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197-231
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector P2-33B (PTD #1972310) Slow TxIA communication Date:Wednesday, February 18, 2026 8:13:48 AM Attachments:P2-33.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, February 17, 2026 6:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector P2-33B (PTD #1972310) Slow TxIA communication Mr. Wallace, WAG injector P2-33B (PTD # 1972310) IA pressure was bled on 02/16 from 890 psi to 100 psi with trace gas returns. Additionally, a PPPOT-T passed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward 1. Well Integrity: Evaluate dummy gas lift valves with extended packing 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Further action as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 10, 2025 4:58 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: WAG Injector P2-33B (PTD #1972310) IA pressure bleed Mr. Wallace, Injector P2-33B (PTD # 1972310) had an IA pressure bleed on 08/10/25. Recently, the IA pressure trend has been increasing and it is not clear if the increase if from thermal effects or TxIA communication. We are going to perform another IA bleed and monitor. If it is determined that the well has TxIA communication we will make it Under Evaluation and notify you. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 2, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-33B PRUDHOE BAY UN PTM P2-33B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/02/2026 P2-33B 50-029-22812-02-00 197-231-0 G SPT 8545 1972310 2136 2483 2492 2504 2498 53 100 100 100 4YRTST P Austin McLeod 11/15/2025 MITIA. Higher than typical bbl counts- deep MD of PKR (14,000') 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P2-33B Inspection Date: Tubing OA Packer Depth 234 3500 3440 3415IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251116190449 BBL Pumped:8 BBL Returned:8 Friday, January 2, 2026 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: WAG Injector P2-33B (PTD #1972310) IA pressure bleed Date:Monday, October 13, 2025 6:44:58 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 10, 2025 4:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: WAG Injector P2-33B (PTD #1972310) IA pressure bleed Mr. Wallace, Injector P2-33B (PTD # 1972310) had an IA pressure bleed on 08/10/25. Recently, the IA pressure trend has been increasing and it is not clear if the increase if from thermal effects or TxIA communication. We are going to perform another IA bleed and monitor. If it is determined that the well has TxIA communication we will make it Under Evaluation and notify you. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. TO PIW Tubing — On ■ Mani ♦ Operable + Mal Opp, ♦ Unix EW Mpn. IA � Man. OA Mpn. OpL � Men. 000A -p Mpn.WXT MEMORANDUM TO: Jim Re gg L C�, 1 � 7�7c�l P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 10, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P2 -33B PRUDHOE BAY UN PTM P2 -33B Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN PTM P2 -33B API Well Number 50-029-22812-02-00 Inspector Name: Matt Herrera Permit Number: 197-231-0 Inspection Date: 11/28/2021 Insp Num: mitMFH211129092415 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2 -33B .i yp J W -'ITVD 8545 -'Tubing 1904 - 1908- T e In � 1888 1894 - PTD 1972310 - 'Type Test SPT" Test psi 2136 IA 297 3507 _ 3461 3447 - BBL Pumped: 7.4 - BBL Returned: 7.3 OA 137 576 560 550 Interval WITAL_ .- P/F P -_- Notes: MIT -IA Performed by Operations per Sundry 321-192. Well converted from a producer to an Injector. IA tested to 3500 PSI Per Operator Friday, December 10, 2021 Page 1 of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y Samantha Carlisle at 8:27 am, Dec 15, 2021 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN DSR-12/15/21MGR17JAN2022 RBDMS HEW 12/15/2021 SFD 12/15/2021 $&7,9,7<'$7(6800$5< 7,2 7HPS 6,,$)/ 6/UHTXHVW $/3 SVL6,#&9,$ )/# EEOV 6OLFNOLQHLQFRQWURORIYDOYHVXSRQGHSDUWXUH :(//6,21$55,9$/ 3UHVVXUHWHVWLQWHJULW\ '5,)772 7$*&$:5'3:*5,1*$7 6/0 0' 38//&$:5'3 VQ+.6VHWVIUXHGHQEHUJSNJ )52069/1$7 0' 81$%/(72'5,)73$67 6/0: *5,1* 7RROVFRYHUHGLQVRIW KDUGSDUDIILQ 3803758&.127$9$,/$%/()25+27%586+ )/86+72'$< /')1:(//6, 6(&85('&217,18('21:65 $VVLVW6OLFNOLQHZ% ) 35(6685(7(67 ,17(*5,7< 3XPSHGEEOV '6/EEOV FUXGHDQGEEOVRI '6/GRZQ7EJZKLOH6/EUXVKHG6/LQ FRQWURORIZHOOSHU/56GHSDUWXUH,$2$ 27* &217,18(')520:65 3UHVVXUHWHVWLQWHJULW\ %586+ )/86+ +RW )520685)$&(72 6/0:%586+ *5,1* 02'(5$7(%8,/'83)520 72 6/0 +($9<%8,/'8372 6/0 '5,)772 6/0: *5,1*:,7+287,668( 6(76/,36723&$7&+(568%$7 6/0 38//%.2*/9)52067 0'1RVHIORZFXW %./*/9)52067 0' /')1:(//6, 6(&85('&217,18('21:65 &217,18(')520:65 3UHVVXUHWHVWLQWHJULW\ 6(7%.'*/9$767 0' 81$%/(72*(73803758&.)/8,'6)25,$/2$' 0,7,$7236, /')1:(//6, 6(&85('&217,18('21:65 &217,18(')520:65 3UHVVXUHWHVWLQWHJULW\ 6(7%.'*/9$767 0' -2%,1&203/(7(:,//5(7851)25,$/2$' 7(67:+(13803758&. ,6$9$,/$%/( :(//6,21'(3$5785(127,),(''622):(//67$786 127( 6/,36723&$7&+(568%/()7,1+2/($7 6/0 :(//6,21$55,9$/ 3UHVVXUHWHVWLQWHJULW\ '5,)77266&6$7 6/0: *5,1* 7LJKWVSRWVIURP WR VOP 38//%.'*/9)52067 6(7%(.)/2:6/((9($767 0' /')1:(//6, 6(&85('&217,18('21:65 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%83% 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%83% 7,2 7HPS 6,/568QLW$VVLVW6/ 35(6685(7(67 ,17(*5,7< $WWHPSWWRORDGWKH,$ZLWKGLHVHO3XPSHGEEOVRI )GLHVHOLQWR WKH,$DQGLWSUHVVXUHGXSWRSVL%OHGEEOVEDFNWRSVL3XPSHGEEOV RI0HRKDQGEEOVRI )6./ZDWHULQWRWKH7%*%OHG,$WKHUPDO H[SDQVLRQSUHVVXUHWLPHV,$SUHVVXUHVWDUWHGWRVORZO\IDOODIWHUSXPSLQJEEOV ,$3VWDELOL]HGDWSVLDIWHUSXPSLQJEEOVLQWRWKH7%*)UHH]HSURWHFWHGWKH 7%*ZLWKEEOVRI )GLHVHO3XPSHGEEOVRI0HRKDQGEEOVRI )GLHVHOLQWRWKH,$)LQDO7,2 &217,18(')520:65 3UHVVXUHWHVWLQWHJULW\ 5$1%586+*5,1*7223(1837,*+763276)520 72 6/0 /56$77(037('72/2$',$%8735(6685('83:%%/6$:$< +ROGLQJ 3RVVLEOHLFHSOXJ /563803('%%/62)+276./'2:178%,1*727+$:,$ EEOV RIGLHVHOWRIUHH]HSURWHFW /56/2$'(',$:%%/62)',(6(/ 3XPSHGILUVWEEOVKRWWRPDNHVXUH ,$ZDVFOHDU 38//%(.)/2:6/((9()52067 6(7%.'*/9$767 0' /')1:(//6, 6(&85('&217,18('21 :65 7,2 7HPS 6,/56XQLW$VVLVW6OLFNOLQH 35(6685( 7(67 ,17(*5,7< 0,7,$WRSVLWDUJHWSUHVVXUH 3$66(' DWSVL SVLPD[DSSOLHGSUHVVXUH ,$ORVWSVLGXULQJWKHVWPLQXWHVDQGSVLGXULQJ WKHVHFRQGPLQXWHV,$ORVWSVLGXULQJWKHPLQXWHWHVW3XPSHGEEOVRI )GLHVHOWRDFKLHYHWHVWSUHVVXUH%OHGEDFNEEOVWRILQDO7,2 6/KDGFRQWURORIWKHZHOOXSRQGHSDUWXUH,$2$27* &217,18(')520:65 3UHVVXUHWHVWLQWHJULW\ /563(5)250('68&&(66)8/0,7,$7236, ,$EOHGEDFNWRSVL 38//(037<6/,36723&$7&+(568%)520 6/0 6(7+(60&; 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Exploratory Development Service 5 Permit to Drill Number:197-231 6.API Number:50-029-22812-02-00 PRUDHOE BAY, PT MCINTYRE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0365548 Property Designation (Lease Number):10. 8. PTM P2-33B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown WAG conversion Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 16491 Effective Depth MD: 13Cr80 11. 5-15-21 Commission Representative: 15. Suspended Contact Name: Kirsty Schultz Contact Email: Kirsten.Schultz@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Camco WRDP-2 SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8979 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 13983 , 14037 / 8545 , 8578 2159 / 2033 Date: Liner 2458 4-1/2" 14032 - 16490 8574 - 8979 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 34 - 7894 34 - 4940 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 115 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" TIW HBBP-T, 4-1/2" Baker ZXP 14585 - 16400 8952 - 9003 4-1/2" 12.6# 13Cr80 29 - 14038 Production 16402 9002 none none 36 - 116 1500 10-3/4" Contact Phone:(907) 564-5258 Date:4-9-21 80 306020"Conductor 1730 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 7860 4560 Intermediate 14170 7-5/8" 31 - 14201 31 - 8679 6890 4790 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2410 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:37 pm, Apr 12, 2021 321-192 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.10 08:53:16 -08'00' Bo York 24 hour notice to AOGCC to witness MIT-IA. AOGCC to witness MIT-IA within 5 days of stabilized injection. * Variance to 20 AAC 25.412(b) approved. Injection packer will be set ~602' above upper most perforations. *Safety valve function test performed within 5 days of injection. 24 hour notice to AOGCC. , ADL 0034624 10-404 DSR-4/12/21MGR19APR21SFD 4/13/2021 SFD 4/13/2021 SFD 4/13/2021 Yes n Required? Comm 4/20/21 dts 4/19/2021 RBDMS HEW 4/21/2021 WAG Conversion Well: P2-33B PTD: 1972310 API: 50-029-22812-02 Well Name:P2-33B API Number:50-029-22812-02 Current Status:SI Producer Rig:SL + WTI Estimated Start Date:May 15, 2021 Estimated Duration:5 Reg.Approval Req’d?10-403, 10-404 Date Reg. Approval Rec’vd: AFE Permit to Drill Number:1972310 First Call Engineer:Kirsty Schultz (907) 564-5258 (O) (907) 350-4310 (M) Current BHP:4140 psi @ 8,800’ TVDss (Based on SBHPS on 11/15/2002) Max Shut In WHP:2410 psi @ 8,800’ TVDss (Based on SBHPS on 11/15/2002) Min ID:3.725” 4-12” XN Nipple @ 14,027 MD. Possible further restrictions exist in tubing due to scale deposits as evidenced by 2008 caliper. Brief Well Summary: P2-33B was completed as a gas lifted producer in the Point McIntyre field and put online in April 1998. The well was a mostly full time producer until ~2012 when it was SI for HWC. Besides a few POPs to retest WC, the well has remained SI since 2012. P2-33B cum’d 3.7 MMBO. P2-33B is well positioned on the flank of PM field to provide injection support and sweep as a WAG injector. Converting P2-33B to WAG service should improve oil production on several offset producers and increase overall oil recovery. Objective: Convert the well service from gas lifted producer to WAG. Notes Regarding Wellbore Condition: - Passing MIT-IA to 3500 psi on the rig on 3/18/98 - Passing MIT-T to 4000 psi on the rig on 318/98 - Failed MIT-OA on 10/26/2002, with no returns noted to surface. - Well’s existing 5K tree will be utilized for injection. - Passing PPPOT-T to 5000 psi on 3/18/2003 - Passing PPPOT-IC to 3100 psi on 10/27/2002 - Note: an MIT-IA to 3500 psi is planned prior to converting the well to injection Variance Requested:20AAC25.412(b) Packer will be set greater than 200ft measured depth from open perfs. Tubing packer is at 13,983’MD which is 602’ MD above the uppermost open perforations at 14,585’. Area of Review – P2-33B Prior to the conversion of well P2-33B from producer to WAG injector, an Area of Review (AOR) must be conducted. This AOR found three other wells (P2-33A, P2-27, and P2-49) within ¼ mile of P2-33Bs entry point into the Kuparuk formation. See attached table Area of Review P2-33B for annulus integrity and zonal isolation of all wells within the AOR. Non-Sundried Work In Progress: Slickline/Fullbore: 1. MIRU SL 2. Pull SSSV 3. DMY GLVs Convert the well service from gas lifted producer to WAG. entry point into the Kuparuk formation. -00 SFD 4/13/2021 three other wells (P2-33A, P2-27, and P2-49) within ¼ mile of P2-33Bs WAG Conversion Well: P2-33B PTD: 1972310 API: 50-029-22812-02 4. FB to load IA and MIT-IA with max applied pressure of 3500 psi 5. Set MCX in preparation for injection Sundry Procedure (Approval Required to Proceed): Well Tie-In: 1. Surface Disconnect; blind production and test headers. Disconnect and blind AL. 2. Install new WAG S-Riser 3. Twin with P2-34 existing MI and PWI lines 4. Install new metering and safety systems 5. Piping support adjustments as needed Operations 1. Place well on MI targeting initial rate of ~25 MMSCFD. 2. Obtain AOGCC witnessed SVS test within 5 days Attachments: -AOR Table - AOR Map - P2-33B WBS MIT-IA within 5 days of stabilized production. State to witness. 24 hour notice to AOGCC to witness. WAG Conversion Well: P2-33B PTD: 1972310 API: 50-029-22812-02 PTD API WELL STATUS Distance TopKuparukTop of Cement Annulus Integrity Zonal Isolation1972310 500292281202 P2-33B SI Producer 0' 14587' MD(-8905TVDss)13470' MD (-8186' TVDss)08/02/2008: TIFL passed10/26/2002: MIT-OA failed03/18/1998: MIT-IA passed to3500 psi on rig.03/18/1998: MIT-T passed to4000 psi on rig.The 7-5/8" casing was cemented with 28 bbl of 15.8 ppg cement.The plug bumped, and a 3000 psi pressure test was successfullyobtained. Calculated TOC ~13470' MD. No cement logs areavailable. 4-1/2" liner was run to 16490' MD. 97 bbls of cementwas pumped, the plug bumped, and floats held. All indications arethat cement to top of liner.1972070 500292281201 P2-33A Abandonedproducer53' 14638' MD(8903'TVDss)13470' MD (-8186' TVDss)11/22/1997: 7-5/8" casing testedto 5000 psi successfully on rig.P2-33A drilled 9-7/8" hole to 15120' MD. The production holewas then abandoned with cement. 15.7 ppg cement was pumpedto 14520' MD and 17.1 ppg cement to 14024' MD. Cement wasthen drilled out, and 7-5/8" casing was set at 14200' MD on11/21/1997. The 7-5/8" casing was cemented with 28 bbl of 15.8ppg cement. The plug bumped, and a 3000 psi pressure test wassuccessfully obtained. Calculated TOC ~13470' MD. No cementlogs are available.1971250 500292278500 P2-27 SI Producer 987' 13833' MD(-8903'TVDss)9879' MD (-6803TVDss)5/7/2016: MIT-T failed5/7/2016: CMIT-TxIA passed to2750 psi7" casing was set at 12403' MD. Pumped 57 bbl cement. Plugbumped. Pressure test completed successfully to 3500 psi with 30min. test. Calculated TOC @ 9879' MD. No cement log across the7" is available. 4-1/2" liner was run to 14340' MD. 96 bbls ofcement was pumped, plug bumped. A CET log was run on12/8/1997 which showed good cement to ~12600 and patchycement to top of liner.92024 500292225200 P2-49 SI Producer 1003' 14229' MD(-8918TVDss)13628' MD (-8452 TVDss)4/29/1992: 9-5/8" casing passedpressure test to 3000 psi for 30min. on rig prior to drill out.9-5/8" casing was run to 14209' MD. On 4/28/1992, 78.4 bbls of15.8 class G cement was pumped. Did not bump plug, floats held.Calculated TOC is 10251' MD. When drilled out the shoe on4/29/1992, green cement was found. 7" liner was run to 14730'MD, Cement log run on 9/7/1992 from 13501' MD to 14604'MD. Cement log indicates TOC at 13628' MD; however, the loggives no data about possible cement above 13501' MD. It ispossible there is cement above 13501' MD. The log showed goodcement throughout the 7" liner.P2-33B Area Of Review CET log wCalculated TOC is 10251' MD. W Calculated TOC ~13470' MD. Cement log indicates TOC at 13628' MD; Calculated TOC @ 9879' MD. 15.7 ppg cement was pumpedto 14520' MD and 17.1 ppg cement to 14024' MD. green cement was found. good cement to ~12600 Calculated TOC ~13470' MD. WAG Conversion Well: P2-33B PTD: 1972310 API: 50-029-22812-02 WAG Conversion Well: P2-33B PTD: 1972310 API: 50-029-22812-02 Hilcorp North Slope LLC ` STATE OF ALASKA RECEWED AL _KA OIL AND GAS CONSERVATION COMMISSION DEC 0 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well❑ Plug Perforations ❑ Perforate Lf' Other fO3CC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 197-231-0 ' 3.Address: P.O.Box 196612 StratigraphiC Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22812-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0365548- PTM P2-33B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PT MCINTYRE OIL , 11.Present Well Condition Summary: Total Depth measured 16491 feet Plugs measured None feet true vertical 8978.74 feet Junk measured None feet Effective Depth measured 16402 feet Packer measured See Attachment feet true vertical 9002.34 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"133#H-40 35-115 35-115 3060 1500 Surface 7860 10-3/4"45.5#NT-80 34-7894 34-4939.98 4560 1730 Intermediate None None None None None None Production 14170 7-5/8"29.7#L-80 31-14201 31-8679.24 6890 4790 Liner 2458 4-1/2"12.6#13Cr80 14032-16490 8574.1-8979.01 8430 7500 Perforation depth Measured depth 14585-14605 feet 16050-16180 feet 16200-16400 feet True Vertical depth 8951.58-8963.48 feet 9054.4-9050.44 feet 9048.15-9002.88 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 29-14038 29-8577.74 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"Camco WRDP-2 SSV 2159 2032.09 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED j ;,_ .» ,, : . Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 100 1267 4363 2030 753 Subsequent to operation: 112 357 6675 2170 757 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 1511 ` Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 • Gas LI WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCC 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catron( BP.Com Printed Name Garry Catron Title PDC PE Signature 0.1/ -' Phone 564-4424 Date 12/10/2013 In-i Ile S4' 1; DEC 1 " 2n„ Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0365548 SW Name Type MD TVD Depscription P2-33B SSSV 2159 1984.59 4-1/2"Camco WRDP-2 SSV P2-33B PACKER 13983 8497.18 4-1/2"TIW HBBP-T Packer P2-33B PACKER 14037 8529.64 4-1/2" Baker ZXP Packer 2 m < I / < a m CO % / a / / \ / 2 HQ _$ / a_ ¥ U a (7c HO pp / / 2 \ / / f / 17- < ± Co 0 a c 2 2 5 2 ± ii -1 O@ o - - .R 2 2 L R >- 01-1 V. 2k ƒ \ / / < 0 -Iin0 a c / / e ± ƒ 2 / O 0 � 2 $ pp A/ / ƒ / 0 / ƒ 0 5 t \ 2 : 2 2 0 @ m ± O 7) k ® \ 2 (---n- c---61, \ 2 / i < R O k a ƒ < t \ / / 0ZZC ƒ In K \ $ � � � o k / / / -/ O » / D Z- F W E & / 7 ,-.4- / Cr b / 2 7 » * \ I O / \ 7 » / m \ i ® / 7 0 : r - 00; - 0 y 2 I : E O li a / ' O > I E a. -1Nz0 2222L -Jo \ Iww O « o Ce / p O ± I a a 0 ± R 2 O \ / r ? o < W _J b / t 2 2 = 2 2 o 2 - w = CO Cr < 2 Er g 2 2 - = L u 2 = 0 - x - 2@ ct L I 2 - < E -' � \ \ \ D 0< C / ) H2 / b / 0a / 2 2 - - cr N - - w A W z \ 2 - I O 2 2 0 - \ \ / \ Z Z - X `> 17- 1= b b L 0 0 ƒ o < W W - / k 2 - O O b % % O O / / \ \ F- 2 O < < < O ± 2 O \ 7 ± ± 4 -- � cr cr - \ \ \ / < / ƒ 0i m d& - m m _, R R m m@ R ± L < m u / F- Z c \ / < / / / \ \ / / / / / 2 I E 0 9 E \ \ / / } ! R - : MOO : i 00 : ; ? o < O D E a R % 2 : r /\/ m/N\ n/N/ r\/ » TREE• 4-1/16"-5M GW SAFETY NOTES: WELL REQUIRES A SSSV. WELL 1VVELLHEAD= 13-5/8"-5M FMC P2-33B SOLID//SLTD L1447740'°°CHROME4-1/2"TBG&4-1/2" ACTUATOR= BAKER OKB.ELEV= 47.50' BF.ELEV= NA KOP= 700' Max Angle= 105°@ 16490' Datum 1.037=---- D= 14437' 2159' — 4-1/2"CAMCO BAL-O SSSVN,D=3.813" Datum TVD= 8800'SS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 5908 4021 62 CA DOME BK 16 04/03/03 10-3/4"CSG,45.5#,NT-80,D=9.953" H 7836' 2 8414 5227 54 CA SO BK 24 04/03/03 Minimum ID =3.725" @ 14027' , I 3 9806 6042 54 CA DMY BK 0 03n6r96 4 10955 6728 51 CA DMY BK 0 03/16/98 4-1/2" OTIS XN NIPPLE 5 11784 7223 53 CA DMY BK 0 03/16/98 6 12453 7625 54 CA DMY BK 0 03/16/98 7 13479 8240 53 CA DMY BK 0 03/16/98 8 13914 8503 52 CA DMY BK 0 03/16/98 Z 13983' —1 7-5/8'X 4-1/2"TTW FBBP-T PKR,D=3.93" I I I 14016' H 4-1/2'FES X NP,D=3.813" I TOP OF BAKER TACK SLV,D=4.875' —{ 14032' ' ' 14027' H 4-1/2"FES XN NP,D=3.725' 14-1/2'TBG, 12.6#,13-CR.0152 bpf,D=3.958" 14037' i I 14038° H 4-1/2'WLEG,D=4.00' 14037' J I 7-5/8"X 4-1/2"BAKER ZXP PKR,D=4.875" I IBKR TACK SLV W/6'EXT/SEALS,D=5.75" —j 14048' I-- 14037' --I ELWD TT LOGGED 09/12/98 7-5/8'X 4-1/2"BKR FI MC LNR HGR,D=4.938' H 14055' __) L 7-5/8'CSG,29.7#,L-80,0=6.875' —1 14200' _A ■ FERFORATDN SUMMARY REF LOG: SPERRY-SUN MWD/GR ON 03/11/98 ANGLE AT TOP PEE: 52°@ 14585' ` PBTD —I 16402' I Note:Refer to Production DB for historical pert data SQE SPF MT3tVAL Opn/Sqz SHOT SOZ 2-1/2' 6 14585-14605 0 11/08/13 2-3/4" 4 16050-16180 0 03/16/98 •■■� • 2-3/4' 4 16200- 16400 0 03/16/98 • RESTRICTION CTU-COULDN'T —I 16301' ``.:v GET DEEPER W/2"ASSY 08/23/02 4-1/2'LNR,12.6#,13-CR-80,.0152 bpf,D=3.958' H 16490' DATE REV BY 00144 ,I TS DATE REV BY COM ENTS FRUDHOE BAY UNIT 11/15/97 ORIGINAL COMPLETION 04/03/03 JJ/KAK GLV GO WELL: P2-33B 03/17/98 FIG SIDETRACK 01/12/07 BSEIPAG WELL ANGLE CORRECTIONS PERMIT No:'1972310 10/06/01 CWKAK CORRECTIONS 02/18/11 MB/JMO ADM)SSSV SAFEIY NOTE API No: 50-029-22812-02 10/31/01 WE/1P SURF LOC CORRECTIONS 11/11/13 DHS/JMD ADPERFS(11/08/13) SEC 14,T12N,R14E,231'FT_&1365 AM. 08/29/02 fTP 'RESTRICTION CTU 01/30/03 JGWtlh GLV UPDATE BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519-6612 May 20, 2012 AUG k.0 t. 2•°12' Mr. Jim Regg n2 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, G( Mehreen Vazir BPXA, Well Integrity Coordinator • III BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations Po rY P� 10-404 � GPMA PM -2 Date: 04/302012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2 -04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2 -31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA -> P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2-41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2 -42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2 -43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2 -46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2-47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS ~.E~E~I\IIEi~~~-~~~ ~ ~. 3 ~00~ 1. Operations Abandon ~ Repair Weil ~ Plug Perforations ~ Stimulate~ Ot~~ ~L&/~ QA ~1115 Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ ~~~~~~r~~~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Dev~elopment ~ - Exploratory ~ 197-2310. 3. Address: P.O. Box 196612 Stratigraphic r Service ]~~' 6. API Number: Anchorage,AK 99519-6612 50-029-22812-02-00- 7. KB Elevation (ft): 9. Well Name and Number: 47.5 KB , P2-33B - 8. Property Designation: 10. Field/Pooi(s): ADLO-365548 - PRUDHOE BAY Field/ PT MCINTYRE OIL Pool 11. Present Well Condition Summary: Total Depth measured 16491 ~ feet Plugs (measured) TAGGED PBTD 16300' 1/30/01 true vertical 8978.74 ~ feet Junk (measured) None Effective Depth measured 46300 feet true vertical 9028 feet Casing Length Size MD ND ~~ ' Burst Colla se P Conductor 110 20" Surface - 110 Surface - 110 Surface 7847 10-3/4" 45.5# NT-80 Surface - 7894 Surface - 4940 5210 2480 Production 14154 7-5/8"29.7# L-80 Surface - 14154 SurFace - 14201 6890 4790 Liner 2458 4-1/2" 12.6# 13CR-80 Surface - 16490 SurFace - 16490 8430 7500 ~'`~ ' ' E +~~ ~ U L ~ ~~k~~~~'"~.w; L1VL t; ' 'Y , ~. , .~ Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ Trus Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR SURFACE - 14037' 0 0 - Packers and SSSV (type and measured depth) 7-5/8"X4-1/2" TIW HBBP-T-PKR 13983' 7-5/8"4-1/2" BAKER ZXP PKR 14037' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 784 1024 5223 288 Subsequent to operation: 734 958 4890 282 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ De~elopment ~- Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas 1~~ WAG ~` GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer ~~~F Signature ~ Phone 564-4944 Date 7/10/2009 / Form 10-404 Revised 04/2006 ~~L~ ~ ~~~~` Submit Original Only ;i~r~ P2-33B 197-231 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P2-33B 3/13/98 PER 16,050. 16,180. 9,054.4 9,050.44 P2-33B 3/13/98 PER 16,200. 16,400. 9,048.15 9,002.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FfL FtLL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ . P2-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/1/2009 CTU # 6 1.75" CT ( Interact Publishing ) Job Scope: Scale Removal Rig up unit MU tools PT RIH w/ 3.70" Turbo mill and motor, 15,790' kicked motor on to minimal motor work, made 2 Geo sweeps while milling. Pad OP notified. ''"''Job complete"** FLUIDS PUMPED BBLS 15 GEO VIS 653 XS KCL 34 50/50 METH 702 Total rm~ ~T~m~ UND~ Tms COV~ n,~S' · BEEN ON' OR JANUARY 03 2.001 PL E W M ATE IA L U N D ER TH IS M ARK ER C:LORgI~ILM. DOC ~ ' . r . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __X Exploratory__ Stratig raph lc__ Service__ 4. Location of well at surface 229' FNL, 3915' FEL, Sec. 14, T12N, R14E, UM At top of productive interval 4517' FNL, 634' FEL, Sec. 1, T12N, R14E, UM At effective depth (asp's 681607, 5998354) (asp's 690003, 6004838) At total depth 2700' FNL, 531' FEL, Sec. 1, T12N, R14E, UM (asp's 690060, 6006657) 12. Present well condition summary Total depth: measured true vertical 16491 feet 8979 feet Plugs (measured) 6. Datum elevation (DF or KB feet) RKB 47.2 feet 7. Unit or Property name Point Mclntyre Unit 8. Well number P2-33B 9. Permit number / approval number 197-231 10. APl number 50-029-22812-02 11. Field / Pool Point Mclntyre Oil Pool Tagged PBTD @ 16300' MD on 1/30/2001. Effective depth: measured 16300 feet true vertical 9028 feet Junk (measured) Casing Length Size Conductor 11 0' 20" Surface 7847' 1 0-3/4" Production 14154' 7-5/8" Liner 2458' 4-1/2" Cemented Measured Depth True Vertical Depth 260 Sx AS 110' 11 0' 1770 Sx CS III & 960 Sx Class G 7894' 4940' 136 Sx Class G 14201' 8671' 466 Sx Class G 1 6490' 8979' Perforation depth: measured 16050'- 16180'; 16200'- 16400'. true vertical 9054' - 9050'; 9048' - 9002'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr-80 Tubing @ 14038' MD. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" TIW HB-BP-T Hydroset Packer @ 13983' MD. 4-1/2" Camco BAL-0 SVLN @ 2159' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation5~5~2001 Subsequent to operation5~30~2001 Representative Daily Average Production orlniection Data OiI-Bbl Gas-Mcr W~er-Bbl 246 389 4859 1119 728 5823 Casing Pressure Tubing Pressure 776 780 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true a, nd correct to the best of my knowledge. Signed ~--"~"~ '~~ Title: PT Mac Surveillance Engineer Gordon Kidd Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 · P2-33B DESCRIPTION OF WORK COMPLETED FB ACID STIMULATION TREATMENT Date Event Summary 5/22/2001' 5/23/2001' 5/28/2001' Performed a tubing pickle as follows: MIRU. PT'd equip to 3800 psi. Loaded IA w/5 bbls of Methanol, followed by 215 bbls of Crude, followed by 10 bbls of Diesel. Pumped FB the following fluid schedule: (a) 2.5 bbls 60/40 Methanol Water @ 1.0 bpm, followed by (b) 13 bbls 50/50 Diesel / Xylene @ 2.0 bpm, followed by (c) 25 bbls 10% HCl w/additives @ 2 - 4 bpm, followed by (d) 183 bbls Crude @ 2-4 bpm, followed by (e) 7 bbls Diesel, followed by (f) shutdown. Secured well f/RD. Placed well BOL w/GL for 500 bbl flowback & test. Performed 8.6 hr well test: Oil = 233 bpd, FM gas = 126 MSCFD, Water = 1613 bpd, & FTP = 1093 psi. Performed a FB Acid Wash Stimulation as follows: MIRU. PT'd equip to 4000 psi. Loaded IA w/5 bbls of Methanol, followed by 215 bbls of Crude, followed by 5 bbls of Diesel. Pumped the following fluid schedule across the open perforations f/: 16050' - 16180' MD (Kuparuk Zone) 16200'- 16400' MD (Kuparuk Zone) Pumped: (a) 5 bbls Neat Methanol Water Spear @ 1.0 bpm, followed by (b) 48 bbls 7.5% HCl w/additives @ 2.4 bpm, followed by (c) 5 bbls Neat Methanol Water Spear, followed by (d) 244 bbls Crude displacement @ 3.5 bpm, followed by (e) Shutdown. ISlP = 1100 psi. Left well shut in for 4 hr soak. RD equip. Placed well BOL & obtained a representative welltest. Page 1 - ll-C0mphan e Report File on Left side of folder 197-231-0 pOINT McINT~ .......... P2"~3'B ........................ 50""029-22812'02 ..... ARCO MD 167_9.1 TVD 08979_. ~_.C.-o'mmpletion Date: 3/17/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/I) D 8405 kq<~ SPERRY MPT/GR/EWR4 OH 4/15/98 4/18/98 ~L DGR/CN?/SLD-MD 7934-15120 OH 12/23/97 12/24/97 P /L DGR/CNP/SLD-TVD ~A 5858-9234(/'L OH 12/23/97 12/24/97 DGR/EWR4-MD L 7934-15120 OH 12/23/9712/24/97 L DGR/EWR4-MD L 14200-16491 OH 4/22/98 4/22/98 <~t~q¥)~h~L D G R/E W R4-TV D , ~,~ L~INALt~58-92348709-8979 OH 12/23/97 12/24/97 DGR/EWR4-TVD , ~,i,AL' OH 4/22/98 4/22/98 R DIR SRVY- ~__ SP~ 14250.-16491. OH 4/3/98 4/22/98 Daily Well Ops '5_,/t/~(~ -3//)~/c{0" Are Dry Ditch Samples Required? yes ~.~knd Received? Was the well cored? yes ~--~--- Analysis Description Receiv_,...~~~' ~S'-~i~aple~' Comments: Tuesday, April 04, 2000 Page i of 1 f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service ~lj~a*. 60tls, ~;0rnw~. (~ Oil [~ Gas r-~ Suspended I-~ Abandoned [--1 Service ,atTciToi.ag~ ..... 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-231 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 r--:. .. 50-029-22812-02 4. Location of well at surface "~/~/~"-,~L. - : i~~i 9. Unit or Lease Name 231' SNL, 1365' EWL, SEC. 14, T12N, R14E, UM - . Point Mclntyre At top of productive interval ~ 10. Well Number At total depth ~ .. ~ .'.'. T" ;~ 11. Field and Pool 2584' NSL, 4738' EWL, SEC. 1, T12N, R14E, UM Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Plan RTE = 47.2I ADL 365548 1~. Date Spudded3/2/98 113' Date T'D' Reached t 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' N°' °r C°mpleti°ns3111/98 3117~98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 16491 8979 FTI 16402 9002 FTI [~]Yes I--INoI 2159' MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/RES 23. CASINGt LINER AND CEMENTING RECORD CASING I SETTING DEPTH HOLE SIZEI WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# H-40 36' 110' 30" 260 sx Arctic Set (Approx.) '10-3/4 45.5# L-80 34' 7894' 13-1/2" 1770 sx Coldset III, 960 sx 'G' .... 7-5/8" 29.7# L-80 31' 14201' 9-7/8 136 sx Class 'G' .... 4-1/2" 12.6# 13CR80 14032' 16490' 6-3/4" 466 sx Class 'G' .... ...... 1 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#. 13CR80 14038' 13983' MD TVD MD TVD 16050'-16180' 9054'- 9050' 16200'-16400' 9048'-9002' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 147 bbls diesel ............ .,,"'% ~ I ~ ! I~ I /t. I 27. PRODUCTION TEST I i W I i I\i/A I Date First Production j Method of Operation (Flowing, gas lift, etc.) '"' March 29, 1998 I Flowing Date of Test !Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF :WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 SUbmit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. K-10 14555' 8932' HRZ 14610' 8966' Top Kaparuk 14638' 8981' Base Kaparuk 16450' 8990' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that i t to the best of my knowledge Signed Dan St°'t~P2-33B/'~- r/~__ _~?.//', ."~~ .... / Title Drillin~l Superintendent Date ,-~/~_~,¢;~~ 97-231 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL LOG TRANSMITTAL To: State of Alaska April 22. 1997 Alaska Oil and Gas ConserYation Comm. Attn.: Lori Tavlor 3001 Porcupine Dr. Anchoratze. Alaska 99501 ,~/ RE: MWD Formation Evaluation Lo_os P2-33B. AK-N~M-80146 The technical data listed below is beinu submitted herewith. Please address anv t~roblems or concerns to the attention of.' .Ali Turker. SDerrv-Sun Drillinz Services. 5631 Silverado Wav. #G. Anchorage. ,AK 99518 2" x 5" TVD Resistivitv& Gamma Rav Lo~s: 50-029-22812-00 1 1 Blueline 1 Folded Ser~ia . / / 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. Shared Services Drilling Point Mclntrye Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Sperry-Sun Drilling Services Local Coordinates Northings Eastings (ft) (ft) Survey Report for P2-33B , Your Ref: API-500292281202 Alaska State Plane Zone 4 Point Mclntyre Pad 2 14250.00 51.780 42.910 8662.40 8709.90 6048.28 N 8402.68 E 14262.47 50.280 42.310 8670.24 8717.74 6055.41 N 8409.24 E 14295.77 46.380 38.010 8692.38 8739.88 6074.39 N 8425.30 E 14327.43 41.560 33.350 8715.17 8762.67 6092.21 N 8438.14 E 14359.15 38.560 30.000 8739.44 8786.94 6109.56 N 8448.87 E 14391.02 38.670 28.640 8764.35 8811.85 , 6126.91 N 8458.61 E 14422.71 39.020 28.740 8789.03 8836.53 6144.34 N 8468.15 E 14454.47 39.720 30.010 8813.58 8861.08 6161.90 N 8478.03 E 14486.06 42.860 31.040 8837.31 8884.81 6179.85 N 8488.62 E 14516.26 45.910 33.090 8858.90 8906.40 6197.74 N 8499.85 E 14547.88 48.730 34.220 8880.33 8927.83 6217.08 N 8512.73 E 14580.89 51.490 33.830 8901.50 8949.00 6238.07 N 8526.90 E 14585.00 52,073 33.535 8904.04 8951.54 6240.76 N 8528.69 E 14612.54 56.000 31.670 8920.21 8967.71 6259.54 N 8540.69 E 14644.28 60.700 30.310 8936.86 8984.36 6282.70 N 8554.59 E 14676.11 64.910 27.430 8951.41 8998.91 6307.49 N 8568.24 E 14707.93 68.990 25.400 8963.86 9011.36 6333.71 N 8581.26 E 14739.54 72.070 21.360 8974.40 9021.90 6361.06 N 8593.07 E 14771.21 75.150 16.260 8983.34 9030.84 6389.80 N 8602.85 E 14803.00 78.400 10.460 8990.62 9038.12 6419.90 N 8609.99 E 14834.83 80.600 7.500 8996.42 9043.92 6450.81 N 8614.87 E 14866.23 81.340 4.810 9001.35 9048.85 6481.64 N 8618.19 E 14897.81 81.830 3.610 9005.97 9053.47 6512.79 N 8620.49 E 14931.31 84.030 2.260 9010.10 9057.60 6545.99 N 8622.19 E 14962.86 87.660 1.450 9012.38 9059.88 6577.43 N 8623.21E 14994.43 89.560 1.850 9013.15 9060.65 6608.98 N 8624.11 E 15026.21 91.230 2.420 9012.93 9060.43 6640.74 N 8625.30 E 15058.14 91.970 1.490 9012.04 9059.54 6672.63 N 8626.39 E 15089.73 92.440 1.500 9010.82 9058.32 6704.19 N 8627.21 E 15121.67 88.770 359.210 9010.48 9057.98 6736.12 N 8627.41 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 6004604.39 N 689859.80 E 7285.71 6004611.68 N 689866.19 E 12.597 7293.79 6004631.04 N 689881.77 E 15.168 7315.04 6004649.17 N 689894.18 E 18.328 7334.64 6004666.78 N 689904.49 E 11.644 7353.46 6004684.35 N 689913.80 E 2.685 7372.11 6004702.02 N 689922.92 E 1.122 7390.82 6004719.80 N 689932.37 E 3.360 7409.70 6004738.01 N 689942.52 E 10.170 7429.09 6004756.17 N 689953.30 E 11.159 7448.51 6004775.82 N 689965.71 E 9.297 7469.63 6004797.15 N 689979.37 E 8.410 7492.57 6004799.88 N 689981.09 E 15.274 7495.51 6004818.94 N 689992.63 E 15.274 7515.93 6004842.43 N 690005.97 E 15.250 7540.97 6004867.55 N 690019.01 E 15.481 7567.59 6004894.07 N 690031.39 E 14.101 7595.52 6004921.70 N 690042.53 E 15.495 7624.38 6004950.68 N 690051.61 E 18.253 7654.30 6004980.94 N 690058.01 E 20.490 7685.14 6005011.96 N 690062.14 E 11.462 7716.43 6005042.86 N 690064.72 E 8.783 7747.40 6005074.06 N 690066.25 E 4.067 7778.53 6005107.29 N 690067.15 E 7.689 7811.59 6005138.75 N 690067.40 E 11.787 7842.81 6005170.31 N 690067.54E 6.150 7874.11 6005202.08 N 690067.95 E 5.553 7905.66 6005234.00 N 690068.27 E 3.721 7937.34 6005265.56 N 690068.32 E 1.488 7968.64 6005297.49 N 690067.74 E 13.543 8000.20 Comment Tie-On Survey Window Point ORIGINAL Target: 14585.00ff MD, 8951.54ft TVD, 689981.09 E, 6004799.88 N Continued... 3 April, 1998 - 10:26 - 2 - DrillQuest Shared Services Drilling Point Mclntrye Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 15153.06 87.630 358,160 9011.47 9058.97 15186.26 90.000 358.860 9012.16 9059.66 15218.14 90.620 359.390 9011.98 9059.48 15249.63 88.680 357.980 9012.18 9059.68 15281.42 88.070 359.040 9013.08 9060.58 15313.10 90.180 359.740 9013.56 9061.06 15344.92 89,210 357,630 9013.73 9061.23 15376.53 90.000 359,210 9013.95 9061.45 15408.32 89.910 357.980 9013.97 9061.47 15441.63 90.970 358,510 9013.72 9061.22 15473.44 91.580 358.510 9013.01 9060.51 15505.42 92,280 358.860 9011.93 9059.43 15536.75 92.990 359.040 9010.49 9057.99 15568.67 93.340 358.680 9008.73 9056.23 15600.36 93.780 359.740 9006.76 9054.26 15633.62 94.040 1.140 9004.50 9052.00 15659.89 94.220 3.080 9002.60 9050.10 15691.62 95.120 3,460 9000.02 9047.52 15723.87 93.040 4.060 8997.73 9045.23 15755.08 91.230 3.710 8996.56 9044.06 15786.78 90.060 3.260 8996.21 9043.71 15818.85 88.550 3.180 8996.60 9044.10 15850.48 88.950 3.190 8997.29 9044.79 15883.45 88,460 2.260 8998.03 9045.53 15915.02 86.220 2.680 8999.50 9047.00 15947.10 84.760 2.680 9002.02 9049.52 15978.41 85.680 2.040 9004.63 9052.13 16011.19 88.280 3.300 9006.35 9053.85 16043.43 89,940 2.860 9006.85 9054.35 16074.93 90.590 2.130 9006.71 9054.21 Survey Report for P2-33B Your Ref: API-500292281202 6767.49 N 8626.69 6800.66 N 8625.83 6832.54 N 8625.34 6864.02 N 8624.62 6895.79 N 8623.79 6927.46 N 8623.45 6959.27 N 8622.72 6990.86 N 8621.85 7022.64 N 8621.07 7055.94 N 8620.05 7087.73 N 8619.22 7119.68 N 8618.49 7150.97 N 8617.92 7182.84 N 8617.28 7214.46 N 8616.85 7247.64 N 8617.10 7273.82 N 8618.07 7305.40 N 8619.87 7337.49 N 8621.98 7368.61 N 8624.09 7400.25 N 8626.02 7432.26 N 8627.82 7463.84 N 8629.58 7496.76 N 8631.15 7528.27 N 8632.50 7560.21 N 8634.00 7591.39 N 8635.28 7624.08 N 8636.81 7656.27 N 8638.54 7687.74 N 8639.91 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 6005328.83 N 690066.26 E 4.936 8031.07 6005361.98 N 690064.59 E 7.443 8063.71 6005393.83 N 690063.33 E 2.559 8095.12 6005425.28 N 690061.85 E 7.616 8126.10 6005457.02 N 690060.25 E 3.846 8157.35 6005488.67 N 690059.14 E 7.017 8188.58 6005520.46 N 690057.64 E 7.298 8219.88 6005552.02 N 690056.00 E 5.588 8250.96 6005583.77 N 690054.45 E 3.879 8282.23 6005617.03 N 690052.62 E 3.558 8314.95 6005648.79 N 690051.02 E 1.918 8346.22 6005680.72 N 690049.51 E 2.447 8377.67 6005711.99 N 690048.17 E 2,338 8408.49 6005743.83 N 690046.77 E 1.572 8439.86 6005775.43 N 690045.56 E 3.616 8471.03 6005808.61 N 690045.01 E 4.272 8503.85 6005834.81 N 690045.34 E 7.397 8529.86 6005866.42 N 690046.37 E 3,077 8561.33 6005898.55 N 690047.70 E 6.711 8593.36 6005929.71 N 690049.06 E 5.907 8624.42 6005961.39 N 690050.22 E 3.954 8655.98 6005993.44N 690051.24 E 4.715 8687.88 6006025.05 N 690052.23 E 1.265 8719.34 6006058.00 N 690052.99 E 3,188 8752.11 6006089.53 N 690053.59 E 7.219 8783.44 6006121.50 N 690054.31 E 4.551 8815.22 6006152.69 N 690054.83 E 3.575 8846.22 6006185.42 N 690055.56 E 8.812 8878.75 6006217.64 N 690056.51E 5.327 8910.81 6006249.13 N 690057.12 E 3.103 8942.11 Comment Alaska State Plane Zone 4 Point Mclntyre Pad 2 Continued... 3 April, 1998 - 10:26 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for P2-33B Yo ur Ref: A PI-500292281202 Shared Services Drilling Point Mclntrye Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) Comment 16106.58 90.880 1.850 9006.30 9053.80 7719.37 N 8641.01 E 16138.38 91.580 0.970 9005.62 9053.12 7751.15 N 8641.79 E 16170.12 94.920 4.310 9003.82 9051.32 7782.80 N 8643.25 E 16201.64 97.200 2.200 9000.49 9047.99 7814.09 N 8645.03 E 16233.28 101.600 2.380 8995.33 9042.83 7845.27 N 8646.28 E 16265.24 102.500 2.380 8988.65 9036.15 7876.50 N 8647.58 E 16297.13 103.540 2.550 8981.47 9028.97 7907.54 N 8648.91 E 16330.15 104.330 2.200 8973.52 9021.02 7939.56 N 8650.24 E 16362.25 105.030 0.970 8965.38 9012.88 7970.60 N 8651.10 E 16393.16 105.380 0.790 8957.28 9004.78 8000.42 N 8651.56 E 16415.00 105.380 0.790 8951.48 8998.98 8021.48 N 8651.85 E 16491.00 105.380 0.790 8931.33 8978.83 8094.75 N 8652.86 E 6006280.78 N 690057.45 E 1.274 8973.52 6006312.57 N 690057.46 E 3.536 9005.04 6006344.24 N 690058.15 E 14.869 9036.52 6006375.56 N 690059.17 E 9.830 9067.71 6006406.77 N 690059.65 E 13.918 9098.70 6006438.02 N 690060.19 E 2.816 9129.75 6006469.08 N 690060.77 E 3.302 9160.62 6006501.13 N 690061.32 E 2.604 9192.46 6006532.18 N 690061.43 E 4.301 9223.25 6006562.00 N 690061.16 E 1.264 9252.78 6006583.06 N 690060.94 E 0.000 9273.62 6006656.34 N 690060.17 E 0.000 9346.15 P2-33B top kuparuk Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 8.980° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16491.00ft., The Bottom Hole Displacement is 11848.92ft., in the Direction of 46.909° (True). Alaska State Plane Zone 4 Point Mclntyre Pad 2 3 April, 1998 - 10:26 - 4 - DrillQuest WELL LOG TRANSMITTAL To: State of Alaska .Alaska Oil and Gas Conservation Comm. .'Attn.' Lori Tavlor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs April 15.1998 AK-Nffvl-80146 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a sired copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Wav. #G. :Anchorage, AK 99518 I LDWG formatted Disc with verification listing. APl#: 50-029-22812-02 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries. Inc. Operator ARCO Performance Enquiry Report Date 18:56, 05 May 98 Page The analysis is from - 09:30, 13 Oct 97 - to - 21:30, 24 Oct 97 Programs in Result Table: P2-33 Well Type P2-33 Event P2-33 Event Time From Time To Duration Description E.M.W.(equivalent mud weight) 09:30, 13 Oct 97 09:30, 13 Oct 97 0 hr 0 min Obtained leak off 12.2 21:30, 24 Oct 97 21:30, 24 Oct 97 0 hr 0 min Obtained required level of integrity 12.6 Hole Size MDR 9-7/8 6-3/4 Facility Date/Time O1 Mar 98 02 Mar 98 03 Mar 98 04 Mar 98 05 Mar 98 06 Mar 98 07 Mar 98 08 Mar 98 Pt Mac 2 Progress Report Well P2-33B Rig Doyon 14 Page Date Duration Activity 00:00-04:00 04:00-04:30 04:30-06:00 06:00-12:00 12:00-13:00 13:00-14:00 14:00-22:00 22:00-22:30 22:30-02:30 02:30-06:00 06:00-09:00 09:00-10:00 10:00-15:30 15:30-17:30 17:30-18:30 18:30-22:30 22:30-23:15 23:15-04:00 04:00-05:15 05:15-06:00 06:00-21:30 21:30-22:15 22:15-22:30 22:30-03:30 03:30-04:30 04:30-06:00 06:00-11:15 11:15-12:15 12:15-13:30 13:30-06:00 06:00-06:00 06:00-08:30 08:30-09:00 09:00-09:30 09:30-11:00 11:00-11:30 11:30-12:00 12:00-12:15 12:15-12:45 12:45-13:45 13:45-14:15 14:15-14:45 14:45-18:30 18:30-19:00 19:00-21:00 21:00-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-06:00 06:00-17:30 17:30-18:00 18:00-18:30 18:30-19:00 4 hr 1/2 hr 1-1/2 hr 6 hr 1 hr 1 hr 8 hr 1/2 hr 4hr 3-1/2 hr 3hr 1 hr 5-1/2 hr 2 hr lhr 4 hr 3/4 hr 4-3/4 hr 1-1/4 hr 3/4 hr 15-1/2 hr 3/4 hr 1/4 hr 5 hr lhr 1-1/2 hr 5-1/4 hr 1 hr 1-1/4 hr 16-1/2 hr 24 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr lhr 1/2 hr 1/2 hr 3-3/4 hr 1/2 hr 2 hr 5 hr 1 hr 1-1/2 hr 1-1/2 hr 24 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr Rig moved 100.00 % Tested Hanger plug Rigged down Xmas tree Rigged up BOP stack Removed Kelly Rigged up Kelly Tested All functions Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 3000.0 ft Singled in drill pipe to 7160.0 ft (cont...) Serviced Block line 'Singled in drill pipe to 14108.0 ft Circulated at 14108.0 ft Tested Casing Drilled cement to 14220.0 ft Drilled cement to 14264.0 ft Drilled to 14295.0 ft Performed formation integrity test Drilled to 14300.0 ft Drilled to 14478.0 ft (cont...) Circulated at 14478.0 ft Flow check Pulled out of hole to 561.0 ft .Pulled BHA Made up BHA no. 2 .,R.I.H. to 12050.0 ft Serviced Block line R.I.H. to 14478.0 ft Drilled to 14590.0 ft Drilled to 14870.0 ft (cont...) Drilled to 14914.0 ft (cont...) Circulated at 14914.0 ft Flow check Circulated at 14914.0 ft Flow check Pulled out of hole to 13929.0 ft Flow check R.I.H. to 14200.0 ft Flow check Pulled out of hole to 12134.0 ft Flow check Pulled out of hole to 300.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 14200.0 ft Serviced Block line R.I.H. to 14916.0 ft Drilled to 14928.0 ft Drilled to 15470.0 ft (cont...) Drilled to 15693.0 ft (cont...) Circulated at 15693.0 ft Flow check Pulled out of hole to 14200.0 ft 1 O4 May 98 Facility Date/Time 09 Mar 98 10 Mar 98 11 Mar 98 12 Mar 98 13 Mar 98 Pt Mac 2 Progress Report Well P2-33B Page 2 Rig Doyon 14 Date 04 May 98 Duration Activity 19:00-19:15 19:15-00:00 00:00-01:15 01:15-01:30 01:30-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-11:00 11:00-11:30 11:30-12:00 12:00-15:30 15:30-16:30 16:30-17:30 17:30-19:30 19:30-06:00 06:00-06:00 06:00-07:30 07:30-08:30 08:30-08:45 08:45-09:30 09:30-11:00 11:00-12:15 12:15-12:30 12:30-13:00 13:00-18:30 18:30-20:30 20:30-21:00 21:00-22:00 22:00-22:30 22:30-23:15 23:15-23:30 23:30-03:00 03:00-03:45 03:45-04:00 04:00-06:00 06:00-07:15 07:15-07:30 07:30-14:30 14:30-15:45 15:45-16:00 16:00-17:30 17:30-21:15 21:15-21:30 21:30-22:00 22:00-23:30 23:30-00:00 00:00-02:00 02:00-04:00 04:00-04:30 04:30-05:15 05:15-06:00 06:00-06:15 06:15-08:00 1/4 hr 4-3/4 hr 1-1/4 hr 1/4 hr 4-1/2 hr 1/2 hr 1/2 hr 2hr 2hr 1/2 hr 1/2 hr 3-1/2 hr lhr lhr 2hr 10-1/2 hr 24 hr 1-1/2 hr 1 hr 1/4 hr 3/4 hr 1-1/2 hr 1-1/4 hr 1/4 hr 1/2 hr 5-1/2 hr 2 hr 1/2 hr 1 hr 1/2 hr 3/4 hr 1/4 hr 3-1/2 hr 3/4 hr 1/4 hr 2hr 1-1/4 hr 1/4 hr 7 hr 1-1/4 hr 1/4 hr 1-1/2 hr 3-3/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 2hr 1/2 hr 3/4 hr 3/4 hr 1/4 hr 1-3/4 hr Flow check Pulled out of hole to 200.0 ft Pulled BHA Retrieved Bore protector Tested BOP stack Tested BOP stack (cont...) Installed Bore protector Made up BHA no. 4 R.I.H. to 3339.0 ft Functioned Survey instruments Tested Kelly cocks R.I.H. to 14184.0 ft Serviced Block line R.I.H. to 15693.0 ft Circulated at 15693.0 ft Drilled to 15916.0 ft Drilled to 16490.0 ft (cont...) Drilled to 16491.0 ft (cont...) Circulated at 16491.0 ft Flow check Pulled out of hole to 14184.0 ft R.I.H. to 16491.0 ft Circulated at 16491.0 ft Flow check Circulated at 16491.0 ft Pulled out of hole to 1000.0 ft Laid down 375.0 ft of 4in OD drill pipe Pulled BHA Downloaded MWD tool Rigged down Drillstring handling equipment Rigged up Casing handling equipment Held safety meeting Ran Liner to 2430.0 ft (4-1/2in OD) Rigged down Casing handling equipment Held safety meeting Ran Tubing to 2-7/8in (2335.0 ft OD) Ran Tubing to 2335.0 ft (2-7/8in OD) (cont...) Held safety meeting Ran Drillpipe in stands to 14134.0 ft Circulated at 14194.0 ft Held safety meeting Ran Drillpipe in stands to 16491.0 ft Circulated at 16491.0 ft Held safety meeting Batch mixed slurry - 100.500 bbl Circulated at 16491.0 ft Functioned Liner hanger Circulated at 16395.0 ft Pulled Drillpipe in stands to 11500.0 ft Rigged down sub-surface equipment - Setting tools Pulled Drillpipe in stands to 8835.0 ft Serviced Block line Serviced Block line (cont...) Pulled Drill collar in stands to 2400.0 ft Facility Date/Time 14 Mar 98 15 Mar 98 16 Mar 98 17 Mar 98 Progress Report Pt Mac 2 Well P2-33B Page 3 Rig Doyon 14 Date 04 May 98 08:00-08:45 08:45-09:00 09:00-10:00 10:00-11:30 11:30-12:00 12:00-18:00 18:00-18:15 18:15-18:30 18:30-20:00 20:00-20:30 20:30-21:00 21:00-00:30 00:30-00:45 00:45-01:00 01:00-04:00 04:00-06:00 06:00-08:30 08:30-09:15 09:15-13:00 13:00-13:45 13:45-15:00 15:00-15:30 15:30-15:45 15:45-17:30 17:30-18:45 18:45-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-08:30 08:30-08:45 08:45-09:00 09:00-13:00 13:00-13:30 13:30-14:30 14:30-18:00 18:00-19:00 19:00-21:45 21:45-22:00 22:00-23:00 23:00-00:30 00:30-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-18:00 18:00-23:00 23:00-00:00 00:00-03:00 03:00-04:00 04:00-06:00 Duration 3/4 hr 1/4 hr 1 hr 1-1/2 hr 1/2 hr 6 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/4 hr 1/4 hr 3 hr 2hr 2-1/2 hr 3/4 hr 3-3/4 hr 3/4 hr 1-1/4 hr 1/2 hr 1/4 hr 1-3/4 hr 1-1/4 hr 5-1/4 hr 1/2 hr 1/2 hr lhr 1 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/4 hr 1/4 hr 4hr 1/2 hr 1 hr 3-1/2 hr 1 hr 2-3/4 hr 1/4 hr lhr 1-1/2 hr 4hr 1-1/2 hr 1/4 hr 1/4 hr 11-1/2 hr 5 hr lhr 3hr 1 hr 2hr Activity Rigged down Drillstring handling equipment Held safety meeting Pulled Tubing in stands to 2350.0 ft Ran Tubing in stands to 2350.0 ft Installed Tie back packer Ran Drillpipe in stands to 14030.0 ft Held safety meeting Circulated at 14000.0 ft Installed Setting tools Functioned Tie back packer Tested Tie back packer - Via annulus Functioned Setting tools Held safety meeting Tested Tie back packer - Via string Circulated at 16375.0 ft Circulated at 16375.0 ft Circulated at 16375.0 ft (cont...) Held drill (Kick (well kill)) Pulled Drillpipe in stands to 14400.0 ft Laid down 93.0 ft of Tubing Pulled Tubing in stands to 2300.0 ft Rigged up Handling equipment Held safety meeting Installed TCP Installed Retrievable packer Ran Drillpipe in stands to 13000.0 ft Held safety meeting Ran Drillpipe in stands to 16402.0 ft Perforated Bullhead well Circulated at 13800.0 ft Circulated at 13800.0 ft Circulated at 13800.0 ft (cont...) Held safety meeting Flow check Laid down 8100.0 ft of 4in OD drill pipe Functioned Kelly cocks Serviced Block line Laid down 5100.0 ft of 4in OD drill pipe Rigged down sub-surface equipment - Retrievable packer Laid down 2300.0 ft of Tubing Held safety meeting Rigged down sub-surface equipment - Gun assembly Serviced Top ram Tested Well control Rigged up Completion string handling equipment Rigged up Completion string handling equipment (cont...) Held safety meeting Ran Tubing to 7600.0 ft (4-1/2in OD) Ran Tubing to 11868.0 ft (4-1/2in OD) Tested SCSSSV Ran Tubing to 14038.0 ft (4-1/2in OD) Installed Tubing hanger Tested Tubing hanger Facility Date/Time Pt Mac 2 Progress Report Well P2-33B Rig Doyon 14 Page Date 06:00-08:30 08:30-09:30 09:30-10:00 10:00-11:00 11:00-11:15 11:15-11:30 11:30-13:00 13:00-14:30 14:30-15:30 15:30-16:30 16:30-19:00 19:00-20:00 20:00-21:00 21:00-06:00 Duration 2-1/2 hr lhr 1/2 hr 1 hr 1/4 hr 1/4 hr 1-1/2 hr 1-1/2 hr 1 hr lhr 2-1/2 hr 1 hr 1 hr 9 hr Activity Circulated at 14036.0 ft Tested Hydraulic packer Tested Hydraulic packer Tested Casing Functioned Other sub-surface equipment Installed Hanger plug Rigged down BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Freeze protect well - 147.000 bbl of Diesel Installed Hanger plug Serviced Wellhead primary components Rigged down Drillfloor / Derrick 4 04 May 98 OF:III_lING S E FI~./I I-- E S 03-Apr-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well P2-33B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 14,250.00' MD Window / Kickoff Survey: 14,262.47' MD Projected Survey: 16,491.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COM~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: ~907) 276-7542 Fcbruap,' 25. 1998 Steve Shultz Enginccring Super~,isor ARCO Alaska. Inc. POBox 196612 Anchorage, AK 99519-6612 Point Mclntvre P2-33B ARCO Alaska. Inc. Permit No. 97-231 Sur Loc: 231'SNL. 1365'EWL. Sec. 14. T12N. R14E. UM Btmholc Loc: 3033'SNL. 500'WEL. Sec. 1. T12N. R14E. UM Dcar Mr. Shultz: Encloscd is the approvcd rcviscd application for pcrmit to drill thc above rcfercnccd wcll. The provisions of thc original approvcd pcrmit datcd Dcccmbcr 19. 1997. arc in cffcct for this rcvision. Chairlnan BY ORDER OF THE COMMISSION dlf/Enclosurcs CC' Dcpartmcnt of Fish &Gamc. Habitat Section W/o cncl Department of Environmental Consen'ation w/o cncl STATE OF ALASKA AL,-~, ..aKA OIL AND GAS CONSERVATIO-c~-COMMISSION PERMIT TO DRILL ' 20 AAC 25.005 REVISED: 02/17/98 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas []Single Zone [] Multiple Zone i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 45' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365548 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 231' SNL, 1365' EWL, SEC. 14, T12N, R14E, UM Point Mclntyre At top of productive interval 8. Well Number Number U-630610 4520' SNL, 634' WEL, SEC. 1, T12N, R14E, UM P2-33B At total depth 9. Approximate spud date Amount $200,000.00 3033' SNL, 500' WEL, SEC. 1, T12N, R14E, UM 02/27/98 12. Distance to nearest property line113. Distance to nearest well" 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 377054, 3033'I No Close Approach 3601.1 16136' MD / 9037' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12275' Maximum Hole Angle 92° Maximum surface 3300 psig, At total depth (-I-VD) 8800' / 4350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade couPi"ing Length MD TVD MD TVD (include stage data) 6-3/4" 4-1/2" 12.6# 13CR80 NSCT 2086' 14050' 8585' 16136' 9037' 390 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 15120 feet Plugs (measured) true vertical 9230 feet Effective depth: measured 14120 feet Junk (measured) true vertical 8628 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset I (Approx.) 110' 110' Surface 7860' 10-3/4" 1769 sx Coldset III, 960 sx Class 'G' 7836' 4914' Intermediate Production Liner ,arforation depth: measured 0 RIG iN A L .~:L-,-?~ ', i:; true vertical ~8..Sk~ 0i~ ~:, '.";;;~s {::o~'~:-_: 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Greg Hobbs, 564-4191 Prepared By Name/Number: Kathy Campoamor, 564-5122 Steve Sh,.tz ..,.//',J /.(_M/C--" &//)./,t,_.~,/V~,\ Title Engineering Supervisor Date Commission Use Only Permit Number APl Number Approval Date I See cover letter 97-231 50-029-22812-02 12/19/97I for other requirements Conditions of Approval: Samples Required []Yes [~}4o Mud Log Required []Yes [~No Hydrogen Sulfide Measures ,~:r'es [] No Directional Survey Required I--lYes F-I No Required Working Pressure for BOPE [-]2M; []3M; ~5M; []10M; [-115M Other: ~;';';,:~i~,al $i[ined By by order of ~:~ Approved By 0avid W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 4icate I Well Name: ]Type of Well (producer or injector): I P2-33B I Producer I I ISurface Location: Target Location: Bottom Hole Location: 231' FNL 3914' FEL T12N, R14E, S14 4520' FNL 634' FEL T12N, R14E, S1 3033' FNL 500' FEL T12N, R14E, SI I AFE Number: 1 2C0108 I [Rig: I DOYON 14 ]Estimated Start Date: 12/27/98 I I Days to complete 19 [MD: 116,136' I ]TVD: 19037' brt [ I RTE: 145.0 ] Well Design (conventional, slimhole, etc.): [ Slirnhole. Drill-out Production Interval Formation Markers: Formation Tops MD TVD KOP/Colville Shale 14275 8725 Swap to 3 % 10.2-10.5 ppg GEM prior to drillout. K-10 14549 8912 HRZ 14585 8932 Kalubik 14602 8944 Kupamk 14616 8952 Build to high angle TD 16136 9037 TD Casingfru bing Program: Hole Size Csg/Tbg Wt/Ft Grade Conn Length Top Btm O.D. MDfrVD MDfrVD 6 3/4 4 1/2" 12.6# 13CR80 NSCT 2086' 14050/8585' 16136'/9037' Tubing 4 1/2" 12.6# 13CR80 NSCT 14008' 42'/42' 14050'/8585' Mud Program: IProduction Mud Propertiesi 3 % KCL Density (ppg) Plastic Vis Yield Point 10.2-10.5 8-25 15-25 GEM System 6 3/4" hole section 8-15 12-24 9.0-9.5 I Fluid Loss 10-12cc Cement Data: Liner Latex Slurry Liner Lead:Sxs/Wt/Yield Tail: Sxs/Wt~ield Comments 4.5" none 390/15.8/1.19 Class "G". Volume based on 150' Lap with 50% excess + 80' shoe. Logging Program: Open Hole Logs: Cased Hole Logs: DIR/GR/RES/DEN/NEU to TD GR/CBT (CBT max/be requested prior to running tubing). Weil Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: Maximum Hole Angle: Close Approach Well: 12275' MD 92 degrees None at this depth. Drilling and Completion Scope 1. MIRU on Suspended Well P2-33A. 2. Swap wellbore fluids to fresh 10.2-10.5 ppg 3% KCL GEM system. 3. Drill out cement and kick off on ST path at -14,275' MD. 4. Drill 6 3/4" production hole with LWD DI1UG~EN~U~S to- 16,136' MD. 5. Run and cement 4-1/2" 13CR liner. 6. Run 4-1/2" 13CR production tubing with 7 5/8"x4-1/2" packer, 4-1/2" SSSV, and 4-1/2"xl.5" GLMs. 7. Secure well, RDMO. Drilling Hazards/Contingencies · The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4350 psi at 8800' ss. Abnormally pressured formations are not expected in this well. · No major instances of lost circulation problems have occurred on Pt Mac 2 wells. · Gas cut mud has been experienced in the Colville shales in neighboring wells. A 10.1 ppg mud minimum mud required. Disposal · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. GH 2/17/97 revised Point Mclntrye Measured Depth (It) IncL AzJm. Sub-Sea Sperry-Sun Drilling Services Depth Northings Easlings (fl) (ft) 14275.00 52.055 43.131 8678.2:2 8725.42 14300.00 50.292 41.919 8693.79 8740.99 14400.00 43.389 36,362 8762.18 8809.38 14405.76 43.000 36.000 8766.3,8 88~3.58 144,..'...'...'...'.33.11 43.000 36.000 8786.38 8,833.~ 14500.00 47.6~,4 29.277 _ _8:I:~'L'~J.418,8,8~.61 14,.,.',',',',',~.63 51.34)6 25.008 88~5.00 8812.20 14581.53 53.8..39 22.362 8885.00 ~.20 14600.00 54..585 21.352 8895.80 8943.00 14602.07 54.669 21.2,10 8897.00 8944.20 14602.25 54.676 21.230 BE~97.10 8944.30 74616.12 55.8'93 20.419 8'905.00 8952.20 14700.00 63.348 'l 5,956 8~,47.41 6994.61 14800.00 72.3~0 11.3,.'.'.'.'.'3~ 8985.06 9032.26 14900.00 81.530 7.16~ 9007.61 905.4.~61 14992.25 90.000 3.500 9014.41. 9,0,61.61 150'(X).00 90.000 3...,500 9014.41 9061 15100.00 90.000 3.500 9014.41 15200.00 90.900 3.500 9014.41 9061.61 15292.25 9,0.0,00 3.50,0 9014.41 9061.61 15300.00 90.000 . 3.543,0 9014.41 9061.61 15.400.00 90.(:K)O 3.54~ 9,014.41 9061.61 15492.25 90.000 3.5(30 9014.41 9061.61 155,0,0.00 90.303 3.434 9014.39 9C~1.59 15550.48 92.276 3.006 9(313.26 :9,060.46 15600.0'0 92.276 3.006 9011.29 905~ .49 1570Q.00 92.276 3.006 9007.32 9054.52 15800.00 92.276 3.00,6 9003.35 9050.55 15900.00 92.276 3.(H:;,6 5999.3.8 9046.58 16000.00 92 ·276 3.0C,6 8,995.4.1 904.2.6 f Proposal Report for P2-33 - P2-336 Wp7 6062.6O N 8416.04 E 6077.01 N 8429.27 E 6133.39 N 8475.41 E 6136.57 N 8477.74 E 6151.66 N 8488.70 E 6191.73 N 8514.23 E 6224.63 N 8531.05 E · 6248.56 N 8541.54 E 6262.46 N 8547.11 E 6264.04 N 8547.73 E 6264.17 N 8547.78 E 6274.83 N 85,51.8~ E 6343.53 N 8574.29 E 6433.45 N 8596.OO E 6529.49 N 8611.5~B E 6620.99 N 8620.1 ! E 6628.73 N 8620.59 E 6728.54 N 8626.69 E 6828.36' N 8~.80 E 6920.43 N ,8638.43 E 6928.17 N .. 6638.90 E 702'7.98 N 8645.00 E 7120.06 N 8650.04 E 7127.80 N 8651.11 E 7178.16 N 8653.94 E 7227.59 N 8656.53 E 7327.38 N 8661.77 E 7427.16 N 8667.01 E 7526.95 N 8672.25 E 7626.73 N 8677.49 E Global Coordinates Dogleg Northi gs Eas~ngs Rate (~) (fl) (°~00~) 6004619.04 N 6,89872.81 E 6O04633.76 N 689885.~ E 60046~1.24 N 6899~.44 E ~.48 N 689932.69 E 6OO4709.83 N 6~9943.28 E 60047.50.51 N 6,B~967.63 E 6004783.81 N 6899~3.85 E 6004807.9~ N 689993.75 E 6004822.02 N 689'99~.99 E 6004823.61 N 68999~.56 E 6004.823.74 N 689999.61 E 6004834.49 N 69O003.40 E 600490:3.73 N 6g0024..19 E 6004,994.15 N 690043.70 E 6005090,54 N 690056.g5 E 6005162.2:2 N 690063.25 E 6005189.96 N 690063~ E 6005Z89.90 N 690067.21 E 6005:3,89.8:3 N 690070:69 E 6005,U~.02 N 690074.28 E .6005489.76 N 690074.57 E 6005589.69 N 690078.24 E 6005681.88 N 690081.6.4 E 6005689.63 N 69,0081.92 E 600574.0.06 N 690083.52 E 6005789.53 N 690084.~ E 60G5889.41 N 690087.73 E 6005989.29 N 690090.54 E 6006089.T7 N 690093.36 E 6006189.05 N 690096.17 E Vertical 10293.48 9.000 10312.00 9.000 1O379.54 8.000 10,.'.'.'.'.'.'.'.'.~. 12 0.000 10399.~ 10.000 10441.61 10.000 1047~t7 10.000 10492,86 6.000 10504.43 6.000 10505.72 6. D00 10505.83 lO.DO0 10514.50 10.000 10567.20 10.000 1O629.42 10.000 10689.21 10.000 10740.63 0.000 1074-4.76 0.000 10798.04 " 0.000 1O900.48 ' :- 0.000 :' 10904'~61 0.000 I o957.9O 0.0(K) 11007.06 4,.0(~ 11011.18 ¢.000 11037.86 0.000 11063.87 0.000 11116.38 0.000 11168.B9 0.000 1 ! 221.41 0.000 11273.92 Alaska State Plane Zone 4 Point Mclntyre Pad 2 FOR PEP, MITTING QNLY T~-on, Start Dir I) 8.C~O°/10Oft: 14.?.75.00tt MD, 8'725.32fl ']'VD ~ Dir, Sail ~ 4.3.000°: 14405.76fl MD, 8813.58ft 'rVD Start Drr O ! 0.000°/lO01t: 14433.1 lft MD, 8833.581t.'rVD Dir Ral~ ~ @ 6.000~llooft: 14581.53ft MD, 8932.20ft TVD HRZ KALU~iK Oir Rale Increase @ 10.000°/10Oft: 14602.25fl MD, 8944.30ft TVD KUPARUK Landir~ Pein[, End ENr, Sa~ @ 90.(]0(0°: 1.499r2,'ZSff MO, 9'061.61fi 'TVO Slart Dir @ 4.000°/100ft: 15492.25fl MD, 9061.61ff 'I'VD End Dir, Sail @ 9'2.276°: 15550.48ft MD, 9060.46ft 'T-VD ConStrued... February, 19<~8 - 9:53 ' 1'- Sperry-Sun Drilling Services Proposal Report for P2-33- P2-33B Wp7 Point Mclntrye Measured Sub-Sea Vertical Local Coonlinetes Depth Irtct. Azim. Depth Deplh I~orthings Easflngs 16100.00 92.276 3.006 8991.43 9038.63 7726.51 N 8682.73 E 16136.11 92.276 3.0~ 8990.00 9037.20 7762.54 N 8684.63 E ~obaJ Coordinetes Dogleg Nc~J~Jngs Easflngs Rate (~) ~) (°/~) 60{~:~8~.~ N 69(X)98.98 E 0.000 6006325.~ N 690100.00 E 1132.6.43 11345.413 All data is in feet unless otherwise stated. Directions and coordinates am relative to True North. Vertical depths are relative to Well Reference. Northings and Eastin~ are reletive to Well Reference. The Dogleg Severity is in Degrees per lOOft. Vertical Section is from Welt Reference and calculated along an Azimuth of 61.301 o (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16136.11ff., The Bottom Hole Displacement is 1 1648.17fl., in the Direction of 48.209° (True). ~' 10~.!~ - 16t36.1 lfl MD, 9(}37.:2OE TVD Alaska State Plane Zone 4 Point Mclntyre Pad 2 FOR PERM~I~ ONI:Y February, 199E - 9:53 ¢ -2- Drit/Quest ,t Shared Services DnTling Well: P2-33B WP'/ KC)P. PERMITTING ONLY SURFAC____._~E LOCATION PLOT DATE: 02/16/98 PROPOSAL TARGET SUMMARY I 41/2' (Jne~ - 161.t~.1 [ DrillQuest* ~::a~: ~lr~:~ = ~ · 10. End~,~ 0 ~: 1~ ~E~~ ~ 8.~1~: -- .. ~: t~ = ~ a~ ~ T~ N~ ~flOO~: 14~Sfl 00'~10C~: 14581..53fl MD. 89~2.213'1TVD ~.'F6~ MD. ~13.Salt TVD 14275.1Z)11 laB, ~725..I1:2~ ZRfD TREE: 4 1/16"- 5M Chrome P2-33 B ~-~ = ~.~' WELLHEAD: 11" x 11" - 5M FMC GL-SL = 11.6' ~ioi i li~----~o~-~~ooo ,11 _ BTC Max Angle: 91° @ 15,165' · · .5" GLM's TBD 4-1/2" 13Cr 12.61b Tubing · ~ I~ ZXP Packer BAKER HMC Hanger I',' 14,050' II 114i2 oo, 1~ PBTD 4-1/2" 13Cr 12.61b 16,136' Cemented Liner i Date Rev By Comments, Point Mclntyre 12/1/97 GH Proposed completion WELL: P2-33~ i i Shared Services Drilling spenr', -sun WELL LOG TRANSMITTAL To' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 December 23, 1997 RE: MWD Formation Evaluation Logs P2-33A, AK-MM-70286 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 P2-33A: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22812-01 2" x 5" TVD Resistivity & Gamma Ray Logs' 50-029-22812-01 2" x 5" MD Neutron & Density Logs' 50-029-22812-01 2" x 5" MD Neutron & Density Logs' 50-029-22812-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 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 December 19, 1997 Steve Shultz Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Point Mcln~'re P2-33B ARCO Alaska. Inc. Permit No. 97-231 Sur. Loc. 23 I'SNL, 1365'EWL, Sec. 14, T12N, R14E, UM Btmnhole Loc. 3589'SNL, 4568'WEL, Sec. 06, T12N. R15E. UM Dear Mr. Shuitz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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 ~vith 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA'OqL AND GAS CONSERVATION COM-~"I~IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 45' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365548 ~,. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 231' SNL, 1365' EWL, SEC. 14, T12N, R14E, UM Point Mclntyre At top of productive interval 8. Well Number 4551' SNL, 612' WEL, SEC. 01, T12N, R14E, UM P2-33B t;~,.~ ~. Number U-630610 At total depth 9. Approximate spud date 3589' SNL, 4568' WEL, SEC. 06, T12N, R15E, UM ~1~..~,~'"/ ~ Amount $200,000.00 :~'2. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 377054, 3589'I No Close Approach 3601.1 15885' MD / 9048' 'I'VD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12275' Maximum Hole Angle 91° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 6-3/4" 4-1/2" 12.6# 13Cr80 NSCT 1885' 14050' 8585' 15885' 9048' 274 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 15120 feet Plugs (measured) true vertical 9230 feet Effective depth: measured 14120 feet Junk (measured) true vertical 8628 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset I (Approx.) 110' 110' Surface 7860' 10-3/4" 1769 sx Coldset III, 960 sx Class 'G' 7836' 4914' Intermediate Production Liner RECEIVED Perforation depth: measured DEC - 1997 true vertical Naska 011 & Gas Cons. Oommissior~ Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 ,AAC 25.050 Requirements Contact Engineer Name/Number: Greg Hobbs, 564-4191 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify t hat t he~ is ~e anc~ correct to the best of my knowledgesig ned ,/'~~ Steve Shultz (' Title Senior Drilling Engineer Date ',4 Commission Use Only ~/ / Permit Number APl Number ApDroval Date I See cover letter ?.~-~__._~/ 50-029-22812-02 /~/¢"¢'~I for other requirements Conditions of Approval: Samples Required []Yes ~ No Mud Log Required []Yes J~No Hydrogen Sulfide Measures ~lYes I--INo Directional Survey Required [X1Yes [--I No Required Working Pressure for BOPE []2M; []3M; ~].5M; I--I 10M; [] 15M Other: Original Signed By by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate OCT 23 05:59PM SHRRED SERVICES DRILLIMG ALASKA bi.-' AND GAS CONSERVATION COMMIb]~ION APPLICATION FOR SUNDRY APPROVAL Type of Request: F- Abandon I~ aUSl~e~d [] Plugging ~'~ Time F.x~enslon [] Perforate ~ AIt§r Casing [] Re~air well [~ Pull Tubing [] Variance [] Other ~ Change Approved Program []Operation Shutdown [] Re-Ente~ Suspended Well [],~flmulate 2, Name of Operator ARCO Alaska Inc, 3. Address P.O. Box 196612, Anchorage, Alaaka 9951g-6612 4, Location of well at surface 231' SNL, 1365' EWL, SEC. 14, T12N, R14E, UM At top of productive interval N/A At effective depth 498' NSL, 1841' EWL, SEC. 8, T12N, R15E, UM At total depth $38' NSL, 1911' EWL, SEC. 87 T13N~ R15E~ UM 5. Tyl3e of well: ~ Development I--] Exploratory [] Stratigraphic .i-]Service H_[gh Angle Completion 6. Datum Elevation (DF or KB) Plan KBE = 45' 12, Present well condition summary Total depth: measured 16005 true vertical 8602 Effective depth: measured 15912 true vertical 8557 feet Pluga (meaaure¢l) feet feet Junk (measurecl) feet Casing Length Size 80' 20" 7860' 10-3/4" 1598g' 7-5/8" Structural Conductor Surface Intermediate Production Liner 7, Unit or Property Name Point Mclntyre 8. Well Number P2 9. Permit Numbe~' 97-178 10, APl Number 50-02g-22BJ_2 ..... 11, Field and Pool Point Mci re ................. .... . L- L - _IJ_L[I ~-~- .... Cemented \ / MD TVD~ 260 sx Arc, ticset (Approx,) 1769 sx Coldset III, 960 sx 'G' 310 sx Class '(3' 110' 110' 7894' 4~18' 15992' 8595' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A ORIGINAL Packera and 888V (type and measured depth) N/A 3. Attachments [] Descri~ion summary of pmpoaal [] Detailed operations program [] BOP ~ketch 4. Estimated date for commen~ing operation O~ober 24. 1997 16, If proposal was verbally approved Blair Wonclzell Name of approver . ceft~act Engi~eer Narne/Numbe~: Gre~ Hobby, ~64.41~1 L 15. Status of well classifications as: I~ Oll [~ Gas [] ~uspended 10/23/97 Service Date approved I .... Pn~l ~, NamelNurnbe~ Ka~y Cernpo~rnor, ~4.B1~. signecl s~,v, snu!? _, J~/_,x,g. Title $.enior Drillinp Engineer Date Commlaalon Use On~ l~a I Ilia .......... I J, I Condltlone of Approval:' Notify Commissio~ ~o rep~sentatlve m~y witness I Approval No~~_/_ Plug integrity ~ BOP Teat ~/ L~ation ~lear~ce - ~ T Me¢hanical Integrity Teat ~ubs~uent fo~ mquir~ 10.~ / . ~,n~ Signe~ By Commissioner D~te / _~Ap. provea_ by order of the Commission ]0V~ tat .............. Inhnefnn ~,, Fo~ 10-403 Rev, 06/15/88 8ubmE In Triplicate I Well Name: I P2-33B I Type of Well (producer or injector): IPr°ducer I Surface Location: 231' FNL 3914' FEL T12N, R14E, S 14 Target Location: 4551' FNL 612' FEL T12N, R14E, S1 Bottom Hole Location: 3589' FNL 4568' FEL T12N, R15E, S6 [AFE Number: [2C0108 ling: [DOYON 14 I Estimated Start Date: [ 12/5/97 ]Days to complete [9 I MD: 115,885' [ I TVD: [9048' brt I IRTE: IWell Design (conventional, slimhole, etc.): Formation Markers: 145.0 I Slimhole. Drill-out Production Interval Formation Tops MD TVD KOP/Colville Shale 14275 8725 Swap to 3% 10.2-10.5 ppg GEM prior to drillout. K-10 14573 8932 HRZ 14573 8932 Kalubik 14593 8944 Kuparuk 14607 8952 Build to high angle TD 15885 9048 TD Casing/TU~ing Program: · --, ...- v Hole Size Csg/Tbg Wt/Ft Grade Conn Length Top Btm O.D. MD/TVD MD/TVD 6 3/4 4 1/2" 12.6# 13CR80 NSCT 1885' 14050/8585' 15885'/9048' Tubing 4 1/2" 12.6# 13CR80 NSCT 14008' 42'/42' 14050'/8585' Mud Program: Production Mud Properties: 3% KCL l Density (ppg) 10.2-10.5 I GEM System 6 3/4" hole section Plastic Vis I Yield P°int8-25 15-25 10sec ge' I ~0n~n gel I 8-15 12-24 pH Fluid Loss 9.0-9.5 10-12cc Cement Data: Liner Latex Slurry Liner Lead:Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 4.5" none 274/15.8/1.19 Class "G". Volume based on 150' Lap with 20% excess + 80' shoe. Logging Program: I Open Hole Logs: ICased Hole Logs: DIR/GR/RES/DEN/NEU to TD GR/CBT (CBT may be requested prior to running tubing). Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: 12275' MD Maximum Hole Angle: Close Approach Well: 91 degrees None at this depth. Drilling and Completion Scope 1. MIRU on Suspended Well P2-33A. 2. Swap wellbore fluids to fresh 10.2-10.5 ppg 3% KCL GEM system. 3. Drill out cement and kick off on ST path at -14,275' MD. 4. Drill 6 3/4" production hole with LWD DIR/GR/DEN/NEU/RES to ~ 15,885' MD. 5. Run and cement 4-1/2" 13CR liner. 6. Run 4-1/2" 13CR production tubing with 7 5/8"x4-1/2" packer, 4-1/2" SSSV, and 4-1/2"xl.5" GLMs. 7. Secure well, RDMO. Drilling Hazards/Continqencies · The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4350 psi at 8800' ss. Abnormally pressured formations are not expected in this well. · No major instances of lost circulation problems have occurred on Pt Mac 2 wells. · Gas cut mud has been experienced in the Colville shales in neighboring wells. A 10.1 ppg mud minimum mud required. Disposal · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class Il wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. GH 12/1/97 TREE: 4 1/16"- 5M Chrome WELLHEAD: 11" x 11" - 5M FMC 10 3/4", 45.5 #/ft, L80, I 7,838 P2-33B RT-GL = 33.8' GL-SL = 11.6' Diesel to 2000' SCSSV - -2000' Diesel to 4000' IKOP: 14,275' Max Angle: 91° @ 15,165' 0.7-1 0.8 ppg mud. 5-6 4.5"X1.5" GLM's TBD 4-1/2" 13Cr 12.61b Tubing BAKER Tie Back Sleeve & ZXP Packer BAKER HMC Hanger 7 5/8", 29.7 #/FT, L80, BTC-M 14,035'i 14,050'I 14,200'1 13,700' JTOC 7-5/8" X 4-1/2" Cr Packer -14,000' 4-1/2" "X' Nipple 4-1/2" "XN" Nipple 150' Liner Lap. ~ 14,050' J PBTD, 4-1/2" 13Cr 12.61b Cemented Liner Date 12/1/97 Rev By Comments GH Proposed completion Point Mclntyre WELL: P2-33 Shared Services Drilling Shared Services Drilling I DriHQuest' Point Mclntrye Alaska Stale Plane Zone 4 Point Mcfrffyre Pad 2 P2-33 '1'ie-o~, Start Dir ~ 6.000"/1001t: 14275.0~1t MD, 8725.321t TVD Dt~ Ra~e Increase e 8.000"/10(~t: .14320.(10ff MI}. 8753.81ft TVD '""~"- End Dir, Sail O 40.000": 14 .,~-..q.10ft MD, 6839.13ft TVD ~,-- :: :.,, .... -,z:. ................................................................................................................................................................... .......................................... ~.~..~_..~..{.....,s.: ....... ~.' ......... ,,-. ........ ~ ........ ¢. ....... ~. ......... ~ .................. ,~ ....... .~ ................ -I-J ~~ I ~'i"lI I! I ~i I i II Iiii I~1"'-~ ~, I I iI I I II1 j IiI I' i I~"'1 I I '1 4 !l'l,""'l' I I I I I'1" I'1 II I Iiu~"'r'l I ! II IJ-II I~ I I I I "1 I '1 ]04G~ :10600 IOIl~ ~i~.~,y l I(~a(] 11~1~ 1144)0 t IISl)O i 1800 s~c: ~r-~.:an~ ~o Votical ~ u~ Z rq 12'29 9875637252 SPERRY-SUN PAGE 03/05 ~ ~ cl~l ~w i Point Mclntrye Alaska State Plane Zone 4 Point Mclntyre Pad 2 P2.33 Shared Services Drilling .... DrillQuest' 7~ 4 1/2" Uner, 1~,0~ MO, '" .., Total Depth: 15BBS,011t MD', \ End Di~E,aJl · g0,7,,=,0': 1516~.01ff MD, gO57.21fl TVD DIre 8.0g:0'll00ft: 16143.10fl MD, 9057,16ft TVD Dir, 8~110 Ce.000*: 1494:3,10ft MD, aO53,67ff TVD 6200 8tarl DIr O 10.000o/100ff: 144~3.10ft MD, 8849.09ff. TVD End Dlr, 8dl O 40,000'; 1.".a.~0.10ft MD, 8839,12,ft TVD Rate Incmaae O 8.000"/100ft: 14320.00ft MD, 8763.81fl TVD Start Dtr · 6.000'/100ft: 14275.00ft MD, 8725.32f1: 'I'VD 95OO Shared Services Drilling Point Mclntrye Measured Depth Incl. Azim, Sub-Sea Ve~ca4 Depth (fl) 51.573 42.900 6662.77 8709.97 52.055 43.131 6676.12 8725.32 Sperry-Sun Drilling Services Proposal Report for P2-33 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastlngs Rate Section (it) (ft) (it) Crt) (o/looft) (ft) Comment Alaska State Plane Zone 4 Point Mclntyre Pad 2 6048.24 N 8402.64 E 60046~.35 N 689859.76 E 6062.66 N 8~16.11 E 6004619.10 N 689672.87 E 10117.91 2.060 10137.64 Tie-~, SladDk ¢~ 6.000°ll00ft: 14275.00ft MD, 8725.32ftTVD P2-33B Wp6 14300.O[I 50.555 43.13 ! 6693.75 8740.95 14320.lX] 49.355 43.131 870~.61 8753.81 14~0.08 43,114 41.165 8761.93 8809.113 1~9.10 40.000 40.000 8791.93 8839.13 1~.10 40.000 40.{Xl0 t4541,55 48.845 40.000 8,96~00 8912.20 14572.94 51.984 40.000 8885.00 8932~----~ 14700.00 64.690 40.000 8~51~56 8998.76 14900.00 84.690 40.000 · 9004.10 9051,30 14943.I0 89.000 40.000 900~.47 8{~--~3.67 15100.00 89.000 40.000 9009.21 9056.41 15143.10 89.000 40.000 9009.96 9057.16 15165.01 90.750 40.113 9010.01 9057.21 6076.90 N 8429.44 E 60046,33.66 N 6~99885.86 E 6088.0B N 8439.91 E 6004645.08 N 689896.05 E 6130.85 N 8478.70 E 6004688.78 N 689933.79 E 6151.04 N 8496.00 E 6004709.39 N 6~9950.60 E 6157.45 N 8501,38 E 6004715.92 N 6a9955.81 E 6181.64 N 8521,68 E 6004740.60 N 68997'5.52 E 6204.93 N 8541.13 E 6004764.26 N 6899l~.41 E 6,:':':':':':':':':~36 N 8556.68 E 6004783.16 N 690009.~ E 623555 N 8568.gl E 6004795.59 N 690019,43 E 6239.98 N 6570.63 E 6004800.12 N 690023.04 E 6244.19 N 8574.17 E 6004804.41 N 690026.47 E 6306.03 N 862~,05 E 61XM867.49 N 690076.84 E 6377.78 N .8~:~6.26 E 6004,940.69 N 690135.29. E 6453.05 N 8749.42 E 6005017.47 N 690196.60 E 6486.01 N 8777.06 E 6005051.09 N 6902:23.45 E 652~.59 N 8813.64 E 6005095.55 N 690258.94 E SS0S.le N 8877.91 E 6005173.68 N 690:~1.33 E 6639.20 N 8,905.61 E 6005207,36 N 690348.22 E 66,.=~.97 N 8919.72 E 6005224.47 N 69(}G61.91 E 6682.72 N 8942.~5 E 6005251.76 N 6~E~3.80 E 5.000 8.000 8.000 0.000 10.000 10.000 I0.000 10.000 10.~ 10.~ 10.~ 10.~ 0.~ 0.~ 0.~ 0.~ 101b-'/.15 10172.45 10230.19 10256.78 10265.I3 Di~ Ral~ Increase O 8.(XX}°/'lO0ft' 14320.0011 MD, 8753.611t 'I'VD End Dir, Sail 0 40.000' ' 144-~.0.10it MD, 8839,131tTVD Start Dir 41 10.O0O'/10~t: 14453.1~ MD, 8649.09ft TVD 10256.70 10326.95 K-10 10351.12. HRZ 103~7.0~ KALUBtK 10372.81 KUPARUK End Dir, Satl 0 89.0Q0°: 14943.10ff MD, 9053.671tTVD Start l~r O 8.000°/100fl: 15143.101t MD, 905'7.16R TVD End Dir, Sail O 90.7r----------------~O~: 15t65.0tfl MD, 9057.21fl't'VD 10750.63 10850.56 108S3.62 1O91552 100[;0.413 Conffnued.. . ITl December, 1997- 10:55 Shared Services Drilling Point Mclntrye Sperry-Sun Drilling Services Proposal Report for P2.33 Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth ~) {ft! (fi) Loc;d Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastlngs Rale Section (ft) (ft) (~) (ft) (°/lOOft) (ft) Comment 15300.00 90.750 40.113 901~;24 9055.44 675~.19 N 9006.68 E 6005329.~ N 690446.~ E 0.000 11050.42 15400.00 90.750 40.113 9006.93 9054.13 6835.6'7N 9071.10E 64~5407.70 N 6~)508.~ E 0.000 11150.36 15500.00 90.750 40.113 9005.62 9052.82 6912.14 N 913E.53 E 6005485.80 N 6~D571.44 E 0.000 11250.30 15600.00 60.750 40.113 9004.31 9051.51 6988.61 N 9199.95 E 6005563.82 N 690633.98 E 0.000 11350.23 15685.0! 90.750 40.113 9003.20 9050.40 7053.62 N 9254.72 E 6005630,14 N 6906~7.'t6 E O.O00 11435.I9 15700.O0 90.750 40.113 9003.00 9050.20 7065.08 N 9254.38 E 6005641.83 N 690696.53 E 0.000 11450.17 15800.00 90.750 40.113 9001.70 9048.90 7141.55 N 9328.80 E 6005719.84 N 690759.08 E O.O00 11550.10 15835.01 90.750 40.113 9001.24 9048.44 7168.33 N 9351.:36 E 6005747.16 N 690780.98 E 0.000 11585.10 15885.01 90.750 40.113 9000.58 9047.78 7206.56 N 9383.571=' 6005786.17 N 690812.25 E 0.0iX) 11635.06 T th 1,588~.01ff MD, 9047.781t TVD All data is in feet uniess otherwise st;~ed. Directions and coordinates are relative to True North. Vertical depths are mtath/e to W~ Reference. Northings and l=e~'ngs are relative to Well Reference. The Dogleg Severity is in Degrees per 100fL Vertical Section is from Well Reference and cslculated along an Azimuth o! 42.019° (True). Based upon Minimum Curvature typ~ calculations, ~t a Measured Depth of 15885.01E, The Bottom Hole DisPlacement is 11831.56ft., in the Direction of 52.476° (True). Alaska State Plane Zone 4 Point Mclntyre Pad 2 Z 1 December, 1997- VENDOR A _ASKA~;T DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET i li~q7 CKlll~7C i00. O0 100. O0 PYMT COMMENTS: accompang 'pe~mi!t to drill' ap~ lication HANDLINQ INST: s/h kathg campo~zmo.~, · 'HE A~ACHEO CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. I~I)~ll I ~ n~ Flrt i ~1~ hh 'H · WELL PERMIT CHECKLIST COMPANY F ELD S POOL WELL NAME ~/¢/'~_~L/~ /~""' ,~,-~./~ PROGRAM: exp [] dev/,~ redrll~serv [] wellbore seg ~_: ann. disposal para req [3 G~5L ARE/A - ~'~'~"~ UNIT# //~.~'~ ON/OFF SHORE O ~) ADMINISTRATION ENGINEERING 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 drilling 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 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ ~ N ,,/ 18. CMT will cover all known productive horizons .......... ~. N 19. Casing designs adequate for C, T, B & permafrost ....... ,..~,,N 20. Adeqt~ate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... (' 22. Adequate wellbore separation proposed ............. '~ N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation .... ~ .... N 26. BOPE press rating appropriate; test to I~sigl N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N REMARKS GEOLOGY AP_PR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N ,// 31. Data presented on potential overpressure zones ....... Y N,~ 32. Seismic analysis of shallow gas zones ............. Y/.N 33. Seabed condition survey (if off-shore) ............. /,Y N 34. Contact name/phone for we,ekly,progress repqrts ...... .,/ Y N lexploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: JDH ,%/~ RNC ~ co Comments/Instructions: HOW/lit - A \FORMS\chekhst rev 09197 GE~L A~E/A'-- ~:~'~) ' UNIT# -- ///_~' J'~ ON/OFF SHORE OA~J WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS ADMINISTRATION ENGINEERING GEOLOGY 2. N 3. 4. 5. 6. t i/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 11. Permit can be issued without conservation order ...... .I Y~NN 12 Permit can be issued without administrative approval ..... 13. Can permit be approved before 15-day wait .......... N Permit fee attached ..................... Lease number appropriate ................. ,~_,,,~, ,,,~ Unique well name and number .................. Well located in a defined pool ................. Well located proper distance from drilling unit boundary. . . Well located proper distance from other wells .......... 14. Conductor string provided ................... Y N '"'h A~ ,,,,~ 15. Surface casing protects all known USDWs ........... Y N~/'~ v~, 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ ,,~ 18. CMT will cover all known productive horizons .......... ~NNNN 19. Casing designs adequate for C. T, B & permafrost ...... N 20. Adequate tankage or reserve pit ................. 21. It a re-drill, has a 10-403 for abandonment been approved... '"~'7 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~'Y(-"Y(-~Ni~N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to ;~"-~ ' psig. 27. Choke manifold complies w/APl RP-53 (Ma-y 84) ........ N 28. Work will occur without operation shutdown ........... 29. Is presence of H:S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... YY NJ ,,. /') 31. Data presented on potential overpressure zones ....... ,~N //"/_,,)~ 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. ,//Y N 34. Contact name/phone for we_eklyprogress reports .... .~. Y N {exploratory only] __G E O L O_0.C~: ENGINEERING: COMMISSION' JDH~ RNC .~4"~ CO Comments/Instructions: 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 Tue Apr 14 14:51:30 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER POINT MCINTYRE 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-MM-80146 TOM MCGUIRE DENIS ACKERM M OF LMED P2-33B 500292281202 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14-APR-98 MWD RUN 2 MWD RUN 3 AK-MM-80146 AK-MM-80146 TOM MCGUIRE TOM MCGUIRE DENIS ACKERM DENIS ACKERM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-80146 TOM MCGUIRE DENIS ACKERM 14 12N 14E 231 1365 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 47.50 46.00 11.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 4.500 16136.0 PRODUCTION STRING 6.750 16491.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND CARL LUNDGREN OF ARCO ALASKA, INC. ON 23 MARCH, 1998. SPERRY-SUN MWD DATA IS CONSIDERED THE PRIMARY DEPTH CONTROL FOR WELL P2-33B. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16491'MD, 8931'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION. EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment 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 14160.0 16442.0 ROP 14200.0 16490.5 FET 14208.0 16449.0 RPD 14208.0 16449.0 RPM 14208.0 16449.0 RPS 14208.0 16449.0 RPX 14208.0 16449.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 14200.0 14479.0 2 14479.0 14915.0 3 14915.0 15693.0 4 15693.0 16491.0 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 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHNiM 4 1 68 RPM MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 14160 16490.5 GR 29.9919 450.411 RPS 0.5808 78.7518 RPD 0.3403 87.4654 ROP 2.104 2260.58 RPX 0.7117 60.4315 RPM 0.4212 76.928 FET 0.7363 28.611 Mean 15325.2 74 8553 12 8474 14 1705 55 1457 10 3823 12 4205 3.34117 Nsam 4662 4565 4483 4483 4582 4483 4483 4483 First Reading 14160 14160 14208 14208 14200 14208 14208 14208 Last Reading 16490.5 16442 16449 16449 16490.5 16449 16449 16449 First Reading For Entire File .......... 14160 Last Reading For Entire File ........... 16490.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/14 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 ....... 98/04/14 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 GR ROP FET RPD RPM RPS RPX $ LOG HEADER DATA DATE LOGGED: SOFTWARE 14160.0 14200 0 14208 0 14208 0 14208 0 14208 0 14208 0 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 DGR DUAL GAMMA RAY STOP DEPTH 14439.5 14479 0 14446 5 14446 5 14446 5 14446 5 14446 5 02-MAR-98 5.07 5.03 MEMORY 14479.0 14200.0 14479.0 38.6 51.8 TOOL NUMBER P0882SP4 EWR4 ELECTROMAG. RESIS. 4 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 P0882SP4 6.750 6.8 GEM GP/KCL 10.30 39.0 10.0 17000 10.4 .160 .680 .220 .260 .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 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 75.5 First Name Min Max Mean Nsam Reading DEPT 14160 14479 14319.5 639 14160 GR 42.9656 165.344 101.149 560 14160 RPX 1.0017 5.2416 3.18251 478 14208 RPS 0.9663 4.5507 3.32727 478 14208 Last Reading 14479 14439.5 14446.5 14446.5 RPM 0.9954 4.9717 3.25794 RPD 0.6396 4.6113 3.37578 ROP 2.104 263.251 29.8108 FET 0.7363 6.1719 2.98551 478 478 559 478 14208 14208 14200 14208 14446.5 14446.5 14479 14446.5 First Reading For Entire File .......... 14160 Last Reading For Entire File ........... 14479 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/14 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 ....... 98/04/14 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 14438.0 14870 5 FET 14445.0 14877 5 RPD 14445.0 14877 5 RPM 14445.0 14877 5 RPS 14445.0 14877 5 RPX 14445.0 14877 5 ROP 14475.0 14914 5 $ LOG HEADER DATA DATE LOGGED: 06-MAR- 98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 14915.0 TOP LOG INTERVAL (FT) : 14479.0 BOTTOM LOG INTERVAL (FT) : 14915.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMIIMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 39.7 80.6 TOOL NUMBER P0882SP4 P0882SP4 6.750 6.8 GEM GP/KCL 10.30 42.0 9.0 18000 2.0 .220 .114 .320 .280 68.9 .0 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 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 14438 33 1783 0 7117 0 5808 0 4212 0 3403 3 3835 1 6163 Max Mean Nsam 14914.5 14676.2 954 450.411 102.835 866 35.5329 7.30054 866 54.2514 8.95147 866 50.814 8.76997 866 53.2003 9.53181 866 629.897 31.1571 880 21.4151 5.03514 866 First Reading 14438 14438 14445 14445 14445 14445 14475 14445 Last Reading 14914 5 14870 5 14877 5 14877 5 14877 5 14877 5 14914 5 14877 5 First Reading For Entire File .......... 14438 Last Reading For Entire File ........... 14914.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/14 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 ....... 98/04/14 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 SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 14871 5 14878 5 14878 5 14878 5 14878 5 14878 5 14917 0 LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 15648.5 15655 5 15655 5 15655 5 15655 5 15655 5 15692 5 08-MAR-98 RPS MWD 3 RPM MWD 3 RPD MWD 3 ROP MWD 3 FET MWD 3 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 12 16 20 24 28 Name DEPT GR RPX RPS RPM RPD ROP FET Min 14871.5 42 3246 3 7744 4 3979 4 3141 4 7872 4 2595 0 8207 Max Mean Nsam 15692.5 15282 1643 95.0685 68.8313 1555 19.0166 10.1844 1555 22.2178 12.566 1555 20.7607 12.3703 1555 23.7991 14.2961 1555 2260.58 62.6876 1552 23.4339 2.78581 1555 First Reading 14871 5 14871 5 14878 5 14878 5 14878 5 14878 5 14917 14878.5 Last Reading 15692 5 15648 5 15655 5 15655 5 15655 5 15655 5 15692 5 15655 5 First Reading For Entire File .......... 14871.5 Last Reading For Entire File ........... 15692.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/14 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 ....... 98/04/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NI3MBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 15646 . 0 16442 . 0 PET 15651 . 5 16449 . 0 RPD 15651 . 5 16449 . 0 RPM 15651 . 5 16449 . 0 RPS 15651 . 5 16449 . 0 RPX 15651.5 ROP 15694.5 $ 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: 16449.0 16490.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA_MMARAY EWR4 ELECTROMAG. RESIS. 4 $ 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 il-MAR-98 5.07 5.03 MEMORY 16491.0 15693.0 16491.0 84.8 105.4 TOOL NUMBER P0882SP4 P0882SP4 6.750 6.8 GEM GP/KCL 10.50 40.0 9.5 17500 8.0 .190 .079 .260 .240 65.6 .0 I0 ...... ~eqLunH UOTqen~lqUOO ~ONTHNI1 ................ e~H Iee~ S~S ................... U~6l~O ~I/~0/86 ..................... eqeQ ~Slq ............. e~u eOTA~eS ~ell~ lee~ 'xze~q!q 5~TqTZ~ Slq S69 ................. squeumzoo N/vlOkrZNll ........... em~H ede~ qxeH I0 ...... ~equmH UOl~en~TqUOD N/~OkTMNfl ................ e~eH S~S ................... ulDl~O ~$/~0/86 ..................... Z~SIq ............. e~ eoTA~eS ~elT~ ede~ 900'SlqSLS ........... e~mH eIT~ qxeH Oq ................ edKL eiT~ 9£999''p~o~eH I~ols~q~ ~n~TxeH PI/~0/86 ....... uo!~eseue© ~o e~eG 0'0'I ........... ~equ~nH uo~S~eA '' 'e~mH IeAeq qns eo!A~eS 900'~IqSLS .............e~eu eolA~eS S'06~9I ........... eiTZ e~TquZ ~og DuTPeeH qsmq 9~99I .......... eil~ ezTquZ ~o~ DulpeeH qs~l~ 69991 §'0699I 69~9I 69991 9'0699I buTPeeH 9 I99§1 6uTPeeH qS~l~ 969I £6§1 969I 969I 969I 969I £69I 069I 9166 0L I6[t 6I 69£I LI 18[0 8I £I9£ 9I [~8£ 99 ['8909I u~eN II9'8[ 618'0 [9'£9[$ t08'§ AOH 9999'L8 I690'9 8~6'9L I~80'9 8Igt'St I006'9 9I£9'09 618I'9 XdH ~19'66 6166'6~ 9'0699I 9999I xeH uIH 8 8[ L 9[ 9 0[ 9 91 £ 8 I 0 TeUUeMO qes~0 epoo 89 I 89 I 89 I 89 I 89 I 89 I 89 I 89 I 0'''adKq-qns Aooi~ UOTqmOlZToeds mnqeQ ....................... SqTUO MqdeG Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
