSED BY TOOLPUSHER, BP WSL&AOGCC INSPECTOR AOGCC CALLED OUT TO WITNESS BOP TEST AFTER A SUCCESSFUL SHELL TEST AS PER REQUEST AT 03:00. AOGCC INSPECTOR BRIAN BIXBY WITNESSED BOPE TEST *ALARMS FOR PVT,H2S&GAS TESTED WITH STATE WITNESS. 15:30 - 17:00 1.50 BOPSUR P PRE RIG DOWN TEST EQUIPMENT. -RIG DOWN ALL BOPE TESTING EQUIPMENT. -CLEAR LINES FREE OF FLUID. -MAKE UP SAFETY JOINT WITH 5-1/2"LIFTER. -PU DUTCH RISER&INSTALL,SHUT THE ANNULAR Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 6 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011 M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 17:00 - 19:00 2.00 DHB P DECOMP PULL THE TWC WITH THE DUTCH RISER AND DRILL SITE MAINTENANCE LUBRICATOR -PJSM FOR PICKING UP THE LUBRICATOR AND PRESSURE TESTING. -PU/MU DSM LUBRICATOR AND EXTENSIONS AND QUICK TEST SUB. -ATTEMPT TO TEST DUTCH RISER AND LUBRICATOR TO 300 PSI LOW AND 3500 PSI HIGH-FAILED TEST _ 19:00 - 21:00 2.00 DHB N SFAL DECOMP INSPECT DUTCH RISER AND ANNULAR -BROKE OFF THE LUBRICATOR AND PULLED THE DUTCH RISER FOR INSPECTION -DRAINED THE STACK TO INSPECT THE ANNULAR. -CHASED DOWN THE LEAK TO A CONNECTION IN THE 9-5/8"DUTCH RISER JUST BELOW THE MANDREL LOCK DOWN. -BROKE APART AND C/O RING GASKET 21:00 - 22:30 1.50 DHB P DECOMP PULL TWC -PJSM FOR PRESSURE TESTING AND PULLING TWC WITH NEW CREW. -RE-INSTALL DUTCH RISER SYSTEM,MAKE UP LUBRICATOR W/EXTENSIONS -PRESSURE TEST TO 300 LOW,4000 PSI HIGH-GOOD TEST PASSES BP PASS FAIL CRITERIA FOR GP(100218) -RETRIEVE TWC AND MONITOR WELL FOR 10 MIN-WELL STATIC -RIG DOWN LUBRICATOR AND SEND OUT THE BEAVER SLIDE 22:30 - 23:30 1.00 WHSUR P DECOMP PULL THE 5-1/2"HANGER -PJSM FOR PULLING HANGER -REMOVE DUTCH RISER,MAKE UP LANDING JOINT CROSSED OVER TO 5-1/2"TCII -RIH AND MAKE UP TO THE TUBING HANGER -VERIFY CORRECT TURNS-7 TURNS -FMC BACKED OUT THE LOCK DOWN SCREWS -CHECK IA PRESSURE-0 PSI -PULL HANGER FREE WITH 190K,CONTINUE PULLING WITH BREAK OVER AT 205K, -PUW-198K -MONITOR WELL,FLUID LEVEL DROPPING IN THE STACK. -PULL HANGER TO THE FLOOR,SHUT THE ANNULAR AND CIRCULATE SURFACE TO SURFACE. -CIRCULATE WITH 9.8 PPG BRINE 23:30 - 00:00 0.50 WHSUR P DECOMP CIRCULATE SURFACE TO SURFACE -LINED UP TO CIRCULATE THROUGH THE • CHOKE AND MUD GAS SEPARATOR. -1 BPM,70 PSI,2 BPM,110 PSI,3 BPM-180 PSI,4 BPM-290 PSI, -FINAL CIRCULATING RATE-5 BPM WITH 510 PSI -9.8 PPG BRINE IN/OUT *SIM OPS:PU AND MAKE UP CASING EQUIPMENT FOR DECOMPLETE. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 7 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Datelme:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/18/2015 00:00 - 01:30 1.50 PULL P DECOMP CIRCULATE SURFACE TO SURFACE -LINED UP TO CIRCULATE THROUGH THE CHOKE AND MUD GAS SEPARATOR. -1 BPM,70 PSI,2 BPM,110 PSI,3 BPM-180 PSI,4 BPM-290 PSI, -FINAL CIRCULATING RATE-5 BPM WITH 510 PSI 9.8 PPG BRINE IN/OUT -MONITOR WELL 10 MIN PRIOR TO PULLING OFF BOTTOM.-WELL IS STATIC NO LOSS -TOTAL LOSS FOR CIRCULATION 5 BBLS. 01:30 - 06:00 4.50 PULL P DECOMP BLOW DOWN ALL LINES. -PJSM:FOR PULLING OUT OF THE HOLE -BLOW DOWN ALL LINES. -LINE UP TO FILL HOLE FOR TRIP OUT.WSL AND DRILLER VERIFY AND AGREE TO PIPE DISPLACEMENTS -LAY DOWN LANDING JOINT,BREAK OUT HANGER -PULL AND LAYDOWN 5-1/2"17#,L-80 TUBING FROM CUT AT 10,396'MD TO 10,259' -MONITOR TRIP ON TRIP TANK. -PULL 5 STANDS,WHILE LOOKING DOWN THE HOLE WELL SWABBING WHILE MOVING PIPE -STOP FOR FLOW CHECK-NO FLOW,WELL STATIC -CIRCULATE BOTTOMS UP -AT 5 BPM,W/400 PSI,NO LOSSES OBSERVED -9.8 PPG BRINE IN&OUT * SIM OPS RIG UP A FILL UP HOSE TO FILL TUBING FROM TRIP TANK TO CONFIRM CORRECT DISPLACEMENT. -ESTABLISH SCR'S 06:00 - 11:30 10.50 PULL P DECOMP DECOMPLETE 5-1/2"TCII TUBING -POOH LAYING DOWN 5-1/2"TCII TUBING FROM 10,200'TO SURFACE. -FILLING PIPE EVERY 10 JOINTS -MONITOR TRIP ON TRIP TANK-CORRECT HOLE FILL OBSERVED. -AVG BREAK OUT 8 K FT/LB 16:30 - 18:00 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -L/D CSG TOOLS -MOBILIZE BAKER FISHING DRESS OFF& SCRAPER BHA#1 T/RIG FLOOR -SIMOPS:LOAD AND STRAP 4-3/4"DRILL COLLARS IN PIPE SHED **SIM OPS:HELD PLANNING MEETING FOR UPCOMING CEMENT JOB FOR 5-1/2"SCAB LINER. SLB,BP IN ATTENDANCE. 18:00 - 19:00 1.00 WHSUR P DECOMP INSTALL WEAR RING -RIG UP AND PREPARE TO INSTALL WEAR RING -DRAIN STACK -INSTALL 7"ID WEAR RING -RUN IN LOCK DOWN SCREWS Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 8 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:OOAM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING©50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 21:00 2.00 CLEAN P DECOMP PICK UP AND RUN IN THE HOLE WITH BHA#1, DRESS OFF&SCRAPER ASSY TO 235' -PJSM FOR PICKING UP BHA: -MAKE UP BHA AS DIRECTED BY BAKER OIL TOOL REP -PICK UP(6)4 3/4"DRILL COLLARS -TOTAL LENGTH OF BHA-235.16 -MONITOR WELL ON TRIP TANK-WELL STATIC 21:00 - 00:00 3.00 CLEAN P DECOMP RUN IN THE HOLE WITH BHA#1,DRESS OFF &-SCRAPER ASSY -PJSM FOR PICKING UP SINGLES -RIH WITH BHA#1 ON 4"DP SINGLES FROM THE PIPE SHED.-FROM 235'TO 3,238'MD MONITOR TRIP ON THE TRIP TANK- CORRECT ANKCORRECT DISPLACEMENTS OBSERVED 12/19/2015 00:00 - 05:00 5.00 CLEAN P DECOMP RUN IN THE HOLE WITH BHA#1,DRESS OFF &SCRAPER ASSY -PJSM FOR PICKING UP SINGLES -RIH WITH BHA#1 ON 4"DP SINGLES FROM THE PIPE SHED.-FROM 3,238'TO 8040' -PUW=176K SOW=130K -MONITOR TRIP ON THE TRIP TANK- CORRECT ANKCORRECT DISPLACEMENTS OBSERVED -RECIPROCATED 7-5/8"CASING SCRAPER 50' ON EITHER SIDE OF THE PROPOSED PACKER SETTING DEPTH F/4375'T/4467'3X **KICK WHILE TRIPPING DRILL WITH AAR W/ DDI TOUR PUSHER AND WSL 05:00 - 07:00 2.00 CLEAN P DECOMP CONT SINGLE IN THE HOLE FROM PIPE SHED WITH 4'DP -RIH 1X1 DP FROM PIPE SHED F/8,040'T/ 10,355' -MONITOR TRIP ON TRIP TANK-CORRECT DISPLACEMENT OBSERVED. -OBTAIN SCR'S—9.8 PPG BRINE -#1 MP 30 SPM=200 PSI 40 SPM=340 PSI -#2 MP 30 SPM=210 PSI 40 SPM=330 PSI 07:00 - 09:00 2.00 CLEAN P DECOMP RIH WITH BHA#1,DRESS OFF AND SCRAPER ASSY -RIH F/10,335'TAG TOP OF4-1/2"STUB AT 10,401.5' -ESTABLISH PARAMETERS PER BAKER REP. -PUW=210 K,SOW=145 K,ROT 175 K,70 RPM W/7.5K FREE TQ. -4BPM=390 PSI,3-5K WOB,MILL TQ=9K, DRESS OFF TO 10,402',GO OVER STUMP WITH NO ROT. -MONITOR WELL FOR 10 MIN-WELL IS STATIC.. -BLOW DOWN TOP DRIVE 09:00 - 10:30 1.50 CLEAN P DECOMP POOH STANDING BACK IN DERRICK 48 STANDS -PJSM FOR POOH WITH DP,STANDING BACK IN THE DERRICK. -POOH F/10402'T/6949', -PUW=147K SOW=129K. -MONITOR TRIP ON TRIP TANK-CORRECT HOLE FILL OBSERVED. Printed 1/6/2016 5:27:29PM • . North America-ALASKA-BP Page 9 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:00 1.50 CLEAN P DECOMP DROP DART AND SHEAR PUMP OUT SUB AND CONT STANDING BACK DP -DROP DART AND SHEAR PUMP OUT SUB OPEN,98 STROKES(9.8 BBLS). -CONT STANDING BACK DRILL PIPE F/6,949' T/5,863'. -LD DP 1X1 F/5,863'T/5,047'. PUW=130K SOW=110K 12:00 - 12:30 0.50 CLEAN P DECOMP RIG SERVICE -LUBRICATE RIG -SERVICE TOP DRIVE,INSPECT DRAWORKS, ST-80. 12:30 - 16:30 4.00 CLEAN P DECOMP POOH LAYING DOWN DP SINGLES -CONT LD DP 1X1 F/5047' T/266'MD. -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING BHA THROUGH THE STACK -WELL IS STATIC. 16:30 - 18:00 1.50 CLEAN R DECOMP LD DRESS OFF BHA#1 -PJSM WITH BOT REP -LD DRESS OFF BHA PER THE BOT REP -RECOVERED.5 LB METAL SHAVINGS FROM EXTREME MAGNET,BOOT BASKET WAS EMPTY,MILL SHOWED SIGNS OF PROPER WEAR 18:00 - 23:00 5;00 CLEAN P DECOMP CLEAN&CLEAR RIG FLOOR - PU MU RIH WITH 7-5/8" RTTS -CLEAR RIG FLOOR OF NONESSENTIAL TOOLS -PJSM WITH HES REP -RIH F/13' T/4,473 MD -OBTAIN PARAMETERS,PUW=112K SOW= 105K,CIRC 5 BPM W/180 PSI -CIRC AND SET RTTS AS DIRECTED BY THE HALLIBURTON REP 23:00 - 00:00 1.00 CLEAN P DECOMP PRESSURE TEST(MIT)FOR 7-5/8"CASING FROM 4,468' TO SURFACE -PRESSURE TEST 300 PSI LOW 5 MIN,4000 PSI HIGH-30-MIN -300 PSI TOOK 2 STKS(.2 BBLS),PRESSURE TEST TO 4100 PSI TOOK 21 STKS(2.1 BBLS) (2 BBLS BLED BACK AFTER TEST) -MIT PRESSURE TEST MEETS PASSING CRITERIA FOR BP GP(100218)1B&38 -CENTER OF ELEMENT FOR RTTS @ 4468' MD -GOOD TEST PER WSL, WTLAPPROVAL NOT NEEDED FOR CONTINUED OPERATION 12/20/2015 00:00 - 01:00 1.00 DHB P DECOMP RELEASE RTTS PACKER -PJSM WITH HES REP. -BLEED OFF ALL PRESSURE -RELEASE PACKER PUW=112K SOW=105K. -PU TO 112K,ALLOW ELEMENT TO RELAX, OPEN RTTS CIRC VALVE. -MONITOR WELL-WELL STATIC -SLACK OFF PAST SETTING DEPTH,SET SLIPS,BLOW DOWN CHOKE/KILL LINES. -PREPARE FOR SLIP&CUT OPERATIONS. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 10 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING©50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 03:30 2.50 DHB P DECOMP SLIP AND CUT 60'DRLLING LINE -PJSM -SLIP AND CUT 60'OF DRILLING LINE. -INSPECT SAVER SUB,PER MANUFACTURER RECOMENDED PROCEDURE. -SERVICE TOP DRIVE,BLOCKS,DEADMAN ANCHOR. -MONITOR WELL ON TRIP TANK WITH CONTINUOUS HOLE FILL DURING SLIP&CUT WITH 9.8 PPG BRINE 03:30 - 06:00 2.50 DHB P DECOMP POOH WITH 7-5/8"RTTS: -MONITOR WELL PRIOR TO PULLING RTTS- WELL STATIC -DROP 2"RABBIT -POOH FROM 4,468'TO SURFACE,RACKING BACK 4"DP -MONITOR TRIP ON TRIP TANK-OBSERVED CORRECT HOLE FILL. -LAY DOWN RTTS TO THE GROUND 06:00 - 08:00 2.00 TIEBAC P OTHCMP RIG UP TO RUN 5 1/2",17#/FT,L80,TCII SCAB LINER • -PJSM FOR LINER RUN OPERATIONS. -RU CASING TONGS&TORQUE TURNS EQUIPMENT,PU&MU LIFTING EQUIPMENT: VERIFY CORRECT SIZE AND LIFT RATING FOR ALL THIRD PARTY EQUIPMENT. -DRILLER AND LEAD FLOOR HAND TO VERIFY SIZE AND RATING FOR LIFTING EQUIPMENT. - MAKE UP DP SAFETY JOINT WITH CORRECT LIFTER,MAKE UP 5-1/2"TCII XO TO THE TIW. 06:00 - 12:00 4.00 TIEBAC P OTHCMP PICK UP AND RUN IN THE HOLE WITH 5-1/2", 17#/FT,L80,TCII SCAB LINER TO 1,124'MD -PICK UP AND BAKER-LOK BAKER,PORTED PUP W/FLOAT COLLAR AND LANDING COLLAR ASSEMBLIES -FILL AND CHECK FLOATS-FLOATS-GOOD -JET LUBE SEAL GUARD ON ALL OTHER CONNECTIONS -TORQUE-TURN ALL CONNECTIONS -MAKE UP TORQUE FOR 5 1/2"TCII CONNECTIONS:5500 FT-LBS-MAX -MONITOR TRIP ON PIT 4-CORRECT DISPLACEMENT OBSERVED. -90 FPM MAX RUNNING SPEED -RECORD PU AND SO WEIGHTS EVERY 10 JTS -FILL LINER EVERY 10 JOINTS 12:00 - 12:30 0.50 TIEBAC P OTHCMP RIG SERVICE -LUBRICATE RIG -GREASE AND INSPECT TOP DRIVE Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 11 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING©50.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 00:00 11.50 TIEBAC P OTHCMP PICK UP AND RUN IN THE HOLE WITH 5-1/2", 17#/FT,L80,TCII SCAB LINER FROM 1,124' MD TO 5,072' -90 FT/MIN MAX RUNNING SPEED SET BY BAKER -MAKE UP TQ FOR 5-1/2"17#,TCII-5500 FT/LB -JET LUBE SEAL GUARD ON ALL CONNECTIONS -TORQUE-TURN ALL CONNECTIONS -90 FPM MAX RUNNING SPEED -RECORD PU AND SO WEIGHTS EVERY 10 JTS -FILL LINER EVERY 10 JOINTS -BACK OUT AND LAY DOWN 4 JOINTS;BAD THREADS. -PU 125K;SO 113K 12/21/2015 00:00 - 00:30 0.50 TIEBAC P OTHCMP RIG SERVICE -SERVICE TOP DRIVE. 00:30 - 04:00 3.50 TIEBAC P OTHCMP PICK UP AND RUN IN THE HOLE WITH 5-1/2", 17#/FT,L80,TCII SCAB LINER FROM 5,072' MD TO-5,902' -JET LUBE SEAL GUARD ON ALL CONNECTIONS. -TORQUE-TURN ALL CONNECTIONS. -MAKE UP TORQUE FOR 5 1/2"TCII CONNECTIONS:5500 FT-LBS-MAX. -90 FPM MAX RUNNING SPEED. -RECORD PU AND SO WEIGHTS EVERY 10 JTS. -FILL LINER EVERY 10 JOINTS. -RUN 145 JTS PLUS SHOE TRACK ASSEMBLIES. -VERIFY CORRECT PIPE COUNT IN THE SHED PRIOR TO PICKING UP THE HANGER. -MAKE UP BAKER 5 1/2"x 7-5/8"HMC LINER HANGER AND HRD-E ZXPN LINER TOP PACKER ASSEMBLY. -VERIFY HMC LINER HANGER PINNED WITH 4 SHEAR SCREWS:-2300 PSI. **BACK OUT AND LAY DOWN TOTAL OF 6 JOINTS;BAD THREADS. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 12 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 09:30 5.50 TIEBAC P OTHCMP RUN IN THE HOLE WITH 5 1/2",17#/FT,L80, TCII SCAB LINER ON DRILL PIPE STANDS FROM 5,902 -MAKE UP FIRST STAND OF DRILL PIPE AND BREAK CIRCULATION -80 PSI @ 1 BPM;130 PSI @ 2 BPM;170 PSI @ 3 BPM,260 PSI @ 4 BPM -CONTINUE RUNNING IN THE HOLE ON STANDS OF DRILL PIPE FROM THE DERRICK -90 FPM MAX RUNNING SPEED -RECORD PU AND SO WEIGHTS EVERY 10 JTS -FILL DRILL PIPE EVERY 5 STANDS -MONITOR TRIP ON THE TRIP TANK.- CORRECT DISPLACEMENT OBSERVED RIH WITH LINER FROM 5,902'TO 10,386' -ESTABLISH PARAMETERS:PU1Iw210K, SOW-150K, PICK UP AND MAKE UP TD CEMENT SWIVEL AND PLUG DROPPING HEAD -MAKE UP CEMENT HEAD AND SWIVEL TO 4" DP SINGLE -RIG UP CEMENT LINES AND CEMENT MANIFOLD ON RIG -RIH AND LOCATE 4-1/2"STUB AT 10,402', CONTINUE IN THE HOLE TO NO GO WITH UNIQUE OVERSHOT AT 10,411'MD-OBSERVE SHEAR WITH 8K -NO-GO& SET DOWN 25K;MARK PIPE. 09:30 - 10:00 0.50 TIEBAC P OTHCMP ESTABLISH CIRCULATION -ESTABLISH CIRCULATION THROUGH PORTED SUB -1 BPM,100 PSI,-2 BPM,160 PSI,-3 BPM,250 PSI,-4 BPM,390 PSI,-5 BPM,540 PSI,6 BPM, 710 PSI -9.8 PPG BRINE IN/OUT 10:00 - 11:30 1.50 TIEBAC P OTHCMP CEMENT 5 1/2",17#/FT,L-80,TCII LINER PER CADE -PJSM WITH RIG CREW,SLB CEMENTERS, BAKER,AND CH2 LEAD -REVIEWAND VERIFY PRESSURE CROSSCHECK CHECKLIST WITH CEMENTERS PRIOR TO PRESSURE TESTING LINES -PT LINES TO 300 PSI LOW 5 MIN,4500 PSI HIGH 5 MIN-CHARTED-GOOD TESTS -BATCH UP 10.0 PPG MUD PUSH AND 15.3 PPG CEMENT -CEMENT LINER PER CADE Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 13 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UW1:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 13:30 2.00 TIEBAC P OTHCMP CEMENT 5.5"SCAB LINER AS FOLLOWS: -15 BBLS OF 10 PPG MUDPUSH.AT 5 BPM -120 BBLS OF 15.3 PPG CEMENT. -PUMP 120 BBLS OF 15.3 PPG CLASS G 5.0 BPM,EXCESS VOLUME 20 BBLS (YIELD 1.31 CU.FT/SK) -DROP DART KICK OUT WITH 10 BBLS OF H2O FROM SLB -NO PIPE RECIPROCATION DISPLACE WITH RIG PUMPS: -DISPLACE WITH 9.8 PPG BRINE- -27 BBLS AT 6 BPM,SLOW TO 3 BPM FOR LATCH UP-DID NOT SEE LATCH -RESUME DISPLACEMENT AT 5 BPM, REDUCE TO 2 BPM TO BUMP THE PLUG. BUMPED THE PLUG AT 2 BPM,FCP-2425 PSI. WITH 171 BBLS PUMPED BY THE RIG(181 BBLS TOTAL DISPLACEMENT) -INCREASED PRESSURE TO 2500 PSI,SET HANGER AS DIRECTED BY BAKER REP.SET BACK DOWN TO ENSURE HANGER SET INCREASE PRESSURE TO 3900 PSI TO LINER TOP PACKER,ZXP PACKER SET AT 3430 PSI -HELD 3900 PSI FOR 5 MIN. BLEED PRESSURE AND RELEASE FROM LINER RUNNING TOOL, -PICK UP ON THE DP UNTIL PRESSURE DROPPED OFF -SLACK OFF AND ROTATE ON LINER TOP PACKER TO VERIFY -CHECK FLOATS,FLOATS HELD,CEMENT IN PLACE.AT 12:43 -ZERO LOSSES DURING CEMENT JOB 13:30 - 14:00 0.50 TIEBAC P OTHCMP CIRCULATE OUT EXCESS CEMENT FROM LINER TOP -P/U 30'AND CIRC CEMENT T/SURFACE. -12 BPM,W/1210 PSI -20 BBLS CEMENT BACK TO SURFACE -FLOW CHECK WELL 10 MIN-WELL STATIC 14:00 - 15:00 1.00 TIEBAC P OTHCMP RIG DOWN CEMENT HOSES FROM CEMENT HEAD -BLOW DOWN CEMENT LINE FREE OF FLUIDS -CLEAN&CLEAR RIG FLOOR. 15:00 - 17:00 2.00 TIEBAC P OTHCMP POOH WITH LINER RUNNING TOOL FROM 4,341'MD TO SURFACE -PJSM FOR POOH. -MONITOR TRIP ON TRIP TANK-CORRECT HOLE FILL OBSERVED L/D RUNNING TOOL AS PER BOT REP -BAKER REP INSPECTED LINER RUNNING TOOL FOR WEAR OR MISSING SEGMENTS -CLEAN AND CLEAR RIG FLOOR. Printed 1/6/2016 5:27:29PM North America-ALASKA-BP Page 14 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 18:30 1.50 BOPSUR P OTHCMP RINSE AND FUNCTION BOP RAMS -PJSM FOR RINSING THE STACK -PULL WEAR RING -FLUSH BOP STACK WITH BLACK WATER PILL -11 BPM,60 PSI,100 RPM, -FUNCTION RAMS AND REPEAT RINSE -DRAIN BOP STACK AND RINSE WELLHEAD *OA LINED UP AND OPENED UP TO BLEED TRAILER 18:30 - 00:00 5.50 BOPSUR P OTHCMP CHANGE OUT BOTH SETS OF VARIABLE BORE RAMS IN THE BOP STACK -FROM 3-1/2"X 6"TO 2-7/8"X 5" -PJSM FOR CHANGE OUT:REVIEW DDI PROCEDURE AND DISCUSS ENERGY ISOLATION-DISCUSS HIGH PRESSURE TESTING REVIEW PRESSURE CROSS CHECK LIST -SET TEST PLUG. -BARRIERS FOR BREAKING CONTAINMENT: TTP,KWF -INSTALL 2-7/8"X 5"VBR'S IN THE UPPER AND LOWER CAVITIES -PRESSURE TEST RAMS WITH 2-7/8"&4" TEST JOINTS -TEST ANNULAR WITH 2-7/8"TEST JOINT. -PRESSURE TEST BOPE TO 300 PSI LOW/ 4000 PSI HIGH FOR 5 CHARTED MIN.PASS FAIL CRITERIA FROM GP(100218) 12/22/2015 00:00 - 02:30 2.50 BOPSUR P OTHCMP PRESSURE TEST VARIABLE BORE RAMS -PJSM:CREW CHANGE-DISCUSS HIGH PRESSURE TESTING REVIEW PRESSURE CROSS CHECK LIST. -PRESSURE TEST UPPER AND LOWER WITH 2-7/8"&4"TEST JOINTS. -PRESSURE TEST BOPE TO 300 PSI LOW/ 4000 PSI HIGH FOR 5 CHARTED MIN.PASSING TEST FOR CRITERIA 1A&2B FROM GP (100218). 02:30 - 06:30 4.00 WHSUR P OTHCMP REMOVE 7-5/8"MANDREL PACK-OFF -PJSM FOR PACK OFF CHANGE OUT-FMC, BP,DDI. -DISCUSS PRECAUTIONS FOR CASING GROWTH. -FMC REP VERIFIED NO CASING GROWTH PRIOR TO PULLING PACK OFF. -INSTALL PACK OFF PULLER,RIR AND ENGAGE PACK OFF. -PULL OFF SEAT WITH 25K,PULL AND LAY DOWN. -INSTALL NEW 7-5/8"MANDREL PACK-OFF PER FMC PROCEDURE -PRESSURE TEST VOID AND SEALS TO 4000 PSI FOR 15 MIN FOR PASS FAIL CRITERIA FOR GP(100218) 3A OA OPEN TO A BLEED TRAILER PRIOR TO CHANGE OUT OF THE MANDREL PACK-OFF Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 15 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 08:00 1.50 TIEBAC P OTHCMP MIT SCAB LINER AND CASING -PJSM ON PRESSURE TESTING -TEST SCAB LINER/CASING TO 300 PSI FOR 5 MINUTES(.3 BBLS)-ZERO BLEED OFF -PRESSURE TEST SCAB LINER/CASING TO 4000 PSI FOR 30 MINUTES(3.9 BBLS)-35 PSI BLEED OFF THE FIRST 15 MINUTES,15 PSI BLEEDOFF THE SECOND 15 MINUTES-GOOD TEST -CALL AND GET WTLAPPROVAL BEFORE MOVING FORWARD -BLEED PRESSURE OFF-3.6 BBLS BLED BACK -BLOW DOWN CHOKE AND KILL LINES *SIMOPS-STAGE DRILLOUT BHA ON RIG FLOOR 08:00 - 09:30 1.50 ROPSUR P OTHCMP TEST 2-7/8"FOSV AND IBOP -PJSM -RIG UP TESTING EQUIPMENT -TEST 2-7/8"FOSV AND IBOP TO 300 PSI/4000 PSI FOR 5 MINUTES EACH FOR 2-7/8"STRING -RIG DOWN TEST EUIPMENT 09:30 - 10:00 0.50 WHSUR P OTHCMP INSTALL WEAR BUSHING PJSM -INSTALL 7"ID WEAR BUSHING IN WELLHEAD 10:00 - 10:30 0.50 CLEAN P OTHCMP RIG UP POWER TONGS -PJSM -RIG UP POWER TONGS FOR 2-7/8"PAC PIPE MAKEUP 10:30 - 12:00 1.50 CLEAN P OTHCMP RIH WITH DRILLOUT BHA -PJSM -MAKE UP DRILLOUT BHA#2 AND RUN IN HOLE -PICK UP AND SINGLE IN 2-7/8"PAC PIPE FROM THE PIPE SHED FROM 189'TO 264' *LOSSES FROM MIDNIGHT TO NOON-0 BBLS 12:00 - 12:30 0.50 CLEAN P OTHCMP RIG SERVICE 12:30 - 20:00 7.50 CLEAN P OTHCMP RIH WITH DRILLOUT BHA -PJSM -RUN IN HOLE WITH BHA#2 ON 2-7/8"PAC PIPE -SINGLE IN PAC PIPE FROM PIPE SHED FROM 264'TO 6095' -MONITOR TRIP ON TRIP TANK-PROPER DISPLACEMENT OBSERVED 20:00 - 22:00 2.00 CLEAN P OTHCMP RIH WITH BHA#2 ON 4"DRILL PIPE -PJSM -LAY DOWN 2-7/8"HANDLING EQUIPMENT -CHANGE OUT ELEVATORS TO 4" ELEVATORS -RUN IN HOLE WITH DRILLOUT BHA#2 FROM 6095'TO 10176' -MONITOR TRIP ON TRIP TANK-PROPER DISPLACEMENT OBSERVED Printed 1/6/2016 5:27:29PM • North America-ALASKA-BP Page 16 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 CLEAN P OTHCMP ESTABLISH PARAMETERS AND WASH DOWN -ESTABLISH PARAMETERS AT 10176':PUMP PRESSURE AT 3 BPM-1110 PSI,PUW 175K, SOW 125K,ROT WT 148K @ 60 RPM W/4-5K TORQUE -SHUT DOWN ROTARY AND WASH DOWN FROM 10176'TO 10215'-TAG CEMENT -PICK UP AND START ROTARY AT 60 RPM -DRILL CEMENT STRINGERS FROM 10215'TO 10302'W/2K WOB,TORQUE 4.5-6K @ 60 RPM *LOSSES FROM NOON TO MIDNIGHT-0 BBLS 12/23/2015 00:00 - 04:15 4.25 CLEAN P OTHCMP DRILL 5-1/2"SCAB LINER SHOE TRACK. -DRILL CEMENT STRINGERS FROM 10,302' TO 10,344'MD. -PARAMETERS:PUMP RATE 2-3 BPM @ 730-1200 PSI,RPM 60-75 @ 4.5-6K TORQUE, PUW 175K,SOW 125K,ROT WT 148K @ 60 RPM. -DRILL FROM 10,302'TO 10,342'WITH 2-3K WOB WITH NO PROBLEMS. -ROP SLOW AT 10,342'MD. -DRILLED ON PLUG AND LANDING COLLAR WHILE INCREASING WOB,INCREASING RPM FROM 60 TO 75,SLOW DOWN PUMP RATE FROM 3 BPM TO 2 BPM.DECREASE PUMP RATE TO 1 BPM. -DRILLED THROUGH PLUG AND LANDING COLLAR TO 10,344'MD(2.5 HRS DRILLING ON PLUG AND LANDING COLLAR). -REAM THRU LANDING COLLAR 1 TIME WITH NO PROBLEMS. -OA PRESSURE AT 0000=0 PSI. 04:15 - 07:00 2.75 CLEAN P OTHCMP CONTINUE TO DRILL CEMENT SHOE TRACT FROM 10344'TO 10,396'MD. -PARAMETERS:PUMP RATE 1 BPM @ 300 PSI,75 RPM @ 4.5-6K TORQUE,3-4K WOB. *SIMOPS-LOAD 5-1/2"TUBING IN PIPE SHED AND CLEAN THREADS. -OA PRESSURE AT 0600=320 PSI. 07:00 - 06:30 1.50 CLEAN P OTHCMP CIRCULATE HI-VIS SWEEP AROUND. -CIRCULATE 20 BBLS 60-VIS SWEEP SURFACE TO SURFACE. -RECIPROCATE PIPE WHILE CIRCULATING. -PUMP AT 4 BPM @ 2250 PSI,INCREASED RATE TO 4.5 BPM @ 2850 PSI. -SWEEP BRING-10%INCREASE IN CUTTINGS. 08:30 - 09:00 0.50 CLEAN P OTHCMP FLOWCHECK WELL FOR 10 MINUTES-WELL STATIC. -BLOW DOWN TOP DRIVE. 09:00 - 11:30 2.50 CLEAN P OTHCMP POOH WITH DRILLOUT BHA#2. -PULL OUT OF HOLE WITH DRILLOUT BHA#2 ON 4"DRILLPIPE-STANDING BACK STANDS IN DERRICK. -PULL OUT OF HOLE FROM 10,396'TO 6,095' MD. -MONITOR HOLE FILL FROM TRIP TANK-HOLE TAKING PROPER FILL. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 17 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UW1:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:00 0.50 CLEAN P OTHCMP RIG UP TO STAND BACK 2-7/8"PAC PIPE. -INSTALL 2-7/8"ELEVATORS. -RIG UP PULLBACK LINE FOR PAC PIPE. -RIG UP POWER TONGS. 12:00 - 12:30 0.50 CLEAN P OTHCMP RIG SERVICE. 12:30 - 15:30 3.00 CLEAN P OTHCMP POOH WITH DRILLOUT BHA#2. -PULL OUT OF HOLE WITH 2-7/8"PAC PIPE, STANDING BACK STANDS IN DERRICK -PULL OUT OF HOLE FROM 6,093'TO 233'MD. -MONITOR HOLE FILL FROM TRIP TANK-HOLE TAKING PROPER FILL. 15:30 - 16:30 1.00 CLEAN P OTHCMP LAY DOWN DRILLOUT BHA#2. -FLOWCHECK WELL(10 MINUTES)BEFORE BRINGING NONSHEARABLES ACROSS STACK-WELL STATIC. -PULL OUT OF HOLE AND LAY DOWN 3-1/4" DRILL COLLARS. -PULL OUT OF HOLE WITH DRILLOUT BHA. -BREAK OUT BIT. 16:30 - 17:30 1.00 CLEAN P OTHCMP MAKEUP MILLING BHA#3. -MAKE UP 3.70"JUNK MILL AND 3.70"STRING MILL. -MU 3-1/8"OIL JARS. -MAKE UP AND RUN IN HOLE WITH 3-1/4" DRILL COLLARS TO 138'MD. 17:30 - 21:00 3.50 CLEAN P OTHCMP RUN IN HOLE WITH MILLOUT BHA#3 ON 2-7/8" PAC PIPE. -PICK 6 SINGLES OF 2-7/8"PAC PIPE FROM PIPE SHED AND RUN IN HOLE. -CONTINUE TO RUN IN HOLE WITH 2-7/8"PAC PIPE FROM DERRICK FROM 138'TO 6,284' MD. -MONITOR PIPE DISPLACEMENT FROM TRIP TANK-PROPER PIPE DISPLACEMENT OBSERVED. -OA PRESSURE AT 1800 HRS=0 PSI. 21:00 - 22:00 1.00 CLEAN P OTHCMP SWAP OVER TO 4"HANDLING EQUIPMENT. -RIG DOWN POWER TONGS. -CHANGE OUT 2-7/8"ELEVATORS TO 4" ELEVATORS. -MAKE UP XO FROM 2-7/8"TO XT-39. -PICK UP AND RIH WITH 1 STAND OF 4"DRILL PIPE. •KICK WHILE TRIPPING DRILL FOLLOWED BY AAR WITH RIG CREW,WSL AND TOUR PUSHER. 22:00 - 22:30 0.50 CLEAN P OTHCMP BLOW DOWN CHOKE. -BLOW DOWN CHOKE. -LINE UP ON TRIP TANK. 22:30 - 00:00 1.50 CLEAN N RREP OTHCMP CHANGE OUT SAVERSUB ON TOP DRIVE. 12/24/2015 00:00 - 01:30 1.50 CLEAN P OTHCMP SLIP AND CUT DRILL LINE -SLIP AND CUT DRILL LINE -SERVICE TOP DRIVE,BLOCKS, DRAWWORKS Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 18 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4011 M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor DOYON DRILLING INC. UW:500292233800 Active datum:ORIG KELLY BUSHING (Q50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 04:00 2.50 CLEAN P OTHCMP RUN IN HOLE WITH MILLING BHA#3 -RUN IN HOLE WITH MILLING BHA#3 ON 4" DRILL PIPE FROM DERRICK FROM 6,379'TO 10,372'MD -MONITOR PIPE DISPLACEMENT FROM TRIP TANK-PROPER PIPE DISPLACEMENT OBSERVED 04:00 - 05:00 1.00 CLEAN P OTHCMP OBTAIN PARAMETERS,CLEAR DRILL STRING -GET SCR'S AT 10,365' -NOTICED HIGHER SCR ON#2 MUDPUMP- TROUBLESHOOT AND FOUND DRILLSTRING OBSTRUCTION -CLEARED OBSTRUCTION AND RE-OBTAIN SCR'S 05:00 - 08:00 3.00 CLEAN P OTHCMP MILL THRU CEMENT IN 5-1/2"SCAB LINER. -ESTABLISH PARAMETERS: PUW 178K,SOW 125K,ROT WT 148K @ 70 RPM,PUMP RATE 3 BPM 1700 PSI -WASH DOWN FROM 10,372'MD AT 3 BPM AND 1700 PSI:2.8 BPM @ 1760 PSI,WOB 4-6K -TAG CEMENT AT 10,395'MD -MILL THRU CEMENT TO 10,481'MD -PRELOADED 100 BBLS OF SAFE-SCAV IN WELL FOR BULLHEADING 08:00 - 08:30 0.50 CLEAN P OTHCMP DRILL CBP -TAG OBSIDIAN BRIDGE PLUG AT 10481'. -DRILL OUT OBSIDIAN BRIDGE PLUG AT 1.5 BPM RATE @ 610 PSI,70 RPM W/4K FREE TORQUE,WOB 3-4K -DRILL PLUG FROM 10481'TO 10483'-PLUG DROPPED -SPACE OUT CONNECTION AT RIG FLOOR AND CLOSE ANNULAR 08:30 - 09:30 1.00 CLEAN P OTHCMP BULLHEAD SAFE-SCAV IN WELL -LINE UP TO BULLHEAD DOWN IA AND DRILLPIPE -BULLHEAD 100 BBLS DOWN IAAND DRILLPIPE:6 BPM DOWN IA @ 1990 PSI,1 BPM DOWN DRILLPIPE AT 760 PSI -FLOWCHECK WELL-WELL ON VACUUM -OPEN ANNULAR 09:30 - 10:00 0.50 CLEAN P OTHCMP CHASE PLUG DOWN TUBING TAIL PIPE -CHASE PLUG DOWN TO 10615' -FLOWCHECK WELL FOR 10 MINUTES AND ESTABLISH LOSS RATE-15 BBL/HR LOSS RATE -BLOW DOWN TOP DRIVE AND MUD LINES 10:00 - 12:00 2.00 CLEAN P OTHCMP POOH WITH MILLING BHA#3 -PJSM -POOH FROM 10615'TO 8847' -LAY DOWN 4"DRILL PIPE TO PIPE SHED -MONITOR HOLE FILL WITH TRIP TANK-WELL ON LOSSES 20-30 BBLS/HR PLUS HOLE FILL LOSSES FROM MIDNIGHT TO NOON-51 BBLS 9.8 BRINE 12:00 - 12:30 0.50 CLEAN P OTHCMP RIG SERVICE Printed 1/6/2016 5:27:29PM s • North America-ALASKA-BP Page 19 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usf(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 15:00 2.50 CLEAN P OTHCMP POOH WITH MILLING BHA#3 -PJSM -POOH FROM 8847 TO 6284' -LAY DOWN 4"DRILL PIPE TO PIPE SHED -MONITOR HOLE FILL WITH TRIP TANK-PROPER HOLE FILL OBSERVED 15:00 - 21:00 6.00 CLEAN P OTHCMP POOH WITH MILLING BHA#3 ON 2-7/8"PAC PIPE -PJSM -CHANGE OUT PIPE ELEVATORS TO 2-7/8" -RIG UP POWER TONGS -CONTINUE TO POOH WITH MILLOUT BHA#3 FROM 6284'TO 138' -LAY DOWN 2-7/8"PAC PIPE TO PIPE SHED -MONITOR HOLE FILL WITH TRIP TANK-WELL ON LOSSES 20-30 BBLS/HR PLUS HOLE FILL NOTIFICATION SENT TO AOGCC OF INTENT TO PERFORM MIT FOR WELL PM1-14 AT 18:45 HOURS. 21:00 - 22:30 1.50 CLEAN P OTHCMP LAY DOWN MILLING BHA#3 -FLOWCHECK WELL FOR 10 MINUTES-WELL ON VACUUM-LOSS RATE 24 BBLS/HR -PJSM -LAY DOWN 3-1/4"DRILL COLLARS -POOH AND LAY DOWN MILLING BHA#3 -SIGNIFICANT WEAR NOTICED ON THE MILL -CLEAR BHA FROM RIG FLOOR 22:30 - 23:00 0.50 WHSUR P OTHCMP PULL WEAR BUSHING -PJSM -PULL WEAR BUSHING FROM WELLHEAD 23:00 - 23:30 0.50 WHSUR P OTHCMP WASH BOPE STACK -PJSM -RIG UP STACK WASHER -CIRCULATE 40 BBLS AT 6 BPM-40 PSI -LAY DOWN STACK WASHER -INSTALL TEST PLUG -FILL STACK WITH FRESH WATER Printed 1/6/2016 5:27:29PM • North America-ALASKA-BP Page 20 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING©50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 BOPSUR P OTHCMP PRESSURE TEST ALL BOPE AS PER AOGCC REGS,SUNDRY#315-565,AND GP 10-45 -PJSM,REVIEW DDI SOP AND PRESSURE CROSSCHECK WITH CONFIRMATION OF CORRECT RESPONSES -VERIFY LINE UP AND FILL STACK AND CHOKE MANIFOLD -SHELL TEST BOP,LOOK FOR LEAKS -TEST BOPE TO 300/4000 PSI FOR 5/5 CHARTED MIN -TEST ANNULAR TO 300/3500 PSI FOR 5/5 CHARTED MIN -TEST BLOWOUT PREVENTERS AND ALL ASSOCIATED BOPE -UPPER 2-7/8"X 5"VBR'S TESTED WITH 3-1/2"TEST JOINT -LOWER 2-7/8"X 5"VBR'S TESTED WITH 3-1/2 TEST JOINT -ANNULAR PREVENTER TESTED WITH 3-1/2" TEST JOINT -ALL TESTS WITNESSED BY TOOLPUSHER, BP WSL *TEST WITNESS WAIVED BY AOGCC INSPECTOR LOU GRIMALDI LOSSES FROM NOON TO MIDNIGHT-255 BBLS 9.8 BRINE *KEEP HOLE FULL THROUGH IA-WELL TAKING 20 BBLS/HR Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 21 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UW:500292233800 Active datum:ORIG KELLY BUSHING @50.O0usft(above Mean Sea Leval) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/25/2015 00:00 - 05:30 5.50 BOPSUR P OTHCMP PRESSURE TESTALLBOPEASPERAOGCC REGS,SUNDRY#315-565,AND GP 10-45 -PJSM,REVIEW DDI SOP AND PRESSURE CROSSCHECK WITH CONFIRMATION OF CORRECT RESPONSES -VERIFY LINE UP AND FILL STACK AND CHOKE MANIFOLD -TEST BOPE TO 300/4000 PSI FOR 5/5 CHARTED MIN -TEST ANNULAR TO 300/3500 PSI FOR 5/5 CHARTED MIN -TEST BLOWOUT PREVENTERS AND ALL ASSOCIATED BOPE -UPPER 2-7/8"X 5"VBR'S TESTED WITH 3-1/2"TEST JOINT -LOWER 2-7/8"X 5"VBR'S TESTED WITH 3-1/2"TEST JOINT -ANNULAR PREVENTER TESTED WITH 3-1/2" TEST JOINT -BLIND/SHEAR RAMS TESTED -TEST CHOKE MANIFOLD VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES -TEST MANUAL AND HYDRAULIC IBOP'S ON TOP DRIVE -TEST FLOOR AND DART VALVES -TEST MAN ADJ/SUPER CHOKE=1500 PSI/ 5 MIN -PERFORM DRAW DOWN TEST OF ACCUMULATOR -FUNCTION BOPE FROM REMOTE PANEL AND MAIN UNIT -ALL TESTS WITNESSED BY TOOLPUSHER, BP WSL -TEST ALARMS FOR PVT,H2S&GAS *TEST WITNESS WAIVED BY AOGCC INSPECTOR LOU GRIMALDI *KEEP HOLE FULL THROUGH IA-WELL TAKING+/-20 BBLS/HR 'SIM-OPS:LOAD PIPE FOR COMPLETIONS IN PIPE SHED 05:30 - 06:30 1.00 BOPSUR P OTHCMP RIG DOWN FROM TESTING -PJSM -PULL TEST PLUG -RIG DOWN TESTING EQUIPMENT FROM CHOKE MANIFOLD 06:30 - 08:00 1.50 BOPSUR P RUNCMP INSTALL FMC ISOLATION/TEST PLUG IN WELLHEAD -PJSM -INSTALL FMC PLUG IN WELLHEAD -SET 10K DOWN ON PLUG -FMC TECH VERIFY PLUG ON SEAT -FMC TECH RUN IN LOCK DOWN SCREWS-TORQUED TO 450 FT-LBS Printed 1/6/2016 5:27:29PM • North America-ALASKA-BP Page 22 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING©50.Oousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 09:00 1.00 BOPSUR P RUNCMP PERFORM ROLLING TEST FROM BELOW ON TEST PLUG -PERFORM ROLLING TEST FROM BELOW TO 500 PSI ON TEST PLUG-PUMPED 78.2 BBLS AWAY-NO LEAKS OBSERVED PAST PLUG -BLEED PRESSURE BACK-7 BBLS BLED BACK 09:00 - 09:30 0.50 BOPSUR P RUNCMP TEST FMC PLUG FROM ABOVE -TEST PLUG FROM ABOVE TO 300 PSI LOW/ 4000 PSI HIGH FOR 5 MINUTES EACH-GOOD TEST 09:30 - 10:00 0.50 BOPSUR P RUNCMP PREP FOR VBR CHANGEOUT -PJSM -BLOW DOWN CHOKE,CHOKE MANIFOLD, KILL LINE -DRAIN MUD GAS SEPARATOR -VOID STACK OF FLUIDS FOR VBR CHANGEOUT *KEEP HOLE FULL THROUGH IA-WELL TAKING+/-10 BBLS/HR 10:00 - 13:30 3.50 BOPSUR P RUNCMP CHANGE OUT VBR'S -PJSM -REMOVE 2-7/8"X 5"VBRS(UPPER AND LOWER PIPE RAMS)FROM BOPE STACK -INSTALL 3-1/2"X 6"VBRS(UPPER AND LOWER PIPE RAMS)IN BOPE STACK *KEEP HOLE FULL THROUGH IA-WELL TAKING+/-8 BBLS/HR *OA PRESSURE-OPSI AT NOON *LOSSES FROM MIDNIGHT TO NOON-170 BBLS 9.8 BRINE 13:30 - 14:30 1.00 BOPSUR P RUNCMP RIG UP TO TEST UPPER AND LOWER PIPE RAMS -PJSM -RIG UP TESTING EQUIPMENT TO TEST RAMS -FILL STACK WITH FLUID FOR TESTING *KEEP HOLE FULL THROUGH IA 14:30 - 16:30 2.00 BOPSUR P RUNCMP TEST UPPER AND LOWER PIPE RAMS -PJSM -TEST UPPER PIPE RAMS AND LOWER PIPE RAMS(BOTH 3-1/2"X 6")WITH 3-1/2"AND 5-1/2"TEST JOINTS -TEST TO 300 PSI LOW/4000 PSI HIGH FOR 5 MINUTES EACH -TEST WITNESSED BY BP WSL, TOOLPUSHER *KEEP HOLE FULL THROUGH IA-WELL TAKING+/-8 BBLS/HR Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 23 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011 M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING ra50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 17:30 1.00 BOPSUR P RUNCMP RIG DOWN TESTING EQUIPMENT/PULL TEST PLUG -PJSM -RIG DOWN TESTING EQUIPMENT -VOID BOPE STACK OF ALL FLUIDS -MAKE UP JOINT OF DRILL PIPE TO FMC ISOLATION/TEST PLUG -CHECK FOR PRESSURE UNDER TEST PLUG-0 PRESSURE -FMC TECH BACK OUT LOCK DOWN SCREWS -PULL TEST PLUG OUT TO RIG FLOOR 17:30 - 19:30 2.00 RUNCOM P RUNCMP RIG UP TO RUN COMPLETION -PJSM -CLEAR RIG FLOOR OF TESTING EQUIPMENT AND TEST PLUG -MOBILIZE TUBULAR HANDLING EQUIPMENT TO RIG FLOOR FOR COMPLETIONS RUN -RIG UP FLOOR TO RUN COMPLETION STRING -VERIFY PIPE COUNT IN PIPE SHED BY WSL(S),DRILLER,AND TOUR PUSHER -VERIFY JEWELRY IN ORDER IN PIPE SHED -MAKE UP SAFETY JOINT *KEEP HOLE FULL THROUGH IA-WELL TAKING 8 BBLS/HR 19:30 - 00:00 4.50 RUNCOM P RUNCMP RUN 3-1/2"X 5-1/2"COMPLETION STRING -PJSM -MAKE UP AND RUN IN 3-1/2"9.2#L-80 TCII COMPLETION STRING WITH ALL ASSOCIATED JEWELRY FROM SURFACE TO 1163" -RUN USING TORQUE-N-TURN SERVICES -MAKE UP ALL 3-1/2"CONNECTIONS TO 2300 FT-LBS -ALL CONNECTIONS BELOW THE PACKER ARE BAKER-LOCKED -JET-LUBE SEAL GUARD DOPE ON ALL CONNECTIONS THAT ARE NOT BAKER-LOCKED -MONITOR PIPE DISPLACEMENT VIA TRIPTANK-WELL ON LOSSES 3-6 BBLS/HR LOSSES *OA PRESSURE AT MIDNIGHT-0 PSI *FLUID LOSSES FROM NOON TO MIDNIGHT- 103 BBLS 9.8 BRINE 12/26/2015 00:00 - 10:00 10.00 RUNCOM P RUNCMP RUN 3-1/2"X 5-1/2"COMPLETION STRING. -PJSM. -MAKE UP AND RUN IN 3-1/2"9.2#L-80 TCII TCII COMPLETION STRING WITH ALL ASSOCIATED JEWELRY FROM 1,163'TO 6,015' MD. -MAKE UP ALL 3-1/2"CONNECTIONS TO 2300 FT-LBS. -USE JET-LUBE SEAL GUARD THREAD COMPOUND. -MONITOR PIPE DISPLACEMENT VIA TRIPTANK-WELL ON LOSSES 3-4 BBLS/HR LOSSES. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 24 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4--011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 10:30 0.50 RUNCOM P RUNCMP CHANGE OUT HANDLING EQUIPMENT FOR 5-1/2"TUBING. -PJSM. -RIG DOWN 3-1/2"ELEVATORS AND SLIPS. -RIG UP 5-1/2"ELEVATORS AND HANDLING EQUIPMENT. -CHANGE OUT DIES IN POWER TONGS TO 5-1/2". -RIG UP 5-1/2"X-OVER TO FLOOR VALVE AND 5-1/2"LIFT SUB ON SHEAR JOINT. 10:30 - 20:30 10.00 RUNCOM P RUNCMP RUN 3-1/2"X 5-1/2"COMPLETION STRING. -PJSM. -MAKE UP AND RUN IN 5-1/2"17#L-80 TCII COMPLETION STRING WITH ALL ASSOCIATED JEWELRY FROM 6,015'TO 9,720'MD. -MAKE UP ALL 5-1/2"CONNECTIONS TO OPTIMAL TORQUE OF 5500 FT-LBS. -USE JET-LUBE SEAL GUARD THREAD COMPOUND. -MONITOR PIPE DISPLACEMENT VIA TRIPTANK-WELL ON LOSSES 3-4 BBLS/HR LOSSES. *FLUID LOSSES FROM MIDNIGHT TO NOON=82 BBLS. *OA PRESSURE AT NOON=0 PSI. 20:30 - 22:00 1.50 RUNCOM P RUNCMP BREAK CIRCULATION. -PJSM. -RIG UP WITH HEAD PIN AND HOSE TO BREAK CIRCULATION. -BREAK CIRCULATION AT 1.0 BPM @ 200 PSI. -CIRCULATE 15 BBLS AT 1.5 BPM @ 250 PSI. -RIG DOWN CIRCULATION EQUIPMENT. 22:00 - 00:00 2.00 RUNCOM P RUNCMP RUN 3-1/2"X 5-1/2"COMPLETION STRING. -MAKE UP AND RUN IN 5-1/2"17#L-80 TCII COMPLETION STRING WITH ALL ASSOCIATED JEWELRY FROM 9,720'TO 10,220'MD. -MAKE UP ALL 5-1/2"CONNECTIONS TO OPTIMAL TORQUE OF 5500 FT-LBS. -USE JET-LUBE SEAL GUARD THREAD COMPOUND. -MONITOR PIPE DISPLACEMENT VIA TRIPTANK-WELL ON LOSSES 3-4 BBLS/HR LOSSES. *FLUID LOSSES FROM NOON TO MIDNIGHT=69 BBLS. *OA PRESSURE AT MIDNIGHT=0 PSI. 12/27/2015 00:00 - 01:00 1.00 RUNCOM P RUNCMP RUN 3-1/2"X 5-1/2"COMPLETION STRING. -MAKE UP AND RUN IN 5-1/2"17#L-80 TCII COMPLETION STRING WITH ALL ASSOCIATED JEWELRY FROM 10,220'TO 10,326'MD. -MAKE UP ALL 5-1/2"CONNECTIONS TO OPTIMAL TORQUE OF 5500 FT-LBS. -USE JET-LUBE SEAL GUARD THREAD COMPOUND. -MONITOR PIPE DISPLACEMENT VIA TRIPTANK-WELL ON LOSSES 3-4 BBLS/HR LOSSES. -WSL(S)VERIFY PIPE IN PIPE SHED OF LEFTOVER PIPE-GOOD COUNT. Printed 1/6/2016 5:27:29PM • I North America-ALASKA-BP Page 25 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/Time:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 02:00 1.00 RUNCOM P RUNCMP LAND COMPLETIONS STRING IN HANGER. -PJSM. -CHANGE OUT PIPE HANDLING EQUIPMENT FOR 4-1/2"TUBING. -MAKE UP 4-1/2"TC-II X 5-1/2"TC-II X-OVER JOINT. -MAKE UP HANGER TO LANDING JOINT. -MAKE UP HANGER TO 4-1/2"JOINT IN COMPLETION STRING. -MAKE UP 4-1/2 JOINT TO OPTIMAL TORQUE OF 3860 FT-LBS. -OBTAIN PARAMETERS ON LAST JOINT:PUW 162K,SOW 125K. -VOID STACK OF FLUIDS. -RUN IN HOLE WITH HANGER AND LAND. -FMC VERIFY HANGER IN PLACE AND RUN IN LOCK DOWN SCREWS AND TORQUE TO 450 FT-LBS.TORQUE GLAND NUTS TO 450 FT-LBS. 02:00 - 04:30 2.50 RUNCOM P RUNCMP CIRCULATE CORROSION INHIBITED BRINE DOWNHOLE. -PJSM. -RIG UP TO CIRCULATE DOWN IA. -BREAK CIRCULATION DOWN TUBING TAKING RETURNS THRU IA -PUMP 20 BBLS AT 2 BBL/MIN AND 330 PSI. -LINE UP TO CIRCULATE CORROSION INHIBITED BRINE DOWN IA TAKING RETURNS UP TUBING. -PUMP 150 BBLS OF CORROSION INHIBITED BRINE FOLLOWED BY 20 BBLS BRINE AT 2 BBLS/MIN @ 575 PSI. -LINE UP TO CIRCULATE DOWN TUBING TAKING RETURNS THRU IA. -PU 10 BBLS BRINE AT 2 BBL/MIN AND 330 PSI TO ENSURE RHC-M PROFILE CLEAR. Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 26 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011 M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UVN:500292233800 Active datum:ORIG KELLY BUSHING(g50.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 09:30 5.00 RUNCOM P RUNCMP MIT 3-1/2"X 5-1/2"COMPLETION/SET PRODUCTION PACKER. -DROP BALL AND ROD AND ALLOW TO FALL 15 MIN. -SET PRODUCTION PACKER AND TEST TUBING TO 300/4000 PSI FOR 5/30 MIN. -SEE PACKER SHEAR AT 2400 PSI. -GOOD PRESSURE TEST: -INITIAL=4190 PSI. -15 MIN=4130 PSI. -30 MIN=4110 PSI. -PUMP 2.0 BBLS TO 4190 PSI/BLED BACK 0.8 BBLS TO 2500 PSI. MIT-IAAND PRODUTION PACKER. -BLEED OFF TUBING PRESSURE TO 2500 PSI. -MIT-IA TO 300/4000 PSI FOR 5/30 MIN. -GOOD PRESSURE TEST: -INITIAL=4200 PSI. -15 MIN=4170 PSI. -30 MIN=4140 PSI. -45 MIN=4125 PSI. PUMP 3.0 BBLS TO 4200 PSI. *WSL NOTIFY WTLAND RECIEVE APPROVAL TO PROCEED. *TEST WITNESS WAIVED BY AOGCC INSPECTOR LOU GRIMALDI. SHEAR DCK VALVE -BLEED DOWN TUBING-DCK VALVE SHEARED AT 2200 PSI DIFFERENTIAL. -PUMP 5 BBLS BOTH WAYS(IA TO TUBING AND TUBING TO IA)-ALL CLEAR. 09:30 - 10:30 1.00 WHSUR P RUNCMP RIG UP TO FREEZE PROTECT WELL -PJSM -RIG UP LITTLE RED SERVICES TO FREEZE PROTECT WELL 10:30 - 12:00 1.50 WHSUR P RUNCMP FREEZE PROTECT WELL -PJSM -PRESSURE TEST LITTLE RED SERVICES LINE TO RIG TO 5000 PSI FOR 5 MINUTES-GOOD TEST -LITTLE RED SERVICES PUMP 90 BBLS OF 80 DEGREE DIESEL DOWN IA FOR FREEZE PROTECTION -PUMP AT 2 BPM.ICP=1290 PSI.FCP=1064 PSI. 12:00 - 13:00 1.00 WHSUR P RUNCMP LET FREEZE PROTECT U-TUBE BETWEEN IA AND TUBING 13:00 - 14:00 1.00 WHSUR P RUNCMP RIG DOWN CIRCULATING EQUIPMENT -PJSM -RIG DOWN CIRCULATING EQUIPMENT ON RIG FLOOR -PULL LANDING JOINT AND LAY DOWN TO PIPE SHED 14:00 - 14:30 0.50 WHSUR P RUNCMP INSTALL TWO WAY CHECK -PJSM -FMC DRY ROD TWO WAY CHECK INTO WELL -RIG UP TO TEST TWO WAY CHECK Printed 1/6/2016 5:27:29PM • • North America-ALASKA-BP Page 27 of 27 Operation Summary Report Common Well Name:P1-14 AFE No Event Type:WORKOVER(WO) Start Date:12/14/2015 End Date:12/27/2015 X4-011M8-E:(4,105,000.00) Project:Point McIntyre Site:Pt Mac 1 Rig Name/No.:DOYON 14 Spud Date/me:2/19/1993 12:00:00AM Rig Release:12/27/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292233800 Active datum:ORIG KELLY BUSHING @50.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:30 1.00 WHSUR P RUNCMP TEST TWC FROM ABOVE -PJSM -RIG TEST TWC FROM ABOVE TO 300 PSI/ 4000 PSI FOR 5 MINUTES EACH-GOOD TEST 15:30 - 16:30 1.00 WHSUR P RUNCMP TEST TWC FROM BELOW -PJSM -LITTLE RED TEST TWO WAY CHECK FROM BELOW TO 300 PSI/4000 PSI FOR 5 MINUTES EACH-GOOD TEST . -4 BBLS TO PRESSURE UP-4 BBLS BLED BACK -RIG DOWN LITTLE RED SERVICES 16:30 - 18:30 2.00 BOPSUR P RUNCMP PREP TO NIPPLE DOWN BOPE STACK -PJSM -RID DOWN EQUIPMENT IN CELLAR -BLOW DOWN ALL LINES -VACUUM OUT STACK -CLEAN OUT DRIP PAN -REMOVE BOTH MOUSEHOLES 18:30 - 21:00 2.50 BOPSUR P RUNCMP NIPPLE DOWN BOPE -PJSM -REMOVE KOOMEY LINES,CHOKE LINES, KILL LINES AND TURNBUCKLES -NIPPLE DOWN BOPE 21:00 - 21:30 0.50 WHSUR P RUNCMP CLEAN WELLHEAD AND HANGER -PJSM -CLEAN WELLHEAD AND HANGER -INSTALL HANGER NECK SEAL 21:30 - 23:00 1.50 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE -PJSM 23:00 - 00:00 1.00 WHSUR P RUNCMP TEST ADAPTER FLANGE AND TREE -PJSM -FMC TEST ADAPTER FLANGE TO 300 PSI-5 MINUTES/5000 PSI-30 MINUTES-GOOD TEST -FILL TREE WITH DIESEL AND 2 BOTTLES OF HEET -PERFORM VISUAL LEAK TIGHT TEST TREE TO 5000 PSI FOR 5 MINUTES-GOOD TEST -SECURE TREE AND CELLAR -PRESSURES ON WELL:TGB/IA/OA=0/0/ 0 PSI **RELEASE RIG AT 23:59 HRS 12/27/2015 Printed 1/6/2016 5:27:29PM • • 0 \ \ g ) \ \ § ) TO o e } \ 0 \ \ j 0 j 0 0 0 o.a # .. \o ) 2 \ \ 2 ct \ 0 \ / ® ) 0 / { 0 / } el 0 k\ §< co o O e = cn - k / ) }~ro » f =) c.O iii 2 E st- - 0 § 0 ) / R. ) / .. E f § l ƒ $ k $ 2 \ $ >- / a ) U) tX --7-- c a } 3 - « 0 G % .0 ( Lo $ _ CD ) CO , , k I E i * > ) } - ( ( Q - \ 0 I J ) ; Lo 2 = « # ® 2 a- 5 / 1) \ \ ) / o \ j 7 § on : as - ) - ` 2 N .- 4 2 / § j c ( 0. § < w - ° ` 24- o) ` U \ } ) » \ \ 0 - \ \ 75—0 \ O 2 ) / j 2 oo ) a - a ¥ / - - ƒ a E \ \ co 0 \ 0 \ co U it < § E k a / e / ) a -4-3.— » \ < e ) § ) \ 0 0 \ } \ \ & Z ( / <OD ) < 3 = 0 0 0 H LO U) P 5 Lu� X # - ƒ ° = - § \ > e < % c § o 0 0 \ _ W < o § 5 2 I / 2 / / # e ( § G m A o w « a I E Z CO CN E C } E § ƒ ® \ - g \ 0 § ..CL \ f ) CO gl ( . 0 ) (114H _ ® 2 § EIi ° - ( ( o ( v $ } S GCL j o o £ 3 6 6@ 3 0 0 NI ) ` ` \ ( ) � � co j / / / & CO 4 ) / ~ 42y o \ / - ) @a zz ec \ ~ � \ z0 2i § 3to t ki \ E _ i ` _/ / LL T E / z / } \ \ IrjCCm < x Sim ƒ - ' E F ee E - z z ) » ƒk z § I - i jBk } / £ < R / / - `i" - 0 ° § F » .al \ O. ) } \ \ 0- 1412) 5 ■ , { = m oee � \ 7 § ■ # . 3 ; - 2 a ) _ : . 0 E - ~ = 2 ( f q z e E = - \ a z a z } 0 E Et' 2 o E z a 12, - \ 41)co - \ E \ \ \ \ Q m 0 = e — _ o Z ( _ — \ \ 0 C . � § # \ J § y {ws ) ii C i © \ \ z - / E -. 2 ° A - z \ .. 2 � $ /= w P. < / ay 03 CL tM / ¥ ` 0 — { _ /t / ° ( co m ci co .0 y — \ ! j ° = 2 / & i / co el£ aEwz z Lu 2 \ /\ - — _o ) > � � \ z � z zf o E o C ; _ / z / / to e LI - ©1> / 2 * E /I) § § PA 0 a J Q \ f ;\ \ 2 ) a. / } k \'[ 9 ) . / y ( / �, e = % - E \ 73 / & } o ) ( -0 ' § a kC c E -I = 2 e c E ( 0 z G = « ° CO ) ) 0 CO / 3 M 3 » I TREE= 6-3/8"aW • P 1 -1 4 NOTE—H2S READINGS AVERAGE 125 ppm VIAEL1J-EAD= 1!111111tN MI—WELL REQUIRES A SSSV WHEN ON ACTUATOR EtAKB2C MI" FMC TBG HGR IS 11"X 5-1/2"5"-Fr STYLE OKB.ELEV= 50', ELEV i= BPV 20"CONDUCTOR — 11T r KOP= 12E8' I 222G8 1/2" X NP, =3.813" Max Angle= 48°@ 6106' 94#'Nil-6°LE' Cohan IA)= 11288 =19.124" GAS LFT MANDRELS ( turn TVD ST MD IVO DEV TYPE VLV LATCH PORT DATE = 8800'SS 1 4018 3627 44 KGB-2 DCX BEK - 12/27/15 10-3/4"CSG,45.5#,NT-80,D=9.953" H 3914' 4282 —5-1/2"X 3-1/2"XO, =2.992' 5-1/2'TBG, 17#,L-80 TCM..0232 bpf, =4.89 — 4282' 4376" —7-5/8"X 5-1/2"BKR ZXP LIP w/BKR FLEX LOCK HGR,13=4780" Minimum ID =2.750" @ 10289' 3-1/2" HES XN NIPPLE 10155' —13-1/2" X NIP, =2,813" 10186" —5-1/2"X 3-1/2" TNT P(R,I)=2.830" 10222' —3-1/2"FES X MP, =2.813" • 10289' —3-1/2"I-ES XN =2.750" 3-1/2"TBG,9.2#,L-80 ICI .0087 bpf,ID=2.992" — 1033T 10332' —3-1/2"VVLEG, =2.855" 5-1/2"SCAB LNIR, 17#,L-80 TCI,10=4.892" --I 10399' 10399' —15-1/2-X 4-1/2"XO. =4.892" 10416' —7-5/8'X 4-1/2"UNIQUE OVERSHOT 4-VT TBG STUB(12/19/15) H 10407' Sr— 10414' —7-5/8"X 4-1/2'BKR S-3 PKR, =3.875' (10418'ELMO JEWLRY LOG 11(13/06) 10447' —4-1/2"I f_.3 X NI', =3.813" 4-1/2-TBG, 12.6#,L-80, .0152 bpf,ID=3.958" — 10610' I 10519' H(71-05148.52)('EL4-1M/2.0 JuNiQuEEHL RYOLVO GER SHOT1111106) 4-1/2TUBING STUB(TAGGES 08/04/05) 10615' 4-1/2"TBG, 12.6#,L-80, .0152 bpf,ID=3.958" — 10554' 10554' —7-5/8"X 4-1/2"BKR SABL-3 PKR =4.00" PERFORATION SUP4.4ARY (10544'ELMO JEWLRY LOG 11/13/06) REF LOG:DLLJM_L ON 03/6/93 10559" H4-1/2"BKR FKR BTM(NO TT-LOGGED 11/13/07) ANGLE AT TOP FERF:45°@1112(7 Note:Refer to Roduction DB for historical perf data ? FISH:4-1/2"MCX FLAPPER(02/26/10) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 11120-11150 0 03/31/07 3-3/8" 4 11162- 11172 0 05/15/93 2-7/8" 6 11180-11200 0 03/31/07 11370' ELM —I TA G TOP OF TBO TA I_(08i23/06) 3-3/8" 4 11210- 11296 0 05/15/93 11366' H4-1/2"PARKER SWS NP,ID=3.813"(11/13/06) 3-3/8" 4 11313-11343 0 05/15/93 3-3/8" 4 11359- 11574 0 05/15/93 11416' H4-1/2"OTIS XN NIP,13=3.725"(11/13/06) 0 11436' —4-1/2'TT,WLEG,ID=4.00"(11/13/06) [0(11/13/06) —1 if. ' PBTD 11680' 004 41004 0040444404 10040404401 40044400044 4.11.10.11.0,414.41.11.4.1 7-5/8"CSG,29.7#,NT95,ID=6875" — 11761' DATE REV BY COIMENTS DATE REV BY COWENTS PONT 143NTY RE UNIT 05115193 POOL 07 IMTIAL COMPLETION WELL: P1-14 08/05105 GJBITLH MO PERMT Nb:'1930160 12/27/15 0-14 IMO AR No: 50-029-22338-00 01/04/15 AID CRLG HO CORRECTIONS Sec.16,T12N,R14E, 1413'FSL 8 823'FEL 01/04/15 SMJM) FINAL ODE APPROVAL 01/05/15 SM/JM) !MDR EDITS BP Exploration(Alaska) ®F Tit \� Iyj��s� THE STATE Alaska Oil and Gas �, of T sKA Conservation Commission i#r*=_ 333 West Seventh Avenue '4140P.*-* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS" Fax: 907.276.7542 SCANNED DEC 1 12015 www.aogcc.alaska.gov Dave Bjork Engineering Team Lead n r�- o BP Exploration(Alaska), Inc. 1 7 J P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P1-14 Sundry Number: 315-565 Dear Mr. Bjork: 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. oerster Chair DATED this /v day of September, 2015 End . pM$ STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPROV LS 20 AAC 25.280 1. Type of Request: Abandon D Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 • Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing Q ' Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well p Re-enter Susp Well 0 Other Scab Liner 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 193-016 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service Q , 6' API Number: 50-029-22338-00-00 • 7. If perforating: 8. Well Name and Numb What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No � PBU P1-14 Will planned perforations require a spacing exception? ECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: SEP 1 4 2015 ADL 028298&034622 ' PRUDHOE BAY,PT MCINTYRE OIL - £BvS ?be(,f 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11768 ' 9189 10476 8272 10476' Unknown(1), 11370' Casing Length Size MD ND Burst t.ollapse Structural Conductor 75 20" 42-117 42-117 2300 520 Surface 3873 10-3/4" 41-3914 41-3552 5210 2480 Intermediate Production 11724 7-5/8" 37-11761 37-9184 8180 5120 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11120-11574 8731-9052 5-1/2",17#x4-112",12.6# L-80 10559 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(ft): 10427/8237 4-1/2"Baker SABL-3 Packer 10554/8328 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: • BOP Sketch p Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: October 25,2015 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 2 ' Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Laplante,Jamin Email Jamin.Laplante©bp.com Printed Name Dave Bjork Title Engineering Team Lead Signature �,. � %s em.'// Phone 907 564 5683 Date oa9�yrl COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315- 546 Plug Integrity 0 BOP Test le. Mechanical Integrity Test V Location Clearance 0 - Other: 6 6110 - - - ,L, 3 5�UV p 5,`,./ (/ )9 s P 15 3/2 O p5 Y /-Y1,+-1,VIetY p1--✓Cn 1-'CY fir's 7k fo 25-00p5y� l'C v e-re ci ,4/L I T/A- G ff r v S 71-41?-1'1'j/cc" r� p C C �e,71-, Spacing Exception Required? Yes 0 No IV Subsequent Form Required: Iv .4 Q APPROVED BYTHE 9).... Approved by: COMMISSIONER COMMISSION Date: !_ /gam/S 1‘'` .1--Y-' RBDMS �7-1) 4 2015 ORIGINAL �� Submit Form and d Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate b 7/y rs 3 • e Ni 44 Sundry Request for Casing Repair Well: P1-14 Date: 9/9/2015 Engineer: Jamin Laplar MASP: 3120 psi ' Well Type: Injector Estimated Start date: Oct 25, 2015 History: P1-14 was completed in May 1993 with four perforated intervals. The well produced from Oct 1993 to July 1994, when it was converted to injection. WAG injection was introduced in March 2003. A tubing swap was performed from 4.5" to 5.5" in Aug 2005. It was discovered that inadvertently during drilling out a FasDrill in the tailpipe during the tubing swap in 2005, the tubing tail pipe came apart/ unscrewed, fell downhole and is lodged at 11,370'-11,436' MD. An attempt to dislodge the tailpipe was made but it failed. Additional perforations above the tubing tailpipe were shot in Mar 2007. In Feb 2014 a MIT-IA failed with a leak rate of 1.2 BPM @ 2530 psi. A LDL run found a PC leak at 6,950' MD. A RWO is required to fix the PC leak before it can be returned to operable injector status. Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to operable status. Pre Rig Prep Work: W 1 Check all LDS for movement; PPPOT-T to 5,000 psi and PPPOT-IC to 3,500 psi. S 2 Pull Px plug, SBHPS, set composite plug at -10,478' MD (this should be in the middle of the joint below the X-nipple, see attached talley from Aug 5, 2005) F 3 MIT-T to 4000 psi, MIT-IA to 3000 psi, establish leak rate. MIT-OA to 1200 psi E 4 Power jet cut the 4-1/2" tubing at - 10,396' MD (18' above the packer at 10,414' MD and 2' below the collar of the second Pup Jt at 10,394' MD.) F 5 Circulate well with 9.8 ppg brine. (Total volume of brine should be -621 bbls which is 1.5x of wellbore volume) and Diesel F/P to 500'. ✓ 6 Set a BPV. ND the tree, NU the dry hole tree, PB IA and upper OA valves O 7 Remove the well house &flow line. Level the pad as needed for the rig. Proposed RWO Procedure: • MIRU Doyon 14. Pull BPV. Circulate KWF. Set TWC. • ND tree. NU and test BOPE with four preventers configured top down (annular, 3-1/2" x 6"VBR's, blind shears, mud cross and 3-1/2" x 6"VBR's). Test the blind and VBR's to 4000 psi and the annular to 3500 psi. Pull TWC. • Pull 5-'h" L-80 tubing from jet cut-10,396' MD. • RIH with dress off assembly, scrape casing and dress off tubing stub • Perform a RTTS packer run. Set RTTS at-4500' MD and pressure test the backside to 4000 psi (this will pressure test the casing from 4500' to surface to ensure that casing is good) • Run a 5-1/2" 17# L-80 Scab liner from PBTD to 4400' MD. • Cement the scab liner with 110 bbls (99 bbls + 0.7 bbl shoe track+ 10 bbls excess) of 15.8 ppg latex class G cement • Replace IC packoff and test, if casing growth is not present • Pressure test scab liner to 4000 psi • Drill out shoe tract and composite plug • Run new 3-1/2" x 5-1/2" 12.6# L-80 completion with 5-1/2" x 3-'/2" HES "TNT" packer. MIT-T& MIT-IA to 4000 psi. • Set a TWC and RDMO. Post rig Work ✓ 1 1 Pull TWC S 2 I Pull ball and Rod, Pull RHC seat its=t= 6-3/8'OW • P1 1 4. Sief NOTE—I12S READINGS AVERAGE 125 ppm ViEL.1.1-EAD. FlAC - WHEN ON MI—WELL REQUIRES A SSSV WHEN ON ACTUATOR. BAKER C MI''''' FMC TBG HGR IS 11 X 5-1/r 5-"Ir STYLE OKB.E3_EV= 5cr 1 BF.ELB/= ....---------- L . LI BPVG KOP= 1289' " M20CONDUCTOR, 117' Max Angle= 48',t,6106' 2134' H 5-lir HES X NIP,D=4562' Datum NO= 11288' 944,NT6OLE, Datura ND= 8800'SS 13=19.124" 10-3/4"CSG,45.58,NT-80,D=9.953' H 3914' I—A Minimum ID = 3.813" @ 10452' ELMD - 6960' —7-5/8"PROOUCT)ON CSG LEAK(84/26/13) a 4-1/2" OTIS X NIPPLE a a I I 10344' —5-1/2'HES X NP,D=4,562" (10349'ELM 0 JEWLRY LOG 11/13/003) 5-1/2"TBG, 174,L-80,.0232 bpf,ID=4.892" — 10394' / 10394' —15-1/2"X 4-1/2"XO.0-3,958- Z 10414' —7-5/8'X 4-1/2"BKR S-3 PKR.CI=3,875" (10418'ELMO JEWLRY LOG 11/13/08) I I 1044T —4-1/2"HF_S X NP,ID=3.813" (10452'ELMO JBVLRY LOG 11113/06) 4-1/2"TBG, 12.64,L-80, .0152 bpf,El=3.958' —I 10510J10510J .„ 10476' —4-1/2'OBSCIAN CEP((}8/23/15) - 'UNIQUE 4-1/2'TUBNG STUB(TA GGES 08/04/05) —{ 10515' ."-----'.-C 1 10519' H7-5/8X 4-1/2OVERSHOT 4-1/2'TBG, 12..6#,L-80..0152 bpf,0=3.958" —f 10554' 10554' —7-5/8"X 4-1/2"BKR SA BL-3 PKR,D=4.00' (10644'EL-MO JEWLRY LOG 11/13/06) 10559' H4-1/2'BKR PKR BTM(NO TT-LOGGED 11/13/07) PEFFORA TON SLFAMARY REF LOG:DL/ML ON 03/6/93 ilk ? —F&-t 4-1/2"MCX FLAPPER(02/26/10) ANGLE AT TOP PERF:45°@ 11120' Nple:Refer to Roduction DB for historical perf data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 2-7/8' 6 11120- 11150 0 03/31/07 3-3/8" 4 11162- 11172 0 05/15/93 2-7/8' 6 11180-11200 0 03/31/07 3-3/8" 4 11210- 11296 0 05/15/93 3-3/8" 4 11313- 11343 0 05/15/93 3-3/8" 4 11359- 11574 0 05/15/93 '71370' ELM H TAG TOP OF TBG TA L(08/23/06) 117 11399' —4-1/2"PARKER SVVS NP,ID=3,813"(11/13/06) 11416" H4-112'011S XN NIP,0=3725"(11/13/06) — 11436" —I4-1/2"TT,VVLEG,0=4.00"(11/13/06) .........— TD(11/13/06) —{ 11644' PBTD —I 11680' •••••••••• •• • •• •• bi.•4•4*• • •*** 7-5/8'CSG,29.74,NT95,0=6.875' H 11761' .....11.11A1.11.114•81 DATE REV BY COMENTS DATE REV BY COMMENTS PONT MCNTY RE UNIT 05/15/93 POOL 07 INITIAL COMPLETION 03/24/15 PJC ADD CONDUCTOR NFORMATION WELL: P1-14 08/05/05 G.JEITTLH RINO 09/04/15 JGUJ10 RLL PX R_UG1SET(BP(08/23/15) PEW Pb:1930160 10/23113 RW/JM) PROD CSG LEAK(04/26/13) 09/11/15 TRUK) UPDATH)CSG 8.FR DEPTHS AR P43: 50-029-22338-00 11/09/13 PJC REMOVE IN-OPS STATUS Sec.16,T12N,R14E 1413'FSL&823'Fa 03/19/15 WO PJC/FU_L FX PLUG 03/21/15 WC/PJC SET PX PLUG/ BP Exploration(Alaska) TREE= 6-3/8"CMv 0 P1 -1 4 SA NOTE""I12S READINGS AVERAGE 125 ppm FMC WHEN ON MI"""WELL REQUIRES A SSSV WHEN ON ACTUATOR= BAKER C Proposed RWO MI FMC TBG IiGR IS 11"X 5-1/2"5""H"STYLE INFf1AL KB.13B/ 50' I I BPVG BF.ELEV= KOP= 1289' Max Angle= 48°@ 6106' Datum MD= 11288' Datum ND= 8800'SS ' I 2,200' H5-1/2"HES X NIP, ID=4.562" 10-3/4"CSG,45.5#,NT-80,D=9.953" H 3914' \ / 4 250' -15-1/2"x 3-1/2"crossover 5-1/2"17#L-80 TC-II and 3-1/2"9.2#L-80 TC-I injection tubing c -4,400' top of 5-1/2"scab liner I Li I I 10,018' -13-1/2" HES 'X'ID=2.813" CO r4 10,050' -15-1/2"x 3-1/2" HES TNTD=2.88" I I 10,069' -13-1/2' FES'X'ID= 2.813" Scab Liner 5-1/2"17#L-80 4,414'-10,394' ' I 10,124' -3-1/2" HES'XII ID=2.75 / 10,141' -I 3-112"WLEG Z 21 — 10414' 7-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 1(10418'ELMDJEWLRY LOG 11/13/06) I I 1044T 4-1/2"FES X NP,D=3.813" (10452'ELMD JEWLRY LOG 11/13/06) 4-1/2"TBG,12.6#,L-80, .0152 bpf, D=3.958" H 10510' 4-1/2"TUBNG STUB(TAGGES 08/04/05) H 10515' I 10519' H7-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" -i 10554' g 10554' 7-5/8"X 4-1/2"BKR SABL-3 PKR,D=4.00" (10544'ELMD JEWLRY LOG 11/13/06) PERFORATION SUMMARY 10548' -{4-1/2"BKR PKR BTM(NO TT-LOGGED 11/13/07) REF LOG:DLUMLL ON 03/6/93 ANGLE AT TOP PERE:45°@ 11120' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ? -FISH:4-1/2"MCX FLAPPER(02/26/10) 2-7/8" 6 11120-11150 0 03/31/07 3-3/8" 4 11162-11172 0 05/15/93 370' ELM -I TAG TOP OF TBG TA L(08/23/06) 2-7/8" 6 11180-11200 0 03/31/07iff/ 11399' H4-1/2"PARKER SWS NP,ID=3.813"(11/13/06) 3-3/8" 4 11210-11296 0 05/15/93 3-3/8" 4 11313-11343 0 05/15/93 11416' -14-1/2"OTIS XN NIP,D=3.725"(11/13/06) 3-3/8" 4 11359-11574 0 05/15/93 -. 11436' H4-1/2"TT,WLEG,D=4.00"(11/13/06) TD(11/13/06) H 11646' - PBTD H 11680' 444444141V 14.6.4.4!.6.6.6.4.6.1 7-5/8"CSG,29.7#,NT95,D=6.875" -1 11760' DATE REV BY COMIuENTS DATE REV BY COMMS NTS POINT MCNTY RE UNIT 05/15/93 POOL 07 INTIAL COMPLETION 04/23/13 TBD/JMD SET PX PLUG(04111/13) WELL: P1-14 08/05/05 GJB/TLH RWO 10/23/13 RW/JMD PROD CSG LEAK(04/26/13) PERMIT No:'1930160 11/13/06 DMS/PJC TBG TAIL DRIFTED w/MLL 11/09/13 PJC RBvIOVER IN-OFS STATUS AR No: 50-029-22338-00 12/14/10 RW/PJC TT ELM)LOGGED 11/13/06 Sec.16,T12N,R14E,1413'FSL&823'Fa 02/18/11 M1B/JMD ADDED SSSV SAFETY NOTE 01/18/12 TM IVJMD ADDED H2S SAFETY NOTES BP Exploration(Alaska) ` . ca -' (D L O u) 13 0 = i > 1 N _ > Oa 0U 2_ > v) > HU) 2 = o " U o w co >+ a � — r co0 iii f-N 2 E 1 E r:. 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They are available in the original file and viewable by direct inspection. / ~ f 0/~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. l [] Other, No/Type. OVERSIZED .~. Logs 'of various kinds . [] Other Scanned by: Dianna Vincent Nathan Lowell -- ., Date¢//~. CJ TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Isl BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, bP 1a~-o-~ ~,- ~++ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~~~ ~~' ~~ Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-O6 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-OSA 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 Schlumberger NO. 4304 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine MahnkE!n 333 West 7th Ave, SuitE! 100 Anchorage, AK 99501 Company: UIC- Ie¡ 3 - Ó'~NED JUN 2 0 2007 Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD P1-16 11637331 WARMBACKS & SBHPS 05/04/07 1 P1-14 11637332 WARMBACKS & SBHPS 05/05/07 1 01-05 11626486 USIT (CEMENT) 05/13/07 1 01-05 11626486 USIT (CORROSION) 05/13/07 1 MPH-14 11638633 INCLINOMETER-DIRECTION LOG 05/13/07 1 MPS-01A 1159454 MDT 05/28/07 1 11-18 11626097 USIT 05/26/07 1 09-15A 11629015 SCMT 06/01/07 1 12-12A 11695061 CEMENT IMAGE & BOND LOG 05/28/07 1 03-36A 11629014 SCMT 05/31/07 1 S-401 11626492 SCMT 06/11/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered ~ILIN 2 0 Z007 Received by: B\ Commì§$\ors 06/15/07 . . ,// / e 0 og escnptlon ae o or L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29/07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-0BA 11686747 LDL 05/20/07 1 G-05 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05/08/07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY 03/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE 05/22/07 1 04-10 11594498 LDL 05/19/07 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A NIA LDL 05/09/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30107 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 Z007 Comm!$$iŒ[¡ WII J b# L 0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 SCANNED JUN 2 1 2007 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: U I~ 1~,3 -Of ç..., . . p 06/07107 NO. 4290 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay o t BL CI CD . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: ~ -- . . WELL LOG TRANSMITTAL RECE\VED ProActive Diagnostic Services, Inc. AUG 2 9 2006 Alaska Oil & Gas Cons. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection[Caliper / MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) EDE Disk P1 - 14 2) 3) 4) 5) 6) 7) 23-Aug-06 Jewelry Log ~{;ANNED AUG 30 200B Print Name: C2L Cf/l,-r'0fh,(p- rn~iL(~.p.Lt Date: cz, / ~/ {)(/) Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM C:IDoclUnents and SettingsIPDS Anchorage - MPLIDesktoplTransmiU)riginal.doc UTe... 'Q"3 -01 to -F J'{0-::¡'-ò ) MEMORANDUM State of Alaska \~?y;' 0 \(, Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor J J)ët¡1 q/ljt> ~ DATE: Tuesday, August 30,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PI-14 PRUDHOE BAY UN PTM PI-14 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \:JBæ:.... Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN PTM PI-14 API Well Number 50-029-22338-00-00 Insp Num: mitJCr050825075115 Permit Number: 193-016-0 Rei Insp Num Inspector Name: John Crisp Inspection Date: 8/19/2005 IA lOA I ---·1····- .__.!ubing I 560 Initial 15 Min. 30 Min. 45 Min. 60 Min. 3010 2970 3000 560 560 580 2270 2270 2270 Packer Depth w~ilT PI-14 ¡Type Inj. ! W -, TVD !. 8228 ~:!. ¡ 1930160 -iT~P~!~~t l:PT IT~~t p_~i.j 2057 Intery.ªJ INlTAL P/F P Pretest I ------,. -~...--~- 320 2270 Notes Initial test post workover. ('- q'.',!. 'i~nK\J!i~~) (~r: \P ~;~, 1 2.0 U ~ \7;)·"",I.r'~.~ \J ~~I. ,)) [~, i Tuesday, August 30, 2005 Page I of 1 ~ - STATE OF ALASKA ALASKAt AND GAS CONSERVATION CO. .~ISSION REPORT OF SUNDRY WELL OPERATIONS AUG 2 5 2005 J.UaS~ía ŒM ¿~ 1. Operations Performed: D Abandon D Alter Casing D Change Approved Program D Suspend D Operation Shutdown D Perforate D Other B Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well B Pull Tubing D Perforate New Pool D Waiver D Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: D Development D Exploratory o Stratigraphic B Service 5. Permit To Drill Number: 193-016 6. API Number: 50-029-22338-00-00 99519-6612 50' 9. Well Name and Number: PBU P1-14 ADL 034622 10. Field / Pool(s): Prudhoe Bay Field / Point Mcintyre Pool 8. Property Designation: 11. Present well condition summary Total depth: measured 11768 feet true vertical 9189 feet Plugs (measured) None Effective depth: measured 11680 feet Junk (measured) None true vertical 9127 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 76' 76' Surface 3873' 10-3/4" 3914' 3552' 5210 2480 Intermediate Production 11721' 7-5/8" 11761' 9184' 8180 5120 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 11162' - 11574' 8761' - 9052' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2", 17# x 4-1/2", 12.6# 7-5/8" x 4-1/2" Baker 'S-3' packer; 5-1/2" 'X' Nipple L-80 10625' 10414' 2134' 12. Stimulation or cement squeeze summary: Intervals treated (measured): C" 11\.' '\ i .~-"~ f'\ , 1 G r,) ,")? 0 (Jr' S .:r-\ pH ~ t. U [, C J ~;; I:J __:J Treatment description including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run D Daily Report of Well Operations DWell Schematic Diagram 15. Well Class after proposed work: D Exploratory D Development B Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 0 GINJ B WINJ 0 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 Dave Wesley, 564-5153 305-094 Printed Name Terrie Hubble Signature -(~ ~ Form 10-404 Revised 04/2004 Title Technical Assistant O RPh¡onGe ¡ N,,5~-L.628 Dat,e ~, ~", 105 T, Pe,r;~,i,:e~~~~~;,e;~;~;~28 I . ! I Ä _ ð.Î1 f(/Jt¡1Þ ~ Içftt'~~ 103/4",45.5#, NT-80, ID = 9.953" P1-14 <.,bmDletion Doyon 16 RWO Comp~èied 8/5/05 ) TREE = WELLHEAD = ÀCTUA TOR = kS. B..EV =' SF. RBi = KOP= ' Max Angle = Datum MD = Datum1VD = 3,914 51/2",17.0#, L-80, TCII TBG ID = 4.892",0.0232 bpf 41/2" X 5 1/2" XO 1-1 75/8" X 4 1/2" Unique Machine OverShot Assy. 4 1/2", 12.6#, TDS L-80, ID = 3.958" 41/2", 12.6#, TT WLEG ID = 4.00" I PBTD 1-1 75/8",29.7#, NT-95, ID = 6.875" DATE 05/15/93 01/17/01 02/20/01 08/12/01 04/13/05 REV BY SIS-lsl SIS-MD RN/TP dew 10,510 10625' 10,625 11,680 11,760 II.- ~ 2,134 1-1 ~ 1/~" 'X' Nipple, ID = 4.562" - XX Plug set I In Nipple. Minimum ID = 3.725" @ 10603' 4-1/2" OTIS XN NIPPLE A -I 10,344 1-1 5 1/2" 'X' Nipple, ID = 4.562" -I 10,414 11 75/8" X 41/2" Baker S-3 packer, ID = I 3.875" -I 10,447 1-1 41/2" 'X' Nipple, ID = 3.813" 1 10,554 1-1 75/8" X 4 1/2" Baker SABL-3 Pkr, ID = 4.00" 1 10,586 1-1 4-1/2" PARKER SWS NIP, ID = 3.813" 1 10,603 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 ~ :8: X ~ ~ COMMENTS ORIGINAL COMFlETlON CONVERTED TO CANVAS FINAL CORRECTIONS Proposed completion, RWO ~ ÆRFORA TION SUMMARY REF LOG: DLUMLL ON 03/6/93 ANGLE AT TOP ÆRF: 45 @ 11162' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 11162-11172 0 05/15/93 3-3/8" 4 11210-11296 0 05/15/93 3-3/8" 4 11313-11343 0 05/15/93 3-3/8" 4 11359-11574 0 05/15/93 .. I,'J""'" DATE REV BY 08/04/05 MJA COMMENTS RWO - Tbg Up Size FMC CnN , 'ÄXäSON 50' 1289' 48 @ 6106' 11288' 8800'SS POINT MCINTYRE UNIT WaL: P1-14 PERMIT No: 93-016 API No: 50-029-22338-00 Sec. 16, T12N, R14E, 1611.16 F8...4096.34 FNL BP Exploration (Alaska) Well: Field: API: Permit: ) ) 07/31/05 N/A 08/06105 Doyon 16 P1-14 Prudhoe Bay Unit 1 Point Mcintyre Pool 50-029-22338-00-00 193-016 Accept: Spud: Release: Rig: PRE-RIG WORK 04/15/05 DRIFTED WI 3.70 CENT AND SB TO 10650' (SLM) PAST TT. 06/19/05 SET FAST DRILL AT 10618' CORRELATED TO TUBING DETAIL. (PRE RWO) TUBING PUNCH WITH 2' OF 1.56" "PINK" PUNCHERS AT 4 SPF FROM 10468' - 10470'. PREPARATION FOR CHEMICAL CUT AND RIG WORKOVER. 06/20/05 STRING SHOT WITH 12' BY 2 STAND STRING SHOT FROM 10515' TO 10527'. CHEMICAL CUT WI 3.5" SEVERING HEAD AT 10525'. LOGS CORRELATED TO TUBING DETAIL AND DESIRED TUBING JOINT IN PROCEDURE. (PRE RWO) ) ) BP EXPliORATION Operatiol1SSuI11maryReport Page 1 015 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-14 P1-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/31/2005 Rig Release: 8/6/2005 Rig Number: Spud Date: 2/19/1993 End: Date From.; To Hours Task Code NPT Phase Description.ofOþerations 7/30/2005 12:00 - 16:00 4.00 MOB P PRE PJSM-Move Rig Off N-06, Remove BOPE's, UD Derrick, Install Booster Wheels. 16:00 - 00:00 8.00 MOB P PRE Move Rig from N-06 to P1-14. 7/31/2005 00:00 - 06:30 6.50 MOB P PRE Move Rig from N-06 to P1-14. Rig arrived P1 at 0630 hours. Order two truckloads 120F, 9.3 ppg, 3% KCI for Well Kill I Circulation Operations. 06:30 - 13:00 6.50 MOB P PRE Raise Derrick. Move Rig up onto 3 layers of Rig Mats. P/U replacement tree and move into well cellar prior to centering rig over well. R/U Top Drive and Rig Floor equipment. Center rig over well. Accept Rig @ 1300 hours. 13:00 - 15:00 2.00 WHSUR P DECOMP R/U Circulating lines to Tree and take on 9.3 ppg, 3% KCI to Pit #2,3 & 4 15:00 - 17:30 2.50 WHSUR P DECOMP P/U and hang off Bridle Lines. P/U DSM Lubricator and pull BPV, UD Lubricator. 17:30 - 18:30 1.00 WHSUR P DECOMP R/U Circulating Lines to Tree Swab Valve. Test Lines to 3,500 psi. 18;30 - 20:00 1.50 WHSUR P DECOMP Circulate 120 deg. 9.3 ppg. 3% KCL Down 4-1/2" Tubing. Take Returns up 7-5/8" x 4-1/2" Annulus.. Pump Rate; 10 bpm at 1,750 psi. Divert all Returns to Slope Tank. 20:00 - 21 :00 1.00 WHSUR P DECOMP Install TWC and Test from below to 1,000 psi 21 :00 - 23:00 2.00 WHSUR P DECOMP N/D Production Tree, Adapter Flange and Remove from Cellar Area. Install XO in Hanger, Threads in Good Shape 23:00 - 00:00 1.00 BOPSUP P DECOMP N/U 11-5/8" x 13-5/8" 5M Adapter Spool 8/112005 00:00 - 03:00 3.00 BOPSUF P DECOMP N/U BOPE's. Modify Drilling Riser and Install Same. Connect Choke and Kill Lines. 03:00 - 03:30 0.50 BOPSUR P DECOMP R/U Test Joint and Test Manifold. 03:30 - 04:30 1.00 BOPSUP P DECOMP Test BOPE's; TWC Leaked, R/U DSM Lubricator and Pull TWC, Install New TWC, Test to 4,000 psi. RID Lubricator 04:30 - 08:00 3.50 BOPSUP P DECOMP Test Bope's: Test Choke Manifold, 250 psi low I 4,000 psi high. Annular Bag to 250 psi low I 3,500 psi high. All tests good; witnessed by R. Klepzig and M. Rooney, Rig Supvs. AOGCC Rep, J. Crisp, waived right to witness BOPE tests. 08:00 - 09:30 1.50 BOPSUP P DECOMP P/U Lubricator and pull TWC. RID BOPE Test equitment. R/U Camco Control Line Spooler. 09:30 - 10:00 0.50 PULL P DECOMP P/U DP Landing Joint and M/U to XO for 4-1/2" TDS. RIH and M/U to Tubing Hanger. Hold PJSM w/ Rig Crew, Tool Pusher, WSL, Camco Operator, and FMC hand. Pull Hanger free wI 125K, Tubing free wI 170K. 10:00 - 10:30 0.50 PULL P DECOMP B/O and UD Hanger, XO, and Landing Joint. Cut single Control Line and attach to Spooler. 10:30 - 19:30 9.00 PULL P DECOMP POH 4-1/2", 12.6#, TDS Tubing; numbering all jts, spooling Control Line and counting SS Bands. Recovered 58 of 59 SS Bands, but it did not look like there were any missing due to the consistency of positioning on the joints. Recovered 261 jts, 1 SSSV Assy, 2 GLM Assy's, 1 SWS Assy. and Cut-Off Jt. at 18.47' 19:30 - 20:00 0.50 PULL P DECOMP RID and UD 4-1/2" Tubing Handling Equipment 20:00 - 20:30 0.50 PULL P DECOMP Clean and Clear Rig Floor 20:30 - 21 :00 0.50 CLEAN P DECOMP Install Wear Ring, 10" ID 21 :00 - 23:00 2.00 CLEAN P DECOMP P/U and M/U Dressoff BHA; 6-3/4" Mill Shoe-2 ea. Washpipe Ext.-Washover Boot Basket-DBL Pin XO-Boot Basket-7-5/8" Scraper-Bit Sub-Bumper Sub-Oil Jar-XO-12 x 4-3/4" DC's. Total BHA Length = 416.54' Printed: 8/8/2005 7:42:47 AM ) ') BP EXPLORATION Operations Summary Report Page 2 015 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-14 P1-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/31/2005 Rig Release: 8/6/2005 Rig Number: Spud Date: 2/19/1993 End: Date From ..,To Hours Task Code NPT Phase Description of Operations 8/1/2005 23:00 - 00:00 1.00 CLEAN P DECaMP RIH Picking Up 4" DP from Pipeshed 8/2/2005 00:00 - 09:30 9.50 CLEAN P DECaMP RIH wI 6-3/4" x 3-7/8" Dress Off BHA on 4" DP 09:30 - 10:30 1.00 CLEAN P DECOMP P/U 4" HT-38 DP Jt #316, get parameters:S/O wt 140K, PIU wt 195K, 40 SPM, 620 psi. Slowly lower and see top of Stub @ 22' in on Jt #316, or 10,500'. P/U to verify and see pressure drop 40 psi. Rotate 50-60 RPM, slowly and engage Dress-off Mill, Increase rotating wt to 165K and see torque increase to 8,000 Ib-ft, then stall out at 10K Ib-ft. P/U and repeat with same results, but also see same 40 psi decrease in Circ Pres when PIU string. Decrease Rot Wt and make -6" of Dress-off to 10,500.5', Doyon 16 RKB. 10:30 - 12:00 1.50 CLEAN P DECaMP Circulate Hi-Vis Sweep, did not see any debris over Shakers. 12:00 - 16:00 4.00 CLEAN P DECOMP POH and SIB DP and DC's in Derrick. 16:00 - 16:30 0.50 CLEAN P DECaMP B/O and UD Baker BHA. Cleanout Junk Basket and find -1 quart of metal fines and some scale. Magnet showed most of the debris to be metallic. There were minor wear patterns on the inside mill and on the end mill. 16:30 - 18:00 1.50 CLEAN P DECaMP MIU FasDrill milling BHA (BHA #2). 18:00 - 21 :00 3.00 CLEAN P DECaMP RIH with 4" DP from Derrick to.10165'. 21 :00 - 22:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line. 22:00 - 22:30 0.50 CLEAN P DECaMP RIH wI 4" DP from Derrick to 10410'. 22:30 - 23:00 0.50 CLEAN P DECaMP Establish Parameters. Pump Rate 4.1 bpm at 720 psi. Up Weight = 200,000 Ibs, Down Weight = 135,000 Ibs. Rotating Weight = 162,000 Ibs at 30 rpm's and 5,500 ft-Ibs torque. Wash down and engage tubing stub with bell guide at 10511'. 23:00 - 00:00 1.00 CLEAN P DECaMP Shear bell guide with 10,000 Ibs. Wash and ream down hole with 0-5,000 Ibs weight on mill. Rotate at 40 rpm's , torque 7,500 ft-Ibs. Pump Rate 4.2 bpm at 690 psi. Engage Fas-Drill Plug at 10603'. Mill on Fas-Drill Plug with 1,000 Ibs weight on mill, 40 rpm's, 9,000 ft-Ibs torque, pump rate 4.2 bpm at 710 psi. 8/3/2005 00:00 - 00:30 0.50 CLEAN P DECaMP Continue to mill Fas Drill Plug. Push out the end of 4-1/2" tubing to 10633'. PI U, Wash and Ream through entire interval again. 00:30 - 01 :00 0.50 CLEAN P DECaMP Pump high visc sweep and circulate around. Gas bubble at surface, shut-in well with annular preventer. 01 :00 - 01 :30 0.50 CLEAN N DPRB DECOMP Monitor well through choke. No pressure, check for flow - no flow. Notified Mr. Rossberg wI BP and Mr. John Crisp wI AOGCC. 01 :30 - 03:00 1.50 CLEAN N DPRB DECaMP Circulate well through choke 467 bbls at 4.3 bpm at 760 psi. Initial returns consisted of gas, crude oil, and KCI water, but cleared up 2/3s of the way thru the circulation. Lost 80 Bbls during the circulation. 03:00 - 03:30 0.00 EV AL P DECaMP SID pump and monitor well. No flow back, see fluid level continue to drop. 03:30 - 13:30 10.00 CLEAN P DECaMP POH and UD DP and D/C's and B/O and UD BHA #2. 13:30 - 14:00 0.50 CLEAN P DECaMP Clear and clean Rig Floor. 14:00 - 15:30 1.50 RUNCO~ RUNCMP R/U and test Torque Turn Equipment, pull Wear Ring. Hold PJSM to discuss RIH wI two different sizes of Tubing. 15:30 - 18:30 3.00 RUNCO~ RUNCMP RIH wI new completion. Bakerlok all connections below Packer, use Jet Lube Seal Guard on all other connections. Torque Turn all 5-1/2" connections to 4,350 ft-Ibs. 18:30 - 19:15 0.75 RUNCO~ RUNCMP Change out pipe handling dies. Safety Meeting with hands on Printed: 8/8/2005 7:42:47 AM ) ) BPEXPLQRATION Operations Sutnmäry.,Report Page 3 öf5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-14 P1-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/31/2005 Rig Release: 8/6/2005 Rig Number: Spud Date: 2/19/1993 End: Date From - To Hours Task Code NPT Phase Description of Operâtions 8/3/2005 18:30 - 19:15 0.75 RUNCOMP RUNCMP hazards with running tubing. 19:15 - 00:00 4.75 RUNCOMP RUNCMP RIH wi 5-1/2", L-80, 17.0#, TCII Tbg. Torque all connections to 4,350 ft-Ibs, use Jet Seal Guard thread compound. 8/4/2005 00:00 - 04:30 4.50 RUNCOMP RUNCMP Continue to RIH wi 5-1/2", L-80, 17.0#, TCII Tbg. 04:30 - 05:00 0.50 RUNCOMP RUNCMP Service Top Drive and Drawworks. 05:00 - 08:30 3.50 RUNCOIVP RUNCMP Continue RIH to 10,495'. Stop and get S/Owt 140K, PIU wt 205K. 08:30 - 09:00 0.50 RUNCOMP RUNCMP M/U Joint #262, M/U to Top Drive, and prepare to circulate down over Stump. Get parameters: 30 SPM, 200 psi. Slowly circulate down and see pressure increase to 220 psi at 12' in on Jt #262. Continue circulating down to the shear pins 16' in. Pins shear @ 5-6K. Continue to No-Go @ 20' in. PIU and repeat twice with same pressure results and No-Go Stack-outs. Top of Stub @ 10,515', Doyon 16 RKB. Mark #262 and calculate Space-out. Will require the following Pup Joints: 3-each 10.16', 1-4.13', and 1-2.43'; to be placed under Joint #261. 09:00 - 09:30 0.50 RUNCOMP RUNCMP POH and UD Jts 262 and 261. M/U Pup Jts. Find circumferential crease near the top of Jt #261 that is reflected by a reduced ID. Attempt to push 4.767" Rabbit thru and No-Go. Check Jt #262 and find the same crease about 3-1/2' from the box-end. Inspect manual Slips and see that the bottoms of the Slip segments are rolled over from impact with the Rotary Table when Floorhands set them down after pulling them from the bowl during each joint PIU while RIH or POOH. 09:30 - 10:30 1.00 RUNCOMP RUNCMP Confer wi town and decide to POH, UD, and Drift the top 50 Joints down to the X-Nipple @ 2,116'. Also will R/U Slickline to run 4.625" Gage Ring to the X-Nipple immediately above the Packer. 10:30 - 17:00 6.50 RUNCOrvP RUNCMP POH Jt 260 thru 210 and the Top X-Nipple. All joints easily passed a 4.767" Rabbit in the Pipe Shed. Release Lil Red Hot Oilers. 17:00 - 17:30 0.50 RUNCOMP RUNCMP PJSM wi Rig Crew, Slickliners, Tool Pusher, and both Co-Men. Wait on FMC to M/U Landing Joint to Tubing Hanger so that Schlumberger can install their packoff to a Lubricator extension. There is no XO from their equipment to "normal" pipe threads. 17:30 - 18:30 1.00 RUNCOtvP RUNCMP M I U Landing Joint to Tubing Hanger. Land Hanger and RILDS. Back Out Landing Joint and LID. 18:30 - 19:00 0.50 RUNCOrvP RUNCMP R I U Lubricator Extension and Pull Slickline Tools to rig floor. 19:00 - 20:30 1.50 RUNCOtvP RUNCMP PJSM with Slickline and Crew on rig up. Rig Up Slickline Equipment. 20:30 - 22:00 1.50 RUNCOtvP RUNCMP RIH wi Slickline. 4.625" Gauge Ring, Spangs, Jars, and Weight Bar. Tag X-Nipple at 8222' SLM. No Tight Spots Found. 22:00 - 23:00 1.00 RUNCOrvP RUNCMP POOH wi Slickline. RID Slickline Equipment. 23:00 - 00:00 1.00 RUNCOrvP RUNCMP P I U Landing Joint and M I U to Tubing Hanger. Pull Tubing Hanger to Floor and L / D. 8/5/2005 00:00 - 01 :30 1.50 RUNCOrvP RUNCMP RIH wi 5-1/2", L-80, 17.0# , TCII Tubing. 01 :30 - 02:00 0.50 RUNCOrvP RUNCMP Service Top Drive, Pipe Skate, Draw Works, and Crown. 02:00 - 04:00 2.00 RUNCOrvP RUNCMP Continue RIH wi 5-1/2", L-80, 17.0# , TCII Tubing. 04:00 - 04:30 0.50 RUNCOrvP RUNCMP M I U Joint #262, M / U to Top Drive, and prepare to circulate down over Stump. Get parameters: Up Weight = 205,000 Ibs, Printed: 8/8/2005 7:42:47 AM ) ) BP EXPLORATION Operations Summary Repott RUNCMP Down Weight = 135,000 Ibs, 30 SPM, 190 psi. Slowly circulate down and see pressure increase to 220 psi at 13' in on Jt #262. Continue to No-Go @ 20' in. PI U and repeat twice with same pressure results and No-Go Stack-outs. Mark #262 and calculate Space-out. Will require the following Pup Joints: 3-each 10.16', 1-6.16' to be placed under Joint #261. Overshot will have 6.5' of swallow over tubing stub. POH and LID Jts 262 and 261. M I U Pup Jts and M I U Jt 261. M / U Tubing Hanger and Landing Joint. Reverse Circulate 10.2 ppg Brine, 3 bpm at 240 psi. Pump 145 Bbls followed by 175 Bbls mixed wI 1-3/4 Bbls Correxit EC-1124 Corrosion Inhibitor. Land Tubing Hanger. PJSM wI Baker, FMC, Lil Red, Doyon Rig Crew, Tool Pusher and Co-Man. RILDS. R/U to circulate Diesel. Remove one DP Pup Jt to enable safer position from which to drop the Ball-and-Rod. Back-off Landing Jt to use Iron Roughneck to break the DP connections. When the Landing Jt Assembly, made up of two DP Pups, a 4-1/2" IF x 5-1/2" TCII, and a 5-1/2" TCII Pup Jt, was removed, the 5-1/2" Collar came out attached to the XO. The Collar was removed, cleaned up, and Baker-Loked to the XO. A thin film of Baker-Lok was applied to the bottom threads of the collar. The shortened Landing Jt Assembly was then re-run onto the 5-1/2" x 3' long Pup Jt. Reverse Circulate 100 Bbls Diesel Freeze Protect and allow to U- Tube for 1-hour. Break off Floor Valve and Drop Ball and Rod. Pressure up on Tubing to 4,000 psi and hold and record for 30 mins--good test. Realign valves and PT Annulus to 4,000 psi. Good test. Bleed down lines, break off Floor Valve. Back out Landing Joint and the 3-foot long 5-1/2" did not come free from the Hanger. Call for Slickline to set Plug in the top X-Nipple @ 2,134'. Wait on Slickline. Bleed down lines. Clear and Clean Rig Floor. PJSM wI SLB Slickline. R I U Slickline. Slickline Crew Change Out. RIH wI XX Plug for 5-1/2" X Nipple. Set Plug at 2140' SLM. POOH wI X-Line running tool. Pressure test XX Plug to 1000 psi. Blow down lines. RID Slickline. Pump out stack and flush wI water. N I D BOPE. N I D BOPE and place on pedestal, remove tubing pup joint from hanger. N I U Adapter Flange and Tree wI DSM Sweeny Wrench. Pressure test Adapter to 5000 psi, good test. Pressure test Tree to 5000 psi - found small leak between SSV barrel and body. Leak very small -3 drips per minute. Discuss with DSM Valve Shop and Wells Group. Decided to have Valve Shop come back after rig moves off and either repair or replace. Install gauges. Secure well and cellar. Ready rig to move and back off well. Release Rig at 0600 hrs. Secure Tree and Cellar. Back rig off Well and Move Rig Sideways off Rig Mats and down Ramps onto Pad. R/U Derrick Bridle Lines and prepare to UD Derrick. Remove BOP Stack and set in transport Cradle. Install and R/U Rear Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-14 P1-14 WORKOVER DOYON DRILLING INC. DOYON 16 Date From-To Hours Task Code NPT, Phase 8/5/2005 04:00 - 04:30 0.50 RUNCOMP 04:30 - 06:00 1.50 RUNCOMP RUNCMP 06:00 - 08:30 2.50 RUNCOMP RUNCMP 08:30 - 10:30 2.00 RUNCOMP RUNCMP 10:30 - 13:00 2.50 RUNCOMP RUNCMP 13:00 - 15:00 2.00 RUNCOMP RUNCMP 15:00 - 16:30 1.50 RUNCOMP RUNCMP 16:30 - 18:00 1.50 WHSUR P WHDTRE 18:00 - 21 :30 3.50 WHSUR P WHDTRE 21 :30 - 22:30 1.00 WHSUR P WHDTRE 22:30 - 23:00 0.50 WHSUR P WHDTRE 23:00 - 00:00 1.00 BOPSUP P WHDTRE 8/6/2005 00:00 - 01 :30 1.50 BOPSUPP WHDTRE 01 :30 - 03:30 2.00 WHSUR P WHDTRE 03:30 - 05:30 2.00 WHSUR P WHDTRE 05:30 - 06:00 0.50 WHSUR P WHDTRE 06:00 - 07:30 1.50 RIGD P POST 07:30 - 10:00 2.50 RIGD P POST Page 4 of 5 Start: 7/31/2005 Rig Release: 8/6/2005 Rig Number: Spud Date: 2/19/1993 End: Description of Ope rations Printed: 8/8/2005 7:42:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') Page Sot S Spud Date: 2/19/1993 End: Date From- To Houts Task Code NPT Phase Descriptionöt Operations 8/6/2005 07:30 - 10:00 2.50 RIGD P POST Boosters and secure Rig Equipment for Rig move to B-02A. BP EXPLORATION, Op.erätionsSu rnmaryRepórt P1-14 P1-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/31/2005 Rig Release: 8/6/2005 Rig Number: Printed: 8/8/2005 7:42:47 AM Pt. Mac 1-14 ') ') ~¢ ¡qS-O/(P Subject: Pt. Mac 1-14 From: John Crisp <john_crisp@admin.state.ak.us> Date: Wed, 03 Aug 2005 08:53:01 -0800 To: Jim Regg <jim_regg@admin.state.ak.us> ~q ~ ,~o-'5 I got a call this morn @ 0100 hrs. about Doyon 16 using their Ann Preventer to to control gas that was released after they drilled thru EZSV. Totally cased hole with no DP or casing pressure when they shut the well in. They were going to CBU thru choke to be on the safe side. Do we need to check this incident out further? o 0 Ctck,~ AeeJeð . SCANNED AUG G 9 2005 1 of 1 8/3/2005 12:52 PM ) ~1f~uŒ (ill~ ~~!Æ~~!Æ / CONSE'::Á.~~ ~~S= / ) 173"t)/~ FRANK H. MURKOW5KI, GOVERNOR 333 W. -rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SCAN~\\ED J\PR 2 8 l.ODS Re: Prudhoe Bay P1-14 Sundry Number: 305-094 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior olL1 unless rehearing has been requested. o;e· , ~~nnan DATED this¡i day of April, 2005 Encl. W4A- ~'JI~lzoos- '> ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL APR 20 AAC 25.280 1 5 Z005 1. Type of Request: o Abandon II Repair Well 0 Plug Perforations 0 Stimulate o Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver o Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Alaskit on & Gas Cons. ~onmiss 'on o Other Anchorage o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: o Development 0 Exploratory o Stratigraphic IBI Service /' 5. Permit To gJill Number 193-016 ,.,r- 6. API Number: /' 50- 029-22338-00-00 r 50' 9. Well Name and Number: PBU P1-14 /" 8. Property Designation: 11. Total Depth MD (ft): 11768 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Point Mcintyre Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective DepthMD (ft): Effective Depth TVD (ft): Plugs (measured): 9189 11680 9127 None Length Size MD TVD Burst Junk (measured): None Collapse ADL 034622 76' 3873' 20" 10-3/4" 76' 3914' 76' 3552' 5210 2480 11721' 7-5/8" 11761' 9184' 8180 5120 Perforation Depth MD (ft): Perforation Depth TVD (ft): 11162' - 11574' 8761' - 9052' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker 'SABL-3' packer; 4-1/2" Camco TRCF-4A SSSV Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 105541 2196' Tubing MD (ft): 10625' 12. Attachments: a Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development IBI Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Robert Tirpack Title Senior Drilling Engineer Signature ~ Phone 564-4166 Date,Ø?,r 7 'V Commission Use Only April 20, 2005 Date: / 15. Well Status after proposed work: o Oil 0 Gas 0 Plugged -&wAG 0 GINJ M'WINJ 'WGJt- Contact Dave Wesley, 564-5153 o Abandoned o WDSPL Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 30,)-: () c¡ i o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: T-e ~ t 4000 pç,' , f)J3TIZ,151__1 --- APPROVED BY , ()KI~~n~ AT COMMISSION ¿,~ Date øf~Late ') ) Obp G~. To: Winton Aubert - AOGCC Date: April 13, 2005 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling P1-14 Application for Sundry Approval - RWO to replace I upsize tubing /"/ Subject: Approval is requested for the proposed work-ov~ of well P1-14. The scope of the rig work-over is to replace existing 4 1/2" tubing with 5 1 12" tubing. Nodal analysis indicates the well is tubing limited and incremental surface pressure only achieves nominal rate increases. A tubing swap is required to increase ,/ injection rates for this pattern by 10K BWPD to get close to the recommended injection rate for this / pattern.~/ P1-14 i WA Injector located in the western GDWFI at Point Mcintyre. The injector has received one cycle 0 'hd is currently on water injection. Cum water injection into the pattern has been almost 78 MMBW while cumulative MI injection has been 17.1 BCFG. Recent injection data for this well indicates it is injecting approximately 20,000 BWPD at a pressure of about 2,1 OOpsi. The P1-14 RWO is currently scheduled for Nabor 7ES beginning around April 28, 2005. The pre-rig work for this RWO will be priority scheduled immediately after the application for Sundry is approved. Scope Pre-Ri~ Operations: 1. R/U SWS E-line and drift the 4 Y2", 12.6#, L-80 tubing through the tubing tail WLEG at 10,625'md. 2. M/U a HES 4 1/2" Fas-Drill EZSV. RIH and set the Fas-Drill at -10,620', in the lowermost pup joint. POH with E-line. Pressure test the tubing to 4,000psi. /' 3. RIH and chemical cut the 4 Y2" tubing at 1 0,525'md, in the middle of the first full length tubing joint above the packer. In preparation for re-completing with an overshot, please do not cut below the middle of this joint. Minimally, 10 feet of tubing stump is desired. 4. Circulate the well to 9.3ppg 3% KCI brine through the tubing cut, until returns are clean. Conduct a CMIT T X IA to 4,000psi for 30 minutes. / 5. Conduct an MIT OA to 2,000psi. 6. Freeze protect to -2,200'md with diesel. 7. Bleed casing and annulus pressures to zero. 8. Function tubing and casing LDS. Pressure test 7 5/8" casing pack-off per Cameron representative. 9. Set a BPV. Secure the well. Level the pad as necessary. 10. Secure wells P1-13 and P1-16, as necessary, for rig MI/RU. Ri~ Operations: 1. Mil RU Nabors 7ES. / 2. Pull BPV. Circulate out diesel freeze protection and displace the well to 9.3ppg 3% KCI brine. Install TWC. ' 3. Nipple down the tree. Nipple up and test BOPE to 4,000psi. Pull TWC. / P1-14 Application for Sundry ) ) ~ 4. R/U. Pull the 4 Y2", 12.6#, L-80, TDS tubing from the tubing cut at -10,525'md and above. Be / prepared to spool up the Camco TRCF-4A SSSV control lines. 5. M/U a triple connection overshot milling assembly and RIH, P/U 4" drill pipe. Engage the tubing stub at -10,525'. Wash over and dress the top of the tubing stump to sufficiently remove any irregularities from the chemical cut. POOH. 6. R/U and pressure test the 7 5/8" casing to 4,000psi for 30 minutes. Record the test. 7. M/U a 3 5/8" milling assembly and P/U sufficient length of 2 3/8" drill pipe to allow milling the HES Fas- // Drill EZSV and pushing it to below the WLEG at -10,625'md. Minimally, this will require -120' of 2 3/8" drill pipe. 8. RIH and mill the Fas-Drill EZSV. Push it clear of the tubing tail. Beware potential pressure beneath the plug. POOH. g. M/U the Unique Machine, L-80, 7 5/8" X 4 Y2" tubing overshot and 4 Y2" tail pipe assembly, packer, and /' crossover to 5 Y2". Run the 5 Y2", 17.0#, L-80, TC-II tubing per program. 10. Overshot the 4 Y2" tubing stump to No-Go point. Space out the completion such that it will land -2' above no-go. RILDS. 11. Reverse circulate 9.3ppg 30/0 KCI brine, with Corrosion Inhibitor, followed by sufficient volume of diesel to freeze protect the well to -2,500' tvd, (-2,600'md). Allow the diesel to U-tube to equilibrium. 12. Drop the Ball I Rod to seat. 13. Set the packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each _ ~~. ~ 14. Install a TWC. 15. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 16. Install BPV. Secure the well. 17. Rig down and move off. Post-RiQ Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 04/20105 Estimated Spud Date: 04/30105 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 P1-14 Application for Sundry 'TREE = WELLHEAD = 'ACTUATOR = . KB.EL.ÈV; 'í3F:äE\i;_m I<OP';~ ' ," "Max Angle = . BatÚmMb = ÖäìÙmTVÖ; ........ 103/4",45.5#, NT-80, 10 = 9.953" 4 1/2", 12.6#, IDS L-80, 10 = 3.958" 4 1/2", 12.6#,11 WLEG 10 = 4.00" I PBID l-t 75/8",29.7#, NT-95, 10 = 6.875" DATE 05/15/93 01/17/01 02/20/01 08/12/01 REV BY SIS-lsl SIS-MD RN/TP FMC CrN .. "........."...... ..,........, AXELSON 50' P .)·14 .. '''''"'1'2"ä§í 48 @6106' m m11288ï "'ssöi:fss . 3,914 . I I g 'J ~ 10625' ~ ~ 10,625 ~ 11,680 f~~_~ 11,760 COMMENTS ORIGINA L COMPLETION CONVERTED TO CANVAS FINAL CORRECTIONS DATE REV BY ) TUBING HANGER: FMClCAMERON BPSH @ 35' MD. 2,196 l-t 41/2" CAMeO TRCF-4A SSSV, ID = 3.812" 1 GAS LIFT MANDRELS ST MD TVD DEV 1YÆ VLV LATCH PORT DATE 1 4,726 4,141 44° KBMG BK2 2 10,459 8,260 44° KBMG BKE Minimum ID = 3.725" @ 10603' 4-1/2" OTIS XN NIPPLE A 10,495 l-t 4-1/2" PARKER SWS NIP, ID = 3.813" 1 10,554 l-t 7 5/8" X 4 1/2" Baker SABL-3 A<r, ID = 4.00" 1 10,586 l-t 4-1/2" PARKER SWS NIP, ID = 3.813" 1 10,603 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 -< ÆRFORA TION SUMMARY REF LOG: DLUMLL ON 03/6/93 ANGLEATTOPÆRF: 45 @ 11162' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11162-11172 0 05/15/93 3·3/8" 4 11210-11296 0 05/15/93 3-3/8" 4 11313-11343 0 05/15/93 3-3/8" 4 11359-11574 0 05/15/93 COMMENTS POINT MClNTY RE UNIT WELL: P1-14 ÆRMIT No: 93-016 API No: 50-029-22338-00 Sec. 16, T12N, R14E, 1611.16 FEL4096.34 FNL BP Exploration (Alaska) 'TREE= . WELLHEA 0 = ÄCTUA TOR = KB. ELEV = BF. ELEV = KOP ::." ' Max Angle = Datum MD = DatunitvD = 103/4",45.5#, NT-80, 10 = 9.953" FMC CrN AXELSON 50' P1)J4 Pre rig ') TUBING HANGER: FMC/CAMERON BPSH @ 35' MD. 1289' 48 @ 6106' 11288' 8800' SS . 3,914 I t /' _bJ_ Pre rig: chemical ~ cut tubing 10525' -:::: --<:::; ::;- :8: Z Pre rig: set HES / ~ ~ Fas-Drill EZSV 10620' ~ 41/2",12.6#, TDS 10625' ~ L-80, 10 = 3.958" 4 1/2", 12,6#, TT 10,625 WLEG 10 = 4,00" I PBTD 1-1 11,680 1 .. 75/8",29.7#, .. NT-95, 10 = 6.875" 11,760 DATE 05/15/93 01/17/01 02/20/01 08/12/01 04/13/05 REV BY SIS-lsl SIS-MD RN/TP dew COMMENTS ORIGINAL COMA-EriON CONVERTED TO CANVAS FINAL CORRECTIONS Proposed pre rig work DATE 2,196 1-1 41/2" CAMCO TRCF-4A SSSV, 10 = 3.812" 1 GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 4,726 4,141 44° KBMG BK2 2 10,459 8,260 44° KBMG BKE Minimum 10 = 3.725" @ 10603' 4-1/2" OTIS XN NIPPLE A I 10,495 1-1 4-1/2"PARKERSWSNIP,ID=3.813" 1 10,554 1-1 75/8" X 41/2" Baker SABL-3 Pkr, 10 = 4.00"1 10,586 1-1 4-1/2"PARKERSWSNIP,ID=3.813" 1 10,603 1-1 4-1/2" OTIS XN NIP, 10 = 3.725" 1 ......c::: PERFORA TION SUMMARY REF LOG: DLL/MLL ON 03/6/93 ANGLE AT TOP ÆRF: 45 @ 11162' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 11162-11172 0 05/15/93 3-3/8" 4 11210-11296 0 05/15/93 3-3/8" 4 11313-11343 0 05/15/93 3-3/8" 4 11359-11574 0 05/15/93 REV BY COMMENTS POINT MClNTY RE UNIT WELL: P1-14 PERMIT No: 93-016 Apt No: 50-029-22338-00 Sec, 16, T12N, R14E, 1611,16 FEL4096,34 FNL BP Exploration (Alaska) , P1-14 Propo~~d Completion 103/4",45.5#, NT-80, 10 = 9.953" 3,914 I I 5 1/2", 17.0#, TC-II - 10460' L-80, 10 = 4.892" 4 1/2" X 51/2" XO 1-1 10,460 I~ 75/8" X 4 1/2" 10,530 ~ UM Overshot Assy :8: Z ~ ~ 41/2",12.6#, TDS 10625' ~ L-80, 10 = 3.958" 41/2",12.6#, TT 10,625 WLEG 10 = 4,00" I PBTD l-i 11,680 '. 75/8",29.7#, ... NT-95, 10 = 6.875" 11,760 DATE 05/15/93 01/17/01 02/20/01 08/12/01 04/13/05 REV BY COMMENTS ORIGINAL COMPLETION CONV ERTED TO CANV AS FINAL CORRECTIONS Proposed cOl1l>letion, RWO SIS-lsl SIS-MD RN/TP dew DA TE REV BY ) TREE = WELLHEAD = ACTUATOR = KB, ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = 1289' 48 @ 6106' 11288' 8800' SS FMC CIW AXELSON 50' 2,200 l-i 51/2" 'X' nipple for HES 'MCX' SSSV Minimum 10 = 3.725" @ 10603' 4-1/2" OTIS XN NIPPLE A 10,450 l-i 5 1/2" 'X' landing nipple, 10 = 4,813" 10,472 1-1 75/8" X 4 1/2" Baker S-3 packer 10,498 l-i 4 1/2" 'X'landing nipple, 10 = 3.813" 10,554 l-i 75/8" X 41/2" Baker SABL-3 Pkr, 10 = 4.00"1 10,586 l-i 4-1/2"PARKERSWSNIP,ID=3,813" 1 10,603 l-i 4-1/2" OTIS XN NIP, 10 = 3.725" I ~ PERFORA TION SUMIV1A RY REF LOG: DLL/MLL ON 03/6/93 ANGLE AT TOP PERF: 45 @ 11162' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 11162-11172 0 05/15/93 3-3/8" 4 11210-11296 0 05/15/93 3-3/8" 4 11313-11343 0 05/15/93 3-3/8" 4 11359-11574 0 05/15/93 COMMENTS POINT MClNTY RE UNIT WELL: P1-14 PERMIT No: 93-016 API No: 50-029-22338-00 Sec. 16, T12N, R14E, 1611.16 Fa 4096,34 FNL BP Exploration (Alaska) I - b~ (/93-0f(P .,. ,\1'.'11, -..~~ ~...- ~4!.:- --:"4!.:~ *.~ ~..... . I'.'I\~ ". To: Gary McBride/John Smart, Well Ops TL Date: June 4, 2003 From: Kira Barton GPMA Petroleum Engineer Subject: P1-14 AdDerf Reauest lOR: 500 bopd Cost Code: PMLP01014 Est. Job Cost: $40M Please add a total of 55 ft of new perforations in the LC2 zone of P1-14. /' TVDe Job Comments 1. S D& T Use 3 3/8" Dummy gun 2. E Adperfs Please refer to attached procedure Tie-in Log: SWS Perf/Jewelry Log (5/12/93) Current Status: Injecting 40184 MCFD MI, 3578 WHP (5/21/03) Max Deviation: 480 at 6106' Minimum ID: 3.725" @ 10603' 4-1/2" OTIS XN NIPPLE Last TD Tag: 11,630' SLM (03/02/99) Last Wellwork: Run Temp Log w/PDS Gauges (6/03/99) Latest H2S reading: no record Gas Lift Design DGLV @ 4726', 10459' MD Well P1-14 has currently injecte '~MBW. The well has 4 W' completion which restricts injectivity. A drag reducing chem~~I~itive was tested in Oct-97. This enabled increased injection, most likely due to increased fractures in the formation. The purpose of this job is to add /' perfs for increased MI and water injectivity. Please perf the listed interval: Perf Interval Footage Gun Size Shot Density Orientation 11600' -11655' 55' 33/8" 4 s.p.f. Random ,/ If you have any questions or concerns regarding this program please call Andy Parker at (W) 564- 5766, or (H) 694-2990. Thank you! cc: w/a: P1-14 Well File A. Parker K.Barton , :""', ';'-'",:,c," J ~ N 2 0 2004 " :"" . '" II. '. lit ~ ' H"':~ ~, ~ v"GA- '¿.h~/200?:> ( STATE OF ALASKA ( /)75 I¿¡ /JY 13 , ALASKA Oil AND GAS CONSERVATION COMMISSION c::z:p f 1/ y APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend D Operation Shutdown 0 PerforateŒ] / VarianceD Annular DisposalD Alter Casinç 0 Repair Well D Pluç Perforations 0 StimulateD Time ExtensionD OtherD Chanqe Approved Proqram 0 Pull Tubinq 0 Perforate New Pool 0 Re-enter Suspended WellO 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name' BP Exploration (Alaska), Inc. 193-0160 / . Development 0 Exploratory 0 3. Address: P.O. Box 196612 6. API Number / Anchorage, Ak 99519-6612 Stratigraphic 0 Service Œ] 50-029-22338-00-00 7. KB Elevation (ft): 9. Well Name and Number: 50.00 KB P1-14 ./ 8. Property Designation: 10. Field/Pool(s): ADL-034622 Point Mcintyre Field / ptmac Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): ¡Effective Depth TVD (ft): Plugs (md): Junk (md): 11768 9189.0 11680 9076.8 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 80 20" 94# H-40 35 - 115 35.0 - 115.0 1530 520 Production 11725 7-5/8" 29.7# S-95 35 - 11760 35.0 - 9183.3 8180 5120 Surface 3879 10-3/4" 45.5# N-80 35 - 3914 35.0 - 3551.7 5210 2480 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11162 - 11172 8761 - 8767.6 4.5 " 12.6 # L-80 35 - 10625 11210 - 11296 8795 - 8855.6 11313 - 11343 8868 - 8888.8 11359 - 11574 8900 - 9052.0 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker SABL-3 Packer 10554 4-1/2" TRCF-4A SSV 2196 12. Attachments: Description Summary of Proposal ŒJ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 00 14. Estimated Date for Decemb~~003 15. Well St~tus after proposed work: Commencina Operation: U(I,:~;'J.- 011 D GasD PluggedD AbandonedD 16. Verbal Approval: Date: WAG D GINJD WINJŒ) WDSPLD Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Andy Parker Printed Name l.d¡{ar~ Title Petroleum Engineer Signature .. ~\~ Phone 564-5766 11/20/03 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3ð3-:3?¥ Plug Integrity 0 BOP TestD Mechanciallntegrity TestU Location Clearance D Other: RECEIVED Subsequent Form Required: I 0 "L/ 0 4- BY ORDER OFDEC 172M3 'L/) r, a... Approved by: THE COMMISSION ~te: 'Uf'!!L I Jx'//J" .J Orlgina1 Slgnea ttY Alaska Oil & Gas Cons. Commission sarah Pe,~~f', Anchorage I~Bfl !jBl~. AL Form 10-403 Revised 2/2003 0 R \ G \ N RBllYt) SUBMIT IN DUPLICATE ( ( '" m~E= Ftv'C . TLBING KA.NGER Ftv'C/CArvERON BPSH @ WELLHEAD = CNV P 1 14 /' 35' MD. AClUA TOR = AXB...SON - KB. B...BI = 50' BF. B...EV = KOP= 1289' tv'ax Angle = 48 @ 6106' 2196' 4-112" CAtv'CO TRCF-4A SSSV, D = 3.812" Datum rvÐ = 11288' 4\ Datum lV 0 = 8800' SS ., GAS LIFT rv\I\ NDRELS 10-3/4" CSG, 45.5#, NT-80, 10 = 9.953" ST rvÐ lVD OBI TYPE VLV LATCH PORT CV\ lE 1 4726 4141 44 KBMG BK2 2 10459 8260 44 KBMG BKE 4-112" PARKERSWS NIP, 10 = 3.813" Minimum ID = 3.725" @ 10603' 4-1/2" OTIS XN NIPPLE 7-5/8"X4-1/2"BAKERSABL-3A<R,ID=4.00" 1 0586' -1 4-1/2" PA RKER SWS NIP, 10 = 3.813" I 4-112" OTIS XN NIP, 10 = 3.725" I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf ,10 = 3.958" I 4-1/2" TT, WLEG, 10 = 4.00" ELMO TT LOGGED 05/12/93 PERFORATION SUMI\MRY RB= LOG: DLLlM...L ON 03/6/93 ANGLEA TTOP PERF: 45 @ 11162' f\bte: Refer to R'oducton œ for historical perf data SIZ E SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 11162-11172 0 05/15/93 3-3/8" 4 11210-11296 0 05/15/93 3-318" 4 11313-11343 0 05/15/93 3-3/8" 4 11359-11574 0 05/15/93 I PBTD I I 7-5/8" CSG, 29.7#, NT95, 10 = 6.875" I 11760' DA lE REV BY COMM8\lTS DA lE RBI BY COrvTvlENTS POINT tv'CINTYRE UNrr 05/15/93 ORIGINAL COMR...E1l0N WELL: P1-14 01/17/01 SIS-Is I CONVERlED TO CANV AS PERMIT f\b: 93-016 02/20/01 SIS-rvD FINAL AR No: 50-029-22338-00 08/12/01 RN/lP CORRECTIONS Sec. 16, T12N, R14E, 1611.16FEL4096.34 FNL BP Exploration (Alas ka) ~' STATE OF ALASKA / ALAS~,, OIL AND GAS CONSERVATION C0~...,~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr-] Suspend['-] Operation Shutdownr-1 Perforate[~ Variancer'l Annuar Disposal[-1 After CasinclD Repair Well['-] Plu.a Perforations[~] Stimulate[~] Time ExtensionD Other[] Change Approved Program[--] Pull Tubingrl Perforate New Pool~-'l Re-enter Suspended Wellr-~ TAG TOTAL DEPTH 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development r-] ExploratoryF1 193-016 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r-~ Service [ 50-029-22338-00-00 7. KB Elevation (ft): 9. Well Name and Number: 35.00 P1-14 8. Property Designation: 10. Field/Pool(s): ADL 034622 Prudhoe Bay Field ! Point Mclntyre Oil Pool 11. Present Well Condition Summary: Total Depth measured 11768 feet true vertical 9188 feet Plugs (measured) Effective Depth measured 11638 feet Junk (measured) true vertical 9097 feet Casing Length Size MD TVD Burst Collapse Conductor 76' 20" 117' 117' 40K 520 Surface 3873' 10-3/4" 3914' 3552' 80K 2480 Production 11721' 7-5/8" 11761' 9187' 80K 4790 Perforation depth: Measured depth: Open Perfs 11162'-11172', 11210'-11296', 11313'-11343', 11359'-11574'. '. ,, . True vertical depth: Open Perfs 8761'-8768', 8795'-8856', 8868'-8889', 8900'-9Q52'. Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 10625'. - ..... .... Packers'& SSSV (type & measured depth) 7-5/8"x4-1/2" BAKER SABL-3 PKR @ 10554'. ........... 4-1/2" Camco TRCF-4A SSSV @ 2196'. 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-Mcr Water-Bbl Casing Pressure Tubin~ Pressure Prior to well operation: 47941 3526 Subsequent to operation: 48549 3521 14. Attachments: 15. Well Class after proposed work: Exploratory[~ Development[~ Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oill-"l Gas[--I WAG[] GINJ[--I WlNJ[--I WDSPLr-'I Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeWar, ne R. Schnorr Title Techical Assistant Signature .,,~,z~,~>.~..~~,~.~.~ Phone 907/564-5174 Date Sept24,2003 Form 10-404 Revised 2/2003 CJRIGINAL P1-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/15/2003 PERFORATTNG: DRTFT/TAG 06/16/2003 PERFORATING: PERFORAT'I'NG 09/22/2003 TESTEVENT--- INJECTION PRESSURE, PSI: 3,552 PS! VOLUME: 49,165 MSCFPD. TYPE: MI EVENT SUMMARY 06/15/03 FOUND WELL ON INJECTION ARRIVAL. RIH W/3 3/8 DUMMY GUN, TEL, 1.75 SAMPLE BAILER TO 9600' SLM. PICK UP WEIGHT-950# (.108 WIRE). DISCUSS W/BP REP. DECISION MADE TO POOH @ CHANGE TO .125 WIRE. HUNG UP IN SSSV. HAD TO PRESSURE SSSV UP TO 6500# BEFORE BEING ABLE TO PULL THROUGH. RIG DOWN. SWAP UNITS FOR MAINTENANCE. BEGIN RIGGING UP SPARE UNIT W/.125 WIRE. 06/16/03 RAN 3-3/8" DMY GUN, W/TEL & 1.75" SAMPLE BAILER. (EOT @ 10,590' SLM - ELMD-10,614, CORRECTION-24'). (TAG BOTTOM @ 11,614' SLM + 24' = 11,638' CORRECTED DEPTH) <<< TARGET = 11665' >>> (SAMPLE IN BAILER LOOKED LIKE BLACK DRILLING MUD). <<< DSO TO PUT WELL BACK ON INJECTION O9/22/O3 TESTEVENT--- INJECTION PRESSURE, PSI: 3,552 PSI , VOLUME: 49,165 MSCFPD. TYPE: MI FLUIDS PUMPED BBLS 2 IPUMPED DIESEL FOR PRESSURE TEST. (2 TESTS) Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU- Tom Maunder P.I. Supervisor FROM: Jeff Jones TO: Camille O. Taylor ¢ DATE: Chair SUBJECT: Petroleum Inspector NON- CONFIDENTIAL July 2, 2002 Mechanical Integrity Tests BPX Pt. Mac 1 P1-14, 16, 21, 25 PBU Pt. Maclntyre Field I Packer Depth Pretest Initial 15 Min. 30 Min. I.. Well, P1-14 JTypelnj., S , T.V.D. , 8321, Tubing, 2350 , 2350 , 2350 , 2350 ,IntervalJ 4 P.T.D.I !930160,TypetestI P" 'lTestpgil 2080 .I Casing I. Zero I 21401 21401 21001 P/F I P Notes: Pre-test pressures monitored 15 min. & stable. Well} P1-16 JTypelnj.] S I T.V.D: J .8774 J TubingJ 18'50 ! 1825 } 1830 J 1830 I!nterval} 4. I P.T.D.I 1930340 ITypetestl P ITestpsil 2194 I CasingI zero I 224o I 2240122101 PIE I P I Notes: Pre-test Pressures monitored 15 min. & stable. - I We,,I P1-21 I Type,nj.I S I T.V.D. 18676 I mubing11850 I' 4850 14850 14850 [IntervalI 4 P.T.D.I 1930590 Imypetestl P ITestpsiI 2169 I CasingIzero I 238°1~235° I 23501 P/F I -P' i Notes: Pre-test pressures monitored 15 min.& stable. ' we,,I P1-25 Type,nj.I S I T.V.D. 18751 I Tubingl 400 I' '380 I 380 I 380 I lntervall 4 I P.T..D.I 1890410 TyPetestI P ITestpsil 2188 I Casingl 200 I 2280 I 2265 I 2265 I P/F I P ! Notes: Pre-test pressures monitored 15 min. & stable. I F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details July ~ 2002: I traveled to BPX's PM-1 Pad to witness 4 year MIT's on water injection wells Pl-14, Pl-16, P1-21 and P1- 25 in the Pt. MacIntyre Field. Roland Johnson was the BPX representative in charge of testing today and he performed the task in a safe and proficient manner. The pre-test pressures were monitored for 15 min. and were found to be stable. The standard annulus pressure test was then performed on each well, with all four wells passing the MITs. Summary.: I witnessed successful MIT's on BPX's water injection wells Pl-14, Pl-16, P1-21 and P1-25 in the Pt. MacIntyre Field, PBU. M.I.T.'s performed: 4_ Number of Failures: 0_ Total Time during tests: 5_ AttachmentS: cc: SCANNED AUG 0 [ 200?_ MIT report form 5/12/00 L.G. MIT PBU Pt Mac 1-14,16,21,25 7-2-02 JJl.xls 7/18/2002 PERMIT 93-016 93-016 93-016 93-016 93-0i6 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-016 93-0i6 93-016 93-016 93-016 93-016 93-016 93-016 _ AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS RUN 5586 5587 5672 DRY DITCH 407 DWOP SURVEY SURVEY BHP CDN CDN CDR CDR /T 8350-11755 DLL/MLL/CN/ZDL 1 ~/T 9197-11766 CDN/CDR EDIT 1 ~ 9197-11766 CDN/CDR/ENHN R 1 ~ 9360-11768 SS#880 ~'COMP DATE:05/15/93 ~/R 02/19-03/11/93 '~350-11768 ANADRILL R ~ 350-11768 ANADRILL ~q~' 11728-11765 9350-11765 FIELD PRINT 9350-11765 TVD 9350-11765 VERY ENHANCED ~L 9350-11765 TVD COMP COMP CDR DLL/MLL/GR/CAL ~ 8350-11755 EPM ~' 7700-11768 MUD ~L 7740-11768 MD MUD ~L/'6259-9188 TVD PDT ~6250-9250 PERF/JEWL/GR/CCL~ 10300-11634 SBT/GR/CCL L./L 10000-11659 SPIN/TEMP/PRESS ~/11050-11624 SSTVD ~' 8350-11755 ZDL/CNL/GR/CAL ~/L 8350-11705 DISKETTE ~/D MWD SURVEY FINAL COMP COMP 9300-11700 DEPTH CORRECTE COMP Page: Date: 1 01/13/95 DATE_RECVD 04/14/93 04/14/93 06/07/93 03/23/93 06/09/93 06/09/93 04/14/93 06/09/93 04/14/93 04/14/93 04/14/93 04/14/93 04/14/93 06/07/93 04/14/93 08/23/93 08/23/93 08/23/93 08/23/93 06/07/93 04/14/93 09/29/94 04/14/93 04/14/93 04/14/93 AOGCC Individual Well Geological Materials inventory Page: 2 Date: 01/13/95 PERMIT DATA T DATA_PLUS RUN DATE_RECVD .Are dry ditch samples required? yes n~ And received? %yes) no Was the well cored? yes ~-~3 Analysis & description received?.~_-----~yes no Are weli tests required? ~sk~/~ Received~ ...... no Well is in compliance Initial COMMENTS ARCO Alaska Inc. ""~ Greater Point McIntyre Engineering Date: Subject: From: September 29, 1994 Transmittal Number ARCO Alaska, Inc. 745 To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed. and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description Run # L3-01 ....Tubing Puncher Record t~q' 1 '1 .~~"~ RAB-Final ~L) ~ Z~Bit and Ring Resistivity ~ ~DR-Final . CI~R-Very Enhanced Resistivity-Ga~a Ray ~, ~rue Vertical Depth CDR-F~al ~~jection Profile Log (Press-Temp-SP~-GR) 1 1 ~jection Profile Log (Press-Temp-SP~-GR) 1 ~6 Perforation Record 23/~" Phased E~ 6 SPF ~-07. Perfo?~g Recora wi~ GR/CCL Jewe~ Log 1 Perfora~on Record 3-3/8" HSD 41B ~ 6 SPF 1 _~2-18/ Perfora~g Record wi~ GR/CCL Jewe~ Log 1 ~2-18 . Static Pressure Survey-Press-Temp ~2-21 Perfora~on Record 3-3/s HSD 4lB ~ 6 SPF 1 Tr~ttal Nmber: 745 Page: 1 This information is confidential Date Run 9/6/94 Company Schlumberger 1-12 3/6/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 8/23/94 8/23/94 7/27194 7/27/94 7/21/94 7125194 7/25/94 7/22/94 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging _ Perforate __ 2. Name of Operator ARCO Alaska, Inc. Pull tubing __ Alter casing __ Repair well _ 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1413' NSL, 823' WEL, Sec. 16, T12N, R14E At top of production interval 832' NSL, 1920' WEL, Sec. 10, T12N, R14E At effective depth 832' NSL, 1920' WEL, Sec. 10, T12N, R14E At total depth 1185' NSL, 1622' WI:L, Sec. 10, T12N, R14E 12. Present well condition summary Total Depth: measured: true vertical: Other X 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB=35' 7. Unit or Property name Point Mclntyre 8. Well number P1-14 9. Permit number/approval number 93-16 /94-152 10. APl number 50-029-22338-00 11. Field/Pool Prudhoe Bay / Point Mclntyre 11768 feet Plugs (measured) None. 91 88 feet f,~et Effective Depth: Casing Conductor Surface Intermediate measured: true vertical: Length Size 76' 20" 3873' 10-3/4 11721' 7-s/8'' 11680 feet Junk (measured) None. 9126 feet Cemented Measured depth 81 cuft Arcticset 76' 2604 cuft PF "F"/464 cu 3914' Ft Class "G" 493 cuft Class "G" 11 761' True vertical depth 76' 3552 9187 Liner Perforation depth: measured 11162-11172', 11210-11296', 11313-11343', 11359-11574' true vertical 8760-8767', 8794-8855', 8867-8888', 8899-9051' Tubing (size, grade, and measured depth) 4-1/2'' 12.6# L80 @ 10625' Packers and SSSV (type and measured depth) Pkr. @ 10554', TRCF-4A SSSV @ 2196' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A Gas Cons. Commission Anchor~..,e 141 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11536 23599 357 1500 8800 Subsequent to operation n/a n/a 7462 20 9401 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations __X Oil__ Gas ___ Suspended Service X 17. I hereby certify that the f~oing~ ~- ,.~,,~ I/i*s true ar/~correct to the best of my knowledge. Signed Even L. Reel (~~/~..¢...~¢,x, Title~ Engineer Date September 22, 1994 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLI,~ATE Pl-14 Daily Report of Well Operations 06/19/94 07/09/94 07/15/94 PASSED STATE WITNESSED MIT TEST IN PREP FOR WATER INJECTION CONVERSION. 4901 VECO INSTALLING FLOW TOTALIZERS FOR WELLS P1-14,16,21. Pl-14 SI @ 2120 HR PUMPED PANEL UP, 5000 PSI 07/16/94 11-14 CHRIS SHOT FLUID LEVEL Pl-14, 16 AND 21 PROD HEADERS WERE CONVERTED TO SWI. SWI HEADER AND SPOOLS PRESSURE TESTED. 2500 PSI ON HEADER. P1-17 PANEL DUMPED. SSSV MOST LIKELY CLOSED ON P1-04 & 14. NEED TO HAVE ANCH CONVERT P1-14, 16 AND 21 TO SWI. 07/21/94 07/23~94 P1-14,16 & 21 WATER METERS SEEM TO BE WORKING & LPP'S SET @ 75 PSIG WERE INSTALLED ON DOWNCOMERS... Pl-14 START WATER INJECTION. P1-14,16 & P1-21 ARE ALL INJECTING WATER, RATES ON 14 & 16 ARE NOT MAKING IT TO SETCIM, FLOYD CHECKED IT OUT & SEEMS TO BE RALPH'S PROBLEM... RECEIVED S EP 2 7 199~. Ai~ska 0il & Gas Cons. Commission Anchor; ? T O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION INJECTION W~LL MECHANICAL BITE(]IRITY TE~T' OPERATOR: ARCO ALASKA INC. LISBURHE, POINT MCINTYRE AND WEST BEACH .... M,NmiUM PRE mT IWnAL' 1;UmUTE ~0 ~E "' ~E REQUmED ~ ~a ~Bm ~ PASS WELL INJ ~~ PACKER CAGING T~ ~ ~ CA~G CA~Q CA~G CA~G TEST START ~E F~m mi ~ID ~D SI~EIGHTmRA~ g~ PRES~RE DATE m~URE ~SSU~ PRE~ ~RE ~ :OMMENT: INJECTIQH WELL TYPE: ANNULAR RUlE GRADIENT: DISTRIBUTION: .T ,:~ Lid.ffnE~ Mdnlym FiddEn~ (Pti8 4~. ~ Sea We~e~ DIESEL . ~- _, P Pmd~ Wahl' SALT WATEPl. , J.L. ~ (ATO.4O~ M ~ Inlecikm ORII I lNG MU0 . ~. K ~ (ATO.4~) / Wd Fie ~) WELL STATU~ I On lr48c~n D~m~ MIT N! Not On In~eflion Outing MIT S EP 2 7 994 A!aska 0ii & t3as Con~, Commission ' Anchor~,,.~e 9f17,'99 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Chan~le approved pro~Iram x 2. Name of Operator ARCO Alaska, Inc. Suspended Operation Shutdown Re-enter suspended well Repair well __ Plugging __ Time extension __ Stimulate Pull tubin~l Variance __ Perforate __ Other __ 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at sudace 1413' NSL, 823' WEL, Sec. 16, T12N, R14E At top of production interval 832' NSL, 1920' WEL, Sec. 10, T12N, R14E At effective depth 832' NSL, 1920' WEL, Sec. 10, T12N, R14E At total depth 1185' NSL, 1622' WEL, Sec. 10, T12N, R14E 5. Type of Well: Development __ Exploratory ~ Stratigraphic __ Service ~x ORIG hiAL 6. Datum elevation (DF or KB) RKB=35' 7. unit or Property name Point Mclntyre feet 8. Well number P1-14 9. Permit number 93-16 10. APl number 50-029-22338-00 11. Field/Pool Prudhoe Bay / Point Mclntyre 12. Present well condition summary Total Depth: measured' true vertical: 11768 feet 9188 feet Plugs (measured) None. Effective Depth: measured: 11680 feet true vertical: 9126 feet Casing Le ng th Size Cemented Conductor 76' 20" 81 cu ft Arcticset 3873' 10-3/4'' 2604 cu ft PF "F"/464 cu Surface Ft Class "G" Intermediate 11721' 7-5/8'' 493 cu ft Class "G" Junk (measured) None. Measured depth 76' 3914' 11761' True vertical depth 76' 3552 9187 Liner Perforation depth: measured 11162-11172', 11210-11296', 11313-11343', 11359-11574' true vertical 8760-8767', 8794-8855', 8867-8888', 8899-9051' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L80 @ 10625' Packers and SSSV (type and measured depth) Pkr. @ 10554', TRCF-4A SSSV @ 2196' RECEIVED JUN 1 1994 AIr, ska. 0il & Gas Cons. Oommis,, Anchorage 3. Attachments Description summary of proposal ~ Convert well from Oil Production to Water Injection. 4. Estimated date for commencing operation June 27, 1994 6. If proposal was verbally approved Detailed operation program __ Name of approver Date approved 7. I .~r~J~ c~tif/~at the/toregoing is true and correct to the best of my knowledge. · a S. Wylie Title GPMA Sr. Engineer BOP sketch I15. Status of well classification as: Oil __ Gas Suspended Service Water Injector FOR COMMISSION USE ONLY 'conditiOns of approval: Notify Commission so representative may witness Date Plug integrity __ BOP test Mechanical Integrity Test Location clearance __ Subsequent for required onginal Signed By .... ~ Ell VVl il lV~Vii Approved b.v order of the Commission Commissioner J Approv~i~ No. on Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Point Mclntyre Pl-14 ARCO Alaska requests approval to convert Well Pl-14 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order 4A. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 11162' and 11574' measured depths This interval correlates with the strata found in ARCO's Point Mclntyre Well No. 11 between the measured depths of 9908' - 10665' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. gas G0ns. G0rnrnissi0~ ^nch0rafle ARCO Alaska, Inc. Isburne/Point Mclntyre Engineex Date: Subject: From: To: August 19, 1993 Transmittal #350 ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point Mclntyre data are enclosed. "' ..~ .~. ~,~ This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title 1blue line, 1 sepia Pl-Gl~Perforating Record Run # Run Date 7/4/93 Company Schlumberger Pl-04 -'Z-Densilog Compensated Neutron -GR P1-04-'Dual Laterolog, GR / SP ;?cSt' P1-04-- Borehole Profile P1-04--Sub-Sea Vertical Depth (Single Shot Data) g,t" !P1-04.~Cement Bond Log q' P1-04-'Cement Evaluation Log (CET) P1-04-Gyro Continuous Survey (GCT) 5/22/93 Altas 5/22/93 Arias 5/22/93 Arias 5/22/93 Atlas 6/12/93 Schlumberger 6/12/93 Schlumberger 7/28/93 Schlumberger P1-05,-Segmented Bond Log, Gamma Ray-CCL P1-05-, Cement Bond Log-CBT w/Jewelry P1-05-* Cement Evaluation Log-CET w/Jewelry P1-05- Gyro Continuous Survey -GCT I 7/11/93 I 8/12/93 1 8/12/93 I 8/12/93 Atlas Schlumberger Schlumberger Schlumberger Pl-13-'1Neutron Poro, Density Poro, GR -MD Pl-13--Neutron Poro, Density Poro, GR -TVD P1-13--Dual Prop Resis, GR -MD x~ P1-13 ~,'Dual Prop Resis, GR -TVD 2~°' 5-7 6/2-6/93 5-7 6/2-6/93 5-7 6/2-6/93 5-7 6/2-6/93 :P1-13 -Dens Poro, Neu Poro, Dual Prop Resis, GR-MD 5-72'~ 6/2-6/93 Pl-13 ~Dens Poro, Neu Poro, Dual Prop Resis, GR-TVD 5-7 2.~ 6/2-6/93 'Pl-13 ~,Bulk Density, Gamma Ray-MD ~" 5-7 6/2-6/93 BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes Pl-14-' Engineering Parameters P1-14" Pressure Data Log P1-14--Formation Evaluation MD P1-14-Formation Evaluation TVD - 2126-316/93 - 2126-316/93 - 2126-316/93 - 2/26-3/6/93 Exlog Exlog BakerHughes BakerHughes PLEASE SIGN ONE COPY AND RETURN Transmittal #350 (AOGCC) Log (contd.) Well Title 1blue line, 1 sepia Pl-16-' Engineering Parameters MD % PI-16 ''~ Pressure Data Log ~Pl-16~Formation Evaluation MD ~Pl-16,.-Formation Evaluation TVD Run. # Pl-t7-Bulk Density -Gamma Ray -MD 5~' 5,5RR Pl-17-Dual Prop Resis -GR-MD 2~5" 5,5RR Pt-17.-'Dual Prop Resis -GR-TVD ~*5 * 5,5RR Pl-17--Dens Poro, Neutron Poro -GR -MD %-1~~' 5,5RR Pl-17.~ Dens Poro, Neutron Poro -GR -TVD 1,*5 u 5,SRR Pl-17-'~sPoro, NeuPoro, DualProp, Resis-GR-MD 2~" 5,5RR P1-t7- [~2sPoro, NeuPoro, DualProp, Resis-GR-TVD 2-~" 5,SRR Run iDate 3/19-28/93 3/19-28/93 3/19-28/93 3/19-28/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 Page 2 Company Exlog Exlog BakerHughes BakerHughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Diskette/Tape (w/verification) Well Title Run # q'5-bS/Pl-04 \P1-04 P1-13 I21-16 Final MWD Survey bl~. DLL/CN/ZDL/GR in LDWG Format l~k ~79¢ Final MWD Survey b~:~ Dual Prop Resis, Neutron, Density, q%..c~k P1-17 Dual Prop Resis, Neu, Dens, GR -Depth Shifted iSRR ~ G'TqU~ o~ Run Date 5/24/93 5/22/93 6/11/93 3/2.9/93 4/16/93 Company BakerHughes Atlas Sperry Sun BakerHughes BakerHughes Please sign ___ and return to' Transmittal #350 Laura S. Lahrson, ATO--409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN STATE OF ALASKA ALASI'O-, OIL AND GAS CONSERVATION C~,MMISSION WELL COMPLETION OR RI:COMP LETION REPORT AND LOG ,, 1. Status of Well Classification of Service Well , OIL I~ GAS [] SUSPEt,,DED E] ABANDONED [] SERVICE [] X Comnleted 2. Name o! Operator 7. Permit Number ARCO Alaska,. Inc. 93-16 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 so. 029-22338 4.1413'NsL,L°cation of wel1823,atWEL,SUrfaCeSEC. 16, T12N, R14E ? :~'i''' ' ~ t '"; ,~'4'7£ , ,. ..... : ...... : t0. Well Number 832'NSL, 1920'WEL, SEC. 10, T12N, R14E ~ At Tota~ Depth :- · :.-;~ Point Mclntyre 1185'NSL, 1622'WEL, SEC. 10, T12N, R14E s. Elevation in teel (indicate KB, 'DF, etc.) 16. Lease Designation and Serial No. KBE = 50' I ADL 34622 12. Date Spudded 13. Da~e T.D. Reached i4. Date Comp., Susp. or Aband. 115. 'Water Depth, it offshore 116. No. ol Completions 2/19/93 3/5/93 5/15/93! N/A leer MSL I One 17. Total Depth (MD.~TVD) 18. Plug Back Depth (MD+TVD)lg. Directional Survey ~)0. Deplh where SSSV set J21, Thickness of Permalrosl 11768' MD/9188' TVD 11680' MD~9 126' TVD YES [] N~ []! 2196' feet MD ! 1750' (Approx.) 22. Type Electric or Olher Logs Run GRICN/ZDL/TEMP/DLIJMLL 23. CASING, LINER AND CEMENTING REC, OF~ · SETTING DEPTH MD CASING SEE WT. PER FT. GRADE TOP BOI'rOM HOLE SIZE CEMB, mr,~ RECORD AMOUNT PULLED 20" 94It NT6OLE Surface 76' 30" 81 cuft Arcticset 10-3/4" 45.511 N TSOLHE 41' 3914' 13-1/'2" 2604 cufl PF "F"/464 cuft Class '12" 7-5/8" 29. 7tt NT95HS 40' 11761' 9-7/8" 493 cuft Class "G" 24. Perforations open Io Production (MD+TVD of Top and Botlom and 25. TUBlYG RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter3-3/8" 4 spf 4-1/2" 10625' 10554' MD TVD 11162'-11172' 8760'8767' 11210'-11296' 8794'-8855' 26. ACID, FRACTURE, CEMENT SOUEF71=. ETC. 11313'-11343' 8867'-8888' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ' 11359'-11574' 8899'-9051' ,27. PRODUCTION TEST Date First Production IMethod ol Operation (Flowing, gas lilt, etc.) Not on production ! N/A Date ct Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IG/~S--OIL RATIO 1'EST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Briel description ol lithology, porosity, lraclures, apparenl dips, and Presence of oil, gas or water. Submil core chips. REEEiVED JUN - 9 199~ Alaska 0il & 6as Cons, .C0mmissi0~ ~chorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ,,. / '~ 30. GE)LOGIC MARKER~ /:{MAT~ TESTS NAME .. Include interval tested, pressure data, all llulds recovered and gravity, MEAS. DEPTH TRUE VERT. DEFTH GOR, and time o! each phase. .......... s~bsea West Sak 8391' 6692' Kalubik 11074' 8647' Kuparuk 11115' 8676' RECEIVED :11. LIST OF ATTACHMENTS J U N 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Anchorage ~7~:~/' .~F,~ //~,~:~I-/~tI Title DrillinaEnoineerSuoervi$or Dale ~/Z~//~,7 Signed /~/ ,f ...... ~,1 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: Pl-14 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/18/93 10:00 SPUD: 02/19/93 11:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 02/19/93 (1) TD: 110' ( 110) 02/20/93 (2) TD: 815' ( 705) 02/21/93 ( 3) TD: 3016'(2201) 02/22/93 ( 4) TD: 3920' ( 904) 02/23/93 (5) TD: 3920' ( 0) 02/24/93 (6) TD: 5300' (1380) 02/25/93 (7) TD: 6459' (1159) 02/26/93 (8) TD: 7643' (1184) 02/27/93 (9) TD: 8134' ( 491) 02/28/93 (10) TD: 9345' (1211) WAIT ON WELLHEAD. MW: 8.5 VIS: 0 MOVE RIG. RIG ACCEPTED @ 22:00 HRS, 2/19/93. N/U DIVERTER. WELD START HEAD. M/U BHA. DRLG. MW: 8.8 VIS:128 N/U DIVERTER. M/U BHA. TEST DIVERTER. RIH. SPUD WELL @ 23:00 HRS, 2/19/93. DRLG F/ 110'-815'. REPAIR TOP DRIVE. MW: 9.2 VIS: 93 DRLG F/ 815'-2465' SHORT TRIP TO BIT. DRLG F/ 2465'-3016' REPAIR TOP DRIVE. R/U TO RUN CSG. MW: 9.5 VIS: 79 REPAIR TOP DRIVE. DRLG F/ 3016'-3920' CBU. SHORT TRIP TO BIT. REAM F/ 2840'-2900' CIRC. SHORT TRIP TO 2750'. CBU. POOH. RIH W/ 10-3/4" CSG. TEST BOPE. MW: 8.5 VIS: 0 RIH W/ 10-3/4" CSG TO 3914' CIRC. CMT CSG. N/D DIVERTER. TOP JOB W/ 250 SX 'C' CMT. N/U BOPE. TEST BOPE. DRLG. MW: 9.0 VIS: 41 TEST BOPE. RIH W/ BHA. CIRC. TEST CSG. OK. DRLG CMT PLUG, FLOAT EQUIP TO 3930' CIRC. LOT (12.8 PPG EMW) . CIRC. DRLG F/ 3930'-5300' RIH. MW: 9.4 VIS: 50 DRLG F/ 5338'-5431'.CBU. SHORT TRIP TO SHOE. DRLG F/ 5431'-6459'. CIRC. POOH. CHANGE BIT. RIH. POOH. MW: 9.5 VIS: 52 RIH. REAM F/ 5993'-6182'. REAM 90' TO BTM. DRLG F/ 6459'-7480'. CIRC. 10 STDS SHORT TRIP. DRLG F/ 7480'-76433'. CIRC. POOH. DRLG. MW: 9.6 VIS: 49 POOH. CHANGE BIT. RIH. REAM 90' TO BTM. DRLG F/ 7643'-8134' CIRC. POOH. CHANGE BIT. RIH. DRLG. MW: 9.6 VIS: 60 RIH. REAM 90' TO BTM. DRLG F/ 8134'-9280' ECEJV D J UN - 9 199 ,Alasl~a 011 & 6as Cons. WELL : Pl-14 OPERATION: RIG : POOL 7 PAGE: 2 03/01/93 (11) TD: 9665' ( 320) 03/02/93 (12) TD:ll000' (1335) 03/03/93 (13) TD:l1530' ( 530) 03/04/93 (14) TD:l1580' ( 50) 03/05/93 (15) TD:11745' ( 165) 03/06/93 (16) TD:11768' ( 23) 03/07/93 (17) TD:11768 - PB: 0 DRLG. DRLG F/ 9345'-9349' REAM F/ 8003'-8098' MW: 9.7 VIS: 60 CBU. POOH. CHANGE BIT, MOTOR. RIH. RIH. DRLG F/ 9349'-9665'. DRLG. MW: 9.7 VIS: 57 DRLG F/ 9665'-10422'. CIRC. SHORT TRIP 12 STDS. DRLG F/ 10422'-10558'. LOST PUMP PRESSURE. POOH FOR WASHOUT. FOUND HOLE. RIH. DRLG F/ 10558'-11000' DRLG. DRLG F/ 11000'-11072' 11072'-11530'. MW: 9.9 VIS: 55 CBU. SHORT TRIP. DRLG F/ DRLG. MW:10.0 VIS: 58 DRLG F/ 11530'-11559'. CIRC. POOH. L/D MTR, MWD. TEST BOPE. RIH. REAM 200' TO BTM. DRLG F/ 11559'-11580' DRLG. MW:10.0 VIS: 51 DRLG F/ 11580'-11647'. CIRC. POOH. CHANGE BIT. RIH. REAM & MAD LOG RUN F/ 11540'-11647' DRLG F/ 11647'-11745' RIH. MW:10.1 VIS: 55 DRLG F/ 11755'-11768'. SHORT TRIP 15 STDS. CIRC. POOH. L/D BHA. R/U ATLAS. LOG RUN: GR/CN/ZDL/TEMP/DLL/MLL. RIH W/ WIPER TRIP. RIH W/ CSG. MW:10.1 KCl P/U BHA. RIH. CIRC. POOH. TEST BOPE. L/D BHA. RIH W/ 7-5/8" CSG. 03/08/93 (18) TD:11768 PB: 0 03/09/93 (19) TD:11768 PB:l1680 RIH. MW: 8.5 Seawater RIH W/ 7-5/8" CSG. CIRC. CMT CSG. DISP W/ SEAWATER. BUMP PLUG W/ 2000 PSI. R/D CMT EQUIP. INSTALL PACKOFF. TEST SAME. TEST BOPE. RIH W/ BIT, CSG SCRAPER. POOH. P/U DP. RIH TO 10000' CIRC. POOH. MW: 8.5 Seawater REV CIRC. RIH. TEST CSG. REV 03/10/93 (20) TD:11768 PB:l1680 RIH W/ TBG. MW: 8.5 Seawater POOH. L/D DP. R/U ATLAS. RUN SBT (CBL). R/D ATLAS. RIH W/ 4-1/2" TBG, 7-5/8" BAKER 'SABL-3' PKR. RECEIVED J Ulq. - 9 199 Alaska Oil & Gas Cons. Anchorage WELL : Pl-14 OPERATION: RIG : POOL 7 PAGE: 3 03/11/93 (21) TD:11768 PB:l1680 RIG RELASED. MW: 8.5 Seawater RIH W/ 4-1/2" TBG. M/I HGR. LAND TBG. SET PKR W/ 4000 PSI. TEST TBG, ANNULUS. OK. L/D LAND JT. N/D BOPE. N/U TREE. TEST TREE. PUMP 95 BBLS DN ANNULUS. RIG RELEASED @ 23:00 HRS, 3/10/93. SIGNATURE: (drilling superintendent) DATE: PACE NO, SURVEY PROGRAM *********** COMPANY ARCO ALAS[A INC, WELL NAME P 1-14/G6 LOCATION ! M$~ COCA?ION 2 ALA~A ~AGN£TIC DECLINATIOH 30,11 WELL HEAD LOCATION: LAT(N!-$) 0,00 DEP(E/-W) AZIMUTH FROM ROTARY TA~L~ TO TARGET IS 42,44 TIE IN POINT(TIP) : HEASU£ED DEPTH 350,00 TRUE V~RT D£PTH 350,00 INCLINATION 0,0~ AZIMUTH 0,00 ~ATITUDE(H/-S) 0o0~ DEPARTURE(E/-W) 0,00 0,00 RECEIVED J UN - 9 199c3 Alaska Oil& Gas Cons. Commission Anchorage flEA3URED IN?ERVAL VERTICAL DEPTH DEPTH ft ft ft 350,00 0.0 350,00 389,01 39,0 389,01 477,52 88.5 477.52 565,58 88,! 565,56 654,56 89,0 654,41 SURVEY CALCULATIONS ~******~***** CIRCULAR ~RC METHOD**~**~* TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft den deo ft 0,00 0.00 0,00 0,00 -0,13 0,31 212,05 -0,11 0,10 0.69 12,93 0.21 1.95 1,84 54,24 1.55 6,53 4.17 32,02 5,13 DEPARTURE DISPLACEMENT at AZIMUTH E/'W ft ft de9 0,00 0,00 0,00 -0,07 0,13 212,05 -0.08 0,22 339.3~ 1,19 1,96 37,50 4.07 6,55 38,40 ~LS de9/ lOOft 0.00 0.63 1,12 1,5~ 2,88 .._ 747,37 8~9,91 927,40 1015.12 1107,50 1194,71 1289,14 1380~26 1471.00 1564,20 92.8 746,83 92,5 838,78 87,5 925,68 87.7 1012,83 92,4 1104.52 87.2 1190.72 94,4 1283,76 91.1 1373,54 90,7 1462,99 93,2 1554.87 14.80 6.28 29,60 12,41 8,37 14,96 33,99 2,28 24,96 6,71 27.50 21.60 13.36 25.40 31,73 0,53 34.72 6,55 27,52 30,56 18,03 35,48 30,53 0,I? 44.37 6.51 28,28 39.38 22.69 45.45 29.95 0,11 55,48 7,58 34,24 49.03 28,60 56,76 30,26 1,40 68,57 9.77 42,41 59,24 36,83 69.76 31,87 2,88 84.80 10.01 41,50 11,30 47,68 85,77 33,77 0,31 100.34 9.63 42,56 82,84 58.09 101,18 35.04 0,47 115,57 9.70 43,83 93,95 68,52 116,28 36,10 0,25 131,22 9.64 46,4d 105,00 79,63 131.78 27,17 0,48 1~54,63 1748,86 1840,48 1935,57 2028,92 90.4 1643,81 94,2 1735,86 91,6 1824,75 95,1 1916.32 93,3 2005,29 147,50 11.12 45,62 116,33 167,48 13,48 49,21 129.86 189.59 14,57 45,79 144,87 215,19 16,69 42.34 163.31 243,46 18,57 42,32 184,21 91.36 147.92 38,14 1.62 106,17 167.73 39,27 2,63 122,51 189.73 40,22 1,50 140,29 215,29 40.66 2.43 159,33 243,54 40,86 2,02 2117.70 2209,14 2305.0~ 2394,62 2490,15 88,8 2088,83 91,4 2173,86 95,9 2262,22 89,5 2343,50 95.5 2429.5e 273,46 20.94 45,02 205.89 3o7.1o 22.25 43,60 229,98 344,45 23.60 40.52 257,73 381,99 25.99 41,12 286,14 423,42 25,42 43,25 316,84 180.07 273,52 41,17 2.86 203,58 301,14 41,52 1,53 228,58 344,49 41.57 1,89 253,14 382,04 41,50 2,68 2~0,95 423,47 41,56 1,13 2581.01 2672,21 2764,00 2857,48 2946,18 3042.28 3135,41 3225.26 3316,49 3408,16 90,9 2510. 91.2 2590, 91.8 2668, 93,5 2745. 88,7 2818, 96.1 93,1 91.2 91.7 2896, 2971, 3043, 3113, 3181, 97 463,77 27,35 40,22 346,98 43 508.43 ~1,40 38,53 361.58 29 556,9d ' 32,58 39,28 419.41 92 608,88 35,11 37.54 460.22 33 659,95 35,44 38,30 500,63 62 715.59 35,44 40.45 543,70 90 770.36 36,68 39,46 585.73 10 825,12 38.49 40,89 627.5~ 09 883,63 41.32 44.36 670,61 44 944.63 42,25 46.05 712.63 307.79 463,83 41,57 2.58 336.13 508,52 41,38 4,53 366,68 557,10 41,I6 1.35 399,00 609,10 40,92 2,91 430,48 660,26 40,69 0,62 465,83 715.97 40.59 1,30 501.03 770,79 40,54 1,47 536,39 825,58 40,52 2,24 576,06 884.05 40,66 3,94 619,40 944,95 40.9~ 1,59 3500,35 35~1,74 36~3,61 3776,96 3850,31 92,2 91,4 91.9 93,3 73,4 3249, 3316, 3383, 3452, 3505, 45 1006.72 42,48 47,00 756,45 46 1068.67 43,00 46,52 799.02 78 1131.13 42.78 43,29 843,29 20 1194.59 42,96 45,14 858,80 59 1244.84 43,62 44,75 924,40 664,57 I006,91 41,30 0,84 709.84 1068,79 41,~2 0,50 753,97 1131,20 41,80 2.40 798,25 1194.64 41,93 1,36 833,78 1244,87 42,05 0,97 1-14/G6 MEASUR£D INTERVAL VERTICAL DEP?H DEPTH ft it ft 3966,37 116,1 3589,63 4057,23 90.9 3655,52 4247.14 189.9 3795,26 4338,01 90,9 3862,28 4427,10 89.1 3926.64 ANAP~ILL SURVEY CALCULATIONS CIRCULAR ARC TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft de9 deo ft 1324,85 43,60 44,13 981.56 1387,36 42,42 44,97 1026,14 1515,90 41,83 43,12 1118,53 1577.26 43.12 42.75 1163,46 1638.83 44.37 39.71 1209,78 DEPARTURE DISPLACEMENT at AZIMUTH £/'W ft ft deq 889,82 1324,86 42,19 933,71 1387,36 42,30 1023,15 1515,90 42,45 1064,94 1577,26 42,47 1105,52 1638,83 42,42 10Oft 0,37 0.68 1,07 1,45 2,74 4613,85 4798,79 4984,16 5170,93 5355.49 5545,72 5721.79 5917,19 6106,17 6293,54 186.8 4060.3~ 184,9 4192.88 185.4 4324.53 186,8 4453,63 184,6 4579.05 190,2 4709,17 186,1 4836,68 185,4 4962,62 189,0 5089,20 187.4 5216,20 1769,00 44,16 39,28 1310.37 1897,89 44,33 40,33 1409,49 2028,29 45.17 40.19 1509.08 2163,14 47,37 40.38 1612,02 2298,45 47,03 40.10 1715.38 2437,02 46,65 38,92 1822,42 2572,39 46,85 40,96 1926,31 2708,42 '. 47,61 44,99 2025,82 2848,70 4~.2f 42,92 2126.84 2~86,44 46,36 43,47 2227,27 I188,42 1769,01 42,21 0,20 1271,02 1897,93 42,04 0,41 1255,35 202~,37 41.93 0,46 1442,60 2163,26 41,83 1.18 1530,08 2298,63 41.73 0.21 1618,37 2437.28 41,61 0,49 1705,36 2572.73 41.52 0.80 179~.11 270~,72 41,59 1.65 1~95.50 2848.93 41,71 0.89 1989,79 2986,64 41,78 1,05 6478,98 6660,17 6845.08 7030,51 7221,22 185.4 5346,43 181.2 5475,4~ 184,9 5606,44 185.4 5739,54 190,7 5878.92 3118.35 44.41 45,09 2321.78 3245,39 44.78 45.82 2411,0I 3375,81 45,02 43.13 2504.14 3504.82 43,23 45,68 2596,39 3634.85 42.85 44,41 2688,35 2081.92 3118,50 41,88 1,22 2172,59 3245,48 42.02 0.35 2264,02 3375,87 42,12 1,03 2354,31 3504.85 42,20 1.36 2446.42 3~34.86 42,30 0,50 7401.41 7594.45 7781,85 7969,80 8155,10 180.2 6011,74 193,0 6154,95 187.4 6294,02 188,0 6432,63 185,3 6568,57 3756,56 42,23 35,75 2779,38 3885,66 41,98 37,88 2880,93 4011,00 42,21 39,35 2979,09 4137,82 42,75 40,62 3076,34 4263,59 42,87 38,70 3173,28 2527.24 3756,58 42.28 2,15 2607,48 3885.71 42,15 0.33 2685,88 4011,10 42.04 0.54 2767,45 4137,95 41,97 0,54 2847,81 4263,77 41,91 0,71 8342,40 8526,42 8712,79 8902.98 9085.30 187.3 6706.22 184.0 6841.96 186,4 6979.59 190.2 7118.68 182,3 7251.80 4390,35 42,52 3%07 3272,15 4514,35 42,42 38,49 3369,01 4639,72 42,38 38,66 3467,25 4769,31 43,64 41,37 3566,56 4893,87 42,57 43.54 365~,48 2927,54 4390.61 41,82 0.23 3005.36 4514,69 41,73 0,22 3083,71 4640,16 41,65 0,07 3167,14 4769,81 41,61 1,17 3251,20 4~94,37 41.63 1,00 9272,86 9487,00 9675,00 9861,27 10046,72 187,6 7391,64 214.1 7551.88 188.0 7690.93 186,3 7827.83 187,5 7~64,56 5018.85 41.02 41,2S 3750,73 5160,89 42,10 41,80 3857,05 5287.40 42,50 41.60 3951,52 5413,70 42,89 41,48 4046.06 5541,91 43,43 41,93 4141,79 3335.52 5019,34 41.65 1,15 3429,73 5161.39 41,64 0,53 3513,90 5287,91 41,65 0,22 3597,66 5414.22 41,64 0,21 3682,97 5542,45 41,64 0,33 10242,29 1042~,08 10606,46 10791,31 193.6 8104.38 179,8 8233,20 184,4 8364,41 I84,8 8495,68 189.3 8630,57 5675,78 44,04 42.20 4241.17 5801,19 44.39 41,76 4334,41 5930,72 44,8~ 41,67 4431,11 6060,85 44.63 42,02 4525,06 6193,68 44,49 41,75 4626,95 3772.66 5676,31 41,65 0,35 3~56,54 5801,73 41,66 0,~4 3942.73 5931,26 41,66 0,27 4029,56 6061,41 41,67 0,19 4118.24 6194.24 41,67 0,13 ~SUR~ INTERVAL V£RTIC~L DEPTH ~EPTH ft ft ft 11162°?7 182,3 8760,47 11352,82 189,9 8895,04 11539,73 186,9 9027,04 11768,00 ~-~I-14/G6 SUgUEY CALCULATION5 ?RggET STATION AZIMUTH SECTION INCLN, N/-$ ft deo deo ft 6321.64 44.66 41.47 4722,62 6455,52 45,06 40,71 4823.54 6587.71 45,08 39.14 4?25,02 PRDJ£CTED SURU£Y AT T~ LATITUDE ~EPARTURE DISPLACEM~HT at AZIMUTH E/-W ft 4203,23 4291,26 4376,18 ft deO 6322.21 41.67 6456,12 41,66 6588.38 41,62 228,3 71~8,19 6749,18 45,10 40,00 . 5049.64 4479,17 deq/ lOOft 0,14 0,36 0,59 6749,95 41.57 0.27 ,,me 4,1993 Page 2 Reports Well P2-55 P2-30 P1-11 ,~P2-48 P1-20 P2-51 k\ Pl-G1 Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Run Date 9/8-10/10/92 10/19-11/5/92 9/11-10/4/92 12/2-27/92 10/13-28/92 7/3-26/92 5/22-6/18/92 11/8-12/8/92 Company Exlog Exlog Exlog Exlog Exlog Exlog Exlog Exlog Please Formerly PM#3 Transmittal #326 and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN Date: Subject: From: To: ARCO Alaska, Inc. Lisburne/Point McIntyre Engineering June 4, 1993 Transmittal #326 ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Logs Well (one blueline, one sepia) [ ~'(P1-14 Perforating Record & Jewelry Log (GR/CCL) 1 \Pl-14' CDR Enhancement (LWD/Depth Corrected) 1 P1-02+ Production Profile Gamma Ray Survey 1 (~P1-G1 I P1-G1 kP1-G1 Integrated For~m. aJion Log-MD Integrated Formation Log-TVD Engineering Parameters Pressure Data Log ~o (P2-48 xP2-48 Integrated Formation Log-MD Integrated Formation Log-TVD Engineering Parameters Log Pressure Data Log Run # Run Date Company 5 / 1293 Schlumberger 3/5/93 Schlumberger 1/26/93 Camco 11/8-17/92 Exlog 11/8-17/92 Exlog 11/8-17/92 Exlog 11/8-17/92 Exlog 12/2-27/92 Exlog 12/2-27/92 Exlog 12/2-27/92 Exlog 12/2-27/92 Exlog Tapes w/Verification Listing Well ~.~ ~ ~ta'7l Run # t~3"'%~o PI-ll ~.~Edit- Bit Runs 1-7 in LDWG Format cmpst O~ Pl-14 ~)-Edit-CDN/CDR in LDWG Format & QRO 1 · '~ <~.a7.~ Run Date 10/3/92 03/05/93~ Company Schlumberger Schlumberger PLEASE SIGN ONE COPY AND RETURN Date: Subject: To: ARCO Alaska, Inc. ..isburne/Point McIntyre Engineer~- April 13, 1993 Transmittal #298, P1-14 ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre Well P1-14 data are enclosed. This information is confidential and your cooperation in maintaining confidentiali.ty is appreciated. RUn # TAPE/DISKETTE w/printout Log 1 blue line, 1 sepia v"LWD: CDR Very-Enhanced Resistivity (Field) cmpst LWD: CDR-TVD Very-Enhanced Resistivity (Field) cmpst I,"LWD: CDN (Field) cmpst LWD: CDN-TVD (Field) cmpst v'Segmented Bond Log / Gamma Ray/CCL 1 ~,'Z-Densilog Cmpnstd Neutron -GR 1 .,,'Borehole Profile 1 v<Sub-Sea Vertical Depth (Single-Shot Data) 1 V'Dual Laterolog / Micro Laterolog / GR / Caliper 1 Run # V'Final MWD Survey ¢{ ~ - ~' DLL/MLL/CN/ZDL/GR in LIS format o~' -kL ~ ~ 1 v/OH Edit: CDN/CDR in LDWG formato~Idr ~Sg7 1 Run Date 3/05/93 3/05/93 3/05/93 3/05/93 3/09/93 3/06/93 3/06/93 03/06/93 03/06/93 Run Date 3/02/93 3/06/93 3/05/93 Company Schlumberger Schlumberger Schlumbeger Schlumbeger Atlas Atlas Atlas Atlas Atlas Company Schlumberger Atlas Schlumberger RECEIVED APR 1 4 ~993 Transmi~/t~k#~ ,as Cons. C0mm/ss,0n ~cflorage Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: STATE of ALASKA OIL/GAS CON. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA OPERATOR: ARCO SAMPLE TYPE: DRIES DATE: 15TH MARCH, 1993 AIRBILL: 646220 AFT#: 3-03-15- CHARGE CODE: 2C0031 NAME: P1-14/G6 SAMPLES SENT: SET E DRY DITCH SAMPLES: 7740-9360 9360-10530 10530-11768 SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVlEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David Johnston_p..~/ date: Commissioner~-'~ file: thru: Blair E Wondzell ~jf~.l,~ subject: Sr Petr Engineer from: Bobby Foster Petr Inspector March 3, 1993 BOB02191.DOC Diverter Inspection Pool Arctic 7' ARCO - P.B.U. Pt. Mclntyre #P1-14 PTD #93-16 Friday, February 19, 1993: I traveled to ARCO's Pt. Mclntyre P1-14 and inspected the diverter system. The system was installed in accordance with AOGCC regulations and all items operated properly. The diverter system consisted of a 20" annular preventer and two 10" lines with 3 valves that can be opened or closed automatically depending on wind direction. SUMMARY: I inspected and witnessed'the function test of the diverter system on Pool Artic Rig 7. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report ~ t A~ ,~ Operation: Drlg Contractor: ~?C~.' [ /4~ ~'~ O Rig No. Operator: ~'~ ~_~'C~ .... per. Rep.: Well Name: ~i~ ~:~ ~ ~-~-~ ~ ~ ~/~// Rig Rep.: Location: Sec. "/~ .... ~'. f~/V/ R. / ~J ~' Development PDT # ~"~ ~ ~ Merdian / Exploratory: Rig Ph, # MISC. INSPECTIONS: Location Gen.: Housekeeping: Reserve Pit: ! /' DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: ??~ in. Vent Line(s) Length: o% ft. Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: .,,--' Turns Targeted / Long Radius: ACCUMULATOR SYSTEM: Well Sign: ~ Systems Pressure: (Gen.) Drlg. Rig:Pressure After Closure: Flare Pit: ~//~ 200 psi Attained After Closure: ~-' Systems Pressure Attained: Nitrogen Bottles: in. psig psig min. sec. min. sec. psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: Mud Pits: ~.~ Flow Monitor: GAS DETECTORS: Light Alarm Methane Hydrogen Sulfide: .,,-- Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector FI-022 OPERATOR REP.: Dvtrinsp2 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 February 3, 1993 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit P1-14 ARCO Alaska Inc 93-16 · 1413'NSL, 823'WEL, Sec 16, T12N, R14E, UM 1214'NSL, 1444'WEL, Sec 10, T12N, R14E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. ' Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the Surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl " ! STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-'lIlb. Type of well. Exploratoryr-1 Stratigraphic Testl-1 Development Oill~ Re-Entry [] DeepenI-!I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska,/nc. RTE(SS)-50'feet Prudhoe Bay Field/Prudhoe 3. Address 16. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 34622 -- 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^^c 25.025) 1413'NsL, 823'WEL, SEC. 16, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 901'NSL, 1732' WEL, SEC. 10, T12N, R14E P1-14 U-630610 At total depth 9. Approximate spud date Amount 1214' NSL, 1444' WEL, SEC. 10, T12N, R14E 2/5/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and mVD) property line . . ADL 28297-1214' lee[ P1-11-44' @ 450' MD feet 2560 11872' MD/9140' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth zoo'feet Maximum hole angle 45 o Maximum surface 3330pslg At total depth (TVD) ~O0'/4390pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of' cement Hole :..Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# NT6OLE Weld 76' Surface Surface 76' 76' 4 yds Arcticset 13-1/2" 10-3/4" 45.5¢ NT8OLHE B TC 3798' 41' 41' 3910' 3500' 2483 CUft PF "E"/406 cuft PF "C" 9-7/8" 7-5/8" 29.7# NT95HS NSCC 11831' 41' 41' 11872' 9140' 493 cu ft Class "G" 119. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production ,j ~I\l ~ ~' Liner Perforation depth: measured Alaska 0il & Gas Cons. true vertical 'Anch0rag~: 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid pro,fram [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify~hat~t.i~., forego~ ~s true and correct to the best of my knowledge Signed ,[/'~ -~~ (~L~ Title Drilling Engineer Supervisor Date /" "~'~'-~,~ ~ ~ Commission Use Only Permit Number IAPI number IApproval date~ ISee cover letter ¢315 0- o ~ ~-, ~-~ ~_ 3 3 ~ J ¢h2 _.,..,,4-- ~ .~ Jfor other requirements Conditions of approval Samples required [] Yes '~'NO Mud log required []Yes ~No Hydrogen sulfide measures [] Yes ,~ No Directional survey reqmrea ~ Yes [] NO Required working pressure for BOPE [] 2M; []3M; J~5M; F11OM; i-115M; Other: Original by order of Signed By Approved by Commissioner ,ne comm,ssion Form 10-401 Rev."'"f2'-Y-85 Submit in triplicate WELL PLAN SUMMARY WELL NAME: P1-14 / G6 WELL TYPE' Slimhole, Iongstring AFE NUMBER: AFC #2C0031 INITIAL COMPLETION' Producer/water injector SURFACE LOCATION' TARGET LOCATION: BOTTOM HOLE LOCATION- 1413'FSL, 823'FEL, SEC 16, T12N, R14E 901' FSL, 1732' FEL, SEC 10, T12N, R14E 1214'FSL, 1444'FEL, SEC 10, T12N, R14E TOTAL DEPTH: CONTRACTOR: ELEVATION' 11872' md / 9190' tvd brt POOL 7 RTE-SS' 50' RTE-GL: 41' GL-SS' 9' DIRECTIONAL INFORMATION: Typ. build and hold, target=8763' tvd brt, 6462' departure. KOP: 700' Angle/dir.: 45°/N42°E Build Rate: 1.5/100'md EOB' 3396' TVD/3693' MD MUD PROGRAM: Surface hole = typical spud mud. Production hole (9-7/8")=3% KCL fresh water. FORMATION MARKERS: TVDss MD WEST SAK 6710 8442 K-10 8415 10849 STUMP ISLAND 8415 10849 HRZ 8560 11054 TARGET (KUPARUK) 8713 11270 TD 9140 11872 MILUVEACH 9173 BELOW TD CASING PROGRAM- Hole Cs_o Wt Gra~le Conn Lenqth To_D Btm 30" 20" 94#/ft conductor WELD 76 GL 76 " 13-1/2" 10-3/4" 45.5# NT80LHE BTC 3798 41 3910'(3500tvdss) 9-7/8" 7-5/8" 29.7# NT95HS NSCC 11831 41 11872 Tbs3 Wt Grade CouDlin0 Lenqth ToD 4-1/2" 12.6# L-80 TDS 11159 41 Btm 11200 LOGGING PROGRAM- Open Hole Loos: Surface N(~NE ~, E (~ E IV EL D Final Mud Logs: Top of West Sak to TD. MWD: GR/Resistivity/Neutron/Density from top of K-10 to TD Wireline: GR/Resistivity/Neutron/Density from top of West Sak to TD. Cased Hole Lo_o~: CET/CBT from PBTD to top of cement ;,~aska u~l & Gas Cons. C0rnrnisstO~ Gyro from PBTD to Surface (Schlumberger) Ancli0ragei COMPLETION' 4-1/2" L-80 tubing with 2 GLM's (4-1/2" x 1") above top packer. Straddle Pack completion across Stump Island with 3 GLM's (4-1/2" x 1") and blast rings. Flapper type sub-surface saftey valve. MEM Page 4 1/21/93 .LIDHOE BAY DRILLING GRL ..,P 20" DIVERTER SCHEMATIC POOL 7 FILL UP LINE I FLOWLINE 20" 2000' PSI DIVERTER 10 BALL VALVE 10 BALL VALVE CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND DlVERTER LINE. THE SECOND VENT LINE CAN BE REMOTELY OPENED TO ACHIEVE DOWNWIND DIVERSION. THIS iS A VARIANCE FROM 20AAC25.035. R TCE V b Anchorage CHOKE WING HCR ~IUAL TYPE E SATE VALVE 5/~'- ~ o, oooPs[ HUB X FLANGE ADAPTOR I,~V,lUAL metal ~ 5/a"-5000Psl GK ,ANNULAR BOP LATCHED HEAD 13 5/8"-10,000PS1 HUB BOTTOM CONNECT]ON HYDRIL 1,3 5/8'- 10,0007Si MPL RAM BOP HUB CONNECTIONS 4 1/16"-10,000PS! SIDE OUTLETS HYDRIL '15 5/8"- I O, O00PSI MPL RAM BOP HUB CONNECTIONS 4 1/16"-10,000PSI SIDE OIJTLETS HCR LYNN INTERNATIONAL ~ 7/~6"-~o, ooo~sl CHECK VALVE KILL WINO McEVOY ,5 1/I6"-10,000PS1 TYPE E gATE VALVE ff'rDRIL 13 5/8"-10, O00PSI MPL RALIt BOP HUB CONNECTIONS 4 1/16"- 10,O00PSI SIDE OUTLETS BLOW-OUT PREVE~R STACK PM RI[; 7 Alaska 0il & Gas Cons, Corm'~Jssi<m Anchorage . . . . . . . . 10. 11. MIRU drilling rig. P1-14/G6 Operations Summary Spud well and drill 13-1/2" hole to 3910' md/ 3550' tvdbrt building angle to 45 degrees. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 9-7/8" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 11872' md / 9190 tvdbrt. Run open hole logs. Set 7 5/8" casing and cement same. Test casing to 3500 psi for 30 minutes. Circulate well to 9.8 ppg inhibited brine with oxygen scavenger. Run cased hole logs: cement bond log Run 4-1/2" straddle-pack tubing completion (Stump Island and Kuparuk). Note: the straddle of the Stump Island may be deleted if no Stump Island is encountered. Freeze protect well with 600' of diesel. NU dry hole tree and test to 5000 psi. Release rig. Run GCT gyro directional survey. Alaska Oil & Gas Oo~;~,. v,u~t-d~ss'~o~'~ Allchor~.~e Surface Casing Depth: Surface Casing Size: Surface Cas!ng Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: P1-14/G6 Cement Volumes Surface String 391 0 10 3/4 45.5 13.5 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1144 TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 3 50 (2483 Cu. Ft.) (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 Intermediate String 11872 7 5/8 29.7 10300 9 7/8 1.4 LEAD Yield Density # sacks # bbls TAIL (CLASS G) Yield Density # sacks # bbls 1.98 15 0 0 1.2 15.7 411 88 ( 0 Cu. Ft.) (493 Cu. Ft.) ?o n McTn-type P1 - i 4/G6 VEI T CAL ViEW SCALE 1500 £-t;, ? DIVISTEIN I EF£BENCE: WELl HEA 6000-- 7500-- ~00 0.00° @ 0 ND R.K.B. 50' (AB[]VE SEA LEVEL) M C~I'I'IC,aL F:~]INT ])ATA o.ooo ~ ~ ~ ..... ~ ~°~ 1'4g ]nc Azl TVD 0.00° I~ 400 MD R.K.B. 50' (ABOVE SE 0 0.00 0.00 7C~ 0 ~ e ~.5/~00' 7OO 0.00 0.00 0 · ~ K END Or' BUILD 3693 44.g0 4~.44 8L:)~ 75~ g.~ 8 ~J3 B gP t~ :i.5/~00' DLS: ~.50 DEG/tO0 FT 10 3/4' CSG. PT. 3840 44.90 42.44 ~ 8~2 ,~,.~ ,_, ~ , ,., TARK~T ll~'7044.90 42.44 8763 4769 436,3 ..~.LA..r' ~ ~ wtU ~/gC 31772 44.90 42.44 911g ~C)3~ 4600 9~90 5O83 6.00° J~ l JO0 MD TJ]T/:~. ]~PTH _]387244.~)042.44 4648 g.o0o @ 1300 MD 1;3.00° I~ ~ 500 MD 15.00° I~ ~ 700 ND 38.00o @ lgo0 MD ;31.00° ~ ;3100 MD 24.00° t~ ;3300 MD '~ 27.00o ~ ~ MD '~ 30.00° ~ ;3700 ND ~ 33.00° @ ~ MD ~, 36.00`) @ 3100 MD .- ~ 39.00o ~ 3~00 MD ~ 42.00o @ ~ MD 44~c)3~°__~ .3603 Hrl FND I-IF ~ Jll 1~ ~ ~ 44 o 4 % .gO @ 093 ND ' '~, 44.g0° e 4;393 Mg '~ 44.90° ~ 4493 Mg '~ 44.g0° @ 4693 ND '~ 44.g0° @ 4893 MD '~ 44.g0° e ~)93 MD ~. 44.90° @ 5293 ND ~ 44.90° @ ~493 ND ~. 44.g0o @ 5693 ND ~,~ 44.g0° @ 5893 M1) ~% 44.90° e 6093 HD '~ 44.90° I~ (:~93 ND ~ 44.90° @ 6493 MD ~ 44.90° @ 6693 MD ~ 44.g0° I~ 6893 MD ~ 44.g0° ~ 7093 ND ~% 44.g0° @ 7~--'~3 MD ~ 44.g0° @ 7493 MD ~ 44.90° I~ 7693 MD ~ 44.g0° @ 7893 MD ~ 44.g0° @ 8093 ND ~ 44.g0° @ 8L---'~:)3 MD ~ 44.90~ I~ 849~ MD ~ 44.90~ @ 8693 MD '%,. 44.g0o @ 8893 MD "% 44.g0° @ gOg3 ND . ~. 44.g0° 1~ gL:x:)3 MD '~. 44.g0° ~ 9493 HD "% 44.g0° @ c)~93 ND ~ 44.g0° @ c)~3 MD ~ 44.g0° e lOOg3 MD ~. 44.g0° I~ l o~g3 MD ' "% 44.g0° @ ~0493 FiD ~% 44.g0° @ 10693 lid ~% 44.90° @ 10893 MD ~ 44.g0° ~ l ~.C~3 MD ~- 44.90° ~ 11~70 ND T/NL>GF'T 6462 -~ '~%% 44.g0° @ J1470 ND 0 J 500 3000 4500 6000 7500 VERTICAL SECTZFIN PLANE' 4B,44© TVI) MD ! t 872.48 VS 6887.40 Nc~'th .5082,63 Eost 4648.06 PPudhoe Bey DP i,,,,, 9 Po nt Hcln¢yPe P]-~ 4/66 HBR]'ZBNTAL SCALE '1000 ~EFERENCE VIEW ?~c, / DIVISIF1N WELL HEAD 10© ~ 000 0 1000 2000 3000 4000 5000 6000 Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Normal Plane Method Date: Page 1 12/20/92 REFERENCE WELL: Prudhoe Bay Drilling Point Mclntyre P1-14/G6 TVD, N/S and E/W are measured from the WELLHEAD ~ellpath Slot Distance Pl-O4/HTP~2 P1-O4/H7 149.36 t Pl-1/pmF PI-1/PM7 341.05 P1-llGCT P1-11 44.46 P1-12/pmll Pl-12/PM11 29.44 P1-2/pm3 P1-2/PM3 129.37 P1-2OGCT P1-20 90.34 P1-25/pm12 P1-25/PM12 165.67 P1-3/pm4 P1-3/PM4 164.67 P1-7 P1-7/PM8 52.43 P1-G1MgD P1-G1 432.86 P1-HRZ1 PI-HZ1 75.22 P2-3OGCT P2-30 6600.84 P2-49 'P2-49 6563.82 P2-49GCT :P2-49 6569.23 P2-5OGCT P2-50 6249.68 P2-51GCT P2-51 4622.37 P2-55GCT P2-55 3322.00 P2-57/pm10 P2-57/PM10 4847.00 P2-58/pm6 P2-58/PM6 5126.52 P2-59/PM9 P2-59/PM9 5935.26 P2-60/pm13 P2-60/PM13 6371.88 pm1 PM1 151.30 pm2 PM2 151.30 Direction 70.96 69.15 70.10 71.51 128.82 250.70 250.92 71.06 125.32 131.15 245.19 84.49 80.87 80.81 90.62 35.60 13.43 121.28 65.09 68.32 81.88 130.98 130.98 Closest Points Ref MD Ref TVD 50'.00 50.00 1050.49 1050.00 450.00 450.00 50.00 50.00 1660.08 1650,00 200.00 200.00 5O.O0 50.00 50.O0 50.O0 1505.97 1500.00 1763.69 1750.00 700.00 700.00 8286.86 6650.00 8004.50 6450.00 8004.50 6450.00 7933.92 6400.00 11463.30 8900.00 9275.08 7350,00 8428.03 6750.00 11816.24 9150.00 9698.61 7650.00 7580.98 6150.00 1868.12 1850.00 1868.12 1850.00 ......... . ................. - . . .... · smith International, Inc, PropOSal Report' ~ -. ~ V~l 8e~n P~ne: 42: lg '~g. C[~re '~ef~e: ~LH~ ~-u~hoe ~ay Ori'Lt .~int NcTntyre P1-14~ Oeptl~ Gtr, Oe~th Recta~utar Of Psels tat Ttude t Lo~g,tU~ (f~) (deg.) (deg.) eft) cfr) C~t) lOO.00 . . . . . 200...00 ' 300,'00 ~00, OO ~. ~ ~0,00 KOP 9. 1.5'/100' LEVEL} o.oo O. OO O.aO 'TOO. DO 0.00 200. 0.00 ~.00 ¢00,00 5~.00 600,00 ?00,00 0.00 0.00 700.00 9OO,{)~) 3.00 42.4& -899.91 lOO:},OO ~.50 42.~4 999.59 110m:),eO ~OO 42.~ 1~.2r I~,~ 7. SO 4~.~ 1~5T 1~,~ ~.00 42.~ 1~.5~ l~.OO lO. SO 42.4~ 1~.~ 1~,00 42.~ 1&~.I6 l~.OO 15.00 42.~ 1~.~ ~ l~.O0 18.00 42.~ 1~.0, 36 ~ ~.00 1~,50 . ~2,~ 1~.05 ~ 21~.00 ~.00 ~,~ ~.~ ~.00 ~.50 ~.4~ 2~1.7~ ~.O0 ~.4~ ~ ~.6~ ~.00 4~.~ ~ ~.00 ~.00 42,4~ 2~.~ ~,00 3 ~. 50 42,4~ 2695.~ GE]~ Coordinates ~o~th.fng .iasting (ft) CLosure Dist. Oir, (fL) cecj. Yert$cat DL$ Sect [ ~ (ft) (do/1 50.00 0.30 a o.oo E ~,23.~ N 1~.3~.57.~05 U 15~,00 O.Ob K O.oO E ~,23.~.~1 N i~.34.57.~05 9 ~0.00' O.OO n 0.00 E ~,23.~.~ N 1~,34.57.~05 g- ~.0o 0.00 w 0,~ E ~.23,~.~1 N 1~,3X.57.~ v 1~9.2T 15.~ N 14.1Z E ~,23.~.P~10 N I~.34.~.~ g 1~.5~ ~.~ ~ ~1.74 E 70.2~.~.1~ H 1~.34.~.1511 g 1~. 16 61.60 W 56.~ E 70,23.~.3949 N 1~.3&.~.~310 U 1541 .~ ~.~ ~ rl.Zg E 7g,23.~.555~ N 1~.34.~.~8 g 1~.~ 116.~.X 106.15 E ~,23.27.~0T N'l~.3L'.~.~O ~ 1~0.36 1~.96 X 126.!6 E ~,~3.~.1~5~ N I~.3~.~.~9 ~ 2i11.~ 2i6.5r ~ 196.22 E ~,~.~.E~ ~ 1~.3~.51.33~4 g 2~.61- ~.59 ~- 31Z.~ E rO,2~.~0.1~ k 1~.34.aT,952T ~ O. OO a O. Oi) O,lOO 0.03 O. Oa a O. OO O,OO o.m ,. o. oo a o.~o o,,e o.eo o.o~ a' o. oo. o~e'O o. 0o a o.~o o.eo o, oo a o. oo o.eo 5.~ a ~.~ 5,~ 1.50 11.~ O ~.~ 11.~ 1.50 ~.gZ 0 ~.~4 20.92 1.50 47.'33 a ~.~ 47.~ 1.50 I~.~ 8 ~.44 105.54 1,~ E19.~ e ~.44 219.~ 1.~ stl.-~ e ~.44 5t~,74 ~.a~ ~ ~z, 4~ ~,~7 i.sO Smith International, Inc.- Proposal Report Ctesure V;;trcat Dist. Orr, S~ticn 616.2~ 1.50 $71.78 1.50 :~leQ.O0 Z,6. O0 ~Z.~. 'L~5,17 2695.17 538,.$4 N ~92.31 32QQ.~ 37.5O ~g.~ 3025.38 Zg~.3Q 5~.~9 X 532.~ ~3~0.~ 39.00 ~.4~ ~1~.~ 305].~ ~.17 N 57(.~ E ~.~.~.~ N 148.~:~.2.5~ ~. 5~1~.38 67~3.~ ~1.~ a ~Z,~ ~1.~ ~O.~ 40.50 ~Z.~ 31.80.71 3T30.~ 6~.~ N' 617.61 E ~.~.~,~13 N 1~8.~.~.~ a 5~1.56 67~5.~ 915.18 a ~.&4 915.17 ~(e.~ ~2.~0 ~Z.~ ~255.~ ~05.~ ~.01 N ~2.11 E ~-~.~,gfl~ N 1~L~.~.6907 ~ 5~.~ 67~8~.al ~1.11 g ~Z.~ ~1.10 ]~4" ~, PT, 3910,42 ~,~ ~.~4 3~50.~0 . 35~,0~ 93520 N ~5.~ i ~.~.35.~9 N liL~.IL~I~ N $~54~,~. 6~06T. 13 1Z6T. 29 a ~.~ IET.EB 3~3~ ~.90 ~Z.~ ~38.74 3HS,74 9~,39 N ~4.74 ~ 70.~.~6,q17 a 1~6.~.~3.~ U 5~5~,~ ~10~.61 1~.~ a ;Z.~ 1325.81 4193.~ ~4.90 G2,~ 3~0.~0 3roa,ze 1~,57 N ~0.01 E 449~,34 ~.gO ~,44 ~,91 391Z,91 1~8,a~ N It]2.~ E ~.~,]8,9~2 N liL~,~.9019 N 5~5~,g~ 6~]r,61 16~,7~ a &2,~ t6~,~ ~5~.34 a~.~ ~Z.~ ~.74 ~.74 1Z~,93 N tlaO.~ E 70.~.39,4855 N 1~L~2LS067 N 5~5~.13 6~3~.Sl 17&9.35 a aZ.q4 fr4g.~ ~6~.34 ~,~ AZ.4~ 41~.57 ~D%.57 1~.02 N 1~8.19 ~.34 ~4,~ A2.~ 41~.~1 ~1Z5.~1 13~.T1 N lZ~.~ E ~.~.~.5102 N 1~L~.19.Z1~ N 5~5~.51 6~?6.al 1~.52 a ~Z.~4 1~90.51 4~3.3~ ~4.~ ~2.{~ ~b.2~ ~1~6.Z4 1~7.20 N 13~.47 E ~.~.~1,0225 N 1~S,~,18,3211 N 5~9.71 6~523,Z1 1~1.11 a ~3,~ 1961,~ 5093,~ ~.~ ~,~ ~7,91 ~¥.91 1551,38 N 1&18.74 E 70,~,~Z,O&H N 1{&,~,15.S]~ ~ 5~61~,09 6~GI6,01 ~.~ ~ &Z,~4 z102,2r 5293,3~ ~,90 ~.~ ~.58 ~,58 1655,56 N 151&,01 E . 5593,34 '6{,CO ~.~ 4~2.e~ ~5~.~ 1811.~ N I~b.~ E ~,~.~,~ N 1~,~,~,5St3 ~ 5~,06 6~7,~ ~55,~ a 63.~a 245520 5693.34 GG.90 ~.~ ~12,91 GZ6Z.91 1~.9Z N IN&.~ E 70,~.~5,126g N lI~,~.0~.t590 N 5~e~,Z5 6~E~,%Y ~25,81 g G2.Z~ 25~.~ 5~$.~4 ~,90 ~.~ ~,~ ~5.~ 1916.01 N i~2.19 E 70.~,~5,~32 N li~.~,05,7~7 ~ 5~.~5 6~0,~ ~,40 a ~Z,4~ 25~.31 5693,34 ~.90 ~.~ ~.58 ~.58 1~.10 N I~.~ E ~.~.~.1~56 N 1{a.~.~.3~ U 5~551.~ 6~8?.~ ~.~ a ~Z,M 2~.~ ~3,34 ~.~ ' ~.~ ~.~ 5~6.23 ~.Z8 N I~.10 E ~.~;~7.I~ N I~.~.01.5~ ~ S~.O3 E~,~ ~.~ g ~Z.~ 2~.13 ~93.~ ~.~ 4Z.~4 ~.~ 5~8.~ ~2~.55 K ZO3a. Ol E ~.~.~.~71 ~ 14L~,SZ.3917 ~ 5~7.6Z 67~1~.15 ~19.~ g 4Z,4~ 3019.~ .. ....................... .. .. .... ....... 1.51) O. O0 . 0.~ 0.0~ 0.08 O.0~ 0.00 9..00 DJaO 0.0O -).00 '3.00 0.00 O. OO (7.00 Smith International, In'o," P'mposal Report ue.!ipelh It): P.I-IIIG61~I.- . Lati rude / Lcrgftu~e Sect t ~ 3090 3161.06 3Z$1 .~ 3372,~ 3514,~ S655.17 3~5.76 ~1 .~ ~5a2.21 . 5~ .~ 51~7.49 5~.18 Smith International PfoposaJ Report . · rARGE! 112~9.89 ~.~0 ~2.~ 113E9.89 ~.90 ~2.~. t1¢69.89 ~4.~0 ~2.~, 890~.67 subsea } [] ! 'A L DePth Rect~rguLae Offsets {fo) (fi) ~,44 ~520.51 N ~1~.~ E I~,10~ 4.7T;~.74 N 4315.28 E 8,558,T'/ 4,7~,87 N ,L324,,% E B?IZ.O0 ~?;5~.01 N 4;]60.,.'.'.'.'.'.'.'.'.3~ E Letf [~te / Lcrgftude 70.26.1~,1983 ~ 1~8,32.50.67~Z ~ 70.~.15.2979~ 1~.32.$0.~0Z$ N. T0,26,1~.6828 ~ 1~B.32.~q. 35~ Y 70,2&,i~5'.6')10i 'R 1LB.:~,Z~,9.]5~ W 70.~6,1~,.21)2~ I~ 11L6.32.Z.,?'.9$84 )~ 70.26.1~,.7147 ~ 1~.-8,32.&6.5~Z& ~ TO.~.1.T.227i] I~ 1~8.32.6~. 1~67 ~ 70.26.1S.7393 ~ 1~8,32.6S. 75~8 U TO.L~.16.Z6~9 ~ 1~8,32.A2.~11~ k~ 70.L~.I&.ZT~ ~ 1~8,32.~D. 9~0 W 5~11.$? 678683.49 ~61.15 a ~2,44 599~12. t2 678~81.t! 599~5t8.~$ 678SZ~.S9 6605,32 5S55571.7& 67]~5~3.27 6~.91 a 5~gg6~.grr 6786~,65 6Z~,$aa 5.~5~678.1S 67~rlS.e2 ~81S.eaa ~..~ 5~;~679.$6 67871&,22 6816.91 ~9~ .~, O, 0~) 6~88.05 0.0~) 6~61.0~ O. DD &4,~2.,08 6,532.6? O.l~ 6,573 .Ua. g. 67~ .4,T &.&15 .(Z2 6~16.E/~ 9. OD 6&~ .Z~ 3. CASING 10-:3/4" 45.5#/FT, NT80LHE. P1-14/G6 DESIGN SPECIFICATIONS SURFACE CASING BTC BURST COLLAPSE PBYS # TJYS # NT80LH E 551 0 3390 1040000 1063000 I · 0 m Burst Pressure The burst rating is based on shutting the well in on a gas kick with pressure equivalent to the leak-off at the surface casing shoe: Burst Pressure = 14 ppg (LOT) @ 3500' tvd = 2548 psi. Safety Factor = 2.16 Collapse Pressure The scenario for collapse rating is based on having lost circulation such that the fluid level drops below the surface casing shoe and there is 9.5 ppg mud in the annulus: COllapse pressure = 9.5 * 3500 * .052 = 1729 psi Saftey Factor = 1.96 Tension Tension is based on full string weight in mud. A maximum casing length of 5000' is assumed, and a vertiCal hole is assumed (for worst case scenario)' Tension = 45.5 * 5000 * .85 = 193375 # Saftey Factor (pipe body) = 5.38 Saftey Factor (joint) = 5.50 PRODUCTION CASING 7-5/8", 29.7 #/FT, NT95HS, NSCC BURST COLLAPSE PBYS # TJYS # NT95HS 8180 7200 811000 813000 1. Burst Pressure The worst case scenario is a tubing leak at the surface with no annulus backup. · .~ Maximum shut-in tubing pressure= burst pressure= 4360 - (.15 * 8810') = 3038 psi Saftey Factor = 2.69 · · Collapse Pressure Assume the casing is evacuated to gas lift gas with 10.5 ppg mud in the annulus: Collapse pressure= 8750"10.5'.052 = 4777 psi Saftey Factor = 1.51 Tension Based on a full string weight in 10 ppg mud. A maximum casing length of 16000' is assumed as a worst case scenario: Tension = 29.7*16000*.85= 403920 #. Saftey Factor (pipe) = 2.01 Saftey Factor (joint) = 2.01 MUD PROGRAM SURFACE MUD PROPERTIES: TYPICAL Density Marsh Yield (ppg) Viscosity Point Spud 8.7 300 40-60 TD 9.5 100 20-40 Surface 10 sec gel 30-6O 15-20 10 min gel 60-80 20-30 pH 9-10 9-10 Fluid Loss 15-25 15-25 FINAL HOLE MUD PROPERTIES: 3% KCL Density Marsh Yield (ppg) Viscosity Point TD Surf 9.5 25-45 10-15 TD 10.2 30-50 10-20 Final 10 sec gel 5-15 10-25 10 min gel 10-20 15-30 pH 9-10 9-10 Fluid Loss 10-15 5-8 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE D/~TE 1~ 2 ~hru (3) Admi ~~ [10 & 13] []-4 thru' 22 ] [~3 thru 28] (6) Other ~ ~ [29 th~ (7) Contact z~ //"'~-~'/'~J~ --' - ~32]' (8) Addl ~ ~~ geology' engineering' DWJ MTM RAD]~) 2" 1 R P C~.~/~ BE~JDH t7 2.~LH- LG rev 12/92 jo/6.011 Company Lease & We 1 1 ~ ~:~/__ j~ ~c~~ ~_ zx' ~ ~/~~f ~ --/~?'/'~' 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. -23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat i ve approval needed .................................... Is lease nL~nber appropriate .......................................... Does well have a unique name & nt~aber ................................ I s conductor st r i ng prov i ded ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed .......... Is a diverter system required ..................... Is drilling fluid program schematic & list of equi Are necessary diagrams & descriptions of diverter Does BOPE have sufficient pressure rating -- test Does choke manifold comply w/API RP-53 (May 84)... Is presence of H2S gas probable ................... ®®®eee®e®®eeeee®eee pment adequate ..... & BOPE attached .... to ..~0:~ psig ..... eeeeeeeeeeeeeeeeeee eeeeeeeeeeeeeeeeeee YES NO B ,, REMARKS FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLFnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks: MERIDIAhI: UM - - SM Exp/~ ~ ~ TYP, E,: Redrill In j__ Rev 29. 30. 31. 32. 33. 0 -rZ ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ARCO ALASKA INC PI- 14 POINT MCINTYRE 1 ~ 7993 C°rornis$iott Run 1' 06 - March - 1993 DLL/MLL/CNIZDL/GR 11755 Tape Subf~le 2' is type: LIS TAPE HEADER POINT MCINTYRE UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 5909.00 BRAD ESARY SEE REMARKS P1 - 14 500292233800 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 02-APR-93 RUN2 RUN3 16 12N 14E 1413 823 50.00 9.00 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 REMARKS: 10.750 DEPTH (FT~ZA c 1~ . 3 9 0 8 0 · 11768.0 DLL/MLL/CN/ZDL/GR LOGS WITNESSED BY: K. PRIVOZNIK, T. JOHNSON, D. TOWEILL CIRCULATION STOPPED @ 11:30 05-MAR-93. CNC IS CALIPER CORRECTED WITH AVERAGE OF ZDL & MLL CALIPER READINGS. CALIPER VERIFICATIONS PERFORMED IN CASING. MLL ON MAIN PASS BELOW 11000' WAS REPLACED BY REPEAT SECTION DUE TO SPIKING. MLL NOT PRESENTED ABOVE 10140' ON MAIN PASS DUE TO SPIKING. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings with depth shifted and clipped curves; (including cased hole). DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GR MLL DLL 2435 SDN $ BASELINE CURVE FOR SHIFTS: CURVE START DEPTH STOP DEPTH 8350.0 11680.0 10140.0 11755.0 8350.0 11732.0 8350.0 11687.0 8350.0 11705.0 GR SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8324.0 8353.5 8355.0 8366.0 8386.5 8388.5 8395.5 8400.5 8410.0 8416.0 8416.5 8436.5 8437.0 8437.5 8443.0 8450.0 8452.5 8454.5 8455.5 8458.5 8459.5 8460.5 8484.0 8486.0 8488.0 8536.5 8537.0 8551.0 8557.5 8565.0 8589.5 8679.5 8701.0 8702.0 8702.5 8727.0 8728.0 8734.5 8738.0 MLL 8324.0 EQUIVALENT UNSHIFTED DEPTH LL3 LLD NPHI 8324.0 8324.0 8324.0 8353.0 8394.5 8354.5 8387.5 8409.0 8415.5 8366.0 8386.5 8436.0 8437.0 8443.0 8452.5 8455.0 8458.0 8459.0 8487.0 8489.0 8702.0 8702.5 8703.0 8728.0 8729.0 8735.5 8400.5 8416.5 8437.5 8451.0 8461.0 8485.5 8537.0 8565.5 8589.5 8679.5 all runs merged RHOB 8324.0 8394.0 8416.5 8454.0 8537.0 8550.5 8557.5 8679.5 8735.0 8738.0 8738.5 8741.5 8745.0 8855.5 8856.0 8860.5 8913.0 8984.0 9016.0 9028.0 9029.0 9034.0 9041.0 9041.5 9042.0 9046.5 9047.0 9047.5 9094.5 9095.5 9098.5 9100.5 9119.5 9154.5 9203.5 9212.0 9213.5 9224.5 9279.5 9316.5 9350.0 9351.0 9423.5 9462.0 9632.0 9771.5 9777.5 9779.5 9780.0 9850.5 9852.5 9876.5 9921.5 9979.5 9997.5 10030.5 10034.0 10036.0 10039.5 10114.5 10125.0 10208.5 10225.0 10225.5 10532.5 10535.5 10542.5 10588.5 10591.0 10591.5 10535.5 8739.0 8741.5 9041.0 9632.0 9850.5 10039.0 10225.0 10542.5 8745.0 9016.0 9028.5 9029.5 9034.0 9046.5 9047.0 9047.5 9094.5 9095.0 9098.0 9154.5 9203.5 9211.5 9213.0 9224.5 9316.5 9349.5 9350.5 9423.5 9771.5 9777.0 9779.0 9780.0 9876.5 9979.0 10036.0 10208.0 10225.5 10591.0 10591.5 8740.0 8855.5 8860.0 8913.5 8983.5 9042.5 9101.0 9119.5 9279.5 9462.5 9852.5 9921.0 10034.0 10114.0 10125.0 10532.0 10589.5 8740.5 8855.5 9041.0 9046.5 9852.5 9997.5 10030.5 10532.5 10592.0 10597.0 10600.5 10616.5 10619.5 10620.5 10641.5 10642.0 10652.0 10662.0 10664.5 10672.5 10674.0 10703.5 10710.0 10716.5 10734.0 10741.0 10758.5 10762.5 10790.0 10839.5 10840.5 10874.0 10875.0 10907.0 10909.0 10917.0 10935.5 10940.0 10949.0 10949.5 10967.0 10967.5 10973.0 10982.0 10983.5 10996.5 10999.0 11000.0 11000.5 11015.0 11019.0 11021.0 11028.5 11029.0 11038.5 11042.5 11073.0 11075.5 11078.5 11083.0 11086.5 11087.5 11088.5 11089.0 11109.0 11112.0 11112.5 11113.5 10597.0 10661.5 10664.0 10672.0 10673.0 10703.0 10709.5 10740.5 10909.0 10916.5 10948.5 10966.5 10997.0 11000.5 11015.0 11021.5 11075.5 11112.5 10662.0 10703.5 10762.5 10875.0 10973.5 11000.5 11029.0 11082.5 11112.5 10592.0 10600.5 10617.0 10620.0 10620.5 10790.0 10840.0 10840.5 10874.0 10936.0 10982.5 10999.0 11038.5 11042.0 11086.0 11086.5 11087.5 11109.0 11112.0 10641.5 10652.0 10716.0 10734.0 10758.5 10907.5 10909.5 10939.5 10949.5 10967.5 10984.5 11001.0 11019.5 11027.5 11072.5 11078.5 11089.0 11114.0 10642.0 10715.5 10968.0 11001.5 11027.5 11114.0 11115.5 11116.5 11117.0 11120.5 11121.5 11125.0 11126.0 11126.5 11127.5 11128.0 11128.5 11129.0 11129.5 11131.0 11131.5 11138.0 11143.5 11148.5 11154.5 11155.5 11162.0 11163.0 11171.0 11191.0 11194.0 11200.0 11200.5 11202.0 11203.5 11206.0 11212.0 11232.0 11235.0 11252.0 11258.0 11276.0 11278.5 11279.5 11291.0 11295.5 11299.5 11300.0 11302.0 11311.5 11335.0 11343.5 11346.0 11361.0 11379.5 11381.0 11382.5 11390.5 11395.0 11395.5 11396.5 11408.0 11410.0 11413.5 11414.5 11121.5 11128.0 11129.0 11191.0 11201.5 11205.0 11381.0 11414.0 11116.5 11119.5 11130.0 11136.5 11148.5 11170.0 11190.0 11199.5 11258.0 11410.0 11113.5 11115.0 11115.5 11124.0 11124.5 11125.0 11126.0 11127.0 11128.5 11143.5 11154.5 11155.0 11161.5 11162.0 11211.0 11231.5 11234.5 11252.0 11278.5 11279.0 11290.5 11302.0 11382.5 11395.5 11396.0 11396.5 11408.0 11415.0 11115.5 11128.5 11131.0 11193.0 11201.0 11203.5 11252.0 11276.0 11299.0 11311.0 11334.5 11343.5 11346.5 11379.0 11391.0 11129.0 11199.5 11252.0 11296.0 11300.0 11361.5 11417.6 11418.0 11418.5 11420.5 11424.0 11425.0 11428.0 11428.5 11433.0 11438.5 11442.0 11442.5 11443.0 11448.0 11454.0 11460.5 11466.5 11477.0 11482.0 11483.0 11489.0 11516.5 11531.5 11537.5 11565.5 11566.0 11566.5 11567.5 11571.5 11577.5 11601.5 11602.0 11613.5 11614.5 11619.5 11620.0 11620.5 11629.0 11637.5 11644.5 11645.5 11648.5 11649.0 11651.0 11652.0 11652.5 11653.0 11666.5 11668.5 11669.0 11672.0 11703.0 11724.0 11725.5 11726.0 11780.0 MERGED DATA SOURCE LDWG TOOL CODE 11443.5 11460.5 11537.5 11601.5 11668.0 11703.0 11723.0 11780.0 RUN NO. 11443.0 11603.5 11669.0 11780.0 PASS NO. 11417.5 11418.0 11418.5 11421.0 11424.5 11425.0 11428.0 11429.0 11433.5 11439.0 11443.0 11448.5 11467.5 11483.0 11483.5 11489.5 11517.5 11566.5 11567.5 11568.0 11568.5 11572.5 11579.0 11615.0 11615.5 11620.5 11621.0 11621.5 11630.0 11638.0 11645.0 11645.5 11648.5 11649.5 11651.5 11652.0 11652.5 11653.5 11666.5 11454.0 11477.0 11531.5 11601.5 11618.0 11725.5 11726.5 11780.0 11780.0 MERGE TOP 11601.0 11671.5 11780.0 MERGE BASE GR MLL MLL DLL 2435 SDN $ REMARKS: CN WN FN COUN STAT * FORMAT RECORD 1 2 8350.0 11680.0 1 2 10140.0 11000.0 1 1 11000.0 11755.0 1 2 8350.0 11732.0 1 2 8350.0 11687.0 1 2 8350.0 11705.0 MAIN PASS. NEUTRON IS AVERAGE CALIPER CORRECTED. CHISM FILTERING IS NOT ACTIVE. MLL IS COMPOSITE OF MAIN & REPEAT PASS DATA. CALl (MLL TOOL) WAS SHIFTED WITH MLL. TENS & TEND WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl (ZDL TOOL) WERE SHIFTED RHOB. $ : ARCO ALASKA INCORPORATED : P1 - 14 : POINT MCINTYRE : NORTH SLOPE : ALASKA (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units 1 GR MLL 68 1 GAPI 2 CALl MLL 68 1 IN 3 MLL MLL 68 1 OHMM 4 LL3 DLL 68 1 OHMM 5 LLD DLL 68 1 OHMM 6 SP DLL 68 1 MV 7 TEND DLL 68 1 LB 8 TENS DLL 68 1 LB 9 NPHI 2435 68 1 PU-S 10 NUCT 2435 68 1 CPS 11 FUCT 2435 68 1 CPS 12 RHOB SDN 68 1 G/C3 13 DRHO SDN 68 1 G/C3 14 PEF SDN 68 1 BN/E 15 CALl SDN 68 1 IN API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 02 980 55 5 4 03 731 77 6 4 03 731 77 6 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 60 * DATA RECORD (TYPE# 0) Total Data Records: 461 966 BYTES * Tape File Start Depth = 11780.000000 Tape File End Depth = 8324.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 110609 datums Tape Subfile: 2 830 records... Minimum record length: 62 bytes Maximum record length: 966 bytes 0'0 0'806[; §L8'6 :(~) H~G DNIS~D S,~DDO~ :(A~) H~Q DNIS~D :(NI)~ZIS II~ ~0~ N~O ~Q DNIS~D QN%f H~OHHHO~ ~XIC6I ~X90I£ ~X£96g ~XIg6C ~XGL6£ k~46 g gI/~H6EEI ~X£96~ ~X90§~ ~XIE6~ ~X908E ~XIE6[ YXS0g~ ~X~E ~X605I ~N£I~ ~X9£6~ HHS~/1N ANHD SI~ A£NH SO SI~ HD ~GO~ H~XA ~00~ HQOD ~00~ HOQNHA (~OAAO~ OA ~0~) DNIHAS ~OO~ 0'008I 0'gg£II 0'0~g8 0'g9£II 0'89£II £6-H~-90 9E C6-H~-~0 0gII I'I 'HHA I00£ 'AHH SAS~ ~6-~-90 :(HH~) GHHaS DNIDDOq :(A~) qYAHHANI DO~ :~OA~O~ NO HHDDO~ :GHGN~ NOIA~DHID : NOISHHA 0'9ELII 0'0§~8 ~QZ 0'60LII 0'0~8 §~gE 0'S§LII 0'0§~8 ~Q O'LLLII 0'0~IOI ~ 0'~0£II 0'0~8 HD H~HQ ~O~S H~HQ ~H~S HQOD ~O0~ HOQNHA AH~q414QS H~I~ :~NH~HHDNI H~HQ :HH~W/1N SS~ :HH~flN DNIH~S ~OOA :HH~W/1N NQH 00~E'0 I I · suna suanbasqns aaq~o e ao~ s6u!a~s IOO~ IIg ~oa~ ~p aapeag 6oi pu~ SaAanO IIe ~o a~!sod~oD SS~ Nike4 H~OH NH~O :HH~IflN H~I~ HHQWHH HqI~ SI~ :~dA$ s~ ~ ~I~qns ~d~A BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: KCL POLYMER 10.00 51.0 8.6 5.2 160.7 0.255 45.0 0.079 160.7 0.206 45.0 0.000 0.0 0.312 45.0 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE O. 000 TOOL STANDOFF (IN) : 0.0 REMARKS: MAIN PASS. NEUTRON IS AVERAGE CALIPER CORRECTED. CHISM FILTERING IS NOT ACTIVE. MLL IS A COMPOSITE OF MAIN PASS & REPEAT PASS DATA. THE CURVE "CAL" IS AN AVERAGE OF CALi(MLL) & CALi(ZDL). $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P1 - 14 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 Name Tool Code Samples Units GR MLL 68 1 GAPI CALl MLL 68 1 IN RMLL MLL 68 1 OHMM RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV SPD DLL 68 1 F/MN CHT DLL 68 1 LB TTEN DLL 68 1 LB CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 02 980 55 5 4 4 40 980 02 1 4 4 71 857 46 1 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 11 639 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 13 SSN 2435 68 1 CPS 14 LSN 2435 68 1 CPS 15 CAn 2435 68 1 IN 16 ZDEN ZDL 68 1 G/C3 17 ZCOR ZDL 68 1 G/C3 18 PE ZDL 68 1 BN/E 19 CALl ZDL 68 1 IN · * DATA RECORD (TYPE# 0) Total Data Records: 1153 966 BYTES * 76 4 83 368 34 4 84 023 70 4 84 611 47 4 52 443 33 4 09 884 61 4 76 731 33 4 67 754 94 Tape File Start Depth = 11780.000000 Tape File End Depth = 8324.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 276501 datums Tape Subfile: 3 1244 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH GR ? 10980.0 MLL 10980.0 DLL 10980.0 2435 11000.0 ZDL 11000.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : STOP DEPTH 11702.0 11777.0 11754.0 11709.0 11726.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN PCM ZDL KNJT TEMP KNJT PCM MIS DLL OS KNJT MIS MLL CENT $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE KNUCKLE JOINT PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG ORIENTATION SUB KNUCKLE JOINT MASS ISOLATION SUB MICRO LATEROLOG CENTRALIZER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 06-MAR-93 FSYS REV. J001 VER. 1.1 1130 05-MAR-93 2208 05-MAR-93 11768.0 11765.0 8350.0 11755.0 1800.0 TOOL NUMBER 3974XA 3517NA 1309XA 2435XA 3508XA 2222EA/2222MA 3921XA 2806XA 3921XA 3506XA 3967XA 1229EA/1229MA 3975XA 3921XA 3967XA 3104XA 1931XA 9.875 3908.0 0.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: KCL POLYMER 10.00 51.0 8.6 5.2 160.7 0.255 0.079 0.206 0.000 0.312 0.000 45.0 160.7 45.0 0.0 45.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN): 0.0 REMARKS: REPEAT PASS. NEUTRON IS AVERAGE CALIPER CORRECTED. CHISM FILTERING IS NOT ACTIVE. THE CURVE "CAL" IS AN AVERAGE OF CALI(MLL) & CALi(ZDL). $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P1 - 14 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 Name Tool Code Samples Units GR MLL 68 1 GAPI CALl MLL 68 1 IN RMLL MLL 68 1 OHMM RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV SPD DLL 68 1 F/MN CHT DLL 68 1 LB TTEN DLL 68 1 LB CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 02 980 55 5 4 4 40 980 02 1 4 4 71 857 46 1 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 11 639 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 sa~q 996 :g~6uaI p~ooa~ ~n~x~ sa~Xq ~9 :g~6uaI p~ooa~ ~n~u~ · ''sp~ooa~ I9~ ~ :aI~qns :Aa~ns ~u~pooap apoo uo~uasalda~ SI~ ~aa& = s~Tu~ g~daG aIT~ O000g~'O = 6u~o~ds IaAa~ aI~ 000000'E£60I = gsdaG pu~ aI~ 000000'08£II = gsdaG ~e$S aI~ ~ S~X~ 996 9/- ~6 ~L L9 ~ I9 ~88 60 ~ 0£ ~E0 ~8 ~ 0£E :spaooa~ ~$~G I~$O~ ~ NI I 89 ~QZ I~D 6I ~ ~/N~ I 89 ~GZ ~ ~ CD/D I 89 ~QZ ~ODZ ~ CD/D I 89 ~GZ N~GZ 9I ~ NI I 89 S~E ~D SI ~ SdD I 89 Gg~g NS~ ~ SdO I 89 GC~E NSS Tape Subfile 5 is type: LIS 93/ 4/ 01 **** REEL TRAILER **** 93/ 4/ 7 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 7 APR 93 7:38a Elapsed execution time = 1 minute , 42.9 seconds. SYSTEM RETURN CODE = 0 FieLD: ~A~E ~ POIt~T ~CINTYRE $o~ou~ ~'~'O:RTH s~oP~ :$TAT~: ~ ALASKA AP~ NIJ~ER, ~ ~0 '0~9-22338 ~F£~E~CE NO ~ 93~1! CONFIDENTIAL ch~um erQer ~as~a Computing Center **** REEL HEADER **** S~VICE NAME : EDIT DATE O~IGIN : FbIC CONTINUATION # COMMENT ~ ARCO ALASKA INC., POINT ~CINTYRE, PI-14, APi 50-029-22338-00 **** TAPE HERDER **** SERVICE NAME : EDIT D~TM : 93/03/25 O~I~IN : FLIC TAPE NAME . : 93111 CONTINUATION # ! 1 PREVIOUS TAPE' : COMMENT : ARCO ALASKA INC., POINT MCINTYRE, P1-14, APl 50-029-22338-00 PRUDHO~ BAY ~WD/MAD LOGS # APl NUMBER{ OPERATOR:. LO~ING COMPANY: TAPE CREATION DATE: JOB D~TA JOB NUMBER{ LO~GING ENGINEER: OPERATOR SURFACE LOCATION SECTION: TOWN~H!P{ ~NL: FEL~ ELEV~TION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WFLL CASING RECORD ]ST STRING ~ND STRING BIT RUN ! BiT RUN 2 BIT RUN 3 mmmmmm, mmm m~m~m mmmmmmmmm 93111 93111 93111 JACKSON jACKSON~ jACKSON PRIVOZNIK PRIVOZNI~ PRIVOZNIK t6 14E 1414 823 50.00 50.00 9.00 OPEN MOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH. PAGE: ~hlumberger Ales~e Computi~q Center B! 25-MAR-t993 08:39 ELD ENGINEER;S ******** RUN T TO ...ES. 51.20 ,.,.BIT TO GE 61.62 , BIT TO DEN T TO ~EUT 127-~!7'. DRiLLgD I~TERVAL 9]50' TO ******** *U************** T TO ~S 28.t7'~ BIT TO GR ~8.79', BIT T~ DES 98 01' T TO ~EUT 104.24'. DRILLED INTERVAL 11560' TO 11~47' SHDOWN INTERVAL ~1480' TO . *~****** RUN 120.~ ' 11560 ,4 BIT TO RES 28.~9', BIT TO GE 38.81, BiT TO EN 56.71' BIT TO NEUT 62.94'. WASHDOW'N INTERVAL 11540' TO 11647' DRILLED INTERVAL 11647' TO 11765'. ~ATRIX DENSITY 2.65 (G~/CC), FLUI6 DENSITY 0 (GM/CC) SOFTWARE VERSION V4.0. $ $ PAOEi **** FIL~ HEADER S~,VIC~ ~ FLIC D~T~ : 93 03/25 M~X R~C SIZ~ : 1024 FIL~ TYPE ~ LO LaST FILE FIL~ HEADER FILE NUMBER: 1 EDITED ME~GED ~WD Depth shifted and cl~Dped curves; all bit DEPTH INCRE,ENT 0.5000 # FILM SUMMARY KR!! TOOL CODE CDN CD~ $ BASFLINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 11689.0 1678.5 62:5 11619.5 START DEPTH 9R75.0 runs merged. STOp DEPTH 11710,0 11738,5 ---- .... --EQUIVALENT UNSHIFTED 11690.0 11676,5 11667.5 11660,0 11637.5 DEPTH---------- IS TaPe Verification ~$t~ng ChlUmverqer Alaska Computin Center ~ ~603 5 11468.0 . 1&60,5 . 1434,5 11411,5 11344,5 9.1300,0 11295,0 ~!236,0 } 1220 0 ~203,0 ~llgg,o J. 1079 0 1!0 0 10994,0 ~.0987'5 ~. 0969,5 10956,0 ~.0934,0 ~ 0920,5 ~ OB 3~, 5 ~0753,5 0719,0 10650,5 10644,0 ~.06~6,5 1060~, 0 10543,0 10539,0 10475,5 ~.. 04~9,0 103:96,0 361,0 ~ 0 291,' 5 10~5~ 0 02~ ~ ~0159 10 ~ 16 · 5 11601,5 11476,5 11469.0 11460.5 11433.5 114~0.0 11373.5 11343.5 11312,0 11]O0,O 11~96,0 11269,5 11~3~,5 !1219,5 11202,5 11196,5 11179,0 1114~,0 11!~7,5 1111~,5 11073,5 1105~ :§ 10986,5 109B0,0 10967,5 10954.5 1093~,0 1091~,0 10875,5 10828,0 o 10716'5 10711,5 10642, 10629 1~597.0 i 10536.~0 10474,5 103 10364'5 10356,0 10346' 10'27~,:5 1025-5 10155,5 ~.01 25-NAR-1993 08:39 PAGE: Chlumberoer Alas~n ComputinO center ioio4 iolo3,.,s 10041: 10040'0 9998.~ ~9997'5 9947.5 9944,5 9869'5 9~68.5 9852.0 9851,,0 9808.0 9806,5 9787,0 9788 9609.0 9612"0 9557,0 9556'0 9521~5 9519-0 9493,~ 9491'0 9474;5 9472"5 9437.0 94~5"0 9423.0 9423,0 941t,0 9410'0 9358'5 9358'0 .93~?,0 933~,0 9330,0 · ~00"0 97,5 $ MERGED DATA SOURCE KRU TOOL CODE MWD R~MARKS~ BIT RUN NO,: ~RGE TOP ME~GE BASE 1 9208,0 11560.0 2 t1560,0 11647.0 ~ 11647,0 11765.0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT MWD GR TO ATLAS WIRELINE GR OF 06-~AR-93. ALL OTHER CURVES WERE' CARRIED WITH TH~ OR SMIFT,= # bis FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 0 3 73 40 4 66 5 66 6 IS ?ape verif~Lcal:ion Listen ~hlumberqer AlasRa Computin~ Center 25=MAR=lgg3 08:39 PAGE" mm--m ----. m mm -- m m mm......., m.mm mM -m-- TYPEREpR CODE VALUE 7 65 8 68 0,5 9 65 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 SET '~i~;''''"'''''''S~RV UNIT DEPT FT G~ MWD GAPI ROP MWD F/HR E~ MWD OHP~ C~bN ~W~ IN P~F MWD BN/E NPHI MWD PU-8 ~OB ~WD G/C3 D~HO MWD G/C3 ~m.m...~mm..~...~m. TYPE - CHAN ** ERVICE API API AP APl FILE NUMB NUMB SIZE OCEBS ORDE~ $ LOG TYPE CSA 8 MOD NUMB SAMP ELaM COD~ (HEX) ~9053 O0 000 O0 0 ! ~ I 4 68 0000000000 19053 O0 000 O0 0 1 ! 1 4 68 0000000000 19053 O0 000 O0 0 1 1 1 4 68 0000000000 19053 O0 000 O0 0 I ! ~ 4 68 0000000000 19053 O0 000 O0 0 I I I 4 68 0000000000 19053 O0 000 O0 0 1 1 I 4 68 0000000000 19053 O0 000 O0 0 I 1 I 4 68 0000000000 19053 O0 000 O0 0 1 I ! 4 68 0000000000 19053 O0 000 O0 0 1 ! I 4 68 0000000000 19053 00 OO0 O0 0 1 1 ~ 4 68 0000000000 --~--~m--...~m...~..m..--.~m.m--.m...mm...mm.......~.....m~m.mmm...~....m DATA DEDT, Rp. MwD RHOP.MWD D~PT. RP.MWD RHOB,MWD RP:MWD RMOB.MWD DMSO. ~P,MWD RMO~.MWD RHOm.~WD 11766' -999. -999. 500° 11000 2. 10500. 2. 2. 10000. 2, 2. 000 250 250 O0 24 37 0o0 571 8OO 00o 311 475 00o 692 509 GR.MWD =999 ~50 ROp. MWD 1.167 RA :MWD - . . so .p DRHO.MWD -999,250 GR,MWD 36,377 ROP :MWD 39,359 RA MWD CALN~..' MWD 10,!92 _mEF:MWD 2.865 NPHI'~WD. o o.,wo -o.o,s , '999.250 '999.250 66.883 26.122 2.120 39.749 2.300 30,766 2.774 29,000 chlumherqer Alaska ComputXnq Center 25-MAR-Igg3 08:39 PAGE D~PT' 9500,000 'GR,MWD 86.247 ROPi, MWD RP.NWD 2,340 CALN,MWD 10.113 PEF,~WD RHOB,NWD '2.,442 DRHO,MWD 0.00] RP':MWD ~99,250 CALN,~WD -,~v999, PEF,MWD RHO~.~WD -999,250 DRHO,MWD '999,250 END OF DA'~A ** ,:262 RA'MWD ~0~-048 NPHI.~WD '999 RA WD -999,250 -999,250 F)L~ NAME .: EDIT ,001 $~RVICE ~ 'FLIC V~IO~ ,: 001~07 LAST FI~ FIL~ ~A~E : EDIT .002 SERVICE : FLIC VERSION ~: O0~A07 DAT~ MAX REC SIZE : 10~4 LAST FILE FILE NEADER FIL~ NUMBER 2 RAW MWD Curves and log header data for each bit run in se6arate files, BIT RUN NUMBER:. 1 D£PTH INCREMENT: 0.5000 FTL~ SUMMARY VENDOR TOOL CODE START DEPTH CDU 9203,0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 11560,0 11560.0 05-MAR-g3 V4,0 IS Tape Vert~'lcatio. Listing chlUmberaeT Alaska Computino Center 25-MAR-lEg3 08:39 PAGE: DATA TYPE (MEMORY OR TD DRILLER (FT)t TOP LOG INTERVAL ~OTTOH LOG INTERVAL mit ROTATING SPEED HOLE INCtINATION MINIMUM ANGLEr ~AXI~U~ TOOL STRING~ (TOP TO BOTTOM) VENDOR TOOL CODE TOOL CON NEUTRON/DENSITY CDR R~$ISTIVITY $ BOREHOLE AND CASING DATA OPEN MOLE BIT SIZE DR!bL'ER$ CASING DEPTH (FT): 8OREHOLE CONDITIONS MUD TYPE~ ~UD DENSITY (LB/G): ~UD VISCOSITY MUD MUD C~LORIDES FLUID L055 RESISTIVITY (OH~M AT TEMPERATURE DEGF) MUD AT ~ASURED TEMPERATURE ~UD AT MAX CIRCULATING TE~PERATU~E~ MUD FILTRATE .~T ~UD CAKE AT NEUTRON TOOL ~ATRIX DENSITY: HOL~ CORRECTION (IN): TOOL STANDOFF (IN): EW~ FREQUENCY (HZ): ii765.0 NOS040 g 875 10,~10 o 6.' o SANDSTONE 2.65 9. 875 ~E~ARKS: ********** RUN I ********** BITBIT TO TO RESNEuT511~720'.B . MATRIX DENSITY ~ 65 (G~/CC), FLUID DENSITY 1 0 (GM/CC~ DOWNHOLE SOFTWARE VERSION V4.0. · $ LIS FORMAT DATA chlumberoer Aias~a Co~putin~ Center 25-~AR-1993 05:39 DATA FORe'AT SPECIFICATION RECORD ** SET TYPE TYPE REP~,CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 5 66 6 73 7 65 Il 66 17 12 68 13 66 0 14 65 FT 1~ 66 68 16 66 0 66 mmmm~mm D~PT ~Op~ bW hTR LW PSR LW TAB LW DCAL LW P~F LW T~PH LW DOHT LW RHOB LW D~HO 5W T~ LW HEFA LW ** SET TYPE - CHAN ** ERV UNIT SERVICE API ~PI APl AP1 FIL~ NUMB ~U~B SIZE REPR PPOCE$S ORDER # LOG TYPE CLASS ~OD NUmB SA~P ELEM C~DE (HEX) FT 6190.53 O0 000 00 0 2 1 1 4 68 0000000000 GAP! 619053 00 000 O0 0 2 I 1 4 68 0000000000 F/HR 619053 00 000 O0 0 2 1 1 4 68 0000000000 OHM~ 619053 O0 000 O0 0 ~ 1 I 4 68 0000000000 OH~ 619053 O0 000 O0 0 2 t 1 4 68 0000000000 619053 00 000 00 0 2 I ! 4 68 0000000000 IN 619053 00 000 00 0 2 I I 4 68 0000000000 619053 00 000 O0 0 2 I I 4 68 0000000000 PU 619053 00 000 00 0 ~ 1 I 4 68 0000000000 PU 619053 00 000 00 0 2 1 1 4 68 0000000000 G/C3 619053 00 000 00 0 2 t 1 4 68 0000000000 G/C3 619053 00 000 00 0 2 1 I 4 68 0000000000 619053 00 000 00 0 2 1 1 4 68 0000000000 CPS 619053 00 000 00 0 2 1 1 4 68 0000000000 CPS 619053 00 000 00 0 2 I I 4 68 0000000000 ** DATA DEPT. PSg. LWi TNP~,LWl -999.250 -999.250 -999,250 IS TaPe Verification List~n~! chlUmberget Alaska ComputinO center. PSR.L~! . 62.,791 TAB,LW! N 999~250 DP~I.bWl T....P~ T~BD~:LW1 3'9~6 gENA.LW'~ oo 'ooo P~R,LW1 ,489 TAB,bWl TNPN.LWI 38,1700' DPHI"LW! T~BQ.LWi 8.900 MENA.bW! PS~.t, W1 140 TgP~LwI 25'600 DPHI'LW! TA~D:LW1 4.271 HENA.DWI ooo .ooo PS~'LW! '798 TAB,LW~. TNPM,PWI 31,800 DPHI:~LWl TaBD,LW1 1,292 ~ENA,Lwl DEPT, 9500,000 GR'LW! PS~,LWl 2,.282 TAB,LWl TNPN,LWi ~9-600 DPHI~'LW TRBD.LWi 1.519 RENA-LWl D~PT. 9202.500 GR"LW! PSR.LW! -999:,~50 TAB'LW! TNPH,LWl -999, 50 DPHI,LW! TRBD.LW~ -999,250 H~MA.LW1 END OF DATA **** FILE FIL~ NAME SERVICE V~R~ION DaT~ MAX REC SIZE F?LE TYPE LAST FILE **** FILE FILM NA~E SERVICE VERSION D~TM ~AX REC SIZE FILF TYPE LAST FILE TRAILER **** EDIT .002 FblC 001A07 93/03/~5 1024 LO HEADER **** : EDIT .003 m FLIC : 001A07 : 03/03/25 : I0~4 I LO 25-~aR'1993 08139 , 3,936 DCAL,LW! 999.250 RHOB.LWl -~99,950 HEFA,LWl 144.827 ROPE,LWI 0,73! DCAL,:LWl 7'600 RHOB..LW1 230.500 MMFA.bWl · 354 rbP~'bw! 9~,:064 DCAL,LWI .!2'300 R~OB.bWl 248'500 MEFA,LWl 9,000 RHOB,bW! 246'500 8~'608 DCtL,bWl 9 800 RHOB'bWl 24}:667 HEFA.LW! .o99. 5o 50 ~..bWl -~9~.~ DC b. -999, 50 RHOB,LW1 -999,~50 H~FA,bW1 . 351~967 999.:~50 0.6 1 4.t22 5'756 .163 2.502 5'085 0'~70 o488 99.250 4.810 ATR'LWl PEF.L:Wl DRHO.LW! PEF.LW1 DRHO.LWl AT~.L'w1 PEr' LW 1 DRHO.,LW1 ATR.LWl PEr.,Lwi D~HO.LW1 ATR,LwWi PEr.L.. DRHO.LWJ. ATR.LW! PEF.LWI DRMO,LWX PAGE: 9 999,250 '999.250 2' 043 5 037 3; 222 099 '0,002 0.013 ],145 ,185 0.018 ~ggg, 250 .999. 250 999'250 IS Tape V~rificat~o~ I..,ist~ng chlumber~er AlasKa Computing Center 25-MAR-l, gg] O8:39 RAW MWD Curves and log' header data ~or each bit Fun in separate files, BIT RUM NUMBER: 2 DEPTH INCREgENT: 0.5000 # VENDOR TOOL CODE START DEPTH CD~ 11~8~.0 CDN 11380.0 hOG HEADER DATA DATE LOGGED: $OFTWARE~ SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TI~E): TD D~ILLER · STOP DEPTH 1.1646,0 11646,0 V~NDOR TOOL CODE TOOL TYPE CDN NEUTRON/DENSITY CDR RESISTIVITY $ ~O~EHOLE AND CASING DATA · OPEN HOLE BlT SIZE (IN): D~ILL~RS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: ~UD D~NSITY (LB/G): MUD VISCOSITY MUD ~UD CHLORIDES (PPM)~ FLUID LOSS (C~)~ RESISTIVI?Y (OHH~ AT TEMPERATURE DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT ~X CIRCULATING TEmPERATUrE: ~UD FILTRATE AT ~UD CAKE AT MT: ~EUTRON ~.~TRIX: ~ATR!X DENSITY: LIP-2'2 V4,0 11765'0 9208,0 11765*0 TboI., NUMBER ND$049 RGS058 g,875 3912.0 10,10 0,313 0,133 68.0 SANDSTONE 2.65 ~chlumberqer AlasKa ComputinO center 99.3 08:39 TOOL STANDOFr (IN)~ ~'WR FREO!,JENCY BIT:TO RES.28.i?', BlT TO GR 38.79', B 98'01' .BXT TO ~gUT I04'2~ .: D~iLLED ~NT~RVALI560 TO 11647' ~ASHDOWN XNT£RVAL ~80. TO 1~56~'. HATRIX OEN$~T¥ ~.65 (G~/CC~ ~LUID DENSITY ~.0 (GH/CC) DOWNHOLE SOF:TWARE V~RSI~N $ FORMAT ~ATA PAGE{ DATA FORm{AT SPECIFICATION nECOIRD ** SET TYPE - 64EB:*** ,TYPE :REPR 1 6 mm m mmmmm ~mmmm~m 6 3 73 4 66 6 73 7 65 8 68 9 65 1! 66 12 68 12) 66 14_ 65 15 66 16 66 0 66 0 0 6O 0 ! ! mmmmmll~mmmm~mmmmmmmmmmmmmm~mm## mmmmmmm#mm#mmmmmmmmmmm~ mmmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mm~mmmm~m~mmm~mm~m#mm D~P? FT 619053 O0 000 O0 0 3 ], 1 4 68 OOO0000000 GR LW2 GAPI 61905) O0 000 O0 0 3 1 I 4 68 0000000000 R~PE LW2 F/HR 619053 00 000 O0 0 3 i t 4 68 0000000000 ATR LW~ OH~ 619053 00 000 O0 0 3 ! 1 4 68 0000000000 PSR LW2 OHM~ 619053 O0 000 O0 0 3 I i 4 68 0000000000 T~B LW~ 619053 O0 000 O0 0 3 1 I 4 68 0000000000 DCA5 bW2 IN 619053 O0 000 O0 0 ) ! 1 4 68 0000000000 PEF bW2 619053 00 000 O0 0 3 1 I 4 68 0000000000 chlumberrler AT ~aska ComDutln~_ Center '""'"'"",~p, [~ ~,, .... '"'""""~,,9o~a oo .... o.;;"""'"'"~oo o ........ ~ "'"'"'"'"'"'"'"'~ ~ ~ o ;~;;~;o D~,, ~.~ ~u ~oos~ oo ooo oo o ~ ~ ~ 4 ~O oooooooooo RHOB ~W2 G/C3 619053 O0 000 O0 0 3 I I 4 68 0000000000 D~HO LW2 G/C3 619053 O0 000 O0 0 3 ! I 4 68 0000000000 TABD LW2 619053 O0 000 O0 0 3 ! I 4 68 0000000000 NE~ LW2 CPS 619053 O0 000 O0 0 3 1 I 4 68 0000000000 HEF~ LW2 CPS 619053 O0 000 O0 0 3 I 1 4 68 0000000000 ** DATA D~PT. 1~646,500 PSR,LW~ -999,250 TRB'LW~ TNPM.LW~ -999"~50 DPf{I'LW2 T~BD.LW~ -999'~250 HENA'LW2 ~S~.'I.,W~ 36.204 T~P~.LW2 ~4'400 DPHI-LW2 TRBD.LW2 0.883 ~ENA.LWR DEPT. ~!380,000 GR'LW2 PSR bW~ '999.~50 T~P~iLW2 -999.~50 DPHI'LW2 TABD LW9 -999.250 HENA.LW2 ** END OF DATA -999o~50 RbPE'hW2 -999. ,999,~50 DCAL.LW2 50 RHOB,,LW2 -99.000 HEFA'BW2 36,~ 1 ROPE'bW2 O, ~8 DCAL.LW2 15'900 RHOB,bW2 257-I07 ~EFAo. LW2 -9~9.~so ~Op~,~w2 :999,~50 DCAB,bW~ 999.~50 RHOB.LW~ -99.000 ~EFh,LW2 '999-250 ATR-LW2 -Egg ~5o PEr-[W:2 -999~ 50 DR~O.LW2 =999. 250 .,~o,~so -Egg' 250 -Egg,250 6 6 =0,013 -999.250 -999'250 -999.250 **** FILE TRAILER FTL~ NA~E ~ EDIT ,'003 VKRSION : O01AO7 D.[T~ : MAX REC SIZE ~ ~0~4 FILE TYPE : LO LAST FILE **** FILE HEADER **** Fib? NAME : EDIT .004 SERVICE : FLIC V~RSION ~ O01A07 D~T~ : 93/03/25 ~AX REC SIZE ~ ~0~4 FIL~ TYPE ~ LO ,IS Tape Verification Listing c~lumberger AlasKa Computin~ Center 25-MAR-lgg3 08:39 C,, . PA~E. F~b~ HEADER FILE NUMBER 4 R~W MWD Curves and log header data for each bit run ~..n se6arate files, BIT RUN NUMBER: 3 DEPTH INCPEMENT~ 0.5000 # FtLF SUMMARY VENDOR TOOL CODE START DEPTH ..... ........ !1476, CON 11476,0 LOG HEADER DATA DATE LOGGED: SOFTWARE~ SURFACE SOFTWARE VERSION: DOWNHOSE SOFTWARE VERSION: DATA TYPE CM~MORY OR R~AL-TIME): TD DRILLER TOP I,O~ INTERVAL ~OTTOM LOG INTERVAL ~IT ROTATING SPEED HOLE INCLINATION (PEG) ~INIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH I~765,0 TOOL S~RING.. (TOP TO BOTTOM) VENDOR TOO5 CODE TOOL TYPE CON NEUTRON/DENSITY CDR RESISTIVITY S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYP~: MUD DENSITY (LB/G): MUD VISCOSITY CS): ~UD MUD CHLORIDES RESISTIVITY (OHMM AT TEMPERATURE DEGF) MUD AT MEASUWED TEMPERATURE (MT): ~UD AT M~X CIRCULATING TEMPERATURE: ~UD FILTRATE AT MT~ MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 05-~AR-93 LIP-~,2 V4,0 MEMORY 11765,0 11765,0 TOOL NUMBER NOS. 049 RGS058 9.875 3912.0 10,10 0,313 0,133 68.0 68.0 SANDSTONE 2.65 Is ?a,~e verification bE chlumber.~er Alaska Comp center· 25-MAR'Igg3 08.'.39 4~ ~IT ~0 G~ 38.81', BIT TO MATRIX DENSITY ~ 65 (G~/CC). FSUID DENSITY ! 0 DOWNHOLE $OFTWA~ VERSION V4.0, " $ I,,~$ FORMAT DATA, 11765' I¸4 DATA FORMAT SPECIFICATION REcO~D ** ** SET TYPE - 64EB TYPE REPRo, CODE VALUE t 66 o ~ 66 0 3 73 60 4 66 1 5 66 6 7 65 8 68 0 5 9 11 66 17 12 13 66 0 14 65 FT 15 66 68 16 66 0 66 I ** SET TYPE NRM~ SERV NIT SERVI ID ORDER D~PT GR LW3 ATR DCAL m FT 619053 O0 000 O0 0 GAPI 619053 O0 000 O0 0 F/HR 619053 O0 000 O0 0 OH~ 619053 O0 000 O0 0 OH~ 619053 O0 000 O0 0 619053 O0 000 O0 0 IN 619053 O0 000 O0 0 619053 O0 000 O0 0 - CHAN ** .;;'""'"" ---.----._ -........ APl APl ~'"~ NUMB ~ "~;~'"'~OCESS # GO~ TYPE 0~A$$ "OD "UPB SAMP E~E~ ¢OD~ (HEX} 4 1 1 4 6B 0000000000 4 ! I 4 68 0000000000 4 ! 1 4 68 0000000000 4 ! 1 4 68 0000000000 4 1 1 4 68 0000000000 4 1 1 4 68 0000000000 4 ! 1 4 68 0000000000 4 1 1 4 68 0000000000 AlasKa ComPutinO Center 25-MAR-1993 08:39 PAGEI 15 ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) m~m mmm~.~ mmmm~mmmm~mmmmmmmmmmmm~m~mmmmmmmmmm mmmm~mm LW PU 619053 O0 000 O0 0 ~ ! 4 6B 0000000000 DPHI LW] PU 619053 O0 000 O0 0 4 ! ~ 4 68 0000000000 RHOB LW3 G/C3 619053 O0 000 O0 0 4 ~ ~ 4 68 0000000000 D~HO LW'3 G/C3 6~9053 O0 000 O0 0 4 ! I 4 68 0000000000 TABD LW3 619053 O0 000 O0 0 4 ! ! 4 68 0000000000 H~N~ LW3 CPS 619053 O0 000 O0 0 4 ! I 4 68 0000000000 H~Fa LW3 CPS 619053 O0 000 O0 0 4 1 I 4 68 0000000000 ** DATA ** DEPT..W {~765'000 GR'LW3 -909.~ RbPE'bW3 . I3'.267 ATR'LW3 s° 50 DCAL'LW3 .999.250 PEF,LW3 T~P~.L:W3 -999,250 DP~I,LW3 -999.~50 RHOB,LW3 :999,250 DRHO.LW3 TABO.LW3 9.2'50 HENA.LW3 254.917 HEFA-LW.3 223 DEPT' ! 1:476'000 GR'Lw~ -999.~50 ~O.E, bW3 -999'250 ATR.LW3 PSR.LW3 -999,~50 TAB.LW13 -999:~50 DCAI~'LW3 999-250 PEF,LW3 TNP~,LW3 '-999,,~'50 DPHi,LW3 -999 50 RHOB,LW3 ~999.~50 DRHO.LW3 TA~D,LW3 -999,~50 HENA,LW3 -999'950 HEFA,LW3 5.200 9,250 ~g.250 · .0~0. -0.015 .999°250 999°250 ** END OF DATA ** **** FIL~ TRAILER **** FIL~ NAME : EDIT .004 SFRVlCE I ~LIC VERSION : 00~A07 DAT~ ~ 93/03/25 ~AX R~C SIZE FILE TYPE LAST FILE **** TAPE TRAILER **** SERVICE NA~E : EDIT DAT~ : 93/03/25 O~IGIN ) FLIC T~P~ NA~E ~ 931!! PREVIOUS TAPE COMMENT : ARCO ALASKA INC., POINT MCINTYRE, P1'14, API 50-029-22338-00 ;ChlUmber~er AlasKa Com~utln~ Center 993 08: 39 PAGE: 16 ORigIN : Fb!C NAME ~ q3~.!l CONTI.NU~TIO~) # COMMENT ~ ARC0 ALASK~ INC., POINT MCINTYRE, Pi-14, 'API WELL NAME : PI-~4 FIELD NA~E : POINT MClNTYRE BOROUGH ~ ~O~TH SLO~ STATE ~ ALASEA API NU~B£R : ~0-099-22]~8 REFERENCE NO ; **** REEL HEADER ****- SERVICE NAME ~ EDIT DATF ~ 93/05/~0 ORICIN REEL MAME I 93~!! CONTINUATION # E IOUS REEL : COMMENT : ARCO ALASKA INC., POINT MCI,TYRE, Pl-'14, API 50'029-2~338-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE ~ 93/05/20 O~I~IN : FLIC TAPE NAME ~ g3111 CONTINUATION # P~VIOUS TAPE CQ~ENT : ARCO ALASKA INC., POINT ~CINTYRE, PI-14, APl 50-029-22338-00 TAPE HEADER PRUDHOE BAY PWD/p~D LOGS LoGGinG CO~PANYI T~Pg CREATION DATEi #. JOB DATA OPeRaTOR WITNESS~ SURFACE LOCATIOw SECTION: TOWNSMIP: FNI~: FSb: FEb: FWLI FLMVATION(FT FRO~ ,SL O) KELLY BUSHINg: DERRICK FLOOR: GROUND LEVEb~ # 93111 93111 93111 jACKSON JACKSON jACKSON PPtVOZNIK PRIVOZNIK PRIVOZNIK 1ST STRING 9ND ST~ING OpEN HOL..E 16 ! 2N 14E !414 823 50,00 50.00 9.00 CASING ~)RII~LERS BTT SIZE (IN) SIZE (IN) D~PTH IINmN)MI))III INNIINNII 9.875 10,750 3912,0 PAGE~ CS Tape verJficatlon Listing ;hlumberqer Alaska Computing Center 3RD STRIHG PRODUCTION STRING # R~M~RKS: COMPUTING CENTER REMARKS: THIS TAPE. FORMAT HAS BEEN' MODIFIED TD INCLUDE FILE 5: COMPOSITE LWD CURVE~ THAT HAYE HAD ~DDIT'IONAL DEPTH CORRECTIOn.IS APPLIED TO BE USED TO MAKE CROSSPLOTS FOR COMPARISON TO ATLAS WIRELINE DAT~ FILE 6~ ENHANCED CDR DATA CpROCESSED FRO~ THE DATA IN FILE 5), FIELD ENGINEEr'S BIT TO ~$ ~8,17',..BIT TO GR 38'79' V' BIT TO DEN BIT TO NEUT ~04.24' DRILLED INTER.AL 1~560' TO WASHDO~N INTERVAL !{480 TO 1~560' *~**~***** RUN 3 BIT TO RES ~ 39' BIT TO GR 3B,81', BIT.TO DEN 56,71~ i'6wASHDOw"i 4 ZNTERVAL 11540' TO 11647' 7' TO i1765', ~AT~IX DENSITY 2.65 (GM/CC), FLUID DENSITY 1,0 (G~/CC) SOFTWARE VERSION V4,0, $ $ 120.94i 1560' ', 98,01' I1647". FIbK NA~E : EDIT .001 V~ION ~ O01A07 D~TE ~ 9~/05/20 ~AX. BEC SIZE ~ 1 ~4 FIL~ TYPE : LO L~ST FILE PAGE,'. FILE HEADER FILE WUMBER~ 1 EDITED ,E~ED ~WD Depth shltte~ and cl~PPed curvesl all bit runs merged, DEPTH IMCRE~ENT 0.5000 # FILE S!J~ARY KRU TOOL CODE CD~ $ B.SELINE CURVE FOR SHIFTS: GR CURVE SHIFT DAT~ (MEASURED DEPTH) START DEPTH 9~0n.0 9278.0 STOp DEPTH m~m~mm~m~qmm~m~.mmm 117!0,0 I17]~,5 IS ?ape Yeri~-lcatton L~stin~ :hiumberoer AlasKa Computtn~ Center PAGE{ ~A 1 1 1 I !. DEPTH ~60 I~36 1220 1~03 1198 118~.0 1t5~.5 I132,5 I 18.5 1079. 0 t 064~0 t035.5 0~94 0 0969 5 0956 0 09]4 0 0920 5 · 10804,0 ~0753,5 107~3,5 10644,0 !063~,0 ~06~6 5 10475,5 ~0429o0 ~03g6,0 ~0370,0 · ------~---£OUIVALENT uNSHIFTED DEPTH--------'' M~ ~690.0 11676 !1660,0 !1637,5 11601.5 11476'5 1146~ 0 1146 1143~,5 1141 1137] 1334 .~5 113~.0 11300,0 11~96,0 11269.5 11~35,5 tlt?g,0 11148,0 !1177,5 1111~,5 11057,0 11029,0 10986.5' 10980,0 10967.5 I0954,5 !0932,0 1091~,0 10875.5 10~28,0 1080],0 10751,0 !0716,5 10711,5 10647,5 10642,0 !06~9,0 10613,5 10597,0 10540,5 10536,0 10474,9 10425.5 10~89,5 10364,5 Chlum. er.oer lasza ¢omPutln~ Center !036t'0 10291 ~.0275 0 ~10256 0 ~023~ 5 10159 5 ~0116 5 0~04 5~ 9998 5 9947 5~ 9969 5 9852 0 9808 0 97870 9749 0 96090 95570 9~2t 5 9493 5 9474 5 94370 94.23 0 9411. 0 9~5~ 5 9337 O 9333 0 9293.5 $ ~00.0 MERGED DATA sOUrCE KRU TOOL CODE .... .. U~D $ R~M~RKS! 10~46,5 ~0287,0 lo s1,$ !0155,5 01i4.5 10040'0 9997,5 9944,5 9868,5 9~06o5 9 88.0 9748,5 9612.0 9556.0 9519,0 9491,0 9472 5 94t0,0 9359.0 9~35o5 9330,0 97,5' BIT RUN NO. MERGE TOp MERGE BASE ~ 9200,0 115~0'0 2 11560,0 11647,0 ] 11647,0 11765.0 THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT MWD GR TO ATLAS WIRELIME GR OF 06-~AR-93. ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT, LIS FORMAT DATA ~h~umberqer ~a$~a Comput~nQ Cente~ 20-MAY,,!. 993 15.'46 DATA FORMAT SPFC!FICATION RECORD TYPE - 64EB TYP~ R~P~ C~DE V!LUE I 66 0 2 66 0 ] 73 40 4 66 l 5 66 6 73 7 65 9 ~5 t~ 66 0 14 65 FT 0 66 0 DEPT GR MWD ROP ~WD R~ P~F MWD NPHT MWD ~OB D~O ~W~ N~ S£RV U~IT ID ~m~m~..m.~m~.~ FT GAPI F/HR OH~ IN BN/E PU-S TYPE - CHAN ** SERVYC~ API AP! AP1 APY FIY,~ NUMB NUmB SIZE REPR PROCESS ORDER # LOG TYPE Ch~$S MOD NUMB S~MP ELEM CODE (HEX) O0 00'0 O0 0 1 1 1 4 68 O0 0 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 I ! I 4 68 0000000000 O0 000 O0 0 I ! 1 4 6~ 0000000000 O0 000 O0 0 1 1 I 4 68 0000000000 O0 000 O0 O ! 1 I 4 68 0000000000 O0 000 O0 0 I I I 4 6~ 0000000000 O0 000 O0 0 1 1 1 4 69 0000000000 O0 000 O0 0 ! I 1 4 68 0000000000 O0 000 O0 0 ! I 1 4 6~ 0000000000 mmmm~mmmmmm~mmmmmmmmmmm~mmmmmmmmmmmmmmmmm! ** DATA D~PT, RD.MWD RHO~.MWD D~PT. RD,MWD RHO~.MWD 11765,000 GR.MWD =999.250 -999,250 CALN.MWD -999.250 -999,~50 DRHO,MWD -q99,~50 11500,000 GR,MWD 36.851 6~,79t CALN._MWD 0,332 2,3~,9 DRHO.~WD -0,013 ROP,MWD 13.167 RA.MWD PEF,~WD -999.250 NPHI.MWD ROD,MWD 35'967 RA.MWD PEF.MWD 2.793 NPHI.MWD -999.250 -999.250 62.990 24.4O0 ~htumberqer Ala$~a~ Computing Center DEPT. {t000.O00 G,.,WD t44'827 ROP,'M'WD RP..MWD 2,,:'489 CALN MWD 02~11 PEF.MWD RHO~.MWD }.5;5 DRMO:~WD 0_,24 DEPT. 10500.000 qR.MWD 90.354 ROP,MWD ~ MWD ~.~40 CA[N,~WD 0.~08 PEF'~WD RHOB~WD 2.447 DRHO.MwD -0.00~ D~PT. iO000.O00 ~R.MWD 90,571 ROP,MWD RP.MWD },798 CALN.MWD 0,~6) PEF.MWD RHOD.MWD 2:455 DRHO.MWD 6 018 RP.MWD ~99'9,250 CALN.~WD -q99,~50 PEF,MWD ~HO~.MWD 999,250 DRHO.NWQ END OF DATA 83'~720 RA'MWD §.O~7 NPHI.MWD 62'~g5 RA'MND 3.099 NPHI.MWD 1{{' ~6 RA'MWD 3~i$ NPHI.MWD t07~ 86 RA,MWD gg~.Q '~50 NPHI,MWD PAGE: 38,700 2§,600 2'801 3128OO 2'145 29.600 :-999'2 0 SERVICE : V~RSlON ~ 001 07 DATE : 93/05/}0 ~Ax REC S~ZE : 1024 FTL~ TYPE : LO LAST FILE **** FILE HEADER ~*** FILE NAME ~ EDIT ,002 SERVICE ~ FLIC VERSION { 00lA07 D~TE { 93/05/}0 M~X REC SIZE { {024 FI~E TYPE : LO LAST FILE ~ FYL~ HEADER FILE NUMBER 2 RAW MWD Curves and ~og header data for each bit run ~n separate f~Xes. BIT RUN NU~BER~. 1 DEPTH INCRE~ENT~ 0.5000 FILE SUmmARY 'h ~ lumberger Alaska COmputin~ Center 20-MAY'1993 15':46 PAGE:: LOG HEADER DATA DATE LOGGED: START DEPTH 9203.0 SURFACE SOF:TWA~ VERSION~ DOWNHOLE SOFTWARE VERSION~ DATA TYP~ (~E~ORY OR REAL-TIME): TD D~ILLER (FT): TOP LOG INTERVAL (FT)t ~OTTOM LOG INTERVAL {FT)~ BIT ROTATING SPEED.(RPM)~ HOLE INCLINATION (DEG) ~IN~MUM ANGLEI ~AXINUM ANGSE~ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR NEHT~ON/DENSITY CD~ RESISTIVITY $ BOREHOL. E AND CASING DATA D~ILLERS CASING DEPTH EHOLE CONDITIONS MUD ~UD DENSITY {LB/G): ~UD VISCSSITY MUD ~UD FLUID LOSS (C3)I RESISTIVITY [OHMM AT TEMPERATURE DEGF) MUD AT MEASURED TEMPERATURE (MT)~_ ~UD AT ~AX CIRCULATING TE~PERATUPE{ ~UD FILTRATE WUD CAKE AT MT: NEUTRON TOOL MATRIX~ MATRIX DENSITY: HOL~ CORRECTION TOOL STANDOFF ¢IN}= EW~ FREQUENCY (HZ.)~ ~E~APKS: STOP~DEPTH 115 o V4,0 ~EMOR¥ 1~765,0 TOOL! NUMBER ND8049 RGSOLB 10.1'0' 0,313 SANDSTONE _ ~.65 (IN): 9,975 ********** RUN 1 BIT TO RES 51 0.' .BIT TO GR 61 2'. BIT T? DEN BIT TO NEUT 1~ 1~' DRILLED INteRVAL 9350 TO 68.0 68.0 ~m~mmmmmmm~mmm~mmmmmm~ 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 8~ 0000000000 89 0000000000 89 0000000000 89 0000000000 89 mmmmmmmm~mmmmmmmmlmmmm (X~N) 3QO~ mmm~m~#mmmm~mmmm~mmmmmm~m~mmmm~mmmmm ~ ~ I ~ 0 O0 o00 ~ ~ [ ~ 0 O0 000 O0 ~ t ~ ~ 0 O0 000 O0 ~ ~ ~ ~ 0 O0 000 O0 ~ ~ ~ ~ 0 O0 000 O0 ~ ~ t ~ 0 O0 000 O0 ~ ~ ; ~ 0 O0 000 O0 ~ ~ ~ ~ 0 O0 000 O0 ~ I ¥ ~ 0 O0 000 O0 ~ ~ ~ ~ 0 O0 000 O0 ~ ~ t ~ 0 O0 000 O0 ~ I I ~ 0 O0 000 O0 ~ ~ ~ ~ 0 O0 000 O0 ~ ~ ~ ~ 0 O0 000 O0 ~ t [ g 0 O0 000 OO mmmm~~m~mmm~mm~mmm~mmm~mmmm~m mmmmmmmmmmmmmmmmmmmmmmmm#mmmm O0 ~d~ l~q ~J~H ~WHO I~q idVD IMQ mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~ $ DO'l # ~OaO Oi mmmm~mm~mimm~m~mm~m~mmmmm~mmmmmm~mmmmmm#m~m~mm~mmmmmmmm~m~mmmm ili~#mlimmlmmmmmlm~m~m~l~l~m~ I 99 0 I .99 89 99 0 99 89 LI 99 ~ 0 89 8 ~& 9 .99 ~ 99 09 ~L E 0 99 0 99 # $ ':O'~A Nolgu~^ ~UV:~OS.SqOHN~O0 . but3s'tq 0~'666- 0~Z"666- 0~"666- 8[0°0 ~:00 ' O- )0 06~ 0~'~666~ 6.. o~":. §.. IMq'OH~O 0;8'~ 0~'666' 05~'666' 05g~'666- 88~ 98 ~80'~ >, 0~:"666- O~g '666- o~ 16 6 · 000'666' o~: 66- IMq*'~OH~ t~q*qvou , · .. t~q'~ · OSg'666- 0SG'666o 0S~'666~ Ogg'666- OOB 80~*0 OOS'9~. ooo2 6E90 I&~'06 O0~:8)Z OOE ~ ~90 'I ~E'06 O0~'OE,~ 009'~ iE4'O L~8'~ 0S~:666~ 9£6'E O~/SO/E6 = ~0~00 ~ Olq~ = gO0* $I~M': aDIA~g 3W~N ~qI~ 3qI& ~q'IHdO ~aq'lHdO T~q*~NaH ~Mq!i~IH~O buI3s~q uo):~e~'t:)l,zeA e~e~::'S3 0~°0~ ~2~nN 0'80~6 O'~A ~NOI&IGNU3 ~(NI) 3Zig &lB ~OH N2dO $ A~IAI~I~H 803 X~I~N3Q/NO~&Q3N m~m~ ~~m~m~m ~ qOO& ~QOD qOO& ~OQN3A (~O~Og O& dO&) 'DNI~&~ qO0£ 0'9~9~:~] 0'9)9{~ (92Q) NOI&~Nlq3NI {(~M) q~AaM~NI ~0'I :NOI~A ~VM~&O~ :NOI~A 3~M&~O~ :QMD909 V~VO a~O'V~H O'08Elt NQO H~d30 &B~S 3QOD ~OO~ 80QNMA 0009'0 :~N~A3~DNI H~d3O g):Si E66I'AVW-OE :. 3qi, 3 Oq : 2dA~ O~/SO/E~ : LOV~O0 ~ £00' ~iqM : :3~VN 3qlM [ 99 0 ~ 99 9~ 89 99 ~ 0 99 E] 89 ~ L~ 9~ ~ ~ 99 ~ 09 ~4 ~ 0 99 ~ 0 99 ; · , # $ · o · ********* g aha ********** 0'89 0'89 EEI'O ElE'O :(NI.) NOI~J3~aOJ ~QOH :XIa&YW qOO& :Hd Ofl~ 9~:~ E661'AVW=O~ bU~lStq uolle~llI~A cae& ~I oq ~ 0~/60/£6 ,' LO~ [00 ~ £00 * ~IQ3 ~ 0~'666- 06~'666- ~Mq'OHBO 06~'666' 0~ 666- ~Mq"~&V 0~ 666' · EIO'O- g~q'OHaO ~8~.~ g~q'~OHa 9t9'19 ~q'~&V 9(SE9 0~666- ~Mq'VJ3H 0~'~:666- ~q'OHaO OS~: 666- 0~[666- ~q*J3d 0~'66~C 0~666- g~"a&~ 0~'66 '000 '0~( O~g 0O6 8£8 000 O~ '66' '666- ~666- '666- 'L~ '0 'gE '66- "666' . 66 666' ~'IHdO O0~'t~ ~Mq~hdN£ .t~m~mmm,mmmmmmm m m mm~m mm mmm m mmmmmm mmmm#m~m~mm~mm 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 89 (X3H) 3003 · I i ' mmm~mmmmmmm~{~mmammmm O0 000 O0 ~Aq oO 000 O0 ~NHO ~Mq O0 000 O0 ~HO ~Mq O0 000 O0 aH/~ ~q 3dO~ O0 000 O0 IdV9 ~q O0 000 O0 ~3 , , , .- . w~q, 3 d~g ~WflN 0o~ ~g~'q~ MdA& 90'1 ~ a~ao ** NVHD - 3dX.& &M~ ** g~:~I E66I-AVW-O~ ouT3s~q uot3eoI~t2eA ede~.g] v'erE ic tion L $ting c'hiumbergerAles~ Computlno center PAGE:) **** FILE HgADER FIL~.~AME : EDiT °004 Si~RVICE .! FLIC VE~SIO... : oo~AO7 DATF ' ~AZ RZC::SIZ~ ~ 1024 FILE TYPB { LO LAST FILE FILF_. HEADER FIL~ NUMBER 4 RAW MWD Curves and log header data for each bit run in separate: ~les. BIT RUN NUM~)ER: 3 DBPTH INCRE~ENT~ 0,5000 # VENDOR TOOL CODE START DEPTH CDP 1.1476.0 CDN 11476.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFT,ARE VERSION:~ DOWNHOLE SOFTWARE VERSION{ DATA TYPE (MEMORY OR REAL-TIME)~ TD DRILL~ (FT3: TOP LOG INTERVAL ~OTTOM LOG I~TERVAL [FT)~ ~IT ROTATING SPEED (RPM)~ HOLE INCLINATIO~ (DEG) MINIMUM ANGL~: MAXIMUM ANGLE= '"'"'""' .... C'R "E$ISTIVXTY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING D~PTH (FT): BOREN~LE CONDITIONS ~UD TYPE: MUD DENSITY (LB/G): MUD V~SCOSITY STOP ,. D£PTH · 1:1765.0: t1765.0 OS-MAR- V4,0 MEMORY 11765.0 g208.0 11765.0 TOOL NUMBER RGS058 9 875 10.10 PAGE MUD FLUI. D.bOSS RESISTIVITY (OH~M AT TEMPERATURE DEGF) MUD iT MEASURED TEMPERATURE (~T){' {UD iT MAX CIRCULiTING TE{PERATURE{ {UD FI~T~ATE AT MUD CAKE AT 0,313 0,:!33 68.0 68.0 ~Et!TRON TOOL MAT~IXI ~ATRI×:,DE~$ITYI MOtE CORRECTION ('!N): SANDSTONE TOOL STANDOFF (IN){ EWR FREQUENCY (HZ): BlT TO RES 28.'39" ~XT TO GR ~8'8~,.;. ~IT 'TO DEN 56 ~!" BIT T'O NEUT 62,94$ DRILLED INTERVAl., 11.647' TO ll~o:'' waSHDOW~ iNTErVAl, ~540~ TO ~647", ' ~AT~I~ DENSITY ~,65. (C~/~C).'FLUID DENSITY i~O (~/CC) DOWNHOLE SOFTWARE VERSION V~.O. DATA FORMAT spEcIFICATION RECORD ** SET TYPE - 64EBb** mmmmmmmmmmmmm~mmmmmmmm~~mm I 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 9 65 ' !1 66 17 ~ 68 13 66 0 14 65 rt I5 66 68 16 66 I 0~7.,'666' 666 S[O'O" 0~;0,6 0cJ~ 66' 0~ :666' 666- · m 0~ · ? ' q- · · 000~66 E~Q'.Vj3H 0f$ 666- E~q.~N3H O~g 666- ~rI'OH~O 0~66 E~q':~OH~ 0~"666- i~q..IHdO 0~'66b- E~q'Hd.N& 0000000000 89 ) t I ~ 0 O0 000 O0 gd3 Eaq ~dafl 0000000000 89 ~ I I ~ 0 O0 000 O0 gdJ i~q ~aaH 0000000000 89 ~ I I ~ 0 O0 000 O0 i~q O~ 0000000000 89 ~ I I ~ 0 O0 0~00 O0 E'D/D E~q O~aQ 000000'0000 89 ~ [ I ~ 0 O0 000 O0 (D/D [~q ~OH~ 0000000000 89 ~ I ¥ ~ 0 O0 000 O0 ad ~ iHda 0000000000 89 ~ [ I ~ 0 O0 000 O0 ~d i~ ~d~& 0000000000 89 ~ t '[ ~ 0 O0 000 O0 i~ J3d 0000000000 89 t I I ~ 0 O0 000 O0 NI E~q qVJO 0000000000 89 ~ ~ I ~ 0 O0 000 O0 [~q a~ 0000000000 89 ~ I I ~ 0 O0 000 O0 ~HO E~q a~d 0000000000 89 ~ t I ~ 0 O0 000 O0 ~HO i~q ~V 0000000000 89 ~ I t ~ 0 O0 000 O0 aH/~ i~q ~dOa 0000000000 B9 V I i ) 0 O0 000 O0 ldVD E~q aD O00OO00000 89 ~ I ~ ~ 0 O0 000 O0 ~ ~d~Q 9~:~I E66I.-AVa-O~ Out~sIq uot~eoi'~laeA eae~ gl ~DB~N qO0~ 0'59~6 0'80 O'~A r 0'0~6 0'0~6 :H~d~O dO~ SNOI~IQN03 ~qOH~BO~ ~¢£~) H&d3O DNIS~O S~gqI~O :(NI) 2~I~ ~LB 3qOH N2dO ¥&VQ 9NIR~3 ON¥ 3qOH~O~ $ t&I~N~O/NO~II~N NOD (NO£~OB 0£ dO~) ~DNI~ qO0~ :gqDNV NONiNI~ (~0) NOI~NIqDNI ~qOM :(NdU) O~3d9 DNI~O~ ~I~ :(~2) q~A~2&NI DOq dO~ :NOIgB~A 3B~M~JOg 3qOHNMOG $ O'OOLII NO3 O'OOL;~ uq~ H~d~O ~&S 3002 90OZ BOSNIA 000~'0 :&N~DNi H~dMO ~30~3H . LOVIO0 11 NOIS~A ' 3Iq& 3DIA~3~ 1900' ~103 : I 9~ 9~ 89 9g 0 99 8~ 99 99 0 99 0 99 mm~mmmmmm~mmm~mmmmmmm~mmmm~m ** ~MODMM NOIt~OIMIOMd~ !~MOM ~&VO ** # : # 9£ :(.NI) NOI£ MaaOO ~qo~ ~ :AZIgN~O 0'89 0'89 9~: S i~ ~66 .. bu~s~q uol'~e~~ea:e~e~ gl ~hlumberqer Alas~8 COmputlnO Center 20-~AY-{ 993 15:46 PAGE{ ~.a~F S~RV UNIT SERVICE ~Pl .~P! API API FILE ~U~B NUmB SIZE REPR PROCESS ID -.ORDER # hOG TYPE CLASS MOD NUmB S~P ELE~ CODE (HEX) ''''''''D~PT .... ------------------------------------------------------------------------------FT O0 . O0 0 5 I I 4 68 0000000000 G~ LWD GAPI O0 000 O0 0 5 I 1 4 68 0000000000 !TR LWD OHMM O0 000 O0 0 5 ! i 4 68 0000000000 PSR LWD OHM~ O0 000 O0 0 5 1 I 4 6~ 0000000000 DCAL LWD IN O0 000 O0 0 5 ! 1 4 68 0000000000 PEF LWD O0 000 O0 0 5 ~ 1 4 6~ 0000000000 TNPH LWD PU O0 000 O0 0 5 I t 4 68 0000000000 RHOB LWO G/C3 O0 000 O0 0 5 ! I 4 68 0000000000 DRHO LWD G/C3. O0 000 O0 0 5 1 I 4 68 0000000000 DEPT, 11700,000 GR bW~ 50,082 ATR,LWD 4 051 PSR LWD DCAL-LWD 10,066 PEF']LW~ 2.646 TNPH.LWD 191200 D~HO,LWD 0,003 DEPT. [{500,000 GR~LW~'~ 36,]75 ATR,LWD 63,941 PSR LWD DCAL.LWD 10.,:181 PEF,LW~ ~,611 TNPH.LWD 25,510 RHOB]LWD DE ~I00 OOO GR.D~R ~2 0~0 ATR.bWD ~ 303 PSR.LWD DRHO.I, WD 0,031 DCA .,06i0 004 PEF.LWD 3,306 T~IP~:LWD 30~ 94 RHOB.LWD DRHO,LWD DEPT, iO000,O00 GR,LWD 87.246 ATR.bWD 2.742 PSRoLWD DCAL,LWD 10,045 PEF'LWD 3,225 TNPH,LWD 28,845 RHOB,LWD DgHO,LWD 0,0!2 ~EPT, 9500,000 GR,LWD 86°70? ATR,LWD 2'292 PSR,LWD DCiL'LWD 10,116 PEF,LWD 3,137 T)tPH'LWD 29.689 RHOB,LWD D~MO,LWD D~PT" 9250,000 GR,LWD -999,250 AT~,LWD -999.250 PSR,LWD DCAt,LWD 9,875 P~F,LWD ~,115 TNPH,LWQ 32,033 RBOB,LWD D~MO,LWD 0,017 :1 24 4]2 2,802 2,79i .B12 °520 2,318 2,475 END OF DATA Alaska Computing center 'SERVICE DAT~ : 93/05/20 MAX REC~i:SlZE F!'I'E TYPE ~ LO LAST FILE VERS~O~ : ool~o7 DATE : 93105/20 ~Ax ~c~siZz : 1.o~ FTL~ TYPE: ! ~0 LAST FILE 20,,~4AY'!993 !5:46 FIL~ HEADER FIL~ NUMBER 6 ~A:W ~WD ' :CurVes and lo~ header data for BIT RUN DEPT. INCR~E.T~ o~sOoo FIL~ SUM~ARY~. VENDOR TOOL CODE LOG HEADERs=DATA DATE LOGGED: 1 ! 699,0 SOFTWARE: DOWNHOLE SOFTWARE VER$IONI DATA TYPE CMEMORY OR REAL-TI~E)~ TOP LOG I~TERVAL (FT)~ ROTTOM LOG BIT ROTATING 8P~£D (RPM)~ ~OLE INCLINATION (DEG) TOO[, ST;~ING (TOP TO BOTTOM VEHDOg TOOL CODE TOOL T~PE R~StETIVITY each bit run in seUarate files. STOp DEPTH 9250.5 05-MAR-93 LIP-2,2 V4,0 MEMORY ~765,0 9208.0 1~765.0 89 99 SI 0 99 E~ 89 ~ 9E 99 II S'O 89 8 S9 L EL 9 g9 ~ ~ 99 ~ 0 99 ~ 0 99 t # $ :(NI) NOI'~33B~OD 3'IOH :XI~£Y~ 900~ m.O~3m 0'89 0'89 ETE'O 0]'0~ :(IM] Hid30 9NI~'' ' '~J ~t3qqZi~O :(NI) 3ZI~ J~l~ 3qOH N~dO ~&~O ~)NI~VD r-JN'~ 3qOH3~tO~ O00°O00~ ~L~'~ 9LL': 6L~'~ 9~'t oo~:ooo~ ~O0'~,Sd 000:000~ ~0~'~^~ 000'000~ ~0o'~ ~00'6~ O0 000~ ~O0'Bd~d 000 000~ ~0 *Hd~ OOg'O~6 "~d~ O~E'~ ~O0'~Agd ~LE'~ ~O0'~A~ ~£'~ ~O0"~d ~00'~ 80E'~ ~O0*HdS~ g~'~ ~O0°Hd~ O00'OOg6 ~00'~3~ [LS*~ ~O0*Hdgd ~8'~ ~O0*Hd~ 000'0000~ ~[['[ ~O0'~a~d ~[~[ ~O0'a~[ ~[~'~ ;O0:a~d ;O0'~V ~0~'~ ~O0'.dS~ ~ ;O0'a~ ~[~ ~O0'Hd~d ~'[ ~00'~ ~0'~ ~O0'..~d ~0['~ ;00".~ 000 0~; '~ ~::.~ ~oO'~.d ~:~ ~00'~ ~:~ ~.O0'~d ~O0*~&~ ~E ~ lO0*'Hdgd LEO 0000000000 89 ~ ~ [ 9 0 O0 000 O0 ~dO ~Agd 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 HNHO ~00 0000000000 89 ~ ¥ '~ 9 0 O0 000 O0 a~O ~00 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 ~HO ~00 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 ~HO ~00 nd~d 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 ~HHO ~00 O000000OO0 89 ~ ~ [ 9 0 O0 000 O0 ~ (X3H) ~OOD ~q:~ dW~ B~N aO~ ~g~q3"':~d~$'DOq .':a3Q~O , - JJJJJJJJJJJJJJJJJJJJJJJJJJJJJJ ~ 99 9~ ou l:~ST'l UOl:~eOT a:.T,~eA ~ #~ NOI£~SNi&NoD O~t~O/E6 ~ O~/~O/~b ~ 0~/~0/~ LOttO0 900' &lO3 :
