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Home My WebLink About197-070D :HOO6WDWXV *,1- 2LO E :HOO&ODVV ([SORUDWRU\ 6HUYLFH +LOFRUS1RUWK6ORSH//& 3HUPLWWR'ULOO1XPEHU6XQGU\ */358'+2(%$<358'+2(2,/ D 6XUIDFH 7RSRI3URGXFWLYH,QWHUYDO 7RWDO'HSWK 61/ :(/6HF715( 16/ :(/6HF715( 61/ :(/6HF715( 6XUIDFH[ \ =RQH$63 *DV 63/8*$EDQGRQHG $$& 6XVSHQGHG $$& :,1-:$*:'63/1RRI&RPSOHWLRQV 3%8*$ :HOO1DPHDQG1XPEHU 6XUIDFH 73,\ =RQH$63[ 7RWDO'HSWK[\=RQH$63 1RQH '15$SSURYDO1XPEHU 'LUHFWLRQDORU,QFOLQDWLRQ6XUYH\ <HV 1R 6XEPLWHOHFWURQLFDQGSULQWHGLQIRUPDWLRQSHU$$&IW06/ 7KLFNQHVVRI3HUPDIURVW0'79' ',/63%+&6*5&DOLSHU)'&&1/&$/*5&%/9'/*5&&/*5 &$6,1*:73(5 )7*5$'(6(77,1*'(37+0' 723 %27720 +2/(6,=(&(0(17,1*5(&25'$02817 38//(' /RFDWLRQRI:HOO*RYHUQPHQWDO6HFWLRQ )LHOG3RROV 'DWH&RPS6XVSRU$EDQG 7RWDO'HSWK0'79' &$6,1*/,1(5$1'&(0(17,1*5(&25' 723 %27720 6(77,1*'(37+79' &RQGXFW 1 1 1 / *5$'(3$&.(56(70'79' / '(37+,17(59$/0'$02817$1'.,1'2)0$7(5,$/86(' 352'8&7,217(67 'DWH)LUVW3URGXFWLRQ1$ 'DWHRI7HVW )ORZ7XELQJ 3UHVV 2LO%EO 2LO%EO *DV0&):DWHU%EO 2LO*UDYLW\$3,FRUU 0HWKRGRI2SHUDWLRQ)ORZLQJJDVOLIWHWF *DV2LO5DWLR&KRNH6L]H :DWHU%EO 6HH$WWDFKPHQW 2SHQWRSURGXFWLRQRULQMHFWLRQ"<HV 1R ,I<HVOLVWHDFKLQWHUYDORSHQ0'79'RI7RSDQG%RWWRP3HUIRUDWLRQ 6L]HDQG1XPEHU'DWH3HUIG 1R3DFNHU *DV0&) 3URGXFWLRQIRU 7HVW3HULRG &DOFXODWHG +RXU5DWH +RXUV7HVWHG &DVLQJ3UHVV $&,')5$&785(&(0(17648((=((7& 78%,1*5(&25' '(37+6(70' <HV 1R:DVK\GUDXOLFIUDFWXULQJXVHGGXULQJFRPSOHWLRQ" 3HU$$&LDWWDFKHOHFWURQLFDQGSULQWHG LQIRUPDWLRQ $'/ 2WKHU 6669'HSWK0'79' 5HI(OHYDWLRQV %)6XUIDFH DWWDFKHG .% )RUP5HYLVHG 6U3HW(QJ 6U3HW*HR 6U5HV(QJ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 :(//&203/(7,21255(&203/(7,215(3257$1'/2* 'HYHORSPHQW 6WUDWLJUDSKLF7HVW 2SHUDWRU1DPH $GGUHVV &HQWHUSRLQW'U6XLWH$QFKRUDJH$. 'DWH6SXGGHG 'DWH7'5HDFKHG 3OXJ%DFN'HSWK0'79' E E/RFDWLRQRI:HOO6WDWH%DVH3ODQH&RRUGLQDWHV1$' :DWHU'HSWKLI2IIVKRUH 1$ $3,1XPEHU /RJV2EWDLQHG/LVWDOOORJVUXQDQGSXUVXDQWWR$6DQG$$&VXEPLWDOOHOHFWURQLFGDWDDQGSULQWHGORJVZLWKLQGD\VRIFRPSOHWLRQ VXVSHQVLRQRUDEDQGRQPHQWZKLFKHYHURFFXUVILUVW7\SHVRIORJVWREHOLVWHGLQFOXGHEXWDUHQRWOLPLWHGWRPXGORJVSRQWDQHRXVSRWHQWLDOJDPPDUD\FDOLSHU UHVLVWLYLW\SRURVLW\PDJQHWLFUHVRQDQFHGLSPHWHUIRUPDWLRQWHVWHUWHPSHUDWXUHFHPHQWHYDOXDWLRQFDVLQJFROODUORFDWRUMHZHOU\DQGSHUIRUDWLRQUHFRUG $FURQ\PVPD\EHXVHG$WWDFKDVHSDUDWHSDJHLIQHFHVVDU\ 3URSHUW\'HVLJQDWLRQ 5HGULOO/DWHUDO7RS:LQGRZ 0'79' DSSUR[ 6XEPLWZLWKLQGD\VRI&RPSOHWLRQ6XVSHQVLRQRU$EDQGRQPHQW By Samantha Carlisle at 8:20 am, Aug 27, 2021 Abandonment Date 8/13/2021 HEW RBDMS HEW 8/30/2021 xGDSR-8/30/21 x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igitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.26 14:07:40 -08'00' Stan Golis (880) 110' 20" x 30" Insulated Conductor 1 Winston, Hugh E (CED) From:Abbie Barker <Abbie.Barker@hilcorp.com> Sent:Thursday, September 2, 2021 2:53 PM To:Winston, Hugh E (CED) Subject:RE: [EXTERNAL] Abandonment report PBU G-03A Hello Huey, Apologies for the delayed response. The variance in TPI that you noted is due to an update in the TPI depth per our Geologist. The TPI value of 9770’ on our form (see box 29 on page 2) matches the uppermost Z1 perf that existed in the well instead of the TSAD depth (8708’) that was the basis for the TPI coordinates and offsets on the form you show below. Please let me know if you have any other questions or need additional clarification. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 From: Winston, Hugh E (CED) Sent: Monday, August 30, 2021 11:11 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] Abandonment report PBU G‐03A Hi Abby, While reviewing we noticed that the original well completion report for G‐03A listed the same values. In order to avoid future confusion in our well history files, can you provide an explanation as to why the values differ? Did you use a revised, recomputed, or more recent directional survey? Thanks Huey 2 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Monday, August 30, 2021 9:51 AM To: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL] Abandonment report PBU G‐03A Awesome! Thank you, Huey! From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Monday, August 30, 2021 9:49 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] Abandonment report PBU G‐03A Alright that did it ڐڑڒڐڑڒ I’ve updated the form. Thanks Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907‐793‐1241 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Monday, August 30, 2021 9:33 AM To: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL] Abandonment report PBU G‐03A Hello Huey, I have reassessed all the information and would like to correct the following information in Box 4A: 3 TPI in Box 4A: FSL 2521, FEL 3067, Sec 12, TIIN, R13. Total Depth in Box 4A: FNL 3224, FEL 4368, Sec 12, TIIN, R13. Please let me know if these updates do not resolve the issues you encountered. Thank you for your continued patience and assistance, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Monday, August 30, 2021 8:12 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] Abandonment report PBU G‐03A Hi Abby, Ok I’ll correct that as well. That is not the original problem I encountered though. Box 4a and 4b should point to the same locations. I have a program that calculates if they do. The SBP coordinates in box 4b for both the TPI and Total depth are pointing to different spots than what is reported in box 4a, each being off by hundreds of feet. Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907‐793‐1241 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Friday, August 27, 2021 4:11 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Winston, Hugh E (CED) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL] Abandonment report PBU G‐03A Hello Huey, I found an error in Section 4a. 4 The first line of 4a should read as follows: “2263' SNL, 1974' WEL, Sec.12, T11N, R13”. Please let me know if you have additional discrepancies or this solves the issue you encountered. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Friday, August 27, 2021 12:30 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] Abandonment report PBU G‐03A Hi Oliver, You are listed as the contact on the Abandonment report recently received by the AOGCC. There is a discrepancy between the coordinates reported in boxes 4a and 4b. Calculated values of the SBP coordinates based on what is reported for the Governmental coordinates reported are of by around 400‐500 feet. Can you please double check these values and let me know if you find an error. If so I can modify the report. Thanks Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907‐793‐1241 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. &78&7-RE6FRSH3 $ 0,58&78 &78&7-RE6FRSH3 $ 0,58&78 &78&7-RE6FRSH3 $ &78&7-RE6FRSH3 $ &78&7-RE6FRSH3 $ QHDUVXUIDFH)LQDO:+3V 669 SVLEEOV,$3ZHQWEDFNRQDYDF)LQDO:+3V 9DF 72&LQ7%* IRDPEDOODW 7,2 0,773 $/RDGHGWXELQJZEEO GLHVHO0,77WRSVL 7,2 7)6XQLW(VWDEOLVK7[2$&RPPXQLFDWLRQ3XPSHGEEOV'6/ GRZQ7%*3XPSHGEEOV'6OGRZQ2$WRDWWHPSW2$[7%*FRPPXQLFDWLRQ1R :(//6,21$55,9$/'62127,),(' SHUIRUDWH MEMORANDUM TO: Jim Regg�� P. I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission iU I �?12ti U DATE: 8/13/2021 SUBJECT: Surface Abandonment - Final PBU G -03A Hilcorp North Slope LLC PTD 1970700; Sundry 319-203 8/13/2021: 1 traveled out to PBU G -03A for inspection of the final surface abandonment after Hilcorp completed the tubing and annular spaces cement top jobs.' Robert Bryan was the Hilcorp representative on location for this inspection. I was handed all the proper paperwork upon my arrival. The wellhead had been cut off 6 feet below natural grade and the area was free of any debris. My inspection revealed: - the tubing previously had a 266 -foot void that was filled with cement; v - the tubing -casing annulus was cemented to surface; - the surface by intermediate casing annulus was cemented to surface; and - the conductor by surface casing annulus was cemented to surface. The cement in the tubing and annular spaces was hard, confirmed with impacts from a 5 -foot steel bar. The marker plate was as found during previous inspections — all well and location information was correct and readable. Attachments: Photos (2) V ' Refer to previous AOGCC inspection reports dated 8/4/2021 and 8/8/2021 for information about well abandonment deficiencies. 2021-0813 Surface Abandon Final PBU G -03A ll.docx Pagel of 2 i f 3 Tj lx > r , A bit �ra�� i P � A bit �ra�� ra�� MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2e(,-c, 1�I4Iza, , DATE: 8/08/2021 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandonment Petroleum Inspector PBU G -03A Hilcorp North Slope LLC PTD 1970700; Sundry 319-203 8/08/2021: 1 stopped by PBU G -03A and took a picture of the cut off after they were instructed to clean out the conductor -by -surface casing annulus to as deep as they could prior to topping off with cement. The top of cement in the tubing is at 266 feet, surface casing -by -intermediate casing annulus is at 9 feet and conductor-byu-surface casing annulus is at 5 feet. According to Jaycen Sala the plan is to dump cement into tubing. I instructed him to contact Mel Rixse and get approval on procedure for 4 cementing as they were told to use conduit to pump cement (normal top job procedure). Attachments: Photo 2021-0804_Surface_Abandon_PBU_G-03 A_gc. docx Page 1 of 3 N QCO a a� U C) O 00O N O N N ¢ cc a O 00 O MEMORANDUM TO: FROM: Jim Regg er.�t, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission if-- � DATE: 8/04/2021 Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector PBU G -03A Hilcorp North Slope LLC PTD 1970700; Sundry 319-203 " 8/04/2021: Arrived at location and met with Jaycen Sala with Hilcorp. From the information I was given, I determined the cutoff depth was approximately 3.5 feet below tundra level. The tubing was absent of cement down to the depth of 266 feet below the casing cut-off. The OA was absent of cement to the depth of 9 feet below the casing cut-off. The conductor to surface casing was full of hydrocarbon -contaminated soil, small gravel and debris. I inspected the identification plate, and well information was correct. I spoke with AOGCC Engineer Mel Rixse about the well situation and got clarification on what he would require for the cement top -job. I passed the following on to Mr. Sala: they are to use conduit to cement the tubing and the OA; they are to remove material out of the void between the conductor and surface casing to a minimum of depth of 6 feet and fill with cement using conduit. I departed location at 2:45 pm. Jaycen Sala contacted me at 5:42 pm and said they cannot get 6 feet down in the conductor -by -surface casing annulus because they have had trouble doing so in the past. Mr. Sala told me they had only tried removing the material by hand at this point. I suggested washing the material with water and sucking it out; Mr. Sala responded they cannot use a super -sucker because the contaminated material (hydrocarbon and gravel has a flashpoint). I instructed him to remove material in the conductor -by -surface casing annulus as deep as possible and contact Mel Rixse about how to proceed. Attachments: Photos (3) 2021-0804_Surface_Abandon_PBU_G-03 A_gc. docx Page 1 of 3 u N N y 4 N N O 00 O MEMORANDUM Founded on State of Alaska Depth TO MW Above Verined Alaska Oil and Gas Conservation Commission TO: Jim Regg \l �I( j+2�( DATE: April 4, 2021 Wireline tag P.I. Supervisor SUBJECT: Plug Verification PBU G -03A FROM: Adam Earl Hilcorp Alaska -North Slope LLC. Petroleum Inspector PTD 1970700; Sundry 319-203 Section: 12 Township: 11N Range: 13E Meridian: Umiat Drilling Rig: N/A Rig Elevation: N/A - Total Depth: 11,288 ft MD Lease No.: ADL 028280 Operator Rep: Jerry Culpepper Suspend: P&A: X Casing[Tubing Data (depths are MD): , Casing Removal: Conductor: 20" O.D. Shoe@ 111 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2675 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 8375 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 8664 Feet Csg Cut@ Feet Liner 2: 2 7/8" O.D. Shoe@ 11288 Feet Csg Cut@ Feet Tubing: 4 1/2" x 7 ' O.D. Tail@ 7870 ft Feet Tbg Cut@ Feet Plugging Data: Test Data: TVDe Pluq Founded on Depth Btm Depth TO MW Above Verined Fullbore ' Bridge plug 7774 ft MD " 5042 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I traveled out to PBU G -03A for a wireline tag on a cement plug. Tool string consisted of 1 7/8"X 10 foot weight bar and a 1 3/4" ✓ X 3 -foot bailer. Hanging Wt. @ 260lbs. Tag top of cement @ 5,042 It Slickline depth. Mushy interface up top and firm chips on bottom inside bailer. Attachments: none rev. 11-28-18 2021-0404_Plug_Verification_PBU_G-03A_ae MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '-Rek," IGI t 2 P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Section: 12 Township: Drilling Rig: NA Rig Elevation: Csg Cut@ Operator Rep: Eric Dickerman Feet Casing/Tubing Data (depths are MD): Conductor: 20 0. D. Shoe@ Surface: 13-3/8" 0. D. Shoe@ Intermediate: 9-5/8" 0. D. Shoe@ Liner: 7" 0. D. Shoe@ Liner: 2-7/8" 0. D. Shoe@ Tubing: 4-1/2" 0. D. Tail@ Plugging Data: Test Data 11N NA DATE: October 4, 2020 SUBJECT: Well Bore Plug & Abandonment PBU G -03A Hilcorp North Slope LLC PTD 1970700; Sundry 319-203 Range: 13E Meridian: Umiat Total Depth: 11288 ft MD Lease No.: ADL 028280 Suspend: P&A: Yes Casing Removal: 111 Feet Csg Cut@ Feet 2675 Feet Csg Cut@ Feet 8375 Feet Csg Cut@ Feet 8664 Feet Csg Cut@ Feet 11288 Feet Csg Cut@ Feet 5016 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified N/A Initial 15 min 30 min 45 min Result Tubing 2895 2854 2827 11 IA 2588 2549 2522 P OA 0 0 0 Tubing IA OA Initial 15 min 30 min 45 min Result Remarks: Prior to notice, a cement plug was placed in the 7 -inch by 4.5 inch tubing from 7774 ft MD (top of fill) to 5100 ft (top of cut 7 -inch tubing). I witnessd the CMIT TxIA to 2500 psi (plug and casing integrity) prior to setting the intermediate cement plug. The CMIT TxIA passed. Attachments: none rev. 11-28-18 2020-1004_Plug_Verification_PBU_G-03A_ll THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU G -03A Permit to Drill Number: 197-070 Sundry Number: 319-203 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wwwa ogc c . o laska.gov 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, Daniel T. Seamount, Jr. Commissioner DATED this c sdaayy of April, 2019. RBDMSI� APR 2 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.290 HtUEIVED APR 18 2019 1. Type of Request: Abandon 51 - Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ O Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change App rami Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well Cl Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development p. 5. Permit to Drill Number 197-070 " 3. Address: P.O. Box 196612 AnchorageAK , 99519-6812 Stretigrephic 11 Service ❑ 6. API Number 50-029-20221-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a sparing exception? Yes ❑ No 171 PBU G -03A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028280 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft). Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11288 9020 5096 5080 5096 Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31 - 111 31 - 111 Surface 2645 13-3/8" 30-2675 30 - 2675 5380 2670 Intermediate 8347 9-5/8" 28-8375 28-8246 6870 4760 Liner 829 7" 7835-8664 7726 - 8521 8160 7020 Liner 3104 2-7/8" 8184-11288 1 8062-9020 1 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9550- 11210 8961 - 9017 4-1/2" 12.6# / 7" 26# L-80 / N-80 26 - 5016 / 7769 - 7870 Packers and SSSV Type: No Packer Packers and SSSV MD (ft) and TVD (ft): No Packer No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary IZ Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: June 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Aivano, Mike (Udelhoven) be deviated from without prior written approval. Contact Email: mike.aivanoQbp.com Authorized Name: Worthington, Area J Contact Phone: +19075645475 Authorized Title: Interventions & Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n I iy _ ^ ,r Plug Integrity lizv� BOP Test ❑ Mechanical Integrity Test o/ Location Clearance Other: `- 1 P�CTLI�G�T W'a ,`LC S I V-4-1,OC 0.T�OH�+ L�dfl+� IL a �O i� Cs4LKl7 1� ( I Post Initial Injection MIT Req'd? Yes ❑ No Vs.�� Spacing Exception Required? Yes ❑ No Subsequent Form Required: �— 4{601. ADBYTHE Approved by: � COMMISSIONER COMMISSION Date: �/& �[-bkj11a Form 10-403 Revised 04/2017 ORIGINAL RBDMSL�' APR 2 6 2019 M&IZZM11iSubmit Form and Approved application is valid for 12 months from the date of approval Atta merits in Duplicate G -03a PBA Intervention Engineer Mike Aivano (907) 564-5475 Reviewed by Aras Worthington (907) 564-4102 Production Engineer Joleen Oshiro (907) 564-4606 Expected start date: June 1, 2019 History G -03a was a 1997 horizontal producer that was completed in zone 1 B. The well was kept online as a fulltime producer until late 2003 when a high inner annulus pressure was observed. An LDL confirmed the leak source between the tubing and the inner annulus. The well had a patch program developed but never implemented. An RWO was conducted on G -03a in 2006, with plans to complete a CTD side track afterwards. The RWO cut and pulled the 7" tubing down to just above the production packer, it was discovered at this time that the 9- 5/8' roduction casing was not competent. Leak points were found fr and - 5291' md, TaCIBP was set above the known s an a Mitring was run. The RWO and the associated side track were abandoned at this point and the well deemed suspended. Objective Drill through 9-5/8" CIBP with service coil. Lay -in cement below the CIBP and circulate in a cement plug above the CIBP. Excavate and cut casings 3 ft below original tundra level and install marker cap. DPZ's present in the well: DPZ 1 from 1988' and - 6230' and and DPZ 3 from 8566' and -11288' md. Procedural Steps Coil Tubing 1. RIH with motor and mill. 2. Mill hole through 9-5/8" CIBP. 3. RIH with cement nozzle to 2-7/8" liner top or top of fill 4. Lay -in cement from 2-7/8" liner top to -5080' and Oust above 9-5/8" CIBP). 5. Lay -in Freeze Protection in the tubing as required Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: I Minimum 6 hours G -03a P&A Sundry v3 Slickline / Fullbore 1. CMIT TxIA to 2500 psi, AOGCC Witness. 2. Drift and Tag top of cement, AOGCC Witness. r_ A•GG� �C 3. Circulate a surfactant pill down the tubing and up the IA. • 5 bbls McOH • 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 • 350 bbls 9.8 ppg brine 4. Pump cement job down tubing taking returns up the 9-5/8" x 4-1/2" annulus. The top of cement in the 9-5/8" x 4-1/2" annulus will be at surface and at -22�d in the tubing. • 5 bbls MEOH • 5 bbls FW spacer • 325 bbls of Class G cement per design ✓ • 2 bbls FW spacer • Foam wiper ball • 30 bbls 9.8 ppg brine • 2 bbls McOH for Freeze Protection Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours E-Line/Fullbore 1. Wait 2 days on cement. 2. MIT -T to 2500 psi 3. Drift and Tag top of cement 4. Perforate -1800' and ( roughly 400 ft above TOC) through 4-1/2" tubing and 9-5/8" casing. Fullbore 1. Pump down the tubing and take returns from the 13-3/8" x 9-5/8" annulus (OA) to flush out any hydrocarbons and or Arctic Pack. Pump the following: • 65 bbls hot (160F) diesel • 33 bbls hot (160F) 9.8 ppg brine • Shut down for one hour to let diesel soak in OA and loosen Arctic Pack • 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 • 175 bbls hot (160F) 9.8 ppg brine Once clean brine is consistently returned from the OA, indicating that all hydrocarbons have been circulated out of the annulus, pump OA surface cement plug as follows down the tubing. The TOC in the OA and tubing will be at surface. • 5 bbls MEOH 5 bbls FW spacer 145 bbls 15.8 ppg cement per design G -03a P&A Sundry v3 Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours DHD 1. Assist Fullbore with cement job and pump N2 across the wellhead to remove excess cement from the valves. This will allow valves to be opened prior to the wellhead removal to check for pressure. 2. Bleed all wellhead pressures to 0 psi. 3. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. AOGCC Witness cement tops in all annuli. 3. Bead weld marker cap on outermost casing stri (30" Conductor) to read as follows: 1h BP Exploration Alaska, Inc. \ 1 BTa e- m u IM- � c- t G -03a �11 t.tid l r^a_r PTD # 197-070 API # 50-029-20221-01 G -03a P&A Sundry 0 Volume Calculations: Lower Cement Plug From 2-7/8" TOL at 8184 ft to above the 9-5/8" CIBP at 5080 ft. Btm Top Section Bpf Vol 8184 7877 7" 29# liner 0.0371 11.4 7877 7769 7" 26# tubing 0.0383 4.1 7769 5080 9-5/8" casin 0.0732 196.8 Total Volume 212.4 2nd Cement Plug 9-5/8" annulus from 5015 ft to surface and in the 4-1/2" tubing from 5015 ft to 2200 ft. 3rd Cement Plug 13-3/8" x 9-5/8" annulus and 4-1/2" tubing from 2000 ft to surface. G -03a P&A Sundry v3 EEV.615' BEV. 9426 Arctic Pack from 1. 4600' Surface to 2305 IT An*•_ _1501097! 9-5/8" Est TOC 4905ft G -03a Current Wellbore Status x 13.3/8" cement 7" Est TOC above Pkr @7875 ft Minimum D =2.377' @ 8188' BAKER XO TO FUS/STL C FBWCMTDNsIAWIN IS LOG M'OOtONOSWA7 AN EAT TOP(9i-80®%50 NIA. PVW b Redit9en LBIa IAMTtl 8A1 aIA SYE SFFj NIBNAL I Wraz DUE i -1V16' 4 %50-10180 - C Omm? 1-IVIG 4 89711-9880 C W21AT 7 6 I=-10770 C OV2M r 6 I=-1090 'C OV2M 1.1Vt6' 4 11060-11170 - C Oww 1-IV76' 4 11150-11210 C OVM7 e29.,N4M..wn9p.o•61er NM4• — 4 4 ; _13.3(8"c&rmnLjoylrf&cg- _ _ _ _ _ _ 2-7/8" Lnr Est TOC 8266ft 7-9DETMa V78701V®Mr KF—tDkTEFWEVr W6699R5 MiE fEV Br OOM.B/IS Ri811gE8Ar Uel awr�611L tOMPLE710M 9LUH CMA SAY8R71MCN G7 "3w NI 1970700 AOOCC 9ElAWWATMM9 ARND SCIM2=1-01 NXLA3WlED"-3NUTK 9 ;12,T1INR13E22VN36197TflK G -03a P&A Sundry 0 5 G-03 P 20'x30" Conductor 110ft 77TI Perf Tbg & IA @ 18ODft 9 -5/8 -FOC 2209ft M e 13-3/8" Csg 2675ft_� m 9-5/8" OV Collar 2719h m y 4-1/2' Tbg 5015 ft 0 9-5/8"CIBP5096ft Holes in Casing 5262- 5291 h 7" Tbg Cut 7769 ft 7" x 9-5/8" Pkr 7875ft -- 2-7/8"UnerTopB184h --- 9-5/8" Csg 8375 ft — 9.1 ppg brine below the CIBP 7" Liner Plug Back with 24, bbls Cement and Tagged at 8846 ft 7" Liner 9385ft - L13-3/8"TOC at Surface ,a Circ CmttoCAfrom 1800fit to Surface Cmt from Drilling Phase Cmt added for P&A --�- _ PerfTbg and IA@"1800ft. Cement from 9-5/8"DVCollarar------. Circ out Arctic Pack and Circ 2718fit to2305ft(calculated( ce ment to surface in CA and Tbg Circ cement in lA from "'- 5015ft to surface. Leave _ cement top Tbg at -2200 ft ''----_- Lay -in cement from top of __ - -- 2-7/8 Liner or top of fill to 5080 h. Cement from 9-5/8" Csg Shoe at 8375 ft to 4095 ft (calculated based on 30% WO) Cement from 7" Shoe at 9385 ft to the 7" x 9-5/8" Pkr at 7875 ft (calculated based on 3096 WO) Cement from 2-7/8" Shoe at 11288 ft to the 8266h (calculated based on 30% WO) PBTD in 2-7/8" Liner at 11254ft 2-7/8" Liner 11288 ft G -03a P&A Sundry 0 6 10,000,01 1,000,000 t c CO C Q 100,000 LL U � o 10,000 o _ � O 0 O v� Y rd d LL `0 1,000 V_ 3 u v c m 100 N 0 0 L F 10 1 Jan - BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT G -03A (197-070) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates Cum. Prod Oil (bbls): 1,087,244 = Cum. Prod Water (bbls): 30,708 Cum. Prod Gas (mcf): 10,502,491 Jan -2010 Jan -2015 —� Produced Gas (MCFM) = GOR Produced Water (BOPM) Produced Oil (BOPM) 10,000,000 W d 1,000,000 N 0 M 100,000 m Z 3 0 3 S 10,000 O t Go N 1 1,000 M 0 d M 100 rDrD 1 0 0 10 s —I- 1 Jan -2020 SPREADSH EET_1970700_PBU_G-03A_Prod-I nject_Curves_W ell_Oil_V 120_20190422.xlsx 4/22/2019 • • ."- Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, February 23, 2016 9:58 AM To: 'Sternicki, Oliver R' Cc: Lastufka,Joseph N (Joseph.Lastufka@bp.com) Subject: Suspended Clarification(PBU 03-05(PTD 176-057);G-03A(PTD 197-070);Y-08A(PTD 188-056) Oliver, The wells need to be brought to a mechanically sound condition with plugs in accordance to 20 AAC 25.11.2. A surface plug may not be required at this time if the wells are otherwise mechanically sound. However,these wells must be included in the development of a P&A plan for suspended wells with no future utility that must be approved through the Commission by 12/31/16. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer APR of Alaska I%, �{�W Ah R 2 1 2016 Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeprx alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.Sternicki@tbp.com] Sent: Tuesday, February 09, 2016 3:20 PM To: Loepp, Victoria T(DOA) Cc: Catron, Garry R (Wipro); Lastufka, Joseph N; AK, D&C Well Integrity Coordinator Subject: Clarification Request: Well status change to Suspended Victoria, In reviewing our Not Operable well stock I came across 3 wells that we would like to convert to suspended status. I need a bit of clarification on what we need to do to change them over. • 03-05, PTD#176057 o Failed RWO in 1991-Tubing pulled, EZSV with cement cap set in the 9.625"casing. For some reason this well did not have a PT in 1991 when the rig moved off of it. I assume that if we apply for a suspension we will need to get a PT. o No future utility • G-03A, PTD#197070 o RWO suspended on 10/25/06 when the rig found holes in the production casing between 5262-5291'. A EZSV was set at 5096' and a 4.5" kill string was run to 5015'. o PT passed to 3500 psi on 10/24/06 1 • • o No future utility • Y-08A, PTD# 188056 o This well has a P&A sundry open (314-595), but we are unable to close it out because we have not been able to get a PT on the cement job that was performed in late 2014. TOC was tagged at 8597', but there is a tubing leak at 4390' and a production casing leak at 2700'. o No future utility Please advise on what is required for each of these to get them moving towards SU status. Regards, Oliver Sternicki q1 wow walk orgaminenow Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickibp.com 2 TREE= X 5000#DMY TREE WELLHEAD= FMC GEN IV • 03-05 0 SAFETY OTES: 4/91 P&A- DIESE .-"73 7395'TO SURFACE ACTUATOR= NIA KB.ELEV= 61' GL ELEV= 22' L KOP= 3100' Max Angie= 43 @ 6511' Datum M)= 10417' Datum ND= 8800'SS 7395' H CDVIENT CAP(ESTIMATED DEPTH) ••••••••A•♦ 13-3/8"CSG,72#,MN-80,D=12.347" 2708' '--.....-- 7595' I- EZSV TBG cur H 8624' 111�1.1.1�1 11 't �w�n ►11 GAS LIFT MANDRELS TOP OF 5-1/2"TBG H 8624' 11 11 ST MD ND DEV TYPE VLV LATCH FORT DATE 111 X11 1 i ►111 8 8659 7480 40 MMIG RK 1I ►111 9 9026 7762 40 MNG RK Minimum ID =0"0" 7396' 11111L1.1.1�1;11111 10 9309 7977 40 WAG RK 11111 SIA 1 1 9671 8255 39 MNG RK CEMENT CAP 1i111111 12 9954 8479 36 MNG 111101r1�1411.1 1111111111111111111 1111111111111111111 11111111111111 41111 /4 4.1A111 1.1.1111111111 AA0 c.0.4 V'.'4 10114' H 5-1/2'BAKE FBR ASSY 'i,44, ..../1111 ►'�= 11111 :.' 5-12"TBG, 17#,L-80,0-0232 bpf,D=4.892" � 10149' ��•�411�'111' 1.1.1111k111 TOP OF 4-1/2"TBG H 10149' 11�1�14111 111111 10136' H 9-5/8'X 5-1/2"BAKER SAB PKR 1111111111111111111 11111111111111111 111111111111111111 111.1'011.111111 4-112"TBG,12.6#,MN-80,0.0152 bpf,D=3.958" -[ 10263' 1111111/11•vv1v1v1 10210' —{ 4-1/2"CA MCO DB-5 NO-GO N�',D=3.813" ��1111111111'AV PERFORATION SUMMARY 1�i1�1111111111111 Ni 44 411 ___ _____ REF LOG: BHCS ON 08/03/76 11111111.1.1. 111/11%Tv, �10263' — 4-1/2"TUBING TA L ANGLE AT TOP PERF: 33©10292' 111111111111111111111 Note:Refer to Roduction OB for historical perf data 111111111111111111111 10226' H t3h4D 11 LOGGED 12/07/86 SIZE SPF INTERVAL Opn/Sgz DATE 1I 111111111111111111 11111111�' 1 10306- 10316 0 02/02/90 1111111111111111 0 10325-10334 0 06/15/88 11111111 111111111 4 10325-10334 0 02/02/90 1111111111111111' 0 10350-10360 0 06/15/88 11111111111111114" 4 10350-10360 0 02/02/90 1111111111111111 0 10370- 10390 0 06/15/88 1111111111111111' 11111111 4 10370-10390 0 02/02/90 11111111 1111111111111111' 0 10405-10430 0 06/15/88 11111111111111i/ 1 10405-10430 0 02/02/90 11111111111111111 10475-10515 S 01/04/90 11111111111111111( 10530-10553 S 01/04/90 11111111111111111' 10570- 10595 S 01/04/90 11111111111111111 111111111111111111 111111111111111111 111111111111111111 111111111 PBTD H 10828• 1'1'ac•A Ake OVVVVVVVVV1 1111111111 9-5/8"CSG,47#,S00-95,D=8.681" 10909' ►111111111111111111111 1111111,111111111111 11111` 1.1- 1 10940' —I FISH-32"LOGGING TOOLS,20"WIRi31t'E 1111111111.1.`X111111 111114.-`.111111111 11.1111,,T411111 10945' H 13'OF 412"TUBING 11111111111 TD --I 10950' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 08/12/76 ORIGINAL CONFLETION 09/13/01 RN/TP CORRFCT1ONS WELL: 03-05 05/91 LAST WORKOV ER-P 8A'd 08/07/02 BHC/tlh FERE CORRECTIONS PERMT No: 1760570 12/19/00 SIS-OAA CONVEF UWW TO CANVAS API No: 50-029-20222-00 01/05/01 SIS-MO FINAL Sec.11,T10N R15E 1469'FNL,863'WEt_ 07/13/01 TP CORRECTIONS BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 5 _ - E AUG 0 3 2012 333 West 7th Avenue Anchorage, Alaska 99501 q7 0 7° Subject: Corrosion Inhibitor Treatments of GPB G -Pad °3 r ' Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD 4 API 4 cement pumped cement date inhibitor sealant date ft bbls ft na qal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 __alp G-03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G -06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G-11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -196 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -23B 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G-31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 .. STATE OF ALASKA _ ALA~ OIL AND GAS CONSERVATION COM-ŠION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ~ Repair Well o Pull Tubing o Operation Shutdown 61.50' ADL 028280 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Liner 11288 9019 11254 9019 110' 2675' 8375' 826' 3104' 99519-6612 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: ~ Development 0 Exploratory 197 -070 o Stratigraphic 0 Service 6. API Number: 50-029-20221-01-00 o Re-Enter Suspended Well o Other 9. Well Name and Number: PBU G-03A 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool feet feet Plugs (measured) 5096 feet Junk (measured) Unknown feet Size MD TVD Burst 20" x 30" 110' 110' 13-3/8" 2675' 2675' 4930 9-5/8" 8375' 8246' 6870 7" 7838' - 8664' 7729' - 8521' 7240 2-7/8" 8184' - 11288' 8062' - 9019' 13450 Collapse 2670 4760 5410 13890 Perforation Depth MD (ft): Below CIBP: 9550' - 11210' Perforation Depth TVD (ft): 8961' - 9017' Tubing Size (size, grade, and measured depth): Kill String: 4-1/2", 12,6# & 7",26# L-80 & N-RO 5015' & Packers and SSSV (type and measured depth): 9-5/8" x 7" Baker 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7875' Treatment description including volumes used and final pressure: 13. Oil-Bbl Re resentative Dail Avera e,Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory ~ Development 0 Service ~ Daily Report of Well Operations 16. Well Status after proposed work: o Well Schematic Diagram ~ Oil 0 Gas 0 WAG 0 GINJ 0 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 David Reem, 564-5743 N/A Printed Name Terrie Hubble Signature Form 10-404 Revised 04/2006 Title Technical Assistant Phone 564-4628 RSOMS 8B Date II/Ot:t ()(p :I 5 2006 Terrie Hubble, 564-4628 Submit Original Only Prepared By Name/Number: · Page 1 of 2 Digital Wellfile Well Events for SurfaceWell - G.' Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC1 -> G -> G-03 Date Range: 29/Aug/2006 to 09/Nov/2006 Data Source(s): DIMS, AWGRS Events Source Well Date DIMS G-03 10/25/2006 RIMS G-03 10/24/2006 l2IMS G-03 10/23/2006 DIMS G-03 10/22/2006 l2IMS G-03 10/21/2006 RIMS G-03 10/20/2006 DIMS G-03 10/19/2006 DIMS G-03 10/18/2006 RIMS G-03 10/17/2006 DIMS G-03 10/16/2006 DIMS G-03 10/15/2006 AWGRS G-03A 10/15/2006 DIMS G-03 10/14/2006 AWGRS G-03A 10/14/2006 AWGRS G-03A 10/13/2006 .DIMS G-03 10/13/2006 AWGRS G-03A 10/13/2006 Description Run Kill Srting. Swap Well over to 9.8 Ib/gal Brine. ND BOPE. NU Tree. Diesel cap. Test Tree. LD BHA. RIH, set & test EZSV @ 5096'. POH & LDDP. P/U & run 41/2" kill string. Swapped well over to 9.1 ppg brine. TOH with Dress Off Assembly. TIH with 9 5/8" EZSV and set @ 5,096'. Tested BOPE. POH Storm Packer and 9 5/8" RBP. Dressed off 7" Tubing Stump. Reverse circluated hi-vis sweep to clean up well bore. Re-set 9 5/8" RBP @ 4,075'. Set 9 5/8" Storm Packer @ 36'. ND BOPE. ND Tubing Spool. Changed out Packoff. NU new Tubing Spool. NU BOPE. Set 9 5/8" RBP @ 7,740'. Used RTTS to find leak in 9 5/8" between 5,261' - 5,292'. Cleaned out to 7,868' with 5 3/4" RCJB. Drifted to 7,971' with 3 3/4" Junk Mill. CBU. Cleaned out to top of 7" @ 7,769'. CBU. Cleaned out 7" down to PBR @ 7,832'. CBU. POH remaining 7" Tubing. MU 7 7/8" Reverse Circulating Junk Basket. TIH with RCJB. Speared Hanger and POH with 7" Tubing down to cut @ 3,535'. Spear Tubing Stump @ 3,535' and jar free. Attempted to pull Hanger free with no success. RU E-line. Chemically cut 7" @ 3,535'. RD E- line. PULLED TWC /RIG TESTED BOP'S Finished RU on GBP G-03A. Killed well with 2% KCL. Set TWC. ND Tree and Adapter. NU BOPE. C/O Pipe Rams to 7". Test BOPE. PULLED BPV /RIG MOVED ON WELL T/I/O=si/O/O MIT OA PASSED @ 2000 psi. (Shut In)(Pre-Sidetrack) OA pressured up w/ 1.2 bbls Diesel pumped. OA lost 120 psi in 15 min. w/ total loss of 160 psi in 30 min. Flnl WHP's=si/O/O Moved Rig and components from MPF-78 to GPB G-03. T/IA/OA = 51/0/0 (Pre-Rig Inspection) PPPOT-IC = FAILED PPPOT-T = PASSED Bled tubing hanger void to 0 psi. Torqued lockdown screws to 550 ft/lbs. Removed internal check and install external test fitting. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 5,000 psi. - Passed Bled inner casing hanger packoff void to 0+ psi. Torqued lockdown screws to 550 ft/lbs. Removed internal check and installed external test fitting. Rigged up test equipment and pumped until clean fluid returns were achieved. Void would only pressure up to 1,800 psi.= FAILED packoff would not build anymore pressure, abandoned test. Rig will change out during workover. T/I/O= 90/0/0. Temp.= SI. TGB, IA , & OA FL's. (pre RWO). ALP= O. TBG FL @ 43'. (2 bbls.) IA FL near surface. OA FL near surface. **CONTINUED FROM 25-SEP-2006** T/I/O 100/0/0. 3X16' STRING SHOT OVER INTERVAL 7752-7768 FT. LARGE CHARGES TUBING PUNCH 7744-7746 FT. 5-3/4" CHEMICAL CUT OF 7" TUBING AT 7766 FT. **Job Complete** ***WELL S/I UPON ARRIVAL*** (PRE RWO) DRIFTED FOR CHEM. CUT W/ 5.75" CENT. TO OBSTRUCTION @ 7864' SLM (TARGET DEPTH FOR CUT @ 7800') ***WELL LEFT 5/1*** T/I/O 100/0/0. 3X16' STRING SHOT OVER INTERVAL 7752-7768 FT. LARGE CHARGES TUBING PUNCH PERFORATED FROM 7744 TO 7746 FT (2FT.) @ 4 JSPF. ***CONTINUED 26- SEP-2006*** *** Job continued from 09-24-06 WSR *** T/I/O = 100/80/0 - Load and freeze protect tubing for E-Line (RWO prep) - Loaded TBG w/10 bbls neat meth followed by 340 bbls 120* 1 % KCL. Freeze protect TBG w 90 bbls 60/40 meth water and 5 bbls neat meth. FWP's = 360/440/0 AWGRS G-03A 09/24/2006 Load and freeze protect tubing for E-Line (RWO Prep) *** Job continued on 09-25-06 WSR *** AWGRS G-03A 09/28/2006 AWC:;8,S G-03A 09/26/2006 AWGRS G-03A 09/25/2006 AWGRS G-03A 09/25/2006 AWGRS G-03A 09/25/2006 AWGRS G-03A 09/24/2006 T/IA/OA= 200/180/70 Pre rig well head MIT. Cycle all LDS on tubing spool, Broke all free. Were hard to get to move. Worked free, with no sign of any bent or broken LDS. Unable to test hanger void. Was trapped pressure in void and was unable to break bleeder screw free. Casing spool { IC hanger} Worked all LDS free, were very tight was able to get all LDS to move free. No signs of any bent or broken LDS. Due to depth of cellar was unable to test. Will need extra man and a confined entry permit. http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 11/9/2006 Digital Wellfile AWGßS G-03A 09/24/2006 AWGRS G-03A 09/23/2006 AWGRS G-03A 09/23/2006 AW~RS G-03A 09/22/2006 AWGRS G-03A 09/21/2006 AWGRS G-03A 09/18/2006 A_W~KS G-03A 09/17/2006 AWGRS G-03A 09/16/2006 AWGRS G-03A 09/16/2006 8WGRS G-03A 09/15/2006 AWGRS G-03A 09/12/2006 AWGRS G-03A 09/11/2006 AWGßS G-03A 09/11/2006 AW~RS G-03A 09/10/2006 AWGRS G-03A 09/09/2006 AWGßS G-03A 09/05/2006 AWGRS G-03A 09/04/2006 AWGRS G-03A 08/31/2006 AWGRS G-03A 08/30/2006 AWGRS G-03A 08/29/2006 . Page 2 of2 *** CONT FROM 09-23-06 WSR *** (fish toolstring) lED SLlCKLlNE TOOLSTRING & IBPoo. BOTH ELEMENTS & STIFFENING RING RECOVERED W/ IBP. RDMO *** WELL LEFT SI *** *** WELL SI ON ARRIVAL *** ( fish toolstring) RIG UP SURFACE EQUIP & EXTRA RISERS, PREP FOR PT *** JOB IN PROGRESS/ CONT ON 09-24-06 WSR *** *** JOB CONT FROM 09/22/06 *** RIH W/ KJ, 4.44 BELL GUIDE, 3.0" JUS, STEEL PIN, SD @ 7858' SLM, LATCH CUTTER BAR.RIH W/ KJ, 3.81 CENT 3' 2 1/8" STEM, 3.5" BLIND BOX,RIH W/ KJ, 3.81 CENT 3' 2 1/8" STEM, 3.5" BLIND BOX.RIH W/4.5 GR, 4.5 BAIT SUB, 7" BLB/ WIREFINDER, 3.75 WIRE GRAB.SD @ 7822' SLM, WORK TOOLS, SD @ 7861' SLM, RIH W/ SAME TOOL, EXCEPT SIZE DOWN BRUSH TO 5.5". LATCH WIRE @ 7862' SLM, RECOVER 300' WIRE, RUN 3.25" LIB IMPRESSION OF ROPE SOCKET, RUN 3.25" BELLGUIDE W/ 2.5" JUC SD @ 8152' SLM LATCH FISH, SHEAR JUC WITHOUT FISH,DECIDE TO RID. *** WELL S/I ON DEPARTURE ( NOTIFY DSO) *** CONT. FROM 09/21/06 *** MAKE SEVERAL RUNS W/ VARIOUS LIB'S TO 7860' SLM (INCONCLUSIVE MARKS ON LIB'S) RIH W/ KJ, 3.50 CENT, 3' 2 1/8 STEM, 3.0" LIB,SD @ 7976' SLM, ( APPEARS TO BE PARTIAL IMPRESSION OF FISH NECK) RIH W/ KJ, 3 3/8" EQ. SLEEVE( OD 3.63)-( 2.5 JDC BRASS) SAT DOWN @ 7976' SLM, TAP DOWN, MONITOR PRESSURE. ( T/I/0-400/350/0 ) IBP FALLS DOWN HOLE SD @ 8168' SLM. RIH W/ KJ, 3 3/8" EQ. SLEEVE. ( OD 3.63 ) 2.5" JDC ( STEEL PIN) T/I/O- 400/350/0, SD LATCH IBP @ 8168' SLM . UNABLE TO PULL IBP OR SHEAR OFF, DROPPED 1st. CUTTER BAR W/ 4.5" CENT'S, DIDN'T CUT BECAUSE OF OBSTRUCTION IN TBG @ 7860" DROPPED 2nd. CUTTER BAR W/ 3.5" CENT'S, GOOD CUT LEFT APPROX 300' OF .108 WIRE IN HOLE FISHED OUT 2nd. CUTTER BAR FROM 7848' SLM CURRENTLY SETTING UP TO FISH OUT 2nd. CUTTER *** JOB IN PROGRESS, CONT ON 09/23/06 *** ***WELL 5/1 ON ARRIVAL *** ( pre jet cut) IBP HAS MOVED FROM 7993' SLM TO 7854' SLM, RIH W/ 5.0" CEN, 3 3/8" IBP EQ. SLEEVE, ( 2.5" JDC, BRASS PIN.) 150# PRESS. CHANGE, UNABLE TO LATCH. RIH W/ QC,5.0 CENT, 3' 2 1/8" STEM, 4.5 LIB. NO IMPRESSION RERUN W/ DIFFERENT CONFIG. *** JOB IN PROGRESS CONT ON 09/22/06*** T/I/0=250/240/0 CMIT TxIA 3500 psi ***FAILED*** (Pre-RWO) - Pumped down tubing w/15 bbls crude. TxIAP tracked to 2300 psi. Pressure stopped climbing, fell back 50 psi then maintained for the next 15 bbls. Final WHP's=550/510/0 "'LLR=1.6 bpm @ 2250 psi'" SET BAKER 33/8" IBP TOP AT 7993.5', OVERALL LENGTH 11.59' WITH 2 6" SEALS AND 1 1" STIFFNER RING, FISHING NECK 1.75". SERIAL #10177090. WELL SHUT IN. ***JOB CO NT. FROM 9-15-06*** FISH FOR ELEMENT AND STIFFNER RING. RECOVERED 1" STIFFNER RING FROM 7851' SLM. ***GIVE WELL BACK TO DSO. LEFT SI*** ***********1 X 6" RUBBER IBP ELEMENT IN HOLE*************** T/I/O = 180/110/0. Temp = S/I. ALP 0 psi. TBG and IA FLs (pre-Eline). TBG FL @ 138'. IA FL near surface. ***WELL SI ON ARRIVAL ***(pre rwo) PULLED 3 3/8" BAKER IBP @ 7832' SLM (MISSING 1 ELEMENT & 1" STIFFNER RING) RUNNING IN HOLE W/ 5.5 WIRE GRAB ***CON'T ON 9/16- 06*** *** WELL SHUT IN ON ARRIVAL **** DRIFT WITH 4.5 CENT. 2' 1 7/84.5 LIB, TAG @ 7844' SLM, LIB SHOWS IBP F.N.. ***WELL LEFT S/I*** PAD OP NOTIFIED T/I/O == 450/420/0. CMIT TxIA to 3500 psi. [Failed without achieving test pressure] LLRT= 3 BPM @ 2400 psi. Pumped 90 bbls of 80* crude into the TBG. Final WHP= 700/700/0. WELL SHUT IN ON ARRIVAL. SET 3-3/8" BAKER IBP AT 7855' IN PBR. DEPTH CHANGED FROM 7850' TO 7855' DUE TO SUDDEN TENSION INCREASE DURING SETTING. NO PROBLEMS RIH OR POOH. FINAL T/ 1/ 0 = 450/ 400/ O. WELL SHUT IN ON ARRIVAL. INITIAL T/ 1/ 0 = 300/200/ O. ATTEMPT TO SET 3-3/8" BAKER IBP AT 7850' IN PBR. NO PROBLEMS RIH. JOB CONTINUED ON NEXT AWGRS - 11-SEP-2006. T/I/0=280/300/0. SI. PAL, IA valve closed at tree. TBG FL (for E-line). TBG FL near surface? ***JOB CONT. FROM 9/4/06*** (pre RWO) PULLED DART FROM PGSL @ 8177' SLM PULLED PGSL W/ @ 8174' SLM ***WELL TURNED OVER TO DSO*** ***WELL SHUT IN ON ARRIVAL *** ATTEMPT TO PULL DART FROM PGSL, SAT DOWN HIGH W/ 3' STEM, KN, 4.5" CENT, EXT., AND 2" JDC @ 7861' SLM ***JOB CO NT. ON 9/5/06*** ** WELL SHUT IN UPON ARRIVAL ** {pre rwo} ATTEMPTED TO PULL PGSL PRONG @ 8184' MD, UNSUCCESSFUL RIG DOWN DUE TO RIG JOB. ** TURNED WELL OVER TO PAD OP, LEFT SHUT IN** ***CONTINUED FROM 08/29/06 WSR*** (PRE IBP - PRE RWO) DRIFTED W/3 3/8 DUMMY GUN TO 2 7/8 XO @ 8183'SLM , NO RESTRICTIONS. ***WELL LEFT S/I ON DEPARTURE*** ***WELL S/I ON ARRIVAL *** (drift for ibp) RIG UP SLICKLINE UNIT. PRESSURE TEST SURFACE EQPT . ***CONTINUED ON 08/30/06*** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 11/9/2006 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/13/2006 10/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 10/13/2006 02:00 - 05:00 3.00 RIGD P PRE Begin RD of Rig Components. Lower and scope Derrick. Have Spooling Unit removed from location and taken to Nabors 7ES for their job. 05:00 - 00:00 19.00 MOB P PRE PJSM. Move rig & rig components from MP F pad to GPB G pad, 38 mile move. 10/14/2006 00:00 - 04:00 4.00 MOB P PRE Continue moving from MP F-78 to GPB G-03. Rig on location @ 04:00. 04:00 - 07:00 3.00 RIGU P PRE PJSM. Spot sub & rig components. Raise & scope up derrick. Rig up. Rig accepted @ 07:00 hrs, 10/14/2006. 07:00 - 11 :30 4.50 KILL P DECOMP PJSM. Rig up tiger tank lines. Spot Little Red pump unit & rig up same. Rig up lines to wellhead. 11 :30 - 12:00 0.50 KILL P DECOMP Pre well kill meeting with all participants. Emphasis on good, crisp communications & established pumping parameters. 12:00 - 13:00 1.00 KILL P DECOMP Finish rigging up Little Red's lines to rig floor manifold. Pressure test all lines to 2500 psi, OK. 13:00 - 14:00 1.00 KILL P DECOMP Line up Little Red to pump down 7" tbg. Bring on pump & establish rate of 4 bpm, 250 psi. Line up Nabors pump to pump down 7" tbg & bring on @ 5 bpm for a combined rate of 89 bpm I 450 psi. Pump a total of 111 bbls and abserve pressure cllimb to pre established ceiling of 2000 psi. Shut down Little Red & continue pumping with rig pump @ 4 bpm 11850 psi. Line up Little Red on 7" x 9 5/8" annulus. Open 7" x 9 5/8" annulus, 2000 psi there. Shut down all pumping & close in well. O/A pressure up to 800 psi. 14:00 - 15:30 1.50 KILL P DECOMP PJSM. Rig down Little Red, bleed down OIA to 250 psi to slop trailer. 15:30 - 17:00 1.50 KILL P DECOMP PJSM. Line up & pump 110 degree 2% KCL down 7" tubing @ 6 bpm I 425 psi, taking returns up 7" x 9 5/8" annulus, thru choke to tiger tank, 250 psi back pressure. Pump 500 bbls, seeing 8.4+ ppg returns on micro motion meter. Shut down & monitor well, tubing & IIA on vacuum. OIA pressure bled down to 200 psi. Continue bleeding O/A. 17:00 - 18:30 1.50 KILL P DECOMP PJSM. Call for two way check valve. Resume pumping @ 6 bpm I 550 psi, taking KCL returns to pits. Pre-tour safety meeting with night crew. Inspect Rig. 18:30 - 20:00 1.50 WHSUR P DECOMP Set TWC with Cameron rep. Test from above to 3,500 psi for 10 minutes - charted. Line up to pump down the IA. Attempt to test from below by pumping down the IA. Took 10 bbls to catch fluid. Tested from below with a pump rate of 1.5 bpm 1700 psi. 20:00 - 23:00 3.00 WHSUR P DECOMP PJSM. ND Production Tree and Adapter Flange. Inspect Hanger threads. They are really worn from wirelinelcoiled tubing work. The Hanger will have to speared to retrieve. 23:00 - 00:00 1.00 BOPSU DECOMP PJSM. NU 13 5/8" BOPE. 10/15/2006 00:00 - 03:30 3.50 BOPSU DECOMP Continue NU BOPE. Change out Pipe Rams from 2 718" x 5" VBR's to 7" Pipe Rams. RU Test Equipment. 03:30 - 07:30 4.00 BOPSU DECOMP Pressure test BOPE per BP/AOGCC Regulations to 250 psi low I 3,500 psi high. The state's right to witness the test was waived by John Crisp at 17:30 hrs on 10/14/2006. The test of the BOPE was witnessed by the Company Man and Toolpusher. 07:30 - 08:30 1.00 BOPSU DECOMP PJSM. Pick up lubricator, pull two way check valve, UD lubricator. 08:30 - 09:30 1.00 PULL P DECOMP PJSM. Pick up Baker Spear, engage 7" below hanger, BOLDs. Printed: 11/6/2006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/13/2006 1 0/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 10/15/2006 09:30 - 10:30 1.00 PULL P DECOMP PJSM. Estimated wt of 7" to chem cut @ 7766' = approximately 180K. Pull to 200K, no movement, 275K, observed hanger come free @ 215K, and see 14" of stretch but no indication of movement of 7". Work several times to 275K, work a few times @ 280K, and pull (1) time to 300K with max stretch of 19". Rough calculations indicate freepoint around 3800' - 4500'. (Holes in 7" @ 3964' & 3966'). 10:30 - 13:00 2.50 PULL P DECOMP PJSM. Call for Schlumberger E line unit. Circulate well bore @ 5 bpm 1430 psi. 74 bbls pumped before getting returns. Circulate bottoms up, (350 bbs), see small amount of gas wI oil spots at btms up. 13:00 - 13:30 0.50 PULL N DPRB DECOMP PJSM. Mix 1/2 bbl EP Mud Lube in 40 bbls brine & pump down 7" x 9 5/8" IIA, Chase wI 70 bbls brine. 5 bpm 1350 psi. Work pipe a couple of times to 280K, no indication of movement downhole. 13:30 - 14:30 1.00 PULL N DPRB DECOMP PJSM. Release spear & UD same. 14:30 - 20:00 5.50 PULL N DPRB DECOMP PJSM. N/D flow nipple, N/U shooting flange. RU Schlumberger E-line. 20:00 - 20:30 0.50 PULL N DPRB DECOMP PJSM with Schlumberger E-line and Nabors personnel. 20:30 - 21 :00 0.50 PULL N DPRB DECOMP MU String Shot and pressure test Lubricator to 500 psi. 21 :00 - 22:00 1.00 PULL N DPRB DECOMP RIH with String Shot to desired chemical cut depth. 22:00 - 22:30 0.50 PULL N DPRB DECOMP Tie in to well bore schematic depths. Examine joints to determine cut depth. Choose 3,535' as cut depth. This is the middle of the 35th joint below the SSSV Nipple. This joint was chosen because it looks the cleanest on the CCL. Shoot String Shot from 3,520' - 3,536'. POOH with wireline. 22:30 - 23:00 0.50 PULL N DPRB DECOMP On surface with wireline. Break down String Shot components and MU new toolstring for Chemical Cutter. 23:00 - 00:00 1.00 PULL N DPRB DECOMP Circulate hot 2% KCL down the well to warm up the wellbore for the Chemical Cutter. Took 58 bbls to fill the hole. Pumped at a rate of 3.5 bpm 1150 psi. 10/16/2006 00:00 - 00:30 0.50 PULL N DPRB DECOMP Continue circulating well to heat up wellbore in preparation of Chemical Cutter. Fluid being pumped at 78 degrees and getting returns at 70 degrees. 00:30 - 01 :00 0.50 PULL N DPRB DECOMP MU Chemical Cutter with Schlumberger E-line reps. 01 :00 - 02:00 1.00 PULL N DPRB DECOMP RIH with Chemical Cutter. Tie in to previous String Shot run. CCL to severing head is 16.5'. Therefore stop CCL at a depth of 3,518.5'. Chemically cut the 7" Tubing at a depth of 3,535'. Good indication seen on surface of successful detonation. The wireline BOPs shook up and down and the wire jumped. 02:00 - 03:00 1.00 PULL N DPRB DECOMP POOH with Chemical Cutter. 03:00 - 04:30 1.50 PULL N DPRB DECOMP RD Chemical Cutter Assembly and Schlumber E-line unit. 04:30 - 05:30 1.00 PULL N DPRB DECOMP ND Shooting Flange. NU Flow Riser. 05:30 - 07:00 1.50 PULL P DECOMP PJSM. M/U spear assembly, engage 7" below hanger, pull to 95K & observe hanger & 7" pulling free. Pull hanger to floor, UD spear assembly. 07:00 - 15:30 8.50 PULL P DECOMP PJSM. POOH wI 7", 26#, Atlas Bradford TC4S tubing & dual control lines. Continuous hole fill WI POOH. Recovered (1) 20' pup jt, 53 full joints & SSSV & 124 stainless steel bands. Calculated hole fill = 19 bbls, actual hole fill = 98 bbls. 15:30 - 16:30 1.00 PULL P DECOMP Clear I clean rig floor. RID spooling unit. 16:30 - 18:30 2.00 PULL P DECOMP Continue to POOH wI 7" tbg. 18:30 - 19:30 1.00 PULL P DECOMP On surface with cut joint. Recovered 19.52' of cut Joint (Joint Printed: 11/612006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/13/2006 10/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 #88). The chemical cut is extremely clean and good looking. Should have no issues spearing the remaining 7" below. RD 7" Handling Equipment. Recovered (2) more stainless steel bands. 19:30 - 22:30 DECOMP Set Test Plug. Change out Pipe Rams from 7" to 3 1/2" x 6" VBRs in preparation for handling DP. Pressure test Pipe Rams to 250 psi 13,500 psi - good. Pull Test Plug and clear and clean Rig Floor. RD and re-RU Tiger Tank further away from Rig to make room for Slickline Unit doing work on adjacent well. 22:30 - 00:00 1.50 PULL P DECOMP PU and MU BHA #3 as follows: Bull Nose, Spear Pack-Off, XO, Itco Spear - 6.095" Grapple, IIco Spear - 6.220" Grapple, Spear Extension, XO, Stop Sub, XO, Bumper Sub, Oil Jar, XO, 6 3/8" DCs, XO, Intensifier, XO. OAL = 242.52'. 10/17/2006 00:00 - 03:30 3.50 PULL P DECOMP TIH with BHA #3 on 31/2" DP. Picking up Joints of DP 1x1 from Pipe Shed. 03:30 - 04:30 1.00 PULL P DECOMP PU Joint #105 of DP. UW = 72K, DW = 70K. MU Headpin to Joint #105. Begin RIH to top of Fish. Found top of fish 10' in on Joint #105....Top of Fish = 3,540' 4ESMD. Continue in to Stop Sub on BHA. Stack 20K down 27' in on Joint #105. Work pipe to get the Grapples to engage the Fish. PU to 225K and jar Fish. PU 7" Fish with an UW = 200K and dragging. 04:30 - 06:00 1.50 PULL P DECOMP Line up to circulate down the DP and up the Annulus. Break circulation at a rate of 3 bpm I 450 psi. Took 24 bbls to get returns on surface. CBU while monitoring returns. 06:00 - 07:30 1.50 PULL P DECOMP PJSM. Increase rate to 5 bpm I 800 psi. See gas in returns wI bottoms up. Continue to circulate to clean, gas free retums. 07:30 - 08:00 0.50 PULL P DECOMP PJSM. Service rig, inspect derrick. 08:00 - 13:00 5.00 PULL P DECOMP PJSM. POOH w/3 1/2" DP. Continuous hole fill while POOH. 13:00 - 14:00 1.00 PULL P DECOMP Break down BHA. Spear would not release from cut Joint. About 2 handfuls of rubber on outside of Fish. RU 7" Handling Equipment. 14:00 - 15:00 1.00 PULL P DECOMP POOH with 7" Tubing laying down in Pipe Shed. Laid down 11 Joints and encountered the Tubing Punch holes. 15:00 - 16:00 1.00 PULL P DECOMP CBU at a rate of 5 bpm I 200 psi - OK. 16:00 - 21 :30 5.50 PULL P DECOMP Continue TOH with 7" Tubing laying down in the Pipe Shee!. Recovered a total of 106 full Joints of 7" from the previous cut depth. Joint #106 had Tubing Punch holes in it. Joint #107 was the cut Joint. Cut Joint length = 19.28'. Inspect the cut and looks fairly clean, looks like 3 different spots had to be pulled apart. 21 :30 - 23:30 2.00 CLEAN P DECOMP Clear and clean Rig Floor. RD 7" Handling Equipment. RU 3 1/2" Handling Equipment. Observe well and well is dead, fluid is neither rising nor dropping. 23:30 - 00:00 0.50 CLEAN P DECOMP PU and MU BHA #4 components as follows: 77/8" Reverse Circulating Junk Basket, Boot Basket, 9 5/8" Casing Scraper, Bit Sub, XO, Bumper Sub, Jar, XO, 6 3/8" Drill Collars, XO, XO, Pump Out Sub. OAL = 235.08'. 10/18/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Continue MU BHA #4 with Baker rep. 00:30 - 06:00 5.50 CLEAN P DECOMP TIH with BHA #4 on 31/2" DP from Derrick. Tight spot at 2,226', it hung up the BHA while RIH. While sitting on top of tight spot, the BHA fell through on its own. Work up and down through a couple of times with no problems, maybe some junk Printed: 11/612006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/13/2006 1 0/25/2006 Spud Date: 6/19/1976 End: 10/25~006 10/18/2006 00:30 - 06:00 5.50 CLEAN P DECOMP on the FOC? Continue TIH with single joints of DP from Derrick and then Pipe Shed 1 x 1. 06:00 - 06:30 0.50 CLEAN P DECOMP Lub Rig. Inspect Derrick. Test PVT Alarms. 06:30 - 08:30 2.00 CLEAN P DECOMP Continue to trip in with BHA #4 and 3 1/2" Drill Pipe 1 x 1 from the Pipe shed. 08:30 - 09:00 0.50 CLEAN P DECOMP Tagged junk/fill at 7,718'. Make-up Head Pin and circulate at 4.0 bpm/1025 psi with Reverse Circulating Junk Basket from 7,718' -7,769' 4es md. 7,769' is the top of the 7" Stump. 09:00 - 10:30 1.50 CLEAN P DECOMP Drop bar and open Pump-Out-Sub. Circulate bottoms up at 5.0 bpm/900 psi. Monitor Well dead. Hole remains full. 10:30 - 15:30 5.00 CLEAN P DECOMP TOH with 3 1/2" Drill Pipe standing back in Derrick and BHA #4. 15:30 - 17:00 1.50 CLEAN P DECOMP BHA to surface. Lay down 6 3/8" Drill Collars. Lay down remaining BHA. Clear RCJB. Recovered several pieces of control line rubber covering. Casing Scraper blades were jammed with rubber. Boot Basket contained -1 gal of scale, rust, and small pieces of rubber. 17:00 - 19:00 2.00 CLEAN P DECOMP Clear and clean Rig Floor. PU 4 3/4" Drill Collars. Break out Spear from 7" Fish. 19:00 - 20:00 1.00 CLEAN C DECOMP PU and MU BHA #5 as follows: 53/4" RCJB (w/6" Shoe), Double Pin Sub, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, (3) 4 3/4" Drill Collars and Pump Out Sub. OAL = 136.91'. 20:00 - 22:30 2.50 CLEAN C DECOMP TIH with BHA #5 on 31/2" DP from Derrick. Pick up 4 more Joints from Pipe Shed. 22:30 - 00:00 1.50 CLEAN C DECOMP With 241 Joints in the well, stack out on top of 7" Stump at 7,769'. Rotate 3 revs and fall into 7" Tubing. Continue TIH inside 7" Tubing. Stack hard on top of PBR Assembly at 7,832'. Seems to be swedging into PBR, about 10K overpull to get out of it. No record of ID through PBR, Baker completions thinks it may be a 6" ID. Consult with Baker Fishing rep and decide to size down RCJB. Break circulation at 3 bpm I 400 psi across 7" interval above PBR prior to TOH with BHA. 10/19/2006 00:00 - 03:00 3.00 CLEAN C DECOMP TOH with BHA #5 standing back DP in the Derrick. 03:00 - 03:30 0.50 CLEAN C DECOMP On surface with BHA #5. Break down RCJB and inspect along with Boot Baskets. They are empty. Inspect 6" Shoe for any markings from PBR, nothing identifiable. MU BHA #6.....same 53/4" RCJB with a 53/4" Shoe on bottom. Add an extension to allow for more debris to be caught in BHA. 03:30 - 06:00 2.50 CLEAN C DECOMP TIH with BHA #6 on 3 1/2" DP from Derrick. 06:00 - 06:30 0.50 CLEAN C DECOMP Rig service. 06:30 - 07:00 0.50 CLEAN C DECOMP Continue to TIH with 3 1/2" Drill Pipe and BHA #6. 07:00 - 08:30 1.50 CLEAN C DECOMP Pick-up Jt # 241 and work through the top of the 7" Stump at 7,769' with very little problem. Continue down to the top of the Seal Assembly at 7,832'. Passed through with no problems. Continue in hole. Set down solid at 7,868' ( botton of the 7" Seal Assembly Nose), once again in an un-known I.D. restriction. Circulated at 3.0 bpm/425 psi. to work Reverse Circulating Junk Basket. 08:30 - 13:30 5.00 CLEAN C DECOMP Lay down 5 singles. Trip out with 3 1/2" Drill Pipe and BHA #6. 13:30 - 16:00 2.50 CLEAN C DECOMP Lay down BHA #6. Clear and clean floor. Discuss J.D. problems and a plan forward with Anch Eng. 16:00 - 18:00 2.00 CLEAN C DECOMP Rig repairs. Repair air bag that actuates the clutch to the Printed: 11/6/2006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/1 3/2006 1 0/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 10/19/2006 16:00 - 18:00 2.00 CLEAN C DECOMP break-out tong line. 18:00 - 20:00 2.00 CLEAN C DECOMP PU and MU BHA #7 as follows: 5 Blade Junk Mill, Bit Sub, (7) Jts of 2 7/8" Pac Pipe, XO, XO, Bumper Sub, Oil Jar, (3) 4 3/4" Drill Collars, Pump Out Sub. OAL = 336.91'. 20:00 - 23:30 3.50 CLEAN C DECOMP TIH with BHA #7 on 3 1/2" DP from Derrick. 23:30 - 00:00 0.50 CLEAN C DECOMP Tag on 7" Stump @ 7,769 with 78 stands in the Hole (234 Joints). Rotate and fell right in with no problems. Pass the top of the PBR with no problems. Saw about a 5K weight bobble as we passed the bottom of the 7" Seal Assembly Nose @ 7,868'. Continue RIH. PU Joint #241. UW = 119K , DW = 114K. RIH with Joint #241 which will get us to our target. RIH and completely bury the Joint with no problems, final depth achieved = 7,971'. 10/20/2006 00:00 . 02:00 2.00 CLEAN C DECOMP MU Headpin to CBU. Break circulation at a rate of 5.5 bpm / 1,280 psi. Had some small traces of oil in returns as bottoms up was reached but no gas. Continue until clean returns. Pumped a total of 515 bbls. RD circulating hose and Headpin. Monitor well to ensure it is still dead - OK. 02:00 - 05:00 3.00 CLEAN C DECOMP TOH with BHA #7. Lay down 4 singles and continue TOH standing back DP in the Derrick. 05:00 - 06:00 1.00 CLEAN C DECOMP On surface with BHA #7. Break down and lay down components. Fluid level remains at surface. 06:00 - 06:30 0.50 EVAL P DECOMP Make-up Halco 9 5/8" RBP and Running Tool. 06:30 - 10:00 3.50 EVAL P DECOMP Trip in with RBP and 3 1/2" Deill Pipe (80 stds). 10:00 - 11 :00 1.00 EVAL P DECOMP Pick-up 2 singles. Set RBP with the center element at 7,740'. Rig-up to pressure test 9 5/8" Casing against RBP. No-Joy. Pumping away at 4.0 bpm/2,000 psi. OAP = 0 psi. 11 :00 - 12:30 1.50 EVAL P DECOMP Pick-up Halco 9 5/8" RTTS Packer. Run in on 1 stand of 3 1/2" Drill Pipe. Set Packer at -93'. Rig up to pump down Drill Pipe and repeat inital casing test with the same results. Shut in Drill Pipe. Pressure up on back-side to 3,500 psi/10 minutes. Good test. 12:30 - 13:30 1.00 EVAL P DECOMP PJSM with Crew just rotating back to work from days-off. Complete handover with Crew rotating off tower. Service Rig. 13:30 - 17:00 3.50 EV AL P DECOMP Release RTTS Packer. Pull 1 stand and lay down Packer. Trip out with 3 1/2" Drill Pipe and RBP Running Tool. 17:00 - 17:30 0.50 EVAL P DECOMP MU 9 5/8" RTTS per Halliburton rep. 17:30 - 19:30 2.00 EV AL P DECOMP TIH with 9 5/8" RTTS on 3 1/2" DP from Derrick. 19:30 - 20:00 0.50 EVAL P DECOMP 46 stands and 2 singles (140 Joints) in the well. UW = 73K, DW = 73K. PU 6' and set RTTS at a depth of 4,531 '. Took 1 1/2 tums to the right to set. 20:00 - 22:00 2.00 EV AL P DECOMP RU Test Equipment. Test from RTTS depth of 4,531' to the RBP at 7,740' through the Drill Pipe - No Joy. Pumping away at the same rate of 4 bpm I 2,000 psi. OA = 0 psi. Shut in DP and RU to test down the IA from surface to RTTS depth of 4,531'. Pressure test to 3,500 psi for 15 mins - good. Bleed down and RD Test Equipment from IA. Release RTTS with Halliburton rep. Consult with Anchorage Engineering and decide to TIH with RTTS to just above RBP and test to confirm RBP is competent. 22:00 - 23:30 1.50 EVAL P DECOMP TIH with 9 5/8" RTTS on 3 1/2" DP from Derrick. 23:30 - 00:00 0.50 EVAL P DECOMP In with 79 stands and 2 singles (239) Joints. UW = 118K , DW = 112K. Set RTTS at a depth of 7,671'. RU Test Equiment. Printed: 11/6/2006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/1 3/2006 1 0/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 10/20/2006 23:30 - 00:00 0.50 EV AL P DECOMP Pump down the Drill Pipe to pressure test from the RTTS to the RBP @ 7,740'. Test to 3,500 psi for 15 mins· good. Pumped a total of 1.3 bbls to achieve test pressure. 10/21/2006 00:00 . 00:30 0.50 EV AL P DECOMP RU Test Equipment on the Annulus (Drill Pipe x 9 518"). Pressure test from surface to RTTS at a depth of 7,671'. Achieved an injection rate of 4 bpm 11,700 psi - no test. Pumped a total of 14 1/2 bbls. Bleed down and RD Test Equipment. Consult with Anchorage Engineering and agree to POH with RTTS about halfway to previous set depth and begin to narrow down location of leak. 00:30 - 01 :30 1.00 EVAL P DECOMP TOH with RTTS standing back DP in the Derrick. Stood back a total of 16 stands (48 Joints). 01 :30 . 07:00 5.50 EVAL P DECOMP Set RTTS @ 6,148'. Tested from below to the RBP @ 7,740' to 3,500 psi for 10 mins - OK. Released and set RTTS @ 5,671'. Tested from below to the RBP @ 7,740' to 3,500 psi for 10 mins - OK. Released and set RTTS @ 5,196'. Attempted to test from below to the RBP @ 7,740' and it failed - rate of 4 bpm 11,850 psi. Released and set RTTS @ 5,292'. Tested from below to the RBP @ 7,740' to 3,500 psi for 10 mins - OK. Released and set RTTS @ 5,261 '. Test from below to the RBP @ 7,740' and it failed - rate of 3 bpm 11,800 psi. Test the annulus to surface and it held to 3,500 psi for 30 mins - OK. Leak identified to be from 5,261' - 5,292'. Discuss plan forward with Anch Eng. 07:00 - 07:30 0.50 EVAL P DECOMP Bleed off pressure. Rig down test equipment. Release Packer. 07:30 - 08:00 0.50 EV AL P DECOMP Service Rig. Inspect Derrick. Check PVT alarms. 08:00 - 10:30 2.50 EV AL P DECOMP Trip out with 3 1/2" Drill Pipe. Lay down RTTS Packer. Clear and clean floor. 10:30 - 13:30 3.00 WHSUR P DECOMP Make-up Running Tool to fetch Halco RBP. Trip in with Running Tool and 3 1/2" Drill Pipe. Stop just above RBP. 13:30 - 15:00 1.50 WHSUR P DECOMP Stop to cut and slip Drilling Line (84'). 15:00·15:30 0.50 WHSUR P DECOMP Latch and release Halco RBP. Monitor Well dead. Fluid level at surface. 15:30 . 17:30 2.00 WHSUR P DECOMP Move Halco RBP up-hole and set at 4,075' above the leak at 5,261'-5,292'. Release RBP and stand back 2 stands of DP in preparation for Storm Packer run. 17:30 - 18:00 0.50 WHSUR P DECOMP RU Test Equipment. Pressure test the RBP to 3,500 psi for 10 mins - charted. OK. 18:00 - 19:30 1.50 WHSUR P DECOMP MU Storm Packer per Halliburton rep. RIH one joint of DP to set Storm Packer. UW = 67K , DW = 67K. Set Storm Packer with mid element at 36' and top of Packer at 29'. Pressure test to 1,500 psi for 5 mins - charted. OK. 19:30 - 20:30 1.00 BOPSU P DECOMP PJSM. ND 135/8" BOPE. 20:30 - 00:00 3.50 WHSUR P DECOMP ND 7" Tubing Spool with Cameron rep. Inspect current Packoff and it is pretty worn out. Inspect top of 9 5/8". Change out and install new Packoff. 10/22/2006 00:00 - 02:00 2.00 WHSUR P DECOMP NU new McEvoy Tubing Spool with Cameron rep. 02:00 - 02:30 0.50 WHSUR P DECOMP Pressure test Packoff to 3,500 psi for 30 mins per Cameron rep. - Good. 02:30 - 05:00 2.50 BOPSU P DECOMP PJSM. NU Test Spool. NU 135/8" BOPE. RU Test Equipment. 05:00 - 14:00 9.00 BOPSU P DECOMP Install Test Plug. Test Plug leaking. Wait on new Test Plug. Install second Test Plug. Start BOP test. Blind/Shear Rams Printed: 11/6/2006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/13/2006 10/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 leaking. Change-out Rams. Pressure test BOPE per BP/AOGCC regulations to 250 psi I 3,500 psi. Good test. The state's right to witness the test was waived by Jeff Jones on 10/21/2006. The test was witnessed by the Company Man and Toolpusher. Rig down test equipment. 14:00 - 15:00 1.00 WHSUR P DECOMP Run in and release Halco Storm Packer. Pull to floor and lay down. 15:00·15:30 0.50 WHSUR P DECOMP Run in with 2 stands. Latch and released Halco RBP. 15:30 - 18:00 2.50 WHSUR P DECOMP Trip out with 3 1/2" Drill Pipe and Halco RBP. Lay down RBP. 18:00 - 18:30 0.50 WHSUR P DECOMP Set Wear Bushing. 18:30 - 19:30 1.00 CASE C TIEB1 PU and MU BHA #8 as follows: Washover Shoe, Washpipe Extension, Triple Connection Washover Boot Basket, XO, Bumper Sub, Oil Jar, (3) 4 3/4" DCs, Pump Out Sub. OAL = 129.04'. 19:30 - 00:00 4.50 CASE C TIEB1 TIH with BHA #8 on 3 1/2" DP from Derrick. 10/23/2006 00:00 - 02:00 2.00 CASE C TIEB1 PU and MU Kelly. UW = 122K , DW = 119K. Dry tag the 7" Stump 8' in on the Kelly = 7,770'. Une up to circulate down the DP. Pump a 25 bbl hi-vis sweep at 3.5 bpm I 450 psi. Spot the pill on the backside with seawater at a rate of 5 bpm I 750 psi. Start dressing off the Stump. Reduce pump rate to 3 bpm I 380 psi. Engage rotary table at 35 RPM with 3,000 ft-Ibs of torque (150 Amps). Wash BHA down dressing off. Continue to work until 18' in on the Kelly - total of 10' washed down. 02:00 - 04:00 2.00 CASE C TIEB1 Une up to reverse circulate. PU BHA off of 7" Stump to avoid plugging off. Reverse circulate until sweep returns to surface. Break circulation at a rate of 3 bpm I 420 psi. Monitor losses while reversing down the 9 5/8" because of the leak at 5,261 '-5,292'. Total loss of 2 bbls. Getting scale across shakers. With the sweep to surface, getting metal shavings and scale across shakers. Continue until sweep completely out. Pumped a total of 247 bbls. RIH over Stump to ensure it is clean. Make it to 18' in on the Kelly with no problems - OK. 04:00 - 04:30 0.50 CASE C TIEB1 Blow down and set back Kelly. Monitor well and notice slight flow up the Annulus. The DP is static about 20' down from Rig Floor. Une up to circulate the well all the way around to condition the hole. 04:30 - 10:30 6.00 CASE C TIEB1 Break circulation at a rate of 4 bpm I 480 psi. No losses noted, increase rate to 5 bpm 1710 psi. About halfway through first circulation, began seeing gas returns to surface. Continue to clean condition well bore. Circulated well surface to surface two times to get all the gas out. Shut well in and monitor. SIDP = 90 psi. 10:30 - 16:00 5.50 CASE C TIEB1 Order out 9.1 ppg brine from MI. Wait on vac trucks to arrive with brine. Weight up the fluid in Pit #3 (-200 bbls) to 9.1 ppg with salt. Continue to wait on final vac truck. 16:00 - 19:30 3.50 CASE C TIEB1 Swap the well over to 9.1 ppg brine at a rate of 5.75 bpm I 1,150 psi. Continue circulating well until 9.1 ppg returns seen on surface. Pumped a total of 653 bbls and shut well in. Monitor well dead. The DP is falling slowly and the Annulus is falling slowly as well. Continue to monitor well for 30 mins - well is dead. Fill hole 2.5 bbls after the 30 mins - 5 bph loss. 19:30 - 23:30 4.00 CASE C TIEB1 TOH with BHA #8 laying down excess DP. Laid down 79 joints of DP. Set back 54 stands (162 Joints) of DP in the Derrick. Printed: 11/6/2006 8:03:50 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-03 G-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/13/2006 10/25/2006 Spud Date: 6/19/1976 End: 10/25/2006 10/23/2006 23:30 - 00:00 0.50 CASE C TIEB1 BHA #8 on surface. Break down BHA components with Baker rep and lay down. 10/24/2006 00:00 - 01 :00 1.00 CASE C TIEB1 Continue breaking down BHA with Baker rep. Clear and clean Rig Floor. 01 :00 - 01 :30 0.50 TA C ABAN PU and MU 9 5/8" EZSV with Halliburton rep. 01 :30 - 04:30 3.00 TA C ABAN TIH with 9 5/8" EZSV on 3 1/2" DP from the Derrick. 04:30 - 05:30 1.00 TA C ABAN 54 stands (162 Joints) of DP in the well. UW = 77K, DW = 77K. Break circulation at a rate of 4 bpm I 500 psi and work through set area. Attempt to set and did not set. Lay down one Joint of DP. Start setting process again. Turn 37 turns to the right. Work up to 50K over (128K). Set EZSV @ 5,096'. Set 20K down on Plug to verify set. 05:30 - 06:00 0.50 TA C ABAN Pressure test 9 5/8" EZSV to 3,500 psi for 30 minutes charted - OK. 06:00 - 07:00 1.00 TA C ABAN Rig service. Inspect Derrick. Check PVT alarms. Remove lower valve from Kelly. 07:00 - 10:30 3.50 TA C ABAN Single down remaining 3 1/2" Drill Pipe in Pipe shed. 10:30 - 11 :00 0.50 TA C ABAN Drain BOP Stack. Pull Wear Bushing. 11 :00 - 15:00 4.00 TA C ABAN Load Pipe Shed with 4 1/2" 12.6Ib/ft, L-80, TCII Tubing. Drift and tally same. 15:00 - 16:30 1.50 TA C ABAN Set test plug. Rig-up test equipment. Test VBPRs on 4 1/2" Tubing. Test at 250/3500 psi. Record on chart. Good test. Rig-down test equipment. Pull Test Plug. 16:30 - 17:30 1.00 TA C ABAN Rig-up to handle 41/2" Tubing. 17:30 - 23:00 5.50 T A C ABAN Run Kill String as follows: 4 1/2" Mule Shoe, Pup Joint, Pup Joint, X-Nipple, Pup Joint, 121 Joints of 41/2" TCII Tubing, Pup Joint, Tubing Hanger. Bottom of WLEG @ 5016'. 23:00 - 00:00 1.00 TA C ABAN P/U & M/U landing jt into hanger. Inspect hanger. RlU circulkating equip. 10/25/2006 00:00 - 01 :30 1.50 TA C ABAN RlU & displace well to 9.8 ppg brine. Pumped 4 BPM @ 120 psi. Pumped total of 370 bbls. 01 :30 - 02:00 0.50 TA C ABAN Blow & RID circulating lines. Drain BOP stack. Land kill string. P/U & SIO Wts. = 65K. RILDS. 02:00 - 03:00 1.00 TA C ABAN Dry rod TWC in hanger. Pressure test TWC from top & bottom to 1000 psi for 10 min. Charted same. 03:00 - 05:00 2.00 TA C ABAN N/D BOPE. 05:00 - 07:00 2.00 TA C ABAN NIU adapter flange & X-mas tree. 07:00 - 08:00 1.00 TA C ABAN Test Adaptor Flange at 3500 psi/30 minutes. Test Tree at 3500 psi. 08:00 - 10:00 2.00 TA C ABAN Wait on DSM. Pick-up Lubricator and pull TWC. LAy down same. 10:00 - 11 :30 1.50 TA C ABAN Rig up LiI'Red. Reverse in with 42 bbls of Diesel. U- Tube Diesel to freeze protect Annulus and Tubing. rig dow Lil' Red. 11 :30 - 12:30 1.00 TA C ABAN Set BPV. Test at 1000 psi from below. Blow down lines and rig down same. 12:30 - 14:00 1.50 TA C ABAN Clean Pits. Secure Tree and Cellar. Released Rig at 14:00 Hrs. Printed: 11/612006 8:03:50 AM TREE'= WB..LHEAD = ACTUATOR = KB, ELEV = BF. B..EV = KOP= Max Angle = Datum MD = Datum ND = 6" CrN M:~;~ FROM DRLG . DRAFT G -03A 34.26' 4600' 95 @ 10922' 9131' 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" I 2675' 14-1/2" TBG, 12,6#, L-80. TCII H 4994' I HOLES IN CSG I 5262' - 5291' 17" TBG. 26#, N-80, .0382 bpf, ID = 6.276" 7870' Minimum ID = 2.377" @ 8188' BAKER XO TO FL4S/STL 1 TOP OF 7" LNR TOP OF 2-718" LNR 9-5/8" CSG, 47#, N-80, ID = 8,681" I 8375' ÆRFORA TION SUMMARY REF LOG: MWD/GR ON 05/14/97 ANGLE AT TOP ÆRF: 80 @ 9550' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 1-11/16" 4 9550 -10180 C OS/21/97 1-11/16" 4 9970 - 9880 C OS/21/97 2" 6 10600 - 10770 C 04/29/99 2'" 6 10830 - 10940 C 04/29/99 1-11/16" 4 11060-11120 C OS/21/97 1-11116" 4 11150-11210 C OS/21/97 I SAFETY NOTES: 2209' -i 9-5/8" FOC I 2719' H 9-5/8" DV COLLAR I 4995' 5015' 5096' -i 9-5/8" HES EZSV CIBP I -i Top of 7" Chern Cut Stump PBR, TOP OF SEAL ASSY, (40' BOT) 7" BTM OF 7" SEAL ASSY NOSE 9-5/8" X 7" PKR I 2-7/8" LNR WLEG, ID = 3.75" I BAKER CTLRT WIGS, ID = 2,97" I BAKER XO TO FL4S AND BPX XO TO STL, ID = 2,377" I 7" SIDETRACK WINDOW @ 8664' 17" LNR, 29#, N-80, ,0371 bpf, ID = 6.184" I 8664' DATE 07/31/77 OS/23/97 09/21/01 12/05/02 OS/29/03 06/03/03 I PBTD I 12-7/8" LNR, 6.16#, L-80, ,0058 bpf, ID 2.377" REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION RN/TP CORRECTIONS A NY ITLH MIN ID & ÆRF CORRECTIONS SRB/TLP DRAWING CORRECTIONS SRB/TLP CORRECTIONS DATE 07/12/03 03/14/06 10/23/06 10/26/06 REV BY COMMENTS A Y /KAK TBG PUNCH CORRECTIONS DRFITLH L TIP SET FVR PROPOSED COMPLETION LHlPAG DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WB..L: G-03A ÆRMIT No: '1970700 API No: 50-029-20221-01 SEC 12, T11N, R13E. 2263' NSL & 1974' EWL BP Exploration (Alaska) . STATE OF ALASKA ~fc 1~3fcx; ALASKA Oil AND GAS CONSERVATION COMMlloN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alasl{l~ ~~~'VED ~n":"" '~·~'i.I·· :·':d",<!Jf<· 11 rz ['J 0, ro' T 6) \) J M ð Commission 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate j:,nci'o!::!g» o Time Extension....." . ", ~ o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well / o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other / 2. Operator Name: 4. Current Well Class: 5. PermitTo Drill Number / BP Exploration (Alaska) Inc. 181 Development D Exploratory 197-070 (\ 3. Address: D Stratigraphic D Service \ 6. APIN Tl~~r: -OJ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 59-02 20~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Wen Name(\~~bêç :;y property line where ownership or landownership changes: P UG Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field I Po ~ay~ Prudhoe Bay Pool ADL 028280 61.50 \ Prudt" 12.i / " PRESENTWEI..I...CONDITIONSÚMMAAY E' ..... ".';/"/'··~.i.. ...../ ///,////" ..··i·. ii.i···....·,·.....···.../i.../. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth ~: l""þfu~eaSUred): Junk (measured): 11288 9019 11254 9019 u None None Casino Lenoth Size MD ~D Burst Collacse Structural \ \. \ , ¡¡,. Conductor 110' 20" x 30" 110' ' '\. 1\o'} /' '\. SurfaC'..e 2675' 13-3/8" 2675' '2675 ' J' '\. 4930 2670 Intermediate \\/ Production R375' 9-518" 8375' R~6' 6870 4760 Liner 826' 7" 7838' - 8664' 7729' - 8521' 7240 5410 Liner 3104' 2-7/8" 8184' - 11288' 8062' - 9019' 13450 13890 , ....... I/" "- f\ "" / Perforation Depth MD (ft): I Perforation Depth ~ft): ~ T JÐing Size: Tubing Grade: Tubing MD (ft): 9550' - 11210' 8961' - 9017' ,,1 7",26# N-80 7766' - 7870' Packers and SSSV Type: 9-518" x 7" Baker ~~ y; packers and SSSV MD (ft): 7875' 13. Attachments: D~}.~ 14. Well Class after proposed work: 181 Description Summary of Proposal ~ D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for '/ 16. Well Status after proposed work: CommencinQ Operations: 1 0/23/06 I 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Dat~~~/23/2006 DWAG DGINJ DWINJ D WDSPL Commission Representative: Winto ubert 18. I hereby certify that the foregoing is truet correct to the best of my knowledge. Contact Frank Roach, 564-4373 Pr;nted Na'ÇJ;aY;d Ream Tille DrllUng Eng;nee, Prepared By Name/Number: Signature C/?nn / Phone 564-5743 Date to/2Jjr;¡(, Sondra Stewman, 564-4750 /' Commission Use On Iv Sundry Number: ?-,¡'y ^ - ~&) t Conditions of approval: Notify Co mission so that a representative may witness -- - . D Plug Integrity DBOP st D Mechanical Integrity Test o Location Clearance Other: 5CAì\W~ED ') c RBDMS 8Ft OCT 2 5 2000 Subsequent For equired: APPROVED BY Approved COMMISSIONER THE COMMISSION Date Form 10-"Í03 Revised 06/2006 r\ Submit In Du licate uRIGINAL p . . G-03A Rig Workover Scope of Work: Original scope called for a tubing from 7" N-80, to 4-1/2" 13Cr-80. Scope has since changed to include 7" scab liner installation due to the discovery of a production casing leak. MASP: 3116 psi Well Type: Producer Estimated Start Date: October 23, 2006 P R" re- Ig: 0 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time) Well is NOT secured at this time. PPPOT-T & IC. S 2 Drift for 3-3/8" ISP plug to -7900'. Pull PGSL set in coil tubing liner top. E 3 Chem cut @ -7800'. (Ref: 07/20/76 7" tubinQ summary). DONE 9/26/06. F 4 Circulate well with seawater and FP w/ diesel thru the cut. MITOA to 2000 psi. PASSED 3/14/06. Sleed WHP's to 0 psi. 0 5 Set a SPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. Sullhead kill before ND tree. ND tree, NU, and test SOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 7" tubing string to the cut. 3. RIH with RSP on drill pipe and set above cut. 4. RIH with RTTS and determine leak point 5. Reset RSP above leak point. Set storm packer below wellhead and change out 9-5/8" packoff. 6. RIH with 7" tubing dress-off assembly and dress off tubing stub. 7. RIH with 7" RSP and set in 7" tubing stub. Stack -30' of sand on RSP. 8. Run and cement 7",26#, L-80 casing scab liner. Top of liner @ -3700'. PT well to 3500psi after drill out. 9. Run 4-%" 13Cr80 completion with Saker S-3 packer. Position packer at -7609' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set SPY. ND SOPE. NU and test tree. RDMO. TREE " WELLHEAD" ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 6" CrN McEVOY OTIS 61.5' 34.26' 4600' 95 @ 10922' 9131' 8800'SS . 13-3/8" CSG, 72#, N-80, 10 = 12.347" I 2675' Minimum ID = 2.377" @ 8188' BAKER XO TO FL4S/STL 17" TBG, 26#, N-80, ,0382 bpf, 10 = 6.276" I 7870' I TOP OF 7" LNR TOP OF 2-7/8" LNR 9-5/8" CSG, 47#, N-80, 10 = 8,681" I 8375' ÆRFORA TION SUMMARY REF LOG: MWD/GR ON 05/14/97 ANGLEATTOPÆRF: 80 @ 9550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9550 - 10180 0 OS/21/97 1-11/16" 4 9970 - 9880 0 OS/21/97 2" 6 10600 - 10770 0 04/29/99 2'" 6 10830 - 10940 0 04/29/99 1-11/16" 411060-11120 0 OS/21/97 1-11/16" 4 11150 -11210 0 OS/21/97 17" LNR, 29#, N-80, ,0371 bpf, 10=6,184" I 8664' DATE 07/31/77 05/23/97 06/03/03 07/12/03 09/05/06 09/11/06 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION SRB/TLP CORRECTIONS A Y /KAK TBG PUNCH CORRECTIONS JRP/PJC PGSL PULLED TEL/TLH IBP SET G-03A ~NOTES: . 2158' -i 7" SSSV OTIS LANDING NIP, 10 = 5,962" 2209' -19-518" FOC I 2719' H 9-5/8" DV PKR I 3964' -iTUBING PUNCH FOR PBGL TOP I 3966' -fTUBING PUNCH FOR PBGL BTM I 7744 . 7746' -1 TUBING PUNCH, 4 SPF (09/25/06) I 7766' ELM -f CHEM CUT (09/26/06) I -i PBR, TOP OF SEAL ASSY, (40' BOT) I -2-7/8" LNRWLEG, 10= 3.75" I -BAKER CTLRT WIGS, 10 = 2,97" BAKER XO TO FL4S AND BPX XO TO STL, 10 = 2,377" I 7" SIDETRACK WINDOW @ 8664' I PBTD I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, 10 - 2.377" 11254' 11288' DA TE REV BY COMMENTS 09/26/06 JCM'PAG PULL/SET/ PULL IBPs (9/15-24/06) 09/26/06 RLM'PAG TBG PUNCH / CHEM CUT PRUDHOE BA Y UNIT WELL: G-03A ÆRMIT No: "1970700 API No: 50-029-20221-01 SEC 12, T11 N, R13E, 2263' NSL & 1974' EWL BP Exploration (Alaska) G-03A PROPOSED I SAFElY NOTES, TREE !. WELLHEAD = ACTUA TOR = KB. ElEV = BF. ElEV = KOP= Max Angle = Datum MD = Datum 1V D = . 6" CPN McEVOY OTIS 61.5' 34.26' 4600' 95 @ 10922' 9131' 8800' SS I 13-3/8" CSG, 72#, N-80, ID = 12.347" I 19-518" x 7" BAKER ZXP LINER TOP PACKER 9-5/8" x 7" BAKER FLEXLOCK III LINER HANGER IT' TBG, 26#, L-80, ,0382 bpf, 10 = 6,276" /9-5/8" x 1" UNIQUE MACHINE OVERSHOT 17" TBG, 26#, N-80, .0382 bpf, ID = 6.276" 14-1/2" TBG, 12,6#, 13Cr-80, VAM TOP Minimum ID = 2.377" @ 8188' BAKER XO TO FL4SISTL I TOP OF 7" LNR I I TOPOF2-7/8"LNR I I 9-5/8" CSG, 47#, N-80, ID = 8.681" I 2675' ~ t ..J r~ r L_____ - 7870' I I ~ ~ 7877' ~~ 8184' ~ 8375' I PERFORA TION SUMMARY REF LOG: MWDIGR ON 05/14/97 A NGLE AT TOP PERF: 80 @ 9550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9550 - 10180 C OS/21/97 1-11/16" 4 9970 - 9880 C OS/21/97 2" 6 10600 - 10770 C 04/29/99 2'" 6 10830 - 10940 C 04/29/99 1-11/16" 4 11060-11120 C OS/21/97 1-11/16" 4 11150-11210 C OS/21/97 /7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I DA TE REV BY COMMENTS 07/31177 ORIGINAL COMPLETION 05/23/97 SIDETRACK COMPLETION 09/21/01 RNITP CORRECTIQNS 12/05/02 ANYffiH MIN ID & PERF CORRECTIONS 05/29/03 SRBffiP DRAWING CORRECTIONS 06/03/03 SRBffiP CORRECTIQNS 8664' : I I 1-14-1/2" HES "X" NIP, 10 = 3,813" I : :.: 2209' H 9-5/8" FOC I . : ---1 2719' H 9-5/8" DV COLLAR I ~ ~ GAS LFT MANDRElS U ST J\¡[) TYÆ VLV 3 3400 4-1/2" 1-1/2" 2 5645 4-1/2" 1" 1 7519 4-112" 1" I 1-14-1/2" HES "X" NIP, 10 = 3.813" I -\7" x 4-1/2" BAKER S-3 PKR, 103.875" I I I -14-112" HES "X" NIP. 10 = 3.813" I I I "14-112" HES "XN" NIP, 10= 3,725" I ~ -JVVLEG I ~~ 7835' -I PBR, TOP OF SEAL ASSY, (40' BOT) I 7871' - 7" BTM OF 7" SEAL ASSY NOSE I ...., 7875' -i 9-5/8" X 7" PKR I = - 8184' -I 3" LNR TOP TEST PLUG (03/14/06) I 1!!::::::3 8184' -I 2-7/8" LNR VVLEG, ID = 3.75" I - 'N 8184' H BAKER CTLRT WIGS, ID = 2.97" I 8188' BAKERXO TO FL4S AND "I ~ BPX XO TO STL, ID = 2.377" r 7" SIDETRACK WlNOOW@ 8664' I ~ ~ I PBID I 12-7/8" LNR, 6.16#, L-80. ,0058 bpf, ß) = 2.377" I DATE 07/12/03 03/14/06 10/23/06 11254' 11288' I "V REV BY COMMENTS A Y /KAK TBG PUNCH CORRECTIONS DRFffiH L TIP SET" FVR PROPOSED COMR.ETlON PRUDHOE BAY UNIT WELL: G-03A PERMIT No: "1970700 API No: 50-029-20221-01 SEC 12, T11N, R13E, 2263' NSL & 1974' EWl BP Exploration (Alaska) e Job# Loa Description Date 8 olor CD C-11A 11225983 LDL 07/02/06 1 8-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G-18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 8-28 11221590 LDL 07/04/06 1 8-01 11211508 PROD LOG W/DEFT 06/23/06 1 W-39A 11216197 MEM PROD PROFILE OS/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02106 1 G-03A 11211493 LDL OS/24/06 1 C-26A 11225979 LDL 06/07/06 1 F-268 N/A MEM PROD & INJECTION 06/06/06 1 F-268 N/A MEM 80RAX LOG 06/06/06 1 W-39A 11216197 MEM 80RAX LOG OS/29/06 1 F-04A 11221602 SCMT 08/18/06 1 Y-08A 11221604 SCMT 08/20/06 1 C-068 11212883 USIT 08/15/06 1 X-27 11217274 US IT 08/26/06 1 K-07D 10942217 MEMORY SCMT 06/15/05 1 Y-1OA 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 S8HP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15/04 1 A·30A 11054295 CH EDIT OF PDC LOG W/GR 04106/05 1 17-048 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 Z-30A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-048 P81 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Scblumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth ,6,'1-0'16 SCANNED SEP 1 4: 2005 WI! L Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~-.....-., - ) r.' > ',.s . .. ~~. \.... o..,,;_i 08/28/06 ~ ') i r .'. ' .i. ... '-;";\.10 NO. 3941 ,~t1! & Gas Cens, CcrnrniMtœ Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: Field: Prudhoe 8ay C . . Alaska Data & Consultmg Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /9 7 - () 7 0 03/15/05 Schlumberger NO. 3363 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD .-" 13 r!l~ C-39 10715421 MCNL 08/19/04 1 if i7-f-i<? E-21A 10670030 MCNL 08/22/04 1 ~, :/1- - / :û C-29A - 10715422 MCNL 08/22/04 1 J" :"~~ - íÎJ.DS 07-33B 10715361 MCNL 11/04/03 1 1 ~...;) I 'J-I5]-07-01A 10889151 RST 08/18/04 1 1 f 1 X-27 10724364 RST 03/10/04 1 1 . -CV E-18A 10621786 RST OS/22/04 1 1 7-~-(/Ï DS 01-24A 10563108 RST 10/09/03 1 1 11-"1.7. E-10A 10621797 RST 06/16/04 1 1 "9 -/02- Z-12 10704020 RST 07/06/04 1 1 ')1- C'1, X-15A 10704021 RST 07/07/04 1 1 '1~;;)1 P1-07A 10831301 RST 07/03/04 1 1 "1 ~ C7{);G-03A 10889210 LDL 02/13/05 1 .~; 2..1, L5-17A 10942195 PSP PPROFIDEFT/GHOST 02/28/05 1 ,'j ~C:J1P1-05 10687701 PPROF PSP/DEFT/GHOST 08/13/04 1 '1- ()¿. ð" MPC-42 10889141 RST 07/26/04 1 ~ -OtJ MPC-42 10621815 RST 08/07/04 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 Date Delivered: I I _3í(&; 105' j\ Ï' L Y. G:... ') Q O· 5 SCANNED ¡-'¡ r' H --'-- 0 L- - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995..0. 3-2~'3~. ATTN:~Beth 'Jí¡ Receiv by: ;Í / fA 'a/fA4tfi¿,-/ ." ' ¡ 11/26/03 Schlumberger NO. 3048 Alaska Data & Consulting Services Company: State of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ( Well Job # Log Description Date Blueline Prints CD D.S.15-01A \Y~~H::JA- 10703946 SCMT 10/31/03 2 NK-62A =¥;~ ._~) l.\ ~ 10572999 MCNL 05/30/03 1 1}:::J ~Jf () E-27A 'I L} - 0 F"Jq 10558568 MCNL 08/09/03 1 1 J;:),-:";5 G-03A ~. ::¡ -0 f.-O 10563449 MCNL 06/04/03 1 1 'I£)~ J)../ F-16A (., Lc - 1 to lì 10558547 MCNL 05/08/03 1 1 ,~~'=< ~ H-27A ~O ~ "-()<.C")g 10700004 MCNL 09/30/03 1 1 '~I~ C E-05A - -L-f Lf ... ()c--SFJ 10672314 RST-SIGMA 09/16/03 1 1 ~ ':;: . r E-04A . Y D - \ '6 \ 10662949 RST -SIGMA 09/15/03 1 1 1(4, ':; -r- \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotechnical Data Center LR2-1 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd. :j:?}::('~ --'" Anchorage, AK 99503-5711 Anchorage, Alaska 99508 >1" . .' ATTN: Beth Date Delivered: DE C 2 2~ Received b~\'.~~,-. ~.:.:......\') ~ c~ ~~(\ 'V"\ - I . . ' AJ8SK2i ...;;..:.. ., . r\J~G. ~;':., ~ ' ~~\~~ ,'s)C/~I~~E[, JH~ 2 @ 200Ll. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Julie Heusser, Commissioner THRU- Tom Maunder, P. I. Supervisor FROM' Chuck Scheve; SUBJECT: Petroleum Inspector DATE: April 24, 2001 Safety Valve Tests Prudhoe Bay Unit G Pad Tuesday, Ar)rii 24, 2001' I traveled to BPXs G Pad and witnessed the one-month retest of the safety valve systems. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 16 wells and 32 components with no failures. The surface safety valve on well G-03A closed rather slowly but passed its pressure test. The wing valve on wells G,16 and G-18A had very slow leaks but did not prohibit a valid test of the surface safety valve:: Well G.21 which:.failed the previous months test.due Io.-a frozen pilot, has the new style insulation box in place and functioned properly. Merv Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the Well houses on this pad was performed during the SVS testing.with no problems noted. Well G-t4A which was shut in at this time and not tested: was found to have the new style insulation box on the pilot. This should fix the problemSfound on previous tests. Summary: I witnessed the one-month retest of the safety valve systems at BPXs G-Pad. :PBU G Pad, 16 wells, 32 components, 0 failures 22 wellhouse inspections Attachment: SVS PBU G Pad 4-24-01 CS X Unclassified Confidential Confidential (Unclassified if doc. removed ) SVS PBU G Pad 4-24-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / G Pad Separator psi: LPS 174 Date: 4/24/01 HPS 720 Well Permit Separ Set L/P Test Test Test Date oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed OASor CYCLE G-01A 1931710 720 550 530 P P P OIL! G-02A 1950230 G-03A 1970700 174 125 100 P P P OIL G-04A 1951630 G-05 1780970 720 550 525 P P P OIL G-06 1790120 G-07 1790180 174 125 110 P P P OIL G-08 1810480 G-09A 1982630 G-10A 1950390! G-11A 1931600 720: 550 540 P P P OIL G-12A 1961050 G-13 1810720 174 125 125: P P P OIL G-14A 1980530 G-15A 1981340 720 550 500 P P P OIL G-16 1811220 720 550 500 P P P OIL G-17 1810940 ~-lSA 1990320 720 550 550 P P P OIL G-19A 1991030 720 550' 530 P P P OIL ~-21 1951540 '720 550 500 P P P OIL G-23A 1960200 720 550 510 P P P OIL G-24 1861830 G-25 1861620 720 550 510 P P P OiL: G-26A 1981510 720 550 500 P P P OIL G-27 1861560 720 550 525 P P P OIL G-29 18616001 G-30A 1950760 G-31A 1980540 720 550 525 P P P OIL G-32A 1970010 90 Day RJF 1/16/01 Page 1 of 2 SVS PBU G Pad 4-24-01 CS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed CAS or CYCLE Wells: 16 Components: 32 Failures: 0 Failure Rate: 0.00% W19o r>av Remarks: Good Test. Surface Safety Valve on Well G-03A closed slowly but passed its pressur test. The wing valve on wells G-16 and G-18A had very slow internal leaks and will repaired by the Operator. RJF 1/16/01 Page 2 of 2 SVS PBU G Pad 4-24-01 CS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~,? DATE: Commissioner ~~~.~ Tom Maunder, P. !. Supervisor o'~ THRU: March 26, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX/G Pad March 26, 2.0Q1; I traveled to BPX's Prudhoe Bay Field, G Pad, to witness Surface Safety Valve System tests and perform well house inspections. Merv Liddelow was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. Fifteen wells were tested with nine failures witnessed. The pilots on wells G-02A, G-1 lA, G-14A and G- 21A failed to operate properly. The SSV's on wells G-01A, G-02A, G-03A, G-09 and G-13 failed to close or failed to hold D/P. Wells G-03 and G-09 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been repaired and passed a retest within 24 hours. Fifteen well houses were inspected and slight crude oil leaks were noted on wells G-14 and G-16. Mr. Liddelow and his crew repaired these leaks immediately. The AOGCC test reports are attached for reference. SUMMARY: I witnessed SVS tests on 15 oil producing wells on BPX's G Pad in the Prudhoe Bay Field. 15 wells, 30 components tested. 9 failures: 30% failure rate. 15 well house inspections Attachments: SVS PBU G Pad 3-26-01 JJ ,cc;: .NON: ,C, O.N FIDENTIA,L SVS PBU G Pad 3-26-0 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unk/Pad: PBF/PBU/G-Pad Separator psi: LPS 152 Date: 3/26/01 HPS 649 ..... ' "" ' ' ' Well. 'Type !: II I I I II I I I Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code ,Code Passed GAS or CYCLE G201A 1931710 649 550 565 P 5 OIL ~, ~ , , , ,, G-02A 1950230 ,152 125 145! 1 5 OIL '/~i970700 152 125 , 115: P 5 '' . ' OIL i3 64A 1951630 G-05 1780970 649 550 '555: p p '' OI~' ~ , , G-06 1790120 , , , G-07 1790180 152 125 115 p p OIL , , G-08 1810480 G-09A" ' 1982630 649 550 560 P 4 OIL G-10A 1950390! G-11A 1931'6001~ 649! 550 '180 3 p OIL ,,, ,,, , G-12A 1961050 , G-13 1810720 152 125 120 P 4 OIL G-14A 1980530' 649 550 0 2 p OIL G-15A 1981340 649 5~0 530 p p " OIL . , ~ , G-16 1811220 649 550 540 P P , , :G-17 1810940 G-18A' 1990320 649 ' 550i 555 p P OIL , , ,, IG-19A 1991030 G-21 "1~5i540 649 '550: 0 2 P ' 0IL i , G-23A 1960200 ,, G-24 1861830 ,, , G-25 1861620 G-26A 1981510 G_2'7' 1~61560 .... ,, i ,i, , , , G-29 1861600 , , G-30A 1950760 G-31A 1980540 "'649 ~50 560 P P '' OIL , , , G-32A 1970010 152 125 140 P P OIL ,. , i '' ' ' ,, , , , ,, , Wells: 15 Components: 30 Failures: 9 Failure Rate: 30.00o/I~] 9o Remarks: G-3. G-9 are shut in for rePair. Operator report.s, all other failures repaired & pas,sed r{ RJF 1/16/01 Page 1 of 2 SVS PBU G Pad 3-26-01 JJ1 III .... I Well Permit I Separ Set IJP Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE RJF 1/16/01 Page 2 of 2 SVS PBU G Pad 3-26-01 JJ1 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 97-070 NGP-MD 97-070 NGP-TVD 97-070 8015 97-070 EOW SRVY 97-070 STAT/TEM/PRES 97-070 STAT TEM PRES 97-070 PRES SRV~Z 97-070 MEM PDC/GR/CCL ~62-11288 ~8459-8958 u~EF~PERRY GR/ROP ~ILLEX 8600-11265 ,-~256-8825 ~,/~82s-92s6 ~,,*~00-9193 ~/85~0-11271 FINAL 06/20/97 FIND~L 06/20/97 1-9 07/02/97 07/21/97 FINAL 10/20/97 FINAL 12/05/97 FINAL 04/21/98 FINAL 05/19/99 10-407 ~0MPLETION DATE @ ~/jj/~?/ DAILY WELL OPS Are dry ditch samples required? yes ~_And received? Was the well cored? yes Q~_.~alysis & description received? Are well tests required~l~es ~Received? ,~.~n~ Well is in compliance Initial COMMENTS BOX 4/21/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 111O15 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape A-04 .lat. '~'~ '-~"~ ~ 98187 RST 980406 I I 1 F-11 98065 CNL 970808 I 1 1 K-05A 97522 PDK-100 971 021 1 C-16 TEMPERATURE LOG 980405 1 1 D-25 PRODUCTION PROFILE 980322 1 1 G-03A FLOWING PRESSURE SURVEY 980401 I 1 H29A CALIPER LOG 980331 I 1 M-03 LLt ~ . INJECTION PROFILE 98041 2 I 1 P-03A L~I ~ CEMENT MAP LOG 980318 I 1 R-32A L,t I ~ CEMENTMAP LOG 980317 I 1 S-21 PRODUCTION PROFILE 980329 I 1 S-21 DEFT 980329 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~':'~) ¢ STATE OF ALASKA ALASKA C '~ND GAS CONSERVATION CC' "/IlSSlON WELL COMPLETION (JR RECOMP LETION h,=PORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator BP Exploration 7. Permit Number 97-70 8. APl Number 50- 029-20221-01 ~~/9. Unit or Lease Name Prudhoe Bav Unit ~/,o. Well Number G-O3A ~¢'1. Field and Pool 3. Address P. O. Box 196612, Anchoracle, Alaska 99519-6612 4. Location of well at su rface 2263' SNL, 1974' WEL, Sec. 12, T11N, R13E At Top Producing Interval 1988' NSL, 2393' WEL, Sec. 12, T11N, R13E At Total Depth 3208 SNL, 4351' WEL, Sec 12, T11N, R13E 5. Elevation in feet (ind 61.50 2. Date Spudded 5/8/97 7. Total Depth (MD+TVD) 1,288, 8958' TVD 22. Type Electdc or Othe GR icate KB, DF, etc.) 6. Lease Designation and Serial No. 028280 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15/20/97 ~_5/23/97 18. Plug Back Depth (MD+T VD)Il9. Directional Survey 120. 11,288, 8958' TVD lYES [] NO [] I Prudhoe Bay Field/Prudhoe Bay Pool 15. Water Depth,n/aif offShfeet MSL°re 16.oneNO. of Completions Depth where SSSV set 121. Thickness of Permafro st 2158 feet MD aPProx 1900' r Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECOR[ AMOUNT PULLED 2- 7/8" 6. 16# L-80 8814 11,288 3-3/4 31 bbls 24. Perforations open to Production (MD+TVD of Top interval, size and number ) 10600-10770', 8940-8943' 1-11/16" 4 spf 10830-10940', 8946-8944' 1-11/16" 4 spf 11060-11120', 8945- 8950' 1-11/16" 4 spf 11150-11210', 8952-8955' 1-11/16" 4 spf and Bottom and t25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SO.)EEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flow lng, gas lift, etc.) I 5/25/97 Date of Test Hours Tested TEsTPRODUCTIONpERIOD FORi~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lith elegy, porosity, fracture s, apparent dips, and pre sence of oil, gas or wate r. Submit core chips. ORIGINAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. ' GEOLOGIC MARKER~ '---' RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each pha se. TSAD 8708 8490 TZ2 8952 8699 TZ3 8895 8647 I 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and co rrect to the best of my k nowledge Signed .,, ~ Title ~..nil -F~hin_q I')rillin.q 'FA Date "1 - ~ ' ' General: This form is des igned for submitting a co all types of lands and le ases in Alaska. Item 1' Classification of Service Wells: Gas injec water disposal, water sup ply for injection, observ Item 5: Indicate which el evation is used as refere given in other spaces on this form and in any atta Item 16 and 24 · If this completion), so state in in item 27. Submit a sep data pertinent to such in well is completed for sep item 16, and in item 24 s arate form for each addit terval. Item 21: Indicate whether from ground level (GL) o Item 23: Attached supplem ental records for this we lng and the location of t he cementing tool. Item 27: Method of Operat ion: Flowing, Gas Lift, R jection, Gas Injection, S hut-in, Other-explain. Item 28: If no cores take n, indicate "none". INSTRUCTIONS mplete and correct well c tion, water injection, st ation, injection for in-s nce (where not otherwise chments. arate production from mor how the producing interva ional interval to be sepa r other elevation (DF, KB II should show the detail od Pump, Hydraulic Pump, ompletion report and log on eam injection, air inject ion, salt itu combustion. shown) fordepth measurem ents e than one interval (mult iple Is for only the interval reported rately produced, showing the , etc.). s of any multiple stage c ement- Submersible, Water In- Form 10-407 Well G-03A Accept 5/7/97 Field Prudhoe Bay Spud 5/8/97 APl 50-029-20221-01 Release 5/22/97 Permit 97-70 CTD Unit Nordic #1 Date Day Depth $/7/97 MI CTD Unit. Rig Accepted at 2400 hrs 5/7/97. NU BOPs. Need 3' extra lubricator to reach rig floor. BOP test. Test wavered by John Spaulding (AOGCC). PO Testing BOPs 5/8/97 2 8883 Pressure Test BOPE, Fax BOPE test report to AOGCC. M/U DS CTC and pull test. RIH with nozzle to switch well to Flopro. Recover seawater. Stop at 8640 ft, circulate and repaired broken drive pin on reel. POOH while chasing FLOPRO to surface. Held Pre-Spud meeting / Safety meeting with crews at crew change. Prepare Sperry Sun MWD tools. TIH and conducted shallow surface test on MWD tools. (OK). TIH and tagged bottom at 8702' Orientated and started drilling. Pumped 150k sweep to clean up milling debris. Drilled to 8744.8 and logged and corrected back to 8707' (-37') Depth Correct. Drilling, survey, drilling. 5/9/97 3 9100 Drilled build section from 8883 - 8903 ft BKB. Drilled into top of Zone 3 and wore out bit #1. POOH. Lay out worn bit and RIH with 1.7 deg bend motor and Bit #2 [tri-cone]. Test Sperry Sun MWD and cont. RIH. Drilled from 8903 to 9030', POOH for Bit and 1.0© Bent Housing & MWD ( 246©) (Zone II). TIH Tie-in (-36' Correction). Tagged bottom at 9030', Drilling surveys and Drilling 5/10/97 4 9339 Orienting TF to HS. Short trip at 9230' to 9080', Drilling Survey, Drilling. Short trip from 9339' to 9030' String became stuck at the mill depth of 9030' Spotted 12 bbl of crude, and worked CT up to 80K, Pumped 2nd stage 18 bbl and worked CT. Still stuck. Spotted 3rd pill and worked between 0 LB and 75K. Thing is stuck. The bit is stuck. Able to orient tool face?.;. Held safety and Operation meeting with crews. Pumped 20 bbls crude, dropped 15/16" ball and disconnected at 5500 psi. Came free Circulated Hole clean, Spotted HV pill. POOH and chased pill out of hole. OOH, cut 100' CT off and PU Fishing tools Top of Fish (Lower HDC) at 8973' Bottom of fish at 9030' 5/11/97 5 TOF 8973 TIH w/Fishing Tools. Tagged top of fish at 8973. (-52' correction) The Up/Down Jars quite working after 4 hits, POOH and installed accelerator and PU new Daily Jars. TIH and tagged the fish and latched. Made 29 cycles from 10k to 75k and 80k. Unable to jar loose. Conversation with Town Engineer. POOH and stood back 7 DC and PU new Accelerator and Jar, CTC, HDC. TIH. Tagged TOF at 8973. Jarring on fish. 31 hits, cool jars down, 29 hits, cool down, With CT at 9009.2 CTM, started jarring. After 60 hits at 80,000#, depth is 9003.8. After 90 hits at 82,000# D= 9001.5' Moved at total 7.7' minus stretch.. 5/12/97 6 TOF8973 Jarring on fish. Jar until Cycle Life neared 8-%. Unlatch from fish, POOH. PU Bowen Center Spear on 3 1/8" DC and 2 7/8" drill pipe. Filled pipe at 4700' 5/13/97 7 TOF8973 TIH with 2 7/8" DP. Latched fish at 9022' DD. Eline depth of 8973' Jarred fish loose PUH 30'. The swivel backed off on the lift sub and the swivel and joint of 2 7/8" drill pipe fell over the wind walls. Half of the joint was inside the structure and the other half was outside against the wind walls. Crane removed the joint of DP and swivel. Charlie Parker and Doug Yessak Nordic Driller were sent for first aid and returned to work. POOH laying down DP. SD at 6000', pulling wet, LD drill pipe 5/14/97 8 9367 POOH laying down DP. LD fish. Recovered all of fish. Clean up floor and pipe shed. Slip and cut drilling line. PU new BHA. TIH Tie-in and WR to 9088' PUH to window. WR to 9342' (38R)and backed reamed to window. WR 90 L to bottom. Hole is clean. Drilling at 0330 hours 5/14, 1997 3with TF at 80L Drilled to 9367' and lost MWD signal, POOH to change out Survey package 5/15/97 9 9780 Make up tools. TIH to 1400', check Sperry tools-OK. TIH, drill Drilled from 9367' to 9673', Bit trip, Changed out Bit and motor. TIH and tied in (-36foot correction. Tagged bottom, corrected TD to 9684 +7.0'). Drilled to 9780' shod trip to window. 5/16/97 10 10106 Finished TIH, Tagged TD at 9784' Corrected 7') Drilling, ST 200' at 9858', Drilling, ST at 9875' Drilling. Bit trip at 9915', RIH and Drilling, survey drilling.. Shod trip at 10076' to window for tie- in. (+29' corrected) RIH 5/17/97 11 10106 RIH and tagged at 9714', this is a constant problem area. Work thru and work to bottom. Trouble getting weight to bottom. Shod trip to window, ream thru each tight spot. Unable to stall motor. POOH, found jet gone from Sperry Equalizer sub. Change Sperry Equalizer sub and probe. Change out motor. Bit packed w/gummy clay. Clean bit, re-run same. TIH. Drilled to 10205. And short trip to 9400' See tight spot s listed below. Drilling. Drilled to 10358' and shod tripped (tight 9723') to window. Tie-in, made (+10' correction). TIH Tagged at 9714', Worked through. RIH. Drilling. At 10380 ROP picked up to 123 FPH, Good SS O'VD at 8944') 5/18/97 12 10525 PO at 0600 hr: Present TD at 10525' Made 419 ft in last 24 hrs. Shod trip to window. Working tight pipe at 10,250. Orientated 360 deg. Spotted 2-10 bbl crude. And still stuck. Dropped ball at disconnected with 6200psi. POOH and PU fishing tools. RIH and tagged at 9705'. Worked through after several attempts. Had trouble from 9700' to 9861' Tagged the fish at 10238'. Latch fish, made 10 hits down. Some travel. Got 5 feet of travel at first. Made 40 jar hits at 80,000#, Fish came free. POOH Recovered all fish, RU BHA #14, TIH. 5/19/97 13 10960 TIH with drilling BHA. Tie-in at window (-34' Correction) WR from 9670' to 9930, Stickey. WR several times, Still a little tight, but able to go in and out of the hole/. WR (170L TF) to to bottom with 170L TF. Tagged at 10360' WR to bottom. WR 94 Deg with LS TF. Drilled to 10597' and short tripped 200' Tight at 10360' and 10370' Drill to 10700' and ST to window Tight spots 9940' 9660' RIH and tagged at 9690', 9720',9880, and 9920' WR through. Drilling at ROP of 126 FPM. At 10775 started to have problem getting WOB had to work several time to get WOB. POOH to window, and swapped mud over to clean FIo-Pro. RIH WR to bottom with new FIo-Pro WR to bottom, hole is clean. 3000# less drag going in the hole. Orientated at TD to 90L to maintain TVD no deeper than 8947' Drilled to 10900' and shod tripped 200' to 10700'. Drilling At 10925, angle jumped to 94, could be bouncing off shale section at 8947'Drilled to 10960. ST to window. 5/20/97 14 11,288 Drill from 10,960' to 11265'. Shod trips to clean hole. Wash back in hole. Small tight spots at 9700' and 11084' Tagged bottom at 11288' See final Survey Projection and closure listed below. POOH Tight spot at 9680' POOH and RU to Liner. Run liner. Ran 103 its 2 7/8" tubing with TIW float equipment 5/21/97 15 PU 1%" CS Hydril tubing. RU and latch hanger. Entry guide (5.75" OD) would not go through the cross over above the Hydril. Worked some gyrations to disconnect and installed tree cap with the right ID. TIH with liner. Tagged TD at 11303' CTM (uncorrected). Dropped ball and disconnected from liner PU, free, Circulated 60 bbl FIo-Pro. PT DS lines to 4000 psi. Pumped 31 bbl 15.6 Class"G" Cement, SD, dropped dart and displaced cement to bottom and sheared dad with 62.7 bbl of FIo-Pro. Circulating pressure were high (4000 psi) with this long assembly. Sheared dart at 2700 psi. Unstung from pack-off bushing, POOH pumping at min rate. Pumped 30 bbl HV pill and cleaned out the top of the liner and chased it to surface. Circ, WOC. RIH jetting liner to seal bushing at 11277' CTD. Lay clean FIo Pro in liner. Displace FIo Pro with SW while POOH. LD CTLRT. Stand back workstring. 5/22/97 16 Stand back workstring. Held Safety and Operation meeting. PU 28 SWS 1 11/16" 20J 4 spf random 2~. PU 39 stand 1%" CS Hydril and TIH with CT. Safety Awareness meeting was conducted by WOA Asset Manager. The meeting was attended by DS, Nordic and BPX personnel. TIH Tagged Seal Bushing at 11254'. PU 43.12' to 11211.9' Dropped 5/8" ball and displaced with 57 bbls of SF. Guns fired, No initial fluid loss. POOH and keep hole full. Stand back workstring. LD perf guns-all shots fired. FP wellbore with MeOH to 500'. Secure well. ND BOPE. Perforation Summary: 10600'-10770,10830'-10940',11060'-11120' and 11150'-11210' 5/23/97 17 Finish ND BOPE.. Move off well. Rig Released at 0900 hrs 5/22/97. Move rig to D-14A G-3A ¢>age No. 1 G-3aeow.xls END OF WELL SURVEYS 5/27/97 5:52 PM BP EXPLORATION ALASKA INC. END OF WELL SURVEY REPORT FOR THE G-3A SIDETRACK MAY 27. 1997 NOTE I GRID N/S AND ENV OFFSETS ALSO GRID ASP X AND Y ARE RELATIVE TO GRID NORTH ~'~: ~ - --; : - ~ I GRID N/S AND E/W OFFSETS ARE REQUIRED FOR GEOLOGICAL WORK : -. I TRUE N/S AND E/VV OFFSETS ARE RELATIVE TO TRUE NORTH . i I . ALL AZIMUTH VALUES ARE RELATIVE TO TRUE NORTH OFFSETS ARE CALCULATED TO GRID AND TRUE NORTH AS INDICATED OmB CONVERGENCE !: 1-21° I I I i r" ',,,-,... COMME"TS MD ,no.] Dlrl SS DEPTH VS TRUE roUE Build Turn Dogleg GRID GRID ASP Y ASP X ft deg'~ degIJ ft ft NFS E/-W degll00 degll00 degll00 N/-S E/-W It tt TIEIN 8600.0 20,4 237,31 8399,1 0,0 -1012.5 -393,8 0.0 0,0 0.0 -1020.6 -372.3 5968385.0 657874.0 KOP 8664,0 20.4 237.3 8459.1 18,0 -1024.5 -412.6 0.0 0.0 0.0 -1033.0 -3908 5968352.5 657855.5 8688.0 24.2 241.2 8481.3 25.5 -1029.2 -420.4 15.8 16.2 17.0 -1037.8 -398.6 5968347.5 657847.8 8708.0 25.5 245.2 8499.4 32.8 -1033.0 -427.91 6.5 20.0 10.6 -1041.8 -406.0 5968343.5 657840.3 8741.0 28.2 252.21 8528.9 46.31 -1038.3 -441.8! 8.2 21.2 12.6 -1047.4 -419.7 5968338.0 657826.6 8773.0 30.9} 258.6 8556.7 61.3 -1042.3 -457.0 8.4 20.0' 13.0 -1051.7 -434.9 5968333.5 657811.4 8802.0 34.0t 259_1/ 8581.2 76.4 -1045_3 -472.3i 10.7j 1.7 10.7 -1055.0 -450.1 5968330.0 657796.2 8835.0 8607.9 95.3 -1048.1 -491.4 11.5 14.8 14.4 -1058.2 -469.2 5968327.0 657777.1 -508.5 11.9 -486.3 5968326.0 37.8] 264.0l i 8862.0 41.0i 270.5J 8628.8 112.3-1048.9 i i 24.1 19.3 -1059.4 657760.1 8895.0 44.2 276.0t 8653.1 134.6 -1047.6 -530.8 9.71 16.7 14.9 -1058.5 -508.6 5968327.0 657737.8. 8922.0 45.4 284.1 8672.3 153.5 -1044.2 -549.5] 4.4 30.0 21.6 -1055.6 -527.3 5968330.0 657719.0, 48.4 296.0 10.0 39.7 657698.4~ I 8952.0 8692.8 174.4 -1036.7 -570.01 30.6 -1048.5 -548.0 5968337.0 8980.0 49.21 305.2 8711.3 193.1 -1026.0 -588.1 2.91 32.9 24.9 -1038.2 -566.3 5968347.5 657680.1 J I 657662.4 5968362.0 -584.0 -1023.9 24.8 9010.0 49.6 315.0 8730.8 211.3 -1011.3 -605.5 1.3 32.7 i 9041.01 51.9 324.0 8750.5 228.0 -993.1 -621.0 7.4 29.0 23.7 -1006.0 -599.9 5968380.0 657646.4 55.4 I 9075.0 327.6 8770.6 244.7 -970.5 -636.4 10.3 lO.61 13.4 -983.7 -615.7 5968402.5 657630.6! 57.6 330.5' 8786.1 257.9 -950.4 -648.4 7.9 10.4i 11.7 -963.9 -628.1 5968422.5 657618.2 I 9103.0 9144.0 63.3t 329.8 8806.3 277.5 -919.5 -666.11 13.9 -1.7i 14.0 -933.3 -646.5 5968453.0 657599.8 9175.0 67.81 328.4 8819.1 293.5 -695.3 -680.61 14.5 -4.5 15.1 -909.4 -661.5 5968477.0 657584.8 I 9205.0 72.4 329.1 8829.3 309.5~ -871.2 -695.3 15.3 2.3 15.5 -885.6 -676.7 5968501.0 657569.7 9237.0 330.1] 8838.0 . -844.6 -710.81 11.6 3.1 11.9 -859.4 -6928 5968527.0 657553.6 i 9263.0 329.4J 8843.6 . -822.7. -723.61 10.4 -2.7 10.7 -837.8 -706.0 5968548.5 657540.3 i 9291.0 327.3] 8848.9t 356.7{ -799.3 -738.0J 2.9' -7.5 7.9 -814.7 -720.9 5968571.5 657525.4 . ' -758.1 3.3 -9.2 9.6 -785.8 -741.6 5968600.5 657504.8 9327.0 324.01 8855.0i 378.41 -770.0 *55.0 79.91 320.4Ii 8859.7' 396.61 -748.2' -775.0[ -3.2 -12.9 13.1' -764.4 -758.9 5968622.0 657487.4 93860 78.2 317.0] 8865.6 418.1 -725.4 -795.11 -5.5 -11.0 12.1 5968644.5 657466.8 i 9411.0 77.4 316.41 8870.9 435.9 -707.6 -811.8t -3.2 -2.4 4.0 -724.5 -796.6 5968662.0 657449.7 , 9440.0 78.1 315.5! 8877.0, 456.81 -687.2, -631.5t 2.4. -3.1 3.9 -704.5 -816.7 5968682.0 657429.6 ] -0.9 -855.31 -7.1 -681.8 -841.0 5968704.5 657405.3 9474.0 77.8 313.1 ! 8884.1 482.0 -664.0 . 7.0: 77.6 -0.6 -7.4 7.3 -662.1 -864.0 5968724.5 657382.4 9505.0 310.81 8890.8 505.7 -643.7 -877.8 ] I , 4.5 9534.0 78.9 309.9~ 8896.7 528.4 -625.4t -899.5 -3.1 5.4' -644.1 -886.0 5968742.5 657360.4 9566.0 80.3 308.0 8902.4 554.1 -605.6t -924.0 4.4 -5.9 7.3 -624.9 -910.9 5968762.0 657335.5 9591.0 80.7 306.2 8906.6 574.6 -590.71 -943.6 1.6 -7.2 7.3 -610.4 -930.8 5968776.5 657315.5 9622.0 81.4 305.0 8911.4 600.6 -572.9 -968.5 2.3 -3.9 4.4 -593.1 -956.1 5968794.0 657290.3 I 9652.0 82.5 302.9 8915.6 626.2 -556.3 -993.2t 3.7 -7.0 7.8 -577.0 -981.1 5968810.0 657265.3 I 304.4i I 9679.0 83.0 8919.01 649.3 -541.4 -1015.5 1.9 5.6 5.8 -562.7 -1003.7 5968824.5 657242.6 9714.0 83.8, 302.71 8923.0i 679.41 -522.2 -t044.4 2.3i -4.9 53 -544.1 -1033.1 5968843.0, 657213.3 -12.5 8925.5 700.61 -509.9 -1064.81 2.5 12.71 -532.1 -1053.7 5968855.0 657192.6 9738.01 84.4t 299.7 737.81 -490.9 -1101.01 3.4J -10.2 10.8 -514.0 -1090.3 5968873.0 6571560 9779.0t 85.81 295,5i 8929.0 9811.0 90.01 293.0 8930.2 767.7 -477.81 -1130.21 13.1Ii -7.8 15.3 -501.5 -1119.7 5968885.5 657126.6 I 9840.01 90.51 289.9 8930.0 795.3 -467.2]' -1157.2 1.7] -10.7 10.8 -491.4 -1146.9 5968895.5 657099.4 t 9870.0i 89.7t 287.8 8930.01 824.3 -457.51 -1185.6 -2.71 -7.01 7.5 -482.3 -1175.5 5968904.5 657070.8 ORIGINAL , ~Page No.2 C--3~,~w.x~s G-3A 5/27/97 5:52 PM .,,, END OF WELL SURVEYS i I t I I GR,DI OR,D ^S.~ COMMENTS MDI Inc.i Dtri SSDEPTH' VSI TRUE TRUEI BuildI Turn Dogleg degl100 deg/~ 00 EJ-W ftI dog dogI ft ftI N/-S F_]-W dog~00 N/..S ft ft 9~97.0! 88.8 286.0t 8930.3 85051 -449,71 -t211.41 -3.3 .6,7 7.5 -475.0 -1201.5 59689120 657044.8 9925.0t 87.4' 282.5t 893t.3 878.0!, -442.8 -1238.5 -5.0 -12.5 13.5 -468.7 -1228.8 5968918.5 657017.6 996'3.01 87.4 278.41 8933.0 915.7J -435.9 -1275.8 0.0 -10.8 10.8 -462.6 -1266.2 5968924.5 656980.1 I II -1309.6 9997.0j 88.3 275.1 8934.3 94961 -431.9 2.6 -9.7 10.1 -459.3 -1300.0 5968928.0 656946.3 10018.0 88.1 273.01 8934.9 970.6 ..-430.4 -1330.5 -1.0 -10.0 10.0 -458.3 -1321.0 5968929.0 656925.4 10056.0 89.2 268.81 8935.8 1008.5 -429.8 -1368.5 2.9 -11.1 11.4 -458.5 -1359.0 5968929.0 656887.4 1008.3.0{ 89.2 269.1I ~.21 1035.4 -430.3 -1395.5 0.0 1.11 1.1 -459.5 -1386.0 5968928.0 656860.4 10113.0! 89.9 265.2J 8936.4t lO85.2j -431.8 -1425.4 2.3 -13.0 13.2 -461.7 -1415.9 5968926.0 656830.4 10143.0~ 90.51 263.7 8936.3 1094.9/ -434.7 -1455.3 2.0 -5.0 5.4 -465.2 -1445.7 5968922.5 656800.6 10174.0l 90.11 261'2i 8936.2] 1125.3l -438.8 -1486.0! -1.3 -8.1 8.2 -469.9 -1476.3 5968918.0 656770.0 10200.0j 88.8 260.7 8936.4 1150.71 -442.9i -1511.7, .-5.0 -1.9 5.4 -474.5 -1501.9 5968913.5 656744.4 I 1°294.°il 88'8tl 265.8 8937.9 1242.8 -455.61 -1604.8 -2.6 8.7 9.1 -489.2 -1594.7 5968899.0 656651.6 10323.0 87.11 267.5 8938.9 1271.6 -457.31 -1633.7 -5.9 5.9 8.3; -491.5 -1623.6 5968896.5 656622.8 10349.0 85.8 269.3 8940.5 1297.4 -458.01 -1659 6 -5.0 6.9 8.5 -492.7 -1649.5 5968895.0 656596.8 10376.0 85.2 268.9l 8942.6 1324.3 -458.41 -1686.61 -2.21 -1.5 2.7 -493.7 -1676.4 5968894.0 656569.9 10405.0 85.8 266.0 8944.9 1353.0 -459.7/ -1715.41 2.11 -t0.0 10.2 -495.6 -1705.2 5968892.0 656541.1 I i I I 10441.0t 89.61 264.2 8946.3 1388.6 -462.8 -1751.3 10.61 -5.0 11.7 -499.4 -1741.0 5968888.0 656505.3 10469.0 91.91 263.1 8946.0 1416.2 -465.9 -1779.1 8.2 .<3.9 9.1 -503.1 -1768.7 5968884.5 656477.6 10504.0 94.1 260.2i 8944.1 1450.4 -470.91 -1813.7 6.3 -8.3 10.4 -508.9 -1803.2 5968878.5 656443.1 10531.0'91193.8 257.2/ 8942.3 1476 4 -476.2i -1840.1, -1.1 -11.1 11.1' -514.7 -1829.5 5968872.5 656416.8 10560.0 255 41 8941.0 1504.11 -483.11 -1868.2t -9.3 -6.2 11.2 -522.2 -1857.5 5968865.0 656388.8 t t I -492'0 -1901'0' 10094.0 88,9 254.0 8941,0 1536.3 -6.5 -4,1 7.7 -531.8 -1890.1 5968855.5 656356.2 10620.0] 88.8 250.7i 8941.6 1560,5' -499.9 -1925.8 -0,4! -12.7 12,7: -540.2 -1914.7 5968847.0 656331.6 10650.01 89.2 247.71 8942.1[ 1587,8 -510.6 -1953,8 1.31 -10.0 10.1~ -551.5 -1942.5 5968836.0 656303.8 10669,0 89.9 243.5 8942,2! 1604,6 -518.4 -1971,1, 3.7i -22.1 22.4 -559.7 -1959.6 5968828.0 656286.6 90,2; 238,9 10711.0 8942.21 1640,1 -538,6 -2007.9 0,7 -11.0 11.0 -580.7 -1996.0 5968807.0 656250.3 t I 10749.088~28188;9I 234.1 8942.5, 1670.4 -559.6 -2039.6, -3.4 -12.6 13.1 -602.3 -2027.2 5968785.5 656219.0 10777.0 231.5 8943.31 1691.61 -576.5 -2061.9/ -3.9 -9.3 10.1 -619.7 -2049.2 5968768.0 656197.1 10802.0 228.2 1709.7j -592.6 -2081.0j .6.4 -13.2 14.7 -636.2 -2067.9 5968751.5 656178.3 8-944.61 10885.0 89.2 222.0 8947.8! 1751.51 .637.0 -2125.6 8.61 -10.3 13.5 -681.4 -2111.6 5968706.0 656134.6 10922.0 94.7 215.31 8945.8 1784.4 -681.3 -__v._,. 9.31 -13.0 15.9 -7265 -21463 5968661.0 656099.9 10951.0' 92.7 212.91 8943.9 1799.1 -700.3 -2177.51 -6.9 -8.3 10.8 -750.8 -2162.0 5968636.5 656084.2 10979.0 90.5 210.6 8943.11 1812.4 -729.1 -2192.2 -7.9 -8.2 11.4 -774.9 -2176.2 5968612.5 656069.9 11010.0 88.8 213.4 8943.31 1827.11 -755.3 -2208.6 -5.51 9.0 10.6 -801.5 -2192.1 59685860 656054.1 11044.0 87.2 216.6j 8944.5 -783.2 -4.7 9.4 lO.51 -829.8 -2211.0 5968558.0 656035.2 11074.0 84.9 215 91 8946.6 1861.1[ -807.3 -7.7 -2.3 8.0 -854.2 -2228.2 5968533.5 656018.0 t 1t105.0 85.1 21811J 8949.3. 1878.1I, -832.0 -2264 4! 0.6j 7.1 7.1 -879.3 -2246.3 5968508.5 655999.9 222.5J 8951.2 1894.21 -852.5 -2281.8! 5.91 16.3 17.3 -900.2 -2263.2' 5968487.5 655982.9 11163.0 86.4 222.5t 8953.0 1913.7t -875.3 -2302.71 0.0 1.0 -923.4' -2283.7 5968464.5 655962.5 ' 11199 0i 86.5 226.1, 8955.31 -901.0 0.3 10.0 10.0 -949.7 -2308.2 5968438.5 655937.9 11232.0 88.0 228.21 8956.9 19,..59.91 -923.4 -2351.91 4.51 6.4 7.8 -972.6! -2331.91 5968415.5 655914.3 TI:) 11255.0 89.5 230.3t 8957.6 1983.6/ -945.0 -2376.9i 4.5 6.4 7.8 -994.6 -235641 5968393.5 655889.7 THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. DISTRICT MANAGER - DRILEX SYSTEMS, INC. I Page No. 1 G-3aeow.xis G-3A END OF WELL SURVEYS 5127197 5:52 PM BP EXPLORATION ALASKA INC VERTICAL SECTION USED RKB NOTE : GRID CONVERGENCE i MAGNETIC DEC. TO TRUE NORTH PREPARED BY: DATES: DIRECTIONAL CO. END OF WELL SURVEY REPORT FOR THE G-3A SIDETRACK MAY 27. 1997 273.51': RELATIVE TO TRUE NORTH -61.5' i i GRID NtS AND E/W OFFSETS ALSO GRID ASP X AND Y ARE RELATIVE TO GRID NORTH GRID N/S AND E/VV OFFSETS ARE REQUIRED FOR GEOLOGICAL WORK TRUE N/S AND EAN OFFSETS ARE RELATIVE TO TRUE NORTH i: ALL AZIMUTH VALUES ARE RELATIVE TO TRUE NORTH i: OFFSETS ARE CALCULATED TO GRID AND TRUE NORTH AS INDICATED i: 1.21':' t i: 28-48° DRILEX h 5/7 TO 5t19/97 DRILEX SYSTEMS, INC. SPERRY SUN MDi Inc. i Dlr! SS DEPTH: COMMENTS: ffi deg! degj TIE IN 8600.0', 20.4i KOP 237.31 8399.1' 8664.0! 20.4i 237.3i 8459.1 8688.0i 24.2i 241.2! 8481_3 25.51 245.2j 8499.41 8708.0 VSI TRUEI TRUE 0.0 -1012.5i 18.0 -1024.5! -393.8 -412.6 25.5! -1029.2i -4204 32.8! -1033.0i -427.9 Build i Turn i Dogleg, degll001 degll00! degll00 0_0i O0! 15.81 6.5; 0.0 0.0; 0.0 162 17.0 2O0 10.6 21.2 12.6 6RID 6RIDI ASP Yin----AS? _X NI-S__ E/-W fl:F! _ft -lO2O.61 -372.3 5968365.0[-~7874;0 -1033.01 -390~81 5968352.5i 6-5'7855.5 -1037.8! -398.6! 5968347 51 65784¢8 -1041.81 8741.0 28_2! 252.2 ~ 8528.91 46_31 -1038.3i -441.8 8.2! -1047.41 61.3 -1042.3i -457.0i 76.4 -1045.31 -472.3 8773.01 30.91 258.6! 8556.7~ 841 20.0i 13.0 10.7i 1.71 10.7 11.5i 14.8~ 14.4 11.9~: 24.1i 19.3 8802.0! 34.0i 259.1 ! 8581.2' 8835.0i 37.8i 264.01 8607.9 9.71 16.71 14.9 4.41 30.0i 21.6 95.31 -1048.11 -491.4 112_31 -1048.9i -508.5' 8862.0i 41.0i 270.51 8628.81 8895_0! 44.21 276.0i 8653.11 134_61 -1047.6i -530.8 8922.0! 45.41 284_11 8672.3! -54951, 8952.0 48.4! 296.01 8692.81 8980.0i 49.21 305.2i 8711.3i 9010.01 49.6i 315.0i 8730.8i 9041.0! 51.9i 324.0i 8750.51 9075.0! 55 41 327.6; 8770.61 -636.41 10.3i 10 6i 13.4 153.51 -1044.2i 174.4 -1036.7; 193.1 -1026.0i 211.31-lO11.3! 228.0 -993.1i 9103.0! 57.6i -570.0i 10.01 39.7i 30.6 -588.1I 2.9'~ 32.91 24.9 -605.5i 1.3i 32.7; 24.8 -621.0! 7.41 29.0~: 23.7 2447t -970.51 - ~ 257.9! -950.4i 277.51 -919.51 330.5 8786.1 63.3! -648.41 7.9! 10.4! 11.7 9144.0! 329.8 8806.31 -666.11 13.91 -1.71 14.0 9175.01 67.81 328.4 8819.1 293.51 -895.31 -680.6! 14.5i -4.5i 15.1 9205.0! 72.4! 329.1! 8829.31 -695.31 15.3i 2.31 15.5 9237.01 76.1i 330.1! 8838.0 9263.0i 78.8i 329.4i 8843_6 9291.0i 79.6 9327.0! 80.8 327.3i 8848.9 324.0! 8855.0 309.5i -871.2i 326.7'1 -844.6!, -710_8i 11.6i 3.1j 11.9 340.8i -822.7i -723.6i 10.4! -2.7; 10.7 9355.01 79.91 320.4i 8859_7i 356.71 -799.3i -7380, 2.91 -7.5i 7.9i 378.41 -770.0i -758.1i 3.31 -92i 9.61 -1051.71 -1055.01 -406.01 5968343.5! 6578403 -419.7 i -~9-6-8~-87~!' - 65~826.6 t -434 91 5968333.5i~-_67_~.8_-!_{_.~. -450.1 5968330.0i 657796.2 -1058.2 -1059.4 -469.2] 5968327.0I ~57~77.1 -486.31 5968326.01 657760. i -1058.5 -508.6 5968327.0!__~:~, -1055.61 -527.31 59683 ~0.0 j ~- ~-~72~1.~ -1048.51 -548.01 5968337.0J 6576~z~ -1038.: -566.3i 5968347.51 657680.1 -1023.9 -584.0 5968362.0 6576~ -1006.0 ~5999 5968380.0 -~5-~64~.~ I i - - -983.7 -615.7i 5968402.5! 6576306 5968422.~i- -657~18.~ -963 9 -628.1t -933.3 -646.51 5968453.0!-'~ -909.4i -661.5! 5968477.0i_ 6~7584.~ -885.61 -676.71 5968501.01_~757:? i ' -837.8! -706.0! 59685485 6575403 -814.71 -720.9 5968571 5 ~75~5.4 -785.8 -741.6i 5968600.5!-65750~ -764.41 -758.91 5968622.0 -741.9 -779.5 5968644.51 657466.8 -724.5 -796.6 5968662.0i-~-~.'~i 9386.01 78.21 317.01 8865. 9411.0i 77.4i 316.4i 8870.9i 9440.01 78.1i 315.51 8877.0i 9474.01 77.8i 313.11 8884_1 9505.01 77.61 310.8 9534.0 9566.01 9591.0 9622.0 9652.0 9679.0 8890.8i 396.6! -748_21 -775.01 -3.21 -12.91 13.1{ 4a8.11 -725.4i -795.11 -5.51 -11.0~ 12.11 435.9i -707.6i -811.8! -3.2i -2.41 4.0 456_81 -687.2i -831_5i 2.4i -3 1~ 3.9, 482.01 -664.0! -855.3! -0-9i -7.1! 7.0! 505.7! -643.71 -877.8 78.91 309.91 8896.71 528.41 -625.4i -899.5 80 3! 308.0i 80.71 306.2i 8902.4 89O6.6 554.1i -605.6i -924.0 574.6i -590_71 -943.6 61.4! 305.0[ 82.5i 302.91 8911.41 600.6i -572.9i -968.5 8915.6! 626.2 -556.3i -993.2 83.0i 304.4i 8919.0i 649.31 -541.4! -1015.5 9714.0! 83.81 302.7 ! 9738.0j 84.4i 299.7 8923.01 679.41 -522.2i -1044.4i 8925.51 700.61 -509.9! -1064.8' -0.6 -7.4! 7.3t 4.5! -3 1: 5.4i 4.41 -5 9i 7.31 1.61 -7.2i 7.31 2.3i -3.9! 4.4i 3.7! -7.0: 7.81 56. 5.8i 2 31 -4 9 5.3i 2.5[ -12.5¢ 12.7i -704.51 -816.71 59686820i 657429.6 -681.81 -841.01 5968704.5F--6¢¢4-051~ -662.1! -864.01 5968724~ 6~_.4 -644.1 -886.01 5968742.5i 65~60.4 -624.9 -910.91 5968762.0] 657~3515 -610.4 -930.81 5968776.51 657315.5 -593.1 -956.1i 5968794.0i 657290.3 -577.0i -981.11 59688~.0!_ ~5~'.-3 ! -562.7 J -1003.71 5968824.5i -544.1i -1033 1! 5968843.0i 6572~ -532.1l -1053.71 ' _1090.31 ~ .... 5968873 0~ 657156.0 9779.01 85.81 29551 8929.0] 737.8i -490.91 -1101.0! 3.4i -10 2' 10.81 -514.0! 9811.01 90.01 293.0 8930.2! 767.7i -477.81 -1130.2i 13.1i -7.8; 15.3i -501.51 -1119.71 5968885.5! 657126.6 9840.0! 90.5~ 289.9! 8930.0! 795.3 -467.2 -1157.2i 1 7: ~10.71 10 8! -491.41 -1146.91 596889551 657099 4 9870.01 89.7¢ 287.81 8930.01 824.3! -457.5 -1185.6i -2.71 -7.0; 7.51 -482.3! -1175.5i 5968904.51 6570708 Page No.2 G-3aeow.xls G-3A 5/27/975:52 PM END OF WELL SURVEYS COMMENTS! MDi Inc.I Diri SS DEPTHI VSi TRUEi TRUEi Buildl Turni DoglegI GRID I GRIDI ASP YI ASP X --- ~ ' , N/-S degl100i deg/100i ltl ft i fti degI degj ftj fti E/-W deg/100 N/.-S E/-WI ! gsgT.0Jl 88.8J 286.0j 8930.3{ 850.5j, -44g.7I' -1211_4j -3.3J -6.7i 7.5j -475.0j -1201.5 5968912.0j 657044.8 i 9925.0j 87_41 282.51 8931.3j 878.0! -442.8j -1238.5J -5.0! -12.5! 13.5{ -468.7J ~12288 596891851657017.6 i ~ , ' I ' ' ' 9963.0j 87.4j 278.4j 8933.01 9157i -435.9J -1275.8j 0.0! -10.8i 10.8J -462.6 -1266.2 5968924.5[ 656980.1 ~ 9997.0j 88.3i 275.1j 8934.3j 949.6¢ -431.9j -1309.61 2.6J -9.71 10.11 -459.3J -13000 5968928.016569463 i lOO18.oj 88.1j 273.0i 8934.9i 970.6i -430.41 -13305i -1.oj -lO. Oi 10.0J -458.31 -1321.0 5968929.0j -~-~6~'~5.~ ¢ lOO56.oi 89.2i 268.8J 8935.81 1008.51 -429.8i -1368_5J 2.9i -111~! 11.41 -458.5 -1359.0 5968929.01656887.4 i 10083.011 89.2!, 269_1J 8936_2j, 1035.4i, -430_3j -1395_5i 0.0! 1.111 1.1J -459.5 -1386.0 5968928.0;, 656860.4 , 13.21 -46~.7J -1415.9 , 65683o.4 .... -13.o! i 10113.0t 89.91 265.2j 8936.41 1065.2i -431.8J -1425.4j 2.3! 5968926.01 ¢ ~0143.0i 90.5j 263.71 8936.3j 10949! -434.7J -1455.3i 2.01 -5.0i 5.4 -465.2 -1445.7 5968922.5'~6568006 ; 10174.0! °.90.1 i 261.21 8936.21 1125.3i -438.8 j -1486.0! -1.3j -8.1i 8.2 -469.9 -1476.3 5968918.0 656770. C] ! 10200.0i 88.8! 260.7i 8936.4i 1150.7j -442.9j -1511.7i -5.01 -1.9i 5.4j -474.5J -1501.95968913.51656744.4 ; 10234.0 89.0! 260.5i 8937_1i 1183.8i -448.4 -1545.2j 0.6i -0.6! 0.8 -480.8J -1535.3, 5968907.0J 656711.0 i 10263.0 89.6i, 263 li 8937.4 j; 1212.2 i -452.6 -1573.9 j 2.1i' 9.0.,J 9.2 -485.5 -1563.9159475968902.5 6566812. ~, ~ -455.~ I ! i i , i 102g4.0j 88.8j 265_8j 8937.gi 1242.8j -1604.8] -2.61 8.7! 91' -48g.2 J - . 59688gg.01 656651.6 i 10323.0j 87.1i 267.5i 8938.9! 1271.6i -457.3 -1633.7J -5.9J 5.9J 8_3 -491.5J -16236 5968896.51656622.8 ,, 10349.0j 85.8l 269.3i 8940_5i ~297.4i -458.0 -1659.6l -5.0i 6.9i 85 -492.7j-1649.5 5968895.01 656596.8 i 10376.0j 85.2! 268.9j 8942.6i 1324.3j -458.4 -1686.6j -2.2i -1.5j 2.7 -493.7 -1676.4J 5968894.0 656569.9 , 104050j 85_81 266.0~I 8944.9 1353.0i -459.7J -1715.4] 2.1~, d0.0! lO.2J -495.6 -1705.2J 5968892.0 6~541.1 ; i i i i j I i i i 4994 -1741.0 i 10441.0] 89.6! 2642i 8946.31 1388.6l -462.8! -1751.3j 10.61 -5-01 11.7, - . 5968888.0! 656505.5' ; 10469.0! 91.9; 263.1] 8946.0j 1416.2i -465.9' -1779.1{ 82i -3.9! 9.1j -503.1! -1768.75968884.51656477.6 ; 10504.01 941i 260.21 8944.11 1450.4! -470.9 -1813.7j 6.31 -8.3!, 10.4j -508.91 -1803.25968878.~ ~-5-6~3~: 10531.0! 93.8i 257.21 8942.3i 1476.4i -476.2 484O. lj -1.1! -1~ 1:, 11.1 -514.7 -1829.5j 5968872.5j 656416.8' i 10560.0i 91.11 255.4i 8941.0i 1504.1j -483.1 -1868.2! -9.3j -6.21 11.2j -522.2 -1857.55968865.01656388.8 ; J ! i i i J j i ; I I 5968855.5 -- i 10594.0i 88.91 254.0j 8941.0i 1536.3i -492.0t -1901.0! -6.51 -4.11 7.71 -531.8 -1890.1i 656356.2 i 10620.0j 88.8i 250.7i 8941.6j 1560.5j -499.9 -1925.8j -0.4j -12.7j 12.7J -540.2J -1914.75968847.0 656331.6 ! 10650.0j 89.2i 247.7i 8942_11 1587.8Ji -510.6 -1953.8i 1~31 -10_0i 10.11 -551.5J -1942.5, 5968836. oj 656303.8 i 10669.0! 89.9i 243.5J 8942.2i 1604.6i -518.4 -1971.1j 3.7i -22.11 22.4i -559.7J -1959.65968828.0 656286.6 ! 10711.0!, 902i 238.9i, 8942.2{ 1640.1i -538.61 -2oo7.9l. 0.71 -11.01, 11.011 -58071. -1996.05968807.0, 656250.3__ i i i ! J { i j i i i 5968785.5 ! 10749.0i 88.91234.1[ 8942.511670.4i -559_61 -2039.6i -3.4i -12.6! 13.11 ~10~ -2027.21 656219.0 i 10777.0j 87.81 231.5j 8943.3i 1691.6! -576_5i -20619i -3.9i -931 10.1j [ ; -2049.2J 5968768.0! 656197.1 'i 10802-0i 86-2i 228_2 8944.6] 1709.7i -592_61 -2081.01 -6.4i -13.21 14.7i -636.21 -2o67.915968751.5f 656178.3 ! 108360! 86.7! 2250, 8946.7J 1732.9j -615.9j -2105.6J 1.5i -9.4! 9.5i -66o. oI -2092.15968727.5! 656154.~ i 10865.01 89.2i 222.0J 8947.81 1751.5i -637.0i -2125.61 8.6i -10.3', 13.5i -681.41 -2111.65968706.0j__6__5_6134._6_ i 10895.0! 92.2i 218.8i 8947.41 1769.51 -659.8i -2145.0i 10.01 -10.7', 146f -704.7 -2130.5! 5968683.01656115.7 i 10922.0i 94.7i 215.3i 8945.8! 1784.4i -681.31 -2161.2i 9.3i -13.0i 15.9[ -726.51 -2146.315968661.0i 65~99.9 i 10951.0i 92.7~ 212_9 8943.9j 1799.11 -705.3j -2177.5j -6.9j -8.3i 10.81 -750.8i -2162.0J 5968636.5165608~ i 10979.0i 90.51 210.6j 8943.1i 1812.4j -729.1J -2192.2j -7.9i -8.2i 11.4j -774.9 -2176.2J 5968612.51656069.9 ! 11010.0i 88.81 213.4i 8943.3j 1827.1j -755_3i -2208.6j -5.51 9.0; 106i -801.5 -2192.1J 5968586.0J ~0~' i ~ , I i -2211.0 ! 11044.0j 87.2! 216.6i 8944.5l 1844.9l -783.21 -2228.1 -4.7[ 9.41 10.5i -829.8 5968558.0 j 656035.2 i 11074.0! 84.91 215.91 8946.6i 1861.1i -807.3J -2245.8J -7.71 -2.3i 8.01 -854.2 -2228.25968533.5J 656018.(~ i 111050J 85.1] 218.1! 8949.3i 1878.1J ~32.oi -22644 0.6i 7.1! 7.1l -8793 -2246.35968508.5i 655999.9 - i , , I ' -900.2 -2281.8J 5.9j 16.3] -2263.215968487.5 655982.9 i 11132.0j 86.71 222.5i 8951.2J 1894.2! -8525 . 17.31 i 11163.0! 86.41 222_5t 8953.0j 1913.7J -875.3 -2302.7 -101 0.0;, 1.0'~ -923.4 -2283.75968464.5, 655962.5 i 11199.0'1 86.51 226.11 8955.3i 1937.2j -901.0j -2327.8j 0.3i 10.0!l 10.0i -949.7 -2308.2J 5968438.5j 655937.9 . -923.4j ~ -2331.9 5968415.51 655914.3 i 11232.0j 88.0i 228.2i 8956.9j 1959.9j ' -2351.9j 4.5i 6.41 7.8i -972.6 TD i! 11265.011 89.5ii 230.3ii 8957.6ii 1983.6Ji -945.0, -2376.9 Jj 4.5ji 6.41 7.8ii -994.6 J -2356.45968393.5i .... 655889:~ THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. i i " ! , BIMO HADIPUTRO ! ; i i j J i j ~' i DISTRICT MANAGER- DRILEX SYSTEMS, INC. ! I J J. ,I : i ,I . ,I 8300 BP EXPLORATION ALASKA G-3A END OF WELL PLOT NORDIC I PRUDHOE BA¥ ALASKA I I NORTH REF. TO GP-JD True (.1.2I) ~//~ag (+27.27) I I I I N/S Scale 1 Inch · 400 ft BP EXPL ORA TirON (ALASKA) iNC. iiiiiiIIII1~1111. ,,i' · II I1'11 IIII I'11 I I I I I II I I I I I I'11 I I I IIII \, ' G-3A PLAN - -800 - -1200 ~ 8gO0 ,~ - - - 9100 ~ G-3A PLAN G-3 ~ G-3A ACTUAL Vertical Section Scale 1 inch · 200 ft PLANE OF VERT SECTn 272.33© RELATIVE TO GRID NORTH I I I I I I I I FILE NAME · CABP~G-3A~G-3AEOW. DW2 DRAWN BY 'B/MO HADIPUTRO DATE · MAY 27. 1997 I I I I GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11598 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) '11/26/97 '1 ~-- o-Do Well Job # Log Description Date BL RF Sepia LIS Tape C-01 · PRODUCTION PROFILE 971 010 I 1 E- 14. WHIPSTOCK SE'I'rING RECORD 971 007 I I _ G-03A . STATIC TEMP & PRESS SURVEY 970929 I I , ,_ H-08 · CORRELATION LOG GR/CCL 971 019 I 1 H- 10 ,--- L,L~ C .... TUBING PUNCH RECORD 971009 I I , , H- 10 ,, "~"' BRIDGE PLUG SET RECORD 971 013 I 1 J-06 . / TEMPERATURE-PRESSURE SURVEY 971 011 I 1 M-30 IvL~ C__, .,, / INJECTION PROFILE 970915 I 1 N- 22 · PRODUCTION PROFILE LOG 971 009 1 1 P-22 . STATIC PRESSURE SURVEY 971010 I 1 R- 16 ¢ WHIPSTOCK RECORD 971 017 1 1 S-42 0 LEAK DETECTION LOG 971012 I 1 W- 06 A · PERFORATION RECORD 971017 1 1 W- 23 · JEWELRY LOG CCL/GR 970901 1 1 Z-03 ' PERFORATING RECORD 971 014 I 1 Z-03 . JEWELRY LOG 971 014 I 1 Z-03 . PERFORATING RECORD 971 018 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11468 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 1 0/20/97 Well Job # Log Description Date BL RF Sepia LIS Tape C-1 . " STATIC pREs TEMP 970929 1 I "' E-02A CET 970829 1 1 F- 05 PRODUCTION PROFILE 970911 I 1 G-03A STATIC TEMP & PRESS SURVEY 9 70 929 1 1 G-23A STATIC TEMP & PRESS SURVEY 9 70929 I 1 !M-15 GAS LIFT SURVEY 970 91 8 I 1 M-30 INJECTION PROFILE 9 7091 5 I 1 M-38 INJECTION PROFILE WARMBACK 970 91 2 I 1 P-24 FLUID COMPENSATED CBL W/GR &CCL 970922 I 1 R- 12 TUBING PATCH RECORD 970 91 3 I 1 S-32 DEFT W/PSP 97091 3 I 1 S-34 INJECTION PROFILE 97091 0 I 1 W-2 'TCP CORRELATION 970827 I 1 W-2 PLUG SETTING RECORD 9 70828 I 1 W-03 A PERFORATING RECORD 970 91 7 I 1 W- 04 PERFORATING RECORD 9 70907 1 1 W-06 A PERFORATING RECORD 9 70 909 I 1 W- 18 GR/CCL JEWELRY LOG 970831 I 1 W-23 PATCH SET RECORD 9 70902 I I ,, Y- 34 STATIC SURVEY 970 921 I I LL rC.. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: OCT o:4 0 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 D !::! I I--I-- I N G S ~:: I::t U~ I r" ~:~ S WELL LOG TRANSMITTAL To: State of Alaska July 2, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 P°rcupine Dr' Anchorage, Alaska 99501 (~ q ~ \ __ MWD Formation Evaluation Logs - G-03A, AK-MW-70135 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.' Jirn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20221-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CI I::! I I._ / I I~J [:S WELL LOG TRANSMTrTAL To: State of Alaska June 25, 1997 Alaska Oil and Gas Conservation Cormn. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs G-03A, RE: AK-MW-70135 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Tan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 G-03A: 2"x 5"MD Gamma Ray Logs: 50-029-20221-01 2" x 5" TVD Gamma Ray Logs: 50-029-20221-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 17, 1997 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit G-03A BP Exploration (Alaska) Inc. Permit No 97-70 Sur. Loc.: 2263'SNL, 1974'WEL, Sec. 12, TI 1N, R13E, UM Btmhole Loc: 3163'SNL, 2722'WEL, Sec. 12, T11N, RI3E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill 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 xvith 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. David Chairman BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish dc Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. '~- STATE OF ALASKA ALASKA Oli_- D GAS CONSERVATION COMMISSION I APPLICATION FOR SUNDRY APPROVALS e of Request: Abandon x Suspend .__ Operation Shutdown ~ Re-enter suspended well Alter casing __ Repair well __ Plugging ~ Time extension ~ Stimulate ~ Change approved program __ Pull tubing __ Variance ~ Perforate ~ Other __ ne of Operator :.x~loration (Alaska) Inc. ] ress · Box 196612, Anchora_qe, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) 61.50 7. Unit or Property name Prudhoe Bay Unit :ation of well at surface 8. Well number ~' SNL, 1974' WEL, Sec. 12, T11N, R13E op of productive interval 3' NSL, 2393' WEL, Sec. 12, T11N, R13E effective depth 4' NSL, 2574' WEL, Sec 12, T11N, R13E total depth 5' NSL, 2604' WEL, Sec 12, T11N, R13E G-03 feet 9. Permit number 10. APl number 50- 029-20221 11. Field/Pool Prudhoe Oil Pool 'resent well condition summary 'oral depth: measured true vertical :- · measured true vertical 3asing Length Structural ._ Conductor 76' S u rface 2641' Intermediate 8341' Production __ Liner 1547' Perforation depth: measured 9149'-9198' 9400 feet Plugs (measured) 9210 feet BKB 9298 feet Junk (measured) 9115 feet BKB Size Cemented Measured depth 20x30 8 c. yds. 110 133/8 5158 C.f. 2675' 9 5/8 1589 C.F. 8375' 1 4 1997 Alas~_ Cg .& i~ias Cons. 6_0.r.,.}~'¢S~v' depth BKB 110 2675' 8246' 7" 484 c.f. 7838-9385 7729-9196 9010'-9145' sqz'd true vertical subsea Tubing (size, grade, and measured depth) 7,, N.80 stabbed into top of liner at 7838, DUPLI{ ATE Packers and SSSV (type and measured depth)9 5/8" xT" packer at 7875'; 4 1/2" SSSV & insert at2158' · Attachments Description summary of proposal x Detailed operations program ~ BOP sketch __ ;. Estimated date for commencing operation :/28/97 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. :igned ~~,~ Title Coiled Tubino Drillino Enoineer FOR COMMISSION USE ONLY ;onditions of approval: Notify Commission so r~e~l'N-~..~a~ witness Plug integrity ~,O,,,cati o n Approved by order of the Commission ~~~./~%~~. Commissioner Date '-' '~" ='Q~ ~ SUBMIT'~N T"RII~ICATE la. Type of work Drill Re-Entry 2. Name of Operator RP ~,n_ lnr~tinn STATE OF ALASKA ALASKA ( AND GAS CONSERVATION CC'~"MISSlON PERMIT TO DRILL 20 AAC 25.005 [] Redrill I~Ilb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] [] Deepen I~1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 3. Address t2 (3 Rn~ 1.qRRI~ Annhnr~np. Al~.qk~ .q.qRl.q-RRl~ 4. Location of well ~t su rf'~c~ 2263' SNL, 1974' WEL, Sec. 12, Tl lN, R13E At top of productive inte rval 1988' NSL, 2393' WEL, Sec. 12, T11N, R13E At total depth 3163'SNL, 2722' WEL, Sec. 12, Tl lN, R ;"3E '1property2. DistanceADL 0282851ine to nearest@ 2115 feet 13. Distance to nearest w ell No close approach feet 5. Datum Elevation (DF or KB) 61.5 KBE feet 6. Property Designation 028280 7. Unit or property Name Prudhoe Bay Unit 8. Well number G-O3A 9. Approximate spud date 5/9/97 4. Number of acres in pr operty 16. To be completed for d eviated wells Kickoff depth 8,~55 feet Maximum hole angle 95 o Setting Depth 10. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 11. Type Bond (see 20 AAC 25.025) Number 2S 100302630-277 Amount $200,000.00 5. Proposed depth (MD and TVD) 2560 10,980', 8951 'ss feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) ) Maximum surface 3330 psig At total depth CI'VD) RRf')O' / ,~7~."~ psig 18. Casing program size Hole Casing 3 3/4" 2 7/8" Specifications Weight Grade 6.16# L-80 19. To be completed for R Coupling ST-L Length 2780 edrill, Re-entry, and Dee Top Bottom I Quantity of cement M D J TVD 8200[ 8016 pen Operations. MD 10,980 'I-VD 8951 (include stage data) i130 c.f. "I~R I'i 1997 Present well condition su mmary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 76' 2641 8341' 9400 feet Plugs (measured) 9210 feet 9298 feet Junk (measured) 9115 feet Size Cemented AJas~__ .0il .& Gas Cons. Anchorage Measured depth True Vertical depth 20x30 8 c. yds. 110' 110' 13 3/8 5158 c.f. 2675' 2675' 9 5/8" 1589 c.f. 83 75' 8246' 1547' 7" measured 9149L9198, true vertical 484 c.f. 7838'-9385' 7729'-9196' 9010'-9145' sqz'd 20. Attachments Filing fee [] Property plat Drilling fluid program [] Time vs depth plot [] 21. I hereby cert~oregOing is true an Signed [] BOP Sketch [] Diverter Sketch [] Drilling program [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirement s[] d correct to the best of my knowledge Title Coil Tubing Drilling Engineer Commission Use Only Date ¢//~//~ -'7 Permit Number IAPI number IApproval date ISee cover letter ~'~-' 74:::) t50- ~ '?'' ~- .2- 0.2.,.2-,. ( - ,c2 ( I /-7* '~ / '¢ '" ~','¢ .~Jfor other requirements Conditions of approval Samples required [] Yes ~ No Mud log required [] Yes ~ No Hydrogen sulfide measures ~ Yes [] No Directional survey requir ed '~ Yes [] No Required working pressure for BOPE []2M; CI3M' F15M; [~IOM; 1~15M; Other: Original Signed By by order of Date _~.~/ ¢ '" Approved by 0avid W. J0h_nsto_n Commissioner t~e commission ~1 (~ Form 10-401 Rev. 12-1-85 Submit in tri ica BPX G-03A Sidetrack Summary of Operations: The well is being sidetracked to reduce GOR and improve PI. This sidetrack will be conducted in two phases. Phase 1: Cut Window: Planned for 4/28/97. · A whipstock will be set on ELine at approximately 8654' MD. · The existing Ivishak perforations will be cement squeezed. · A window will be cut in the 7" liner and 10 ft of formation will be drilled. Phase 2: Drill Directional Hole: Planned for 5/09/97. - Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan to planned TD of 10,980' MD (8,951' -I-VDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8200' MD and cemented with approx. 23 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 8654' MD (8445' -I-VD ss) - TD: 10,980' MD (8851' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging - A Gamma Ray log will be run over all of the open hole section. TREE: CAMERON 6" WELLHEAD: McEVOY ACTUATOR: OTIS G-03A Proposed Completio, KB. ELEV = 61.50 BF. ELEV = 34.26 -5/8 FOC 13-3/8", 72#/ft, N-80, BTRS. 9-5/8 D.V.PACKER 2209 2719 KOP: 3000 MAX ANGLE: 38° 7", 26#/ft, N-80, AB-TC- 4S TUBING TUBING ID: 6.276" CAPACITY: 0.0382 BBL/FT TBG/CSG ANNULAR VOLUME 0.0256 BBL/FT SSSV LANDING NIPPLE (OTIS 7") ( 3.813" ID) 2158 PERFORATION SUMMARY REF: LOG: BHCS 7/15/76 INTERVAL C 9010-9036 9050-9075 9089-9119 9130-9145 9149-9183 9193-9198 PEN/SQZ'D SQUEEZED SQUEEZED SQUEEZED SQUEEZED 7" LINER 7877 I TOP OF SEAL ASSY. I BOTTOM OF SEAL ASSY. I I BOT) 7835 7871 9-5/8", 47#/ft, N-80, BTRS 8375 2 7/8" liner cemented to 200 ft above window MARKER JOINT [ 9014 WHIPSTOCK NRWO - GAS SHUT OFF BAKER FB-1 PERM. PACKER, 5.5" ENTRY GUIDE & 4.0 MIN. I.D. 3.5" TBG BETWEEN PKRS HAS 3.0" I.D. BAKER F-1 PERM. PACKER Abandonment cement 9003 ]--- ! downsqueezed below whipstock. --,_ -- i - ' PBTD [ 9331 7", 29 #Iff, N-80, BTRS 9385 9045'1 G-OS Plan -2,600 -2,200 -1,800 -1,400 -1,000 -600 -200 .500 .700 .900 -1,100 -1,300 X distance from Sfc Loc -1,500 IWellName G-03 CLOSURE Distance 1,171 ft Az 219 deg NEW HOLE ENV(X) N/S (Y) Kick Off -389 -1,032 TD -729 -916 State Plane 657,517 5,968,470 Surface Loc 658,246 5,969,386 Az Chg MD (ft) 25.0 165 25.0 90 0.0 110 -3.0 165 -1.5 850 -10.0 450 -5.0 140 5.0 350 Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 2,320 Drawn: 4/8/97 16:15 Plan Name: Case 1 Vertical Section Go'03 200 400 600 800 Path Distance (Feet) ~ 1,000 1,200 1,400 1,600 1,800 2,000 2,200 2,400 i 8300 + ..... ~ - ! i ! .~ 8350 8400 ~ Angle (~ K.O.= 20 deg Li MD:8660 -TSAD DL 1= 23 deg/100 45 deg 45 deg DL 2= 18 deg/100 DL 3= 5 /100 TZ3 10980 TD Tot Drld:2320 ft Marker Depths @Orig Wellbore TSAD J 8,490Jff TVD TZ2 J 8,699Jff TVD Target J 8,960Jrt TVD TZ3 I 8,e471ftTVU Kick Off J 8,455 ft 'I-VD I 8,660 ft MD Deprtr I~KO 1,118 ft MD KO Pt 8,66oj MD New Hole 2320J I Total MD 10,980J TVD TD 8,951 J Build Rt deg/100 MD (ft) 15.0 165 0.0 90 5.0 110 12.0 165 2.4 850 0.0 450 0.0 140 0.0 350 Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 2,320 Drawn: 4/8/97 16:15 Plan Name: Case 1 G-03A CT Drilling & Completion BOP W '"F · 12" 36" 22.5" 18"I 38" 2 318" CT ~1 I I I I ~o,ooo psil Pack-OffI Lubricat°r~'~ I 7 t/16" Annular 7 1/16" 5000 psi Alaska .Oil .& Gas Cons. ~chora§e Blind/Shear 7 t/16" Pipe/Slip 2 318" 7 1/16" X 5,000 psi ~ ~1/16 _.. ,, ::: ::: SWAB OR MASTER VALVE I WELL PERMIT CHECKLISToo Y FIW. LD & POOL~ INIT CLASS ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. · N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N ll. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ....... N ~'~3~ PROGRAM: expD dev~redr~ servn wellbore seg[] ann disp pa~a~q[q gj? REMARKS ENGINEERING 14. Conductor string provided ................ Y 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg. · Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ~ N BOPEs adequate ..................... /~ N 25'BOPEpressratingadequate;testt°3~'~psig~N26. 27. Choke manifold complies w/WI ~-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY APPR D~TE / / 30. Permit can be issued w/o hydrogen sulfide measures .... Y on potential overpressure zones ..... Y 31. Data presented 32. Seismic analysis of shallow gas zones .......... ~//,N. ./~_/,~ . 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports · · ./. Y N [exploratory only] GEOLOGY: ENGINEERING: CO~ISS ION: Comments/Instructions: HOWldlf- A:\FORMS\cheklist rev 01197 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. Sperry-Sun Drilling Services LIS Scan Utility Wed Jun 25 16:40:18 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/06/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF M C OFILMED Comment Record TAPE HEADER PRUDHOE BAY UNI~Ste MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-70135 STEVE LATZ WHITLOW/HILD JUL 02 1991 Alask~ Oil & Gas Cons. Commission G- 03A An o~.or~§e. 500292022101 BP EXPLO~TION (~S~), INC. SPERRY-SUN DRILLING SERVICES 25-~N-97 MWD RUN 2 AK-MW-70135 STEVE LATZ WHITLOW/HILD MWD RUN 3 AK-MW-70135 STEVE LATZ PARKER/HILDR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-70135 STEVE LATZ PARKER/HILDR MWD RUN 5 AK-MW-70135 STEVE LATZ PARKER/HILDR MWD RUN 6 AK-MW-70135 STEVE LATZ PARKER/HILDR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: MWD RUN 7 AK-MW-70135 BUD JAHN PARKER/HILDR MWD RUN 8 AK-MW-70135 BUD JAHN PARKER/HILDR 12 llN 13E 2263 MWD RUN 9 AK-MW-70135 BUD JAHN PARKER/HILDR FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1974 61.50 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7. 000 9385.0 PRODUCTION STRING 3.750 11288.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 9 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR TRACY LOVE OF BP EXPLORATION (ALASKA), INC. ON 5/15/97. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11288'MD, 8958'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMARAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Conunent Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8635.5 11261.0 ROP 8661.5 11287.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 8662.0 8903.0 2 8903.0 9030.0 MWD 3 9030.0 MWD 4 9342.0 MWD 5 9368.0 MWD 6 9684.0 MWD 7 9938.0 MWD 8 10107.0 MWD 9 10525.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9342.0 9368.0 9684.0 9938.0 10107.0 10525.0 11288.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8635.5 11287.5 9961.5 5305 8635.5 GR 16.78 524.98 48.5159 5252 8635.5 ROP 5.36 1682.93 73.1515 5253 8661.5 Last Reading 11287.5 11261 11287.5 First Reading For Entire File .......... 8635.5 Last Reading For Entire File ........... 11287.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8618 . 5 8876.0 ROP 8661 . 5 8902 . 5 $ LOG HEADER DATA DATE LOGGED: 08-MAY- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.4 MAXIMUM ANGLE: 41.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 8903.0 8662.0 8903.0 TOOL NUMBER NGP 170 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 3.750 3.8 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 FLO-PRO 9.20 65.0 9.0 5.2 .000 .000 .000 .000 53.9 .3 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8618.5 8902.5 8760.5 569 8618.5 GR 23.27 524.98 73.6544 483 8618.5 ROP 5.36 391.96 38.2287 483 8661.5 Last Reading 8902.5 8876 8902.5 First Reading For Entire File .......... 8618.5 Last Reading For Entire File ........... 8902.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8876.5 9003.0 ROP 8904.5 9029.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERV~LL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 09-MAY- 97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9030.0 8903.0 9030.0 45.4 49.6 TOOL NUMBER NGP 170 3.750 3.8 FLO- PRO 9.20 65.0 9.5 5.2 .000 .000 .000 .000 56.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 8876.5 9029.5 8953 307 GR 17.95 83 30.8311 254 ROP 16.45 51.25 26.702 251 First Last Reading Reading 8876.5 9029.5 8876.5 9003 8904.5 9029.5 First Reading For Entire File .......... 8876.5 Last Reading For Entire File ........... 9029.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9003.0 9315.0 ROP 9030.0 9341.5 $ LOG HEADER DATA DATE LOGGED: 09-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 50.0 MAXIMUM ANGLE: 80.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9342.0 9030.0 9342.0 NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHU~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX:' MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 NGP 277 3.750 3.8 FLO-PRO 9.30 65.0 9.5 5.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 70.3 First Name Min Max Mean Nsam Reading DEPT 9003 9341.5 9172.25 678 9003 GR 19.7 103.83 29.8249 625 9003 ROP 12.84 107.12 60.1644 624 9030 Last Reading 9341.5 9315 9341.5 First Reading For Entire File .......... 9003 Last Reading For Entire File ........... 9341.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Con~nent Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9315.5 ROP 9339.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: STOP DEPTH 9341.0 9367.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) 14-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9368.0 9342.0 9368.0 79.2 80.3 TOOL NUMBER NGP 170 3.750 3.8 FLO-PRO 9.10 65.0 9.0 4.9 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 58.6 First Name Min Max Mean Nsam Reading DEPT 9315.5 9367 9341.25 104 9315.5 GR 23.45 27.54 25.4768 52 9315.5 ROP 47.37 502.31 123.296 57 9339 Last Reading 9367 9341 9367 First Reading For Entire File .......... 9315.5 Last Reading For Entire File ........... 9367 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... 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BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9341.5 9657.0 ROP 9369.0 9683.5 $ LOG HEADER DATA DATE LOGGED: 14-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.2 MAXIMUM ANGLE: 83.1 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9684.0 9368.0 9684.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 289 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 8.90 65.0 9.0 6.2 .000 .000 .000 .000 63.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .3 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9341.5 9683.5 9512.5 685 9341.5 GR 16.78 62.66 25.832 632 9341.5 ROP 24.79 1366.09 69.143 630 9369 Last Reading 9683.5 9657 9683.5 First Reading For Entire File .......... 9341.5 Last Reading For Entire File ........... 9683.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9658.5 9910.5 ROP 9673.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9937.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT T~4PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 15-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9938.0 9684.0 9938.0 83.1 90.5 TOOL NUMBER NGP 289 3.750 3.8 FLO-PRO 8.80 65.0 9.0 6.3 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 ROP MWD 6 FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 9658.5 9937 9797.75 558 GR 23.17 156.5 62.8479 505 ROP 13.99 2355.96 139.723 528 First Last Reading Reading 9658.5 9937 9658.5 9910.5 9673.5 9937 First Reading For Entire File .......... 9658.5 Last Reading For Entire File ........... 9937 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ........... '..STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9911.0 10080.0 ROP 9938.5 10106.5 $ LOG HEADER DATA DATE LOGGED: 16-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.4 MSC 1.32 NGP 5.74, DEP 2.041, MEMORY 10107.0 9938.0 10107.0 42 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 89.2 TOOL NUMBER NGP 289 3.750 3.8 FLO-PRO 8.90 65.0 9.0 5.7 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9911 10106.5 10008.8 392 9911 GR 28.69 113.01 50.8587 339 9911 ROP 16.97 1128.8 66.4692 337 9938.5 Last Reading 10106.5 10080 10106.5 First Reading For Entire File .......... 9911 Last Reading For Entire File ........... 10106.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ 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BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10080.0 10498.5 ROP 10107.5 10525.0 $ LOG HEADER DATA DATE LOGGED: 17-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10525.0 10107.0 10525.0 TOOL NUMBER NGP 277 3.750 3.8 FLO- PRO 8.90 65.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.0 6.3 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 79.7 First Name Min Max Mean Nsam Reading DEPT 10080 10525 10302.5 891 10080 GR 26.13 120.24 41.0739 838 10080 ROP 35.29 1682.93 95.0454 836 10107.5 Last Reading 10525 10498.5 10525 First Reading For Entire File .......... 10080 Last Reading For Entire File ........... 10525 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... 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BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10492.0 ROP 10519.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11261.0 11287.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 19-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 11288.0 10525.0 11288.0 84.9 94.7 TOOL NUMBER NGP 289 3.750 3.8 FLO-PRO 9.00 60.0 9.0 5.4 .000 .000 .000 .000 72.6 TOOL STANDOFF (IN) : .3 EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10492 11287.5 10889.8 1592 10492 GR 27.09 640.53 61.0137 1539 10492 ROP 14.52 1359.25 92.8079 1537 10519.5 Last Reading 11287.5 11261 11287.5 First Reading For Entire File .......... 10492 Last Reading For Entire File ........... 11287.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/06/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Scientific Technical Next Reel Name UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File