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195-169
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240509 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 4/17/2024 HALLIBURTON MFC END 3-25B 50029221250200 203021 3/31/2024 HALLIBURTON PPROF MPU J-16 50029226150000 195169 3/28/2024 HALLIBURTON WFL-TMD3D NCIU A-18 50883201890000 223033 5/1/2024 READ Multiple Array PProf PBU B-05D 50029202760400 213069 4/24/2024 HALLIBURTON RBT PBU C-16C 50029204380300 213191 4/26/2024 HALLIBURTON RBT PBU D-18B 50029206940200 215001 4/21/2024 HALLIBURTON RBT TBF A-07 50733200360000 167046 4/17/2024 HALLIBURTON RBT TBF A-18 50733201430000 168076 4/16/2024 HALLIBURTON RBT Please include current contact information if different from above. T38771 T38772 T38773 T38774 T38775 T38776 T38777 T38778 T38779 MPU J-16 50029226150000 195169 3/28/2024 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 12:46:46 -08'00' Some people who received this message don't often get email from twellman@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions Date:Monday, April 1, 2024 9:41:45 AM Attachments:MPU_j-16_WFL_28-MAR-24.pdf PTD 2240120 and 1951690. From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday, April 1, 2024 8:46 AM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Nathan Sperry <Nathan.Sperry@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Katharine Cunha <Katharine.Cunha@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions Andy, Please see the attached Water Flow Log / Oxygen Activation Log run on MPU J-16 (PTD 195-169). Sorry for the delay as it was affected by weather and the service provider’s unit repairs but the attached log indicates zero flow behind the casing at the top of the Schrader. Please let me know if this is sufficient to prove isolation and allow for injection into MPU I-23 (PTD 224-012) upon completion as per the COA’s in the PTD. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, March 7, 2024 1:17 PM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Nathan Sperry <Nathan.Sperry@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Katharine Cunha <Katharine.Cunha@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Chris and Andrew, The type of log we are aiming to run is a waterflow log or an oxygen activation log. I’m currently working on scheduling the job but target to have this log completed in the next 2 weeks. If there are any issues with this timeline I will make sure to provide an update with the reasoning. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Thursday, March 7, 2024 8:13 AM To: Taylor Wellman <twellman@hilcorp.com>; Nathan Sperry <Nathan.Sperry@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Katharine Cunha <Katharine.Cunha@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions Taylor and Nathan, In addition to the email reply stating the specifics on the proposed mitigation plan, would you please submit a revised AOR and for the MPU I-23 PTD calling out the issue in J-16 with the mitigation plan detailed. Please identify the well in the updated AOR map. I will splice those revised pages into the final PTD document. Thank you, Andy From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, March 6, 2024 15:26 To: Taylor Wellman <twellman@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Nathan Sperry <Nathan.Sperry@hilcorp.com>; Katharine Cunha 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. <Katharine.Cunha@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions Taylor, We didn’t talk about the type of log to be run on J-16 and estimated date it may be completed - so if you could reply here, we will attach these emails to the I-23 PTD approval for the record. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday, March 4, 2024 4:03 PM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Nathan Sperry <Nathan.Sperry@hilcorp.com>; Katharine Cunha <Katharine.Cunha@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions Chris and Andrew, With regards to MPU J-16 (PTD 195-169 / API 50-029-22615-00-00) you are correct. After further review of the original cementing records, the first stage cement job on the 7” casing would not have come high enough to have isolation across the Schrader Bluff in this well. The condition of the isolation within J-16 has been a miss for multiple well penetrations through time. Below is a summary table of injectors in the proximity of MPU J-16 and details about them. Well Distance to J- 16 (ft) Pool - Sands Open Start Inj Stop Inj Vol (MMBW) Status J-15 1,154 Schrader (Nb, Oa, Ob) 1999 2018 6.9 Cmt to surf 10/8/2020 J-17 4,275 Schrader (Nb, Nc, Oa, Ob) 1998 2020 7.9 Shut In - Operable CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. J-18 2,776 Schrader (Nb, Oa, Ob) 2005 2019 2.9 Shut In - Not Operable (MIT-IA allowed to lapse, Mechanically good) J-19A 2,848 Schrader (Nb, Nc, Oa, Ob) 2009 2020 2.3 Shut In - Not Operable (MIT-IA allowed to lapse, Mechanically good) I-21 268 Schrader (Oba)2021 N/A 1.5 Horizontal Well - On Injection I-28 243 Schrader (Oa)2021 N/A 1.8 Horizontal Well - On Injection I-35 770 Schrader (Nb)2020 N/A 1.9 Horizontal Well - On Injection I-37 1032 Schrader (Nb)2020 N/A 3.3 Horizontal Well - On Injection We would like to propose keeping all wells currently online and injecting, while concurrently running a Water Flow Log in MPU J-16 to check for water flow between the Schrader and Ugnu sands. Keeping the injection wells online will provide the actual conditions that could lead to crossflow and have the highest chance for detection. Once that data is obtained, it will be provided back to you and further actions can be enacted if needed. We are open to coming over to your offices to discuss anything about these wells if you would like. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Friday, March 1, 2024 5:36 PM To: Nathan Sperry <Nathan.Sperry@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL] MPU I-23 (PTD 224-012) - Questions Nathan, I am completing my review of the MPU I-23 PTD and have a few questions: 1. Regarding the Area of Review: I have a question about one of the offset wells: MPU J-16 (50-029-22615-00-00). From what I can tell, the original plan for this well was to run 7” casing to TD (12,212’ MD) and do a 2-stage cement job: stage 1 across Kuparuk and stage 2 across Schrader Bluff. But they couldn’t get the 7” past 10,553’ MD, so they set it there and ran a 5” liner from the base of the 7” to TD. I see from your notes on this well that the stage collar was set 4,681’ MD with a TOC of 2,998’MD. But the depth of the stage collar appears shallower to the Schrader Bluff by over 1,000’ MD. Do you have any information (volumetrics, quality, etc.) about the first stage job that would support isolation across the Schrader Bluff? 2. I noticed there are conflicts between the H2S hazard description in the 12-1/4” hole (p.48) vs. the 8-1/2” hole (p.50). Would you please clarify? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 3m000m-oo CK Imo ono orm o �(7 z C a-3 O M 3 M 3 O N 3 a _. 3 m m m K W x 0 7 0 =m M M m C N — m Company HILCORP ALASKA, LLC. c w^a .'Dn.m m� m.m �3 ��Z m ^.�<� Q` 3 --10 r0Pl� m well MPUJ-16 D` m n m a a �3� �M m n��a, a� a m 3 = 3 Field County MILNE POINT N. SLOPE State ALASKKA r s s a m m w s — o Tr 0 O. O Q j c A O J 0 O N 'O j 0 o B. co m gq�rnmD TN 3 \ \ m D 7 Co W Cn r m o Zrn /y1 \tY T rn O D N o A QQ N Z O N O a o r cl) =.a Om�O yM z M O m (� 3 n Oa S. n�a a m N O D W U V _NON CNN N N O.3CD N N.N N % ` r .. D s c ^ammEL rm �' ao c 3 _ ' O m o N U) 5.o O O O O N N 0 n w 0I r m /�� p o,C ;U 0o� TI (n(n(n(nm > xnwDou D o M r-Mw A�A3n w x m m m O 1� O t m m m a r w rn f n o2 of m Z 1D D Z o 0 G w 0' m z O 0 D N (O W w S S <<< Fold Here >>> HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OR WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS, OR RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF. Comments LOG TIED INTO PDF PROVIDED BY CUSTOMER. IMPULSE TESTS AT: 5700', 5650', 5600', 5550', 5500', AND 5450' NO FLOW DETECTED MPU J-16i Tree: 3 1/8" - 5M WKM Wellhead: 11" 5M FMC, GEN 5 w/ 3.5" FMC Tubing Hanger, 3.5" NSCT T&B, 3" CIW H BPV profiile 20" 91.1 ppf, H-40 112' KOP @ 600' Max. hole angle = 60 deg. f/ 3000' to 10300'. 40 deg at TD. Hole angle across perfs = 42 deg. 9 5/8", 40#/ft, L-80 Btrc. 3113' and 7", 26,ppf, L-80 Btrc. casing (ID = 6.276", cap. = 0.0383 bpf) 3.5", 9.3 ppf, L-80 NS-CT tubing (ID = 2.867", cap. = 0.0087 bpf) Orig. KB Elev. = 65 ' (N 22E) Orig. GL Elev. = 35' RT To Tbg. Spool = 25.87' (N 22E) Halliburton 4681' and menter LAND TOP: 5,748' MD ;AND TOP: 6,039' MD ;AND TOP: 6,180' MD tker 7" S-3 packer 10,289' and Min. tbg. restriction = 2,75" no-go HES 3.5" 'XN' npl. in landing npl at 10,304' md. (w/ 2.75" no-go) 10,304' and Wireline entry guide 10,308' and Two 7" casing marker joints (20' & 21') Stimulation Summary at 9777' to 9818' and w/ RA tag on top 08/12/96 - High pressure breakdown - Baker 5"x 7" liner 10,351 and four 200 bbl.stages of linear gel. hanger and packer 5", 15ppf, NT13CR80, FL4S liner 7" 26#, L-80, Btrc. 10,553' and (ID = 4.408", cap. = 0.0188 bpf) Perforation Summary Ref log: 11/17/95 WA SBT Size SPF Interval (TVD 'B' Sand 3 3/8" 6 11655'-11665' (7058'-7 'A' Sand 3 3/8" 6 11724'-11796' 7106'-7 Atlas Alpha Jet deep penetrating cl (EHD = 0.47", TTP= 21.0) @ 60 dei, phasing DATE REV.BY 11/19/95 DBR 01/ 03/96 JBF 08/12/96 JBF COMMENTS N22E DRILLED AND CASED Completion string run by N 4ES Update 1/17/95 Eline TD 12,034' wl )rig. PBTD 12,064' and 5", 15#, 13CR, FL4S 12,203' and MILNE POINT UNIT WELL J-16i API NO: 50-029-22615 HALLIBURTON IMPULSE TEST 5450 Database File mpuJ_16_23_mar _24.db Dataset Pathname pass15 Presentation Format tmd3d_imp Dataset Creation Thu Mar 28 1830:15 2024 Charted by Time scaled 360/hour Depth (ft) ELTIM 0 GEN VOLTS (V) 100 FBKSUM (sec) 0 OAIF 2000 FAR ACT 1000 LBKSUM -------------------------- 0 OAIL 2000 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAPI) -------------------------- 0 (GAPI) 500 ►Zl] Ell] M11 1*7 :N 1*70-ND: fiUU] IPZf lElf, IDit, ►4zr, ►zlc ►zl.lc 1*70-%VIM cIlU; QW,, .Mkvl 5463.6 1*7 :N 1*70- cD. 01.1f, Q-1f, Mit, WOR,, b'Z[:M 1*70-ND: CYIf, 6111f, 6M,, .Zif, U'Fif N*70.10 . 5463.6 AfeIf, F512% 1M�111( IPZf IsMISM I.Z[:N ILl-if, IRIf, f olf, EMzfl Depth (ft) ELTIM 0 GEN VOLTS (V) 100 FBKSUM (sec) 0 OAIF 2070 FAR ACT 1000 LBKSUM OAIL 2000 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAPI) -------------------------- 00API 0 (G) 5 ----------API------00 HALLIBURTON IMPULSE TEST 5450 TMD-3D Impulse Pass 15 Summary Impulse Test at: 5463.6' Generator at: 5450' Weighted Average Velocity = 0 ftlmin UP Weighted STD - 0 0/min C.Waen�ftlePW1 J-16 WFLUASWM es Inpulse Test 1 Sensor Depth Sensor Velocity Rate bbls/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen OR 5439.4 GR /WA UP 0.00 14 13 5447.9 OAIF /N/A UP 0.69 4 0 54472 OAIL MA UP 021 1 0 5447.9 FSBF /WA UP 0./3 6S 26 54472 LSBF /WA UP 0.56 19 12 54602 GR/2 /N/A DOWN 0.00 1S 14 In ulse Test 2 Sensor Depth Sensor Ve" Rate bblilday Direction I Statistical Confidence JAVGCPS I Gen On AVGCPS Gen ON 5139.E GR /WA UP 0.00 13 14 5447.9 OAIF /WA UP 0.59 3 0 5N72 OAIL I /N/A UP 0.02 0 0 5447.9 FSBF i /WA UP 0./2 56 23 St472 LSBF /N/A UP 0.53 17 10 54602 GR/2 I /WA DOWN 0.00 14 14 Inpulse Test 3 Sensor De Sensor Velocity Rate bbls/da Direction Statistical Confidence AVGCPS I Gen On AVGCPS Gen ON 5439.4 GR /N/A UP 0.00 1 14 13 5447.9 OAIF /N/A UP 0.65 3 0 5447.2 OAIL /N/A UP 0.00 0 0 5447.9 FSBF /N/A UP 0.77 51 21 5447.2 LSBF /N/A UP 1 0.3E 17 11 S4602 GR/2 MN/A DOWN 1 0.00 14 14 HALLIBURTON IMPULSE TEST 5500 Database File Dataset Pathname Presentation Format Dataset Creation Charted by Depth (ft) ELTIM (sec) mpuJ_16_23_mar _24. db pass14 tmd3d_imp Thu Mar 28 18:0736 2024 Time scaled 360/hour 0 GEN VOLTS (V) 100 0 OAIF 200 0 FAR ACT 1000 -- - - - - -------------CT - --- OAIL 20010 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM m 5513.6 5513.6 5513.6 .o Im 100 120 140 160 5513.6 5513.6 ►III 220 240 ►.11 5513.6 300 5513.6 5513.6 320 340 360 WE m h h k 5513.6 m m !i 5513.5 1 500 520 1�yu I. IY�I��i i k pfT,p II;!'�Ylir I obi ryl i �i 5513.5 560 ME 5513.5 620 5513.5 JI t Vm 5513.5 5513.5 700 720 740 760 5513.5 Depth (ft) WW ELTIM 0 GEN VOLTS (V) 100 (sec) 0 OAIF 200 0 FAR ACT 1000 -------------------------- 0 OAIL 2000 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAR) --------------------------- 0 (GAPI) 500 9:3 WillLtl 1:326111LA HALLIBURTON IMPULSE TEST 5500 TMD-3D Impulse Pass 14 Summary Impulse Test at: 5513.6' Generator at: 5500' Weighted Average Velocity = 0 ftlmin UP Weighted STD-0 Wmin C.WaenNeseann.DeftlePWl J-16 WFLVA.A5500. es In ulse Test 1 Sam Depth Sensor Velocity Rate bbla/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen OR 5489.4 GR /WA UP 0.00 37 38 5497.9 OAIF MA UP 0.62 3 0 54972 OAIL MA UP 0.12 1 0 5497.9 FSBF eWA UP 0.83 60 31 5497.2 LSBF 8WA UP 0.40 26 20 5510.2 GR82 8N/A DOWN 0.00 14 14 In ulse Test 2 Sensor Depth Sensor Ve" Rate bblilday Direction I Statistical Confidence JAVGCPS I Gen On AVGCPS Gen ON 5489.4 GR 8WA UP 0.00 37 36 5497.9 OAIF 8WA UP 0.51 2 0 5497.2 OAIL 8N/A UP 0.00 0 0 5497.9 FSBF eWA UP 0.79 55 30 5497.2 LSBF eN/A UP 0.00 24 21 55102 GR82 /WA I DOWN 0.00 11 f1 Inpulse Test 3 $ems De Sensor Vekxfty Rate bbls/da Dhectlon Statistical Confidence AVGCPS I Gen On AVGCPS Gen ON 5489.4 GR 8N/A UP 0.00 1 37 37 5497.9 OAIF 8N/A UP 0.63 2 0 5497.2 OAIL 8N/A UP 0.00 0 0 5497.9 FSBF 4N/A UP 0.71 51 28 $497.2 LSBF 4N/A UP 1 0.00 23 21 55102 GR82 MN/A DOWN 1 0.00 14 14 HALLIBURTON IMPULSE TEST 5550 Database File mpuJ_16_23_mar _24.db Dataset Pathname pass13 Presentation Format tmd3d_imp Dataset Creation Thu Mar 28 17:4535 2024 Charted by Time scaled 360/hour Depth (ft) ELTIM 0 GEN VOLTS (V) 100 (sec) 0 OAIF 200 -------------------------- 0 FARACT 1000 0 OAIL 200 0 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM W 5563.6 5563.6 5563.6 .o IR 100 120 140 160 5563.6 5563.6 ►III 220 240 ►.11 IPp„ CFI Is,l� pui iy ��I 5563.6 300 5563.6 320 340 360 m 5563.6 1 400 5563.6 m m !i 5563.6 1 500 520 ELF 5� P i LL l 0 5563.6 560 WE 5563.6 620 5563.6 I�M6fiiKd 5563.6 5563.6 700 720 740 760 5563.6 Depth (ft) ELTIM 0 GEN VOLTS (V) 100 (sec) 0 OAIF 2000 FAR ACT 1000 -------------------------- 0 OAIL 2000 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAP]) -------------------------- 0 (GAPI) 500 9:3Will LItl 1:3:6111LA HALLIBURTON IMPULSE TEST 5550 TMD-3D Impulse Pass 13 Summary Impulse Test at: 5563.6' Generator at: 5550' Weighted Average Velocity = 0 ftlmin UP Weighted STD - 0 0/min C.Waen�ftlePW1 J-16 WFLUASA 50. es In ulse Test 1 $ems Depth Sensor Velocity Rate bbls/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen Off 5539.4 GR /WA UP 0.00 32 31 5547.9 OAIF /N/A UP 0.46 2 0 5%7.2 OAIL MA UP 0.00 0 0 5547.9 FSBF /WA UP 0.81 54 27 55472 LSBF /WA UP 0.29 21 17 5560.2 GR/2 /N/A DOWN 0.00 11 11 In ube Test 2 Sensor Depth Sensor Ve" Rate bblilday Direction I Statistical Confidence JAVGCPS I Gen On AVGCPS Gen ON 5539.E GR /WA UP 0.00 30 30 5547.9 OAIF /WA UP 0.48 2 0 55472 OAIL I /N/A UP 0.00 0 0 5%7.9 FSBF i /WA UP 0.73 47 26 55472 LSBF /N/A UP 0.00 20 18 55602 GR/2 I /WA DOWN 0.00 11 11 Inpulse Test 3 $ems De Sensor Vekxfty Rate bbls/da Direction Statistical Confidence AVGCPS I Garton AVGCPS Gen ON 5539.4 GR /N/A UP 0.00 1 31 30 5547.9 OAIF /N/A UP 0.52 2 0 5547.2 OAIL /N/A UP 0.00 0 0 5547.9 FSBF /N/A UP 0.75 53 20 55472 LSBF /N/A UP 1 0.00 21 18 5560.2 GR/2 MN/A DOWN 1 0.00 1 11 11 HALLIBURTON IMPULSE TEST 5600' Database File mpuJ_16_23_mar _24.db Dataset Pathname pass12 Presentation Format tmd3d_imp Dataset Creation Thu Mar 28 1723:15 2024 Charted by Time scaled 360/hour Depth (ft) ELTIM 0 GEN VOLTS (V) 100 (sec) 0 OAIF 200 -------------------------- 0 FARACT 1000 0 OAIL 200 0 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM m 5613.6 5613.6 5613.6 .o Im 100 120 140 160 5613.6 5613.6 ►III 220 240 ►.11 5613.6 300 5613.6 320 340 360 m 5613.6 1 400 5613.6 m m !i 5613.6 1 500 520 5613.6 560 WE 5613.6 620 5613.6 5613.6 5613.6 700 720 740 760 II'�id I1 I'gjin p!, Id. I. roe � 5613.6 :ro Depth (ft) ELTIM 0 GEN VOLTS (V) 100 (sec) 0 OAIF 200 0 FAR ACT 1000 ------------------------- 0 OAIL 200 0 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAPI) ------------------------- 0 (GAPI) 500 9:3Mill I 1:3:6111LA HALLIBURTON IMPULSE TEST 5600' TMD-3D Impulse Pass 12 Summary Impulse Test at: 5613.6' Generator at: 5600' Weighted Average Velocity = 0 ftlmin UP Weighted STD - 0 8/min C.WaenNefeEnn�Wop`1 J-16 WFLVASI'N. as In ulse Test 1 Sensor Depth Sensor Velocity Rate bbla/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen OR 5559.4 GR BWA UP 0.00 23 24 5597.9 OAIF MA UP 0.50 2 0 55972 OAIL MA UP 0.00 0 0 5597.9 FSBF BWA UP 0.76 57 29 55972 LSBF /WA UP 0.28 25 19 56102 GR/2 8N/A DOWN 0.00 12 11 In ulse Test 2 Sensor Depth Sensor Ve" Rate bblilday Direction I Statistical Confidence JAVGCPS I Gen On AVGCPS Gen ON 5589.E GR 8WA UP 0.00 24 24 5597.9 OAIF /WA UP 0.45 2 0 5597.2 OAIL 8N/A UP 0.00 0 0 5597.9 FSBF NWA UP 0.79 51 27 5597.2 LSBF NN/A UP 0.10 24 20 5610.2 GRl2 /WA I DOWN 0.00 12 12 Inpulse Test 3 $ens Depth Sensor Vekxfty Rate bblsfdav Dhecdon Statistical Confidence JAVGCPS I Gen On AVGCPS Gen ON 5589.4 GR 8N/A UP 0.00 1 25 23 5597.9 OAIF /N/A UP 0.00 1 0 5597.2 OAIL 8N/A UP 0.00 0 0 5597.9 FSBF 4N/A UP 0.3E 31 22 55972 LSBF 4N/A UP 1 0.00 21 19 56102 GRN2 MN/A DOWN 1 0.00 1 11 13 HALLIBURTON IMPULSE TEST 5650' Database File mpuJ_l6_23_mar _24.db Dataset Pathname passl1 Presentation Format tmd3d_imp Dataset Creation Thu Mar 28 17:0135 2024 Charted by Time scaled 360/hour Depth (ft) ELTIM 0 GEN VOLTS (V) 100 (sec) 0 OAIF 200 -------------------------- 0 FARACT 1000 0 OAIL 200 0 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM m 5663.6 5663.6 5663.6 .o Im 100 120 140 160 J,n I� , 5663.6 5663.6 ►w� 220 240 ►.11 5663.6 300 5663.6 320 340 360 m 5663.6 1 400 5663.6 m m !i 5663.6 1 500 520 VI i i Nd� 5663.6 560 ME 5663.6 620 5663.6 5663.6 5663.6 700 720 740 760 WW 840 Depth (ft) ELTIM 0 GEN VOLTS (sec) 0 OAIF 200 -------------------------- 0 OAIL 2000 0 Upper GR (GAPI)500 (V) 100 0 FAR ACT 1000 LONG ACT 1000 FBKSUM LBKSUM Lower GR (GAR) 0 (GAPI) 500 HALLIBURTON IMPULSE TEST 5650' TMD-3D Impulse Pass 11 Summary Impulse Test at: 5663.6' Generator at: 5650' Weighted Average Velocity = 0 ftlmin UP Weighted STD-0 Wmin C.Waen�ftlePW1 J.16 WFLUASA56S0. es In ulse Test 1 Sensor Depth Sensor Velocity Rate bbls/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen OR 5639.4 GR eWA UP 0.00 25 25 5647.9 OAIF MA UP 0.58 2 0 56472 OAIL MA UP 0.00 0 0 %47.9 FSBF eWA UP 0.81 62 29 56472 LSBF /WA UP 0.46 23 17 5660.2 GR/2 /NIA DOWN 0.00 11 10 In ulse Test 2 Sensor Depth Sensor Velocity Rate bblilday Direction Statistical Confidence JAVGCPS I Gen On AVGCPS Gen ON 5639.4 GR 8111A UP 0.00 25 24 5647.9 OAIF /WA UP 0.50 2 0 5647.2 OAIL /NIA UP 0.00 0 0 %47.9 FSBF eWA UP 0.71 49 27 %47.2 LSBF/NIA UP 0.03 20 16 5660.2 GM /WA I DOWN 0.00 11 11 Inpulse Test 3 Sent De Setnor Velocity Rate bbls/da Dhectlon Statistical Confidence AVGCPS I Gen On AVGCPS Gen ON 5639.4 GR BN/A UP 0.00 1 25 26 5647.9 OAIF /N/A UP 0.53 2 0 5647.2 OAR. BN/A UP 0.00 0 0 5647.9 FSBF 4N/A UP 0.77 50 25 5647.2 LSBF 4N/A UP 1 027 20 16 56602 GR82 MN/A DOWN 1 0.00 1 12 11 HALLIBURTON Database File Dataset Pathname Presentation Format Dataset Creation Charted by Depth (ft) ELTIM (sec) m p u J_ 16_23_mar - 24-d b pass10 tmd3d_imp Thu Mar 28 16-38-58 2024 Time scaled 360/hour 0 GEN VOLTS (V) 100 0 OAIF 200 0 FAR ACT 1000 -- - - - - -------------CT - --- OAIL 20010 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM W 5713.6 5713.6 5713.6 .o Im 100 120 140 160 5713.6 5713.6 ►w� 220 240 ►.11 5713.6 300 5713.6 5713.6 320 340 360 WE m 5713.6 m m !i 5713.6 1 500 520 5713.6 560 WE 5713.6 620 5713.6 Ah IN,AAJA i J 5713.6 5713.6 700 720 740 760 5713.6 Depth (ft) 840 ELTIM 0 GEN VOLTS (V) 100 FBKSUM (sec) 0 OAIF 2000 FAR ACT 1000 LBKSUM ------------------------ 0 OAIL 2000 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAR) -------------------------- 0 (GAPI) 500 HALLIBURTON IMPULSE TEST 5700 TMD-3D Impulse Pass 10 Summary Impulse Test at: 5713.6' Generator at: 5700' Weighted Average Velocity = 0 ftlmin UP Weighted STD - 0 0/min C.WaenNeseann.DeftlePW1 J-16 WFLUASA57U0. es In ulse Test 1 Sensor Depth Sensor Velocity Rate bbla/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen Off 5609.4 GR eWA UP 0.00 20 21 5697.9 OAIF MA UP 0.64 3 0 56972 OAIL MA UP 0.04 0 0 5697.9 FSBF eWA UP 0.83 68 30 56972 LSBF aWA UP 0.30 22 17 5710.2 GR/2 aN/A DOWN 0.00 9 9 In ulse Test 2 Sensor De Sensor Velocity Rate bbls/da Direction Statistical Confidence AVGCPS I Gen On AVGCPS Gen Off 5689.4 GR 8WA UP 0.00 20 21 5697.9 OAIF aWA UP 0.60 2 0 56972 OAIL aN/A UP 0.00 0 0 5697.9 FSBF eWA UP 0.77 56 27 5697.2 LSBF eN/A UP 0.44 21 15 57102 GM 8WA I DOWN 0.00 9 9 Inpulse Test 3 Sensor De Sensor Vekxfty Rate bbls/da Direction Statistical Confidence AVGCPS I Gen On AVGCPS Gen ON 5W9.4 GR aN/A UP 0.00 1 19 21 5697.9 OAIF 8N/A UP 0.60 3 0 5697.2 OAIL aN/A UP 5697.9 FSBF aN/A UP 0.78 Se 1 26 5697.2 LSBF 8N/A UP 1 023 21 17 5710.2 GRN2 MN/A DOWN 1 0.00 a 9 HALLIBURTON TEST ZERO MOVEMENT Database File Dataset Pathname Presentation Format Dataset Creation Charted by Depth (ft) ELTIM (sec) m p u J_ 16_23_mar - 24-d b pass2 tmd3d_imp Thu Mar 28 14:3526 2024 Time scaled 360/hour 0 GEN VOLTS (V) 100 0 OAIF 200 0 FAR ACT 1000 -- - - - - -------------CT - --- OAIL 20010 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM M 111::, 11: 11: Im 100 120 140 160 uh Ull rw� 220 o r.l 11: 300 111::, 320 340 360 WE 11: Me m 11::Mmpwl 520 Ull b��td kill 11: 560 11: 620 111::, M. 700 720 740 760 WE 840 Depth (ft) ELTIM 0 GEN VOLTS (V) 100 FBKSUM (sec) 0 OAIF 200 0 FAR ACT 1000 LBKSUM ------------------------ 0 OAIL 2000 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAPI) -------------------------- 0 (GAPI) 500 HALLIBURTON TEST ZERO MOVEMENT TMD-3D Impulse Pass 2 Summary #N/A Weighted Average Velocity = 0 ft/min UP Weighted STD-0 Worn 0 Inpulse Teat t Sem Depth Sensor Velocity Rate bbls/day Direction Statistical Confidence AVGCPS Gen On AVGCPS Gen Off MA GR /WA UP /WA /N/A MA M/A OAIF MA UP /WA /N/A MIA /WA OAIL MIA UP M/A #N/A MIA /NIA FSBF /WA UP /N/A /N/A MIA /WA LSBF /WA UP /N/A MA MA MIA GR#2 /NIA DOWN /N/A MA MA In ube Test 2 Sensor De Sensor Vebcity Rate birls/day DirectionStatistical Confidence AVG CPS I Gen On AVG CPS Gen Off /WA GR /WA UP /WA MA MIA /WA OAIF /WA UP MA MA MA /NIA OAIL I /NIA UP MIA MA MA /NIA FSBF i /WA UP M/A MA MA M/A LSBF NN/A UP MIA MA MA M/A GR/2 I /WA DOWN MA MA MIA Inpulse Test 3 Sensor De Sensor Velocity Rate bbls/da Direction Confidence Confidence AVGCPS Gen On AVGCPS Gen ON /N/A GR /NIA UP MIA I MA MA /N/A OAIF /N/A UP MA MIA MIA /N/A OAIL /N/A UP M/A M/A MIA /NIA FSBF #N/A UP M/A MA MA /N/A LSBF #N/A UP 1 MIA MA MIA /NIA GR/2 MN/A DOWN I MIA M/A MIA HALLIBURTON FLOW SIMULATION Database File Dataset Pathname Presentation Format Dataset Creation Charted by Depth (ft) ELTIM (sec) m p u J_ 16_23_mar - 24-d b pass3 tmd3d_imp Thu Mar 28 14-58-05 2024 Time scaled 360/hour 0 GEN VOLTS (V) 100 0 OAIF 200 0 FAR ACT 1000 -- - - - - -------------CT - --- OAIL 20010 LONG ACT 1000 0 Upper GR (GAPI)500 -------------------------- Lower GR (GAPI) 0 (GAP)) 500 -------------------------- FBKSUM LBKSUM m 1097.1 1105.2 1113.4 .o Im 100 120 140 160 1121.6 1129.7 ►III 220 o ►.11 1137.8 300 1145.9 320 340 360 us 1154.0 1 400 420 1162.2 ME m !i 1170.3 1 500 520 540 1178.4 560 WE 1186.6 620 WE 1194.7 1202.9 1211.1 M. 700 720 740 760 1219.2 1 800 Depth (ft) ELTIM 0 GEN VOLTS (V) 100 FBKSUM (sec) 0 OAIF 200 0 FAR ACT 1000 LBKSUM ------------------------- 0 OAIL 200 0 LONG ACT 1000 0 Upper GR (GAPI)500 Lower GR (GAP]) -------------------------- 0 (GAPI) 500 HALLIBURTON FLOW SIMULATION TMD-313 Impulse Pass 3 Summary Impulse Test at: 1109.9' Generator at: 1096.3' Weighted Average Velocity =11.7 itlmin UP Weighted STD-0.50/min C WSMNeeaMalN MmW W L16M AMOW SNUUTtON.M Inpulse Test / Senor Depth Sensor Velocity Rate bblslday Direction Statistical ConOdence AVGCPS Gen On AVGCPS Gen Off 1085.7 GR EWA UP 0.86 85 18 1094.2 OAIF MA UP 0.79 110 1 1093.5 OAIL MA UP 0.76 83 1 1094.2 FSBF 12.2 464 UP 0.79 622 14 1093.5 LSBF /WA UP 0.78 4" 10 1106.5 GR/2 8WA DOWN 0.03 5 3 In ulse Test 2 Sensor Depth Sensor Ve" Rate bbloidav Direction Statistical Confidence JAVGCPS Gen On AVGCPS Gen Off 1005.7 GR 8WA UP 0.00 33 21 1094.2 OAIF 11.9 451 UP 0.85 109 1 7093.5 OAIL 11.3 427 UP 0.81 86 1 1094.2 FSBF 11.9 153 UP 0.86 635 14 1093.5 LSBF 11.1 4a UP 0.82 447 11 1106.5 GR02 OWA I DOWN 0.00 5 5 Inpulse Test 3 Sensor Depth Sensor Veloctty Rate bblsfdav DiracOan Statistical Confidence AVG CPS Gen On AVG CPS Gen Off 1005.7 GR BN/A UP 0.00 36 16 1094.2 OAIF 12.3 465 UP 0.91 112 1 1093.5 OAIL 11.4 431 UP 0.87 86 1 10942 FSBF 12.2 461 UP 0.95 670 17 1093.5 LSBF 11.4 433 UP 9.34 463 13 1106.5 GR82 MN/A I DOWN 0.00 5 7 HALLIBURTON BASELINE T E M P E RAT U R E Database File mpuJ_16_23_mar _24.db Dataset Pathname pass8 Presentation Format sdx_main Dataset Creation Thu Mar 28 16-01-43 2024 Charted by Depth in Feet scaled 1:600 0 Temperature - PRT (degF) 200 -------------------- 0 Pressure - QPC (psi) 5000 0 Gamma (x10 Offscale) (GAPI)150 CCL -200 Cable Speed (ff/min) 200 3000 Line Tens (lb) 0 5000 5050 5100 0 Temperature - PRT (degF) 20 ---------------------------------------- 0 Pressure - QPC (psi) 500 -------------------------- - -- --- - --- -- Temp -1 Diff Temp - PRT (degF) -1 ---------------- (degF) Press r 67.4 68.3 It 1706.3 1735.3 5150 5250 5350 5450 5500 72.1 1817.5 i 5550 5650 0 -------------------- Temperature - PRT (degF) 200 0 --------------------------------------- Pressure - QPC (psi) 5000 0 Gamma (x10 Offscale) (GAPI)150 CCL -200 Cable Speed (ff/min) 200 3000 Line Tens (lb) 0 A 0 Temperature - PRT (degF) 20 ---------------------------------------- 0 Pressure - QPC (psi) 500 -------------------------- - -- - - - Temp -1 Diff Temp - PRT (degF) 1 ----------------- (degF) Press HALLIBURTON BASELINE T E M P E RAT U R E HALLIBURTON CONFIRMATION PASS Database File mpuJ_16_23_mar _24.db Dataset Pathname passl7 Presentation Format sdx_main Dataset Creation Thu Mar 28 18-53-56 2024 Charted by Depth in Feet scaled 1-600 0 Temperature - PRT (degF) 200 0 Temperature - PRT (degF) 20 0 Pressure QPC (psi) 5000 0 Pressure QPC (psi) 500 ----------------------------------------------------------------------------- --------------------------------------- 0 Gamma (x10 Offscale) (GAP[)150 Temp -1 Diff Temp - PRT (degF) 1 ------------------- CCL (degF) Press -200 Cable Speed (ff/min) 200 3000 Line Tens (lb) 0 1.7MIX 17t,R : 61.10If: 5550 c-Mf 1.1:1.1f: i ►Aff-1 =i[:t/L1.1 72.8 --4- 1700.0 ; r r 'I I I It 0 Temperature - PRT (degF) 200 0 Temperature - PRT (degF) 20 0 Pressure QPC (psi) 5000 0 Pressure QPC (psi) 500 ----------------------------------------------------------------------------- ------------------------------F) --------- 0 Gamma (x10 Offscale) (GAPI)150 Temp 1 Diff Temp -PRT (degF) 1 ------ -------F) CCL (degF) Press -200 Cable Speed (ft/min) 200 3000 Line Tens (lb) 0 HALLIBURTON CONFIRMATION PASS Calibration Report Database File mpuJ_16_23_mar_24.db Dataset Pathname pass10 Dataset Creation Thu Mar 28 1638:58 2024 Temperature Calibration Report Serial Number: 1156824 Tool Model: PRT016 Performed: Mon Mar 25 13-05-43 2024 Point # Reading Reference 1 12943.00 cps 72.63 degF 2 18578.00 cps 107.60 degF 3 29432.00 cps 175.39 degF 4 40877.00 cps 24825 degF 5 51976.00 cps 319.32 degF 6 57510.00 cps 354.63 degF 7 cps degF 8 cps degF 9 cps degF 10 cps degF Calibration Report Serial Number: 217230 Tool Model: 003 Quartzdyne Pressure Gauge Gauge Model: SPBO08-16-177 Performed: 22 Dec 2007 Pressure Temperature Order: 3 3 Prescale Algorithm: 1 1 Scaling Factor: 0.01 0.01 Offset Frequency: 18946 55575 Minimum: 12 25 Maximum: 16000 175 Cal Units: psia Span: 1 Zero: 0 Coefficients- AO- 1.123840E+01 Al- -3.411860E-01 A2: -1.914710E-02 A3: 9.463840E-06 130: 4.106100E+01 131: -2.071350E-02 132: 2.628270E-05 133: -5.352850E-08 CO: -1.906330E-03 C1: 9.444840E-06 C2: -3.903590E-08 C3: 4.334420E-11 D0: 5.653750E-07 D1: -1.373990E-09 D2: 4.419050E-11 D3: 2.360180E-14 Quartzdyne Temperature Gauge Gauge Model: SPBO08-16-177 Performed: 22 Dec 2007 Pressure Temperature Order: 0 3 Prescale Algorithm: 1 1 JC811ng YaCIOf u-u I u-u I Offset Frequency: 18946 55575 Minimum: 12 25 Maximum: 16000 175 Cal Units: "C Span: 1 Zero: 0 Coefficients- AO- 2.507980E+01 Al- -7291630E-01 A2: -8.513980E-04 A3: -6.777110E-07 Gamma Ray Calibration Report Type / Serial: 020 / AJF00107 SHOP CALIBRATION Fri Jun 16 13-17-44 2017 Counts/Sec. Gain Offset Jig Units Background 18.9 cps Calibrator 216.4 cps 1.0533 GAPI/cps PRIMARY VERIFICATION Fri Jun 16 13:21:25 2017 Background 18.9 cps Calibrator 228.4 cps Difference 209.4 GAPI BEFORE SURVEY VERIFICATION Background 0.0 cps Calibrator 0.0 cps Difference 0.0 GAPI AFTER SURVEY VERIFICATION Background 0.0 cps Calibrator 0.0 cps Difference 0.0 GAPI Thermal Multigate Decay 3 Detector Calibration Report Serial -Model: 12262609-A Shop Calibration Performed: Mon Mar 25 10:4830 2024 Horizontal Water Tank S/N: 11227352 Generator S/N: CO672 Generator Total Usage: 46:30 (hr:min) VFP Mode Stabilization Result Logged Expected Value Diff. ToI. Units GENV 84.00 85.00 -1.00 +/-15.00 V ITCR2 2432 2500 -68 +/-250 cps Horizontal Water Tank Result Logged Expected Value Diff. ToI. Units FarTemp 77 <100 degF NPHV 1060 <1200 V FPHV 1336 <1400 V LPHV 1348 <1400 V OXRN 3.520 3.500 0.020 +/-0.200 OXRF 3.019 3.000 0.019 +/-0.200 OXRL 3.061 3.000 0.061 +/-0.200 COSR2 0.336 0.320 0.016 +/-0.050 LIS12 1.045 0.820 0.225 +/-0.400 TCCR2 1908 1500 408 +/-1000 cps ITCR2 2426 2500 -74 +/-500 cps Sigma Mode Stabilization Result GENV FCAP Horizontal Water Tank Spec Result FarTemp NPHV FPHV LPHV OXRN OXRF OXRL ty:>1:2�IIfi N/F Normalizer N/L Normalizer N/F Inel Norm N/L Inel Norm RNF RNL RINC RINCL SGFN SGFF SGFL FSIN LSIN FCAP LCAP NFTR FFTR LFTR NBKG FBKG LBKG RTN RTF Logged Expected Value Diff. Tol. Units 84.00 85.00 -1.00 +/-15.00 V 5748 5500 248 +/-500 cps Logged 77 1059 1339 1353 3.530 3.004 3.061 Logged 1.306 0.310 0.877 0.161 0.765 3221 1.141 6.199 23.840 22.780 22.100 16146 3111 5789 1376 0.96 0.91 1.16 127 82 20 0250 0250 HTMD3D Module 2021.5.14.0 TMD3D Module 2023.3.17.1 HTMD3D Module 2021.5.14.0 TMD3D Module 2023.3.17.1 Expected Value 3.500 3.000 3.000 Expected Value 1250 0290 0.910 0.169 0.770 3.300 1.100 5.900 24.000 22.850 21.800 14000 2750 5200 1200 0200 0200 Diff. 0.030 0.004 0.061 Diff. 0.056 0.020 -0.033 -0.008 -0.005 -0.079 0.041 0299 -0.160 -0.070 0.300 2146 361 589 176 0.050 0.050 Calibration Software Modules Env Module Log Data Acquisition Software Modules Env Module Gamma Ray Calibration Report �.S <100 <1200 <1400 <1400 +/-0200 +/-0200 +/-0200 Tol. +/-0200 +/-1.000 +/-0270 +/-1.500 +/-0.500 +/-0.500 +/-1.000 +/-2500 +/-500 +/-1000 +/-250 <5.00 <5.00 <5.00 <500 <500 <100 +/-0200 +/-0200 Units degF V V V Units cu cu cu cps cps cps cps cps cps cps usec usec Serial Number: 11224503 Tool Model: 002 Performed: (Not Performed) Calibrator Value: 1.0 GAPI Background Reading: 0.0 cps Calibrator Reading: 1.0 cps Sensitivity: 1.0000 GAPI/cps Sensor I Offset (ft) Schematic Description Length (ft) O.D. (in) Weight (lb CCL GR TFGT TNGT GR#2 CCL#2 QP#2 QTMP#2 TEMP#2 LLMTEN 26.42 24.16 15.69 14.74 CHD-1-7/16 (12345678) Monocable Head Assembly WT-1-11/16" 1.6875" WEIGHT BAR ROLLER _BOGGI E-1.69Roller 1 11/16" Roller with 2.0" Wheels WT-1-11/16"_Lead 1.6875" WEIGHT BAR ROLLER _BOGGI E-1.69Roller -1 11/16" Roller with 2.0" Wheels TTTCU-002(11224503) Through Tubing Telemetry Cartridge - Ultrawire XHU-003 (11983707) Crossover Halliburton 1553 to Ultrawire .-TMD3D-A (12262609) Halliburton TMD3D Tool 128 7.00 1.17 5.00 1.17 WLQIS�I 158 1 ME WISM1 XO1553LT6T1-101796586 0.14 6 TO 1 1553 LINE TERMITATOR 101796586 PGR #2 -020 (AJF00107) 192 3.44 Production Gamma Ray 2.07 QPC #2 -003 (217230) 1.58 141 Quartz Pressure/Collar Locator 141 PRT #2-PRT016 (1156824) 1.04 UW Platinum Resistance Thermometer 0.46 BUL-SNDX (10000766) 0.32 0.00 SNDX TERM - 5/8" SR 1.44 1.69 1.69 1.69 1.69 MCI:M 1.69 1 iR*MlI 1.69 1.69 1.69 1.69 1.69 1.50 84.00 3.00 48.00 3.00 Lf:�rP1■ 7.00 3.00 9.50 8.80 6.00 1.50 Dataset: Total length: Total weight: O.D.: mpuJ_16_23_mar _24.db: field/well/runt/pass10 44.10 ft 293.30 lb 1.69 in Log Run Sheet LoUPasss StilbW R EV"Is Pass Start Tn11e EndThde Start Pass Depth End Pass Depth Direction Line Speed Comments PASS? 1500 1505 SURF 300 DOWN 50 RIH PASS2 1515 000 1000 1000 STATION 0 TOOL CHECK PASS3 1545 1615 1050 1253 DOWN 10 TOOL CHECK FLOW SIMULATION PASS4 1615 16:45 1260 4900 DOWN 160 RIH PASS5 1645 1655 4900 5590 DOWN 100 CORRELATION PASS6 JUNK PASS7 1655 1700 5400 4990 UP 60 CORRELATION PASSE 1700 17:15 4990 5750 DOWN 60 BASELINE TEMPERATURE PASS9 1715 1724 5750 5390 UP 60 CORRELATION PASS10 1 17:30 1 18:00 5700 1 5700 STATION 0 IMPULSE TEST 5700 PASS11 18 00 18 15 5650 5650 STATION 0 IMPULSE TEST 5650 PASS12 18.18 18.37 5600 5600 STATION 0 IMPULSE TEST 5600 PASS13 18 45 19 00 5550 5550 STATION 0 IMPULSE TEST 5550 PASS14 19:06 19:25 55M 5500 STATION 0 IMPULSE TEST 5500 PASS15 1927 1948 5450 5450 STATION 0 IMPULSE TEST 5450 PASS16 JUNK PASS17 20 00 20 05 5760 5350 UP 60 CONFIRMATION PASS PASS18 2005 2053 5350 SURF UP 150 POOH I EL Company HILCORP ALASKA, LLC. Well MPU J-16 Field MILNE POINT County N. SLOPE HALLIBURTC1I State ALASKA WATERFLOW LOG • Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i qs- i6q File Number of Well History File PAGES TO DELETE Complete RESCAN ❑ Color items - Pages: ❑ Grayscale, halftones, pictures, graphs, charts - Pages: ❑ Poor Quality Original - Pages: ❑ Other - Pages: DIGITAL DATA ❑ Diskettes, No. ❑ Other, No/Type OVERSIZED ❑ Logs of various kinds ❑ Other COMMENTS: Scanned by: Bever! Dianna Vincent Nathan Lowell Date: 2,j , /► 1 /s/ ❑ TO RE -SCAN Notes: Re- Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /s/ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5 . J FEB 2 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 .! Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPJ -Pad 9/512011 Corrosion 1 Vol. of cement Cement top off Corrosion inhibitor/ Well Name, PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ-05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/212011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/212011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 x---> MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 820/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/12009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8212011 MPJ -26 2040640 50029232050000 1.2 NA 12 NA 11.9 8/20/2011 SENT BY: BPX-i~IPOC ;12-18-98 ;11'28A~ ; BPX-MILNE POINT~ BPX Milne Point Unit J-16i Increased Monitoring Program 907 276 7542;# 1/ 1 Post4te Fax Note 7671 bo./O~Pt Phone J ' Report to AOGCC MONTH: November YEAR: 1998 Date i' WHP " lAP OAP RATE Comments 'Initials 1' 2448 2300 170 368 JB 2, 2441 2380 170 336 JB 3 2430" 2:)50 180' 3~14 ....... JB '_..4' 2431 2250 1'1~0 327 .... .JB- 5 24,;{0 2230 '~75 362 ......... JB 6! 2413 "2220 ' 170 291 " JB ,, ,, ,, , 7 2427 2230 170 380 JB ., , 8 2422 2230 170 320 JB 9 2438 2230' ~ 170 331 ...... JB 10 2359 2250 160 277 JB 11 2369 ....... 2250" 160 258 ' " JB .. ,,, . . . 12 2359 2460 160 244 JB 13 2393 2460 160 298 JB 14 2364 245 JB '~5 2378 2220 160 283 ..... JB ~ 16 2369 22~0 ~60 272 ~[~',~i'~?~ .... ~B 17 2368 2220 '1~0 254 jB 18 23~ 2~0 160 258 DF~ ~ 8 ~. jS "19 2388 2220 160 266 'JB 20 2391 2220 160 263' ~~&~~~ - JB , , ,,, , ~ ~'--L -~ 21 2394 2240 160 862 '~~ JB ., ~ 22 2403 2220 160 268 JB ,, ,, 23 2389 2220 160 254 JB , ,, 24 2405 2220 160 266 JB 25 2374 2210 165 361 JB 26 2374 2210 165 361 JB 27 '2388 2200 170 638 JB ,, 29 ~ ~. JB 3~ ...... JB ..i . iii i Ave. 2,3~ 2,170 159 332 ~Monthly Averages SUBMIT TO THE OI ADVISOR AT THE END OF THE MONTH Verified true ~_ccurate ltllP~/O/~ll~a~ns Integrity Advisor Date PAA/JAD Nile, Son Do~umeots > &1Gl Inm'eas. d Mo.itodng Program """, CANNED DE C l 9 2002 09/06/98 TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ANNULAR INJECTION 'DATA ENTRY SCREEN Asset Milr~.e. .......................................... Rig Name ~.~t~.Qr.$..22F,, ......... ; ............ ....... Inj Well Name M.P..,,I.:.I.IL., ......... ~ ....................... Sur Csg Dep :~.1..'1.2 ................ Cumulative Data, Well Total Mud/Ctg Permit Start ..;.....1.:1.~/.1.2[.9.~ ..... i. Legal Desc 23'.1.Z:bI~iL,..:3.3.:3.6.'.~.EL,..Seg.~B.,.'['.:I.3.~,.B.1.0~ .................................. Researc~C~ED [~0V 1 ~ ~:~{~ Permit End ....... ~.2/.:~.1/.~.5.... .... Rig. completion FormatiOn lntermittant Final Wash Fluids Fluids Freeze Freeze RigW~ Daily .Data ~ FonTalion Freeze Freeze Daiy 170 ~50 1~5 ~ ................... ~ ................. IWell [riec-li~ Ddg Mud MPJ-16 11/13/95 170 MPJ-16 11/14/95 250 MPJ-16 11/15/95 125 MPJ-16 11/16/95 310 are.d rvlces rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, 'AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 14 1998 Naska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with Our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are proVided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #2, K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K.21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a SUndry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and june 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From thOse records, we show the following wells not listed on your report were used for annular disposal: ,. ,Annular Disposal Letter .', 12/14/98 ~4 - ~?~ q4- ~-z. q~ -~5'z. · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - ~' o o ~ ~ },~ Mdn~Pointwellsf-06, H-05, H-06, J-13, L-24 - qs-o~ PBU wells-18-30, 18-31, 14-~,~43, ~-34, E-36, G-~A, ~d S-33-'~'"°~ ~dividud logs are provided to ~ou f6f thes~ ~ogs as w~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these recordS. If I can be :of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED Maska Oii& Gas Cons. Commissior~ Anc,,hora~o har(ll'd Se~ice Dlilling nn~ar Injection Volumes L~ly 25, 1995 until December 1998 umulative Report Surface Casing ;I Inj Well Depth Legal Desc ~dicott Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End Status ~yon 15 1-19/I-18 5000 Sec. 36, T12N, R16E 8,960 7,848 992 120 12/5/95 12/5/96 Open ~yon 15 1-23/O-15 4246 2020'FNL 2087'FEW, SEC.36.T12N,R16E 32,084 30,604 1,160 200 120 9/30/95 12/31/95 Open ~yon 15 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36.T12N, R16E 9,879 9,729 150 8/31/95 12/31/95 Broached ,yon 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N. R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open · . ~yon 15 2-40/S-22 4531 2020'FNL, 2289'FEL, Sec 36,T12N, R16E 31,195 29,952 1,063 120 60 7/25/95 12/31/95 Open )A ~ .o.~...!.~ ............. !.5.-.47 3515 3648'NSL, 4956'WEE, Sec 22,T11N, R14E 3,002 903 2,009 90 11/7/95 12/31/95 Open yon 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11 N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached yon 14 DS 15-48 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open yon 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open yon 9 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N R14E 2 266 936 380 800 150 7/25/95 12/31/95 Open yon 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R14E 6,086 2,250 1,100 2,565 171 7/26/95 12/31/95 Open yon 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,3! 1 1,861 200 1,100 150 8/24/95 12/31/95 Open yon 9 18-33 4140 3690'NSL, 56'WEL Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open bors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open bors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open . bors 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open b..o..r.~..!~E- ...................... !.~;.~.~. .................................... .3. . .2... .8. ~. ................................ 2..~..2.9..i. US...L..,_.?..!...7.'...W_EL.:.....S..e.c_?_,..T_I_O_N?..!..~E- ............................ ..3..i..9.7..~ ................................ ..2,...3..!.~ ............................... ?.~ .............................. !_2_0__~./?~ ............... 1~_3.!?_5_... ...... _O..p...e_n_ ........ ploration Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed ne 7E MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR11E 19,608 18,538 285 685 !00 4/18/96 4/18/97 . Open 3ors 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open 3ors 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 , 140 1/5/96 1/5/97 Open ~ors 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 100T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open ~,o,,r, ,'~,..,2, 2,,E.,.,,,,.,: .............. ,M, ,,,~, ,C, ,=.2,,? .............................. , ,5,~0.,.~ ................................ . ,S.,,~,,c,,,,?, (~,', T. !, .3.U '.,,,,R, ,.!, °..~ ..................................................................................................................... ~2r.~ ...................... ................. ~.~,9. .............................................................. i,,,..i .......................................................................................................................................................................... ,,7,~ ............... ..~, ,.!.,,5,!~ ......................... ,2~, 4 !. ,5,~, ~9,7. .............................. .0, .p, e,,, .n., ................ , Page 1 Shar.~d Service DHIling Annul' ~r Injection Volumes July 25, 1995 until December 1998 Cumulative Report Surface Casing Cum Mud Cum Rig Rig Inj Well Depth Legal Desc Cum Total & Ctgs Wash Nabors 22E MPF-06 8766 Sec 06,T13N, R10E 1,927 1,731 Nabors 22E MPF-14 6690 Sec 06,T13N, R10E UM 18,717 17,107 1,270 ~labors 22E MPF-70 7919 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 ~labors 22E MPH-05 5335 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 Cum ComPl Cum Form Cum Interm Cum Final Disposal Period Fluids Fluids Freeze Freeze Start End 196 1/25/96 1/25/97 340 6/3/96 6/3/97 190 56 6/17/96 6/17/97 190 8/19/95 12/31/95 Annulus Status Open Open Open Open ~labors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open ~labors 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31/95 Open qabors 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 Open ~labors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28.T13N, R10E 985 915 70 11/12/95 12/31/95 Open qabors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 1/25/96 1/25/97 Open qabors 27E MPF-22 8841 Sec06.T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open qabors 27E MPF-25 3405 1857'NSL, 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 225 65 12/26/95 12/26/96 Open ~.b._°.,,?,..2...7.~ ................... .M.P.,.F,.:,,3.,7,. ............................ ~.~,! ................................... !..~3_!?S_..L.;_2~3_i~,.EL.'.,,,S.~,c..~..T.,.?..,3,,,.N.'....,R_?_E_ .......................... ??.2. ......................... t'.S..8_7. .......................... 7. o_ ................................................................................................................................................... ..75 ........... .7,./,.2.?.5. ..................... !?,.3.!~.g,,.,5' ............ Optn- ~labors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' O3en ~labors 27E MPF-53 6750 2028'NSL, 2572'WEL Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 O:)en ~labors 27E MPF,61 6585 2077'NSL, 526'WEL; Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 12/31/95 O~en ~labors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 O3en ~labors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 75 8/31/95 12/31/95 O~en ~labors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40. 775 65 140 9/12/95 12/31/95 O )en ~abors 27E MPL-24 6515 3654'NsL, 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165. 335 70 11/27/95 12/31/95 O )en ¥OA . 8E F-33 3570 3332'NsL, 2174'WEL, Sec 2,TllN, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open 8E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 . 135 12/18/95 12/18/96 Open )oyon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1~035 140 1/31/96 1/31/97 Open )oyon 9 D-31 32i5 SEC. 26, T11N, R13E 150 150 4/20/96 4/10/97 Open )oyon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, .T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open ~abors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R 12E 5,943 2,636 1,716 Page 2', . . 1,511 80 5/7/97 . 5/7/98 OPEN Shared Sei~/ice Dr. illing Ann~i~'r injection Volumes July 25, 1995, until December 1998 Cumulative Report Surface Casing Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Rig Inj Well Depth Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End Status Nabors 28E B-33 3504' 969'SNL, 1898'EWL, Sec 31, Tt 1N, R14E 3,974 2,842 857 195 80 5/1/96 12/31/96 Broached . . . Nabors 28E E-34 3664 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open Nabors 28E E-36 3648 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 Open Nabors 28E E-37 3810 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Open Nabors 28E E-39 3638 3358'NSL 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A . 3509 . 291.~iN~i:.,..1.9.7.4_,.WE~L, sec 12.!T!.1N, R?.3E ............. .5,...9.3~ ............... !.,?~.8. !.!~? ....... 2~3.!.? !°/2°/95 12/31!9..5. .............. ..°.pe? Nabors 28E G-21 3509 2911'NSL 2368'WEL, Sec 12,Ti 1N, R14E 11,430 3,956 3,072 4,270 70 62 9/8/95 12/31/95 Open Nabors 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 O3en Nabors 28E S-33 2958 1639'SNL 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 O3en Nab~l?.~.8..E ............. ~.;.4..1. ............................. ~..3..1. .................... 4.1.5.2'.. ?..S..L,.....4..5.0.~;....W....E.~7....~ ?...3..5.t...T.. ! .2..N.,. ............................................... ..8..,?~2. .......................... ~!..5...9 ....................... 2,.0....~.. .......................... !j...7.~!' 115 2/6/96 2/8/97 o:)en Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 O3en Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 O3en Nabors2ES H-36 3550 4478'NSL, 1265'WEL, Sec21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 O3en Page 3 W 95-- 169 6957 ~DRESSE~;' ,SR :} 150 .... 'i 'i989 R 9 ~S '/ ~; ,'3 H L !^.1 I,~ ,;? I3, R/' C D i'q i::: !:~ '~ .[7..:, Q i ,' "(', C. 2., i.fl./ ..: 2/"' 'i :-) ,/' 9 5 A :' e d r" y ~..'J 'i 't c h s a m p 'J e s v ::- ::~" Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska99518 o 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) December 12, 1996 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD Depth Corrected CDR, CDN for well MPJ-16 (Redo), Job # 95386 was sent t BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 9951 9-6612 1 OH LIS Tape State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive 1 OH LIS Tape Anchorage, AK 99501 OXY USA, Inc. Attn' Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape Sent Certified Mail Z 777 93 937 511 * Redo due to use of TVD data instead of MD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO' BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 9~~IVED Date Delivered: DEC 1 3 t996 -Alaska (,"il & Gas Cons. Commission ~chora~e Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,....clL, N APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon __ Suspend ___ Op.ra[iun ShL4down ~ Re-~ter suspended well ~ Alter cas!n9 __ Hepalr wail __ Plugging __ Tirna e×ten~ion .__ Stimulate ~ Change approved program Pull tubing ___. Var.:a,'c~ X Perforate __ Olher __ 2. Name of Operator BP £xp_i_o_rat_.!on_ (A_.!~Ska) Inc. 3. Address P. O. Box 198612, Anchorage, Alaska 99519.661Z Location of well at surface 2317'NSL, 3336' WEL, SEC. 28 ,TI3N, RIOE At lop of productive interval 4689'NSL, 1007' WEL, SEC. 20 ,T13N, R10E At effective depth At total depth #921' NSL, 1233' WEL, SEC. 20, T13N. RIOE 5. Type of Well: Development _.. FY.~'Or_~IOry __ Stmf:grachi¢ __ EBrvice _X. 6. Datum elevation (DF or KB) 64' 7, Unit or Property name MILNE POINT UNIT 8. Well number MPJ-16i 9. Permit number 95-169 10. APl number 50- 029.22615 11. Field/Pool MPU. KUPARUK RIVER SAND feet 12. Present well condition summap/ Total depth: measured true vertical Effective depth: measured true verdcal 12212' feet 7476' feet 12064' feet 7363' feet Plugs (measured) Junk (measured) ORIGIIq Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 2~0 SX arctic ~ef I 650 ~ pf 'e', 250 sx 'g' 399 sx class 'g' 112' 20" 3113' ~5/8" 10553' 7' 1852' 5" 532 sx class 'g' measured (11655'-11665') (11724'-11796') Measured d~t~ 112' 3113' 10553' 12203' true vertical (7057'-7065`) (7106'-7162,') Tubing (size, grade, and measured depth) 3.1/2", 9,3#, L.80 NSCT tubing, (10308') Packem and SSSV (type and measured depth) 7" Baker S-3packer (10289'), No SSSV True vertical depth BKB 112' 2584' 6293' 7467' RECEIVED ,,_~EC 0 £ 1996 Alaska 0il & Gas Cons. C0mmiss Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch ...... MPU requests approval to follow AOGCC and MPU resolution p/an. Attacl7ed well telex of ~bg arrd annulus psi fast dated 6/I 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Chuck $cheve 6/15/96 Date approved 15. Status of well classification as: Oil __ Gas __.. Service Water injector Suspended__ 17. ! hereby certify that the foregoing,J~ true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Cor,ditiur,s of approval: Notify Commission so representative may witnessI Plug integrity ......... BOP Test__ I_nc~tion clearance Mechanical Integrity Test ~ Subsequent form required Original S Approv* by order of the Comm*,,o, "~vJd W, dohpstoD OommlssJo~r Date suBu~ Form 10,403 Rev 06/15/88 .a. pproved Copy Returned , BP EXPLORATION (ALASKA) Milne Point Unit INC. TO: S. Rossberg FROM: J. Fox DATE: 08 / 12 / 96 RE- MP J-16i High Pressure Breakdown SERVICE CO'S.: BJ, Peak JOB SUMMARY STEP RATE INJECTiVITY TEST Design Rate, Stg. vol. Max Rate, Treating IS'IP, Treat grad, psi/ft BPM Pumped bpm Press., psi psi 0.25 3.0 25bpm, 1750 0.68 4700 psi9 0.5 I .3 25bpm, 1850 0.70 4700 psig 1.0 2.7 25bpm; 2074 0.74 4700 psi9 2.0 4.1 25bpm, 2280 0.76 4700 psi9 3.0 6.7 25bpm, 2460 0.79 4700 psig 4.0 9.2 25bpm, 2660 0.82 4700 psi9 4.6 I 3 25bpm, 281 0 0.84 4700 psi~l 5.0 I 7 25bpm, 2895 0.85 4700 psi9 6.0 1 3.8 25bpm, 311 5 2500 0.88 4700 psi9 * Not compensated for friction pressure HIGH PRESSURE BREAKDOWN Stage Fluid type / vol. Target Initial Final Prop. vol. / ISIP No. max. rate / rate/ mesh rate / STP STP STP 199.8 bbl. of 20 25 11.3 20.2 not appl. 2850 one ppt linear ~lel 4700 4600 4636 10/23/96 DATA FRAC & FRAC 11:58 AM SENT VIA MICROSOFT MAIL BPM I PSIG PSIG BBL BBL PU. lNG SUMMARY COMMENTS 199.8 bbl. ~f 20 25 20.3 20.2 not appl. 3000 two ppt linear ~lei 4700 4550 4669 199.8 bbl. of 20 25 21,5 21,5 not appl. 3000 three ppt linear gel 4700 4649 4860 199.8 bbl. of 20 25 21.0 20,1 not appl. 3100 four ppt linear gel 4700 4641 4700 Notes on operation: - Experienced problems recording proper rates dudng the step rate test due to faulty electronics. The rates and pressures were however recorded and maintained accurately w/local readouts. Comments -- Injection rate before the well was shut in for this stimulation job was 1550 bpd at 2580 psig. The rate following the procedure was 2200 bpd at 2600 psig. There appears to be a significant increase in injectivity although somewhat tess that what was seen in previous HPBDs. - Based on the step rate test the formation broke down at approx. 2100 psig and 2 bpm. This is however not supported by subsequent ISIPs. - Gel breaker was not used in any of the stages. - Rates were steadily increasing over the first half of the first stage. It is suspected that this is primarily due to the reduction in friction pressure as the gel is displacing the seawater in the tubing. - ISlPs increased somewhat throughout the job. - The reported pressure communication between the tubing and annulus was small enough that it was negligible during this period of high pressure pumping. L,,.DATE/TI M E 08 /11 / 96 PM 1030 1045 08 /12 / 96 O83O 0930 1006 1037.5 1107 1119 1152 1202 1230 1241 1311 1329 1410 2030 OPERATIONS SUMMARY Following C-17i HPBD move tanks and equipment to J-16i and partially setup. Fill tanks w/1050 bbl. of 70 deg. F seawater. Inj. rate = 1550 bwpd @ 2500 psig. Water injection plant went down. Shut in well. Rate = 0 bpd. lAP = 2270 psig., OAP =175 psig. MIRU remaining BJ equipment. Pressure tested surface lines to 5000 psig. STEP RATE INJECTIVITY TEST Start Step rate test pumping seawater at min. rate of 0.25 bpm. Steping up rates once pressures stabilize. End step rate test at 6 bpm. Shut down pumps and monitor surface falloffpressures. ISIP 2500 psig. HIGH PRESSURE BREAKDOWN Switch to 20 ppt linear guar gel and sart pumping first stage of the HPBD. Rates limited by the max. surface treating of approx. 4700 psig. Continue to increase rates to maintain 4700 psig as the gel displaces the seawater in the tubing. Rates stabilized once the tubing_ was loaded. With 200 bbls. pumped shut down pumps to allow time for pressure to fall off and the fracture to close up. Start second stage by bring rates up to the target (max. allowable) surface treating pressure of approx. 4700 psig. With 200 bbls. pumped shut down pumps to allow time for pressure to fall off and the fracture to close up. Start third stage by bring rates up to the target (max. allowable) surface treating pressure of approx. 4700 psig. With 200 bbls. pumped shut down pumps to allow time for pressure to fall off and the fracture to close up. Start fourth stage by bring rates up to the target (max. allowable) surface treating pressure of approx. 4700 psig. With 200 bbls. pumped shut down pumps. Record ISIP and start rigging down frac fleet. Put well back on injection at2200 bwpd /2600 psig. Injection rate = 1910 bwpd at 2487 psig. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 08/12/96 INJECTIVITY TEST DISPLACEMENT = ### BBLS ' PUMPING SUMMAR TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1 004 0 171 9 161 3 0 0 Prepare to start step rate test. 1006 0.25 1656 0.5 0.5 Start pumping at minimum rate and allow pressure to stabilize before increasing rate. 101 7 0.25 1729 1750 3.0 3.0 Pressures stabilized - increase rate. 1017+ 0.5 4.3 4.3 Rate stabilized 1020 0.5 1850 Pressures stabilized - increase rate. 1020+ 1.0 1941 4.7 4.7 Rate stabilized 1023 1.0 2074 7.0 7.0 Pressures stabilized - increase rate. 1023+ 2.0 1729 2197 7.7 7.7 Rate stabilized 1025 2.0 1729 2280 11.1 11.1 Pressures stabilized - increase rate. 1025+ 3.0 2375 12.0 12.0 Rate stabilized 1027 3.0 1739 2460 17.8 17.8 Pressures stabilized - increase rate. 1027+ 4.0 2608 19.0 19.0 Rate stabilized 1030 4.0 2660 27.0 2.,0 Pressures stabilized - increase rate. 1030+ 4.6 171 9 Rate stabilized 1032 4.6 2810 40 40 Pressures stabilized - increase rate. 1032+ 5.0 1700 2884 Rate stabilized 1035 5.0 1690 2895 57 57 Pressures stabilized -increase rate. 1035+ 6.0 1690 3101 Rate stabilized 1037.5 6.0 1661 3115 70.8 70.8 Pressures stabilized - shut in Pump and allow fracture to close up. Monitor surface pressures. ISIP 2500 psig. 1042 2173 1047 1980 1052 1862 1057 1816 1102 1786 1107 4593 .. HIGH PRESSURE BREAKDOWN Stage 1 1107 0 1680 1769 0 0 Prepare to start HPBD. 1108 11.3 1748 4600 7 7 Establish rate at max. allowable STP. 1111 13.6 1729 4539 50 50 1115 18.4 1671 4338 100 100 1116 19.1 1661 4483 116 116 Gel on perfs. 1117 20.3 1661 4609 150 150 111 9 20.2 1651 4636 199.8 199.8 Shut down pumps and allow fracture time to close. Monitor pressures. ISIP = 2850 psig. 1124 0 2594 1129 0 2429 1134 0 2303 1139 0 2211 PUMPING SUMMAR. TIME RATE ]ANNP WHP STAGE CUM COMMENTS BPM ]PSIG PSIG BBL BBL 1144 0 2146 1149 0 2097 Stage 2 1152 0 171 9 2074 0 200.1 Prepare to start second stage. 1155 20.3 1768 4550 54.2 254.3 Established rate at target (max. allowable) pressure 1158 20.2 1729 4630 100 300.1 1200 20.2 1729 4654 150 350.1 1202 20.2 1719 4669 200 400.4 1207 0 2685 1212 0 2550 1217 0 2448 1222 0 2368 1227 0 2303 Stage 3 1230 0 1778 2271 0 400.4 1233 21.5 1846 4649 30 430 Established rate at target (max. allowable) pressure 1234 21.5 1836 4740 50 450 .. 1237 21.5 1826 4800 100 500 1239 21.5 1807 4836 150. 550 1241 21.5 1797 4860 199.8 600.2 1246 0 2750 1251 0 2629 1256 0 2537 1301 0 2437 1306 0 2183 f 1311 0 1884 2042 0 600.3 Stage 4 1311 0 1884 2042 0 600.3 1313 21.0 1914 4650 33 6333 Established rate at target (max. allowable) pressure 1315 21.0 1894 4641 50 650.3 · 1316 20.1 1884 4740 100 700 1318 20.1 1884 4784 150 750 1321 20.1 1855 4714 200 800 1321 20.1 1846 4700 210.7 811.0 Utilized as much gel as possible out of the hydration - shut down pumps and monitor pressures for ISIP of 3100 psig. 1325 0 1855 2827 1329 0 1875 2837 End of job. Rig down frac fleet. TIME RATE BPM IANNPI WHPI PSIG IPSIGt PUMPING SUMMAR STAGE C U M BBL BBL COMMENTS age 7 , FLUIDS PUMPED DOWNHOLE INJ TEST: 71 Bbls HPBD: 811 Bbls 882 TOTAL FLUIDS PUMPED DOWN HOLE 0 Diesel to IA, tubing, or GC O Diesel Recovered (not downhole) 0 Total Diesel JINONE PETREDAT WINDOW GEL QUALITY CONTROL CHECK SEA H20 SEA H20 20# GEL 20# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH HPBD 7.6 68 7.6 14 6 min n/a n/a FLUID ADDITIVES GBW-4 GBW-12 X-cide NEl18 '11-19-96 ' 7:51 ' BPX-MILNEPOINT~ 907 276 7542;# 1/ 2 BP MILNE POINT FACSIMILE TRANSMISSION COVER SHEET DATE: NUMBER OF PAGES' ~ PLUS COVER TO' .~,~... LOCATION' ,~.,'c~, FAX NUMBER: LOCATION: ]~,~r,. F,~,~ TELEPHONE: SPECIAL INSTRUCTIONS- RECEIVED N0V 1 9 1996 Alaska 011 & Gas Cons. Oommissic Anchorage FACSIMILE REPLY NUMBER: CONFIRMATION NUMBER: (907) 659-6390 (907) 659--6300 C:\DATA\FAA\LOTUS\FAX I l/18/96 To · Blair Wondzell From' Mark O'Malley ( MPU Well Cps Coordinator ) Subject · Ml'J-16i (1.-4-96) Completion .packer test.. Witnessed by Lou Grimmaldi. A small leak was discovered from the tubing to the annulus, (6/11/96) A pre initial Mechanical Integrity test was performed by Matthew Linder at that time the leak was conl'irmed. (6/15/96) A verbal notif, ication was given to AOOCC Inspector Chuck Scheve. q'hc injector was rcstri, cted to water and monitored weekly from that point. (10/22/96) The 4-year MI'i' was performed with Bobby Foster. The tubing and annulus was within 100 psi of each other. The annulus was bled down 1000 psi. The well gained 80 psi during a 3{) min. test. '['his well will I,all under our Casing Pressure Resolution Program (CPRP) and will be tested on a 6-month rotation. The well witl continue to be a water injector with the annulus pressure monitored weekly. Thank you, Mark O'Mallcy ....STATE OF ALASKA .~LASKA OIL AND GAS CONSERVATION COM~.oSION APPLICATION FOR SUNDRY APPROVALS ,, rype of Request: Abandon SuSpend ___ Operation Shutdown ~ Re.enler suspended well ~ Alter casing __ Repair well ..... Pluggin.q ~ Time extension ~ Stimulate Change approved pr~.jram ....... Pull tubing __ Vel'lance X Perforat~ ... Other __ 2. Name of Operator BP Exploration (Alaska)/nc, 3, Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4_ Location of well at surface 2317'NSL, 3336' WEL, SEC. 28 ,T13N, RIOE At top of productive interval 4689'NSL, 1007' WEL, SEC. 20 ,T13N, RIOE At effective depth At total depth 4921' NSI_, 1233' WEL, SEC. 20, T13N, RIOF. 5, Type of Well: D~velopment Exploratory .... S~ratlgraphiu . 6. Datum elevation (DF or KB) 64' 7. Unit er Property name MILNE POINT UNIT 8, Well number MPJ- 16i 9. Permit number 95-169 10. APl number 50.029-22615 11. Field/Pool MPU- KUPARUK RIVER SAND feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12212' feet Plugs (measured) 7476' feet 12064' feet Junk (measured) 7363' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 112' 20" 250 SX arctic set 3113' 9.E/8" 650 sxpf'e'.,250sx'g' 10553' 7" 399 sx class 'g' 1852' 5" 532 sx class measured (1 ~E55'-11665') (11724'-11796') true vertical (7057'-7065') (7106'-7162') Measured cl~l~ 112' 3113' 10553' 12203' Tru~/~rtical depth 112' 2584' 6293' 7467' Tubing (size, grade, and measured depth) $.1/2", 9,3#, L-80 N$CT tubing, (10308') Packers and SSSV (type and measured depth) 7'Baker $-3packer (10289'), No SSSV 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch __ MPU r~que.~ts approval to follow AOGCO and MPU resolution plan. Attached well telex of tbg and annulus psi test dared 6/11/96, 14, Estimated date for commencing operation 16, If proposal was verbally approved Name of approver Chuck Scl;eve 6/1~g~ Date approved 15, Status of wcll classification as: 0il __ Gas __ Service Water injector Suspended__ 17. I hereby certify that the foregoing Is true end correct to the best of my knowledge, Signed ~"~ ~ Title FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ......... BOP Test ~ location clearance Mechanical Integrity Test / Subsequent form required 10-(-.~,'~,~-~ I Approval No,30~_ ~ j ~ , Approved by order of the Commission Commissioner Date --orm IO-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PRUDHOE BAY, ALASKA TO: Hendrix/Stevens FROM: Matthew Linder WELL# Main Category: Sub Category: ILeak d_e_tect Operation Dale: 10 6Ji 1 / 9 6 Date: I06/11/96 Cost tracking: D..iZ~ctive' Set 3.5" XXN plug in tallpipe and pressure test tubing to evaluate tubing integrity. Rigged up camco wireline line and drifted tubing t° 3000'. RIH and set a 3.5' XXN plug at 10276' wire. Rig up HB&R. Pressure test hose to 3800 psi. Pressured up on tubing to 3500 psi shut down and monitor well. Tim.e: Tub.jng PSI .... _I.A.P..SI O,A. P_S! Initial shut in pressure 1000 psi 1260 psi 160 psi 18:33 3500 psi 1380 psi 160 psi 18:48 3310 psi 1440 psi 160 psi 18:54 3125 psi 1460 psi 160 psi 19:00 3025 psi 1480 psi 180 psi 19:10 2850 psi 1520 psi 160 psi 19:21 ___2700 o~i f1540 psi 160 0si Loss 800 psi Gain .;I-eO"psi Bled tubing pressure back to 1000 psi, inner annulus dropped to 1420 psi. HB&R's pump truck developed a internal leak while blaeding back tubing pressure. After 30 minutes, inner annulus continued dropping to 1280 psi. Ran in hole and pulled 3.5" XXN plug. Conclus. lon.' With a good test on the wellhead the night before and from the results above, it appears the tubing has a very slow leak. These finding also reflect back to tl3e RWO reports dated 1/4/96, setting of production packer. Returned well to injection. TD Wireline Depth__ TD Measured Depth: .... ~ STATE OF ALASKA .... ?~'~-~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-169 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22615 4. Location of well at surface ~:'2..~e...,.~ ,. ,~..:: ~ 9. Unit or Lease Name 2317' NSL, 3336' WEL, SEC. 28, T13N, R10E !" i:?i,.:'.','::'(i::i:i i~.! ti "i ......~(,~... ~ _.,.. _~ Milne Point Unit 4689' NSL, 1007' WEL, SEC. 20, T13N, R10E ~' MPJ-16i At total depth ~ ~~ · . ........ 11. Field and Pool 4921' NSL, 1233' WEL, SEC. 20, T13N, R10E ~ -~~ -- Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Sands KBE = ~'~ ADL 025515 17. Total Dopth {MD+WD) ~ 18. ~lu~ Back Depth {MD+W~ 1 ~. ~iroctional Sumoyl2o. Dopth whoro SSSV sot ~1. lhickness ol ~ormafrosl 12212 7476 F~ 12064 7363 F~ ~Yes ~No I N/A MD/ 1800' (Approx.) 22. Type El~tric or Other Logs Run SBT, MWD, LWD, EMS, GWCBUCCL 23. CASING, L~NER AND CEME~ING RECORD CASING S~ING DEP~ HOLE SIZE ~. PER FT. G~DE TOP ~OM SIZE CEME~NG RECORD 20" 91.1~ H-40 ' 32' 112' 24" 250 SX Arcticset I (Approx.) 9-5/8" 40~ L-80 31' 3113" 12-1/4" 650 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 7" 26~ 'L-80 28' .10553' 8-1/2" 399 sx Class 'G' 5" 15~ NT13CR80 10351' 1'2203' 8-1/2" 532 sx Class 'G' ~0V Aia~ ~ ~u ~ u~ ................. 24. Pe~orations open to Production (MD+TVD of Top and BoSom 25. TUBING RE. RD and inte~al, size and number) SiZE DEP~ S~ (MD) PACKER S~ (MD) 8-8/8" Gun Diameter, 6 spf 8-1/2", L-80 10809' 10289' MD ~D MD ~D 11655'-11665' 7057'-7065' 11724'-11796' 7108'-7162' i26. ACID, F~O~RE, CEME~ SQUEAL, ~C. DEP~ I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/80 bbls diesel 1~65s'-~665',~724'-~7~' Frac'd w/800 bbls, 20 ppt Linear Gel 27. PRODUO~ON TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 6, 1996 ! Water Injection Date of Test Hours Tested PRODUOqON FOR OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing PressureOALCU~TED . OIL-BBL GAS-MOF WATER-BBL O~L CRAwl-APl (OORR) Press. 24-HOUR RATE 28. ~RE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate?'" Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk A3 11719' 7105' Top Kuparuk A2 11760' 7135' Top Kuparuk A1 11845' 7198' . 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the for_egoing_is true and ~fol'rect to the best of my knowledge 'nmSchCe~ Title Senior Drilling Engineer Date I i ' Prepared By Name/Number: Kathy Campoamor, 564-5122 INSTRUCTIONS RECEIVED GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ' NOV 1 2 1996 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. ~aska 0il & Gas Cons. C0mrnission Anchorage 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPJ-16 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/31/95 12:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 22E 10/31/95 (1) TD: 112'( 0) 11/01/95 ( 2) TD: 1256.'(1144) 11/02/95 (3) TD: 2963'(1707) 11/03/95 (4) TD: 3132' ( 169) 11/04/95 (5) TD: 3488'( 356) LOAD PIPE SHED MW: 0.0 VIS: 0 MIRU FROM MPJ-19A TO MPJ-16o RIG ACCEPTED @ 0000 HRS., 10/31/95. DRILLING MW: 0.0 VIS: 0 FINISH NU. MU FLOWLINE & INSTALL MOUSEHOLE. PU BHA & STAND BACK IN DERRICK. FUNCTION TEST DIVERTER SYSTEM. BOBBY FOSTER WITH AOGCC WAIVED WITNESSING TEST. MU BHA, ORIENT & TEST MWD. FILL HOLE & CHECK LINES. SPUD & DRILL 12-1/4" HOLE F/l12' T/1058'. POOH & CHANGE PDM. TIH. DRILL & BUILD ANGLE. DRILLING MW: 0.0 VIS: 0 DRILLED F/1256 T/1455'. POOH. TOP DRIVE CAMLOCK CONNECTION SHORTED OUT. REPAIR CAMLOCK FITTING ON TRACTION MOTOR. ADJUST BEND ON PDM. TIH T/1455'. OK. DRILL F/1455' T/2963'. NU BOP ~ MW: 0.0 VIS: 0 DRILL F/2963' T/3132'. CIRC SWEEPS & COND HOLE. MONITOR WELL, PUMP PILL, POOH TO JARS, RIH. OK. CIRC SWEEPS & COND MUD. DROP EMS, MONITOR, PUMP PILL, BLOW DOWN TOP DRIVE. POOH T/BHA & LD. CHANGE STB BLADES & BAILS & RU CASING EQUIP. RUN 9-5/8" CASING. SHOE @ 3112'. MU CEMENT HEAD, CIRC MUD. TEST LINES, DROP BOTTOM PLUG. PUMP CEMENT, DROP TOP PLUG, BUMP PLUG, CHECK FLOATS. OK. LD CEMENTING HEAD, LANDING JT & DO TOP JOB. LD CASING EQUIP. ND DIVERTER, SPEED HEAD & BOP. DRILLING MW: 0.0 VIS: 0 NU BOP & FLOWLINE. MU TEST JT, DART, TIW & TEST PLUG. TEST ACCUMULATOR, BOP, CHOKEMAN & ANNULAR. PULL TEST PLUG. INSTALL LONG WEAR BUSHING. PU BHA & LOAD TOOLS. PU PIPE. CUT & SLIP DRILLING LINE. SERVICE TOP DRIVE. RIH T/3016'. FILL DP, CIRC, TEST CASING. OK. DRILL CEMENT, PLUGS & FLOAT EQUIP. 10' NEW FOR CBU & PERFORM EMW TEST. OK. DRILL F/3142' T/3488'. WELL - MPJ-16 OPERATION: RIG : NABORS 22E RECEIVED, 1 19g$ PAGE: 2 11/05/95 (6) TD: 6150' (2662) 11/06/95 ( 7) TD: 8810' (2660) ~aska 0ii & GR.s Cons, Comml~iQn Anchorage DRILLING MW: 0.0 VIS: 0 CLEAN FLOWLINE OF CEMENT & RUBBER PLUG. DRILL F/3488' T/4534'. CIRC SWEEPS OUT OF HOLE. MONITOR WELL. PUMP PILL. SHORT TRIP, BACK REAM. WANTED TO SWAB, RIH TIGHT HOLE 4438'-4478'. REAM LAST STAND TO BOTTOM. DRILL F/4534' T/6057'. MONITOR. PUMP PILL, BLOW DOWN KELLY. SHORT TRIP, HIT BRIDGE @ 5387'. REAM 5387'-5400'. DRILL F/6057' T/6150'. DRILLING DRILL F/6150' T/8810'. MW: 0.0 VIS: 0 11/07/95 ( 8) TD:10350' (1540) 11/08/95 (9) TD:11848' (1498) 11/09/95 (10) TD:12212' ( 364) 11/10/95 (11) TD:12212' ( 0) 11/11/95 (12) TD: 0 PB: 0 DRILLING MW: 0.0 VIS: 0 DRILL F/8810' T/10319'. PUMP LO/HI VIS SWEEPS, CBU, MONITOR WELL, PUMP PILL, BLOWDOWN. POOH TO CASING SHOE. OK. CUT DRLG LINE. SERVICE TOP DRIVE, GREASE CROWN. PU PIPE, RIH FILLING DP EVERY 25 STDS. OK. DRILL F/10319' T/10350' CONTROL DRILLING MW: 0.0 VIS: 0 DRILL F/10350' T/11097'. MONITOR WELL. SHORT TRIP. OK. DRILL F/11097' T/ 11655'. CONTROL DRILL F/11655' T/11848'. RIH MW: 0.0 VIS: 0 CONTROL DRILL F/11848' T/12039'. DRILL F/12039' T/12212'. PUMP SWEEPS AROUND, MONITOR WELL. WELL FLOWING, MUD UNBALANCED. CBU. CIRC & INCREASE MUD WT. MONITOR. CBU. SHUT IN WELL. CIRC & INCREASE WT ~ MONITOR TWO MORE TIMES. PUMP PILL, BLOW DOWN TOP DRIVE, POOH. MONITOR WELL. POOH TO CASING SHOE IN DRILLING MODE. SERICE TOP DRIVE & CROWN. RIH TO TD. RUNNING CASING MW: 0.0 VIS: 0 RIH SLOWLY, BREAK CIRC, COND MUD. WELL STABLE, MONITOR WELL. POOH, L/D BHA, UNLOAD CDN TOOL. R/U AND RUN 7" CASING. DISPLACING CEMENT MW: 0.0 RIH WITH 7" CASING T/3112'. CIRC @ SHOE. RIH WITH 7" CASING T/6064'. CBU. RIH WITH 7" CASING T/8906'. RIH T/9753'. RIH T/10150'. RIH T/10553'. WORK PIPE, NO MOVEMENT IN PIPE, FIGURE STRETCH, CIRC & WORK CASING. UNABLE TO WORK FREE. LD TOP JOINT & RU CEMENTING HEAD. WORK CASING, CIRC, PREPARE TO CEMENT, PULLED TWICE. DISPLACE CEMENT. ACTION PLAN OK'D VERBALLY BY JOHN SPAULDING & BLAIR WONDZEL WITH AOGCC. WELL : MPJ-16 OPERATION: RIG : NABORS 22E PAGE: 3 11/12/95 (13) TD: 0 PB: 0 11/13/95 (14) TD: 0 PB: 0 11/14/95 (15) TD: 0 PB: 0 11/15/95 (16) TD: 0 PB: 0 TESTING BOP MW: 0.0 SHUT IN BACKSIDE. WOC. BLEED OFF BACKSIDE, LOAD CEMENT PLUG, OPEN ANNULAR. PUMP CEMENT, DROP PLUG. SHUT ANNULAR & SQUEEZED LAST CEMENT OUT ES & CLOSE. WOC. SIP BUILT, BLEED OFF CASING, LD CEMENT EQUIP, PREP STACK FOR ND, BLEED OFF BACKSIDE. ND CHOKE & KILL LINE, PU STACK, SET SLIPS. MAKE RUFF CUT, MOVE STACK, MAKE FINAL CUT, NU BOP, INSTALL PACKOFF. TORQUE LOCKDOWNS, TEST PACKOFF. NU FLOWLINE, CENTER STACK. CHANGE RAMS, CHANGE TOP DRIVE & IRON ROUGHNECK. RU TEST JOINT. TEST BOP. PU DP MW: 0.0 TES BOP'S & CHOKE MANIFOLD. TEST ANNULAR. PULL TEST PLUG, INSTALL WR. BOP TEST WITNESSED BY JOHN SPAULDING WITH AOGCC. CHANGE OUT VALVE #7 IN CHOKE MANIFOLD, ADJUST ACCUMULATOR VALVE. SERIVCE TOP DRIVE. CUT & SLIP DRILLING LINE. PULL WR, INSTALL TEST PLUG, TEST CHOKE MANIFOLD & VALVE #7, PULL TEST PLUG, INSTALL WR. PU BHA. PU & RIH WITH 3-1/2" DP, RABBITING DP. TAG CEMENT @ 4652', DRILL OUT CEMENT & ES. REAM RUBBER HANGING UP, BLOWDOWN TOP DRIVE. RIH, PU 3-1/2" DP. POOH TO RUN LINER MW: 0.0 RIH PU DP, TAG CEMENT @ 10437'. CIRC & TEST CASING. DRILL CEMENT & FLOAT EQUIP F/10437' T/10562'. WASH & REAM T/10929', BRIDGE @ 10850'. CIRC HOLE CLEAN THICK MUD & OIL RETURNS. WASH & REAM T/12213'[ NO MUD LOSSES. PUMP LO-HI VIS SWEEPS, MIX GELATION TREATMENT, NO MUD LOSSES. MONITOR WELL, PUMP PILL, DROP RABBIT. POOH SLM, MONITOR WELL AT SHOE. REVERSING OUT CEMENT MW: 0.0 POOH, FINISH SETTING BACK SLM, LD REST OF PIPE. POOH, LD BHA. RU TO RUN 5" LINER. RIH WITH LINER, USED TURBOLATORS AND BOW SPRING CEN. HAD TO PUSH LINER IN THE HOLE. MU LINER HANGER & PACKER. CIRC LINER, CHANGE BAILS. RIH TO CASING SHOE, HAD TO KELLY UP TO PUSH LINER. CIRC DP & LINER VOLUME AT SHOE. RIH T/12212', TAGGED BOTTOM. SPACE OUT, RU CEMENT HEAD, BREAK CIRC. CBU. PUMP WATER TEST LINES WITH CEMENT, BUMPED PLUG, SET LINER HANGER, CHECKED FLOATS. OK. ROTATED OUT OF HANGER, PU & SET DOWN ON PACKER. SET PACKER, REVERSE OUT CEMENT. WELL ' MPJ-16 OPERATION: RIG : NABORS 22E PAGE: 4 11/16/95 (17) TD: 0 PB: 0 11/17/95 (18) TD: 0 PB: 0 11/18/95 (19) TD: 0 PB: 0 11/19/95 (2O) TD: 0 PB: 0 POOH WITH DP MW: 0.0 RELEASE FROM HANGER & SET PACKER. REV OUT CONTAMINATED CEMENT. MONITOR RIG & BLOW DOWN TOP DRIVE. POOH & LD SETTING TOOL. PU DP, RD HANDLING TOOLS & MU CASING SCRAPER. RIH WITH 3-1/2" DP. TAG LANDING COLLAR @ 12064'. TEST CASING & LINER, CHECK ALL SURFACE EQUIP. OK. CIRC & RECCIP DP. MONITOR WELL & PUMP PILL. POOH. LD SCRAPER & STAND BACK DP. PU 2-7/8" HANDLING TOOLS MW: 0.0 FINISH POOH, LD DC & MILL. PU DC & BAKER POLISHING MILL. TIH T/5690'. SLIP & CUT DRILL LINE, SERVICE CROWN & DRAWWORKS. FINISH RIH TO TOP OF LINER @ 10350'. DRESS OFF LINER & ATTEMPT TO RE-TEST. CBU & RE-DRESS LINER TOP. PUMP PILL & POOH. LD DC. RU ATLAS & RUN BOND LEG. RU & RE-TEST LINER & CASING. OK. RU 2-7/8" HANDLING TOOLS. ND BOPE MW: 0.0 FINISH PU DP & TIH TO LANDING COLLAR. DISPLACE WELL WITH CACL/BR & FILTER. TEST CASING & LINER. OK. POOH T/2033', LD DP. FREEZE PROTECT TOP WITH DIESEL. FINISH POOH, LD DP. CLEAR RIG FLOOR, PULL WEAR RING, CHANGE RAMS. ND BOPE. MOVE RIG MW: 0.0 FINISH ND BOPE, NU ADAPTER & TREE & TEST. LD DP OUT OF DERRICK IN MOUSEHOLE. CHANGE TOP DRIVE. PREP RIG TO MOVE TO MPL-25I. RIG RELEASE @ 2200 HRS., 11/18/95. SIGNATURE: (drilling superintendent) DATE: SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPJ-1 6i Rig Name: N-4ES AFE' 330200 Accept Date: 01/01/96 Spud Date: Release Date: 01/04/96 Jan 2 1996 MIRU. Set in rig & raise derrick, trim herculite. Check well for pressure & ND tree. Check LDS & gland nuts. NU BOP's & change out manual choke valve. Change rams in BOP. Test BOP's. Test waived by John Spaulding. Load pipe shed & drift & SLM tubing. Rig floor. PU 3-1/2" tubing t/2300'. Circ out diesel cap. POOH with tubing. Rig accepted 01/01/96 @ 1200 hrs. Jan 3 1996 TOH with 3-1/2" tubing. Test casing, ok. ND flow nipple & NU shooting flange & lubricatOr & test. Run #1-#4 perf 5" liner across Kuparuk A&B sands w/3-3/8" gun, 6 spf. Made three runs with 6"'GR/JB on e-line. ND shooting flange & NU flowline. MU 6" bit & 2 csg scraper & RIH on tubing from shed. Prep for packer. :. Jan 4 1996 PU 3-1/2" tubing to TOL. POOH with 3-1/2" tubing & scrapers. MU Baker packer & RIH with same. MU hanger & land same. RILDS & set TVVC. ND BOP's & NU comp tree. . Test adapter flange & tree. Pull TWC & displace well down annulus with source water & corrosion inhibitor & 80 bbl diesel & U-tube to tubing. Drop ball & let fall 1 hr set pkr & hold for 30 min. Remained static, bleed tubing & annulus & hold for 1 hr. Remained static after initial climb due to compression. Bleed annulus & prepare to set BPV. Test witnessed by Lou Grimmaldi w/AOGCC. Jan 5 1996 Set BPV & secure well. Rig released 01/04/96 @ 0800 hrs. Page Miine Point Unit, Alaska TO: Steve Rossberg FROM: J. Fox Well Name: IMP J-16i Main Category: Iinitial perf. Sub Category: IA and B Sand Operation Date: IJan. 2, 1995 Date: I Jan. 2, 1995 Objective: In preparation for the completion of this well the rig has been placed over it and is prepared to run the completion string. The well will be perforated wireline conveyed as the final step before running the completion. Sequence of Events: 0700 - NU shooting fig. on rig BOPs. RU Atlas E-Line Unit. Pressure test lubricator to 1000 psig - ok. 0800 - MU and RIH w/24'x 3 3/8" hollow carrier / GR / CCL to 11,916' RKB. Did not tag bottom as bottom was tagged on recent SBT run. Run correlation log. Depth correct. Log up into shooting depth at 30 fpm. Detonate guns perforating casing from 11,772' to 11,796' RKB. Log off and POOH. All shots fired. 1100 - MU and RIH w/24' x 3 3/8" hollow carder / GR / CCL. Correlate depth and correct. Log up into shooting depth at 50 fpm~' Detonate guns perforating casing from 11,748' to 11,772' RKB. Log off and POOH. All shots fired. 1315 - MU and RIH w/24'x 3 3/8" hollow carrier / GR / CCL. Correlate depth and correct. Log up into shootihg depth at 50 fpm. Detonate guns perforating casing from 11,724' to 11,748' RKB. Log off and POOH. All shots fired. 1500 - MU and RIH w/10'x 3 3/8" hollow carrier / GR / CCL. Required 3 attempts to get tool string inside liner top. Correlate depth and correct. Pull up into shooting depth at 20 fpm. Detonate guns perforating casing from 11,655' to 11,665' RKB. Log off and POOH. All shots fired. 1715 - MU and RIH w/6.0" gauge ring / junk basket assembly to the top of the 5" liner. Made 3 runs and retrieved approx. 1/2 cup of metal and brass debris on the first two runs and a third of a cup on the final run. It was believed to not be perf debris. 2200 - RDMO E-line unit. Results: The 5" liner was perforated across the Kup. 'A' and 'B' Sands as per program w/3 3/8" hollow carriers loaded w/21.0 gm Alpha Jet ("Deep Penetrating") charges (EHD - 0.47" TTP = 21.0") at 6 JSPF, 60 deg. phasing, random orientation. It should be noted that the tool string tended to "yo - yo" due to drag /inertia in the high hole angle and relatively small liner size. This makes depth accuracy limited to an est. 2'. At 30 fpm (optimum speed to get good CCL and GR log) line tension cycled approx. 150 lbs. every 3' or so. A line speed of 50 fpm was used on two subsequent gun runs which resulted in less yo-yoing (50 lb. cycles over 6') across the interval to be perforated. It also resulted in a poorer quality GR log but sufficient to vedfy coarse depth correlation. Fine depth correlation was provided with the CCL. On the final run the logging speed was initially run at 50 fpm w/too much yo-yoing. The speed was slowed down to 20 fpm and the yo - yoing all but disappeared. The GR quality was good enough to fine tune depth correlation and the CCL was consistent enough to confirm the correlation. TD was not tagged during the perforating as it was recently recorded during the ,SBT logging run at 12,034' RKB. Tie in log/date_Nov. 17, 1995 - SBT / GR_ ....... Interval Measured Depth ..... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing I111,655'1,665' JSPF IIrand°m ling de9 I Gun charge: Alpha Jet, 21.0 gm., AlphaJet, EHD = 0.47", TTP = 21.0" SHARED SERVICES DRILLING MILNE PT/MPJ-16 500292261500 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 6/95 S~=~RRY-SUN DRILLING SERVICES ~ PAGE 1 ANCHOR3kGE ALASKA ' DATE OF SURVEY: 110295 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50109 KELLY BUSHING ELEV. = 64.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -64.70 137 137.92 73.22 229 229.08 164.38 320 320.35 255.65 410 410.73 346.03 0 0 N .00 E .00 .00N .00E .00 0 10 S 70.13 E .13 .07S .21E -.12 0 12 S 22.22 E .18 .28S .41E -.37 0 14 S 24.32 E .04 .62S .55E -.74 0 12 S 23.49 E .03 .95S .70E -1.09 501 501.20 436.50 592 592.49 527.79 683 683.13 618.43 774 773.87 709.17 865 864.74 800.04 0 15 N 35.18 E .46 .94S .89E -1.13 1 19 N 4.54 E 1.22 .28N 1.09E .01 2 46 N 8.01 W 1.66 3.50N .87E 3.19 4 34 N 11.09 W 1.99 9.23N .13W 9.00 6 47 N 14.40 W 2.46 18.04N 2.18W 18.04 956 954.82 890.12 1050 1046.66 981.96 1145 1138.91 1074.21 1241 1228.87 1164.17 1337 1315.77 1251.07 9 13 N 18.06 W 2.72 30.19N 5.78W 30.70 13 33 N 17.17 W 4.63 47.84N 11.35W 49.16 16 57 N 15.64 W 3.57 71.98N 18.42W 74.29 22 18 N 13.98 W 5.64 103.01N 26.56W 106.38 27 24 N 26.22 W 7.54 140.47N 40.71W 146.12 1432 1400.37 1335.67 1527 1484.60 1419.90 1622 1569.26 1504.56 1717 1652.09 1587.39 1813 1732.58 1667.88 27 38 N 23.83 W 1.18 180.40N 59.34W 189.34 26 23 N 26.51 W 1.84 219.27N 77.58W 231.42 28 32 N 27.55 W 2.30 258.46N 97.59W 274.25 31 4 N 26.25 W 2.73 300.77N 119.04W 320.45 33 32 N 23.09 W 3.15 347.03N 140.23W 370.41 1908 1811.54 1746.84 2004 1888.51 1823.81 2099 1963.56 1898.86 2195 2035.68 1970.98 2288 2102.06 2037.36 35 21 N 21.61 W 2.09 397.14N 160.81W 423.99 37 8 N 20.93 W 1.91 449.74N 181.28W 479.94 39 8 N 21.04 W 2.10 504.76N 202.38W 538.40 42 50 N 18.67 W 4.20 563.72N 223.61W 600.72 46 20 N 17.39 W 3.87 625.95N 243.84W 665.97 2384 2167.95 2103.25 2479 2231.16 2166.46 2575 2290.48 2225.78 2603 2307.45 2242.75 2671 2348.17 2283.47 46 43 N 16.96 W .52 692.37N 264.37W 735.36 50 16 N 17.34 W 3.73 760.63N 285.44W 806.68 52 58 N 16.81 W 2.85 832.24N 307.43W 881.46 52 30 N 16.92 W 1.71 853.58N 313.90W 903.73 53 29 N 16.78 W 1.47 905.28N 329.56W 957.67 2766 2403.22 2338.52 2861 2455.80 2391.10 2957 2507.89 2443.19 2983 2521.75 2457.05 3030 2546.14 2481.44 55 56 N 15.72 W 2.73 979.95N 351.31W 1035.37 57 11 N 14.26 W 1.84 1056.88N 371.90W 1114.99 56 57 N 13.39 W .80 1135.01N 391.13W 1195.45 58 14 N 12.96 W 5.14 1156.27N 396.10W 1217.29 58 50 N 12.55 W 1.46 1195.16N 404.91W 1257.15 S-r~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE PT/MPJ-16 500292261500 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 6/95 DATE OF SURVEY: 110295 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50109 KELLY BUSHING ELEV. = 64.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3132 2598.80 2534.10 58 50 N 12.55 W .00 1280.15N 423.83W 1344.20 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1348.49 FEET AT NORTH 18 DEG. 19 MIN. WEST AT MD = 3132 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 346.25 DEG. S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPJ-16 500292261500 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 6/95 DATE OF SURVEY: 110295 JOB NUMBER: AK-EI-50109 KELLY BUSHING ELEV. = 64.70 FT. OPERATOR: BP EXPLOKATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -64.70 .00 N .00 E 1000 997.65 932.95 37.55 N 8.14 W 2000 1885.00 1820.30 447.26 N 180.33 W 3000 2530.43 2465.73 1169.95 N 399.25 W 3132 2598.80 2534.10 1280.15 N 423.83 W .00 2.35 2.35 115.00 112.65 469.57 354.57 533.20 63.63 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ,S~RRY-SUN DRILLING SERVICES ANC}{ORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPJ-16 500292261500 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 6/95 DATE OF SURVEY: 110295 JOB NUMBER: AK-EI-50109 KELLY BUSHING ELEV. = 64.70 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -64.70 .00 N .00 E .00 64 64.70 .00 .00 S .01 E .00 .00 164 164.70 100.00 .10 S .29 E .00 .00 264 264.70 200.00 .41 S .46 E .00 .00 364 364.70 300.00 .79 S .63 E .00 .00 464 464.70 400.00 1.08 S .79 E .00 .00 564 564.70 500.00 .36 S 1.04 E .01 .01 664 664.70 600.00 2.62 N .99 E .06 .05 764 764.70 700.00 8.52 N .01 E .25 .19 865 864.70 800.00 18.04 N 2.18 W .75 .50 966 964.70 900.00 31.79 N 6.30 W 1.80 1.05 1068 1064.70 1000.00 52.13 N 12.66 W 4.07 2.28 1172 1164.70 1100.00 79.97 N 20.61 W 8.20 4.13 1280 1264.70 1200.00 117.76 N 31.04 W 15.67 7.46 1392 1364.70 1300.00 163.34 N 51.77 W 27.54 11.87 1504 1464.70 1400.00 210.43 N 73.17 W 40.13 12.59 1617 1564.70 1500.00 256.26 N 96.45 W 52.59 12.46 1732 1664.70 1600.00 307.68 N 122.39 W 68.00 15.42 1851 1764.70 1700.00 366.62 N 148.58 W 87.01 19.01 1974 1864.70 1800.00 432.90 N 174.84 W 109.83 22.82 2101 1964.70 1900.00 505.64 N 202.71 W 136.62 26.78 2235 2064.70 2000.00 589.97 N 232.33 W 170.79 34.17 2379 2164.70 2100.00 689.06 N 263.36 W 214.96 44.17 2533 2264.70 2200.00 800.28 N 297.70 W 268.47 53.51 2699 2364.70 2300.00 926.97 N 336.03 W 334.38 65.90 2878 2464.70 2400.00 1070.26 N 375.30 W 413.51 79.14 3066 2564.70 2500.00 1225.11 N 411.57 W 501.40 87.89 3100 2582.24 2517.54 1253.42 N 417.88 W 517.76 16.36 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0,00 D~(B/-~) 0o00 I~/.II'tUTH ~ RO'I'~Y Ti~T~ TO TAA"T IS TIE IH POInT(TIP): ~ D]~PTH 112,00 TRUE UERT D]~:91-1 112,00 II,~LII,~'rlON 0,00 AZIMUTH 0,00 I.qTITUD£(N/-$) 0o00 D~AR'~(S/-t~) 0,00 · I'PJ'16 ft ft ft ft d~ ~ ~.82 ~,8 ~,82 -0,~ 0.26 161.~ ~3.08 ~.3 ~3.~ -0.~ 0.15 167.53 ~5.~ ~.5 ~5.~ -0.7~ 0,~ 15%97 437.~ ~,0 437,56 -1.2~ 0.34 1~,47 W-S ft ft ft 0,00 0.00 -0,19 0,07 0,20 -0,37 0,12 0.3? -0.73 0.23 0,76 -1,14 0,53 1.26 529,16 91,6 529..15 -1,24 0,40 14.83 -:1.,01 0,82 616,96 8,9,8 618,94 0,27 1,77 2,36 0,67 0,95 709.52 90.6- 709,41 4.11 3.35 353,0~ 4,70 0,69 800.01 90,5 799.64- 10.76 5.26 348,11 11.39 -0.46 891.64 91.6 890,70 20,72 7,37 346.06 21,21 -2,76 1,30 1,17 4,75 11,40 21,39 AZI~LrI14 0.00 161,23 162.30 162,33 155.20 141.12 54.75 8,39 357.58 352.56 DLS lo0ft 0.O0 0.29 0.21 O.1B 0.18 0,68 1,55 1,80 2,15 2,31 985,47 1015o90 1046,13 1077,8.6 1110.04 93,8 983.41 30,4 1013,29 30,2 1042.82 31,7 1073,62 32,2 1104,65 35,07 10,30 341,68 3%02 -6,85 40,63 11,58 341,80 40,50 -8,66 47.29 13,16 342,60 46,67 -10.64 54,87 14.58 343,70 53,95 -12,84 63.32 16.07 344,?0 . 62,13 -15.13 35.66 41.42 47.87 55.46 63.95 346,93 347.93 347.16 346,61 346.31 3,20 4,21 5,24 4.53 4.75 1173,12 1266,63 1363,13 1459,52 1555.26 63,1 1164,97 81,66 17,95 344,32 93.5 1252.25 115.06 24.02 338.91 96,5 1329.33 156.55 27,03 333,03 96.4 1425,51 199,58 26.20 334.07 95.7 1511.10 242,33 27.04 333,12 79,92 -20,04 111,59 -30,79 149,47 -47,81 188,12 -67.(75 226,54 -B6,I3 82,40 115,76 156,93 199,71 242,36 345,93 344.57 342.26 340,38 339,16 2,99 6.81 4,07 0,98 . 0,96 1650.62 1746.60 1842.49 1936.14 2030,67 95.4 1595,26 286,91 29,04 331,37 %,0 1677,66 335,88 32,64 334,65 95.9 1757,46 388,98 34,*68 337,32 93.7 1833.64 443.47 36,49 339.25 94.5 1908,,.79 500,80 38.18 338,34 266.20 -I07.02 310.05 -129.28 358.61 -150.87 409.24 -171,02 462,68 -I?1.76 286,91 335,92 369,05 443.54 500,84 338,10 327,37 337.18 337,32 337.49 2.27 4,14 2,63 2,27 1,87 2127.66 2223.17 2316.18 2412.81 25(~.10 ?7,0 1983.77 562.30 40.55 339.83 . . 95.5 2054.26 626,65 44.32 342.28 93.0 2119,92 692,29 45.87 343,86 96,6 .2185,72 762.78 46.28 342,52 95,3 2246,8.4 835.66 51,?1 342.67 520,14 -213,70 581.10 -234,57 644,12 -253,74 711.84 -274,22 781.58 -296.00 562.33 626.65 692,29 762,83 I)35.7B 337.67 336.02 33B,~ 338.93 939,25 2,63 4,31 2,06 2,69 3,81 2603,63 2696,91 2794.45 2889,83 2983.14 95.5 2305.47 910.84 52,36 342.87 93.3 2360.76 985.71 54.93 342.84 97.5 2415.41 1066.12 %,93 344,78 95.4 2467,35 1145,51 5-/.00 --345.85 93,3 2517,22 1223,69 58.32 345,82 853,61 -318,41 925,39 -340,b'5' 1002,98 -363,06 1080,36 :383,34 1156,83 -402,64 911,07 986,06 1066.67 1146.35 1224.90 339,54 339,80 340.10 340,46 340.01 0.50 2,75 2.63 0,95 1.32 3058,73 3167,80 3208,13 3305.72 75,6 25'56,25 1287.76 59,49 346,81 10%1 2612,24 1379,93 ~,76 349,86 40.3 2633,23 1413.69 58.50 349,46 97,6 2684,13 1495.59 ~.~ 347,85 ~,O 2734.16 1575.25 57,78 347.15 1219,71 '-417,94 1311.38 -436,66 I345.26 -443.04 1426.89 -459.41 150%69 -476,6~ 1289.33 1362,23 1416,33 1499.03 1579,40 341,09 341,58 341,77 -342,15 342,43 1.91 2,51 1,10 1,41 ?AG£ i,10. 3 ~ I~TE~A~L VERTICAL ft ft ft 3493,95 ?3.3 ~,~ ~,76 94.6 2878.~ 3~8,76 ~,0 ~6,~ ~74.~ %.0 ~74.~ 3970.34 4066,35 4160.39 427:)4.96 4350.74 4446.49 4542,46 4637.64 4732.72 4827.97 4921.10 5016.53 5112.17 5207.34 5303.35 5398.44 5493,80 b'590.52 5685,65 5780.51 ~73,95 5966,44 6064,52 6160,16 6256,66 6351,32 6446.46 654~_,83 6637,85 . 6734,49 6829,t5 6V24.57 7020,09 7115,56 72t0,34 ~PJ-16 TARGffl TIATI~ AZI~JTH 'LATITUI)£ ))EPARTURE ))I~LAC~q~ at SK'TII~ I~CI.q. )U-8 ~/-W it deg. de9 it it it 1653.25 b-/.96 347.56 1582.77 -494.17 1658.12 1734,i0 60,69 347,44 1662,73 -511,90 1739,74 1815,29 60.43 348,38 1743,26 -529,15 1821,80 1896.27 59.57 348.41 1823.84 ,545.70 1903.73 1978,10 60.02 347,19 1904,94 -563,24 1986,46 95.6 3021.80 2060.34 60.84 346.05 1985,80 -582.47 2069.46 96.0 3069.09 ?.143.16 60.15 345.73 2066.84 -602.85 2152.96 94;0 3116,34 2223,81 59,51 345,26 2145,55 -623,21 2234,22 94,6 3164,17 2304.77 59,73 ~45.63 2224,52 -643,72 ~15,7B 95,8 3212.09 2386,~ 60.23 346,77 2305,05 -66~,50 L~39B,65 95,7 3259,45 2466,97 60.47 348.75 2386.37 -681.14 2481.66 96,0 3306.69 2550,62 60,56 352,13 2468,74 -695,01 1564.70 95,2 3352.85 2630,81 61,44 355,45 2551,48 -704,01 2646,82 95.). 3398.27 2709.72 61.50 359.31 2634.90 -707.83 2728.32 95.3 3444,08 2787,21 61,01 1.03 2718,41 -707,58 2808,9~ 73,1 3490,03 95,4 3537,49 95,6 356.5,32 · 95,2 3633,38 96,0 3662,66 95,1 3733,01 95,4 3782,23 96.7 3831.28 · 95,1 3877,97 94,9 3927,27 2~1,~ 59,86 I,~ 2938,19 ~,49 0,67 ~t4,70 59,50 0,~ 30ctO,~ 59.85 3166,60 ~8,37 1,0~ AZIl~mt deg 342.66 342.09 343,34 343,53 343.65 ~43.74 343.80 343.86 343.94 344.07 344.28 344,57 344.96 345.4t 2799,40 -705,93 2887,04 345,S5 2882,17 -704,49 2967,02 346.26 2964,98 -703,38 2047,27 346,65 3047,12 -702.19 3126,98 347,02 3129.50 -700.85 3207.02 347.38 3240,76 57,70 1,82 3210,14 -698,83 3285,33 33t5,56 60.15 2,01 3291,76 -696,10 3364.56 3391,79 58~91 2,26 3375,06 -692,99 3445.47 3466.56 59.52 , 1.93 3456.73 -690.01 3524.93 3542,i5 60.66 0,96 3538,93 -687,94 3605,17 93.4 3973.32 3617.2.4 60.29 0.65 3620.23 -686.79 3684.80 ~.5 4019.42 ~91,22. 59.92 . 1.25 3700.40 -685.46 3763.35 96.1 4069.04 3769.77 '59.29 358.89 3784.99 -605.35 3846.54 95,6 4117.19 3847,23 60,25 358,39 3867,61 -687,31 3928,20 96,5 4165,09 3926,01 60.23 357,92 3951,34 :690,00 4011,I3 94.7 4212.~ 4Q03,40 59,~ 357,35 4033,30 -693,38 4092,47 95,1 4260,21 4081,49 59,67 355,62 41!5,36 -698,42 4174,20 96,4 430?,07 4160,54 59,39 -356,63 4178,22 -704,03 4256,84 95,0 4357,16 4238,24 59.81 357,05 4280,05 -708,55 4~,31 96,6 4405,69 4317,28 59.90 357.32 4363.52 -712.65 4421,33 94,7 4452.99 '4394.79 60,16 357,33 4445,43 -716.48 4502.79 95,4 4500,31 4472,69 &0,38 359,07 4528,24 -719.08 4584.98 95,5 4547,51 4550.89 60.40 356.78 4611,23 -722,09 4/J67.43 95.5 4594.91 4629.43 60.06 3~.96 4693.98 -726,61 4749.88 94.8 4642,17 4707.64 60.13 355.25 4775.94 -732.19 4831.74 347,72 348.06 348,40 348.71 349,00 349.26 349,51 349.74 349,97. 350,09 350,98 351,10 351,20 351,28 iQOft 0,42 2.87 0,91 1,19 1,35 0,77 0.81 0o41 1.15 1,81 3,07 3,18 3,57 1.66 1,27 0.38 1,56 0,98 2,58 1.30 0.71 1,49 0,50 0,69 2,17 1,10 0,42 0.63 1.58 0.95 0.58 0°26 0.28 1.59 2.08 0,40 1.5'7 PAGE HO. 4 ~J-16 lt~~ I~ VERTICAL DEPTH DEPTH 7400.34 94.7 4735.2B 74'73,49 93.2 4701.16 7588,28 94.8 4828.47 7682,0~ 93.8 4875.74 ft ft -739.83 4914,56 -751,51 4997.18 -768,33 5078,11 -787.34 5159,99 -806.49 5240.72 AZIBJIH deg 351,34 351,35 351,30 351,22 351,15 DL9 lOOft 1.25 4.29 0,48 0,78 7778,02 7B73,01 7964.54 805%69 8153,77 96.7 4924.75 94,2 4972,79 91,5 5019.74 95,2 5068.80 94.1 5117.23 5191.62 59.51 345.16 5259,04 5~2.28 59,17 342,05 5336.76 5350.74 59.12 340.45 5411,16 5432.26 58,83 336,66 5487.03 5512,83 59.20 335.02 5560.62 -827,30 5323,72 351,06 -B50,16 5404.05 350.95 -875,42 5481,51 350,81 -905,21 5561,20 350.~ -938o22 5639,21 350,42 0.70 2,8~ 1.50' 3,43 1,54 0248.51 8343.83 8437,12 8532.62 8626,44 94,7 5165.47 95,3 5213.65 93.3 5260,40 I5.5 5307.88 93.8 5354,73 5594.23 59,59 334,73 5634,44 5676.17 59.71 331,92 5707,94 5756.19 60.13 329,54 5778.35 5837,9B ~,25 328,~ 5~49,41 5917,80 59,84 326,26 5917,89 -972,84 5717.81 350.20 -1009,77 b-/96,57 349,97 -1049,23 5872,83 349,71 -1091,84 5950,44 349,43 -1135,62 6025,87 349,14 0,49 2.54 2,26 0,91 2,17 8720,69 8815.02 0910,85 9003,00 90?7.46 94.2 5401,99 94,3 5449.12 95,8 5496,97 92,2 5543,10 94,4 5589,61 5~7,06 59,~ 323.15 5964.43 6075,33 60,07 320,04 &048,46 6154,25 60.02 320,29 6112,21 6230,03 59,96 319,46 6173,2B 6306,89 61,01 315,89 6233,98 -1182,74 6100,19 348,82 2,86 '1233,50 6172,95 348,47 2,86 -1286,69 6246,18 348.11 0,23 -1338,16 6316,65 347,77 0.78 -1393,46 6387,82 347,40 3,4B 9192,66 9287.88 9477.32 9570,36 95,2 5635,47 f5.2 5680,37 94.7 b'723,79 94.7 b766,60 93,0 5809,17 6383,92 61,39 315,51 6293,~ 6460,51 62,35 312.65 6352,08 6536,30 63,09 312,20 640B,90 6612,11 63,15 312.03 6465.54 66~,30 62,39 312,03 6520,92 -1451.73 6458,94 347.01 -1512.05 6529,57 346.61 -1574.21 6599,40 346,20 -1636,86 6669,52 345,79 -1698,31 6738.44 345,40 0,53 2,83 0,89 0,17 0.81 9662,34 9758,12 9853.72 9947,64 10042,71 92,0 5851,53 ?5,8 5895,51 95,6 5939,77 93,9 5983,49 95,1 6027,90 6759,36 62,77' 311,47 6b-/5,28 68~,15 62,57 311,01 6631,37 6910,48 62,27 311.03 6686,99 6984,28 62,25 310,70 6741,38 7058,87 62,04 310,93 6796,32 -1759,23 6806,56 345,02 -1823,21 6877,44 344,63 -1887,14 6948,17 344,24 -1950,01 7017,74 343,B7 -2013,62 7088,34 343,50 0,68 0,48 0,31 0,32 0,31 10138,49 10230,92 10251.75 10347.94 10443,20 95,8 6072,82 92,4 6117.04 20,.8 6127,35 96.2 6177.25 95,3 6229,36 7133,69 62,02 309.96 &851,20 7205,47 60,8! 310,92 6903,85 7221.56 5%86 311,15 6915,73 7294,81 57,64 311,36 6969,95 7366,03 56,03 311,71 7022,82 -2078,00 7159,40 343,13 -213~,77 7227,84 342,78 -2153,43 7243,24 342,70 -2215,25 7313,51 342,37 -2274.93 7382,10 342,05 0,87 1,59 4,~ 2,32 1,72 10536,76 10630,69 10724.83 10820,30 10912,44 93,6 6283,26 93,9 6340,63 94,1 6400,69 95,5 6462,62 92,1 6522,97 7434.31 53,61 311,34 7073,52 7~X),78 ~1,08 311,92 7122,91 75~,05 49,62 313,11 7171.89 7631,62' 49,50 313,10 7221,54 7694,67 48,67 312.46 7268,83 -2332,18 744B,07 341,75 -2387.76 7512,47 341,47 -2441.19 7575.97 341.20 -2494,24 7640,15 340,95 -2545,35 7701,60 340.70 2,61 2,74 1,~ 0,13 P~E HOo 5 ~ IKIERUAL UERTICAL ])~°TH 'DEPTH ft ft ft 11007,21 94,8 6586,36 11101,43 94,2 6651,44 11196,05 94.6 6719,14 11289,97 93.9 6788.05 11365.~ ~o3 11479,60 11575,16 11666,64 11759,54 11855,07 11950,04 12044,56 12123,58 94.3 6927,80 '95,6 65e8,20 91.5 7065,79 92,9 7134.74 95,5 7205,89 · 95,0' 72y"7,11 94,5 7348.54 79,0 7408,51 · ~TOTO 12212,00 88,4 7475,75 I~J-16 TIA'[;~ STATI~ AZIR)TH SECTI~ I~LIq, K/-S ~-~ ft d~ d~ ft ft ft ~,02 47,~ 312,24 7316,28 -~97,~ ~,~ 7819,~ 45,31 312,~ 7~2,28 -2~7.67 78~,~ 787%01 43,31 312,~ 7407,15 -2696,~ 7~2,~ 7~,65 42,~ 312,~ 74~,~ -~42,97 7~,~ 7~4,~ 42.61 313.14 7494'.45 -~.~ 7~6,~ I~TITUI)E ])EPARTURE I)ISPI~EHi~ at 80'52,80 42,60 313,82 75:38,36 -28;.'.%,33 8054,31 8111,88 42,50 314,91 7583,5'/ -2882,52 8112,92 8168,37 42,23 314,49 7626,92 -2926o33 8169,05 8225,39 41,95 314,65 7670,63 -2970,70 8225,79 8283,79 41,75 314,65 7715,42 -3016,04 8283,98 8341,68 41,08 316,14 7760,15 -3060,16 8341,73 8399,05 40,76 316,24 7804,83 -3103,02 83~,05 8446.~ 40,49 317,20 7842,29 -3138,29 8446,91 8500,48 40,50 317,20 7864,42 -3177,30 8500,54 AZIHUTH deg 340,45 340,22 340,00 339,79 339,58 939.36 339,19 339,01 336,83 336.65 338,48 338,32 336,19 DLS deq/ lOOit 1,40 2,19 2,11 1.09 0.38 0,4~L 0,78 0,43 0,32 0,21 1,26 0,35 0,66 O,OO MEMORANDUM TO: David jo~, Chairman" THRU' Blair Wondzell, P. I. Supervisor ~i'[~':',?~ FROM' Lou Grimaldi, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 3,1996 FILE NO' QW9JACDD.doc SUBJECT' Rig\BOPE insp., Nabors 4ES BPX, Milne Point Unit Well MPU J-16 PTD #95-169 Wednesday, January 3, 1996: ! traveled to BPX's Milne Point Unit to make a Rig\BOPE inspection on Nabors 4ES completing a new injection well MPU J-16. A, inspection of the BOP stack revealed some flanges on the lower mud cross that had threaded ports in them. ! had noticed these last October 27 and requested them to be removed. The rig was cOmpleting this well and being a~injector I allowed the rig to finish the job. I informed the Toolpusher Gene Sweat that after their rig move I would return for their initial BOP test and before they could continue,the threaded flanges would have to be replaced. Other than these flanges I found the rig to be in good condition. Summary.: i made a Rig\BOPE inspection on Nabors 4ES. I found some previous non-compliance's that still required attention. Attachment: QW9JACDD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling Workover Cmpl. X UIC X Well Name: J-16 Nabors Rig No. 4ES Rep. BPX Rep. Larry Myers Section 28 T. 13N R. 10E M. U DATE: 1/3/96 PTD# 95-169 Gene Sweatt Rig Ph.# 659-2233 INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored Chke/kill line size turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) IN COMPLIANCE IN COMPLIANCE YESI NO I N/A ' × I X REMARKS: INSPECTION ITEMS (C.) MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) Hydraulic choke panel I Choke manifold INSPECTION ITEMS (E.) MISC. EQUIPMENT Flare/vent line All turns targeted downstream choke lines) Reserve pit tankage Personnel protective equip, avail. All Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping Threaded ports on BOP stack below rams. I will witness next BOP test at which time these must be removed IN COMPLIANCE IN COMPLIANCE IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection 10/27/95 Date of Last BOP Test 1/2/96 Resulting Non-Compliance Items: Tapped and threaded ports on BOP stack had not been removed Non-Compliance not corrected & Reason: Same as above Date Corrections Will Be Completed: next BOP test BOP Test & Results Properly Entered On Daily Record? OK Kill Sheet Current? N/A Distribution: odg - Well File ¢ - Oper./Rig c- Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) Louis R Grimaldi Larry Myers O. W9JACDD.XLS Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) December 13, 1995 TO: BP Exploration (Alaska) Inc~ Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the I;)e~)th shifted CDR/CDN.CDR/CDN TVD'$ for well MPJ-16 Job # 95386 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 I OH LIS Tape 3 Bluelines each 1 Film each 1 Depth shift display State of Alaska ......... 1 OH- -%- ""' - LI-S 'Tap~e'L-------~ Alas..ka©il & Gas Conservation Comm. 1 Blueline each .~._-Att-h' Larry Grant 1 RF Sepia each ,001 Porcupine Drive ..... nchorage,-Alask~-99501 OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 I OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 360 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-661~~~ Schlumberger Courier: v Dat8 Delivered: Received By: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RF."CEIVED DEC 1 5 1995 Alaska 011 & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Date: RE: 6 December 1995 Transmittal of Data Run # 1 ECC #: 6522.00 Sent by: HAND CARRY Data: SBT/GR Received by: Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 A/as~ O;;:& Gas Cons. Com.lissior LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 21 November 1995 Transmittal of Data ECC ~: 6522.00 Sent by: US MAIL Data: SBT/GR Dear Sir/Madam, Reference: MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 SBT FINAL BL & RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John~, DATE: Chairmaf¢~-- November 12, 1995 THRU: Blair Wondzell, ~¢_.~ FILE NO: P. I. Supervisor FROM: John Spaulding¢~(.,¢, SUBJECT: Petroleum Insp. awolklcd.doc BOPE Test Nabors 22E BPX MPU well MPJ-16 Kuparuk River Field PTD 95-169 Sunday November 12, 1995: I traveled to BPX's MPU to witness'the BOPE test on Nabors Rig 22E. The AOGCC BOPE test report is attached for reference. Several problems were encountered during testing causing the longer test time. One valve on the choke manifold failed and was replaced, this valve has failed in past test and was rebuilt each time. The remote HCR kill line actuator valve was out of adjustment and was not allowing the accumulator to work properly. The regulator on the accumulator air pump was out of adjustment and needed corrected prior to finishing the accumulator test. All problems were corrected and re-tested at conclusion of the test. Summary: I witnessed the BOPE Test on Nabors 22E, 3 failures, 7 hours test time. Attachments: awoiklcd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: Nabors Rig BPX MPJ-16 Set @ 10,553' Weekly X Other 22E PTD # Rep.: Rig Rep.: Location: Sec. DATE: 11/12/95 95-169 Rig Ph.# 659-4446 Laverne Linder Dave Mountjoy 28 T. 13N R. IOE Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign yes Drl. Rig yes Hazard Sec. yes Quan. Test Press. P/F 300/3,000 P 1 500/5,000 P 1 500/5,000 P 1 500/5,000 P '1 500/5,000 P 2 500/5,000 P 1 5O0/5,000 P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 18 Test Pressure P/F 500/5,000 P 42 500/5,000 P 2 P Functioned FuncEoned P ACCUMULATOR SYSTEM: System Pressure 3,100 P Pressure After Closure 1,500 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 55 Trip Tank ok ok System Pressure Attained 4 minutes 11 Pit Level Indicators ok ok Blind Switch Covers: Master: yes Remote: Flow Indicator ok ok Nitgn. Btl's: 1950, 2000, 2000, 2000 Meth Gas Detector ok ok 2000, 2000, 2000, 2200 Psig H2S Gas Detector ok ok sec. sec. yes TEST RESULTS Number of Failures: 2 ,Test Time: 7.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) AWOLKLCD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 26, 1995 . Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-16 BP Exploration (Alaska), Inc. Permit No 95-169 Surf Loc 2317'NSL, 3336'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc 4944'NSL, 1083'WEL, Sec. 20, T13N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting ddlling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (Mi) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the B©PE test performed before ddiling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W J~ Chairman BY ORDER OF ON c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryr--J Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 64. 7 f e et Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 025515 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2317' NSL, 3336' WEL, SEC 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 4725' NSL, 971' WEL, SEC 20, T13N, RIOE MPJ- 16 2S 100302630-277 At total depth 9. Approximate spud date Amount 4944' NSL, 1083' WEL, SEC20, T13N, RIOE 10/30/95 $200,000.00 i12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD) property line ADL 315848 1083 feet No Close Approach feet 2544 12168' MD / 7341' TVD feet 116. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) !Kickoff depth 500 feet Maximum hole angle 52 o Maximum surface 3301 psig At total depth (TVD) 7000'/'3998 ps~g ;18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3069' 31' 31' 3100' 2591' 617sxPF'E', 250sx'G; 150sxPF'E' 8-1/2" 7" 26# L-80 Btrc 12138' 30' 30' 12168' 7341' 221 sxClass 'G; 187sxClass'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor , .-,, Surface ,, !.= ! ~ Intermediate Production 0CT 2 ~ Liner Perforation depth: measured Alaska 0il & Gas Cons. Corllrnissio~ true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] IDrilling fluid program [] Time vs depth plot [] Refraction analysis l-I Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby certify that the,foregoin~ lis true and correct to the best of my knowledge · · Signed '-'/.,~ --~"c.~,//~,~..~t~.~.j Title SeniorDfillin~ Engineer Date [~,/~2- ///" Commission Use Only Permit Number ['APl number ...._ IApproval date See cover letter ~',~"'--- ,,,?~' ~' 150- ~::::~---'~'"' '~'-'~--'~,/'"~ //O -" ~.~- ~," ~',...~-"'" for other requirements Con~liti~'ns ~f approval Samples required [] Yes .~ No Mud Icg required []Yes J~] No Hydrogen sulfide measures .1~ Yes [] No Directional survey requirecl ~ Yes [] No Required working pressure for B(~_j=_~,~inal~ ~l~6~j~; J~5M; I-I10M; I-I15M; Other: by order of Approved by David W. Johnston Commissioner tne commission Date/~,/(.~// ,.. Form 10-401 Rev. 12-1-85 Submit in tri~i~.te I Well Name: Well Plan IMPJ-16 Summary ]' Type of Well (producer or injector): [ Kuparuk Injector [ Surface Location: Target Location: Bottom Hole Location: 2317 NSL 3336 WEL Sec 28 T13N R10E UM., AK 4725 NSL 0971 WEL Sec 20 T13N R10E UM., AK 4944 NSL 1083 WEL Sec 20 T13N R10E UM., AK [AFE Number: [ 330170 I [ Estimated Start Date: [ 10/30/95 MD: [ 12168' I [ TVD: I Well Design (conventional, sHmhole, etc.): I Rig: I Nabors 22-E I Operating days to complete: [ 15 [ 7341' bkb I IKBE: I Milne Point Ultra Slimhole 7LS 65' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1962 1865 NA 5499 3795 Top of Schradeir Bluff Sands (8.3 ppg) Seabee Shale 5978 4035 Base of Schrader Bluff Sands (8.3 ppg) HRZ 11177 6584 High Resistivity Zone Top Kuparuk 11389 6744 Kuparuk Cap Rock Target Sand -Target 11730. 7005 Target Sand (9.9 ppg) Total Depth 12168 7341 Casing/Tubing Program: Hole Size Csg/ WffFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3069 31/31 3100/2591 8 1/2" 7" 26# L-80 btrc 12138 30/30 12168/7341 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3998 psi is 3301 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional DSS N/A 1. PDC Bit f/Prince Creek to TD w/MWD Dir and LWD (GR/CDR/CDN). Mudloggers are NOT required for this well. OCT 995 Oil & Gas Cons. Commission Anchorage Mud Program: ] Special design considerations ] None- SPUD MUD Surface Mud Properties: Density Marsh Yield 10 sec 10 min pH Fl6id (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 9.0 50 35 15 30 l0 15 Intermediate Mud Properties: N/A Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: ] None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 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: I KOP: 150o' Maximum Hole Angle: Close Approach Well: 62 (No Shut Ins) I Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Request to AOGCC for Annular Pumping Approval for MPJ-16: 1. Approval is requested for Annular Pumping into the MPJ-16, 9-5/8" x 7" casing annulus. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 3100' md (2591' tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface' Pressure while annular pumping is calculated according to the following equation and is 3100 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (aBES) (aBES) Milne Point MPJ-13 4070 0 1995 Milne Point MPJ-16 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. , 2. 3. 4. 5. . . 10. 11. 12. 13. 14. 15. 16. MPJ-16 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD. ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out FE and 10' of new formation -- Perform FIT to 12.5 PPg. Drill 8.5" hole to TD as per directional plan -- Run and Cement 7" Casing. RIH while PU 3-1/2" drill pipe and tandem 7" 26# scrapers and bit. Drill the ES Cementer and RIH to PBTD, perform a casing wash while displacing the hole with source water. Filter source water to 2 micron absolute. Freeze Protect Top 2000' of hole with diesel. Pressure test above the plug to 3500 psig. POOH LD remainder of 3-1/2" drill pipe. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Perform Casing Wash. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: . . -3. The Kuparuk reservoir sands are over pressured to 12.7 ppg in the MPJ-09 injector which is located one fault and 1898 feet away from the MPJ-19 location. Reservoir bulk volume calculations indicate the highest possible pressure adjacent the fault line is 10.9 ppg EMW. The MPL-17 kuparuk producer is in the same fault block as the MPJ-19 target and shows reservoir pressure at virgin (3500 psig or 9.6 ppg). An IHR Gyro will be run in the first 1500' out of the surface casing shoe to ensure that we do not drill cross the fault line into the possible MPJ-09 pressure. In the unlikely event MPJ-09 fault is crossed, the kick tolerance for the 10.9 ppg pore pressure case with 11.4 ppg mud weight is 83 bbls. This is calculated using a 0.39 psi/ft gas gradient for the Milne Point. Kuparuk Crude with a 600 GOR. ~)iscuss the MPJ-09 pressure status and this kick tolerance at the pre-reservoir meeting before drilling into the Kuparuk reservoir -- and perform a Flow Check after penetratinq each of the Kuparuk A3, A2, and A1 sands. Gas hydrates: Although hydrates were encountered on E, H, and Pads, it is evident from the neutron/density crossplots of MPJ-01 and from 6 wells drilled by Nabors 22E in 1994 that hydrates are not present on J Pad. This was confirmed when MPJ-19 was drilled and did not encounter hydrates. However, in the event hydrates are encountered follow the guidelines outlined on the MPI Pad Data Sheet. 4. No other drilling hazzards or risks have been identified for this well. CASING SIZE: 9-5/8" MPJ-16 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 61 7 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER:0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9~5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 150 sacks. ()CT Oil & Gas Cons. C0rnmissi0r~ Anchorage MPJ-16 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: 221 FLUID LOSS: < 50cc/30 min @ 140° F YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/s THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60° F BHST 80° F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight, LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 187 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 18 joints of 7" (36 total). This will cover 300' above the C1 Sand. 2. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer above and below the 7" ES Ceme Total). 3. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint from OB Base Sand to 200' above Sand (44Total). 4. Run two 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 5. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 84. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the Kuparuk Target Sand wi excess. 2. Stage 2 cement volume is calculated to cover from the OB Base to 1000' above the NA Top with 30% excess. t7~ · ~"~ 0'CT 23 .0il .& Gas Cons. Commission Anchorago SHARED SERVICES DRILLING I II I II II I I IIII I m i I I II I I i · II II iiiii I IIIi i i I I · il i II MPJ-95C (P7) VERTICAL SECTION Section at: 312.41 TVD Scale.J 1 inch = 1600 feet Oep Scale.' 1 inch = 1600 feet Drawn · i0/23/95 VIEW A ! I -.~ Marl(er Identification MU DKU 5bL;IN INL;L : :I A) KB 0 0 0 O. ( B ._ I . 8) KOP/BUILD 2.5/200 500 500 0 0.( : C) CURVE 2.5/:100 2:100 :1973 484 40.C ...... ' ..... ~~ DI END 2.5/100 CURVE 2934 2508 ]031 59.c. E) CURVE 2.0/:100 4t:16 3]00 ]880 59.~. ' F) END 2.0/100 CURVE 4710 3399 2269 59.c. .... G) CURVE 2.0/:100 7105 4600 3667 59.c. .... ~-~q~'~f'-~l~ H) END 2.0/tO0 C~VE 9240 5607 5347 66.[ I) DROP 2.0/~00 10004 59J2 604B 66.[ ~ J) END 2.0/~00 DROP ~1330 6698 7~01 40.( K) TARGET t ]730 7005 7358 40.( ~ L) TD ]2t68 734] 7639 40.( I ~ ' FEASIBILITY PLAIN ~ , :XE~UTI()N ( 800 1,600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 t t200 t2000 ]2800 ]3600 Section Departure ;~.51;).03 9:53 AN PI ' - - 0 I 0 ,q N -23-95 10:38 Anad~.ill DPC 907__344 2160 I~ . 08 SHARE'S) SERVTCES DRT"LLZN6 ... i I i A,"arkerK8 Identif~cati°n' MO0 . So MPJ-956 (P7) O] END 2.5/~00 CURVE 2934 1503 389~ " E) CURVE 2.0/]00 4J~6 2096 632 CLOSURE · 8488 feet at Azimuth 338.26 F) ENO 2.0/~00 CURVE 4710 2605 693 G) CURVE 2.0/~00 7]05 4677 693 DECLINATION.' +0.000 (E) H) END 2.0/~00 CURVE 9240 6338 ~45] SCALE · ~ ~nch = ~600 feet I) DROP 2.0/]00 ~0004 68~ t969 a) ENO ~.0/~00 OROP ~]330 75~] ~746 DRAWN ' ~0/23/95 K) TARGET ~]730 7695 2936 L) TD ~2168 7885 3144 ]o4oo- - -- ....... : _. ~.. -- , ANAD~ ~ILL A ..... ~ ..-.-.- 7200- 6400 5600~- ....... ' .-. _ ...... I 4800- - . , I 4000 -. I 3~oo ·, i · 2400 I 1600 ¢ 800 ...... · ' o ...... ~00 4800 4000 3200 2400 ~600 800 0 800 ~600 2400 3200 4000 4800 5600 ~ <- ~EST ' EAST -> WELL PERMIT CHECKLIST ADMINISTRATION 1. 2. 3. 4. 5. 6. 8. 9. 11. :1.2. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............ Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ · Y Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING WELL NAME GEOL AREA UNIT# PROGRAM: exp [] der [] redrll [] .serv~ 15. Surface casing protects all known USDWs~. ........ N 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... Y~ N 19. Casing designs adequate for C, T, B & permafrost .... ,~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~~- 22. Adequate wellbore separation proposed .......... Y~ N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ............... . ..... ~ N 26. BOPE press rating adequate; test to .~-~ psig.~ N 27. Choke manifold complies w/API RP-53 (Ma% 84) ...... .~~ 28. Work will occur without operation shutdown ....... ~.~3 N 29. Is presence of H2S gas probable ............ ~ ~ N GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Seismic analysis of shallow gas zones .......... Y/N Data presented on potential overpressure zones ..... Y 32. 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports .... /~ Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ ~ TAB ~'~ ?_~ .... Comments/Instructions: '"')W/jo - A:~ORMS%cheklist rev 03/94 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 simp!ify finding information, informati;:)n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. POINT ./ /, ~' .-, , ~' ._ %. & 6';4 ~"-'; -' "' ..... ........ · .: _. .., ..... ,_. :..~ -., ._._;. ';'..._ .~.. . ,' ¢: . ...... ':7~,:.--:~ '-.- :~.=-,.' ~;'/- - ' . .~ ..~.: ,..._ _ .. .. ::- ~ :-.-: ..:-~.-~--:~'Z ~.~ ~ _.': .."- :::a ~. / .~ ~:..-.'.-:'-:,'.:-~:~ .'¢:;-----~.; :..; >~; ~ Run 1' 17 - November - 1995 GRCH Marked Line 3150 . -'"'"'- ' ,..._~ 11989 WESTERN ATLAS Logging Services Tape Subfile 2 'is type'~ IS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPJ - 16 500292261500 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 05-DEC-95 6522.00 BRAD ESARY JIMMY PYRON 28 13N 10E 2317 3336 .00 65.00 35.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 9.625 3112.0 3RD STRING 7.000 10553.0 PRODUCTION STRING 5.000 12203.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ GR GRCH 1 1 17-NOV-95 WESTERN ATLAS LOGGING SERVICES 40.00 26.00 15.00 REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... Marked Line GR/SBT. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MAGNETIC MARKS FOR DEPTH CONTROL. THE MAIN PASS WAS LOGGED IN 2 SEPARATE PASSES, AN UPPER & A LOWER PASS, WITH A GAP BETWEEN THE TWO. THE PA~ ~S ARE IDENTIFIED ON THE 5 £LINE AS: PASS 1: 9500 - TD PASS 2: 3150 - 6415'. FOR THE PURPOSES OF THIS LDWG TAPE THESE 2 PASSES HAVE BEEN COMBINED INTO ONE PASS IDENTIFIED AS PASS 1. A THIRD PASS, THE REPEAT, IS NOW IDENTIFIED AS PASS 2. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 3150.0 11989.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. NOTE: THERE IS A DATA GAP IN THE GAMMA RAY FROM 6376 - 9500t . CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ - 16 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 310 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 141 1022 BYTES * Tape File Start Depth Tape File End Depth = 12069.000000 = 3146.000000 Tape File Level Icing = 0.500000 Tape File Depth b,,its = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35695 datums Tape Subfile: 2 244 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 11800.0 11989.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: i BASELINE DEPTH 11810.0 11815.0 11850.0 11859.5 11867.5 11879.0 11888.5 11914.0 11920.0 11944.5 11955.0 11969.0 11979.5 $ REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 11810.5 11815.0 11850.0 11859.5 11867.5 11879.5 11889.0 11914.5 11920.0 11945.0 11955.5 11969.0 11980.5 PASS 2 (REPEAT PASS). CN WN FN COUN STAT / ? ?MATCH. OUT $ : BP EXPLORATION (ALASKA) : MPJ- 16 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 * DATA RECORD (TYPE# 0) Total Data Records: 1022 BYTES * 4 30 995 99 Tape File Start Depth = 12082.000000 Tape File End Depth = 11794.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1155 datums Tape Subfile: 3 49 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3150.0 $ LOG HEADER DATA STOP DEPTH 12027.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON CENTROLLER SEGMENTED BOND TOOL CENTROLLER VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: 17-NOV-95 FSYS REV. J001 VER. 1.1 31 17-NOV-95 12064.0 12034.0 3150.0 11989.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA .0O0 12203.0 .0 MUD 10.90 .0 .0 0 .0 .000 .000 .000 .0 .00 HOLE CORRECTION , _~) : JO0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 PASS I (MAIN PASS). NOTE: THERE IS A DATA GAP IN THE GAMMA RAY FROM 6376 - 9500'. $ CN WN FN COUN STAT BP EXPLORATION (ALASKA) MPJ - 16 MILNE POINT/KUPARUK NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 2 CCL SBT 68 3 SPD SBT 68 4 TEN SBT 68 1 GAPI 1 1 F/MN 1 LB 4 4 81 310 01 1 4 4 81 150 01 1 4 4 81 636 99 1 4 4 81 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 714 Tape File Start Depth = 12069.000000 Tape File End Depth = 3146.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 214161 datums Tape Subfile: 4 Minimum record length: Maximum record length: 794 records... 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11796.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 12040.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON CENTROLLER SEGMENTED BOND TOOL CENTROLLER VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: 17-NOV-95 FSYS REV. J001 VER. 1.1 2210 16-NOV-95 12064.0 12034.0 3150.0 11989.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA .000 12203.0 .0 MUD 10.90 .0 .0 0 .0 .000 .000 .000 .0 .00 HOLE CORRECTION .q): 000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ - 16 : MILNE POINT/KUPARUK : NORTH SLOPE · o ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 2 CCL SBT 68 3 SPD SBT 68 4 TEN SBT 68 1 GAPI 1 1 F/MN 1 LB 4 4 81 310 01 1 4 4 81 150 01 1 4 4 81 636 99 1 4 4 81 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 12082.000000 Tape File End Depth = 11794.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6921 datums Tape Subfile: 5 102 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 6 is type: LIS 95/12/05 01 **** REEL TRAILER **** 95/12/ 6 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 6 DEC 95 12:08p Elapsed execution time = 3.90 seconds. SYSTEM RETURN CODE = 0 , E O NDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~~, DATE: Chairman~ October 22, 1996 THRU' FILE NO' Blair Wondzell, ¢~~ P. i. Supervis°~~~/~'DJ FROM- Bobby Fo§ter~' SUBJECT: Petroleum Inspector JW91JVDD.doc Mechanical Integrity Test Miine Point Unit Pads J and F Tuesday, October 22, 1996: ! traveled this date to BPX MPU well F-74 and J-16 and witnessed the MIT. As the attached AOGCC MIT report shows well F-74 passed this initial test. Well J- 16 has a leak from the tubing to the 7" casing and the pressures will equelalize. I called Blair Wondzell and he agreeed to test the well by bleeding the casing off to 1000 psig below the tubing pressure and observe the well for 30 minutes. During the 30 minutes test time the casing pressure gained 80 psig. I feel that this well should be tested every 6 months. Summary: I witnessed the MIT on BPX's MPPU wells J-16 and F-74. Attachment: JW91JVDD.XLS X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO FIELD / UNIT / PAD: MPU - PADS J AND F DATE: 10/22/96 i!i ~wELE ! i':' INJ.:i TEST; ~:'ANNiii: ::iii~::~D :!! iii ii!i:: :i !::~A~ING~i ::~i i:!!'. ~BG.i TEST ' ~.i;:',CsG':':i !TBG:::: i:::TBG~:':i ,' TBG .sTART:i !::,ii:NAME ii::: FLuiD .:TYP;~: ::F:~UIDiii i :B:~::: i ii ':~':I~E':ii~:!GR'AD'~'i::: :i:~:iZE: PRESS ~iPR:ESS ::' :i CSG:'!~ i:: ,: C:SG:;:!; i: :::CSGi'::i ':,,TIME . J-16 '" S P DIESEL .6,150 7"-26#-L 80 3.5" 2;550 2,.575.. 2,550 2,500 11:45AM BRINE 10,289 1537.5 2,450 ..... 1,400 11460 1,480" i~c~i[/IMF-NT~,~ ...... Thi.~ W~.ll h~.~ ~ fuhinn fn n~.~incl I~?k' Th~. nre.~.~ure w;~.~ hied nfl nf the fut)in'q, fn dp. lermin~ if fha. le~k w~.~ minnr I nnnf~nf~.d mv .~un~.rviMnr nd he agreed to this type of test. ~:~ '.';':% ~ I .......... !... IBRINE 14,760 I 1815 I 0 I 1,850 '1 1,.810 .... i 1,800 ...... COMMENTS: This is tile initial test of this well. :'COMMENTS: ! I COMMENTS: COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M .= ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST Distribution: 'odg - Well File c - Operator c -,Database c -Tdp Rpt File c - Inspector · , , OPERATOR REP SIGNATURE: O'MALLEY/KETCHEUM JW91JVDD.XLS ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 6.7 0.35 0.00 9.5 0.49 0.00 0.00 , AOGCC REP SIGNATURE: WELL TEST: Initial 4 - Year X Workover Other BOBBY D. FOSTER (Rev 9117196) LARRY GRAi~T Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE A_NCHOR3LGE 99501. Date: RE: 9 January 1996 Transmittal of Data ECC #: 6522.01 Sent by: H~/YD CARRY Data: PFC/PERF Dear Sir/Madam, MPJ-16 MILNE POINT / KUPARUK NORTH SLOPE, AK . . Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Run # ~ Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~/~ Or FAX to (907) 563 7803 JAN Date ~ ..... u;:~ ~ .... u,~,~Solu~ , .
