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180-005
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' Wallace, Chris D (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 28, 2019 10:40 AM To: Dan Marlowe; Wallace, Chris D (DOA) Cc: Holly Tipton; Juanita Lovett; Michael Quick Subject: RE: D-15rd2 Shut-in due to possible IA casing communication (PTD 180-005) Dan, Sorry for delay in response. I agree that the IA is intact and there is no issue with the casing or tubing. The Seawater injection (45 deg F) has a cooling effect on the wellbore and once SI it allowed the IA to warmup and increase pressure. You have approval to bring well back on iniection. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ( or (Guv.schwartzOalaska.cio ). From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday, January 17, 2019 7:57 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Holly Tipton <hotipton@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Michael Quick <mquick@hilcorp.com> Subject: FW: D -15n:12 Shut-in due to possible IA casing communication (PTD 180-005) Guy & Chris D-15rd2 has been shut-in for about 6 weeks now for monitoring post -earthquake. We initially allowed it to thermally stabilize at 2100 psi, then bled to 1000 allowed it to stabilize, then to 500 and allowed it to stabilize. (see updated TIO plot) The goal was to see if we had any issues with the 7" casing as we quickly determined that we don't have communication between the IA and tubing. With the additional information, a temp log isn't warranted as everything appears to be in order. As such, We request permission to return D-15rd2 to injection. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarloweahilcorp.com • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Friday, April 15, 2016 9:18 AM To: Wallace, Chris D (DOA) Subject: RE: Shut-in D-15RD2 due to possible IA casing communication (PTD 1800050) Attachments: D-15RD2 90 day TIO & Bleed rpt.xlsx OK Chris...here's where we stand on the D-15RD2 well integrity testing. It does appear that the IA pressure changes were thermal in nature, larger than normal (hot PW injector), but thermal none the less. Per the attached 90 day TIO and bleed report, once the well was consistently injecting, the IA pressure did get bled a couple of times early during the restart (and once later on). Since then the IA pressure has stabilized at a safe level of 250 psi. There were a couple of times that the PW went down resulting in a cool down and consequent drop in IA pressure, but when injection returned, the IA pressure went back up to its previous levels. The well hasn't needed any IA pressure bleeds since 3/18 while injection pressures into the well have remained - 3900 psi. This indicates that the mechanical integrity of the well is intact and that injection should be allowed to continue without any AA type requirements. Please let me know if you concur. We will continue to monitor this well and notify you if anything changes with regards to this well's integrity. Larry SCANNED DEC 0 5 2016 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Wednesday, March 02, 2016 2:55 PM To: Larry Greenstein Subject: RE: Shut-in D-15RD2 due to possible IA casing communication (PTD 1800050) Larry, As discussed just now on the phone, lets revisit this after 30 days continuous injection when we can review the TIO and any bleeds needed in the period. As discuss let`s try to minimize the bleeds to allow a better picture of the temperature effects to form. 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. 1 0 • 0 0 0 0 0 0 0 0 in 0 0 IN e•II •-1 in C.) ) t kl, C:t .1 C..) il ti) ............. allIMIIIIMIIIMMI / I , 4-.1 •-. C) .6 ' CV EU r--t r•4 .ft '...i. a c! I -----' / cri 0 0 0 0 IA 1.....1 tN 0 MC < Ce -. ... ...immr 1.11 11111 ' .-4 0 Ci < = ' 1.L. ) CI at M 0 I an ) .. CI, C-J .. T T I -- 0 0 CD 0 C 7, 0 CD CD 0 CD 0 0 0 ,--. Tr ty'l CV • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, February 22, 2016 10:43 AM To: 'Larry Greenstein' Subject: RE: Shut-in D-15RD2 due to possible IA casing communication (PTD 1800050) Larry, Thanks for the email and call. Approved for plan below and up to 30 days injection. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer SCANNED MAY 1 9 2016 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.aov. From: Larry Greenstein [mailto:Igreenstein©hilcorp.com] Sent: Monday, February 22, 2016 10:37 AM To: Wallace, Chris D (DOA) Subject: Shut-in D-15RD2 due to possible IA casing communication (PTD 1800050) Good morning Chris. Seems like we might have some tbg x IA communication with this well. Being a produced water injection well that was being brought back online after some surface work, the IA pressure increase seemed to be more than just a thermal response, so we shut the well down. We'd like to get some approved diagnostic time with this well. Keeping the well shut down, we'd like to perform a low pressure MIT-IA and then bring the well back online for no more than a month to further monitor the IA pressures as the increase may just have been strongly thermal. If the MIT-IA is not successful, then bringing this well back online will allow us to establish an accurate downhole thermal profile to hopefully prove the water is going where it's supposed to be going with a temp survey. Please let me know if you would like anything additional to consider this request. Attached are the well's schematic and 90 day TIO plot. Larry 1 • • • From: William Barnes Sent: Monday, February 22, 2016 4:28 AM To: Larry Greenstein Cc: Dan Marlowe; Terry Hensley; Jon Loomis Subject: D-15RD2 IA 7" casing communication Larry Produced water Injection was S/D 02/19/2016 at 0700hrs for piping and seal changes B.O.L.02/21/2016 at 1730hrs. 02/19/2016 tubing @ Opsi.this well usually @ Opsi during shut in periods.02/20/2016 tubing was @ 1300psi. 02/19/2016 IA 7" casing @ 50psi.02/20/2016 IA 7" casing @ Opsi 02/21/2016 At around 2000hrs taking tubing and casing readings D-15 IA 7" was showing Opsi. D-15 IA 7" casing limits set at 1000psi upper limit. Constraints sent out from town. D-15 IA 7" casing at 2145 spiked to 1350psi, Pressure switch alarms @ 500psi, changed gauge to verify. Checked with lead Mike Loomis (said to try two or three time bleeding down) and bled to 180psi monitoring for buildup. 0045hrs D-15 IA 7" @ 390psi. 0120hrs D-15 IA 7" @ 500psi. Bled down to 160psi monitoring. 0330hrs D-15 IA 7" @ 360psi. Bled down to 160psi monitoring. 0415hrs D-15 IA 7"@ 220psi.Shut in well. Willie Barnes Sr operator Dolly Varden Platform 2 • • CD C:. CD CD C, CD C. 0 Ill 0 0 CV •-I gml sr, 0 l ....._ .......,.. .1111.1.1111111. 10 •-• 0 rsi . ........ 40 ir-II 0 VD •—I 0 CV c) al ko ...) c) nil c) c) %CI 1,--1 0 CNI •-•4 C :6- SP ID •..... •-1 C •—• CNI 1... IN ••••••••. 4) *0' 01 ..-• 1,01 PO 0 ...i VD 0 1 al 0 1,1 SIC ci 1 CP NI 0 If) ° .—.• •-•4 v.-11 CI m 0 cc a 1.11 10 0 1...1 •-.1 0 0 I C4 I CI ...., Lf1 = Ct < CO ""•••• 0* •-. Il Ln 0 C CNI ......, J:Ju." 01 = tNi 1.-- i •—I Ill1 •-4 0 CNI t11 ' . LII ir-4 0 CV Iii . i•—I ...... • I 41111111j1 1.11 •-•1 i rg I °D , 0 111 1 CNI 1 •-1 .-11 i 0 ,,E1.., —, . ...._ c• CO CD CD CD rsi CD CD CO 0 v—i 0 0 0 0 Sr VI IN ir-4 Imag~roject Well History File Coverage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes. No. [3 Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY ROBIN VINOENT~MARIA WINDY DATE;q/~.~(~' ~N Scanning Preparation x 30 = '1 ~ + = TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY ROBIN VINCE~ARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A'n'ENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAUTY. QRAy$CALE OR COLOR IMAGES) NO ¸NO IIIII RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10102Rev3NOTScanned,wpd • • OF I j/j�s THE STATE Alaska Oil and Gas oA ASK 1 Cseration Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ca\rk Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 SCANNED NO I 3 7U 3 Fax: 907.276.7542 Dan Marlowe Operations Manager Hilcorp Alaska, LLC Q-d 0 ©5" 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil & Hemlock Oil Pools Trading Bay Unit/D-15RD2 Sundry Number: 313-527 Dear Mr. Marlowe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair, Commissioner DATED this IS day of October, 2013. Encl. . . • STATE OF ALASKA tO , ', ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon Cl Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations El Perforate U . Pull Tubing GI • Time Extension 0 Operations Shutdown 1=1 Re-enter Susp.Well 0 Stimulate CI Alter Casing CI Other Complete • El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC Exploratory 0 Development El 180-005 ' 3.Address: 3800 Centerpoint Drive,Suite 100 6.API Number Stratigraphic El Service GI'• Anchorage,AK 99503 50-733-20159-02 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 0 No U A Trading Bay Unit/D-15RD2 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 ■, McArthur River Field/Middle Kenai G Oil&Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,400' 10,229 • 10,195. 10,0291, 10,276 (cement) Casing Length Size MD TVD Burst Collapse _ Structural Conductor Surface Intermediate 2,500' 13-3/8" 2,500 2,434' 3,090 psi 1,540 psi Production 6,003' 9-5/8" 6,003' 5,877' 5,750 psi 3,090 psi Liner 4,643' 7" 10,380' 10,208' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.2#/N-80 9,151' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Otis WD Packer/SSSV:N/A Packer 9,090'(MD) 8,932'(TVD)and 9,470'(MD)9,307'(ND)/SSSV:N/A 12.Attachments: Description Summary of Proposal U. 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service IS 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/15/2013 Oil El Gas El WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ GI . GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 1:1 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(Mhilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature --- It. / Phone (907)283-1329 Date 10/7/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: XPlug Integrity 0 BOP Test 13/ Mechanical Integrity Test Location Clearance CI Other: 44- 3A00e-) fs: 50 e 7:75- ISpacing Exception Required? Yes 0 No Subsequent Form Required: /0 - qd-f APPROVED BY Approved by: Ogi p -)2.6,4,......,_ COMMISSIONER THE COMMISSION Date: /0..../S-'-' /3 .\11 714., 10•Ion. 13ri 1 n 1 k 1 it:Nib "0,0/a(5./7" RE3DMS OCT 16 NZ Submit Form and Form 10-403(Revised 10/2012) ApproUalcittUii 414 Alaonths from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: D-09RD Hilcorp Alaska,LLC Date: 10/07/2013 Well Name: D-15RD2 API Number: 50-733-20131-01 Current Status: Injector / Leg: Leg#A-2 (NW corner) Estimated Start Date: October 15, 2013 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 180-005 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell:907-398-9904 Second Call Engineer: Ted Kramer Office:907-777-8420 Cell: 985-867-0665 AFE Number: 1322465 The well is currently injecting about 400 bwpd. When shut-in the pressure falls off gradually. The well needs to be shut-in about 4 weeks before the workover, and bled down to reduce the reservoir pressure around the wellbore. The estimated pressures assume a salt water gradient and fluid rate at surface. If the fluid level drops, a fluid level needs to be shot with the Echo meter. Current BHP: '"3900 psi @ 8480'TVD/9720'MD .46 psi/ft,(8.8 ppg)at mid pert of GZ&Hemlock Max.Expected BHP: ^'3900 psi @ 8480'ND .46 psi/ft.(8.8 ppg)Recomplete in same zones Max.Possible SP: 0 psi Using 0.46 psi/ft SW gradient to surface Brief Well Summary D-15RD2 is an injector capable of much more flow than it is taking now. Prior to 2003 it took about 2200 bwpd. Since then, the rate has steadily declined to its current 400 bwpd. This injector is one of three injectors (D- 15RD2, D-45, D-09RD)that support Dolly and Grayling offtake from the southern flank of the main feature. The objective of this rig workover is to pull the existing tubing and injection packer, mill/retrieve the lower selective packer, re-perforate the G-zone and Hemlock, and run a new 4-1/2" injection completion with plastic-lined tubing that is expected to last at least 10 years, preferably for the life of the well. Once D-15RD2 is re-perforated and tubing integrity is restored the well is expected to inject about 3500 bwpd supporting offtake from much of the southern nose. Once reservoir pressure is recharged,an oil rate bump of approximately 243 bopd gross and 212 bopd net(7/8) is expected from surrounding producers. Approximately 50%of this rate increase, or 121 bopd gross, is credited to this injector repair for economics,while 50%of this rate bump has or will be credited to the producer repairs completed or coming in the future. Notes Regarding Current Wellbore Condition • Communication between tubing and the tubing by casing annulus • There is a hole in the tubing at 600'that has been difficult to patch. See WSR of 3/1/12 for the latest details on the patch. A 2.5"GR was run to 10,069'on 2/26/12 so options to inside cut the tubing before scale is rattled loose should be available. Procedure: 1. Skid rig and RU HAK Rig 1 over D-15rd2 well slot. 2. Notify AOGCC 24hrs before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi LOW and 3,000psi HIGH. 3. RU E-line. Cut tubing just above the upper permanent packer at 9090'. c.� s b.* G /o•f/J • • Well Work Prognosis Well: D-09RD Hilcorp Alaska,LLC Date: 10/07/2013 4. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from cut at 9090'. CBU—losses should be minimal. 5. POOH, LD tubing. Run overshot and jars on workstring and attempt to release from Anchor and pull the Otis locator and seal assembly. LD same. 6. Mill and retrieve packer at 9090' 7. Mill and retrieve packer at 9470'. 0 8. Clean out fill to a PBD of 10195'.Circulate with FIW to clean wellbore. POOH. 9. PU bit and scraper and RIH to 9150'. Circulate hole clean with clean filtered inlet water until returns are clean and well is ready to be re-perfed. POOH. 10. PU retrievable test packer and RIH to 9100'. Set packer, test backside to 2500 psi to confirm casing integrity. Hold for 30 minutes, record with a chart recorder. 2,04'hs� 11. POOH 200' and PU storm packer. RIH, set same at 200' and hang off stringy,. Pressure test t• • Release from storm packer, POOH. Replace tubing head. .__� ��f1a - 1 r /So P 6c'��° 12. RIH, engage storm packer, release same, POOH, LD storm packer and retrievable packer. `k '/'D` 13. PU TCP guns and RIH and re-perforate the G-zone and Hemlock zones per the Perf Recommendation. 14. After detonation, circulate perf gas,confirm well is static, POOH. 15. Provide a minimum 24 hour notice to AOGCC prior to the workover pressure test. 16. PU injection packer and 4-1/2" plastic lined tubing. RIH, set packer within 200' of top perforation ±9,060'. a�4, Ft—.J. 7 17. Land the tubing hanger, and pressure up backside to confirm packer is set. 18. Conduct WO MIT by pressuring annulus to 2500 psi and holding for 30 minutes with a 2-pen chart IA- recorder. rr- 19. Set BPV. NU tree,test same. 20. Place well on injection. Well is expected to take between 2500 and 5000 bwpd at full header pressure and new perforations. 21. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. v Attachments: DM-) 1. Current Well Schematic 3'n • 1164 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack • • McArthur River FieId,TBU SCHEMATIC Well: D-15RD2 Ilikorp,tlaska,LLC As Completed: 09/21/82 RKB to TBG Head=39.00' CASING DETAIL Size Wt Grade Conn ID Top Btm i 1 ' 13-3/8" 61 K-55 Butt 12.515" Surf 2,250' 9-5/8" 40,43.5,47 N-80 Butt 8.681" Surf 6,003' 7"Lnr&TB 29 N-80 Butt. 6.184" Surf 10,380' TUBING DETAIL 3-1/2" I 9.2 N-80 I Butt. I 2.992" I Surf 9,151' �vv° ,1 f_ "7 k "' JEWELRY DETAIL No Depth ID Item 1 39.00' 4-1/2"CIW"F"Hanger w/4-1/2"ASL pin x 3-1/2"Butt pin 3.958" bottom 2 9,102' 2.992" 3-1/2",9.2#,N-80,Butt tubing 3 9,089' 3.00" Otis Locator • 2 4 9,090' 4.00" Otis WD Packer with 8'Seal Bore Extension(Set w/E-line) 5 9,107' 2.750" Otis"X"Nipple �- ‘. -0-1-' 6 9,138' Mule Shoe EOT 64.,WO 7 9,470' Otis WD Packer 8 9,485' 2.750" Otis"X"Nipple 3 II 1 9 9,496' Bell Guide EOT 4 ►� /A-1 L-1--- SLICKLINE/FISH/FILL INFORMATION: A.Sept 1982:EZSV junk pushed to bottom at 10195'. 5 6 B.8/25/88:Bailed to 10100'. G-2 PERFORATION DETAIL G-3 Last Perf Zone Top Btm Amt SPF Status Date =-G-4 G-2 9,243' 9,244' 1 4 9/8/82 Sqzd G-2 9,258' 9,272' 14 4 9/17/82 Open 7 4 1�- /lit L(.L- G-2 9,276' 9,277' 1 4 9/7/82 Sqzd G-3 9,284' 9,300' 16 12 9/16/82 Open t, G-4 9,322' 9,352' 30 12 9/16/82 Open 8 B-1 9,676' 9,698' 22 12 9/21/82 Open 9 B-3 9,815' 9,856' 41 1 9/3/87 Open B-3 9,860' 9,862' 2 2 5/8/80 Sqzd =- B-1 B-4 9,890' 9,995' 105 4 5/14/80 Open 8-5 10,030' 10,050' 20 8 9/21/82 Open - B-3 B-5 10,050' 10,075' 25 4 5/4/80 Open B-5 10,075' 10,100' 25 8 9/21/82 Open 8-5 10,100' 10,118' 18 4 5/4/80 Open B-4 B-5 Plug Back Depth=10,195' TD=10,400'MD MAX HOLE ANGLE=25° • • McArthur River Field, TBU PROPOSED Well: Completed:D-15RD2 ture Fu Hi!carp Alaska,LE.l RKB to TBG Head=39.00' CASING DETAIL i i . , [ Size Wt Grade Conn ID Top Btm 13 3/8" 61 K 55 Butt 12.515" Surf 2,250' 9-5/8" 40,43.5,47 N-80 Butt 8.681" Surf 6,003' 7"Lnr& TB 29 N 80 Butt. 6.184" Surf 10,380' TUBING DETAIL 4-1/2" 13.55 L-80,PL BTC 3.4 Surf ±9,178' JEWELRY DETAIL No Top Depth ID Item 1 39.0' Hanger 2 ±9,100' Tri-Point Stim-Top Production Packer 3 ±9,147' X-Nipple 4 ±9,178' WLEG , SLICKLINE/FISH/FILL INFORMATION: CA r v A. Sept 1982: EZSV junk pushed to bottom at 10195'. p�" B. 8/25/88: Bailed to 10100'. 2 1 3 x PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt SPF Last Perf Status 4 Date G-2 9,243' 9,244' 9,083' 9,084' 1 4 9/8/82 Sqzd G-2 9,258' 9,272' 9,098' 9,111' 14 4 9/17/82 Open G-2 ±9,264' ±9,275' ±8,104' ±8,113' 11 Future 8-2 G-2 9,276' 9,277' 9,115' 9,116' 1 4 9/7/82 Sqzd 8-3 G-3 9,284' 9,300' 9,123' 9,139' 16 12 9/16/82 Open G-2 ±9,287' ±9,297' ±8,123' ±8,131' 10 Future G-4 G-3 ±9,322' ±9,350' ±8,152' ±8,175' 28 Future G-4 9,322' 9,352' 9,161' 9,191' 30 12 9/16/82 Open 8-5 G-4 ±9,362' ±9,372' ±8,185' ±8,193' 10 Future G-4 ±9,452' ±9,460' ±8,259' ±8,265' 8 Future G-5 ±9,487' ±9,505' ±8,288' ±8,302' 18 Future B-1 G-5 ±9,523' ±9,546' ±8,317' ±8,336' 23 Future _ HK-1 ±9,674' ±9,704' ±8,441' ±8,446' 30 Future B-1 9,676' 9,698' 9,511' 9,533' 22 12 9/21/82 Open B-3 HK-2 ±9,732' ±9,808' ±8,489' ±8,552' 76 Future HK-3 ±9,808' ±9,872' ±8,552' ±8,605' 64 Future 5/3/00: 8-3 9,815' 9,856' 9,648' 9,689' 41 1 9/3/87 Open - 2.70"GR _B-4 B-3 9,860' 9,862' 9,693' 9,695' 2 2 5/8/80 Sqzd tagged up HK-4 ±9,872' ±10,007' ±8,605' ±8,717' 135 Future at 10,294' B-4 9,890' 9,995' 9,723' 9,826' 105 4 5/14/80 Open HK-5 ±10,007' ±10,116' ±8,717' ±8,807' 109 Future B-5 B-5 10,030' 10,050' 9,861' 9,881' 20 8 9/21/82 Open = B-6 B-5 10,050' 10,075' 9,881' 9,906' 25 4 5/4/80 Open y ;.gro,;: B-5 10,075' 10,100' 9,906' 9,930' 25 8 9/21/82 Open O..* • • ... n Dolly Varden Platform D-15RD2 Current Hi�rn.p must...ilk 07/12/2013 D-15RD2 Tubing hanger,CIW-AP- 13 3/8 X 9 5/8 X 7 X FBB,11X4'''A Armco Seal 3 1/2 lock lift and susp,w/4" type H BPV profile,7" EN,'A"non continuous control line BHTA,CIW,w/internal knockup cap,41/16 5M FE Oa u. 1.1 11111.•1 Valve,Swab,WKM-M, e 0 r 41/16 SM FE,HWO,FF trim O '0 0'0 .. Min J 1 3t m�w pOr ilk Valve,Master,WKM-M, 41/16 5M FE,HWO,FF trim _ O o Q o Adapter,CIW-FBB,11 5M FE X ..OW,. 41/16 5M,prepped for 7" 1111 ' l i ` all extended neck,1/2npt control line port V 1 1i.. (1- Tubing head,CIW-AP,13 5/8 WI r 111 Valve,CIW-F,2 1/16 5M FE, 3M X 11 5M,w/2-2 1/16 5M ` n HWO,AA 550,X-bottom prep, - 1'VR profile I11 OnI�I�\1r e:Al viii •-i. III _ ' iimi 1 Casing spool,CIW-WF, 13 5/8 3M X 13 5/8 3M, I F I V 11 I Valve,CIW-F,2 1/16 3M FE, w/2-2 1/16 5M SSO / ., ((�1 HWO,AA 0�� min fit ;A l 11011.1' III _ • ■ . m. Casing head,CIW-WF, �' 13 5/8 3M X 13 3/8"csg Valve,CIW-F,2 1/16 3M FE, thrd bottom,w/2-2 1/16 III J III HWO,AA 5M EFO ❑ - � n _, IN a is,,_1. • • II Dolly Varden Platform D-15RD2 Proposed 07/12/2013 N irnrp:11xrkn.HA, D-15RD2 Tubing hanger,SME-CL,11 X 13 3/8 X 9 5/8 X 7 X 4'/=EUE lift and 4'''A TC-2 41/2 susp,w/4"Type H BPV profile,2-3/8 CCL,6''4 extended neck,17-4PH stainless steel BHTA,Bowen,4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel ii a ni Valve,Swab,WKM-M, '� 41/16 5M FE,HWO,FF trim }}�� V Valve,Wing,WKM-M, 31/aSM FE,w/15"Safeco liIMI al _ _ op , Full Stainless eratorFF Steel Valve,Master,WKM-M, 4 i91:ir Ilk 1/16 5M FE,HWO,FF trim ...—., Adapter,Seaboard,11 5M FE n 11w 1�) X 41/16 SM,w/6 Y.pocket, a _ 2-'/:CCL exits,Full Stainless 'le •i' :_1��" Steel =An MI■lidarl .`\ '—, Tubing head,S-8,13 5/8 3M x 11 5M,w/2-2 1/16 5M III Ill II tell v. 550,w/BG bottom w/1-2 1/16 5M WKM-M I valves - WM10 4I1.1_i. Jll .> _ Casing spool,CIW-WF, 13 5/8 3M X 13 5/8 3M, 11i liI Valve,CIW-F,2 1/16 3M FE, w/2-2 1/16 5M SSO 14, -� ' 6 HWO,AA I�Illg1'! r 1'Jil II�-i•- lit ll�ii� �.- Casing head,CIW-WF, �� 13 5/8 3M X 13 3/8"csg Valve,CIW-F,2 1/16 3M FE, thrd bottom,w/2-21/16 III ' I 1 I HWO,AA 5M EFO E - - 11411130' . 11111011 I ■ l r ! • • ' . I I Dolly Varden Platform 2013 BOP Stack(HAK#1) 06/20/2013 Nilt•nrp.tLi ka.I.11 6 Hydril • 4.54' GK 13 5/8-5000 III iii ii, iii iii /II 4ii Shaffer SL -1.= .- 0 si— _ IF- 2.83' 13 5/8-5000 - - III III III III III �j,}�` I f• 'y ' 7� ill E ill! 2.00' 1 ill III I.1 111 1111 4 7411.10�1•' 3 i. Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses III III III III III Riser 13 5/8 5M#13 API hub X 13 5/8 5M FE 17.00' Dolly Riser Xover 13 5/8 5M API#13 hub X 1.75' III III 11 5M Flange Regg, James B (DOA) b50 From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Thursday, March 01, 2012 3:28 PM To: Regg, James B (DOA) Subject: Dolly Varden Platform Well D -15RD2 AIO 5.016 Compliance Temp Survey Jim, A compliance temp survey was conducted on McArthur River Field, Trading Bay Unit, Dolly Varden Platform Well D- 15RD2, AIO 5.016 (PTD #1800050) waterflood injector on 2/26/12. The previous compliance temp survey was conducted on 4/1/10. The attached temp survey plot shows the MD plot overlaying D -15RD2 temp surveys on 2/26/12 and 4/1/10. The plot clearly indicates downhole containment of the injection fluids within the approved injection interval with no significant temperature anomalies. The well was carefully brought on a few days prior to running the temp survey to aide in the determination of fluid entry depths. Please call me if you have any questions at 777 -8322. Thank you. Larry 1 • TBU D -15RD2 PTD 180050 2/26/2012 Temperature Survey per AIO 5.016 'Hilcorp I Well:I -15RD2 Varden 102 -26 -2012 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 0 I I _ 1000 Pressure- Temperature Profile 2000 1. RIH 2010 vs 2012 Overlay 3000 4000 • v 5000 c Q 6000 — 7000 i 4 1/1/ 8000 f 9000 - -- -- — — 10000 11000 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) – Perfs — 13 -3/8" 9 -5/8" —7" —TBG ---- 2 -26 -12 Pressure — 4 -1 -10 Temp — 2 -26 -12 Temp Report date: 2/29/2012 • • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 ) \s\.,-3S0 Mobile 907 223 0128 Fax 907 263 7897 Email jzager @chevron.com h�A,S�h) torQ" C.,--0S-7?... 1C•4s —k November 16, 2011 V- - .) a0 ®_ rLk \ NOV yi 7 UIC Manager M— ` � r — 0 t LA, ordlaggew Thor Cutler, OCE -082 t1C11or U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 Seattle, WA 98101 , 1: i} 0 `` ` Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authorization from EPA Region 10 to commence Class I infection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 ! • UIC Manager US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivanOchevron.com or 263 -7685. Regards John ager 9 Enclosures: US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 11006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of 2 • . OMB No. 20400042 Approval Expires 12/3112011 United States Environmental Protection Agency e f EP Washington, DC 20460 EPA Application To Transfer Permit Name and Address of Existing Permittee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Piet • 840 Acres Surface Location Description I I I I I I SC 1/4 of tie 1/4 of 1/4 of SW 114 of Section 6 Township $n Range 13w - 4 -1-- - - - 4 -1- --1- -- Locate well In two directions from nearest lines of quarter section and drilling unit 111 1 ( Surface 1 — -- 1--- - - --1 y I Location 754 ft. frm (NIB) S Line of quarter section 1 I I I I I L and I i 18ft. from (ENV) w Line of quarter section. W ! I I I I I I 1 Well Activity Well Status Type of Permit I — -4 —1— 4 - - 4 - 4 - x Class t X Operating _, Individual I _ I I 1 _ I I _ __ Class!! Modification/Conversion –�– Area 7 _ 8 Brine Disposal Number of Wells % 1-- -4 --- -4-I--4- j — Enhanced Recovery K Proposed 1 1 1 1 1 1 , Hydrocarbon Storage Class III Other lease Number S Attached Well Number See Attached Name(s) and Address(es) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centerpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification i certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John "Lager, General Manager 11/15/2011 EPA Form 7520-7 (Rev. 12 -08) • • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9R0 50- 733 - 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50 -733- 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 1 33 9N 13W M -30 50- 733 - 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W _ G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1838 FNL/ 1487 FEL 29 9N 13W G -16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 _ 50- 733 - 20148 -00-00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W 0-15 RD2 50- 733 - 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 1I006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 11006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. 1 Agreement to Transfer UIC Permit No. AK- 11006 -A • • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK- 11006 -A • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr @chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263 -7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK- 11006 -A • 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which • together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer UIC Permit No. AK- 11006 -A • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company By: — . `. .t By: Name: $ r Name: --la Its: Pe./ Its: v 1 �� pp / — Ah:∎,) j5 20 1 Date: ! llrrcl. S � 'fix: � (� Date: 1 5 Agreement to Transfer UIC Permit No. AK- 1I006 -A 2011 July's Waivered Injection Well Report Page 1 of 1 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, August 08, 2011 1:18 PM -o 0 C O V �OV J To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A; Hallett, Trudi R. Subject: 2011 July's Waivered Injection Well Report Attachments: Master Well List TIO Report 2011 08 01.xis Hi Tom & Jim, Here is July's monthly report for all the active monitored injection wells. We have returned D -15RD2 to injection this last month and all pressures are looking as expected. You can see some of the near wellbore fill up results in a drop off in rate at similar injection pressures. This should level out over a short period of time. Monopod is having sand filter problems, so A -29RD is down and A -08RD2 is injecting only the minimum necessary to keep the treated effluent system functioning properly. These monitored wells are responding as expected to ups and downs in injection volumes without any apparent pressure or rate anomalies observed. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2011 08 01.xis» AU G 1 6 201 8/9/2011 Plot nitre & Rate vs Time - Well D -15RD2 • . 800 3000 Ilk w 700 "' 5/8" 2500 13 3/8" Tubing 600 —Vol 2000 500 T 40Z T, on 1500 300 1000 200 500 100 0 0 N � . O O 0 1 O o O 0 M M M v 1n 1n co r 0 0 0 0 0 0 0 Date 7" 9 5/8" 13 3/8" FEW Vol TIO Report 07/31/11 2950 100 15 2950 613 07/30/11 2950 100 15 2950 632 Data Sheet 07/29/11 2950 100 15 2950 640 07/28/11 2950 90 18 2950 641 07/27/11 2950 50 14 2900 647 D -15RD2 07/26/11 2950 50 15 2900 659 07/25/11 2950 50 15 2900 587 07/24/11 2950 50 15 2940 664 INJECTION 07/23/11 2950 50 15 2950 675 07/22/11 2950 50 15 2920 679 07/21/11 2950 50 15 2950 694 Permit # 1800050 07/20/11 2850 50 15 2840 659 07/19/11 2850 10 15 2820 663 07/18/11 2650 15 15 2650 539 Admin Approval # AIO 5.016 07/17/11 3000 20 15 3000 710 07/16/11 3000 20 10 2950 712 07/15/11 2900 10 10 2900 727 API # 50- 733 - 20159 -02 07/14/11 2950 10 20 2950 749 07/13/11 3000 10 20 3000 778 07/12/11 3000 10. 20 m 2950 775 01/31/2011 to 08/01/2011 07/11/11 3000 10 20 2950 797 07/10/11 3000 10 28 2950 795 07/09/11 3000 10 28 2950 797 07/08/11 3000 10 301 2950 488 07/07/11 3000 10 351 3000 480 1 07/06/11 2650 10 45 2650 571 07/05/11 200 5 5 900 0 07/04/11 0 0 5 2600 0 07/03/11 0 0 5 800 0 07/02/11 0 0 5 0 0 07/01/11 0 0 5 0 0 06/30/11 0 0 5 0 0 06/29/11 0 0 5 0 0 06/28/11 0 0 5 0 0 06/27/11 0 0 5 0 0 06/26/11 0 0 5 0 0 8/9/2011 2:45 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 08 01 (2).xls D -15RD2 Maunder, Thomas E (DOA) From: Martin, J. Hal [Hal.Martin@chevron.com] Sent: Tuesday, April 06, 2010 2:46 PM To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Anderson, Christy D; Loomis, Jon M Page 1 of 1 Subject: Dolly Varden Platform Well D-15RD2 AIO 5.016 Compliance Temp Survey Attachments: D-15RD2 Temp Survey 4-1-10 vs 4-5-08.zip Tom, A compliance temp survey was conducted on the McArthur River Field, Trading Bay Unit, Dolly Varden Platform Well D-15RD2, AIO 5.016 (PTD 1800050) waterflood water injector on 4/1/10. The previous compliance temp survey was conducted on 4/5/08. The attached temp plots (MD and TVD) overlaying Dolly Varden Well D-15RD2 temp surveys on 4/1/10 and 4/5/08 indicate downhole containment of the injection fluids with no significant temperature anomalies. As you recall, our waterflood injection has been down on the Dolly since April 2009 (except for a brief waterflood system injection test period in September 2009 and again in October 2009) due to surface piping issues. However, previous communication with the AOGCC indicated your desire and acceptance of a compliance temp survey for Admin Approval wells like Dolly Varden Well D-15RD2 even though the well was not on injection for the period immediately prior to running a temp survey. Also, for your information, we are nearing surface piping repairs on the Dolly and hopefully will be able to restore injection sometime in the next month or so. Thanx, Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com -,, s 5/13/2010 (Chevron I WeII:ID-15RD2 I Field:~DollyVar~en ~4-01-10 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1000 2000 -- - - Pressure-Temperature Profile 1. Going in hole 9400' RKB 3000 - -- 4000 ._. ~ 5000 - - - .C s~. 6000 7000 -- 8000 -- 9000 10000 , 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) 4-1-10 Pressure Perfs 13-3/8" 9-5/8" Page 1 of 1 Regg, James B (DOA) • • From: Martin, J. Hal [HaLMartin@chevron.com] ~ ~ 43 Sent: Monday, April 21, 2008 1:47 PM ~f ~ U v To: Regg, James B (DOA) ll Cc: Maunder, Thomas E (DOA); Greenstein, Larry P Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication O ~ ~ ~ 5 ]im, Sorry I failed to get with you last week. As I suspected, my work load is a little bunched up at the moment, I have not prepared the Admin request for D-15RD2. I do not know exactly when it will be, although my guess is sometime during the is~ half of May. Therefore, I will have D-15RD2 shut-!n until I can get you the paperwork, '~ Thanx, al ~~A~~~~ NAY ~ ~ 2008 4/30/2008 • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Wednesday, April 09, 2008 10:10 AM To: Martin, J. Hal Cc: Maunder, Thomas E (DOA) Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication Page 1 of 6 Hal -Tom and I have reviewed the temp surveys and pressure plot. {t is acceptab{e to keep TBU D-15RD on injection while you pursue an administrative approval. Any change in the mechanical condition of this well (e.g., OA pressurization) must be immediately reported to the Commission (myself or Tom during office hours; North Slope Inspector during after hours). ., We would expect to see your request soon, say on or before 4/18 Jim Regg AOGCC ~~~~ APR ~ ~QO~ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Tuesday, Apri108, 2008 5:27 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Greenstein, Larry P Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing commun'rcatian ]im, Yes. See the attached. It`s the latest LTSI report Larry sent you last week with a few days added to show the response thru the shut-in on 4/5. Thanx, Hal From: , James B (DOA) [mailto:jim.regg@alaska.gov} Sent: Tuesda , ri108, 2008 3:16 PM To: Martin, J. Hal Cc: Maunder, Thomas E Subject: RE: TBU Dolly 15RD2 1800050) tubing /casing com tion ~~ Do you have a wellhead pressure plot (tubin , ~ ner us, outer annulus) that you could share for the 34 day injection period? Jim Regg AOGCC 333 W.7th A e, Suite 100 Ancho , AK 99501 e: 907-793-1236 fax: 907-276-7542 4/9/2008 Plot Pressure & Rate vs Tim e -Well D-15RD2 3000 _ .,~ .,.a._ _ - _ _ . ..___ _...:., . ___.:~. ....~- --M..,-.. looo soo ~~~ 2500 ~9 5/8" - 13 318" 800 -Tubing i -Vol D-15! - - 700 2000 - ---__ _-- - - -- - - 600 d - y 5 ~ N 1500 --- d a aoo 300 200 500 100 w 0 0 ~ Q m m ao m w ~ o 0 o g Q t7 O O1 N O a0 ao ao o 0 R ao co m m ao ao m 0 0 ~ o o Q o o 1~ O 1~ O f3 O ~ ~ ~ m m m w Q Q g P t~Q ~ t7 (D OI c3 ~ ^ ao Q ~ 10 UD ~ Q O Q \ Q O O O N O ` ` ` O O N N _ Q Q ~ N N ~ N t~`! f~ N l~ f~ f~ O O O O O O ~L' ~ N N N fV (V N f~1 t~ M O O O O O O C~ O l'1 l~ O O N (~ M O O f") O _ y t~ O O O O O O O O O O O O O DatDe ~' 9 S/8" 13 3/8" Tubing Vol D-15 04/05/08 1000 20 75 1200 0 04/04/08 2850 20 75 2850 509 04/03/08 2850 20 75 2850 597 04/02/08 2825 20 75 2825 04!01/08 2850 20 85 2850 03/31/08 2900 20 70 2850 03/30!08 2850 35 85 2800 03/29/08 2850 30 85 2800 _ 03/28/08 2750 30 90 2800 03/27/08 2825 30 95 2800 03/26/08 2850 25 90 2800 03/25!08 2800 30 90 2775 03/24/08 2850 30 90 2800 03/23/08 2900 30 94 2850 03/22/08 2900 30 95 2810 03/21/08 2900 30 95 2825 03/20/08 2900 30 90 2840 03!19/08 2900 30 90 2860 03/18/08 2900 30 90 2850 03/17/08 2875 30 94 2820 03/16/08 2800 30 90 2800 03/15/08 2900 10 95 2850 03/14/08 2800 20 100 2800 03/13/08 2800 20 100 2800 03/12/08 2800 40 100 2800 03/11/08 2800 20 100 2800 03/10/08 2800 30 100 2800 03!09/08 2850 30 104 2800 03/08/08 2900 30 105 2840 03/07/08 2875 30 103 2800 03!06/08 2850 30 100 2800 839 03/05/08 2850 30 100 2850 820 03/04/08 2850 30 100 2825 638 03/03/08 2300 30 90 2800 347 03/02/08 800 30 85 800 100 03/01/08 1300. 75 20 2100 104 4/9/2008 9:42 AM - TIO Reports 7e.xls J J Dolan TIO Report Data Sheet D-15RD2 INJECTION Permit # 1800050 API # 50-733-20159-02 12/31 /2007 to 03131 /2008 D-15RD2 TIOPIot.xls D-15RD2 (2) i Chevron 0i! Co. 'Jyett: D-15RD2 Field: Dolly Varden 04-05.2008 Pressure (psis) 0 500 1000 15x(1 2000 2500 3000 3500 4000 4500 6000 5500 8 i ~! ""~._ Pressure-Temperature Profile 1. RIH 2008-2007 Overlay ~ 1000 i - - ~ - - - 1', - - I I j 2000 _ '' ~ I 1 3000 4000 - --- _. _ ~ I ... w p ~ sooo - ~ --- - o ' i X000 __.__ ._ .. __ i ' 1 9000 l ~ _. ._. I ~ 10000 ~ ~ i -~ ± i t ~ + I ~ F ~ ~ ~ I 50 60 70 SO 90 100 110 120 130 140 150 Tec~perature (Deg. F) ~ __ _____ ~ ~.. __. 45-08 Pressure = Perfs 13-318" 9-518" ~ 7" -TBG 4-5-08 Ternp 3-17-07 Teatp Report date: 4(7!2008 Chevron OiI Co. Well: D-15RD2 Field: Dolly Varden 04-OS-2G08 Pressure (psis) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 '5000 5.500 o I s i 1000 2000 3000 ~ 4000 d d ~~.. v 5000 s a m ~ sooo 7000 sooo 9000 10000 50 60 70 80 ~ 4-5-08 Pressure - Perfs 90 100 110 120 130 140 Temperature (Deg. F) --- - 13-318" 9-518" 4-05-08 Temp 3-17-07 Temp 150 Report date: 417/2008 U Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, April 08, 2008 3:16 PM To: Martin, J. Hal Cc: Maunder, Thomas E (DOA) Page 1 of 5 Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication Do you have a wel{head pressure plot (tubing, inner annulus, outer annulus} that you could share for the 34 day injection period? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Tuesday, April 08, 2008 2:15 PM To: Regg, James B (DOA) Cc: Greenstein, Larry P; Maunder, Thomas E (DOA) Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication Tim, To continue with the thread below, we shut-in Dotty Varden Welt D-15RD2 on 4 j4 j08 and ran a temp survey on 4/5j08. A pdf fete of the graphical results of the survey is attached (MD and TYD). During the 34 day injection period, the rate ranged between about 550 and 800 BWPD with 2775 - 2850 psi tubing pressure. Our interpretation of the survey is that it has no anomalies and all the injected water is going in to the G-tone and Hemlock pertorations as i# should. If you concur, we'd like to get permission from you to resume and continue to inject into the D-15RD2 while we process the request for an Admin ~pprovat on this well. Thanx, Hal From: Martin, J. Hal Sent: Wednesday, March 19, 2008 12:12 PM To: 'Regg, James 6 (DOA)' Cc: Greenstein, Larry P; Brown, Glynn B; Fahnholz, Norman E; Lee, John R Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing J casing communication We started on Marcft 1~. 4/8/2008 • Page 2 of 5 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, March 19, 2008 11:46 AM To: Martin, J. Hal Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication Thank you for the update. When was injection commenced? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Tuesday, March 04, 2008 1:29 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Greenstein, Larry P; Cole, David A Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication 'im, This is a note to inform you that unless you have an objection, we are now beginning the 45 day injection period I asked for at the end of Last year for Dolly Well D-15RD2. INy understanding for the 2 month delay to restart injection on D-15RD2 is because of the Chevron internal process/time needed to set up the annulus monitoring system/alarm in the event it's needed and install metering for the well. In about 30 days we should be shutting the well in to run a temp survey. We'll keep you posted if anything comes up beforehand. Thanx, Hal Fro egg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: W ,December 26, 2007 3:38 PM To: Martin, J. Hal Cc: Maunder, Thomas E • Greenstein, Larry P Subject: RE: TBU Dolly 15RD2 00050) tubing / casing c unication You are approved to place TBU D-15RD2 on inje ~ r up to 45 days in preparation of a temperature survey. Any anomalous injection pressures or rates mus co icated to the Commission immediately and the well shut in. The sundry application is not req ~ to perform this work, which is a precurs Chevron's decision about requesting an administrative royal under AIO 5 for sustained injection in TBU D- 2. Any active pressur anagement must be documented and reported to the Commission on them TIO pressure repo ontact me if you have any questions. Jim AOGCC 4/8/2008 Page 1 of 4 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, December 26, 2007 3:38 PM ~~~ ~ Izl~~(% To: Martin, J. Hal Cc: Maunder, Thomas E (DOA); 'Greenstein, Larry P' Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication You are approved to place TBU D-15RD2 on injection for up to 45 days in preparation of a temperature survey. Any anomalous injection pressures or rates must be communicated to the Commission immediately and the well shut in. The sundry application is not required to perform this work, which is a precursor to Chevron's decision about requesting an administrative approval under AIO 5 for sustained injection in TBU D-15RD2. Any active pressure management must be documented and reported to the Commission on the monthly TIO pressure report. Contact me if you have any questions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Maunder, Thomas E (DOA) Sent: Sunday, December 23, 2007 8:25 AM To: Regg, James B (DOA) Subject: FW: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication There is a sundry in my "stack" regarding this well. It appears that they had the intital temp survey, but did not get to do the follow-up. As I read it they want to re-start. 1 think that is appropriate. If you concur, then we can let Hal know. I am uncertain if they really need a sundry to do this. Tom From: Martin, J. Hal [mailto:HaLMartin@chevron.com] ~ti~;~ "t s ,~~~5- {z,~<.c~ rte/ ~ Sent: Wed 12/19/2007 4:55 PM To: Maunder, Thomas E (DOA) ~`~~ir,5 "'~~~ ~S¢ ~~~~~~~ Cc: Greenstein, Larry P; Lee, John R; Fahnholz, Norman E ~>~ ~'''~~` T ~ ~~~`~"~~~ Subject: RE: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication `~' ~ `1~r~~ ~~~~'~ G1G~-:t~t.~rl ~{~pru'C~ Tom, --7 ~1~ ~ ~2~~ ~ .1s~'c.~tta-, t arum elo is an old com unication thread that I want to pick u gain on Dolly harden ell - 5R 2. The request I have from you is: ith the attached 41?3, will you allow us to resume i€ejection in preparation for aollow-up temp survey after about 3t7 days? i gave also irtcleaded a schematic and the letter to accompany the 4013. ow for some discussion concerning this well, which is essentially repeated in the attached letter. s discussed below, ®-15FtD2 (apparent, but not actually expected tbg-csg communication issue) ha abase line temp survey run and was returned to injection for a few days, but was shut-in due to the lack of injection when limiting the injection pressure to 230A psi. The follow 12/26/2007 Page 2 of 4 up temp survey was there#oot done. During this time the N~Allowabie Sur#ace d3perating Pressure spreadsheet program #unctionality broke down and we weren't able to evaluate the allowable pressures as quickly. Two things have happened recently. 1) a now haue the spreadsheet program above working at probably 5+Q1o (just some cosmetic su## to work thru) 2) I took the time to dig in the well #iles to con#irm the casing wt and grade and did a little con#irmation #iguring. The answer is that the 7" injection casing should be able to withstand at least 3250 psi, although a are currently sur#ace piping limited to 2900 psi. I would like to attempt to restore injection in this wail using the 2900 psi as a max surface pressure. I# the well will take #luid, I would like to do so far about 30 days and then run a temp survey to con#irm 7" integrity and resume full time injection while applying #or Admin Approval. Let me kno what you think. Than, Hal Fro :Lambert, Steve A Sent: iday, March 23, 2007 8:52 AM To: Tho s Maunder' Cc: Martin, Hal Subject: RE: U Dolly 15RD2 (PN 1800050) tubing /casing communication From: Thomas Maunder [mai :tom maunder@admin.state.ak.us] Sent: Friday, March 23, 2007 8: AM To: Lambert, Steve A Cc: Dolan, Jeff J; Jim Regg Subject: Re: TBU Dolly 15RD2 (PN 180 0) tubing /casing coq~r Steve, Back in the message trail, you mentioned of r Would you please send us an electronic copy. Call or message with any questions. Tom Maunder, PE / AOGCC Thomas Maunder wrote, On 3/20007 1:41 PM: nication )~ -~~~ c. the baseline temperature survey on this well. Steve, It is acceptable to place D-SRD2 back in service. Please add it to e monthly pressure/rate report. As discussed, we hav eceived a sundry essentially seeking approval for at you have sent in this message. We will treat your tter as a request for administrative approval. Until the 2 temperature survey is available, daily monitori of the rate and pressure should confirm the casing integrity. It ould be expected that at similar rate at the injection pressure would be the same as previously experienc If the prior rate/pressure relations 'p is not apparent, the well should be immediately SI so that further diagnos 'cs can be performed. Call message with any questions. Tgrh Maunder, PE 12/26/2007 t ` ~ l~ --005 ~ >~ISi~ kf3 C~fk3.EIIL@i SZ33I~fAITC Caq~leted 9-2i-~62 9-518". 407, 43.5+3, A7A 180 csg-- ~7 ty~ rrF'r tb0 G~" ASL x 4~" ASI. " 7 , 2914, N-80 Kitt csg 5717 tap of 7" liner (battcm of tie-6aciJ 5995 3-518" csg shoe '~'~~(~/h°~ p ; s7~Ps DIL Mtaam~a..~~ Otis 7" x 4" WD pkr v/8' SS eat. -~ 9102 Otis locator and seal assaeblr "`-" ' 9FF9 3s," Otis x-Hippie X2.75 ID} ^ k 91St 3f"' full ~vt mrle shoe ~7rnP ?erforatiors fi-2 9253 - 9Z7Z 5--3 4284 - 9300 G~i 9322 - 9352 Otis 7" x G" WO pkr 9470 34" Otis x-nipple C2.75'ID) 9485 . cell Cuide 9496 block I?erforatians .. F3-i 9676 - 9700 B-3 9815 - 98~g >~+ 9890 - 9495 }'r5 10030 - 10118 l' ~ ~ ` r l u _ ~ ',,_ C 1' ' < Fill @ I009I' 8186 ~ '~ ~ ~ T '+~ i03B0 7 " liner s hoe ~( `` ~^ ,~ ~" r~,~ L~ I Z~~ f'r ~~ r 47i~~Ps~ !~'C L9 G~'<2rrr~ r~vC~ .3'/1~~~ w~aa M! Pressure -~ N W ? CT O O O O v W A O O O O O 8/31 /07 I 9/03/07 ' ~ ~ ~ 9/06/07 ', j ~ ~ __ -- - ,I 9/09/07 ~ ~ I ~ I I I I 9/12/07 I ! ~ o ~ w v+ ~! . w w 9/15/07 I ~ ~ ~i 0D - cn _ 9/18/07 ~ i ~ I ~ j i w 9/21 /07 I ~ ~ rb , ~ ~ 9/24/07 i ~ j ~ , .r z ~ 9/27/07 ~ ~ . 9/30/07 ~ I ~ ~ a, v' s ~ ~ ~ 10/03/07 ~ I j '~ ~ 10!06/07 ~ I ~ b ~. 10/09/07 ~ 10112/0? I ~ i ~ ~ 10x15/07. ! F ~' ' ~ 10/18/0'7 ~ ! I ~ "'°' 'I 0121 J07 ~ a ~ 10/24/07 ~ I i C r C j ~ I rD 10/27/U7 ~ ~ ~ ~ C ~ I 10/30/07 ' ~ ~-+ 11/02/U7 ' , I ~ ~ , 11/05/07 I +`~ ~ ~ ~ 11 /08/07 i a i 1 i /11 /07 I 11'14!07 i j 1 'i 117/07 11 /20/07 11 /23/07 ~ ~ ~ ~ 11 /26/C7 ' ~ i ~ I ' 11 /29/07 i i I' ~ I ° ~ o 0 o Rye o 0 N 0 0 0 • 1 v c. ~. ~ Li G `~ ~ ~ ~~ • Chevron Oil Co. Well: D-15RD2 Field: Dolly Varden 03-17-2007 Pressure (psia) 1200 1700 2200 2700 3200 3700 4200 4700 5200 5700 0 1000 2000 3000 4000 .-. ... ~ 5000 L >~ d 6000 7000 8000 9000 10000 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 Temperature (Deg. F) Pressure - Perfs 13-3/8" 9-5/8" 7" - --TBG Temperature - - - - - Report date: 12/24/2007 • Let me~kaLw what you think. Thanx, FIaE • Page 4 From: Lambert, Steve A Sent: Friday, March 23, 2007 8:52 AM To: Thomas Maunder' Cc: Martin, J. Hal Subject: RE: TBU Dolly 2 (PN 1800050) tubing /casing communication From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 23, 2007 8:38 AM To: Lambert, Steve A Cc: Dolan, Jeff J; Jim Regg Subject: Re: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication Steve, Back in the message trail, you mentioned of having obtained the baseline temperature survey on this well. Would you please send us an electronic copy. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 3/20/2007 1:41 PM: Steve, It is acceptable to place 'TBU D-SRD2 back in service. Please add it to the monthly pressure/rate report. As discussed, we have received a sundry essentially seeking approval for what you have sent in this message. We will treat your letter as a request for administrative approval. Until the 2nd temperature survey is available, daily monitoring of the rate and pressure should confirm the casing integrity. It would be expected that at similar rates that the injection pressure would be the same as previously experienced. If the prior rate/pressure relationship is not apparent, the well should be immediately SI so that further diagnostics can be performed. Call or message with any questions. Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 3/20/2007 1:34 PM: Tom, the rate spike in well D-15RD2 appears to have been a data entry error. Well D-15RD2 was shut-in for 2 days prior to March 12, when the tbg-csg communication became apparent. The pressure gauges have been checked and the tubing and casing pressures are tracking. The wellhead has been inspected and there does not appear to be communication thru the wellhead. A baseline temperature survey was run on Saturday March 17. There were no temperature anomalies noted on the log. Chevron proposes to return well D-15 to injection for the purpose of confirming that there is in fact wellbore integrity. Following a 30 day injection period, a static temperature survey will be run to verify that all injec#ed fluids are exiting the wellbore at the perforations. if the temperature survey confirms wellbore integrity, Chevron would propose to continue injection into the well under an administrative approval for long term injection. 4/8/2008 • Page 5 of 5 From: Thomas Maunder [mailto:tom maunde_rOa adminstate.ak.us] Sent: Monday, March 19, 2007 11:26 AM To: Dolan, Jeff J Cc: Martin, J. Hal; Jim Regg Subject: Re: TBU Dolly 15RD2 (PN 1800050) tubing /casing communication Jeff, I have received a sundry to allow this well to return to service. Looking at the rate/pressure information you sent, I note there is a large rate value on February 14. There is not pressure change indicated. Is the rate spike in error? Also, it appears there was an injection SD immediately prior to noting the communication. Can you confirm and offer any comments? Thanks in advance, Tom Maunder, PE AOGCC Dolan, Jeff J wrote, On 3/14/2007 9:01 AM: Tom, Jim; During a routine walk around yesterday, March 13th 2007, the water injection well D-15RD2, Permit Number 1800050, "A" annulus (tubing by 7") was observed to have high pressure. The well was immediately shut in. I have enclosed the last 90 days of pressure observations. «D-15RD2 Pressure Data 2007 03 13.x1s» 7eff Dolan Engineering Technical Support MidContinent/Alaska Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7807 Fax 907 263 7847 dolanjj~chevran.cam 4/8/2008 SARAH PALIN, GOVERNOR A1tASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Lambert Advising Reservoir Engineer Chevron North America P.O. Box 196247 Anchorage, AK 99519-6247 ~~Ne) MAR 2 8 2007 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pools TBU D-15RD2 PTD: 180-005 Sundry: 307-094 Dear Mr. Lambert: I am returning herewith the unapproved Application for Sundry Approval relating to the above referenced well. Submitting a sundry application with regard to resuming/ continuing injection into a well with pressure communication is not the proper procedure. Approval to keep TBU D-15RD2 in service to conduct diagnostic testing has been given in response to your electronic message of March 20, 2007. This approval was granted following initial well equipment assessment that indicated no surface leaks and competent production casing based on the available pressure record. When the additional diagnostic information has been gathered, Chevron should submit the information to the Commission with a request for an administrative approval under Area Injection Order (AIO) 5. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A per on may not appeal a Commission decision to Superior Court unless rehe '. g h s been requested. DATED thisM::ay of March 2007 Encl. Chevron Steve Lambert Reservoir Engineer MidContinent/Alaska Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7658 Fax 907 263 7847 Email salambert@chevron.com 4~,+~~ Y C Mai z s zoo? i~si~~ ;.iii ~~ Cas Cons. Commission March 15, 2007 Anchorage Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 ~~N~N~~~ App 0 9 2D0~ RETURN TO INJECTION DOLLY VARDEN PLATFORM WELL NO. 15RD2 MCARTHUR RIVER FIELD ~~~ ~~~ Dear Tom: Union Oil Company of California is proposing to return well D-15RD2 to injection. Enclosed is form 10-403. Well D-15RD2 experienced pressure on the tubing casing annulus and was shut-in on March 14. The well is a critical component of the efforts to maintain productivity and improve recovery from the Tyonek G and Hemlock reservoirs. i It is planned to inspect the wellhead to confirm that there is no communication. Assuming that the wellhead is found to have integrity, following is the proposed procedure for bringing this well back on injection. 1) Run baseline temperature survey. 2) Obtain permission to inject. 3) Inject until the well has stabilized (approximately 1 month). 4) Follow-up temperature survey. 5) Obtain variance to inject. 6) Monitor well daily and repeat temperature surveys every two years. Please let me know if you require additional information. Sincerely, Steve Lambert Enclosure MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECE\VED MAR 1 6 2007 Abandon 0 Alter casing 0 Change approved program [2] 2. Operator Name: Union Oil Company of California 3. Address: Suspend 0 Repair well 0 Pull Tubing 0 1. Type of Request: P.O. Box 196247 Anchorage, Alaska 99519 n Perforate 0 A'8SKr8~as t;ons. 'Utner U Stimulate 0 Time Extension []ilichorage Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 80-05' Service [2] 6. API Number: fl)'7J'I' z.ø¡~.ð ~ 50-733-~2' ß 5.",·1>7 8. Well Name and Number: Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 D-15RD2 . 9. Property Designation: ~ dÞ . ~ 10. KB Elevation (ft): 11. Field/Pool(s): .iJlk-/(~ 4/1fucI-e/c.. Trading Bay Unit ADl.J.?5"94 liJ1 ..' ~..¡.\1 þ 106' above MSL McArthur River Field, T :.: emlock ib 12. PRESENT WELL CONDITION SUMMARY ,. ,. R.,ø'1 Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): IJUnk (measured): 10,400' 10,229" I 10,195' 10,029' 110,276'"10,400' Casing Length Size MD TVD Burst Structural 31/2" \ Packers and S~ V MD (ft): Packer @ 9.)61 / "hol IIIl<ill ~JÆoss after proposed work: ( /' ~\tQ 0 AI / Development Ï' 16. ~~ us a~r~rroposed work: 3/19/2007 "'-- Commencing Operations: 0/ ~ V" 0 Plugged 17. Verbal Approval: Date: WA~ ~¿/' GINJ 0 WINJ Commission Representative: / \ ~ ~.{ 18. I hereby certify that the foregoing is true and correct to the best o~nowl~~, " Contact Printed Na~ .Steve La~ert " Title p¡loleum Engineer Signature ) "" -ði: ~ ~ ~hone 263-7658 Date '--" V''' >-~ COMMISSION USE ONLY Conductor Surface Intermediate 2,500 133/8" J-55,61# Production 6,003 9 5/8" N-80, 40#, 43.5#,47# 4,643 7" N-80, 29#, uttress Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): \ Tubi g 9676-9700, 9890-9995, 9815- 9510-9534, 9648-9729, ,972l 9856,10030-10118 9827,9860-9948 , Packers and SSSV Type: I" Otis 7" x 4" WD Packer , 13. Attachments: Description Summary of Proposal [2] Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Collapse 2,500 2,434 6,003 5,873 ^ \ / 10,380 9,955 ize Tubing Grade: 1,540 3,090 5,750 3,090 8,160 7,020 9.2# N-80 Tubing MD (ft): 9151' \ o Service [2] o Abandoned [2] . WDSPL o o 3/15/2007 Conditions of approval: Notify Commission so that a representative may witness SUndry Number: ,~r¡ ~ 0 q ~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent Form Required: R8DMS BFl MAR 2 8 2007 Approved by: . _ . 1\ I COMMISSIONER Form 10-403 Revised 06/20060 K \ b \ \\\ I.J... L APPROVED BY THE COMMISSION Date: A11lI# ~.LSubmit~,:£,icate ~ ,."..-, -c to? ~- 3''-''Þ7 TBU Dolly 15RD2 (PN 1800050) tubing I casing communication . . Tom, Jim; During a routine walk around yesterday, March 13th 2007, the water injection well D-15RD2, Permit Number 1800050, "An annulus (tubing by 7") was observed to have high pressure. The well was immediately shut in. / I have enclosed the last 90 days of pressure observations. «D-15RD2 Pressure Data 2007 03 13.xls» Jeff Dolan Engineering Technical Support MidContinent/Alaska Chevron North America Exploration and Production 909 West 9th Avenue ... Anchorage, AK 99501-3322 Tel 907 263 7807 Fax 907 263 7847 sCANNED MAR 2 '7 2007 dolanjj@chevron.com C D·· D-15RD2 Pressure Data 2007 03 ontent- escnptlOn: 13.xls D-15RD2 Pressure Data 2007 03 13.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 1 of 1 3/19120072:53 PM Hours 3000 7" 5/8" 33/8" 2500 Rate 2000 ( , ... ::::¡ !Ii !Ii ~ n.. 1000 500 500 11/29/06 on 3/1 1 1000 7107 02127/07 Time at 2:52 Prism Chart MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg y/> 01 '7) P.I. supervisorJY1i I I '::J Q4- DATE: Monday, September 13,2004 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA FROM: Chuck Scheve Petroleum Inspector D-I5RD2 TRADING BAY UNIT D-15RD2 Src: Inspector Reviewed By: P.I. Suprv 1ßL Comm NON-CONFIDENTIAL Well Name: TRADING BAY UNIT D-15RD2 API Well Number: 50-733-20159-02-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40908 I 64608 Permit Number: 180-005-0 Inspection Date: 9/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-I5RD2 Type Inj. s TVD 8929 IA 20 2300 2300 2300 P.T. 1800050 TypeTest SPT Test psi 2232.25 OA 20 240 240 240 Interval 4YRTST P/F p Tubing 2800 2800 2800 2800 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Monday, September 13,2004 Page I of I Schlumberger PL Advisor Injection Profile Memory PLT w! FIoView Company : Field : Well · Date Logged : Date Processed : Reference Number: APl Number : Log Analyst : Union Oil Company of California McArthur River Trading Bay Unit D-15 (~b~ 17-Mar-2002 03-April-2002 22146 R. Heath Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 (907) 273-1700 foil ~nterpretat;ons are op~mons based on inferences from electncal or other measurements and we cannot, and do not guarantee the accuracy or correctness of any ~nterpretat~ons and e shall not, except ~n the case of gross or wdlful neghgence on our part, be hable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone result;ng m any interpretation made by any of our officers, agents or employees These interpretations are also subJect to clause 4 of our general terms and conditions as set out m our current ~ce ~¢hedu e Union Oil of California Job Number 22146 Well D-15 Field McArthur River 1. Logging Objectives The objective of this logging suite was to determine the water injection profile into each set of perforations in both the G-Zones and the Hemlock Benches. 2. Main Results Table 1 Interpreted Surface Results Zone Depth ~]ater From To Surface % Ft Ft STBPD G-2 9258 9272 -10.95 1.1% G-3 9284 9300 -0.62 0.1% G-4 9322 9352 -117.61 11.7% HB-1 9676 9700 -79.65 8.0% HB-3 9815 9856 -650.36 64.9% HB-4 9890 9995 -4.86 0.5% HB-5 10030 10118 -137.56 13.7% Total -1001.6 3. Injection Log Interpretation Union 0il Company of California (UNOCAL) well, Trading Bay Unit (TBU) D-15 is an injection well located in the McArthur River field of Cook Inlet, Alaska. No well deviation information was supplied for this analysis. Well D-15 was logged with the PLT Memory production logging tools consisting of gamma ray, temperature, pressure, gradiomanometer, PFCS 3.5" fullbore spinner, and FIoView (DEFT). The tools were conveyed on slick line, using memory-logging techniques. The downhole temperature and pressure at 9,250 feet are 84.7 degrees F. and 8037 PSI. The injection profile obtained indicates the majority of the water (65%) is being injected into the Hemlock Bench 3 perfs. The injection rate quantified by the spinners was approximately 1000 BPD, although no actual injection rate was available for comparison. Note: the logger did not obtain passes entirely across HB-5 and the rate calculated above this zone is assumed to be entering into any available perfs below 10,030 feet. Union Oil of California Well D-15 Job Number 22146 Field McArthur River 3.1. Injection Profile Caliper 1 Temperature 94 ( in ) 8 84 ( degF ) Caliper 2 Pressure ( in ) 8 7980 ( ps~ ) 8400 ~ Fullbore Spinner D-15 Well,Sketch (g ~50 Union Oil of California Well D-15 Job Number 22146 Field McArthur River 3.2. Data Editing : t 50( Union Oil of California Job Number 22146 Well D-15 Field McArthur River 3.3. Stable Intervals Table 3 contains the average production log readings for the stable intervals between perforations. Table 3 Stable Interval Values Depth Temperature Pressure Fluid Density Fluid Velocity (ft) WTEP WPRE WFDE SPIN top (degF) (psi) (g/cra3) (fi/rain) bottom 9220.0 84,6 8010.3 9250.0 84.7 8022.4 1.173 -20.7 9273.0 84.7 8032.4 9283.0 84.7 8037.5 1.173 -20.4 9301.0 84.7 8046.6 9321.0 84.7 8056.9 1.173 -20.5 9390.(: 84.9 8089.3 9400.C 84.9 8093.7 1.173 -17.9 9752.(: 86.4 8248.2 9762.(: 86.4 8250.1 1.174 -16.3 9882.2 87,1 8302.5 9888.2 87.2 8305.2 1.174 -3.2 10000.0 90.9 8358.4 10020.0 91.5 8368.6 1.175 -3.5 Union Oil of California Welt D- 15 Job Number 22146 Field McArthur River 3.4. Spinner Calibration 9220,0 - 9250.0 ft -- ~73.0 - 9283.0 ft -- 9301.0 - 9321.0 ft 9630.0 - 9670.0 ft 9701.0 -9814.0ft ._ 9857.0 - 9889.0 ft 9996.0 - 10029.0 it -100. 0 -1 100.0 cable speed - ~rr SPlNvs OYEL Union Oil of California Job Number 22146 Well D-15 Field McArthur River 3.5, Fluid PVT Production Data Fluid PVT Properties IFluid Type Water Cut (%) Liquid 1.00 Oil APl Gravity (dAPI) 32.00 Standard Conditions Gas Gravity 0.68 Water Salinity (ppm) 10000.00 Bubble Point Pressure (psi) 14,70 Solution GOR (ft3/bbl) 0.00 Bubble Point Bo (bbl/bbl) Oil Density (g/cm3) Bo (bbl/bbl) Bw (bbl/bbl) 0.98 l/Bg (ft3/bbl) 2205.07 Oil Density (g/cra3) Water Density (g/cm3) 1.03 Reservoir Conditions Gas Density (g/cm3) 0.38 Oil Viscosity (cP) Water Viscosity (cP) 0.81 Gas Viscosity (cP) 0.05 Solution GOR ( ) 0.00 Correlations Standing Beggs-Robinson Meehan Standing Union Oil of California Job Number 22146 Well D-15 Field McArthur River 3,6. BorFIow Interpreted Results Surface Cumulative Rates Gas From Gas from Gas (1000 Oil (1000 Water (1000 Water Cut (%) Formation Stable interval (ft) Oil (bbl/d) Water (bbl/d) ft3/d) [t3/d) rt3/d) G-2 9220.00 - 9250.00 0 -1001.62 0 £ 0 10(; G-3 9273 00 - 9283.00 0 -990.67 0 0! 0 10(; G-4 9301 00 - 9321.00 0 -990.04 0 0 0 10(; HB-1 9390.00 - 9400.00 0 -872.44 0 0 0 10(: HB-3 9752.00 - 9762.00 0 -792.78 0 0 0 10(; HB-4 9882.18 - 9888.16 0 -142.42 0 0 0 10(: HB-5 10000.00- 10020.00 0 -137.56 0 0 0 10(: GeoQueat 6OO W. i~1Airpod Road Anehomg®, AK 99618-1199 ATTN: Sheni® NO. 8923 C~mpany: I I Alcmka Oil & Gc~ Cons Oomm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/12/94 Held: Pmdhoe Bay Well Log Desoription BL RR Sepia RF Sepia Mylar q ~" [ ~ D.S. 1-6 PROD PROFILE (8-20-94) . 1' 1 ~,~- c>-~ D.S. 2.13 PERF RECORD (8-21-94) I 1 ?s'-?_~ D.$. 3- I PROD PROFILE (8-19-94) I 1 -- ~7_~T D.S. 4-4 PROD PROFILE (8-25-94) 1 1 · ~'3 -/~'CD.$. 4.5A PROD PROFILE (8-19-94) 1 1 ? ~'~-'~ D.S. 4-29 IN,lEO PROFILE (8-19-94) 1 1 ~e-?~ D.S. 6-10 PROD PROFILE (8-20-94) I 1 26 -~ D.S. 6-15 PERF RECORD (8-20-94) 1 1 .~y--'Sr~ D.S. 9-26 LEAK DETECTION (8-23-94) 1 1 c/.~ _4oa,~D.S. 11-24A DUAL BURST TDT-P (8-19-94) 1 1 ~V- c/.~ D.S. 11.33 DUAL BURST TDT-P (8-25-94) I 1 ,,, ~. r ~' I ~ ~-~// D.S. 12.3 PERF RECORD (8-22-94) 1 1 ~ '_ ~, ~ ! ~/ 9/-J[¥ D.$. 14-15 PERF RECORD (8-20-94) I I _ -~-/' ? b~D.S. 14-20 PROD PROFILE (8-24-94) 1 1 S '_P ~) ~' 1' Alnekn fiji~ Gas Cons, --, )94 commission Anchorage SI~NED: ~~,f.,,f~ /~~ DATE: Please ~ign and retum py of this transrnittal to Sherrle at the above address. Thank you. ALASKA OIL AND GAS CONSERVATION COMMISSION a~'~'~ k APPLICATION FOR SUNDRY APPROVALS_ 1 TvDe of Request A. banaon ~ Susper,:l __ Alter ~s, ng ~ Repair we~l w Cnange aDprovecl program __ Pull tulmng ~ Vanance ~ 2 Name of Operator J 5 TyPe o! Well UNOCAL (Harathon 0il Company- Sub ~0perat~en,_ Exploratory __ 3 Address .J Strat~grapn,c_ P.O. BOX ].90247 Anchorage, AK 995]{9 Serv,ce.l. , Ooerat~on shutd(:wvn ~ Re-enter susl:agf~:led w~HI ~ v Plug~ng ~ 'lime extension ~ Stimulate A Perforate __ Other 4 Locat, on of wetl at surface Leg A-2, Cond. 10 Dolly 754' FSL, 1,130' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,897' FSL, 737' FWL, Sec. 6-SN-].3W-SM At effective depth 1,965' FSL, 846' FWL, Sec. 6-8N-].3W-SM Attotq~,§~§~d ' FSL, 868' FWL, Sec. 6-8N-13W-SM Varden Platform 6. Datum elevation (DF or KB) 106' KB above MSL 7. Umt or Property name Tradi Unit 8 Well number D-15RD2 9 Permit number 80-05 10 APl number_ 5oL73'3-:20159-02 llMFc'~II~/~I~[C River Field feet 12 Present well condmon summary Total depth measured true vertical E ffectwe depth measured true vertical 10,400' feet 10,229' feet 10,195' feet 10,029' feet Plugs (measurea) Junk(measure(I) 10,276' - 10,400' CMT None Casmg Length Structural Conductor Sudace 2,500' Intermediate 6,003 ' Production 4,643' Dner Perforation depth measured true vertical Size 13 3/8" 9 5/8" Cemented 11 2,300 sx 3,450 sx 1,575 sx See Attachment #1 Measured depth True vemcal depth 2,500' 6,003' 10,380' 2,434' 5,873' 9,955' RECEIVED Tubing (size, grade ana measured depth) 3 1/2", 9.2#, N-80 BTC tbg PacKers and SSSV (type and measured depth) 9,151' Descnpl]on summary of proposal DEC - 7 Alaska 0il & Gas Cons. CommiSstOr~ Anchorage Detaled operations program BOP sketch 14 l~st~mated date for commencing operation 15. Status of well classification as. tt/zs/gz .. 16 If proposal was verbally approved O~1 __ Name of approver Date approved Serwce 17 I hereDy certify that the foregoing is true and correct to the best of my knowledg~ Conditions of appro~l: Not,~'~ Comm,sslon so representative may witness Plug integrity ~ BOP Test ~ I..ocaaon clearance ~ Mechamcal Integnty Test ~ Subsequent form required 10- ~ O y Gas __ Suspended Water Injection Approved by order of the Commmaon Form 10403 Rev 06/15/88 URlijiNAL SIGNED BY qUSSELL A. DOUGLA~ Attachment #1 TBU D-15RD2 Perforations G-2 G-3 G-4 B-1 B-3 B-4 B-5 ZONE MD {DIL), 9258' -9272' 9284'-9300' 9322'-9352' 9676'-9700' 9815'-9856' 9890'-9995' 10,030'-10,118' TVD 9097'-9111' 9123'-9139' 9160' -9190' 9511'-9534' 9650' -9690' 9722'-9826' 9861' - 9948' RECEIVED Alaska Od & Gas Oons, Anchoraga WELL D-15RD2 PROCEDURE Acidize Water Injection Well · · · Hold safety/operational meeting with pumping service company. MSDS. Review SI injection to well. Monitor SITP. RU pumping equipment on wellhead. Pressure test lines to 4000 psi. Pump treatment as follows: a) b) c) d) e) f) g) h) i) J) Pump 1200 gallons (28 bbls) 12-1/2~ Sodium Hypochlorite at 1-2 BPM or 3800 psi max. Add 1/2 #/gal Benzoic acid flakes (TLC-80) diverter to the Sodium Hypochlorite (continuous). Displace Sodium Hypochlorite with 107 bbls FIW. Allow fluid to heat up for 12 hours. Pump on additional 5 bbls every 4 hours during the 12-hour heatup period to agitate the treatment. Pump 2000 gallons 15~ HCl w/ 2 gal/lO00 gal HAI-85M, 20 lbs/lO00 gal Ferchek A and 2 gal/lO00 gal Losurf 300 additives at 1-2 BPM or maximum 3800 psi. Pump 10 bbl diverter pill w/ 500 #'s Benzoic acid flakes and 1 gal/lO00 gal Losurf 300 mixed in FIW. Pump 2000 gallons 15~ HCl w/ additives. Pump 10 bbl diverter pill. Pump 2000 gallons 15~ HCl w/ additives. Displace treatment w/ 110 bbls FIW with 6 gal/lO00 gal Cla-Sta added. RD Halliburton lines. Return well to injection immediately. H: \wp\WLPRO\D 15RD2 RECEIVED o EC - ? !B92 Alaska, O~l & Gas Cons. Commission Anchorage 7", 29//, 11-80, bull csg, Dl L Measuremenls Oils 7" x ,l" WU pkr w/ O' SB exl. G-Zone Perforations G-2 9258-9272 G-3 9204-9300 G-4 9322-9352 Oils 7" x 4" WO pkr 3-I/2" Oils x-n~pple (2.75"1D) Bell Guide Ilemlock Perforallons B-I 9676-9700 B-3 9815-9845 8-4 9890-9995--- B-5 10030-10118 9090 9470 9485 9496 D-15R02 IlO COHPLETION SCIIEHATIC CompleEed 9-21-8Z CIW Ivpe "r" 'bg hgr. ,1-1/2" ASL x ,1-1/2" ^SL. .-3-1/2", 9 211, ll-OO, B[C 5737 lop of 7" liner (botlom of lie-back) 5994 9-5/8" csg shoe 910Z Oils Iocalor and seal assembl~ .. 9119 3-1/2" Oils x-nipple (2.75"10; 9151 3-1/2" tull cul mule shoe Avg Dev=8.5° -F$11 @ 10,190 WLH 5-87 10,195 PBID 1~.10,~80 7" liner shoe WEC 9/87 STATE OF ALASKA f ALASKA OIL AND GAS CONSERVATION COMMISSION 10Deral, ons performed Pull ruling ~ Alter ca. rig __. Rel3~r ~ ._.. 2 Name of Operator / 5 Type of Well UNOCAL (Marathon 0il Company - Sub qperato~~_ ' , / 3 AClapreS~ J S~raagrapn,c 4 LocaU°n~wa~atsurface Leg A-2, Cond. 10 Dolly Varden Platform 754' FSL, 1,130' FWL, Sec. 6-SN-13W-SM At top of proOuctwe tnterval 1,897' FSL, 737' FWL, Sec. 6-SN-13W-SI'4 At efiecttve deptn 1,965' FSL, 846' FWL, Sec. §-SN-13W-SN At total depth 1:968' FSL. 868' FWL. 12 Present well condmon summary Total depth measured true vertical Effec[,ve depth measured true vertical REPOFrr OF SUNDRY WELL OPEFIATIONS Ooeram3n snutOown __ SarraJate ~ Plugg~ ~ P~'rlorate .._. Sec. 6-8N-13W-SM feet 10,400' feet 10,229' feet feet Size Plugs (measured) Junk fmeasured) Cemented CasLn_g Structural 10,195' 10,029' Length Ot{IGINAi. 7. Umt or Property name Trading Bay Unit 8. Well numDer D- 15RD2 9 Permit number/approval numDer 80-05 lO APl number 5o-- 733-20159-02 11 Field/Pool feet 10,276' - 10,400' CMT None Measured depth True vertical depth Conductor Surface IntermeO~ate 2,500 ' Procluct~on 6,003 ' Liner 3 I Pedorauon depm mea~u~'~oq' 13 3/8" 9 5/8" 11 2,300 sx 3,450 sx 1,575 sx 2,500' 6,003' 10,380' 2,434' 5,873' 9,955' true vertical See Attachment #1 TuO~ng {s~ze, grade, and measured depth) 3 1/2", 9.2#, N-80 BTC tbg La 9,151' PacKers and SSSV (type and measured depth) (lti~ 7" ~ 4" WD Pkr. La 9,470' - Otis 13. SUmulatlon or cement squeeze summary 14 7" x 4" WD Pkr. w/8' SB ext La 9 090' RECEIVt:U Intervals treated (measured) Treatment aescnptlon including volumes used and final pressure Pnor to welt oDeratlon DEC 2 ?- 1992 A{m.qka 0ii & Gas Oons. ReoresentaUve Dally Average Proclucaon or lnjecuon Data Anchorage Od-Bbl Gas-Md Water-Bbl Casing Pressure Tui::,ng Pressure 1555 3975 Subseauent to operation 2182 i5. Atta~nts 16 Status of welt c~ass~flcatlon as Col~es of Logs and Surveys run ~ Da~ly Report of Well Operauons X O~1 __. Gas ~ Suspended '17 I hereby cer~'lfy that the foregoing is true and correct to the best pt my knowledge ,1 Form 10'404 Rev 0~5~' ' ' ' 3 4000 Sennce Water Injection Date t21Zo[c~._. SUBMIT IN DUPLICATE Attachment #1 TBU D-15RD2 Perforations ZONE G-2 G-3 G-4 B-1 B-3 B-4 B-5 MD (DIL) 9,258'-9,272' 9,284' -9,300' 9,322'-9,352' 9,676'-9,700' 9,815'-9,856' 9,890'-9,995' 10,030'-10,118' TVD 9,097'-9,111' 9,123'-9,139' 9,160'-9,190' 9,511 '-9,534' 9,650'-9,690' 9,722'-9,826' 9,861 '-9,948' RECEIVED DEC ~: 2 1992 Alaska Oil & Gas Cons. (5ommiss~O~ Anchora~le DA1~LY NELL OPERATIONS D- ! 5R02 11/26/92 RU chicksan to wellhead. Psi test 1Jne to 4,000. OK. Open well TP : 3,000. Start pumping 1200 gallons 12-1/24 Sodium Hypochlorite at I BPM, 3800 psi w/ 1/2 ppg Benzoic acid flake diverter. Displace Sodium Hypochlorite w/ 107 bbls FIW. Complete 107 bbl displacement. SI well. Allow Sodium Hypochlorite to soak and heat up. 11/27/92 Pressure test line to 4000 psi. OK. Open well. Start pumping treatment as follows: i BPM, 3800, psi. - 2000 gal 154 HCl - 10 bbl Benzoic acid flakes diverter - 500 lbs. Benzoic acid flakes in 10 bbl FIW - 2000 gal 154 HCl - 10 bbl diverter pill - 2000 gal 154 HC1 Displace treatment w/ 110 bbls FIWw/ 6 gal/lO00 gal clay stabilizer. Final rate 1.18 BPM at 3800 psi. SD pump. Displacement complete. RD. Place well on injection. H: \wp\WE LLOPS\D 15RD2 RECEIVED DEC 2 199 Alaska Oil & Gas Cons. Gomm~ssm~' Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed Operat,on shutdown __ Sbmulate X Pluggmg __ Perforate Pull tul~ng ~ Alter caang ~ Repar well __ 2. Name of Operator ! 5 Type of Well Ioprnent __ UNOCAL (Marathon Oil Companj/ - Sub ~peratO~x;~oratonj~ 3 Address | Strabgraph~c __ P.O. Box ]90247 Anchorage, AK 9951~) Serv, ce_Z_ 4 Locabon of well at surface Leg A-2, Cond. J0 Do]]y Varden Platform 754' FSL, 1,130' FWL, Sec. 6-8N-13W-SM At top of producbve ~nterval 1,897' FSL, 737' FWL, Sec. 6-8N-13W-SM At effecbve depth 1,965' FSL, 846' FWL, Sec. 6-8N-13W-SM Attot~l,d~, FSL, 868' FWL, Sec. 6-SN-13W-SM 12 Present well cond~bon summary Total depth measured ] 0,400 ' feet true vertmcal ] 0,229 ' feet Plugs (measured) Other __ 6. Datum elevabon (DF or KB) 106' KB above MSL 7 Umt or Property name Trad~ .... '_mn, _ 8 Well n~J~rnber'' D- ] 5RD2 9. Permit number/approval number 8-241 10 APl number 5o-733-20159-02 11 Reid/Pool McArthur River Field 10,276' - 10,400' CMT Effecbve depth' measured 10,195 ' feet true vertical 10,029 ' feet Casing Length Structural Conductor Surface 2,500 ' Intermediate 6,003 ' Producbon bner 4,643' Perforabon depth measured true vertical Size 13 3/8" 9 5/8" See Tubng (size. grade, and measured depth) 3 1/2", 9.2#, N;80 BTC tbq@ Packers andSSSV (type ano measured depth) Otis 7" x 4" WD Pkr. @ 9,470' Junk(measured) Cemented 2,300 sx 3,450 sx 1! 1,575 sx Attachment #1 9,151' - Otis 7" x 4" WD Pkr. None Measured depth True vertical depth feet 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment 2,500' 2,434' 6,003' 5,873' 10,380' 9,955' RE£EIVED , ]aska Oil & Gas Cons, C~mmiss;o~; ~chofage w/8' SB ext ¢ 9,090' Treatment descnptlon including volumes used and final pressure 14. #2 "Daily Summary of Operations" Tubing Pressu re Prior to well operation 2/24/89 Subsequent to operatlon 3/1/89 Representative Dady Average Productmon or Injecbon Data OII-Bbl Gas-Md Water-Bbl Cas)ng Pressure 3270 3900 15. Attachment~( 2' Copies of Logs and Surveys run __ Daily Report of Well Operations ~ NA NA 451 NA NA 1701 Service [,Jater Injection 16 Status of well classificabon as: Oil __ Gas __ Suspended __ SUBMIT IN DUPLICATE 17. I hereby cerbfy that the foreg(~ng is true and correct to the best of my knowledge. Form 10-404 ~v 06/15/88 ~ TBU Attachment #1 D-15RD2 Perforations G-2 G-3 G-4 B-1 B-3 B-4 B-5 ZONE MD (DIL) 9258'-9272' 9284' - 9300' 9322' -9352' 9676'-9700' 9815' -9856' 9890' -9995' 10,030'-10,118' TVD 9097'-9111' 9123'-9139' 9160' -9190' 9511'-9534' 9650' -9690' 9722'-9826' 9861' - 9948' ¢ Attachment #2 TBU Wel 1 D- 15RD2 Daily Summary of Operations 2/25/89 RU pumping unit and PT disclarge lines, OK. Pumped acid/bleach treatment as follows' Stage 1st 2nd Volume Rate qals Fluid (BPM) 2000 10% HC1 + additives 0.60 2100 FIW .56 2000 5% NaOC1 + 7% NaOH .80 3360 FIW 1.3- 2.8 4000 10% HC1 + additives 1.12 1050 FIW .93 1210 FIW + 350 lbs NaOH 1.0 Press (_psi) 4OO0 4000 4000 2200-3900 49OO 3900 3900 RD and place will back on injection. Telecopy No. (907) 276-7542 October 27, 1988 D K Corle=t Region Operations Marathon Oil Company P 0 Box 190168 Anchorage, AK 99 Dear Mr Corle=t~ On September 26, 1988 we received the cement bond logs on wells D-6RD, D-15 RD2, D-16RD, D-24A, and D=29RD. Thank you for your prompt help. Sincerely, , Blair E Wondzell Sr Petr Engineer Jo/A.BEW.122 Alaska RegIon Domestic Production Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 September 23, 1988 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Sir: Enclosed are sepia copies of the cement bond logs you requested for Dolly Varden water injection wells D-6RD, D-15RD2, D-16RD, D-24A, and D-29RD. Should you have any questions or require further assistance please contact Mr. Norm Fahnholz at (907) 561-5311. Sincere ly, D. K. Corlett Region Operations Engineer NEF/em/878/0E34 A subsidiary of USX Coroorabon STATE OF ALASKA J, ALA .~ OIL AND GAS CONSERVATION CO .,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend .r-] Operahon Shutdown [] Re-enter suspended well ~ Alter camng ~ T~me extension F; Change approved program [] Plugging [] Shmulate ~ Pull tubing r--] Amend order ~ Perforate [] Other 2 Name of Operator UNOCAL (Marathon Oil - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 4 Locahon of well at surfaceLeg A-2, Cond. 10 Dolly Varden Platfor~z 754' FSL, 1,130' FWL, Sec. 6-SN-13W-SM At top of productwe interval 1,897' FSL, 737' FWL, Sec. 6-SN-13W-SM At effective depth 1,965' FSL, 846' FWL, Sec. 6-SN-13W-SM At total depth 1,968' FSL, 868' FWL, Sec. 6-SN-13W-SM 5 Datum elevahon (DF or KB) 106' KB above MSL feet 6. Umt or Property name 7. Well number D-15RD2 8. ~rmit number 80-05 9. APl number 50-- 733-20159-02 10 Pool McArthur River Field 11 Present well condition summary Total depth' measured true vertical 10,400' feet Plugs (measured) 10,229' feet 10,276' - 10,400' CMT Effective depth measured 10,195 ' true vertical 10,029' feet Junk (measured) None feet Casing Length Size Structural Cemented Measured depth True Vertical depth Conductor Surface 2,500' 13 3/8" Intermediate 6,003' 9 5/8" Production 2,300 sx 2,500' 2,434' 3,450 sx 6,003' 5,873' bner 4,643' Perforation depth, measured true vertical 7" See Attachment #1 1,575 sx 10,380' RECEIV[D M? ' :i A:~sk~, Oil & Gas Cons. C0mmissi0~ Anchorage Otis 7" x 4" WD Pkr. w/8' SB ext @ 9,090' Tubing (size, grade and measured depth) 3 1/2". 9.2#, N-80 BTC tb~ (a 9 151' Packers and BSSV (type and measured~ep-th) ' Otis 7" x 4" WD Pkr. @ 9,470' - 9,955' 12 Attachment~ #2 Description summary of proposal E~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation March 1988 14 If proposal was verbally approved Name of approver Date approved 15 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed R.D. Roberts /~.~¢_~,/~~ Title Environmental ENqineer ' 6" Commission Use Only Date ~/30./8R Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Commissioner I N°' by order of the commission Form 10-403 Rev 12-1-85 Attachment #1 TBU D-15RD2 Perforations ZONE G-2 G-3 G-4 B-1 B-3 B-4 B-5 ~ (DIL) -- 9,258' - 9,272' 9,284' - 9,300' 9,322' - 9,352' 9,676' - 9,700' 9,815' - 9,856' 9,890' - 9,995' 10,030'- I0,118' TVD 9,097' - 9,111' 9,123' - 9,139' 9,160' - 9,190' 9,511' - 9,534' 9,650' - 9,690' 9,722' - 9,826' 9,861' - 9,948' NEF/em/28/Sundr2 Attachment # 2 Well D-15RD2 Bleach/Acid Perforation Cleanup Procedure 1. RU return lines to portable tank. Backflow well to collect samples for H2S, bacteria, and solids analysis. 2. RU CTU, N2 and acid pumps. Pressure test surface lines and BOPE to 5000 psi. 3. RIH. Spot and pump 2000 gallons of inhibited 5% NaOC1 (bleach). 4. Backflow wellbore volumes (230 BW), jetting from 3000' with N2. 5. Inject 100 bbls of FIW. 6. RIH. Spot and pump 6000 gallons of 10% HC1 with surfactant, diverter, iron reducer, and clay stabilizer, and inhibitior. Follow with 2000 gallons of 2% NH4C1 water with surfactant and clay stabilizer. 7. POH and RD equipment. Return well to injection immediately. PMO/em/676/OE28 REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed- Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other [] 2 Name of Operator UNOCkL 3 Address P.O. Box 190247 Anchorage, AK 99519 4 Location of well at surfacet, eg A-2, Cond. 10 Dolly Varden Platfor~z 754' FSL, 1,130' F~, Sec. 6-8N-13W-SM At top of produchve ~nterval 1,897' FSL, 737' ~'14'L, Sec. 6-8N-13W-SM At effechve depth 1,965' FSL, 846' ~'L, Sec. 6-8N-13W-SM At total depth 1,968' FSL, 868' [~¢b, Sec. 6-8N-13W-SM 11 Present well cond~bon summary Total depth, measured true vertical 10,400' feet Plugs (measured) 10,229 ' feet Perforate [] Pull tubing [] 5 Datum elevahon (DF or KB) 106' KB above MSL 6. Umt or Property name Trmd~nE Bay Hn~t 7 Well number D-15RD2 8 Approval number 7-465 9 APl number 50-- 733-20159-02 10 Pool McArthur River Field 10,276' - 10,400' CMT Feet Effective depth: measured 10,195 ' trueverhcal 10,029' feet Junk (measured) feet None Casing Length S~ze Structural Cemented Measured depth True Vertical depth Conductor Surface 2,500' 13 3/8" Intermediate 6,003' 9 5/8" Production 2,300 sx 2,500' 2,434' 3,450 sx 6,003' 5,873' Liner 4,643' Perforahon depth, measured true vertical 7,I 1,575 sx See Attachment #1 Tub~ng(s~ze, grade and measured depth) 3 1/2", 9.2#, N-80 BTC tb~ @ 9,151' Packers and SSSV(type and measured~epth) Otis 7" x 4" WD ?kr. @ 9,470' - Otis 7" ~0,380' 9,955' RECEIVED SEP 2 3 Alaska Oil & Gas Cons. Commission Anchorage x 4" WD Pkr. w/8' SB ext @ 9,090' 12 Stimulation or cement squeeze summary Intervals treated (measured) Attachment #2 Treatment description including volumes used and final pressure 13. Representative Daily Average~l~:~c~r InJection Data OiI-Bbl Gas-Mcr Water-Bbl Camng Pressure Prior to well operation 8/10/87 102 Subsequent to operation 9/8/87 1270 Tubing Pressure 3600 psi 4000 psi 14 Attachments #2 Daily Report of Well Operahons ~ Cop~es of Logs and Surveys Run [] 15. I hereby cerhfy that the foregoing ~s true and correct to the best of my knowledge * Marathon Oil Company Sub-Operator Signed D. RoDerts TItle~viro~t~l ]~rzg~--~eer Date 9/22/87 Form 10-404 Rev 12-1-85 Submit In Dupllca~ Attachment #1 TBU D-15RD 2 Perforations ZONE G-2 G-3 G-4 B-1 B-3 New Perforations B-4 B-5 MD (DIL) 9258'-9272' 9284'-9300' 9322'-9352' 9676'-9700' 9815'-9856' 9890'-9995' 10,030'-10,118' TVD 9097'-9111' 9123'-9139' 9160'-9190' 9511'-9534' 9650'-9690' 9722'-9826' 9861'-9948' Attachment #2 Daily Summary of Well Operations Well D-15RD2 8118187 RU CTU. RIH pumping FIW @ 3/4 BPM w/2-3/8" Navidril and 2.80" Mill on 1-2" CT. Circulating pressure = 2500 psi, tag x-nipple @ 9110' CTM and PU to 9097'. Pump 20 bbls 30#/1000 gal gel sweep and circulate w/90 bbls FIW @ 1BPM (Hole volume = 80 bbls). SD pump, POH, RD CTU. 8119187 RU jet nozzle, pressure test BOPE to 5000 psi, and RIH to 10,000'. Pump 2000 gal 15% HCL plus additives, followed by 2000 gal 12-3 mud acid plus additives, and 2000 gal 3% ammonium chloride. Acid was spotted to perfs before squeezing, pressures are as follows (Displaced ammonium chloride to perfs w/20 bbls FIW). Procedure Rate Pressure Remarks Displace HCL 1 BPM 3300 psi Squeeze HCL 1/2 BPM 3900 psi Press decreased slowly as HCL pumped away. Squeeze HF 1/2 BPM 3700 psi Decreased to 3500 psi. Squeeze NH4CL 3/4 BPM 3900 psi Increased to 4200 psi at end of job. ISIP = 2000 psi, 1500 psi after 5 min, 1380 psi after 10 min, 1200 psi after 15 min. POH and RD. MU injection line, pressure test surface equipment, RIH, and pump 2000 gal 15% HCL and 40 bbls FIW down tubing @ 1BPM. Pressures increased during pumping from 2000 psi to 3200 psi. POH and place well on injection. 9/3/87 RU E-Line and RIH w/20', 2-5/8", 1 SPF, 0° phasing perf guns and shoot B-3 from 9836'-9856' DIL and POH. Guns did not fire. MU 20' of perf guns as before and RIH and shoot B-3 from 9836'-9856' DIL and POH. Seven shots failed out of twenty total. Five of the seven shots were from 9836'-9846'. MU 30' of perf guns with select charges, RIH and shoot B-3 from 9815'-9845' and POH. Ail but one shot fired. RD E-I~ine and put well back on injection. NEF / lb / 48 / Sundr 3 N~sk~ 0~ & G~s Co~s. Com~ss~o~ STATE OF ALASKA AL ,..,,A OIL AND GAS CONSERVATION C ,,,~IISSION APPLICATION FOR SUNDRY APPROVALS I Type of Request. Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] T~me extension ~ Change approved program ~ Plugging [] Shmulate [] Pull tubing ~ Amend order [] Perforate ~ Other E3 2 Name of Oper~or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4 Locahon of well at surfaceLeg A-2, Cond. 10 Dolly Yarden Platform 754' FSL, 1,130' FWL, Sec. 6-SN-13W-SM At top of productive ~nterval 1,897' FSL, 737' FWL, Sec. 6-8N-13W-SM At effechve depth 1,965' FSL, 846' FWL, Sec. 6-8N-13W-SM At total depth 1,968' FSL, 868' FWL, Sec. 6-8N-13W-SM 5 Datum elevahon (DF or KB) 106' KB above MSL 6. Umt or Property name Trading; Bay Unit 7 Well number D-15RD2 8 Permit number 80-05 9 APl number 50-- 733-20159-02 10. Pool ' McArthur River Field 11 Present well condition summary Total depth, measured true vertical 10,400' feet Plugs (measured) 10,229' feet 10,276' - 10,400' CMT Effective depth measured 10,195 ' feet Junk (measured) true vertical 10,029' feet None feet Camng Length S~ze Cemented Measured depth True Vertical depth Structural Conductor Surface 2,500' 13 3/8" 2,300 sx 2,500' 2,434' 9 ~'8" 6 003' 5 873' Intermediate 6,003' ~ ;.f.~/ 3,450 sx , , Product,on ~ ~ g~ ~ ~... Liner 4,6~' 7" 1,575 sx 10,380' 9,955' Perforation depth measured ~'~ ~O°~'] Zone G-2 9,258' - 9,272' MD 9,097' - 9,111' TVD - ~"~ G-3 9,284' - 9,300' MD 9,123' - 9,139' TVD true vertica~.A~c~£.~'$"q~v'~"~.,~. .,.~?, G-4 9,322' - 9,352' MD 9,160' - 9,190' TVD ~\~5\.'2~TM ~?.'"~;-~' B-1 9,676' - 9,700' MD 9,511' - 9,534' TVD B-4 9,890' - 9,995' MD 9,722' - 9,826' TVD Tubing (s~ze, grade and measured depth) B-5 10,030' - 10,118' MD 9,861' - 9,948' TVD 3 1/2", 9.2#, N-80 BTC tbg @ 9,151' Packers and SSSV (type and measured 8epJh) Otis 7" x 4" WD ?kr. @ 9,470' - Otis 7" x 4" WD Pkr. w/8' SB ext @ 9,090' 12.Attachments: #1 Description summary of proposal [] Detmled operations program [] BOP sketch [] August, 1987 13 Estimated date for commencing operation Date approved 14. If proposal was verbally approved Name of approver Date 7/27/87 15 I hereby~ertify that the foregoing is true and correct to the best of my knowledge Signed'K' ~ D. I~:)be_rt.s Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~pro~ed C~y * Marathon Oil Company- Sub-Operator ~~ Commissioner Approved by [iV LONNiE g. &llll J Approva, No. ~=.:~4_.~--~ by order of '~ ~"~V the commission Date Form 10-403 Rev 12-1-85 Submit m triplicate Attachment #1 Application for Sundry Approval Well D-15RD2 Cleanout Procedure Approval is requested to change a previously approved program (Sundry Approval No. 7-262, Date 4/20/87). In May of this year, an attempt to perforate Hemlock Bench 3 was aborted when the perforating guns were stuck at approximately 4,500' MD. The guns were successfully retrieved. The following procedure is proposed to clear the tubing of suspected iron sulfide buildup. Perforating operations will resume once the tubing has been cleaned out. 1. Rig up coiled tubing with downhole motor and bit (2.80"). 2. Pressure test surface equipment and BOPE to 5000 psi. 3. Clean out to X-nipple at 9119'. 4. Circulate tubing clean. Run polymer sweeps, if necessary. 5. POH. LD motor and make up jet nozzle. 6. RIH. Spot and pump the following acid treatment: A. 2000 gal. 15% HCL with surfactant, diverter, iron stabilizer, and inhibitor. B. 2000 gal. 12-3 mud acid with surfactant, diverter, iron stabilizer, and inhibitor. C. 2000 gal. 3% ammonium chloride. 7. Displace to perforations with injection water. 8. POH w/coiled tubing and rig down. 9. Pump directly into tubing 2000 gal. of 15% HCL as in Step 6-A above. 10. Place well on injection and monitor rates and volumes. 11. Resume perforating Hemlock Bench 3. WLB/NEF/em/28/Sundr2 STATE OF ALASKA t AI.~' A OIL AND GAS CONSERVATION CO ,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well Q Alter camng ~ T~me extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operiltor UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-2, Cond. 10 Dolly Varden Platform 754' FSL, 1,130' FWL, Sec. 6-SN-13W-SM At top of produchve ~nterval 1,897' FSL, 737' FWL, Sec. 6-8N-13W-SM At effectwve depth 1,965' FSL, 846' FWL, Sec. 6-8N-13W-SM At total depth 1,968' FSL, 868' FWL, Sec. 6-8N-13W-SM 5. Datum elevahon (DF or KB) 106' KB above MSL feet 6. Unit or Property name TradinK Bay Unit 7. Well number D-15RD2 8. Permit number 80-05 9. APl number 50-- 733-20159-02 10. Pool McArthur River Field 11. Present well cond~twon summary Total depth: measured true verhcal 10,400' feet Plugs (measured) 10,229' feet 10,276' - 10,400' CMT Effective depth: measured 10,195 ' true vertical 10,029' feet Junk (measured) None feet Casing Length Structural Size Cemented Measured depth True Verhcal depth Conductor Surface I n termed late Produchon L~ner 2,500' 13 3/8" 6,00~ 9 5/8" ,, ,3,ECEIVE 7,, 2,300 sx 2,500' 2,434' 3,450 sx 6,003' 5,873' 1,575 sx 10,380' 9,955' Perforat,ondepth: measurecl~p~ ] ? J987 Zone G-2 9,258' - 9,272' MD 9,097' - 9,111' TVD G-3 9,284' - 9,300' MD 9,123' - 9,139' TVD t~'~v~d~'~asCo,v.s 0-4 9,322' - 9,352' MD 9,160' - 9,190' TVD AnCh0~eb0/n~$M~~ B-1 9,676' - 9,700' MD 9,511' - 9,534' TVD B-4 9,890' - 9,995' MD 9,722' - 9,826' TVD Tubing(size, grade and measured depth) B-5 10,030' - 10,118' MD 9,861' - 9,948' TVD 3 1/2", 9.2#, N-80 BTC tbg @ 9,151' Packers and SSSV(type and measured depth) Otis 7" x 4" WD Pkr. @ 9,470' - Otis 7" x 4" WD Pkr. w/8' SB ext @ 9,090' 12.Attachments: ]~1 Descriphon summary of proposal [] Detailed operahons program [] BOP sketch [] 13. Estimated date for commencing operation April, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /-'j~J,? ,Z~, ~"~~' Title Enviror~nmntal Engin~...r ~y~ D. Roberts Commission Use Only Date 4/15/87 Co n d it,o n ~a~p roval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance * Mar~~/~.yyrator Approved by ~ '",~" {,__ -~/~~/~~~ Form 10-403 Rev 12-1-85 Attachment #1 Perforate Hemlock Bench 3 in Well D-15RD2 Procedure 1. Skid Rig #77 over Well D-15RD2. 2. Rig up surface pressure recorder. 3. SI injection and get pressure falloff for 24 hrs. 4. Rig up E-line with 2-5/8" guns, 1SPF and 0° phasing. 5. Pressure test lubricator to 2,500 psi. 6. Perforate Hemlock Bench 3 from 9,815 - 9,856. POH. 7. Commence water injection. Note: Based on the incremental injection rate into Hemlock Bench 3, additional perforating may be necessary. 8. Run injection profile. NEF/em/28/Sundr2 Umon Od and Gas/~v~s~on Western Region Umon Od Compan~ ~, Cahforma P 0 Box 6247. Anchorage, Alaska 99502 Telephone (907) 276-7600 unl,on DOCUMENT TRANSMITTAL November 4, 1983 Hand Carried TO: William Van Alen FROM: R.C. Warthen LOCATION: 3001 Porcupine Drive LOCATION: Alaska District Anchorage, Alaska 99501-3192 ALASKA OIL & GAS CONSERVATION COMMISSION i Transmitting: One (1) tape and verification listing each of the following wells: TBU D-25RD - Run i and 2 TBU D-25RD - Run 2 TBU D-34A Deepen TBU D-15RD -',. TBU D-15RD #2 ~ KTU 43-6X ~,¢.0 l't~¢':~--- One (1) tape of TBU D-3RD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: ' ' STATE OF ALASKA 41 ALASKA (*. AND GAS CONSERVATION C(~ vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS D rll ,, n----~ we,--~ -~ ~~'~ 2 Name of operator 7 Permit No. Union Oil Company of California* 80-05 3 Address 8 APl Number P. O. Box 6247, Anchroage AK 99502 50-733-20159-01 4 Location of Well at surface Leg A- 2, 754 'FSL, Cond f~10, Dolly Varden Platform, 1130'FWL, Sec 6-8N-13W-SM 9 Umt or Lease Name Trading Bay Unit 5 Elevat.on ~n feet (~nd~cate KB, DF, etc ) 106'KB Above MSL 6 Lease Designation and Se.al No ADL-18729 10 Well No D-15RD2 WO 11 F,eld and Pool McArthur River Field For the Month of SEPTEMBER ,19 82 ,'12 Depth at end of month, footage drdled, f~shmg jobs, d.recnonal drdhng problems, spud date, remarks ~ 10,400'TD; 10,229'PBTD Perfd G-2, 3, & 4 and B-l, 4, & 5 intervals. Acidized G Zone. Set inj pkr @ 9090' Estab inj into G Zone & Hemlock. Inj 340 BWPD into G Zone & 62~ into Hemlock. Workover operations completed 09-22-82. 13 Casing or hner run and quantities of cement, results of pressur3 tests NA 14 Coring resume and brief description NA 15 Logs run and depth where run Injection Profile across G Zone and Hemlock DST data, perforating data, shows of H2S, m~scellaneous data NA " OCT Z 9 982 Alaska Oil & Gas Cons ~.~ 17 I hereby/~r, t4tfy that the foregoing ~s true and correct to the best of my knowledge (I NO~jport on th~s form ~s required for each calendar month, regardless of the status of operations, and must be fded m dupheate w~th the Alaska Od ~t'~d Gas Conservation Commission by the 1 [th of the succeeding month, unless otherwise d~rected ~orm ~0-404 Marathon 0±1 ,., v 2C'om'-an,~ - ~ ~ ,-,~, ,-~uh-C~'era~-or Subm,t m duphcate [:lev 7-1-80 i, , STATE OF ALASKA ' ALASKA(' LAND GAS CONSERVATION C~ MISSION 0~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION,,.. 1. Drilling well r-1 Workover operation ~ ' 2. Name of operator 7. Permit No. Union Oil Company of California* 3. Address P. O. Box 6247 4 Location of Well at surface Leg A-2, Cond #10, Dolly Varden Platform 754'FSL, ll30'FWL, Sec 6-SN-13W-SM 5 Elevanon ~n feet (~ndlcate KB, DF, etc ) 106'KB Above MSL 6. Lease Demgnat~on and Se,al No ADL-18729 80-05 8. APl Number 50- 733-20159-01 9. Unit or Lease Name Trading Bay Unit 10. Well No D-15RD2 WO 11. F,eld and Pool For the Month of. AUGUST ,19 82 McArthur River Field '12 Depth at end of month, footage drilled, hshlng jobs, directional drllhng problems, spud date, remarks 10,400'TD; 10,229'PBTD RU over well on 08-29-82. Killed well & pulled tbg Set retr BP @ 9454'. Press tstd csg & plug OK. from pkr @ 9500'. 13 Casing or hner run and quantities of cement, results of pressure tests NA 14 Comng resume and bmef descmpt~on NA 15 Logs run and depth where run NA ,16 DST data, perforating data, shows of H2S, m,scellaneous data NA RECEIVED OCT 1 9 1982 Alaska Oil & ~as Cons. Cor~..flission Anchorage 17 I here~rt~y that the foregoing Is true and correct to the best of my knowledge · ,_..~-~n..O,, o., s or~ ,s r..u,~ ,or .~ c~,.n~r ~on,.. r...r~,.s ~¢~l~nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise Form 10-404 Rev 7-~0 *Marathon 05_1 Company - Sub-Operator Submit in duplicate STATE OF ALASKA ALASKA(' ,-AND GAS CONSERVATION C(~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL ]I~ 2 Name of Operator 7 Permit No Union Oil Gompany of California* 80-5 3 Address 8 APl Number P. O. BOX 6247, Anchorage AK 99502 50- 733-20159-02 OTHER [] 4 Location of Well :leg A-2, Cbnductor fl10, D~11¥ Varden 21atform 754'FSL, ll30'FWL, Sec. 6-8N-13W-SM 5 Elevation m feet (mdmate KB, DF, etc ) 106' KB above MSL 12 Lease Designation and Serml No A-18729 9 Unit or Lease Name Trading Bay thit 10 Well Number D-15RD2 11 Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tnphcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation E~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [~ (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Workover operations began August 29, 1982, and were ooncluded September 22, 1982. See Attachments for a record of operations. * Marathon Oil Company Sub-operator RECEIVED OCT 1 9 1982 Alaska 0il & Gas Cons Commission Anchorage 14 I her b~v c"c~tlfy that the foregoing ~s true and correct to the best of my knowledge e ~ace below for Commission use -- oi~nd~t~ons of Approval, ~f any Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ir~ Triplicate and "Subsequent Reports" i r~ Duplicate ATTACHMENT D-15RD2 Workover was completed as follows: 1. The well was killed w/ FIW and the tbg was pulled and layed down. 2. The G-Zone G-3 and 4 sands were perfd at 9284 '-9300' and 9322'-9352' DIL w/ 4" csg guns, 4 HPF. 3. The G-3 and 4 perfs were acidized w/ 1000 gal of 7-1/2% HCL, and 2000 gal of 12-6 HF and 150# of diverter. Communicated to G-1 and 2 sands. 4. Recovered perm pkr @ 9500'. Perfd for a block squeeze between G-2 and 3 sands at 9276' DIL. 5. Squeezed 150 sx C1 G cmt into perfs at 9276' DIL. 6. Perfd for a block squeeze between G-1 and 2 sands at 9243' DIL. Could not break down formation @ 6000 psi. Drilled out cmt and rtnrs. 7. Reperfd Hemlock B-1 9676'-9698' DIL and G-Zone G-3 and G-4 9284'-9300' and 9322'-9352' DIL w/ 4" csg gun, 4 HPF. 8. Isolated the G-Zone, acidized w/ 1000 gal of 7-1/2% HCL, 2000 gal of 12-6 HF. Communicated to G-1 and 2 sands. 9. Circ 15 sx C1 G cmt into perfs @ 9276' DIL, spotted 60 sx of cmt and squeezed perfs @ 9243' DIL. Drilled out cmt and rtnrs. 10. Reperfd G-4 sand 9322'-9352' DIL, and G-3 sand 9284'-9300' DIL w/4" csg gun, 4 HPF. 11. Perfd G-2 sand 9260 '-9262' DIL and 9269 '-9271' DIL w/ 2-1/8" gun, 4 HPF. Reperfd G-2 sand 9258'-q272' DIL w/ 2-1/8" thru tbg and 4" csg guns, 4 HPF each. 12. Set G-Zone/Hemlock isolation pkr @ ~7~k' CBL. Set injection pkr @ 9090' CBL. Ran 3-1/2" inj tbg. 13. Established FIW inj. Logged inj profile across G-Zone and Hemlock. 14. Reperfd Hemlock B-1 9678'-9700' DIL w/ 2-1/8" thru tbg guns, 4 HPF. 15. Reperfd Hemlock B-5, 10,030'-10,050' and 10,075'-10,100' DIL w/ 2-1/8" thru tbg guns, 4 HPF. 16. The well was returned to injection. ~~lV~ 0CT 1 9 1982. Alaska Od & Gas Cons. Ccmm~ssion Anchorage ( D-15RD2 Water Injection by Zone Zone Rate % Total BWIPD G-2 0 0 * G-3 80 8 * G-4 260 27 * B-1 202 21 * B-4 18 2 * B-5 400 42 ** 960 100 * Based on injection log run 09-21-82. ** Based on injection log run 09-21-82 and results of Bench 5 reperforation 09-22-82. RECEIVED OCT 1 9 1982 Alaska Oil & Gas Cons CorDm;s;ior~ Anchorage Zone G-2 G-3 G-4 B-1 B-4 B-5 D-15RD2 Workover Perforated Intervals (DIL) Top 9258 'MD 9284 'MD 9322'MD (9097 'TVD) (9123'TVD) (9160 'TVD) Bottom Shots 9676 'MD (9511'TVD) 9890 'MD (9722'TVD) 10030'MD (9861'TVD) (10,030'-10,050' 9272'MD (9111'TVD) 8 HPF 0°, 360° Phasing 9300'MD (9139'TVD) 12 HPF 360° Phasing 9352'MD (9190'TVD) 12 HPF 360° Phasing 9700'MD (9534'TVD) 9995 'MD (9826'TVD) 10118 'MD (9948'TVD) 10,075'-10,100') 8 HPF 0°, 360° Phasing 4 HPF 0° Phasing 4 HPF 0° Phasing 8 HPF 0° Phasing RECEIVED OCT 1 9 1982 Alaska 0il & Gas Cons, Anchorage STATE OF ALASKA ~ ALASKA~ LAND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS /, OTHER [] 1 DRILLING WELL [] COMPLETED WELL 2 Name of Operator Union Oil Company of California* 3 Address P. O. Box 6247, Anchorage AK 99502 4 Location of Well Leg A-2, Conductor #10, Dolly Varden Platform 754'FSL, ll30'FWL, Sec. 6-SN-13W-SM 5 Elevation ~n feet 0nd~cate KB, DF, etc ) MST. 12 6 Lease Demgnat~on and Serial No A-18729 8 APl Number 50_733-20159-02 9 Unit or_Lease Name 10 Well Number D-15RD2 11 F~eld and Pool McArthur River Field Check Appropriate Box To Indmate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tnphcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Camng [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [~] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of stamng any proposed work, for Abandonment see 20 AAC 25 105-170) Marathon Oil Company intends to complete D-15RD2 as a G-Zone/Hemlock water injection well. This will be accomplished by running one string of 3-1/2", 9.2#, N-80 tubing and utilizing waterflood control valves installed in side pocket mandrels to control the injection rate into the G-Zone. A permanent packer will be run between the G-Zone and Hemlock formations for isolation while a retrievable packer run with the tubing will be set ir~nediately above the G-Zone to isolate the tubing/casing annulus from injection pressure. * Marathon Oil Company Sub-operator 14 I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ~--~ ~-.. ~.~)0_.~.~%4~' Title b~l'(~ ~. S~' The space be~w for Comm,ssion use ~.w~) q" Cond,tlons of Approval, if any Approved by OIItllll COMMISSIONER Approved op¥ Returned By Order of the Comm~smon Form 10-403 Rev 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ~n Duphcate STATE OF ALASKA ~ ALASKA ,LAND GAS CONSERVATION C ,,.MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL 2 Name of Operator 7 Permit No Union Oil Qampany of Q~lifornia* 80-5 3 Address 8 APl Number P. O. Box 6247, Anchorage AK 99502 50-733-20159-02 4 Location of Well Leg A-2, Cbnd #10, Dolly Varden Platform, 754' FSL, 1130' FWL, Sec. 6-SN-13W-&M 5 Elevat,on m feet (md~cate KB, DF, etc ) 106' KB above MSL 6 Lease Designation and Serml No A-18729 9 Unit or Lease Name Trading Bay Unit 10 Well Number D-15RD2 11 FIeld and Pool OTHER [] 12 (Submit m Tr~phcate) Perforate ~ Alter Casing [] Perforations Stimulate ~[ Abandon [] Stimulation Repmr Well [] Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulhng Tubing (Note Report multiple compleBons on Form 10-407 w~th a submitted Form 10-407 for each completion ) McArthur River Field Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Duplicate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) It is Marathon's intention to workover Well D-15RD2 as follows' 1. Kill the well with workover fluid. 2. Pull and lay down the 4-1/2" by 3-1/2" tubing string. 3. Perforate the G-Zone Sands @' G-2 9260'-9280' MD G-3 9284'-9300' MD G-4 9322 ' -9352' MD ~,-/~ ~2~ _ ~o ~/~ 4. Stimulate the formation as needed to affect acceptable injection rates. 5. Run in the hole with dual 2-3/8" tubing strings. 6. Complete the well as a dual water injector in the Hemlock and G-Zones. ~ ~ O ~ ,4 '-2 o -'~.~'- Alaska 0il & Gas Cons. C0mrnissi, Anchorage * Marathon Oil Company Sub operator 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge The space bel~-for Comm BY LI:)H~tI[ C. SMiTI! Date ~ ~.pproved Returned By Order of COMMISSIONER the Commission Subsequent Work Beportecl on Form No ~_~L Datecl/?~-~ Conditions of Approval, if any Approved by Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate Documen( .,ansmi° ' ~__[_co~~? ~.,o.O,,Com~.,,o,C~ ~'1 I co~,~l union .ii co"~,,~,~-~l DATE SUBMITTED _M. ON IT~. W. Kugler Alaska 0&G Cons. Conin. ^~3001 Porcupine Drive Anchorage, AK 99504 TRANSMITTING THE FOLLOWING FR~. C. Warthen Union 0i 1 AT PO Box 6247 Anchorage, AK 99.~ TELEPHONE NO 021 ST'T T' I 5T/',l' TEC I TBU D-15 RD #2 intout )uter Tape & Printout ser At #1 #2 acknowiedge returning copy of this document RECIY. ~ ~ , DATE: FORM 1-2M02 (REV 11-72) PRINTED IN U S A NOTE' ¢ l apes wi ll be forthcominl~ocument Transm;o.~I upon r~ceipt from Union Oil Company of , ornJa ~ATE SUBMITTED ACCOUNTING MONTH July 10, 1980 T°H. W. Kugler ~P.~ C. Warthen Alaska O&G Cons. Comm. Union Oil Company ^T3001 Porcupine Drive ^PO Box 6247 Anchorage, AK 99504 Anchorage, AK 99502 TELEPHONE NO TRANSMITTING THE FOLLOWING - I ........ TBU D-15 RD #2 1 Sepia & Blueline each' ... Dual Ind./SFL TVD Run 1, 1" Dual T nd/SFL TVD Run l, 2" Dual Ind/SFL/GR Run 1, 5" Comp. Neutron/GR 2", 5" · 2" 5. ,,~ ~H£ Snnic/GR Run l, , Formation Density/GR 2", 5'~' ~'- Formation Dens/Comp. Neu./GR Comp. Densilo§ 2", 5" Comp. Densi/Comp. Neutron BHC AcoustiloQ. 5" BHC Acoustil oq/F-Curve DI/Focused Loq 2" 5" Ptease acknowledge receipt hv rctttrning copy of this document transrnitta.. FORM 1-2M02 (REV 11-72) PRINTED IN U S A F~.~rm P--7 ~ SUBMIT INDt- , ,ATE* STATE OF ALASKA (s~ other in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la TYPE OF WELL OwIELLLO GAS WELLI I DRYF"'~ b TYPE OF COMPLETION NEW WORK DEEP- I-~! PLUG ~ DIFF. WELL [--~ OVER [~ EN ~ BACK I~1 RESER Other W~t~ Tnjec,_tc~ Other 2 NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247~ Anchorage AK 99502 4 LOCATION OF WELL (Report tocatlon clearly and in accordance with any State requirements)* At surface 754'FSL, 1130'FWL, Sec 6-8N-13W-SM (Leg A-2, Cond At top prod interval reported below 1924'FSL, 777'FWL, Sec 6-8N-13W-SM At total depth 1968'FSL, 868'FWL, Sec 6-8N-13W-SM #10, DVP) 5 APl NUMERICAL CODE 50-133-20159-02 6 LEASE DESIGNATION AND SERIAL NO ADL-18729 A-926 i7 IF INDIAN, ALLOTTEE OR TRIBE NAME __ 8 UNIT, FARM OR LEASE NAME Tradin~ Bay Unit 9 WELL NO D-15RD2 10 FIELD AND POOL, OR WILDCAT McArthur River Field 11 SEC,T, R, M, (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12 PERMIT NO 80-5 10,400'MD DEPTH 10,276'MD I HOW MANY' ' 21 ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS 10:229'TVD 10 ;157'TVD I NA All 22 PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)' 23 WAS DIRECTIONAL SURVEY MADE Hemlock Injector - See Item 28 Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN GR-DIL, Ray-BHC, FDC-CNL-Cal, 25 CASING SIZE WEIGHT, LB/FT 9-5/8" 9-5/8" 43.5 9-5/8" TDT-K, CBL-CCL, VDL, Gyro Surv, FMT CASING RECORD (Report all strings set In well) DEPTH SET (MD) 3292' 26 LINER RECORD 7" I 5737' 10,380' 1000 sx 7" Tie-BackI 41' 5,738' 575 sx 28 PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) B. 1: 9676'-9698' SOS 2-1/8" Enerjet 4 HPr B. 4: 9E90'-9995' SOS 2-1/8" Enerjet 4 HPr B. 5: 10,030'-10,118' SOS 2-1/8" Enerjet i H~ 30 HOLE SIZE CEMENTING RECORD AMOUNT PULLED 12-1/4" 1000 sX C1 G SCREEN (MD) 27 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9423' 9500' ~-l/g" 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED SEE AFTACHED SHEET PRODUCTION DATE FIRST PRODUCTION DATE OF TEST IHOURS TESTED CHOKE SIZE FLOW TUBING ICASING PRESSURE CALCULATED PR ESS I 24-HOUR RATE 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) NA 32 LIST OF ATTACHMENTS IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) PROD'N FOR OIL--BBL TEST PERIOD OIL-BBL I I WE LL STATUS (Producing or shut-In) Injection GAS-MCF WATER--BBL I GAS--OI L RATIO GAS--MCF WAT~R--~B~. ~' IOILGRAVITY-API (CORR) I I~. ,~ .) '~ ~i'~.,~ I Y ~:, ~ , '"/, 'l 3'ES~~NEssED B Well H~ory, Casing and Tubing Details ' 33 I hereby certify j~h~lhe foregoln~ at~5~ ,~o~ation is cornpletvnd correct as determined from all available records SI TITLE , *(See instructions and Spaces for Additional Data on Reverse Side) DATE 6~20~80 *Marathon Oil Company - Sub-Operator INSTRUCTIONS General Th~s form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska Item: 16: Indicate which elevation ~s used as reference (where not otherwise shown) for depth measurements g~ven ~n other spaces on th~s form and ~n any attachments Items 20, and 22' If th~s well is completed for separate production from more than one ~nterval zone (multiple com- plet~on), so state ~n ~tem 20, and ~n ~tem 22 show the producing ~nterval, or ~ntervals, top(s), bottom(s) and name(s) (~f any) for only the ~nterval reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately ~dent~fied, for each additional ~nterval to be separately produced, showing the additional data pertinent to such ~nterval Item 26. "Sacks Cement" Attached supplemental records for th~swell should show thedeta~ls of any multiple stage cementing and the location of the cementIng tool Item 28' Submit a separate completion report on th~s form for each ~nterval to be separately produced (See ~nstruct~on for ~tems 20 and 22 above) 34 SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35 GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT DEPT 36 CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER -- Attachment to Well Completion Report TBU Well D-15RD2 Item 29: 9860'-9862' Perfd 2 HPF and sqz 50 sx Class G neat at I BPM w/ 2000 -2500 psi. 9860'-9862' Spotted 6 bbls 7-1/2% HC1 w/ 2 gals A200 at 1/4 to i BPM @ 4000 - 4800 psi. 9860'-9862' Sqzd 100 sx Class G neat into perfs w/ final press 5400 psi. 10,030'-10,118' (Bench 5) Spotted 1000 gals 7-1/2% HC1, 4000 gals 12-10 Mud Acid, 1000 gals 7-1/2% HC1 at 1/2 BPM w/ 4750 psi. (Bench 4-5) Spotted 500 gals 5% HC1, 2000 gals 12-6 Mud Acid, 500 gals 5% HC1. Final rate 3/4 BPM at 4000 psi. (Bench 4-5) Spotted 750 gals 7-1/2% HC1, 2000 gals 12-10 Mud Acid, 750 gals 7-1/2% HC1. Final rate 1-1/2 BPM at 2800 psi. FO~M 484 ~'V ~-~ DATE May 20, 1980 M~RATHON OIL COMPANY HISTORY Of Oil OR GAS WELL FIELD McArthur Rvr Field WELL NO. D- 15RD2 LEASE STATE A I aska trad inq Bay Unit PARISH Kena i Pen in- COUNTY su la Borough BLOCK SEC. 6 TWP 8N R.13W M EASUREM ENTS TAKEN FROM 106.2' EL£V KB fToP Of OiL STRING ~ ELEV TOP OF ROTARY TABLE ELEV. ~ GRD OR MAT, ELEV. ~ HISTORY PREPARED BY L.G. Haywood TITLE Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1980 02-11 02-12 02-13 02- 14 02-15 02-16 02-17 WELL HISTORY - TBU WELL D-15RD2 (Marathon AFE 4677) RU dr lg eqpmt. Moved rig over D-15RD & ran elec cables. RU Otis & shifted XA slv@ 10,541'. POH & RD Otis. Displ FIW in tbg & csg w/ 10.2 ppg mud. NU BOPE. PU tbg & pulled seal assy from pkr. C&C mud. RU to pull 4-1/2" SL tbg. Drawworks motor failed after pulling tbg about 2/3's of the way out of hole. All rig power SD. Now working on DC power. WO on drawworks motor. Fin POH w/ 4-1/2" tbg & stood back. PU 15 jts 2-3/8" tbg stinger & RIH on 4-1/2" SL tbg to 10,922'. C&C mud. HOWCO mixed & pumped 100 sx CIG neat w/ 5 bbls wtr ahead & 3 bbls wtr behind. Displ w/ 159 bbls mud. POH to 10,050'. C&C mud. POH w/ 4-1/2" tbg & stinger. RU DA & lub w/ JB & GR. DA ran JB & GR to 7490'. Set Halliburton EZ-Drill BP ~ 9400'. RIH w/ 4-1/2" SL tbg then POH LD same. ND BOP stack. MU spear & latched onto 9-5/8" csg. Prep to remove 9-5/8" csg slips. Worked 9-5/8" csg w/ spear. Could not pull csg high enough to remove slips w/ 400,000# pull. Cont to work csg. Pul led to 415,000# & finally able to remove slips. RU Dialog & ran FPI. 1st reading indicated 9-5/8" free only to 450'. 9-5/8" became more free each time pipe was moved. Final reading indicated 9-5/8" csg free to 650'. Released spear. POH & RD Dialog. NU 13-3/8" BOP. MU Tri-State mechanical csg cutter & RIH to 650'. Cutting csg @ 0700 hrs. Cut 9-5/8" csg @ 650'. POH LD cutter. RIH w/ spear w/ pack-off. Latched 9-5/8". Worked pipe--pipe not yet free. Failed to circ. PI cut @ 650' & into fm below 13-3/8" csg @ 2250' w/ 50 psi. POH w/ spear. R IH w/ mech cutter & cut 9-5/8" csg @ 535'. POH. RIH w/ spear. Worked pipe--pipe not yet free. Could not circ. PI fm as above w/ 50 psi. POH w/ spear. Rev pack-off on spear. RIH & latched 9-5/8" csg. Press on 13-3/8" x 9-5/8" csg ann ls w/ 1000 psi. Could not circ. Appears to be a bridge between surf & cuts @ 535' & 650'. Cont to work pipe to 400,000# pull. Pipe would not free up. Released spear & POH. RU Dialog & ran FPI. Pipe free only to 300'. RD Dialog. RIH w/ mech cutter & cut 9-5/8" csg @ 295'. POH. RIH w/ spear & latched 9-5/8" csg. Worked pipe--pipe still not free. POH w/ spear. PU & R IH w/ 12" x 10-3/4" WO shoe on 11-3/4" x 10-3/4" WP to 70' & stopped. Rotated & washed over 9-5/8" csg from 70' to 78' @ 2'/hr. Mud returns appear to contain dehyd mud--cannot detect any cmt yet. CBL does not indicate any cmt above 13-3/8" csg shoe. Well History - TBU D-15RD2 Page 2 02-18 02-19 02 -20 02-21 02-22 02-23 02-24 02-25 WO 9-5/8" csg from 78' - 115'. POH. Built & instld pack-off assy inside 9-5/8" csg stub. Stopped lost circ. RIH & WO 9-5/8" csg to 155'. POH. RIH & retr pack-off from 9-5/8" csg stub. RIH w/ mech cutter & cut 9-5/8" csg ~ 145'. POH. RIH w/ spear & latched 9-5/8" csg. POH & LD 103' of 9-5/8" csg. Instld pack-off in 9-5/8" csg stub. R IH w/ 11-3/4" x 10-3/4" WO shoe & WP. WO 9-5/8" csg from 155' to 170'. Rec mostly dehyd mud & sml amt of cmt over shaker. WO 9-5/8" csg from 170' to 257'. POH. RIH & retr pack-off from 9-5/8" csg. MU spear & R IH. Latched 9-5/8" csg & pul led csg free from cut @ 295' w/ 25,000# over wt. LD 150' of 9-5/8" csg. R IH w/ spear & latched 9-5/8" csg. Worked csg--cannot pull free. Released spear & POH. RIH w/ pack-off & set in 9-5/8" csg. RIH w/ 11-3/4" x 10-7/8" WO shoe & 11-3/4" x 10-3/4" WP. CO bridges from 221' to 295'. Rec cmt & dehyd mud. WO 9-5/8" csg from 295'-306'. WO 9-5/8" csg to 306'. POH. RIH & retr csg pack-off. RIH w/ mech cutter & spear. Cut 9-5/8" csg @ 320'. POH. Rec 2.85' of csg. RIH w/ spear & rec 23.3' of 9-5/8" csg. RIH w/ spear & worked 9-5/8" csg w/ 350,O00#--csg not free. POH. RI H w/ WP & washed to top of csg stub @ 320'. WO 9-5/8" csg from 320' - 338'. POH. RIH & retr pack-off. R IH w/ cutter & spear. Cut 9-5/8" csg @ 351'. Latched onto csg & POH. Rec 31' of csg. RIH w/ mech cutter & spear. Cut csg ~ 390'. Could not pull csg. RI H w/ mech cutter & spear. Cut csg @ 386'. POH. Rec 34.19' of 9-5/8" csg. RIH w/ WP. Washed & worked WP to 388'. POH. RIH & retr pack-off. RIH w/ cutter & spear. Cut csg @ 401'. POH. No rec. RIH w/ cutter & spear. Latched 9-5/8" csg & POH. Rec 14.40' of csg. RIH & set pack-off in 9-5/8" csg stub. RIH w/ WP & washed over to 404'. Cut & pulled 9-5/8" csg from 447'. WO 9-5/8" csg to 456'. Cut & pul led 9-5/8" csg from 490'. Pul led 9-5/8" csg from 535'. RIH to 12-1/4" bit & cleaned hole to csg stub @ 535'. Attempted to cut csg @ 580'--no cut. RI H to 570' & cut 9-5/8" csg. Cut & retr 9-5/8" csg from 571'. Cut & retr csg from 610'. Retr csg for original cut @ 650'. RIH w/ 12-1/4" bit & circ to 650'. Cut & retr csg from 690'. RIH w/ Johnson pkr to test 13-3/8" csg. 13-3/8" csg has holes between 532' & 577'. POH w/ pkr. Tstd BOPE. RIH w/ spear & engaged csg. Pulled 400,000// & got 9-1/2" stretch. Cut csg @ 1129'. Wouldn't pull w/ 450,000//. Cut csg @ 790'. Retr 101.64' of 9-5/8" csg w/ 200,000// pull. PU 12-1/4" bit & RIH to C&C hole. Cleaned hole to 791'. RIH & cut 9-5/8" @ 889'. POH & rec 97.38' of 9-5/8" csg. RIH w/ 12-1/4" bit & cleaned hole to top of stub @ 888'. Attempted to pull csg from cut @ 1129'--tight. Cut csg @ 995'. Jarred on csg--no rec. Cut csg @ 942'. Jarred on csg--tight. Cut csg @ 922'. Jarred on csg & moved top of stub to 849'. POH. PU 3 - 8" DC's & RIH. Jarred on 9-5/8" csg @ 849'.. Jars parted in middle. POH & MU OS. R IH w/ OS & rec jars & spear. Attempted cut @ 888'. No cut. POH. RIH & cut & rec 21.34' csg from 888'. RIH & jarred on csg w/ 400,O00#--no progress. RIH w/ WP & CO to 888'. R IH & attempted cut @ 902'--no cut. RIH & cut & rec 34.43' csg. RIH w/ 12-1/4" bit & CO to 942'. POH. Well History - TBU D-15RD2 Page 3 02 -26 02-27 02 -28 02 -29 03-01 03 -02 03 -03 03-04 O3-O5 RIH w/ spear & rec 39.45' of csg. Top of stub @ 983'. Made CO trip to 983'. RIH & cut & retr csg from 1063' (78.20'). RIH to rec csg from cut ~ 1129'. Jars parted. RIH w/ OS & fished jars & spear. RIH w/ spear & engaged 9-5/8" csg ~ 1063'. Jarred on csg. Jarred csg loose w/ 250,000#. POH rec 65.56' csg. RIH w/ 12-1/4" bit & CO to 1128'. POH & PU 8-1/2" bit. RIH & CO to 1190'. RIH to 2487' & circ hole clean. POH. RIH w/ cutter & cut csg @ 1210'. POH & MU spear. R IH & engaged spear ~ 1128'--jarred csg loose. Rec 80.70' csg. Made CO run w/ bit to 1208'. Circ hole clean & POH. PU cutter & RIH. Cut csg @ 1285'. POH & MU spear. RIH to 1208' & engaged spear. Jarred csg loose w/ 200-300,000//. POH rec 76.20' csg. Made CO run w/ bit to top of csg stub @ 1285'. CO to 1285'. POH. R IH & cut & retr 9-5/8" csg from 1400' (113.05'). RIH w/ 12-1/4" bit & CO to 1400'. POH. RIH & cut & retr csg from 1490' (89.81'). R IH & cut csg @ 1589'. Jarred & circ around 9-5/8" csg. POH. Rec 99.30' csg. Cleaned contaminated mud from rig floor. RIH w/_ DC's. Circ thru clrs to clear contaminated mud. RIH w/ 12-1/4" bit & CO to stub @ 1590'. POH. RIH & cut & retr 9-5/8" csg from 1692'. POH w/ 103.99' of csg. RIH & cut & retr 9-5/8" csg from 1885'. POH w/ 192.68' csg. R IH w/ 12-1/4" bit & CO to 1885'. POH. RIH w/ cutter to 2085' & cutting 9-5/8" csg. Cut csg ~ 2085'. POH. RIH w/ spear, moved 9-5/8" csg 6", then it stuck. POH. RIH & cut csg 8 1985'. POH. RIH w/ spear--could not pull csg. POH. RIH & cut & retr csg from 1925' (46.85'). Tstd BOPE--OK. RIH & retr csg from 1985' (53.33'). POH LD 9-5/8" csg & tools. (Total rec today: 100.18'. Top of stub @ 1985'.) RIH w/ 12-1/4" bit & cleaned hole to 1985'. RIH w/ spear & worked 9-5/8" csg from 1985'--tight. POH. RIH w/ cutter & attempted to cut. POH--no cut. R IH & cut csg @ 2033'. POH. R IH w/ spear & worked csg free from 2033'. POH rec 48.77' csg. RIH w/ spear & worked csg. POH rec 50.77' csg w/ centralizers. RIH w/ 8-1/2" bit & chased junk into csg. RIH w/ 8-1/2" bit to 2517'. (Total rec today: 9,9.54'. Top of stub @ 2085'.) CO hole w/ 8-1/2" bit & POH. RIH w/ cutter & cut csg 8 2150'. POH. RIH w/ spear & POH w/ 65.34' csg. R IH w/ cutter & cut csg @ 2240'. POH. RIH w/ spear & POH w/ 91.17' csg. RIH w/ cutter & cut csg @ 2420'. RIH w/ spear. POH--no rec. LD spear & PU hyd cutter. R IH & cut csg @ 2410'. POH LD cutter. (Total rec today: 156.51'. Top of stub @ 2240'.) RIH w/ spear & jars to 2240'. Jarred on csg--tight. POH. RIH w/ cutter & cut 9-5/8" csg @ 2370'. POH. RIH w/ spear & jars. Jarred on csg. POH rec 128.06' csg. RIH w/ spear & jars to 2370'. Jarred on csg. POH rec 39.79' csg. LD fishing tools & WP. RIH w/ 5" DP. RIH to 2455' & circ hole clean. Pumped 20 bbls wtr, 336 sx C I G neat cmt @ 15.9 ppg followed w/ 38 bbls mud. PU to 2150' & pumped wiper plug. POH & WOC. Cleaned rig. (Note: top of 9-5/8" tub @ 2410'; btm of 13-3/8" @ 22 50 ' · ) Well History - TBU D-15RD2 Page 4 03 -06 03-07 03 -08 03 -09 03-10 03-11 03-12 03-13 03-14 03-15 WOC. RIH w/ 12-1/4" bit & scraper to 2150'. C&C mud. POH. RU Dialog & ran 13-3/8" caliper 2150'-surf. RIH w/ pkr & tstd 13-3/8" csg. Tstd to 1500~--hole in 13-3/8" csg @ 642'. POH. R IH & set cmt rtnr @ 630'. Pumped 440 sx C! G neat cmt in 5 stages--would not hold press. WOC between stages. Staged cmt into hole @ 642'. Sqzd hole w/ FP of 1700#. Pul led out of rtnr & rev c irc out 18 sx cmt. C irc & POH. WOC. RIH w/ 12-1/4" bit & scraper. POH. RIH w/ pkr & located holes in 13-3/8" csg ~ 387' & below 532' (holes from previous testing between 535'-577'). POH. RIH w/ cmt rtnr & set @ 522'. Mixed 200 sx C I G cmt ~ 16+ ppg. Pi holes below 522'--no press. Began staging cmt into holes be Iow 522'. Staged cmt into holes below 532'. Mixed 200 sx CIG cmt 16 ppg. Pumped 150 sx. WOC. Staged 20 sx cmt into holes w/ press incr to 200 psi. Pul led out of rtnr & rev out 30 sx cmt. Circ hole clean & POH. WOC. PU rtnr & RIH to 370' & set rtnr. Mixed 200 sx CIG cmt. Pumped 150 sx into holes below 387'. WOC. Staged 15 sx cmt into holes w/ press i ncr to 2000 psi. Pul led out of rtnr & rev out 35 sx cmt. Circ & POH. WOC. WOC. RIH to 369' w/ 12-1/4" bit. Drld 1' hd cmt & cmt rtnr. Fin drlg rtnr ~ 370'. Drld cmt from 373'-426'. CO to rtnr ~ 522'. Tstd 13-3/8" csg to 1000 psi--OK. Drld rtnr 522'-526'. Drid hard cmt 526'-576'. CO to rtnr @ 630'. Tstd 13-3/8" csg. P! holes 532'-577' w/ 450 psi. POH. RIH w/ rtnr & rtnr prematurely set ~ 219'. POH. RIH w/ 12-1/4" bit. Drld 16" or rtnr & pushed rtnr to 604'. POH. WO cmt rtnr. RIH w/ cmt rtnr & set ~ 500'. Mixed & pumped 300 sx CIG cmt. After 50 sx, 13-3/8" x DP annls press up. Closed pipe rams & pumped 250 sx cmt w/ 700 psi ann ls press & 300 psi DP press. PU & rev circ--no cmt rec. Circ hole clean. POH. WOC. Tstd BOPE. WOC. RIH w/ 12-1/4" bit to 498'. Circ. Tstd 13-3/8" csg to 750#--0K. Dr Id 2' cmt & cmt rtnr to 507'. Dr id cmt & cleaned hole to 627'. Tstd 13-3/8" csg to 750#--0K. POH. Chgd bit & RIH. Drld rtnr junk from 627'-630'. Fin drlg rtnr 630'-633'. Drld cmt rtnr parts to 702'. RIH to 2150' & circ hole clean. Tstd 13-3/8" csg--pumped away @ 250~. POH. RIH w/ RTTS & located holes in 13-3/8" csg between 847' & 892'. POH. R IH w/ rtnr & set @ 755'. Mixed & pumped 300 sx C! G neat cmt. Staged last 50 sx. FP 575 psi. Pul led out of rtnr & circ hole clean. POH. WOC · WOC. Cleaned rig & mud tanks. RIH w/ 12-1/4" bit & 2 junk subs. Dr Id on rtnr set @ 755'. Dr Id rtnr from 775 '-778'. Dr Id rtnr parts & cmt from 804'- 887'. RIH to 2150' & circ. Tstd 13-3/8" csg. Broke dwn @ 400 psi. POH. RIH w/ csg scraper to 2000'. POH. RIH w/ RTTS & located leaks between 849' & 884'. POH. RIH w/ cmt rtnr. Set @ 745'. Mixed 300 sx CIG neat cmt. PI holes in 13-3/8" csg. Staged last 70 sx. FPP 710 psi. FSIP 475 psi. Pulled out of rtnr & WOC. Well History - TBU D-15RD2 Page 5 03-16 03-17 03-18 03-19 03-20 2399 ' TD 03-21 2881 ' TD 03-22 3972'TD 03-23 4353' TD 03-24 5120 ' TD 03-25 5590'TD 03-26 6000'TD 03-27 6000'TD 03-28 6000'TD 03-29 6000'TD 03-30 6310'TD WOC. Upgraded rig eqpmt. RIH w/ 12-1/4" bit & 2 junk subs. Drld rtnr ~ 745'. Drld cmt from 825'-880'. CO to 994'. Tstd 13-3/8" csg--no good. POH. RIH w/ RTTS & found leak from 844'-884'. POH. RIH w/ EZSV & set @ 735'. Mixed 300 sx CIG neat cmt & displ to rtnr. Staged 70 sx into holes over a 3-1/2 hr period. FP 700 psi & holding 700 psi. Pulled out of rtnr & circ hole. WOC. WOC. Cleaned rig & mud pumps. Tstd 13-3/8" csg above top of cmt plug w/ 500 psi--OK. POH w/ rtnr stinger. RIH w/ 12-1/4" bit & 2 junk subs to 735'. Drld on rtnr @ 735'. Drld rtnr @ 735'. Drld cmt 794'-888'. Tstd 13-3/8" csg to 350#--0K. RIH to 2146'. Drld junk & cmt to 2241'. Drld cmt to 2275'. Cleaned mud handling eqpmt. Displ hole w/ new mud. C&C mud. POH & emptied JB's. RIH w/ 12-1/4" bit & JB. Circ & POH. PU DD & BHA. R IH & RU steering tool. Attempted KO. Couldn't drill--junk under bit. POH. RIH w/ bit & JB. Drld junk & cmt 2275'-2280'. POH. RIH w/ 12-1/4" bit, DD, & direc BHA. Orient tools & kick off. Direc drld to 2399 ' · POH w/ DD. Tstd BOPE--OK. PU BHA & RIH. Tstd fm w/ 350#. Drld & surv to 2728'. POH. PU DD & orienting BHA. RIH to 2728'. Oriented tools & DD to 2881'. POH for new drlg assy. MU BHA. RIH to 2681'. Reamed 2681'-2881'. Drld & surv to 3972'. Drld & surv to 4035'. POH for new BHA. Drld & surv to 4308'. Tripped for bit #10 & drld to 4353'. Drld & surv to 4569'. POH & chgd BHA. RIH & reamed 4308'-4368'. Drld to 5120'. Drld to 5156'. Circ, surv, & POH. RIH w/ bit #13. Drld to 5590'. Drld 5590'-5606'. Circ & surv. POH for bit #14. RIH & drld 5606'-5890'. POH for bit #15. RIH & drld 5890'-6000'. C&C mud for logging. C&C for logs. Surv & POH. RU Schl & ran DIL, Sonic, FDT, & Neutron logs. RD Schl. RIH w/ 12-1/4" bit & drlg assy. C&C for 9-5/8" csg. POH. POH & LD BHA. RU to run 9-5/8", N-80 csg. Shoe @ 5994'; FC ~ 5912'. RU HOWCO & pumped 30 bbls wtr, 1000 sx CIG cmt w/ 1/2 gal/sk Econolite & 0.3% HR-6L, 400 sx CIG neat cmt, followed by 10 bbls wtr. Bumped plug w/ 2500 psi. Floats held OK. Cmt to surf. CIP @ 0615 hrs. CU cmt from surf eqpmt. Raised BOPE & set 9-5/8" csg si ips & cut off 9-5/8" csg. WOC & chgd & tstd BOPE. PU 8-1/2" bit & BHA. RIH. Fin R IH. Tstd 9-5/8" csg to 2500~#--0K. Dr Id FC & cmt from 5910'-5858'. Tstd to 2500 psi--OK. Dr Id cmt & shoe from 5958'-6000'. Drld to 6020' & C&C mud. Conducted leak-off test. Fm took fluid @ 13.6 ppg equiv. Drld to 6092'. POH & chgd BHA. R IH & reamed 6010'-6092'. Drld to 6310'. Well History - TBU D-15RD2 Page 6 03-31 6513'TD 04-01 6640 ' TD 04-02 6733'TD 04-03 6988 ' TD 04-04 7365'TD 04-05 7626 ' TD 04-06 7819 ' TD 04-07 7990'TD 04-08 8331'TD 04-09 8614'TD 04-10 8788'TD 04-11 8954'TD 04-12 9117'TD 04-13 9315'TD 04-14 9575'TD 04-15 9712'TD 04-16 10,122'TD 04-17 10,372'TD 04-18 IO,400'TD Drld 6310'-6429'. Circ & surv. POH. Observed slight mud flow. RIH w/ bit ~17 to 6429'. Circ & built MW to 10.4 ppg. SI BOPE to check press--had 25# on csg & DP. Circ. Drld 6429'-6443'. Built MW to 10.5 ppg. Circ. SI BOP's--checked press--OK. Drld 6443'-6513'. Built MW to 10.6 ppg. Hole OK. Drld to 6640'. Checked well--had slight mud flow. Mud wt 10.6 ppg. Built MW slowly to 11.7 ppg. C&C mud for 18 hrs. Still have slight flow. Will incr MW to 12.4 ppg. Built MW to 12.2 ppg. PU to csg shoe & monitored flow. Well back flowed ~! 2.5 BPH. RIH & washed 6610'-6640'o Drld 6640'-6664'. PU to csg shoe & monitored well. Well back flowed ~ 2.5 BPH--steadily decr. RIH & washed 20' of fill. Circ, checked mud, & surv. No chg in MW. POH. RIH w/ bit ~18. No pit gain, no gas during trip. Drld 6664 ' -6733 ' · Drld 6733'-6988'. Circ & surv. Tripped for bit #19. RIH. Drld w/ bit #19 6988'-7365'. Circ & surv. POH. RIH w/ bit ~20. Washed 60' to btm--no fill. Drld 7365'-7626'. Drld 7626'-7678'. Circ & surv. POH. RIH w/ bit #21 to 6000'. Checked well for flow--no flow. RIH & washed 7648'-7678'--no fill. Drld 7678'-7819'. POH. Fin POH. Tstd BOPE. RIH w/ bit #22. Drld 7819'-7990'. Surv & POH. RIH w/ 9-5/8" csg shoe. Checked well--no flow. RIH to 7990'---no fill. Drld w/ bit #23 from 7990'-8331'. Drld 8331'-8414'. Circ & surv. POH. Checked rig eqpmt. RIH w/ bit #24. Reamed 8384'-8414'. Drld 8414'-8614'. Drld 8614'-8686'. POH. Chgd bit & BHA. RIH & reamed 8656'- 8686'. Drld 8686'-8788'. POH. RIH w/ bit #26. Fin RIH w/ bit ~26. Reamed 8758'-8788'. Drld 8788'-8954'. Circ & surv. POH. RIH w/ bit #27. Fin RIH w/ bit #27. Drld 8954'-9084'. Circ & surv. POH. Chgd bit & RIH. Reamed 9024'-9084'. Drld 9084'-9117' w/ bit #28. Drld 9117'-9280'. Circ & surv. POH. RIH w/ bit #29. Reamed 9250'-9280'. Drld 9280'-9315'. Drld 9315'-9575' w/ bit #29. Drld 9575'-9696'. Surv & POH. Tstd BOP & RIH. Reamed 9636'-9696'. Drld w/ bit #30 from 9696'-9712'. Drld from 9712'-10,122'. Drid 10,122'-10,180'. Surv & tripped for bit ~31. Drld 10,180'-10,372'. Drld to 10,400'. Circ for logs. Surv & POH. RU DA & tstd lub to 2500#. Ran DIL/SP & Sonic/GR logs. POH w/ Sonic too I . Well History - TBU D-15RD2 Page 7 04-19 IO,400'TD 04-20 IO,400'TD 04-21 IO,400'TD 04-22 10,400 ' TD 04-23 IO,400'TD 04-24 IO,400'TD 10,292'PBTD 04-25 IO,400'TD 10,292'PBTD 04-26 IO,400'TD 10,292'PBTD 04-27 IO,400'TD 10,292'PBTDBTD 04-28 IO,400'TD 10,292'PBTD 04-29 IO,400'TD 10,292'PBTD 04-30 IO,400'TD 10,292'PBTD 05-01 IO,400'TD 10,292'PBTD 05-02 IO,400'TD lO,292'PBTD Fin POH w/ Sonic tool. RIH w/ Density/Neutron--tool started sticking. POH. RIH w/ bit. C&C mud. POH w/ bit to log. Fin POH w/ bit. RU DA & tstd lub to 2500//. Ran DIL/SP, Neutron/Density/GR, & RFT. RD DA. RIH w/ bit. Circ from 10,400'--no fill. POH. RU csg handling tools. Ran 4623' of 7" Inr on DP to 10~380'. (Top of 7" @ 5650'; shoe ~ 10,380'.)~4' Circ csg Inr for cmtg. Circ csg. Dropped shear ball & pumped dwn. Tstd cmtg lines. Pumped 30 bbls wtr, 500 sx CIG w/ 0.3% HR-6L, 1/2 gal/sk Econolite, 1/4 ///sk Flocele, 500 sx CIG w/ 0.4% Halad 22A, 1% CFR-2, 3% KCI & 1/4 #/sk Flocele, 10 bbls wtr. Displ w/ 270 bbls mud. CIP ~ 1100 hrs. Pulled out of hgr 10 stds. Circ wiper plug dwn DP. POH. WOC. WOC. RIH w/ 8-1/2" bit. C&C mud to 5676'. Drld cmt stringers & cmt from 5676'-5736'. Tstd Inr lap to 2400//. POH. Tstd BOPE. PU 6" bit, 7" scraper, & 4-3/4" DC. RIH to top of lnr. Circ to 5770'. Tstd csg w/ 2500//. RIH to 10,292'. C&C mud. Tstd csg to 2550//. POH. RIH w/ 9-5/8" csg scraper to 5736'. POH. RIH w/ DST tools, 2500' wtr cushion. Set pkr @ 5701'. Opened test tools--had light blow for 15 rain, dead for 5 min, light blow for 40 min. Closed tool after 1 hr flow period. ~OH. Had 180' fluid rise during 1 hr flow. DST press: IF=1114 psi; FF=1162 psi; 2 hr S! 3935 psi. R IH w/ 7" RTTS to test 7" Inr to 3500#--0K Lap leaking si ightly. POH. R IH w/ 9-5/8" EZSV rtnr. Spotted wtr below rtnr. Closed pipe rams. Started breaking dwn Inr lap w/ wtr. Attempted to break dwn 7" Inr lap. Got 2 BPM rate w/ 4000// surf press. I ncr press to 4075'. 9-5/8" csg broke dwn. Set rtnr & POH. RIH w/ RTTS to locate leak. Leak between 2153'-2618'. Located leak in 9-5/8" csg between 2309'-2315' & POH. RIH w/ 8-1/2" bit. Drld rtnr ~ 5717'. POH. RIH w/ 6" bit. Drld & pushed rtnr junk to PBTD. Circ hole clean. C&C mud from 10,292'. POH. RIH w/ BOT lnr tie-back slv polishing mill. Wouldn't go into Inr. POH. RIH w/ tapered mill. Milled junk on top of Inr. POH. RIH w/ BOT polishing mill. Polished Inr tie-back slv. POH. Fin LD 5" DP. Set RBP ~! 202'. ND BOPE. Instld 7" csg hgr, NU BOPE & tstd. Pulled RBP. R IH w/ 7" 29//, N-80 tie-back csg to top of hgr ~ 5756'. Circ prior to cmtg. Circ 7" csg. Cmtd 7" tie-back w/ 400 sx CIG w/ Flocele & 150 sx CIG neat, 15.8 ppg. Stabbed into tie-back slv& set 7000// on slv. Bled off press--no flow back. CIP ~ 1057 hrs. Set slips & cut csg. RIH to top of cmt @ 5674'. WOC. WOC. Drld plug & firm cmt from 5674'-5765'. POH. RIH w/ csg scraper to 5800'. POH. Tstd 7" csg against blind rams to 3000#--OK. RIH w/ bit PU 3-1/2" DP. Fin RIH w/ DP to 10,276'. Circ & POH. RU Schl & ran CBL. Running gyro. Well History - TBU D-15RD2 Page 8 05-03 IO,400'TD 10,292'PBTD 05-04 IO,400'TD 10,292'PBTD 05-05 IO,400'TD 10,292'PBTD 05-06 10,400'TD lO,292'PBTD 05-07 IO,400'TD lO,292'PBTD 05-08 IO,400'TD 10,292'PBTD 05-09 IO,400'TD 10,292'PBTD 05-10 IO,400'TD 10,292'PBTD 05-11 IO,400'TD lO,292'PBTD 05-12 IO,400'TD 10,292'PBTD 05-13 IO,400'TD 10,292'PBTDTD Fin gyro surv & tstd BOPE. RIH & dspl to FIW. POH. RU Schl & ran TDT log. MU pkr & RIH w/ DP. FIH. Set pkr ~ 9520'DPM. RU SOS & tstd lub. Perfd B-4 from 9960'-9995'DIL w/ 4 HPF. Attempted to inj FIW--no inj. ~eoerfd B~. Attempted to inj--well would not take wtr. ~erfd B-5_in 3 runs from 10,030'-10,118' w/ 4 HPF. POH after perfg. ~ Attempted to inj FIW w/ 3950 psi--no rate. RU Halliburton & attempted to inj. At 5800 psi, well took 6 bbls in 35 min. Perfd B-l?~6~7~!-_969~8'DLL. Inj w/ Halliburton @ 5850 p~i~'~-u-mped 28 bbls @ aver rate of 2/3 BPM w/ press incr to 5850 psi. SI well WO acid. RU Dowel l & tstd surf lines to 7000#. Spotted acid to end of DP. Pumped 500 gals 5% HCI, 2000 gals 12-6 Mud Acid, 500 gals 5% HCI followed w/ FIW. Final rate 0.75 BPM @ 4000#. Released pkr & RIH to 9800'. Circ. Set pkr & inj into B-4 & B-5 @ 1/3 BPM w/ 5800#. SI well WO acid. RU Dowel I. RIH & spotted acid across B-4 & B-5. Set pkr & acidized B-4 & B-5 w/ 750 gals 7-1/2% HCI, 2000 gals 12-10 Mud Acid, 750 gals 7-1/2% HCI. Final rate 1-1/2 BPM ~ 2800 psi. Set pkr ~ 9520' & inj w/ platform system--meter failed. Set pkr @ 9800'. Inj into B-4 & B-5 w/ Dowel l @ 1.7 BPM ~ 4000 psi. Set pkr @ 10,018'. Inj into B-5 @ 0.33 BPM w/ 4200 psi. Set pkr ~ 9520'. Inj into B-l, B-4, & B-5 w/ platform system @ 1.7 BPM @ 3750 psi. Inj FIW into B-l, 4, & 5 @ 115 BPH @ 3400 psi. RU SOS, test lub. RIH & ran tracer & temp surv. Survs indicated 100 BPD into B-l, 300 BPD into B-5 & remainder entering upper part of B-4 perfs & going up into Benches 2 & 3. POH. RIH & perfd 4 holes for sqz from 9860-9862'. Set pkr @ 9893'. PI sqz perfs dwn annls ~ 2 BPM w/ 1900 psi. Released pkr & rev circ from 9893'. Rev hole clean. POH & LD pkr. Set BP ~ 9878'. Set rtnr @ 9793'. Sqzd perfs ~ 9860'-9862'w/ 50 sx cmt. Rev out 1/2 bbl, 2-1/2 bbls in csg, & 7-1/2 bbls thru sqz perfs. CIP @ 2330 hrs, 05-04-80. WOC 5 hrs & POH w/ DP & stinger. RIH w/ 6" bit & drld up rtnr @ 9793' drld firm cmt to 9862' & CO to 9876' POH. Fin POH. RIH w/ Baker Retrievamatic pkr & set @ 9799'. Tstd sqz perfs 9860'-62' to 4000#, bled to 3000# in 5 min; to 1500# in 30 min. Press to 4500#, bled to 3300# in 5 min; to 1500# in 30 min. Set pkr between sqz perfs & BP, held 4000# firm. Set pkr @ 9799' to breakdown. Estab rate w/ max of 6000~, max PI rate 2-1/4 bbls in 30 min. Spotted 6 bbls HCI & PI sqz perfs. Pumped 35 bbls FIW ~ 0.8 BPH w/ 4000-4350#. POH & LD pkr. RIH w/ rtnr. RIH w/ rtnr & set ~ 9791'. Mixed & pumped 100 sx CIG neat w/ 0.3% Halad 22A, 1/2% CFR-2. FP 5400#. CIP @ 1130 hrs. POH. WOC. Tstd BOPE. WOC. RIH w/ bit & drld rtnr & hard cmt. POH. RIH w/ pkr & tstd sqz perfs to 4050~--0K. PU to 9512' & inj into B-1. Short term rate of 3/4 BPM w/ 3800#. POH. RIH w/ bit & junk sub. Well History - TBU D-15RD2 Page 9 05-14 IO,400'TD 10,262'PBTD 05-15 IO,400'TD 10,262'PBTD 05-16 IO,400'TD 10,262'PBTD 05-17 IO,400'TD 10,262'PBTD 05-18 IO,400'TD 10,262'PBTD 05-19 IO,400'TD 10,262'PBTD Drld BP @ 9878' & pushed junk to 10,262'PBTD. POH. RIH w/ bit & scraper to PBTD. Rev hole clean. POH. RIH w/ Retrievamatic pkr. Set pkr @ 9512'. Inj into B-l, 4, & 5 @ less than 500 BPD w/ 3750#. Set pkr @ 10,010'. Pumped 1000 gals 7-1/2% HCI, 4000 gals 12-10 Mud Acid, 1000 gals 7-1/2% HCI into B-5 ~ 1/2 BPM w/ 4750#. Press dropped to 3100# after 400 gals 12-10 into perfs. Incr rate to 1BPM @ 3400#. Displ acid @ 1 BPM w/ 3400~ & 1.2 BPM w/ 3800~. SD pump. Press decr to 3000~ in 30 min. Bled press & released pkr. Rev circ--no acid in annls. Set pkr & attempted to inj w/ platform system--meter would not record rate. Pumped 25 bbls w/ Dowel l @ 1/2 BPM w/ 3750~. Released pkr. RIH to 10,251' & rev hole clean. PU & set pkr ~ 9520'. RU SOS & perfd B-4 from 9890'-9960'DIL w/ 4 HPF. RU to platform inj system & i nj w/ 3750#. Meter wouldn't record rate. RU SOS & RIH w/ inj logging tools. lnj FIW @ 1390 BPD w/ 3750~. Ran inj profile. B-1=450 BWPD; B-4=190 BWPD; B-5=750 BWPD. S! well & ran 1 hr & 3 hr temp survs. No indication of fluid entering B-2, 3, or 6. POH & RD SOS. Rev hole clean & POH w/ DP & pkr. RU SOS to run gauge ring & JB. Tripped gauge ring & JB. RIH & set Otis WD pkr ~ 9500'DIL. RD SOS. RU & ran downhole compl assy & 4-1/2" SL tbg hydro testing & drifting. Fin running 4-1/2" tbg hydro testing & drifting. Spaced out tbg. Displ annls w/ treated FIW. Landed tbg & ND BOPE. NU Xmas tree. Fin instlg tree. Removed BPV. Released rig ~ 1200 hrs~ 05-18-80. FINAL REPORT per r -sun d A Fouch~ President Mr. Cum~is Dowden ~rathon Oil Ccmpany P. O. Box 2380 Anchorage, AK 99502 May 8, 1980 Re: Our Boss Gyroscopic Survey Job No. Boss-16579 Well D-15 RD #2 McCarthurRiver Field Cook Inlet, Alaska Date of Survey: May 1, 1980 Dear Mr. Dowden: Please find enclosed the "Original' and four (4) copies of our Boss Gyroscopic Multishot Directional Survey run on four dlfferentmethods. Included in the four methods are Radius of Curvature, Average Angle, Tangential and Trapezoidal. Thank you for gmvlng us this opportunity tobe of service. ~.V/'kc Enclosures Yours very truly, SP~,RY-SU~ INC. Doug Walker Senior Survey Engmneer RECEIVED ,~'~'~ i'~ ~. 0 1980 ~ Alaska 0t~ & G's ~,,m,~ ~.m,.msslon COnFIDEnTIAL MARATHgN OIL COMPANY TPU 0-15 ROll2 MCA~THUR FIVER FIELD DATE OF SURVEY VERTICAL SECTION DIRECTION ~GE 1 MAY 1 ~ 1gaff CLOSURE COOW INLET, ALASKA BeSS GYROSCOPIC DIRECTIONAL SURVEY SPERRY-SU N,~ INC, BOSS-1657~ TRUE SUB FEASURED VERTICAL SEA RECORD 0 CCURSE COU iNCLINATIGN DIRE F SURVEY RSE DOG-LEG CTION SEV TOTAL RECTANGULAR COORDINATES VERTICAL DE~TH DEPTH TVD r)EG PIIN BEG DEG/iO0 NORTH/SOUTH EAST/~IEST SECTION 975.15 1868.95 TIE ON AT 23OD FEET 116,85 N la8,33 W lq7,$0 2100,00 2066,61 19R0,/tl 22n0.00 P157,PO 2050,80 23C0.D0 22q7,lq 21a1,5a 2q ~5 N 54 W 1,89 lq0.96 N 25 53 N 54 W 1,la 166,10 N 23 52 N 62 W 3,8q 188,43 N 180.75 W 178,13 215.34 W 210.39 250.88 W 235,0.00 2293.77 2187,57 22 5 N 66 W q,90 196,99 N 26R.qO W 252 .aL 2aPf).OG 23aQ,30 223q,10 20 55 N 73 W 5.76 203.3a N 285,56 W 262,51 ?aSC,O0 2387,11 2280,91 2500.00 243q,20 2328,00 2550.00 2q81.51 2375,31 20 13 N 75 W 1.,71 20~.16 N 19 q N 75 W 2,30 212.59 N 1R q. 3 N 7q W .,80 216,97 N 302.45 W 271.01 318.66 W 278.99 33q,2~ g 286.77 26P0.30 2528.9R 2422.7R 17 5a N 75 W 1.75 221.17 N 27('P.00 262A.60 2518.qP 16. q N 75 W 1.83 22A.7R N 377.57 W 308.05 2750.00 2672,R6 2566.66 2F)Ctl. O0 2721,50 2615,30 285U.00 2770.36 266q.lG 14 lq N 66 W 5,75 233.10 N 12 3q N 52 W 7.23 23P,92 N 12 11 N 3q W 7,76 2q6,60 N :.'589,90 W 315,04 399.85 ~ 322.q6 407.1q W Pgrn.o0 2R19,30 2713.10 11 30 N 23 W 4.90 255.56 N 412.04 2~0.00 286R.26 2762.06 3090,00 2917,21 2~11.01 11 52 N 23 Y ,7A 264.88 N 11 38 N 23 W ,53 274.27 N 415,99 I,I 351.8q 419,93 W 361,9 ~lPC.OO 3015.16 2~8.9G 3?{~O.OO 3113.11 3006,91 11 37 N 21 W ,36 293.00 N 11 37 N 22 W .26 311.75 N q27.35 W 381.8a 43~,68 W q01.77 330S,00 3211.06 310z+, 86 3A. OO.O0 330R,99 32D2.79 11 39 N 22 W .09 330.q2 N 11 ~1 N 21 I~ .34 3~9,23 N 442.30 W a21,67 449,72 U q41.67 35CU,00 3q06.95 3,300.75 3790,00 3602.93 3~q6,7,3 11 32 11 27 !1 53 38on. OD 3700.90 3594.70 11 36 a57-18 W 461,56 46q,75 W 4R1 472.31 W 500-89 479,96 W 520.69 ~qPn.CO 3798.P7 3692.67 11 32 N 22 W ,07 4al,92 N anno,oo 3R96.85 3790,65 aln.n. O0 3q94.Pl 3R88.61 a2orl.00 4032.q0 3,qBG.7O nxnn_nn ~1ql .20 ~CPs.0rJ 11 32 11 39 10 46 10 2,'5, N 23 W .1¢ q60.40 N N 22 W .15 q78.96 N N 22 W ,R9 496.96 N N 2a W .47 513.90 N 495,1a W 560,22 502,R4 W 580,03 510.17 W 5q9,23 517.30 W 617.5~ T kUE tip E D. _ _V E El1 DE~TH DEPTH SUnV[ v '~PERRY= SUN, IN£. RECORD OF SURVEY ,qUU CCURRE COURSE DOG 'LEb SEA_ IhC L It,IhT InN DIRECTION REV TVD DEG MIN DEG DEG/103 DaTE OF SUPVFY VEFTICAL SECTION DIRECTION PAGE 1, CLqSIJRF TOTAL RECTANGULAR COORDINATES NOR TH/SOUTH E ~ST/~£ST BOSS-16579 VERTICAL SECTION 529.86 N 52q.55 5~o52 N 551,10 558,07 I', 536,91 571,q3 N 5~2,~6 585,25 N 5~7,~7 634.53 650.?~ 67q.[ 6q3.6~ 4on'~,O .r,r n ~.0 r,1 ~q 19 W N 2U W ,15 ': 21 W .06 ;4 19 W N 19 W 598.78 N 552.2a 611,79 N 556,9~ 62~.77 t,} 561.76 637.77 N 566,39 65O.g7 N 570.g3 707.9~ 721.65 735.3F 749.09 762.q° H 1° id ,12 664,23 t,, 575,56 N ],q W N 17 W .r~2 N 17 W .~.~ N 16 W .13 677,32 ~; 579,9Q W 690,7P 1'4 58~,12 W 704.65 N 5gE,3fl W 718.50 $', 592.3q. W 776.9~ 7~ ~ . GR ~19.1~ 833 1~ W .16 13 W .~.0 1n W 13 W 732,_q_.6 ~: 5q6,27 W 745.97 N 5q9,68 W 759,31 N 6,02.33 W 772,58 ~' 60~,96 W N 8 W ,76 7B5.05 N 607,,21 W a62.G 875.61 9C1.7a aDh. D0 ¢ 26c~.72 A163.qF 6 b6 5.r n.n~ r, 36, g.O 2 6262.~2 -~, ~3 f ~?.00 046~.31 6362.11 F. 5q 7' ¢,00 L567,52 6461,32 7 2P POC'. O0 6666.75 6560,55 G 4R N 1 W . Pq t,; ....... 2 E N 8 E N 16 E 1.17 797.1R N 60~.12 W s~i.-P:-'o E--~ --6o 7.9 7 w 820.90 N 657.~2 W ~33.33 N 606.22 W ~,~5.~G N G03.70 W ~13.~0 925,3q ~8.5~ W 15 E N 1° E .62 ", 2p E .32 857,64 N 6nn.45 W g70.oq T RUE ~ iJt~ PEP IH n, FP TH TVD SURV kY DATE OF qURV~Y VEPIIC~L SECTIOh DIRECTION PAGE CLO ~ ,~tlRE RECOPD OF SURVLY CCUDSF COURSE DOG-LEG I NC_L I~! A T IO~ ..... p_ I_5 E_ C__T__ I_O_ N SEV DEG HI~ DEG OEG/1DU T [iT AL RbCl ANGUL/~R Cr'ORD INATES NOR TH/SOUTH EAST/WEST BOSS-1657'J VERTICAL SECTION 8 24 823 R '"5 b' ~O E ,Ag N 2",., E .r4 N 2° E N 32 E .3a 92a.a3 N 57g,10 937,71 N 972,78 b50.78 N 566,33 963.q9 N 559.14 97A.17 N 551.57 10q2,Tt~ 1 054._0~.~ 1_D64. , ,, 1075.4~ POCC. p~nr. 00 .... 3_7.55_._~ ? ..... Z 6~._~_,~_? .......... O0 7~54.5q 77/*8.34 O0 7q53.a5 7847.25 O_v ....... 8 0 5 L,_3_6 ....._7 9_5.5_._1 6 ........... O0 H151.25 80~5.05 1_7 N 23 N .SP' N 33 N 7 '7 35 E .33 37 E .29 ql E .39 PSt.~. P 7_TJT. PP,~ 'e N 44 L .22 N q6 E .5 Z N ag E .43 I_~LG,_Y_6__N qga,2~ 1 $57,q7 ~.l q8,7.74 1(69,93 N ~7&.70 ~t?O. 22 N 465.31 1091.27 r.: 453.77 1_!32,17 1140,72 llqq. O" 1157.34 1165.50 q 5u 9 31 R q7 N 4g E , ~2 N 91 E ,87 N 5(' E .2q N 52 E ,38 1_102.39 N 4ql,55 W 1113,A9 N 429.12 W l12a.lO N AlT.lO W 11~3,7~, N a05,51 W L173,~_~_ 11~1 ll~q,21 11q5,99 11/43.16 N 393.R4 W 1202.5' q/4 rl P, o ,=, ," ,* · 0 afar r,. C, 0750,0 4336,59 q23r,.sq ~ 51 qq35,ql 9329.21 '45'~q. 25 942P,, OS g 41 4635.13 9526.95 k 29 N 5.'5. E .75 N 53 r .13 N 5t~ E N 57 E .49 1 152,1H N 1161.26 llTr). ~9 ~' 1 179./48 ll~7.ql 382.35 W 1208.73 37'J ,72 W 121~,q5 358,47 W 1221,1P 346,21 W 1227, 333,91 W 1232.62 N N N 5~, E 61 E ,,.. 1195,78 N 321.~7 W 1237.q,' 1203,36 N 121C.53 fl l~17.aO N 121°.03 N 309.25 W 12~2.10 297.07 W 12t~6.3~ 2gq.DO W 125',.31 2H2.2/4 W 12r"l.PP ~rap'rHUR RIVE~ FIELD DATE (DF SIIRVEY MAY VLRTICAL SECTIUN DIRECTION rAGE CLOSURE C.FOK INLET, ALASKA [':oSP GYRuqCOPIC DIRLCTI¢'t~aL SI]RVEY SP[RRY-~UN, INC. RECORD OF SURVEY [~, gSS-1657~ ** THE C~LCULATIuN$ ARE RASED ON THE MINIMUM RADIUS OF CURVATURE METHOD ** ltORI_7ONTAL DIS, PLACEMENT = 1251.2H FEET AT NORTH 1~ DEG. 2 MIN. WEFT S~-Ai~T OF SURVEY WAS 1PF,.2O FEET ABOVE SEA LEVEL Tr't~ r-15 qr'j,? 6oo~ ]NLFT, ALAeKA BOSq GYROSCOPIC DIRELTIqFAL StlFVEY RECORD OF CnLIF, SF COURSE DOG-I. EG INCLIhATION DIFECTION SEV DEG MIN DEb DEG/IO0 DATE CF F, URVFY VFklICAL S[£f~ 6N--Fi]R-E-~-TIO'N MA Y AGE 1 1, lUSC CLOSURF BOSS-1657q TOTAL k L CT A N btJ-[-A ¢~ C OOPDI,*~ATLS NORTH/SOUTH EAST/WE'~T VEPTICAL SECTION 1~75.15 1¢468. q5 2966.61 1 96rJ. a, 1 2}O O.OO PPq 7.71 21~1.51 235r'.0 [, 22q3.7q 21~7.54 TIE ON &T 2~ ~+5 N 5~ W 25 55 N 5a 23 52 fl 62 '~ 2 5 ~ 66 W 116,85 N 14P.'3.. 1,9~% lqI,17 N 180.59 1,14 166,31 N 215,18 ,3.Rq lPg.lq N 2%[I.70 fl,qO 197,1q N 26R.29 147.2~* 178.24- 210.~'~, 2~9,. 252 · 5~ 55 N 7"., 1 3 ~,' 75 W q N 7~ W ~+3 N 7a ~ 5~ N 75 W 5,76 203,5~ N 285.SP W 1,71 20F,36 N 332,27 W 2,30 212,79 N 31g.~ k' .RO 217.17 N 33~.06 V 1.75 221.37 N 3~..20 W 2.62.62 271.12 279.10 2q~.3H 16--t~ N 75 W 1~ 18 N 66 W ]2 3~ N 52 W 12 1 1 f! 3~ W 11 38 N 23 W 1.R3 22H.mR N 37 ?.3g 5.75 233.30 N 389.72 7.23 239.12 N 3rig. G7 7.76----246.~{J J~J a06.95 2'55.75 ~,~ ~ll.P, 5 W 3000.00 2917.12 Xl C'~. 0(, 3015.37 q3r'r,O0 3210,97 2810.92 ll 38 N 23 W 290,q.ct7 !1 37 N 21 W 3 '3'~6.82 11 77 N 22 W 31fl~.77 11 3c N 22 W 30~.lq 315.1~ 323.35 5'32.'17 3~2.q0 351 .~ 362.. 3~1.93 4Ol.a5 ~2 1 .76 35¢ fi. O0 3q 06,8F) 36CC.00 35UA,RE 3202.71 11 ~-1 N 21 N 3900.66 11 32 N 23 W 3398.65 :ll 27 N 22 W 54°6.6~- 11'-~'~.,~ N 23 W 359~.6] 11 36 N 22 W 37"P.OU 3602.A5 3ROI .0£ 3700.Pl . ~4 .~-4~-4-~ N 449.5~ W 4~41 · 75 · q5 36P.11 N q56.99 W ~61.Gq · 2D 386.54 N 4fi~.56 W a~l. Sq .lq 4Oq. O8 N ~72.13 W · 13 42~.54 N ~7q.77 W 520.77 · lq 466.59 N 4~q.-~5 W b6t.l, .15 479.15 N 5,'P.¢% W 5~'c.!1 · q7 534.~'3 N 517.11 W 617.a1 F~PATHON OIL COf~PAhv T~U n-15 RD,~2 CnOK INL[T~ ALASK~ DA'rE OF SURVFY V-E_F'rT]~S-A'[--S-. E CTTC~IR E C T I ¢,~ POFS GYROSCOPIC DIA[CTIOHGL SIJRVt Y TRUE SUB CG ME A S UREa-"-- VF_R T ICAL '~E-/~-' ' INCL DEPTH DEPTH TVD DE' -- ~PE'RR Y- eUN ;-INC. RECORD OF SURVEY U~ .gE CbURSE DOG-LEG I r,;-A-t i ("~ D I1TECTI-O-N ...... SEV'" G MIN DEG DEG/IOO T " RECTANGULAR~ NORTH/SOUTH NA¥ PaGE BOS$-16579 OTAL COOPDINATES "' V'E~TIcAL EAST/WEST %ECTIO~; a7P ", O0 4586,11 q47v,31 ape '~,00 q685,02 4578,82 9 q7 N 25 W R 42 N 2'5 W 1.15 fq 15 N 24 W .47 P 21 N 21 W-- g 36 N 2,'" W °28 52~+,36 W 6~.nq - 530.91 W 650.3r- 536.72 W 542". 1'? 5q7.2~ U 693.73 5P O .n, 00 4R83,02 510n,O0 q~.2,06 ff'p p r., 0 O 5S 81 · 10 53"~.DO 51Pti.12 N 19 W t,t 20 W ,15 N 21 W N 19 W N lq W ,24 5q8.9~ 611.99 624 .q6 ~37'.9-~ 651.17 552.09 556.75 W 721.72 561.5R W 735.4q 566,2 i--W '" 749.16 570,7~ W 76~.n~ c~.nr,cO 5675.0g 5172.73, ~ 1 5271.qP, 7 51 5379.'~F 8 21 5469.~2 8 1q 5568 .R~ R 16 N 1'~ W · 12 N lr~ V .P 6 N 17 U ,52 N'" 17 "W .ui N 16 W ,13 66q,43 N 575.37 ~ 777.ol 677.52 N :,79.75 W 790.75 690.97 N 583.93 W R(IA.PS 7'04,'85-~' 5gg'.ll" W R19.~6 718.69 N 5q2.16 W R33.6~, 5667,82 ~ 25 5766. ~4 7 36 5R~,5.?1 g 3 5 '? 6 ~ .'~'-~ ......... 7-"3'~ 6064.1P 7 4 N 16 W N 13 W .~O N lO W .59 N 8 W 732 .g~ ~l 7q6.16 tJ 759.51 N 772.'7'8' 'N 785.2q N Gl12.15 W R75.6~ 60~',77"W a89;P3 - 607.02 W gO1.SS 6163.q4 6 56 6262.7,~ C 43 63F2.,ri 2 6 5A 6q61.;'4 7 28 6560.46 6 4P N --]---Q .-A-4 N P E N 3 E 7cjT. 37 ~l 607.94 W 913.R,B 809,25 N 607.79 W 925,fl] 821.09 N 607.24 W 936.R'~ 833.52 N 60~.03' g ~.67---- R45,66 N 603.51 'W 95g,q2 N 16 E 1.17 7 4] 7 55 N / 5~ N 1~ E .91 ]5 E 1~ iL 2-1'--r_ 26 E .32 f,/!PATHON OIL COMPANY TBU D-15 ROff2 MC~THUk PIVE~ FIELD COOK INLFT9 ALASKA ,P, OSS L, YROSCOPIC DIRECTIC,~AL SU PV FY TRUE SUB COURSE SPEPPY-SUN· INC. RECORD OF SURVLY C£,URSL DOG-LEG MEASURED VERTICAL SEA INCLINATION DFPTH DEPTH TV[} DEG MIN DIRECTION SLV DLG DEG/ICD DATE OF ,SU~VLY VL~'J-~-CAL %ECTI(~N DIR~'-~TIr)N MAY 1 · lgAr~ CL(,S TM UR;. ROSS-1657'~ TOTAL RECTANGULAR CL, ORD IN'AT['S ' NORTH/SOUTH E A ST/WEST · VERT I CAL SECT IOlJ 7qro.(}O 7269.R6 7t5~.66 R 3 75~.0G 7359.83 7253.63 R 769r.C0 7~5P.76 7352.56 77{"[.C0 7557.6R 7qSl.qH R 25 7,q n 'l. 00 7656.59 7550.3q 8 35 N 20 L N 23 E ,5~ N 29 E .~B 92~.63 ~ 577.92 937.90 N 572.59 950.97 N 566.1Q 963.69 N 55P.95 976,38 lq 551,~P N ~ F N 32 L lO31,Dq lOq2,P& 105~.,~.~ 10A~. 1075.53 N 33 E · 36 N 35 E · 33 N 37 E .29 988.76 N 5q3,52 1000,75 N 535.38 1012-59 N 526,71 1085.B2 1995.66 1105,25 ~20P,O0 8052.27 7g~+G.O T R 50 ~300.00 8151.16 ROaq.9~ g 33 N 3q E ,21 N ~] E .39 102q,27 N 517,65 1635,66 N 508-16 lllQ,5~ 1123.5a N a~'3 E N ~q E .22 N 46 E ,53 N a%"-_ --E' . lg " 1132,77 llqO,R3 11~+9,11 1157;45 11~5,61 91 N ~ ~ E .6-5 N qR E ,32 N 51 [ ,87 N 50 E .~-4 N 52 E .38 1173.~ - 11~1. 1189,.33 ' liq6.11' 1202,66 96ri,r,. OD qT~q,OO mPrO,O0 q336,50 923n,3v 8 51 9q35.32 9329,12 8 fl8 o633.6~ 9526.R4 8 29 51 E °58 53 E ,75 53 E .13 1 ~-~2-, 37 N .%82'16 1161,~5 '"1 370,53 1170,69 N 35P,28 5a E ,16 ~7 E .t49 117q,67 N 3q6,03 W 11~8,11 N .333,72 W 12DA,PA 1215, 0~. 1221,31 1 227,31 1232.75 10?nD.CO 102cn,GG ~731.95 9625.75 R 27 8 5 [~ 10 7 ~*~ 6 56 9,830.91 q72a,.71 9q. 2o,qo 'q~23.7n b 02 P.,-')3 ....... 9':~22,73 br,53.73 9':'q7.53 N 58 E .18 N 5~ E A1 E .~1 N 59 E 1i95,98 N 321,2P. 1203,56 N 309.06 1210,73 N 296.Sg 1 217; g-~--k' 2-W4-,-A-2--~-- 1219.22 N 2a2,05 12~'7.62 12~2.25 1 2aG.',q 1251.AP MAPATFtON OIL COMPANY ,'rHu D-Z5 RDt~2 ~,'d~R THUF, R ik/~-~'-fltZL-~/~-' _r.l"O~ INLrT~, ALASKA POS? GYROSCOPIC DIRECTIONAL SURVEY bATE OF qUD Vt]Y V EFT I CAL--S-[ CT I O~ DIRECTION P/~GE MA Y l ~ CLnSUPE BOSS-1657'~ SP FRRY-SUN~, INC, RECORD OF SURVEY ** THE CALCIILATIONS ARE BASED ON HORIZONTAl. DTSPLACFMENT : THE TRAPEZOIDAL OR AVG, FUNCTION 1251,A2 FEET AT NORTH 13 DEG, 2 OF ANGLES METHOD MINo WEST CTRUE STAF~T OF SURVEY NAS 106,20 FEET ABOVE SEA LEVEL M~/~THON IL COMPANY TBU D-15 ~Dff, 2 MCAPTHUR RIVER FIELD DATE OF SURVEY VERTICAL SECTIDN DIRECTION PAGE MAY 1 e 13AO CLOSURE COOK INLET,~ ALASKA PO$S GYROSCOPIC DIRECTIONAL SURVEY SPERRY-SUNv INC, BOSS-16579 TRUE SUB MEASURED. . Y.ERTICAL ..... ~]~A DEP TH DEPTH TVD RECORD OF SURVEY COURSE COURSE DOG-LEG ,,, INCt._INATION DIRECTION SEV DEG MIN DEG DEG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 20t~.0.00 _ 19.75,15 .., 1R68.95 TIE ON AT 2000 FEET 11G,85 N 1A8.33 W 1A6.0P 2100,00 2065,96 1959, 76 24 PPOP,O0 2155.93 20A9,73 25 P~PO,O0 .......... 2247,3~ 2141,18 23 45 N 54 W 1.89 53 N 54 W 1 52 N 62 W 1~,1.52 N 182.15 W 167.12 N 217.51 W 186.18 N 253.20 W 177.47 210.0.~ 2,36 2350,00 2293,71 21~7.51 22 5 N 66 W 4.90 193,77 N , 270,40 W 247.:~1 2400v00 234'L, 4'2 223~.22~ . ;..O 55 2~50,00 2387.34 2P~1.14 20 13 PSPO.DD 2434,60 e3es.~n 1~ ~ ... 25~,00 2481., 05 2.375.75 18 Q3 P6n~,O0 2529.53 P~23,33 17 5~ N 73 ~ 5.76 198,87 N 287.51 W 256,18 N 75 W 1,71 N 75 1,/ 2,30 N 75 W 1,7 5 203,41 N 304,18 207.74' N 314,93 212,17 N 335,35 264,20 271.R3 279.4R 216.14' N 350.20 W 286.56 ..... 27P10, 0,10 2625.62 2519.q? 16 q 2750,00 2674,08 2567,88 Iq 18 2ROP.O0 2722.88 2616,68 12 34 ~. , 2850.00 2771,75 2665,55 12 11 N 75 W 1.83 223,4'0 N 376.90 W N 66 ~' 5.75 N 52 u 7.25 N 34' W 7,76 228,41 N 388,19 W 235,05 N 396.81 W 243.76 N 402,75 W 299.41 306.73 315,07 3R~.86 2'nDO. OD 2820.75 2714.55 11 30 N 23 W 4,90 252,96 N 406.62 W 334.67 295n.00 2864,68 2763.4R 11 52 N 23 W .74 262.41 N 410.65 3oOn.O0 2q18.65 2f112,45 1] 38 N 3170.00 3o16.60 2910.40 11 37 N ,320C, 00 3114,56 3008.36 11 37 N 3300.00 3212,50 3106.30 11 39 N 3APn. O0 3310.q2 3204.22 11 ~+1 N 21 W ,34 34'6.85 N 344 41Q.51 W 354. 421.63 W 3;74.63 ~29,17 W 436.86 W 414 444,02 W 434.42 3?;00,00 3408,Q0 3302,26 11 52 N 360[', O0 3506,~1 3400,21 11 27 N .~TO.r',O0 3604,59 34,98,19 11 33 N 3702.35 3596.15 11 36 N 23 W ,45 365,28 N 22 W ,20 ' 383.70 N 23 W .......... ,.1.9 ....... 4'02,17 N 22 W .1~ '~20", 80 'N 451.76 W 454.09 ~'59.16 W ~73.67 466,89 W ~93,37 .... ' '.27 74 2.~76. w........... 513.20 __~q~, O0 3B00.33 3694.13 11 32 N 22 W ,07 439.33 N q81,98 W 532,41 4000,00 3898,31 3792.11 11 32 41C0.00 3996.25 3890.05 11 39 ~20.0,00 q094.49 3un8,2m lO 46 N 25 W .14 457,,76 N N 22 W .I5 ~76.a4 N N 22 W .R9 4'93.77 N 489.72 W 552.5~ 497.38 W 572,~7 504.38 W 590.89 q3OP,O0 q192,Rq qOP6.6q 10 25 N 24 W .47 510,32 N 511.65 g 608.63 MARATHON OzL COMPANY I'BU D-15 ROll2 flCS~ THUR_RI VER FIELD COOK INLET, ALASKA BOSS GYROSCOPIC DIRECTION/~L MEASUkED V DEPTH TRUE SU ER.T_.I C AL ........ SE DEPTH TV -'-'". AGE 2 DATE OF SURVEY HAl' 1,~ 1980 VERTICAL SECTION DIRECTION CLOSURE SURVEY SP ERRY,-.SU N~ INC.. RECORD OF SURVEY COURSE COURSE DOG-LEG INCLINATION .... DI.RECTION SEV DEG MIN F)EG OEG/lOO BOSS-16579 TOTAL RECTANGULAR COORDINATES VEETICAL NORTH/SOUTH EAST/WEST SECTION 4AC ?1.0.0 A291,39 A185.19 qSn~.O0 439,9,24 ~284 .. 47q D.,O0. ~5NS,lq 9681 a,P, ?'. O. 00 4687,02 A580 9 N 25 W ,69 525,70 N 518,88 W 625. N 23 W 1,15 ' 539.6q N 52~,7~ %; 6qO N 2q W ,AT 552.78 N 5:30,51 W N 21 ....W ....... ,~ 566,36 N 535,6~ W 668 N 20 W ,28 580.~3 N 5~0.73 W 683 · 04 8 42 · 00 q 15 .o4 B 21 · 82 ' 8 36 ,2O ,0~ ,1G zlO O 0,_00. q786.06 q679 50PO,O0 q885,10 4778 51r~,00 qgRq,lq A877 52t £. Od ..... 5083.18 ............ 4.976 5390,00 5182,18 5075 · 86 7 55 · ~C 7 5¢ · 94 7 57 · 98 ...... 7 55 · 98 8 8 N ..... 19_. W .69 593,q3 N 5q5,26 W 697 N 20 ~; ,15 .606,44 N 550,05 W 710 N 21 W ,06 619,:39 N 554,91 W 72~ .N ..... 19 . W ,2,.8 ........... 6.~2.~..N ....... 559.31 .W .... 738 N 19 W ,2q 6A5,79 N 563,98 W 752 5400.00 5281.20 5175..00, , 8 ,,i 550Po00 5380,26 5274.06 7 51 56('n,00 5~7q.20 5373,00 8 21 57rn.O0 557P, 15 5A71,95 8 19 .113 .77 .15 . . .2"J 5800,00 5677.11 5570.91 R 16 N _ .19 W ,12 658.96 N . . . 568..57 W . .~766,05 N 18 W ,26 671,97 N 572.7~ W 779,65 N 17 W .52 685,87 N 576,93 W 79A,13 .N ....... 1.7. _~ oOq 699.7,3 N 581-09 W 808,55 N 16 W .13 71.9.56 N 585.03 W 822,90 5900,00 5776,Dq 5669,84 8 25 N 16 W .16 727,66 N 588,9A W 837.52 6100,00 6200.00 G30C,O0 5875.16 5768.96 7 36 N 597~. 17 5867.97 8 3 N 6073,32 5967.12 7 30 N 6172.56 6066.36 7 4 N 6271,83 6165.63 6 56 N 13 W .90 740,56 N 591.85 w 850.~ iD W .59 75A,36 14 59q.25 W 86~,,. 15 W .66. ".767.,,.!0..N .. . 597.10 V .877.79. 8 W .76 779.29 N 596.75 W 890.05 1 W .84 791.36 N 598.9`3 W 901.87 6599.00 6371. lA 626A.gq 6 43 6600.00 6470,A1 636~+.21 6 5q t:, 700._00 656°.57 6463.57 7 28 6~nO.O0 666P,86 6562.66 G 48 , 67~0.. OO~ , 67,67.97 ,, 666,1,. 77 7 7OOC. O0 6867. O1 6760.81 7 55 71~'D.OO [,q66.05 6859,85 7 58 72rn,90 7065,01 6q58, H! 8 15 N 2 E N 3 E N 8 .... E N N N 15 N 19 N 21 · AS ,, 803,0q' N 598.~,~ ,19, 815.0A N 597.84 ............... · 85 ........... 827.91 N 596.0:3 E 1.17 839.30 N 592.80 I E , ,,.91 ..... g~52.27,,N ,, 58,9.:53 E ,2q ; 865,59 N 586,0:3 E ,62 878,68 N 5BleAR 92~.76 936.94 9~7.37 957,32 971.5n 983.3q 995.35 730P.00 7363.91 7n57.71 P 32 N 20 [ ..32 906.02 N 571.26 W 1307.87 MS~aTHON IL COMPANY TF~U D-15 RD~2 MC~PTHUR RIVER FIELD DATE OF SURVEY VERTICAL SECTION DIRECTION PAGE 5 MAY 19 19R3 CLOSURE COOK INLET~ ALASKA BrS% GYROSCOPIC DIRECTIONAL SURVEY SP ERRY-SUN9 INC, BOSS-1657a TRUE SUB ME~kSURED VERTICAL SEA RECORD OF SURVEY COUPSE COURSE DOG-LEG INCLINATION DIRECTION SEV TOTAL RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH TVD 7qO0.OO 72.62,92 7156,72 DEG fqIN DEG DEG/iO0 fl 3 N 20 E NORTH/SOUTH EAST/WEST SECTION 919.1q N 566.38 W 1019.6q 7~00,00 7361,85 7255,65 76rc,00 7460,78 735q,58 7~00,.00 765R,58 7552,3R 770[',00 7757,5q ... 7651,3q 80nO,O0 7856,A7 7750,27 lal 00.00 7955.37 78q9.17 P200.,.O.O. . 805q,.2..7 ........ 7 ~ ~ 8 ' 07 ~500,00 8153,16 8OqG,g6 PqOll.O0 8251.96 81q5.76 8 2~ N 2,3 E 8 23 N 29 E .8.2.5 ........ N i...50 E R 55 N 52 E ....... ,.09 ,,817 N 3m3 E ' 3 ~ 8 2.9 N 255 E '33 8 3O N 37 E '29 R .tO N .99 E '21 8 33 N ~1 E .5 9 8 5~ N q3 E .qO ~32,56 N 560,60 W 1031.q9 9A5,29 N 553,q9 W 957.99 N 5~6,22 W 1053. 970.68 N 538,36 W 1063,~2 98~1.75 14 550-q? W 99~,65 N 522,07 W IO06,AA' N 513,15 W 1018,01 N 50:3,95 W 1Q7~.Q1 1083,~1 lOq3,~O 1102,71 1029.21 N ~9~,18 W 1111,55 1 ~'qO,60 N q83.75 W 1120.~2 REDO,DO F~350,79 824q.5q e6Cc,O0 8qq9.50 R345,30 R700,O0 85~8,22 8qq2,02 ~ q8 N ~+q E q 11 N 46 E , · g 12 N q5 E o19 1051,64 N 1062,71 N 1074,03 N q73.16 W 1128.92 A61.66 W 1137.25 450.58 W 1 1~}5.87 PP, Otq.O 0 6,,6q6.9q 85~,n.7q ,qgnn.o0 R7q5,~+7 8639,27 9 11 N ~+8 E .fl3 9 5C N 48 E .65 1084.80 N 438.59 W l155.FIq 1096,27 N q25.95 W aO@O,O0 flP, 4q ,oq 8737,89 o100,00 89q2,92 R836,72 970P,O0 90~1.80 8935.60 9 51 N /+8 E ,52 8 q7 N 51 E ,87 8 34 N 5O E ,2q l107.qO N 1117.09 N 1 126.69 N ql 5,72 W 1170,... A01.92 W 1177,47 .390,52 W 118 q. 5':} 93nn. O0 9140.66 903q.qF, 9q 0,9 ~,,0 0 q239.65 9133.q5 9500.00 933,q. z+6 9232.26 qGon.o0 9q37,29 9331,09 R A1 N 52 E .38 (4 7 N 51 E .58 P_ 51 N 525 E .75 F~ ~+8 N 53 E 8 ~,1 N ,Eq E .16 1 135,92 N 378.58 W 1190..q3 - 11q~+,73 N 367.55 W 1197.05 115q,08 N :355,33 W 1203,5q 1165.20 N 3~$,0~ W 1209.80 1172,05 N 330,82 W 1215,81 9635.05 9528.R5 9000.00 9733.96 9627.76 8 29 N 57 E .q9 8 27 N 58 E ,18 1180,07 N 318,q3 W 1220.97 1187,79 N 305,93 W 1225,R2 IOOCO,O0 '9832.97 972A.77 10100.00 9931 .95 g825.75 IOPCO.O0 1D031.03 '~<)2q. 8S 8 5 m 58 E °37 R 10 N 61 E .ql 7 qR N 60 E ,qO 1195.22 N 1202,13 N 120R.96 N 293.99 W 1230.50 281,58 V 123~,57 269,85 W 1238.71 IP?;'..r.bo 10055.R4 9q~-9.6q 6 56 N 59 E .t.q9 1210,51 N 267,26 W 1239.66 SF'ERFY- SUN l INC. PECORD OF SURVEY DATE OF' SURVEY VERTICAL SECTION DIRECTIOM PAGE 4 MAY 1, 19~g CLOSURE BOSS-1657o ** _'[._HE C~LC__U] A___T_I_O]~J~_ARE DASED nN THE TANGENTIAL bR TERMINAL ANGLE METHOD ** HORITONTAL DIO, FLACEMLNT = 1239.66 FEET AT NORTH 12 DEG. 27 MIN. WEST (TRUE) START OF SURVEY WAS IOG.2D FEET ABOVE SEA LEVEL TFU D-lb RD'~2 PCAO'fHUR PTVEP FIELD DAli OF SURVFY VERTICAL SLCTION DIRECTION CLOTURe_ PJNSS GYROSCOPIC [~IRECTIONaL TPUE SUE, MEA~ttPED VEPTICAL SEA ~~H I::rE-_ Pq"T-f- T V D ,SURVEY SPERR Y-,RUN, INC. DECORD OF--~Y COURSE COtJRSL DOG-LEG T INCLINATION DIRECTION SFV RECTANGULAR D'EG -~'iN DT.I~- .......... DEG/iO~~ NORTH/SOUTH BgSS-1657~ OTAL COORDINATES VERTICAL EAST/~EST 2ODOoDD 1975.15 ~ifiC~.O0- ,.666.62 2200.00 2157. r)2 1868.95 TIE 011 AT 2no0 FEET 116.85 N 1960-42 24 45 N 5q-- W ~ i~.'89 i4~4g N 2050.82 25 53 N 54 W 1.1~ 166.11 N 21ql.5~ 25 52 N ~2 W 5.g~ 188.~1 ~ 2i87,5~ ' ''22 5 .... N ~ ..... ~.90 iS~.$5 N N 73 W 5.76 203.28 N 75 W 2.30 212.53 N 7~ W .80 216.°.1 N' 7~ W: i,T5 ..... 22"1-~-I-1 2R~.75 W 262.52 302,,65 '-,,i 271 518.86 W 279.00 33~.q~ W 2~6.7'~ 3~.58 W 2~.2~ .";77.78 W 308.07 398-~-.12 ~ 315.12 AO0.10 W 323.16 QOT.Q5 W 332.~1 ~ 1'2 '.'36 ~ 3q2.30 2056.00 286R.2fl 2762.04 11 52 N 23 ~/ ?, ~ ,3 f,'-~ C'O -----2~. -?~-7-* 1 ~ ......... 2~~-- i i- 3-P--- ' N - 23 W 31~0.06 3015.1~ 2998.qq Il 37 N 21 W 320(,, O0 3t13.09 3906.~9 11 37 N 22 W N 21 W --N-- 23 W N 22 W N 23 ' :N ..... .7~ 265.17 N .53' 27-~ ~56 N · 36 2q3,30 ~,' · 26 312.05 N .O9 '-~', :5-0'r72 N .3q 340.53 N .---45 36g.~.,-"'"' N · 2 O 386,65 N .19 ~'05,0¥ N · 1-3 ~23.64 L; 416.30 '¢ 352.2~ 4,20.25 ~ 362 .,~ 427.67 W 382, 435.0U W qq ~.'6'~ ....~ 422.97 ' q50.O~ W qq2.O7 ~;57.50 W q61.76 465.07 W ~g1.62 ~72.63 W 501.33 · ~<?,2~ W ' 521.10 N 22 W N 23 W N 22 W N 22 14 q87.82 W 5qO.gO 503.16 W 5,q0.4~ 510.~8 W 599.63 517.62' W ~'~- =~ TBU D-15 RDfl2 MCA)THUR RIVER FIELD "-"~nOKI- iNLL¥" &LASKA BOSS GYROSCOPIC DIRECTIONAL SUPVr-Y TRUE SUB COURSE DATE OF SURVEY VERTICAL SECTION DIRECTION SPERRY-SUN, INC. RECORD-OF SLi RV L¥ COURSE DOG'LEG ~'-. PAGE 2 MA, 1, l qSD, CLOSUAE BOSS-1657q TOTAL MEASURED VERTICAL SEA INCLINATION DIRECTION SEV RECTANGULAR COORDINATES VERTICAL 4~r~P.,O{J z~289.63 ~183'z+3 9 ~7 N 25 W ,6~ 530,17 N 52~,88 W 6~,9~ ~6fO,O0 ~q87,2q ~381,0~ 8 15 N 2~ W ,q7 558,38 N 537,2~ W 665.21 47{lq.00 4586.19 ~+ t+79.99 R 21 N 21 W ~SPP.UO 4685.10 4578.90 R 36 N 20 W .28 5500.00 5378,26 ~ L._L._~~ .12 5272.06 7 51 N 1R w °26 571,7~+ N 5~2.68 W 585.57 N 5~+7.79 W 694. 612,11 N 557,26 W 722.07 625,09 N 562,08 W 735.R0 W · 651,30 N 571.25 W 763,~D 66q,56 N 575,8~8 Id 777,_37 677,65 N 580,25 W 791,11 ~6~.C.GO 5~+77.26 5371.06 8 21 N. 17 W 5RP, O. O0 5675.16 5568.96, e 16 N 16 U 5 9..E~,_O 0 5771+,10 5__6..6_.~, 9 O 8 25 60~P.O0 5873,12 5766.92 7 36 GR~O.O0 5972,19 . 7 ,27 5~65.07 7 30 6300.00 6170.q7 606~,27 7 6~ ~.72_ 6500.00 6369.01 N ,,!6 U N 13 Id N 1~ W N 8 W 6163.52 6 56 N 1 W 6262,81 6 ~)3 N 2 E 691.10 N 58A,.Aq W 805.16 70q.98 N 588.6~2 W 819.62 718,82 N 592,66 W 834.02 .~16 732.7c] N 5C26o5~) W .90 7~6,30 N 599,98 W 862.'~ · 59 759,65 N 602-65 W 876-U5 .66 772-92 N 605.29 W 889.57 .76 785.~0 N 607.52 ~ 902,23 797,55 N 608,~3 W 914.28 809,q3 N 608,28 Id 925o82 6990,00 .... 6765.9.5 6659.75 7 ql N lq E 7000.00 6865.03 6758.83 7 55 N 15 E · 71CC.00 696~+. O7 6~57.87 7 58 N 19 E 7200.00 7063.07 6956.R7 8 15 N 21 E 7300.00 7162.C9 7bSb. RO 8 32 N 20 E ,19 .91 821,28 N 607,73 W 937.23 853,72 N 606,5~ l,d 8q5,87 N 603.98 W 960.35 858.05 N 600.72 I,/ 971.4,q 871.19 N 597.33 Id 983.5~ l~8~,ql N 593.31 W 995,4~ .32 897,66 N 588,A6 d 1007,29 911-33 N 583,35 W 1019.46 MAP &THDN .L COMPANY TFU D-15 RD¢t2 ?CAm. THUR RIVER FIELD. COOW [NLET~ ALASKA POSS GYROSCOPIC DIRECTIONAL SURVEY · , DATE OF SURVEY V ERTI C AL,_SE C T,I.ON .,D IR MAY PAGE' 3 1, 1 :)SO' CLOSURE BOSS-16579 TRUE SUB COURSE _.___P_~:j~SIJkED . V£RTICAL . . SEA ._INCLINAT DE~TH DEPTH TVD DEC MI 7~D._00 : 750C.00 76P0.00 7.7.1~ C. 00 7P. nC,. O0 7260.95 715_~, 75 8 ~ 7.559,92 7255.72 R 24 7458,85 7352.65 8 2.'5 . .7557._75 .........74.51,.58 .. 8__25 7656,68 7550,qR 8 35 S_P.ER R y,. SU_N_~ INC, , RECORD OF SURVEY COURSE DOG-LEG T ION ..... DIRECTION .... SEV . . RECTANGULAR N DEG DEG/lflO NORTH/SOUTH OTAL COORDINATES .. EAST/WEST VERTI SECTIuN 578.~7 W lO)1 573,05 W I0q3 566,60 W 1054 559,q. 0 W 1065 551,84 W 1075 ,25 .55 7g00.00 pOnO.O0 P]no,o0 R200.O0 83C0.00 N 33 E .3G 989,02 N N :35 E ,33 1001,01 N N 37 E ,29 . 1012.85 N ...... N ..37 ........ E ....... .2i. .. 1024.53 N. N z+1 E .39 1035,92 N 543.97 ~ 10RR.2r-, 5:35.85 W 1046.10 527,16 W 1105. G9 . 518,10 W.. 1115.0~ 508,61 W 1123,9.q 8500,O0 870{3.00 PSO0.O0 N 43 E .qO 1047.22 N N 44 E .22 1058.44 N N ~+6 E .53 1069.50 N N ..AS ..... E .... ol,9 ....... 1080.70..N N 48 E ,43 1091.75 N 498.51 W 113P.70 4~8,00 W ll*l,2G 476,96 W 1149,54 ..... 465,57 W . . 1157,88 454.03 W 1166,04 8900,0{3 9100,60 q2. O O.. 00 930C.00 N 48 E ,_6,5 1102.86 N N q, 8 E ,32 1114,17 N N 51 E .87 1124,57 N .... N . 50 ..E . . ,2.q .... 113~.21 N N 52 E ,38 1143.63 N 429,37 W 1182. 417,35 W 1189,7q q05,75 W 1196,52 394,08 W 1203,06 . 9B0¢.00 9237.70 913!.50 {~ 7 9336,61 9250, a'l 8 51 9435,42 9329.22 8 AR 9534.2G gq~R.DG ...... R..ql 9633, lq 9526,94 8 29 ~9~00.00 9732.05 lOPCO,O0 9831,01 lOlPO.O0 9930.01 10200,00_ .1.0.929, Oq lOPPS.00 lq053.83 9625.85 P. 27 9'724-.P1 R 5 9722.84 7 48 9947.63 6 56 N 51 E ,58 .. 1152,66 N N 53 E ,75 1161,7q N N 53 E ,13 1170,97 N N ..5q. E .... ..16 ....... 1179.96 N, N 57 E .49 1188,40 N N 98 E .18 1196,27 N N 58 E ,37 120:3.84 N N 61 E ,41 1211,02 N N 60 E ,qO 1217,89 N 382.59 W 1209,26 370.97 W 1215.49 35P. o72 W 1221,72 3.q 6. qG_W . 1227.71 334,15 W 1233,15 321.71 W 1238,01 309,49 W 12q2-63 297,31 W 1246.87 285.24 W 1250,Bq N 54 E 3.49 1219,52 N 282.48 W 1251.B1 ~R ~ tHoNxSI L COMP ~r~Y DATE OF SURVEY VERTICAL SECTION DIRECTION PAGE ~ MAY 1, lq~( CLOSURE ('('OK INLETs, ALASKA BOSS GYROSCOPIC DIRECTI~)N&L SURVEY SPERRY-SUN, INC. RECORD OF SURVEY BOSS-1657~ ** THE CA~LC_U_LATIONS APE BASED ON THE AVERAGE ANGLE METHOD ** HORI?ONTAL DISFLALE~,ENT : 1251.81 FEET AT NORTH 13 DEG. 2 MIN. WEST (TRUE) START OF SURVEY gAS 106.25 FEET ABOVE SEA LEVEL CURVE DATA LOCATED IN THE APPENDIX Document Trans[--'al Un,on Omi Company of ,.. "%rnla UI11 !1 FORM 1-2M02 (REV 11-72) PRINTED IN U S A DATE SUBMITTED ACCOUNTING MONTH ,1 TO FR~M'.~ '~1 tt. W. Kugler R.C. Wart~n Alaska O1~ ~ns. ~. ~ton 0tl ~ny AT AT ~O1 Po~uptne ~rive PO ~x 6~47 Anchoraae. ~ 995~ ~choraqe. AK 99502 -- TELEPHONE NO. TRANSMITTING THE FOLLOWING I ~& I~ ~;~N~ signing ~,,u i'etu,-,,,,,, copy o _ , .,~, ,~ Form No P-4 REV. 3-1-70 ' ( SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchoraqe AK 99502 4. LOCATION OF WELL WELL WELL OTHER Water I n jector Rc CEIV : Leg A-2, Cond //10, Dolly Varden Plat~/b~ 0i,& ~ ~ 754' FSL, 1130'FWL, Sec 6-8N-13W-SM ~rlutai~ 5. APl NUMERICAL CODE 90-133-20159-C)2 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 A-926 7. IF INDIAN ALO~FEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trad inq Bay Unit 9. WELL NO. TBU D- 158D2 10. FIELD AND POOL, OR WILDCAT M~Ar~h~r I~iv~r Fire!ri l 1. SEC. T. R. M. (BOTTOM HOLE 0fl OBJECtiVE) ~ec. 6, T8N, R13W, SM 12. PERMIT NO. 8(3-5 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. MAY REPORT OF DR ILL I NG OPERATIONS 05-01 IO,400'TD 10,292'PBTD 05-02 IO,400'TD 10,292'PBTD 05-03 IO,400'TD 10,292'PBTD 05-04 IO,400'TD 10,292'PBTD 05-05 10,400'TD 10,292'PBTD WOC. Drld plug & firm cmt from 5674'-5765'. POH. R IH w/ csg scraper to 5800'. POH. Tstd 7" csg against blind rams to 3000//--OK. RIH w/ bit PU 3-1/2" DP. Fin RIH w/ DP to 10,276'. Circ & POH. RU Schl & ran CBL. Running gyro @ 0700 hrs. Fin gyro surv & tstd BOPE. RIH & displ to FIW. POH. RU Schl & ran TDT log. MU pkr & RIH w/ DP. FIH. Set pkr @ 9520'DIL. RU SOS & tstd lub. Perfd B-4 fro~ ~960'-9995'DIL w/ 4 HPF. Attempted to inj FIW--no inj. Reperfd B-4. Attempted to inj--well would not take wtr. Perfd B-5 in 3 runs from 10,030'-10,118' w/ 4 HPF. POH after perfg. Attempted to inj FIW w/ 3950 psi--no rate. RU Halliburton & attempted to inj. At 5800 psi, well took 6 bbls in 35 min. P -~]~~DJ~676'-9698'DI__L. Inj w/ Halliburton @ 5850 psi. Pumped 28 bbls ~ aver rate of 2/3 BPM w/ press incr to 5850 psi. S! well WO acid. *Marathon O~(]~Company - Sub-Operator 14. I hereby c~th~at=.t~he f~In~7~d~co~7..' SIGNED.//,r/~"t'/' It. ~~ TITLE Dist. Drlg. Supt. May 27, 1980 DATE NOTE~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. May Report of Drilling Operations We l I TBU D-15RD2 Page 2 05-06 IO,400'TD 10,292'PBTD RU Dowel l & tstd surf lines to 7000#. Spott'ed acid t~,end of DP. Pumped 500 gals 5% HCI, 2000 gals 12-6 Mud Acid, 500 gals 5% HCI followed w/ FIW. Final rate 0.75 BPM ~ 4000#. Released pkr & RIH to 9800'. Circ. Set pkr & inj into B-4 & B-5 ~ 1/3 BPM w/ 5800#. SI well WO acid. 05-07 IO,400'TD 10,292 ' PBTD RU Dowell. RIH & spotted acid across B-4 & B-5. Set pkr & acidized B-4 & B-5 w/ 750 gals 7-1/2% HCI, 2000 gals 12-10 Mud Acid, 750 gals 7-1/2% HCI. Final rate 1-1/2 BPM ~ 2800#. Set pkr ~ 9520' & inj w/ platform system--meter failed. Set pkr ~ 9800'. Inj into B-4 & B-5 w/ Dowel l ~ 1.7 BPM ~ 4000~. Set pkr @ 10,018'. Inj into B-5 ~ 0.33 BPM w/ 4200#. Set pkr ~ 9520'. !nj into B-1t B-4~, & B-5 w/ platform system @ 1.7 BPM ~ 3750#. 05-08 IO,400'TD 10,292 ' PBTD lnj FIW into B-l, 4, & 5 ~ 115 BPH ~ 3400#. RU SOS, tested lub, RIH & ran tracer & temp surv. Survs indicated 100 BPD into B-l, 300 BPD into B-5 & remainder entering upper part of B-4 perfd, & going up into Benches 2 & 3. POH. RIH & perfd 4 holes for s~qz from 9860'-9862'. Set pkr ~ 9893'. PI sqz perfs dwn annls @ 2 BPM w/ 1900#. Released pkr & rev circ from 9893'. 05-09 IO,400'TD 10,292'PBTD Rev hole clean. POH & LD pkr. Set BP @ 9878'. Set rtnr @ 9793'. Sqzd perfs ~ 9860'-62' w/ 50 sx cmt. Rev out 1/2 bbl, 2-1/2 bbls in csg, & 7-1/2 bbls thru sqz perfs. CIP @ 2330 hrs. 05-10 IO,400'TD 10,292'PBTD WOC 5 hrs & POH w/ DP & stinger· RIH w/ 6" bit & drld up rtnr 0 9793' drld dirm cmt to 9862' & CO to 9876' POH ~ ~ · · 05-11 IO,400'TD 10,292'PBTD Fin POH. RIH w/ Baker Retrievamatic pkr & set @ 9799'. Tstd sqz perfs 9860'-62' to 4000#, bled to 3000# in 5 min; to 1500~ in 30 min. Press to 4500#, bled to 3300# in 5 min; to 1500# in 30 min. Set pkr between sqz perfs & BP, held 4000# firm. Set pkr ~ 9799' to breakdown. Estab rate w/ max of 6000#, max PI rate 2-1/4 bbls in 30 min. Spotted 6 bbls HCI & PI sqz perfs. Pumped 35 bbls FIW @ 0.8 BPH w/ 4000-4350#. POH & LD pkr. RIH w/ rtnr. 05-12 IO,400'TD 10,292'PBTD RIH w/ rtnr & set @ 9791'. Mixed & pumped 100 sx CIG neat w/ 0.3% Halad 22A, 1/2% CFR-2. FP 5400#. CIP @ 1130 hrs. POH. WOC. Tstd BOPE. 05-13 IO,400'TD 10,292'PBTD WOC. RIH w/ bit & drld rtnr & hard cmt. POH. RIH w/ pkr & tstd sqz perfs to 4050#--0K. PU to 9512' & inj into B-1. Short term rate of 3/4 BPM w/ 3800#. POH. RIH w/ bit & junk sub. May Report of Drilling Operations Well TBU D-15RD2 Page 3 05-14 IO,400'TD 10,262'PBTD 05-15 10,400'113 10,262'PBTD 05-16 10,400'713 10,262'PBTD 05-17 IO,400'TD 10,262'PBTD 05-18 IO,400'TD 10,262'PBTD 05-19 IO,400'TD 10,263'PBTD Drld BP ~ 9878' & pushed junk to 10,262'PBTD. POH. RIH w/ bit & scraper to PBTD. Rev holeclean. POH. RIH w/ Retrievamatlc pkr. Set pkr @ 9512'. Inj into B-l, 4, & 5 ~ less than 500 BPD w/ 3750#. Set pkr @ 10,010'. Pumped 1000 gals 7-1/2% HCI, 4000 gals 12-10 Mud Acid, 1000 gals 7-1/2% HCI into B-5 @ 1/2 BPM w/ 4750#. Press dropped to 3100# after 400 gals 12-10 into perfs. Incr rate to 1BPM @ 3400#. Displ acid @ 1BPM w/ 3400~ & 1.2 gPM w/ 3800#. SD pump. Pre~s decr ~o 3000# in 30 min. Bled press & released pkr. Rev circ--no acid in annls. Set pkr & attempted to inj w/ platform system--meter would not record rate. Pumped 25 bbls w/ Dowell @ 1/2 BPM w/ 3750~. Released pkr. RIH to 10,251' & rev hole clean. PU & set pkr ~ 9520'. RU SOS & perfd B-4 from 9890'-9960'DIL w/ 4 HPF. RU to platform inj system & inj w/ 3750~. Meter wouldn't record rate. RU SOS & RIH w/ inj logging tools. Inj FIW @ 1390 BPD w/ 3750#. Ran inj profile. B-1=450 BWPD; B-4=190 BWPD; B-5=750 BWPD. SI well & ran 1 hr & 3 hr temp survs. No indication of fluid entering B-2, 3, or 6. POH & RD SOS. Rev hole ~lean & POH w/ DP"& pkr. RU SOS to run gauge ring & JB. Tripped gauge ring & JB. RIH & set Otis WD pkr ~ 9500'DIL. RD SOS. RU & ran downho.!e compl assy & 4-1/2" SL tbg hydro testing & drifting .... Fin running 4-1/2" tbg hydro testing & drifting. Spaced out tbg. Displ annls w/ treated FIW. Landed tbg & ND BOPE. NU Xmas tree. Fin instlg tree. Removed BPV. 05-18-80. FINAL REPORT Released rig ~ 1200 hrst RECEIV!fD 2 8 980 Anohora~,~ Form No 10-404 REV 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER Water Injector 2. NAME OF OPERATOR 8. Union Oil Company of California* 3. ADDRESS OF OPERATOR 9 P. O. Box 6247t Anchoraqe AK 99502 4. LOCATION OF WELL Leg A-2, Cond //10, Dolly Varden Platform 754'FSL, 1130'FWL, Sec 6-SN-13W-SM 5. AP! NUMERICAL CODE 50-133-20159-02 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 A-926 IF INDIAN-ALOTTEE OR TRIBE NAME --- UNIT FARM OR LEASE NAME Tradinq Bay Unit WELL NO. TBU D-15RD2 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC. T R M (BOTTOM HOLE OBJECTIVE) Sec. 6t T8N~ R13Wt SM 12. PERMIT NO 80-5 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. APRIL REPORT OF DRILLING OPERATIONS 04-01 6640'TD Drld to 6640'. Checked well--had slight mud flow. Mud wt 10.6 ppg. Built MW slowly to 11.7 ppg. C&C mud for 18 hrs. Still have slight flow. Will incr MW to 12.4 ppg. 04-02 6733'TD Built MW to 12.2 ppg. PU to csg shoe & monitored flow. Well back flowed @ 2.5 BPH. RIH & washed 6610'-6640'. Drld 6640'-6664'. PU to csg shoe & monitored well. Well back flowed @ 2.5 BPH--steadily decr. RIH & washed 20' of fill. Circ, checked mud, & surv. No chg in MW. POH. RIH w/ bit #18. No pit gain, no gas during trip. Drld 6664'-6733'. 04-03 6988'TD Drld 6733'-6988'. Circ & surv. Tripped for bit #19. 04-04 7365 ' TD RIH. Drld w/ bit #19 6988'-7365'. 04-05 7626'TD Circ & surv. POH. RIH w/ bit #20. Washed 60' to btm--no fill. Drld 7365'-7626'. 04-06 7819 ' TD Drld 7626'-7678'. Circ & surv. POH. RIH w/ bit #21 to 6000'. Checked well for flow--no flow. RIH & washed 7648'-7678'--no fill. Drld 7678'-7819'. POH. 04-07 7990'TD Fin POH. Tstd BOPE. RIH w/ bit #22. Drld 7819'-7990'. Surv & POH. *Marathon Oil Company - Sub-Operator 14 I hereby certlff~aat,~.he fo.~ing/~fo ng e $~rtect // n~o,- n~a. ~..., 5/2/80 SIGN ED ~/~ ~ ~~~~TLE /~ I ~ ~ DATE NOTE~epor, on ,h,s form ,s requ,red for each ~e~mo~. regardle, of the .atus of operatiom, and mu. be filed in duohcate with the oil and gas conservation comm~tt~ by the ~th of the succ~ing month.unlm otherwise directS. April Report of Drilling Operations Well TBU D-15RD2 Page 2 04-08 8331'TD 04-09 8614'TD 04-10 8788 ' TD 04-11 8954'TD 04-12 9117'TD 04-13 9315'TD 04-14 9575'TD 04-15 9712'TD 04-16 10,122'TD 04-17 10,372'TD 04-18 IO,400'TD 04-19 IO,400'TD 04-20 IO,400'TD 04-21 IO,400'TD 04-22 IO,400'TD RIH w/ 9-5/8" csg shoe. Checked well--no flow. RIH to 7990'---no fill. Drld w/ bit #23 from 7990'-8331'. Drld 8331'-8414'. Circ & surv. POH. Checked rig eqpmt. RIH w/ bit #24. Reamed 8384'-8414'. Drld 8414'-8614'. Drld 8614'-8686'. POH. Chgd bit & BHA. RIH & reamed 8656'- 8686'. Drld 8686'-8788'. POH. RIH w/ bit ~26. Fin RIH w/ bit #26. Reamed 8758'-8788'. Drld 8788'-8954'. Circ & surv. POH. RIH w/ bit #27. Fin RIH w/ bit #27. Drld 8954'-9084'. Circ & surv. POH. Chgd bit & RIH. Reamed 9024'-9084'. Drld 9084'-9117' w/ bit #28. Drld 9117'-9280'. Circ & surv. POH. RIH w/ bit #29. Reamed 9250'-9280'. Drld 9280'-9315'. Drld 9315'-9575' w/ bit ~29. Drld 9575'-9696'. Surv & POH. Tstd BOP & RIH. Reamed 9636'-9696'. Drld w/ bit ~30 from 9696'-9712'. Drld from 9712'-10,122'. Drld 10,122'-10,180'. Surv & tripped for bit #31. Drld 10,180'-10,372'. Drld to 10,400'. Circ for logs. Surv & POH. RU DA & tstd lub to 2500#. Ran DIL/SP & Sonic/GR logs. POH w/ Sonic tool. Fin POH w/ Sonic tool. RIH w/ Density/Neutron--tool started sticking. POH. RIH w/ bit. C&C mud. POH w/ bit to log. Fin POH w/ bit. RU DA & tstd lub to 2500#. Ran DIL/SP, Neutron/Density/GR, & RFT. RD DA. RIH w/ bit. Circ from 10,400'--no fill. POH. RU csg handling tools. Ran 4623' of 7" lnr on DP to 10,380'. (Top of 7" @ 5736'; shoe @ 10,380'.) Circ csg lnr for cmtg. Circ csg. Dropped shear ball & pumped dwn. Tstd cmtg lines. Pumped 30 bbls wtr, 500 sx CIG w/ 0.3% HR-6L, 1/2 gal/sk Econolite, 1/4 #/sk Flocele, 500 sx CIG w/ 0.4% Halad 22A, 1% CFR-2, 3% KCI & 1/4 #/sk Flocele, 10 bbls wtr. Displ w/ 270 bbls mud. CIP @ 1100 hrs. Pulled out of hgr 10 stds. Circ wiper plug dwn DP. POH. WOC. April Report of Drilling Operations Well TBU D-15RD2 Page 3 04-23 10,400 ' TD 04-24 IO,400'TD 10,292 ' PBTD 04-25 IO,400'TD 10,292'PBTD 04-26 IO,400'TD 10,292'PBTD 04-27 IO,400'TD 10,292'PBTD 04-28 IO,400'TD 10,292'PBTD 04-29 IO,400'TD 10,292'PBTD 04-30 IO,400'TD 10,292'PBTD WOC. RIH w/ 8-1/2" bit. C&C mud to 5676'. Drld cmt stringers & cmt from 5676'-5736'. Tstd Inr lap to 2400#. POH. Tstd BOPE. PU 6" bit, 7" scraper, & 4-3/4" DC. RIH to top of Inr. Circ to 5770'. Tstd csg w/ 2500#. RIH to 10,292'. C&C mud. Tstd csg to 2550#. POH. RIH w/ 9-5/8" csg scraper to 5736'. POH. RIH w/ DST tools, 2500' wtr cushion. Set pkr ~ 5701'. Opened test tools--had light blow for 15 min, dead for 5 min, light blow for 40 min. Closed tool after 1 hr flow period. Fin DST. POH. Had 180' fluid rise during 1 hr flow. DST press: IF=1114 psi; FF=1162 psi; 2 hr SI 3935 psi. RIH w/ 7" RTTS to test 7" Inr to 3500~--0K. Lap leaking slightly. POH. RIH w/ 9-5/8" EZSV rtnr. Spotted wtr below rtnr. Closed pipe rams. Started breaking dwn Inr lap w/ wtr. Attempted to break dwn 7" Inr lap. Got 2 BPM rate w/ 4000# surf press. I ncr press to 4075'. 9-5/8" csg broke dwn. Set rtnr & POH. RIH w/ RTTS to locate leak. Leak between 2153'-2618'. Located leak in 9-5/8" csg between 2309'-2315' & POH. RIH w/ 8-1/2" bit. Drld rtnr @ 5717'. POH. RIH w/ 6" bit. Drld & pushed rtnr junk to PBTD. Circ hole clean. C&C mud from 10,292'. POH. RIH w/ BOT Inr tie-back slv polishing mill. Wouldn't go into Inr. POH. RIH w/ tapered mill. Milled junk on top of lnr. POH. RIH w/ BOT polishing mill. Polished Inr tie-back slv. POH. Fin LD 5" DP. Set RBP ~ 202'. ND BOPE. Instld 7" csg hgr, NU BOPE & tstd. Pul led RBP. RIH w/ 7" 29#, N-80 tie-back csg to top of hgr @ 5736'. Circ prior to cmtg. Circ 7" csg. Cmtd 7" tie-back w/ 400 sx CIG w/ 1/4 #/sk Flocele & 150 sx C! G neat, 15.8 ppg. Stabbed into tie-back slv& set 7000# on slv. Bled off press--no flow back. CIP @ 057 hrs, 04-29-80. Set slips & cut csg. RIH to top of cmt 5674'. WOC. Form ! ~403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-133-20159-02 SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) 7o ~' OIL I--'! GAS ~ WELLm m WELL OTHER Water Injector 2. NAME OF OPERATOR i8. Union 0il Company of California* 3. ADDRESS OF OPERATOR 9. P. 0. Box 5247, Anchorage AK 9cj502 4. LOCATION OF WELL At surface Leg A-2, Cond #10, Dolly Varden Platform, 754'FSL, 1130'FWL, Sec 6-8N-13W-SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106,2'KB Check Appropriate Box To Indicate Nature of Notice, Re 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 A-926 ~ IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME Trad lng Bay Unit WELL NO. D- 15RD2 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6t T8Nt R13W~ SM ].2. PERMIT NO. 80-5 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Tie back 7" Liner (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. While trying to establish an injection rate prior to a cmt sqz of the Inr lap, a leak occurred in the 9-5/8" csg between 2309'-2315'MD. The 9-5/8" csg is set @ 6003'MD. The 7" Inr ran from 5736' to 10,380'MD. Ran 5695' of 7" Inr from tie-back slv@ 5736' to surf. Cmtd tie-back as follows: Pumped 30 bbls wtr, followed w/ 400 sx CIG w/ 1/4#/sk Flocele, 15.8 ppg, tailed in w/ 175 sx CIG neat. Dropped plug, pumped 10 bbls wtr & displ. Bumped plug to 1750#. Stabbed in tie-back slv. Bled psi--no back flow. Let cmt set & tstd 7" csg to 3000#--held for 30 min.--OK. Verbal approval received from Russ Douglass to Jack McClellan, °4-2~8~'~[I'~,L' ][~ '! ~[) *Marathon Oil Company - Sub-Operator 16. I hereby certify that the foregoing is true and correct Dist. Drlg. Supt. 5/5/80 TITLE DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: BY ORDET~TI~F TIiE COMrvllSSh3){ DATE See Instructions On Reverse Side Form No. P-4 ~ · REV. 3-~1-?0 STATE OF ALASKA el L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-133-20159-02 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 A-926 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL E~] GAS E} Water Injector --- WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Union Oil Company of Cai ifornia* Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 6247, Anchorage AK 99502 TBU D-15RD2 10. FIELD AND POOL, OR WILDCAT McArthur River Field 4. LOCATION OF WELL Leg A-2, Cond //10, Dolly Varden Platform 754'FSL, 1130'FWL, Sec 6-8N-13W-SM 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PERMIT NO. 80-5 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. MARCH REPORT OF DRILLING OPERATIONS 03-01 Cut csg @ 2085'. POH. RIH w/ spear, moved 9-5/8" csg 6", then it stuck. POH. RIH & cut csg ~ 1985'. POH. RIH w/ spear--could not pull csg. POH. RIH & cut & retr csg from 1925' (46.85'). Tstd BOPE--OK. RIH & retr csg from 1985' (53.33'). POH LD 9-5/8" csg & tools. (Total rec today: 100.18'. Top of stub @ 1985'.) 03-02 RIH w/ 12-1/4" bit & cleaned hole to 1985'. RIH w/ spear & worked 9-5/8" csg from 1985'--tight. POH. RIH w/ cutter & attempted to cut. POH--no cut. RIH & cut csg @ 2033'. POH. RIH w/ spear & worked csg free from 2033'. POH rec 48.77' csg. RIH w/ spear & worked csg. POH rec 50.77' csg w/ centralizers. RIH w/ 8-1/2" bit & chased junk into csg. RIH w/ 8-1/2" bit to 2517'. (Total rec today: 99.54'. Top of stub @ 2085'.) 03-03 -- CO hole w/ 8-1/2" bit & POH. RIH w/ cutter & cut csg @ RECEIVED 2150'. POH. RIH w/ spear & POH w/ 65.34' csg. RIH w/ cutter & cut csg @ 2240'. POH. RIH w/ spear & POH w/ 91.17' r ~ · :~.'~] ~ 0 1~0 csg. RIH w/ cutter & cut csg @ 2420' RIH w/ spear. POH--no rec. LD spear & PU hyd cutter. R IH & cut csg ~ 2410'· POH LD cutter. (Total rec today: 156.51'· Top of Al~sk~ Oi~ & G~s ~ m?~ uc~,.m~.'~O~tub @ 2240'.) Anoh~rag~ Oil Commpany - Sub-Operator 14. I hereby ~et~ify that th"~e "f~~ co%ect#'~~ ' Dist. Drl . Su t. DATE 4/9/80 NO eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. March Report of Drilling Operations We l I TBU D-15RD2 Page 2 03-04 RIH w/ spear & jars to 2240'. Jarred on csg--tight. POH. RIH w/ cutter & cut csg @ 2370'. POH. RIH w/ spear & jars. Jarred on csg. POH rec 128.06' csg. RIH w/ spear & jars to 2370'. Jarred on csg. POH rec 39.79' csg. LD fishing tools & WP. RIH w/ 5" DP. 03-05 RIH to 2455' & circ hole clean. Pumped 20 bbls wtr, 336 s× CIG neat cmt @ 15.9 ppg followed w/ 38 bbls mud. PU to 2150' & pumped wiper plug. POH & WOC. Cleaned rig. (Note: top of 9-5/8" stub @ 2410'; btm of 13-3/8" @ 2250'.) 03-06 WOC. RIH w/ 12-1/4" bit & scraper to 2150'. C&C mud. POH. RU Dialog & ran 13-3/8" caliper 2150'-surf. RIH w/ pkr & tstd 13-3/8" csg. Tstd to 1500#--hole in 13-3/8" csg @ 642'. POH. RIH & set cmt rtnr @ 630'. Pumped 440 sx CIG neat cmt in 5 stages--would not hold press. WOC between stages. 03-07 Staged cmt into hole ~ 642'. Sqzd hole w/ FP of 1700#. Pulled out of rtnr & rev circ out 18 sx cmt. Circ & POH. WOC. RIH w/ 12-1/4" bit & scraper. POH. RIH w/ pkr & located holes in 13-3/8" csg ~ 387' & below 532' (holes from previous testing between 535'-577'). POH. RIH w/ cmt rtnr & set @ 522'. Mixed 200 sx CIG cmt @ 16+ ppg. PI holes below 522'--no press. Began staging cmt into holes below 522'. 03-08 Staged cmt into holes below 532'. Mixed 200 sx CIG cmt @ 16 ppg. Pumped 150 sx. WOC. Staged 20 sx cmt into holes w/ press incr to 200 psi. Pulled out of rtnr & rev out 30 sx cmt. Circ hole clean & POH. WOC. PU rtnr & RIH to 370' & set rtnr. Mixed 200 sx CIG cmt. Pumped 150 sx into holes below 387'. WOC. Staged 15 sx cmt into holes w/ press incr to 2000 psi. Pulled out of rtnr & rev out 35 sx cmt. Circ & POH. WOC. 03-09 -- WOC. RIH to 369' w/ 12-1/4" bit. Drld 1' hd cmt & cmt rtnr. 03-10 -- Fin drlg rtnr @ 370'. Drld cmt from 373'-426'. CO to rtnr ~rEl~/~-~,~.~ .... 522'. Tstd 13-3/8" csg to 1000 psi--OK. Drld rtnr ~----~ L~ 522'-526'. Drld hard cmt 526'-576'. CO to rtnr @ 630'. ,~ Tstd 13-3/8" csg. PI holes 532'-577' w/ 450 psi. POH. RIH ~ ~ ~ 0 ~0 w/ rtnr & rtnr prematurely set @ 219'. POH. RIH w/ 12-1/4" bit. Drld 16" or rtnr & pushed rtnr to 604'. POH. WO cmt 03-11 -- RIH w/ cmt rtnr & set @ 500'. Mixed & pumped 300 sx CIG cmt. After 50 sx, 13-3/8" x DP annls press up. Closed pipe rams & pumped 250 sx cmt w/ 700 psi annls press & 300 psi DP press. PU & rev circ--no cmt rec. Circ hole clean. POH. WOC. Tstd BOPE. March Report of Drilling Operations Well TBU D-15RD2 Page 3 03-12 WOC. RIH w/ 12-1/4" bit to 498'. Circ. Tstd 13-3/8" csg to 750#--0K. DRId 2' cmt & cmt rtnr to 507'. DRId cmt & cleaned hole to 627'. Tstd 13-3/8" csg to 750#--0K. POH. Chgd bit & RIH. Drld rtnr junk from 627'-630'. 03-13 Fin drlg rtnr 630'-633'. Drld cmt rtnr parts to 702'. RIH to 2150' & circ hole clean. Tstd 13-3/8" csg--pumped away @ 250#. POH. RIH w/ RTTS & located holes in 13-3/8" csg between 847' & 892'. POH. RIH w/ rtnr & set @ 755'. Mixed & pumped 300 sx CIG neat cmt. Staged last 50 sx. FP 575 psi. Pulled out of rtnr & circ hole clean. POH. WOC. 03-14 WOC. Cleaned rig & mud tanks. RIH w/ 12-1/4" bit & 2 junk subs. Drld on rtnr set @ 755'. 03-15 Drld rtnr from 775'-778'. Drld rtnr parts & cmt from 804'- 887'. RIH to 2150' & circ. Tstd 13-3/8" csg. Broke dwn @ 400 psi. POH. RIH w/ csg scraper to 2000'. POH. RIH w/ RTTS & located leaks between 849' & 884'. POH. RIH w/ cmt rtnr. Set @ 745'. Mixed 300 sx CIG neat cmt. PI holes in 13-3/8" csg. Staged last 70 sx. FPP 710 psi. FSIP 475 psi. Pulled out of rtnr & WOC. 03-16 -- WOC. Upgraded rig eqpmt. ~]~-[ II/ RIH w/ 12-1/4" bit & 2 junk subs. Drld rtnr ~ 745'. Drld 03-17 ~ ~,~,~? f~' ~] cmt from 825'-880'. CO to 994'. Tstd 13-3/8" csg--no good. ' ~" POH. RIH w/ RTTS & found leak from 844'-884'. POH. RIH w/ · · 03-18 -- EZSV & set ~ 735'. Mixed 300 sx CIG neat cmt & displ to rtnr. Staged 70 sx into holes over a 3-1/2 hr period. FP 700 psi & holding 700 psi. Pul led out of rtnr & circ hole. ~OC. WOC. Cleaned rig & mud pumps. Tstd 13-3/8" csg above top of cmt plug w/ 500 psi--OK. POH w/ rtnr stinger. RIH w/ 12-1/4" bit & 2 junk subs to 735'. Drld on rtnr @ 735'. 03-19 Drld rtnr @ 735'. Drld cmt 794'-888'. Tstd 13-3/8" csg to 350#--0K. RIH to 2146'. Drld junk & cmt to 2241'. Drld cmt to 2275'. Cleaned mud handling eqpmt. Displ hole w/ new mud. C&C mud. 03-20 2399'TD POH & emptied JB's. RIH w/ 12-1/4" bit & JB. Circ & POH. PU DD & BHA. RIH & RU steering tool. Attempted KO. Couldn't drill--junk under bit. POH. RIH w/ bit & JB. Drld junk & cmt 2275'-2280'. POH. RIH w/ 12-1/4" bit, DD, & direc BHA. Orient tools & kick off. Direc drld to 2399'. March Report of Drilling Operations Well TBU D-15RD2 Page 4 03-21 2881 ' TD 03-22 3972'TD 03-23 4353'TD 03-24 5120'TD 03-25 5590'TD 03-26 6000'TD 03-27 6000'TD 03-~28 6000 ' TI] R CE /FD 03- 2 eJ~: ~"'~60~0~0 ' TD 03-30 6310'TD 03-31 6513'TD POH w/ DD. Tstd BOPE--OK. PU BHA & RIH. Tstd fm w/ 350#. Drld & surv to 2728'. POH. PU DD & orienting BHA. RIH to 2728'. Oriented tools & DD to 2881'. POH for new drlg assy. MU BHA. RIH to 2681'. Reamed 2681'-2881'. Drld & surv to 3972'. Drld & surv to 4035'. POH for new BHA. Drld & surv to 4308'. Tripped for bit #10 & drld to 4353'. Drld & surv to 4569'. POH & chgd BHA. RIH & reamed 4308'-4368'. Drld to 5120'. Drld to 5156'. Circ, surv, & POH. RIH w/ bit ~13. Drld to 5590'. Drld 5590'-5606'. Circ & surv. POH for bit ~14. RIH & drld 5606'-5890'. POH for bit #15. RIH & drld 5890'-6000'. C&C mud for logging. C&C for logs. Surv & POH. RU Schl & ran DIL, Sonic, FDT, & Neutron logs. RD Schl. RIH w/ 12-1/4" bit & drlg assy. C&C for 9-5/8" csg. POH. POH & LD BHA. RU to run 9-5/8", N-80 csg. Shoe @ 5994'; FC @ 5912'. RU HOWCO & pumped 30 bbls wtr, 1000 sx CIG cmt w/ 1/2 gal/sk Econolite & 0.3% HR-6L, 400 sx CIG neat cmt, followed by 10 bbls wtr. Bumped plug w/ 2500 psi. Floats held OK. Cmt to surf. CIP @ 0615 hrs. CU cmt from surf eqpmt. Raised BOPE & set 9-5/8" csg slips & cut off 9-5/8" csg. WOC & chgd & tstd BOPE. PU 8-1/2" bit & BHA. RIH. Fin RIH. Tstd 9-5/8" csg to 2500#--0K. Drld FC & cmt from 5910'-5858'. Tstd to 2500 psi--OK. Drld cmt & shoe from 5958'-6000'. Drld to 6020' & C&C mud. Conducted leak-off test. Fm took fluid @ 13.6 ppg equiv. Drid to 6092'. POH & chgd BHA. RIH & reamed 6010'-6092'. Drld to 6310'. Drld 6310'-6429'. Circ & surv. POH. Observed slight mud flow. RIH w/ bit #17 to 6429'. Circ & built MW to 10.4 ppg. SI BOPE to check press--had 25# on csg & DP. Circ & drld 6429'-6443'. Built MW to 10.5 ppg. Circ SI BOP's--checked press--OK. Drld 6443'-6513'. Built MW to 10.6 ppg. Hole OK. Form 1G-403 REV,, 1-10-73 ' r Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) t 5. APl NUMERICAL CODE ~' O~L I--'1 GAS [--] WELLU WELL OTHER Water Iniector 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR P. 0, Box 6247t ^nchoraqe ^K 99502 4. LOCATION OF WELL At surface Leg A-2, Cond #10, Dolly Varden Platform, 754'FSL, 1130'FWL, Sec 6-8N-13W-SM 13- ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 6. LEASE DESIGNATION AND SERIAL NO.~_/ ADL-187?g A-q?R (~/ 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME TFading Bav Hnit 9. WELL NO. D-15RD2 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6: T8N~. R13W.. SM 12. PERMIT NO. 80-5 )ort, or Other Data NOTICE OF INTENTION TO'- TEST WATER SHUT-OFF g-.--I FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The original casing design, as indicated on the permit to drill, showed our intent to drill 8050' of 12-1/4" hole from the existing 13-3/8" casing shoe at 2250'MD to a depth of 10,300'MD; run and cement 9-5/8" casing. After reconsideration was given to the possibility of encountering the same pressure zone found on D-5WO at 6035'TVD, we intend to drill a 12-1/4" directional hole to 6000'MD and set 9-5/8" casing and cement with approximately 1400 sx Class G cement. Drill an 8-1/2" directional hole from 6000'MD to 10,300'MD, run and cement a 7" liner. Our original injection zone and bottom hole objective will remain as indicated on the approved permit to drill. Verbal approval for this procedure was obtained from Russ Douglass to Tony Swan on March 20, 1980. Al2ska Ol! & L ,~ *Marathon Oil Company - Sub-Operator 16. I hereby certJLf~that the foregoing is true and correct SIGN ITLE Dist. Drlg. Supt. DATE 3/27/80 (This space for State of fl~'e use) . / . (?~., COMMISSIONER APPROVED BY~p,'~-~R~ TITLE CONBITION5 OF OVAL, IF 4N~.. BY ORDER OF T~ COMMISSl0N See Instructions On Reverse Side DATE Approved Cop~' Returned e Fo?~ No P-4 REv 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA Gl L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OTHER Water Injector 1. WELL WELL 2. NAME OF OPERATOR Union Oil Company of California* 3 ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL Leg A-2, Cond #10, Dolly Varden Platform 754'FSL, 1130'FWL, Sec 6-8N-13W-SM 5. AP! NUMERICAL CODE 50-13~-?n 159-02 6. LEASE DESIGNATION AND SERIAL NO. ADL- 187?9 A-926 7. IF INDIAN-ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bav lin it 9. WELL NO':'. ' TBU D-15RD2 10. FIELD AND POOL, OR WILDCAT McArthur R!:,er F!e!d 11 SEC. T. IL M. (BOTTOM HOEE OBJECTIVE) Sec. 6. T8N: R13W; SM 12. PERMIT NO. 80-5 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. :'~ -~ FEBRUARY REPORT OF DRILLING OPERATIONS 02-11 -- RU drlg eqpmt. 02-12 02-13 02-14 02-15 Moved rig over D-15RD & ran elec cables. RU Otis & shifted XA slv@ 10,541'. POH & RD Otis. Displ FIW in tbg & csg w/ 10.2 ppg mud. NU BOPE. PU tbg & pulled seal assy from pkr. C&C mud. RU to pull 4-1/2" SL tbg. Drawworks motor failed after pulling tbg about 2/3's of the way out of hole. All rig power SD. Now working on DC power. WO on drawworks motor. Fin POH w/ 4-1/2" tbg & stood back. PU 15 jts 2-3/8" tbg stinger & RIH on 4-1/2" SL tbg to 10,922'. C&C mud. HOWCO mixed & pumped 100 sx CIG neat w/ 5 bbls wtr ahead & 3 bbls wtr behind. Displ w/ 159 bbls mud. POH to 10,050'. C&C mud. POH w/ 4-1/2" tbg & stinger. RU DA & l ub w/ JB & GR. DA ran JB & GR to 7490'. Set Halliburton EZ-Drill BP @ 9400'. RIH w/ 4-1/2" SL tbg then POH LD same. ND BOP stack. MU spear & latched onto 9-5/8" csg. Prep to remove 9-5/8" csg si ips. *Marathon Oil Company - Sub-Operator 14. I hereby c~f~ that the foregoing ~s~l~e and correct SIGNED~,~~ .~'. ~~__.t~ff~._T~nE Dist. Drlg. Supt. DATE 3/]-]-/80 NOTE~aport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. February Report of Drill ing Operations Well TBU D-15RD2 Page 2 02-16 02-17 02-18 02-19 Worked 9-5/8" csg w/ spear. Could not pull csg high enough to remove slips w/ 400,000# pull. Cont to work csg. Pul led to 415,000# & finally able to remove slips. RU Dialog & ran FPI. 1st reading indicated 9-5/8" free only to 450'. 9-5/8" became more free each time pipe was moved. Fnal reading indicatd 9-5/8" csg free to 650'. Released spear. POH & RD Dialog. NU 13-3/8" BOP. MU Tri-State mechanical csg cutter & RIH to 650'. Cutting csg @ 0700 hrs. Cut 9-5/8" csg @ 650'. POH LD cutter. RIH w/ spear w/ pack-off. Latched 9-5/8". Worked pipe--pipe not yet free. Failed to circ. PI cut @ 650' & into fm below 13-3/8" csg @ 2250' w/ 50 psi. POH w/ spear. RIH w/ mech cutter & cut 9-5/8" csg @ 535'. POH. RIH w/ spear. Worked pipe--pipe not yet free. Could not circ. PI fm as above w/ 50 psi. POH w/ spear. Rev pack-off on spear. RIH & latched 9-5/8" csg. Press on 13-3/8" x 9-5/8" csg annls w/ 1000 psi. Could not circ. Appears to be a bridge between surf & cuts @ 535' & 650'. Cont to work pipe to 400,000# pull. Pipe would not free up. Released spear & POH. RU Dialog & ran FPI. Pipe free only to 300'. RD Dialog. RIH w/ mech cutter & cut 9-5/8" csg @ 295'. POH. R IH w/ spear & latched 9-5/8" csg. Worked pipe--pipe still not free. POH w/ spear. PU & RIH w/ 12" x 10-3/4" WO shoe on 11-3/4" x 10-3/4" WP to 70' & stopped. Rotated & washed over 9-5/8" csg from 70' to 78' @ 2'/hr. Mud returns appear to contain dehyd mud--cannot detect any cmt yet. CBL does not indicate any cmt above 13-3/8" csg shoe. WO 9-5/8" csg from 78' - 115'. POH. Built & instld pack-off assy inside 9-5/8" csg stub. Stopped lost circ. RIH & WO 9-5/8" csg to 155'. POH. R IH & retr pack-off from 9-5/8" csg stub. RIH w/ mech cutter & cut 9-5/8" csg @ 145'. POH. RIH w/ spear & latched 9-5/8" csg. POH & LD 103' of 9-5/8" csg. Instld pack-off in 9-5/8" csg stub. RIH w/ 11-3/4" x 10-3/4" WO shoe & WP. WO 9-5/8" csg from 155' to 170'. Rec mostly dehyd mud & sml amt of cmt over shaker. WO 9-5/8" csg from 170' to 257'. POH. RIH & retr pack-off from 9-5/8" csg. MU spear & R IH. Latched 9-5/8" csg & pulled csg free from cut @ 295' w/ 25,000# over wt. LD 150' of 9-5/8" csg. RIH w/ spear & latched 9-5/8" csg. Worked csg--cannot pull free. Released spear & POH. RIH w/ pack-off & set in 9-5/8" csg. R IH w/ 11-3/4" x 10-7/8" WO shoe & 11-3/4" x 10-3/4" WP. CO bridges from 221' to 295'. Rec cmt & dehyd mud. WO 9-5/8" csg from 295'-306'. February Report of Drilling Operations We l I TBU D-15RD2 Page 3 02-20 02-21 02-22 02-23 02-24 02-25 WO 9-5/8" csg to 306'. POH. RIH & retr csg pack-off. RIH w/ mech cutter & spear. Cut 9-5/8" csg @ 320'. POH. Rec 2.85' of csg. RIH w/ spear & rec23.3' of 9-5/8" csg. RIH w/ spear & worked 9-5/8" csg w/ 350,O00#--csg not free. POH. RIH w/ WP & washed to top of csg stub @ 320'. WO 9-5/8" csg from 320' - 338'. POH. RIH & retr pack-off. RIH w/ cutter & spear. Cut 9-5/8" csg @ 351'. Latched onto csg & POH. REc 31' of csg. R IH w/ mech cutter & spear. Cut csg ~ 390'. Could not pull csg. R IH w/ mech cutter & spear. Cut csg @ 386'. POH. Rec 34.19' of 9-5/8" csg. RIH w/ WP. Washed & worked WP to 388'. POH. RIH & retr pack-off. RIH w/ cutter &~ spear. Cut csg @ 401'. POH. No rec. RIH w/ cutter & spear. Latched 9-5/8" csg & POH. REc 14.40' of csg. RIH & set pack-off in 9-5/8" csg stub. RIH w/ WP & washed over to 404 '. Cut & pulled 9-5/8" csg from 447'. WO 9-5/8" csg to 456'. Cut & pul led 9-5/8" csg from 490'. Pul led 9-5/8" csg from 535'. RIH to 12-1/4" bit & cleaned hole to csg stub @ 535'. Attemptd to cut csg @ 580'--no cut. RIH to 570' & cut 9-5/8" csg. Cut & retr 9-5/8" csg from 571'. Cut & retr csg from 610'. Retr csg for original cut @ 650'. RIH w/ 12-1/4" bit & circ to 650'. Cut & retr csg from 690'. RIH w/ Johnson pkr to test 13-3/8" csg. 13-3/8" csg have holes betwee 532' & 577'. POH w/ pkr. Tstd BOPE. RIH w/ spear & engaged csg. Pulled 400,000# & got 9-1/2" stretch. Cut csg ~ 1129'. Wouldn't pull w/ 450,000#. Cut csg @ 790'. Retr 101.64' of 9-5/8" csg w/ 200,000# pull. PU 12-1/4" bit & RIH to C&C hole. Cleaned hole to 791'. RIH & cut 9-5/8" @ 889'. POH & rec 97.38' of 9-5/8" csg. RIH w/ 12-1/4" bit & cleaned hole to top of stub @ 888'. Attempted to pull csg from cut @ 1129'--tight. Cut csg @ 995'. Jarred on csg--no rec. Cut csg @ 942'. Jarred on csg--tight. Cut csg @ 922'. Jarred on csg & moved top of stub to 849'. POH. PU 3 - 8" DC's & RIH. Jarred on 9-5/8" csg @ 849'. Jars parted in middle. POH & MU OS. RIH w/ OS & rec jars & spear. Attempted cut @ 888'. No cut. POH. RIH & cut & rec 21.34' csg from 888'. RIH & jarred on csg w/ 400,O00#--no progress. RIH w/ WP & CO to 888'. RIH & attempted cut @ 902'--no cut. RIH & cut & rec 34.43' csg. RIH w/ 12-1/4" bit & CO to 942'. POH. February Report of Drilling Operations Well TBU D-15RD2 Page 4 02-26 02-27 02-28 02-29 RIH w/ spear & rec 39.45' of csg. Top of stub ~ 983'. Made CO trip to 983'. RIH & cut & retr csg from 1063' (78.20'). RIH to rec csg from cut @ 1129'. Jars parted. RIH w/ OS & fished jars & spear. RIH w/ spear & engaged 9-5/8" csg @ 1063'. Jarred on csg. Jarred csg loose w/ 250,000#. POH rec 65.56' csg. RIH w/ 12-1/4" bit & CO to 1128'. POH & PU 8-1/2" bit. RIH & CO to 1190'. RIH to 2487' & circ hole clean. POH. RIH w/ cutter & cut csg @ 1210'. POH & MU spear. RIH & engaged spear ~ 1128'--jarred csg loose. Rec 80.70' csg. Made CO run w/ bit to 1208'. Circ hole clean & POH. PU cutter & RIH. Cut csg ~ 1285'. POH & MU spear. RIH to 1208' & engaged spear. Jarred csg loose w/ 200-300,000#. POH rec 76.20' csg. Made CO run w/ bit to top of csg stub @ 1285'. CO to 1285'. POH. RIH & cut & retr 9-5/8" csg from 1400' (113.05'). RIH w/ 12-1/4" bit & CO to 1400'. POH. RIH & cut & retr csg from 1490' (89.81'). RIH & cut csg @ 1589'. Jarred & circ around 9-5/8" csg. POH. Rec 99.30' csg. Cleaned contaminated mud from rig floor. RIH w/ DC's. Circ thru clrs to clear contaminated mud. RIH w/ 12-1/4" bit & CO to stub @ 1590'. POH. RIH & cut & retr 9-5/8" csg from 1692'. POH w/ 103.99' of csg. RIH & cut & retr 9-5/8" csg from 1885'. POH w/ 192.68' csg. RIH w/ 12-1/4" bit & CO to 1885'. POH. RIH w/ cutter to 2085' & cutting 9-5/8" csg. Janua~ 16, 1980 Trading Bay Unit D-15RD2 Onion 0tl Company of California Permit No. 80-$ fJur. Loc.: 754*FSL~ !130*PWL, Sec 6, T8N~ R13W, SM. Bottomhole Loc.~ 1780'FSL, 950'FWL, Sec. I~r. Robert T, Anderson District Land Manager Onion Oil Company of California P, O, BOX 6247 Anchorage, Alaska 99502 Dear Mr. Anderson~ Enclosed is the approved application £or permit to drill the above referenced we11. Well samples, core chips and a mud log are not required. A directional smrvey is required° If available, a tape contain- ing the digitized log in£ormation on all logs shall be submitted £o~ copying except experimental logs, velocity surveys and ditmeter 8urveys. ~any rivers in Alaska and their drainage systems have Been classified as important £or the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 ~d the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to c~umencing operations you may he contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and ~ regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as a~ended, Prior to Mr. Robert T. Anderson TredXng Bay Unit D-15RD2 -2- January :16, :1980 ccmmoneXng operations you Bay be contacted by a representative of the Department of BnvXronmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, tho Alaska Depaztnent of Labor Xo being notified o£ the issuance of this permit to dril 1. To aM us Xn sehedulXng fXeld work, we would apprecAate your notXfytng thio office within 48 hours after the veil is spudded. We ~uld also like to bo notified so that a repre- .entatXvo of the commission Bay he present to w~tness testing of bio. out p~eventer equXpuent bo£ore surface casing shoe Xo drX!led. In the event of suspension o.r abandonment, please gave tiffs offAee adequate advance notificat~on os that we leaF have a w~~ p~ooOBt. Very truly yours, Enclosure cc, Depertnent of FXsh & Game, Habitat Sec't~on v/o encl. Depertnent of ~vLromntal ~nse~etLon v/o/encl. ~parment o~ Ls~F~ Superior, Lair Lev ~pl~anoe D~vXsXon v/o e~l. Hmlsbe Porto I0-- 401 ~ I--I--71 SUBMIT IN TRIPq~ (Other ~nstruetJons ~ reverse s{de) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN ]1. TTPR Or WORK RE DRILL :l~ DEEPEN F-1 b. ?YPg or WBLL API #50-133-20159-02 6 L~F-~SE DII~IGNA'~ION A. ND S~u&L NO AD[.- 18729 A-926 IF IN'DIAN 8 UNIT, FARM OR LEASE NA~ME Trading Bay Unit D- 15RD2 10 FIELD AND POOL OR WILDCAT McArthur River Field 11 SEC, T R M, (BOTTO%~ HOLE OBJECTIVE) O,L.,L,. [--]W.C'.O'' [--] O...' Water Injector .-o..g'"~c' ~-] M,', .,,, 'ZO.,. [-] NAME OF OPE~.ATOR Union Oil Coml~any of California* 3 ADDRESS O~ OPERATOR P. O. Box 6247, Anchoraqe AK 99502 4 LOCATION OF WELL At surface 754'FSL, 1130'FWL, Sec. 6, TgN, R13W, SM, Leg A-2, Cond 10 At proposed prod zone 1780'FSL, 950'.FWL, Sec. 6; T8N; R13W; SM 13 DISTANCE IN MILES AND DIRECTION FROM NEAHEST TOWN OR POST OFFICE' Approximately 21 mi les NW of Kenait Alaska 14 BOND INFOP~ATION TYPE Statewidesuretyand/orNo United Pacific Insurance Co. B-55502 15 DISTANCE FROM PROPOSED* Il6 NO. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT 950' 3085 (Also 1o nearest dr~g, umt, ff any) 18 DISTANCE FROM PROPOSED LOCATION' Iv PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED. 10,300 ' MD 1350' 10,200' TVD 21 ELEVATIONS ~Show whether DF, RT, CR, etc ) KB 106' above MSL 23 PROPOSED CASING AND CEMENTING PROGRAM Sec. 6t T8N, R13W, SM ._.~.., $100,000 I7 N~O ACR~ ASSIGNED TO T~,S WELL 80 20 ROTAHY OR CABLE TOOLS Rota r y 22 APPROX DATE WORK WILL START* 02 -04 -80 , , , , SIZE OF HoLE SIZE OF CASINO WEIGHT PER FOOT GRAK~E SE"CTING DEPTH quanttty of cement ,. 12-1/4" 9-5/8" 40# ......N-80 2900' App._~ox 210,0 sx in 2 stages .w,/ 17-1/4" 9-5/8,, 43.5# ~N-80 4250' stare clr @ 6500'MD. _ 1 ?- 1/Ii,, 0-5/R,, Z[7~ N-R(] 56(]0' . , . 12-1./A" 9-5/8" ~7~ p-11ri 7~)lq~ ! . .. !2-1/4" q- 5.IR" ~.~ P-1 C-75 SEE ATTACHED FOR DESCRIPTION OF PROPOSED PROGRAM. *Marathon Oil Company - Sub-Operator IN ABOV~ SPAC'g D~SCRIBE I~ROPOSED PRO(3R.~uM If ~I ~ to dee~n 'give ~ on p~sent p~u~lve zo~ ~d p~ ~w p~du~lve ~ne If ~_~1 ls ~ ~rlll or ~n d~to~ly, glve ~ent ~ on SUbsu~a~ ~ ~d mea~d ~d ~ue ver ~1 dept. Oi~e-b~u[ pre~e~ter' p~gram sAMPLEs AND CORE CHIPS [] YE/ KNO DmEcrIoNA~ SURVEY R~Z~uma~ ~if,.eEs [] NO MIlD LOC [] v~s ~.NO January. 11, 1980 =TL~ Dist:. Land Mgr_, APPROVe) B *Set IndnKlio~ C~ Revere Side BY ORDER OF THE 01/16/80 ( ) TUBI, NG/CASING DETAIL WELL NO.: ~-~D~ DATE: ~_~_~ BY: ~--S~ Item Description Set I_ts S i ze Wt Thread Grade Range Cond i tion L.ength From To I ~- ~ _~. z ~T~ ~ I ~- ~ ~. ~_ ~Z~ ~ N-Rn ~ I ~. 12. ~ ,7.< ~~. ~7 I Z- ~ ~. ~_ ~ - g)-80 ~ ! ~o. ~1 ~z?.71 _~~ .... ~~ ~.~o ~ . . _ , ,, , , ,, ' TUBI. NG/¢A$1. NG DETAIL f ' ' WELL NO.: ~-i%,~b 2~.. ~ · ,. DATE: o4- - 2~ - ~, 0 BY: ~ t::::::::.~c,~ Item Description , Set ,_s__ S i ze Wt .... Thread . G__r_ad_e Range Cond i t ion Length From To - ~" 7Z.__~ :.' , . ........ ~ ~ _., ~ ~ - .2. ') -, , r ,,....'-'-~,- ,~_, ~...,.~. ~_.,,~..~.~.,. ~_~l~i,,., o ,-o ~7-?'<'~ i~G . ,W. 4~_ !>._~ '..~ 4,-, .3 I I ~ I .._J ' "%.t / ') / · .... · .... .... ...... · TUBI, NG./CASING DETAIL 7" k ;~-- % · WELL NO.: ]])- !~D_.z, · DATE: ~. ~z~'"~ _-- _~0-.~_ _ BY: Item Description Set ts Si ze Wt Thread Grade Range Condition Length From To .- _ ...... ~_: ~# ~_. .....~~____~ ~OLI ~oJ ~;~ ~.ooJ &.27 ~ 77o.~ ~ 7,~ ~ _! : __~" ~ .R~. N-~O ~ : ~ 42..21 /oz~.~ , ,, ..... -- ( TUBI, NG/CASING DETAIL . ~- ~/~" WELL NO.: ~-!%~Dz DATE: .~.- ~ e- ~: ~., BY: , I rem Description Set .,Its ,Size Wt ;Thread Grade Range Condition Length From To ,"?_._,.'-:......,, -t-~_~I~ ~ c,.-'~L-." l.~.,,.;.-~,,,b..~.~r'~ .... ~z.~ o .4--~,.,el ' · '--,' . ....... ~. ,'~" ,_, ,Z. ~ 2-, ~ , - 47,__. 2.~- ~, 2. .9- ~/~ 4-'7 ~ " ,' - e ~/~ ~,.,,,,,. ,, n~ ' .,~'"' .'l. . t 9~ ¢.,,~" t ~.~ (,:,oo~. ,',"= ' ,.: _L A ~a/ ; ,..,c_ : - ../-. t 1'I ?,.. / ~ ~ '~ ...... ,,, - .................. "' ' ~" I. ~ : _ ~!',( -b--~. , ~ · ',/. , , _ , ,, , ,, ,, ,, , , , , Remarks: TBU WELL D-15RD2 Objective: Plug the existing water injection completion in the Hemlock formation, cut and recover the 9-5/8" casing to below the 13-3/8" casing shoe, and drill 8050 feet of 12-1/4" hole to a new location with the Hemlock formation top approximately 1780'FSL, 950'FWL, Sec. 6, T8N, R13W, SM. Run and cement 9-5/8" casing and complete the well as a Hemlock injector. Procedure: 1. Skid rig 77 over Well D-15RD, Leg A-2, Conductor 10. The tbg string consists of a CIW hgr w/ 4-1/2" SL top & btm threads, 325 jts 4-1/2" SL tbg, XA slv, 5" seal assy, & XN nipple landed in a WD pkr @ 10,585'. Tbg up wt when landed was 160,000#, dwn wt was 95,000#. 2. Open XA slv ~ 10,541'. Displ hole w/ 10.2 ppg kill mud. 3. lnstl BPV. ND tree. NU & test 13-5/8", 5000# BOPE. The BOPE will be tstd on a weekly basis & reported. 4. PU tbg string. POH & LD tbg. 5. Run 2-3/8" tbg stinger on 5" DP to sting thru perm pkr @ 10,585' &] plug back across existing perfs w/ CIG cmt. Lay cmt plug from 10,600' - 10,920' (approx 115 sx). Set perm BP @ 9500' on WL. 6. PU BOPE. RIH w/ csg spear. PU 9-5/8" csg string & remove csg slips. NU BOPE. Work 9-5/8" csg & run FPI. Check to see if csg is free dwn to 2400'. The 13-3/8" csg shoe is @ 2250'. Install csg slips. 7. NU BOPE. 8. Trip 8-1/2" bit & scraper to 3000'. 9. RIH w/ csg cutter. Cut & recover 9-5/8" csg dwn to 2400'. 10. RIH w/ OEDP. Lay KO plug from 2400' - 2250' (approx 100 sx). 11. Run 12-1/4" bit & CO to 2275'. 12. Run DD assy & KO cmt plug. 13. Drill 12-1/4" direc hole to TD (approx IO,300'MD, IO,200'TVD) according to direc program. 14. Run open hole logs as directed by Reservoir Engr group. 15. Run 9-5/8" csg string to TD w/ stage clr @ 6500'. 16. Cmt 9-5/8" csg from TD to 2800' in two (2) stages: TBU We l I D- 15RD2 Page 2 1st Stage: Cmt w/ approx 750 sx CIG w/ 4% gel & additives followed w/ 400 sx C! G neat (15.5-16.0 ppg slurry). This volumes assumes a gauge hole of 12-1/4" & includes 30% excess. Refer to caliper log prior to deciding on exact volume. 2nd Stage: Cmt w/ approx 650 sx CIG w/ 4% gel & additives followed w/ 300 sx CIG neat (15.5-16.0 ppg slurry). This volume assumes a gauge hole of 12-1/4" & includes 10% excess. Refer to caliper log prior to deciding on exact volume. 17. Run 8-3/8" bit & CO 9-5/8" csg to fit cir. 18. Run CBL from TD to 9000' & from 3000' to surf. Run gyro from PBTD to 2000'. 19. Sqz cmt if necessary. 20. RIH w/ bit & scraper to PBTD. Displ hole w/ FIW. 21. Run gauge ring & JB on WL. Set perm pkr. Run & land 4-1/2" SL tbg string in perm pkr. 22. Install BPV, ND BOPE, mount & test tree. 23. Perf & injection test as directed by Reservoir Engr. GANewberry:l 01-07-80 - MARATHON Oil_ GO.- -- DOLLY VARDE~ PLATFORM -- U Mu4 Pan Drlllin~ Hippie-. 'N Pr~v~,~fcr ( P 1 p~Rc~rn$) ~ ~CZW Swin~- Bolt Clamp J ~J / Conneators - Diagram~ 2 -13s/8"x ~,OOO~ [o 0'i Riser ~BOP Stack For t9 D~ilin9' From Uhd~r 15s/6" J J s~,f=o~ o~,~.s To ~.- I · I ' --' --- i "l 0 0 J? 12",,3, O00" CasIng Hec~d w/Flgn~ed Outlets ~. Valves ~G 17~d {~) G-28 + · G-19/ '11 oD -27- D-29 G-.12rd~ G-12 & rd e~¢D- 26 DOLLY . D-lO D-2A ~/-¢~ I D-34A D-24A 27 PAN AM R ST 0 (3, I 1 35 UN - MRO KUST '-ELL FC -IA 0-25 rd D-9 D-14 '22 .o~¢0"/.0 I I I LEGEND COME PROD. B-I INd. ABAND. PRro5. B-I 15 ABAND. INJ. B-I BENCH -I WELL PTS. 2000' 4000' ' 6000' BOOC , ...... :: .... , -" :_.: :'_ ~ ~'" j FEE T MARATHON OIL COMPANY ANCHORAGE DIVISION TRADING BAY UNIT . McARTHUR RIVER FIELD TCP HEMLOCK BENC~- I CONTOUR INTERVAL: I00 FT. 2OOO' ,.Scale' Do'e: FEB 1979 · n:LL ~- TVD 0-~_ I000- 2000- 3000. ~000_ I 5000-- 6000.! 7000- 8000 9000 I0,000_ 1600tMD 1800tMD 2100~MD KOP ~ 2270~MD, 2220~TVD 2700~MD 3200~MD Hemlock Top ~ 9560'TVD, 9658'MD, TD ~ 10,200'TYD, 10,300'MD 4300'MD Original Hole Angle 25°20' New Average Angle 6°30' Drop 19° Angle I500 t 10CO 5O0 10,935'/' / 9800~ / 8800' Original Hole Course N53°W New Hole Course 77oo' NO4°E Turn 41° Right ; 6600' -2000 5500' \ x/x !*°°, __~ ~ o 5500'MD 1130' J ! 754 t ~ 6 ~ 10,935'¥ t t t , t I I~ F~C' CR-!3 ~/7~ CASING STR rSG CASING SIZE i h~2 '--~qVA L Bottom Top Wt. EESCP-rPTZOL w/ Grade Tr.r aad "/0 lbs ~', v~,~ STAT-Z__ DATE /- /~'/- FO DESIGN BY ~?:SiON !~;~:~ ~F CCZ~CSE COLLtCSE CDF 5L~S? il/22.'~ ZDF -top of SSRE'~S~H PF~SS. ~ -~ T ~ . ..... scctzon TEl SiOi~ bot%~ tcnszon Y~LD lbs 1030 lbs ~sz ~sz P~JCE PER YC. Cf ztzs-o 29o o /JSD. ~3,~~ /V-F~ ~'~ 7000 3'~o 19'o6) /%,~oo _7poo 3~oo ~3 5 # e-,,o Fro 3oqO JRT~ . 1.3~ jv~o _~?,xo 337 g~lo 2gq~ 1,3~ ~r ~ &33o 2,93 _ ~ 3 3~o Fornalae- Collapse resxstance in %cnsicn = X (Collapse pressure raters) L>urst Pressure = ~P + I)ep~h ( Hyd. Gr. II ---5) AF (Bouyancy Factor) = z.oo- (o.o153 × ~:ua w:. z) _,.c3 IO . _ -- Ca!culatzons: CHECK LIST FOR NE%; ~,~LL PERMITS 1. Is the permit fee attached .......................................... 2. Is ~11 to be located in a defined pool ............................. 3. Is a registered survey plat attached ................................ 4. Is ~11 located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells .................... sufficient undedicated acreage available in this pool 6. Is 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... [0. Does operator have a bond in force .................................. 13. 14. 16. 17. 18. 19. I1. Is a conservation order needed ...................................... [2. Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... L5. Will cement tie in surface and intermediate or production strings ... Will c~nent cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Does BOPE have sufficient pressure rating - Test. to ~OoO psig .. Company No Lease & ?~11 No. Item (1) Fee Approve Date <7,,,-/-- ~- / "~-.~ (2) LOc. (3) Admin. :o-F-- (4) Cas.q. /~ff~ 0 -.. 0 ~3 a- ~ (5) BOPE Approval Reccmmended: Additional Requir,,~ments: Engin.~.~. _.ring: _ rev: 12/12/79 Well Histocy File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Basic Information Tape The Basic Information Tape (BLT) is a binary, partially multiplexed tape containing up to 20 data curves. The data samples are represented as IBM, 32-bit floating point numbers. The tape consists of a 276 byte heading record followed by a series of data records whose length is defined in the heading record. The last data record is followed by two end-of-files. The tapes are 9 track, 800 bits per inch. I I I III , I I j II I- -~ __ Heading Record The heading record contains the information necessary to recover the curve data from the data records and some identification information. ' 1. The Epilog Computation Center (ECC) number is a unique number assigned at one of the Dresser Computer Centers. Any questions regarding the data should, if possible, include this number. 2. Company name - Well name. These are free format fields used to identify the well. 3. The number of curves (N) is designated as a 16 bit binary integer number. This number must be less than or equal to 20. It gives the number of curves of data that will be in the data records. 4. Curve names. Each curve is designated by a 4 character name. A list of Dresser Atlas standard names is given in the appendix. These names appear in the order in which the data appears in the data record. 5. The starting and ending depth gives the first depth for which there is data on the tape and the last depth respect- ively, l%%en the starting depth is smaller than the ending depth the data is recorded downward. With field data, the ending depth may be smaller since the data is recorded from the bottom of the well upward. The ending depth may be given as 0 or 99999 when it is not known during record- ing; this occurs on BIT tapes recorded in the field. 6. Level Spacing (L). This field designates the depth increment between the data samples. The data samples are taken at regularly spaced depth increments. 7. Number of samples (F). This fSeld gives the number of samples of each curve recorded in each data record. This number will be less than or equal to 125. DATA R£CORDS The samples in the data records are recorded as floating point members (IBM standard). This consists of a sign bit, 7 bit exponent and a 24 bit mantissa normalized to the nearest 4 bits. exp. mantissa sign bit. The exponent is biased by 40~6. Thus, 41100000~6 represents the number 1.0. The data record consists of N . F . 4 bytes of data where N is the number of curves and F is the number of samples of each Curve. The first F samples in the record will be of curve 1, the next F samples will be of curve 2, etc. Each record will contain data for F . L feet of data, where L is the level spacing. The current standard usage at Dresser data center is Level spacing = L = .5 feet Samples per record = F = 125 Thus each record represents 62.5 feet of data. These numbers are given as an example only, however, since L and F may vary from tape to tape, and will certainly be different for BIT tapes recorded in the field. DRESSER COMPUTER SERVICES DIVISION FILE DATA SPECIFICATIONS (Continued) DATE 10-6-77 EXHIBIT ]. Page ]. of , ~ _ APPLI CATIOH FILE HAHE I FILE FILE NAIVE 2 NUMBER , ,,, IDENTIFICATION POSITION CHAR- NO, NO. FI ELD DESCRIPTIOH ACTER- OF OF FIELD SUB FIELD START STOP ISTI¢S DECIHALS BYTES 1 Epilog Computation Number 1 4 FP 4 2 Company Name 5 84 AN ,80 3 Well Name 85 164 AN 80 4 NJ]tuber of C1]rYe.q o]1 Tane 165 166 INT 2 5 Filler 167 168 2 6 Curve Names 169 246 AN 80 7 ........ Tape starting depth 247 250 FP 4 8 , Tape ending depth 251 254 FP I 4 _ '9 Data level spacing 255 258 FP ! 4 ..... 10 Depth column (=0) 259 260 INT 11 . ,, Filler 261 262 ....... 2 12 [ Number of samples of each curve 263 266 FP 4,., per record 13 Filler 267 276 8 _ ;_.,, ~.._~----~~~-- __ ~DOo- 5~ 4-OO SHEET 2 LIBRARY TAPE CURVE SPECIFICATIONS Company Marathon Oil Company Well TBU D-1S RD No. 2 Field McArthur River County,State Kenai, Alaska 7-14-80 Date Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR Gamma Ray .. CD/CNLOG 20-120 CAL Caliper CD/CNLOG 6-16 CORR Correction CD/CNLOG -. 5-. 5 DEN Bulk Density .... CD/CNLQ.G. 2-3 SSN Short Space CD/CNLOG 0-2000 , , LSN Long Space CD/CNLOG 0-2000 NEU Compensated Neutron CD/CNLOG ... 60-0 DENP Density Porosity CD/CNLOG 60-0 AC Acoustic BHC/AC 150-50 GRA Gamma Ray BHC/AC 20-120 RXO Shallow Focused Log DIFL .2-2000 RILM Medium IndustioF Log DIFL .2-2000 RILD Deep Industion Log ,,, DIFL , , .2-2000 SP Spontaneous Potential DIFL 0-100 ..... GRI Gamma Ray DIFL 20-120 59)7,! DAGE 1 ~ARATHO~ OIL 23~PANY .... TBU 3-19 ~CARTHUR RIVER .... KE~AI,AL,ASKA HLAC DATA EVERY [ SAMPLES GR CAL ~ORR 32~ NEd 3E~P AC 5852,00 20,00 6,00 '0,50 2,15 58,~7 50.19 5b,07 28,9~ 5852.50 20.00 5.99 -0,50 2.15 69,59 5],41 5b,OO 50,40 2.o 4.o6 ..................................................................... 2,06 ~1,52 35.~9 56,25 58~3.50 ~5.21 B.66 -0,50 563~,00 ~5.95 8.67 -0,50 5e3~.50 b0.$5 8.67 -0.50 2.05 ~2.15 ~6.55 56.58 52.U0 5835,00 5~.88 8,67 -0,50 2,05 ~2,~8 56,2~ 56,9~ 55,16 5835.50 55.86 B.66 -0.50 2.05 ~2.87 56.~_5 57.60 58.75 5~.76 B.67 -0.50 2.05 ~5.90 56.09 5~.9~ 5656.50 5537.50 53.78 8.66 -0,50 2.11 ~+1.99 52.55 56,45 49.15 5858,50 56,11 B,S7 -0.50 2,17 ~0,95 ~9.03 56,9~ ~8,0~ 5559.50 61,62 6,67 -0,50 2.19 ~0.94 27.64 55,75 51.95 58~0.50 62.96 6.69 -0.50 2.21 ~0.00 26.70 66.22 5q,39 56~1.50 61.62 8,~7 -0,50 2.18 58,55 EB.7$ 69.00 55,U1 58~2.50 61.49 B.$7 -0.50 2.15 58.16 ~1.77 69.?T 55,90 58~3.50 63, 68,37 51,~S 584~ 50 55,7~ 5845.50 58. 58,5& 58~6.50 54.7i 55,~7 5'~4.7.50 51.~+6 51.95 58q. 8.50 51.58 8.67 -0.50 2.08 36.87 5~.56 56.~5 58~9,50 ~9.99 B.6B -0,50 2,07 58,12 55,~5 56,~5 5850.50 47,05 B.S7 -0.50 2,05 59.19 56.22 56,~5 ~,~ 5851.50 ~8.52 8.69 -0.50 2.07 59.90 55.27 56.5~ 5852,50 ~7.66 6.66 -0.50 2.08 ~1.~3 5~.5~ 56.79 ~2,52 5653.50 qB.6~ 8.67 -0.50 2.00 ~+1,69 39.11 5~.66 585~.50 ~3.99 8.~7 -0.50 2,00 ~2.22 ~B.62 60.~ ~0,5~ 5855.50 ~3.99 B.~7 -0.50 2.0~ ~2.58 ~6.68 56.2l 5856.50 53.5~ 8.67 -0.50 2.10 ~1.92 55.36 128.S~ ~0,20 ' DAGE 2 MARATHON 3IL CDMPANY .... TOU 7-15 5D ,~ MCARTHUR RIVER .... KENAI,AL'nSKA HL~C §937.! 3&TA EVERY ! SAMPLES GR 5857.50 57.33 5858.00 55.99 5858°50 5{ 5559.00 53 5659,50 {9 55G0.00 ~7 5560,50 43 5~Gl,O0 ~ .81 5561,50 ~0,~0 5562.00 28.94 5.G7 -0.50 AC 6RA 1~0,$9 38,73 116.7~ 39,58 .......................................... 9U,01 53.66 95.56 1~6°5r B,6B ,,.0.50 2.00 q0.71 6,0.00 5564.00 47.29 5.G7 -0.50 2.20 37.37 27.a8 61.19 5565.00 52.65 5.65 -0.50 2.20 t5.99 !?.O~ 6b.15 29.67 5BGG.O0 47.78, B.GB -0.50 2.16, ,,~5.05 29.75 6b.08 ~1.05 5567.00 57.87 5.S7 -0,50 2.11 5~8.00 30.55 8.~8 -0.50 2,00 31.83 ~2.~5 G5.11 36,77 5~70 25.75 5571.00 52.9< 25.92 5572.00 35.~1 28,05 5573.00 35.t~2 76 26.65 557q., O0 5~.69 B.E, 5 -0.50 2.21 27.16 2G.~8 66.77 5575.00 55.50 8,67 -0.50 2.19 29.7t 2~.17 66,96 28,6~ 5576.00 5~.32 B.G7 -0.50 2,16 ~1.50 Z9.BO 58.~0 tl.87 5877.00 5~.81 5.67 -0,50 2,1~ ,55,50 50.S5 5b,05 51.75 5978.00 35.5~ 8,G9 -0.50 2.15 ~3.26 ~1.25 56,~+ 31,2~ :"::~:~: :,6:~8 ;: ::~: ::::~ ~:~ :':: :5:~:~:.;~:~ 5579,00 35.06 5.GG -O.bO 2.13 ,5~. 09 31.27 55.30 .............................. ~.::~: ............. ...................... ........ , ....... ': .,2,,',~:d~:,,:L~ , ................................. ..................... ................ ........................... :~:~;::.~.:~::~:::,.,,,,:,: .......... 5580.00 3G.VO B.GB -0.50 2.1V 3~.lG t0.91 6~.OV ............................ ~::;~ ...................... ;~,,.~.:~ ............................. ~......~k~L~ .............. ~ ......... . ................ ~;.,~'=~,~ .......~,~.~.;:~;,.,~.. ,- ~,.... ........ .,~;~:~;~:~. .................... ~.~.....~:~..,..~;:~:~,..~x.~. ...................... ~=~.~a~,,.x~x~=x~x;~ ..................... .,.~,~.~ .......... 5581.00 55.~2 B.G7 -0.50 2,15 ~4,56 51.59 G~.BO 52,~5 ................ : ....................... ~ ................................................................................................ & ............................ ~:L..-...L ............. L::2 .......................................................... $~:::.:..._t:.L_.::L .............................................. ~.~:~.......~.~ .............................. :.~::.~::.~..:.~....::~.~:~::~::,~ ....................... ~;.~::::... :~s:~:::.~:~_. ........................... ..:.~2~::': ..~k.: ............................... 5582.00 55.91 B,GB -0,50 2,07 ,52,6~ 55,01 66.50 28,~5 PAGE 3 MARATH04 OIL CD4PA4¥ .... T.~U ]-15 OD 9CA~{TguR RIVER .... KENAI,A~'ASKA qLAC 5957,1 DATA EVERY 1 SA~mLES 58~3,00 5683.50 5~8~.50 5885.00 SR CAL CORR DEq NEd 35.79 8.69 ....... ;~~-- 2.06 33.1~ -55.89 35.30 8.~8 -0.50 2.06 32.99 ~5.79 AC ~7,1~ ~0,89 ~?,72 29,91 $7,~8 58,59 SO,~O 5585,50 56,B~ 31,75 5887,50 35.~2 B,55 -0.50 2,11 52.80 32.~7 5886.00 588~.50 ~.~0 8.57 -0.50 2.15 .... ~'~'~' ....... 50.~0 5~.65 ~0,65 5887,00 ~7.38 8.69 -0.50 2.18 3~,3~ 28.51 5~.06 $1,26 5888,00 ~'5,79 8,57 -0,50 ~,22 a9.91 ~6.2'5 6~,7~ $0,77 5589.50 35.06 8.67 -0.50 2.30 29.08 21,31 6~.6~ 11,51 5B90,50 35.18 8.67 -0,50 2,32 50,95 ~0,20 61,62 52,85 5591.50 35.18 8,67 -0.50 2,23 32,7~ 25,17 S1.79 31,B7 5892,50 35.79 B,S9 -0,50 2.17 53,97 ZB,gS 61,29 ~0.17 5893,50 37.50 8.$7 -0.50 2.1l 36.23 52.63 ~0,69 30,65 5~9~,50 59 7 61,59 31,U2 5895,50 37, 35,05 5896,50 38. 5B97 50 60 33,8~ 5~98.50 36, ~.U 35,91 5599,50 38.73 8,SB -0.50 2.07 33,95 155.06 55,21 ~6,65 59{}0,50 ~,36 B,S$ -0,50 2,11 52,95 52,91 5~01.50 ~9.~8 5.$7 -0.50 a.19 ~1.~7 ~7.8~ 6Z.Oa ............................................................................................................................................................ , ................ ................................. ~.;~ii~,:¢i:~; ,}~::.~i:~:,.;,,,;; .................... :, :i!~,,2::~::~.? :: :? 5902,50 ~9.25 5.$7 -0,50 2,28 51,19 E2.17 65,1U ~f~:,;. .............. -L..-:L-..:: ~.~L,,.:i ~,Z; ............................... i~ ~;,l,i~;, ' . L,:i; ::!..',i ~ ,,.,:Z ................................................ ~ .................................. ,,.,,.....,.L ........... ~::~:f,.; :;;:; :~ , ................. ,.:~::f:::. ................ ........................ . ........... 5903.50 51.09 5.$9 -0.50 2. 1 32.7 aO.5 6~,18 ~2,5M 590~.50 50.72 8.$S -0.50 2.30 3t.95 al.~l 5906,50 ~.2~ B.67 -0,50 2,19 32,95 ~7.78 66,9Z 5~07,50 ~5.~6 8,69 -0.50 2.17 5~,55 29.00 ~AGE ~ M~RATHO~ 3IL S3~PA~¥ .... TSU 3-15 ~CAR?HUR RIVER .... KE~AI,A~'~$KA HLAC 3ATA EVERY 1S~9~LES 5g09 5909 5910 5910 5911 5~12 ,00 -0.50 3{+, 9q. ,50 .00 ,50 ,00 ,50 . o 0 ..... -~-~ :V'5- ......... -L~ :"~-~4 ........ : o-~'-e, 6 ...... -f:,-i"~~ ....... ~ 5. ,+ 5 ~ Vi- ...... ~'; ~ ~ .... '-0% ~6 ........ ~-';'~ ~- ..... ~"~-T~ ......... ~-~-~Z- .... ~-~-~-~ ........ ~-~--'-~ ~ ...... ~8. e5 .... -~'~-~-f ........ :-~ ~'-5~- ............ -f2-f~ ........ ~-~-~ ........ '~;"~-~- ..... f'~'i'~- ......... ~'f ~-~f ...... ....................................................................... 5912,50 67,63 8,68 -0,50 2, {.q. ;55o25 5{.,10 82,~+~ 55,5'~' ......... -s-~-'~-~-. ~--~ ............ ~-~-;-'~-~- .................. ~-'; ~"~ -- :b";-'~-- ~;'-i-~- ......... :~"4-:~-~- -'~"~-',-~'~ ~-~---:'~'~ ~;'~'~- '- .......... ~ ~_~..~. ~.~ .......... _~.~..~._~_~. ............. -~i'.~.~'-';---; ~S-~-]~e~2 ..;. '"~;~_~'!~211;.~K;.~-_i~i_~.";';~;~;~.~-;-; ~ ..;;';.~'.~'i~.~.';"2.~-;,~?/~/~ ................ 591~.00 35.79 B,G7 -0,50 2,17 5~,2~ ~B,B5 B~.~U 32,~5 5916.00 qO.07 8.GB -0,50 2.22 5~oB2 25,91 82.50 35,~2 5917.00 {+0.56 8.GB -0.50 2,2q- :55,90 25.00 B1.3~+ 3q., 52 59-'18, O0 q0.69 8.69 -0.§0 2,2q. ,~5.83 ~{+,76 77,5q 5919,00 3~.32 B,GB -0.50 2.26 5G.25 E5.~1 86.05 5920°00 53.9~ 68 -0,50 2,~8 ~5, 7q,~9 3~,q~T 592 O0 33 1 32,5~ 5922,00 29.7~ 30,65 5923,00 28.51 26o9~ 5 )2~.00 30. Oq. .,67 '.'~ 5 5.00 53,22 B,G7 -0, 13 2.25 ,~, 17 2~+. 37 Gl.~3 i~Ti ~:i~ii~'::~i':~]~i:~i~!i:;: ........ '~':~?~iT~!~!~¢:~ii~:~ii~ ~7'"::~'i:~i~: ~'?~T~:T~ .......................................................... ~:. ................ ......................... .............................. ~.~ ~;;~ .......... ........... ;,S:g;~ ............................. 'h:~.~iZ~:~z~:~s::~:,~:~; ;~ .':'' ~.,&::,:& ~,,.,.,,,,,,,2~,... ....... 5926.00 55.5~ B.G7 -0,50 2,21 ,51.16 26.77 66.65 L~:hL ........... :~&~;~' ~,.~.~.~i~....~ ............. .............. i..,.....~,_.~..,:~::i i~ ._.2~...L~ .............................. ........ ................... ....................... ........................... :~A~,~.~'.~).~}:~;~ ~...~:~. ...................................................... 5928,00 36.65 8.6B -0.50 2,16 :53, B2 ~9.66 78.15 )0.77 5~29.00 55.q2 8.68 -0.50 2.1~ 5~.88 ~O.B7 82,21 31.1~ PAGE 1 DqARATHDN 3IL COMPANY .... TBU 3-15 BD ~? ~CARTHUR RIVER .... KE~AI,Ak'ASKA flLAC 5937.1 DATA EVERY I SAMPLES RXO 6020.00 0.20 10,02 6020.50 0.20 0,20 ~021,50 6022,00 6022,50 6025,5O 12,00 6,15 10.09 1R,U5 6,72 ~0,62 10.14 12,16 6,93 58,91 52 1~.28 13.52 37,71 8.76 ....... i-¢-i'~ ........ 38. ~ 5 37.48 8.66 15.08 59,~6 59,35 0.20 --6-,-~-~ ....... 0,20 0,20 602~,00 0.20 8,59 602~.50 0.20 '"' 60:~5'00 0'20 6025.50 6026.50 0,20 7,02 13,79 97,29 ~8,31 7,82 6,63 15,86 6027,50 7,38 9,87 19.65 98,3~ 58,0~ 6028,50 6,76 10,76 21.95 98.12 3~.85 6029,50 16.20 10,69 22,57 97.50 33,06 6030,50 28,11 12,82 23,~2 96,67 32,06 603 50 46 3( 6052,50 50. 6033,50 21, 60 iO 17,9 96,17 56, 60 50 17,91 6.59 7,59 96,02 93,13 6037.50 8.05 6.19 6.94 96.63 91.8~ 6038.50 6.58 6.02 6.68 96.63 ~0.53 60.59,50 6.17 6.32 ~0~+0.50 7,03 7.03 ~,57 95,71 ,o 7.66 7.25 7.~4 9~.85 82.06 ..................... 6'"0"~7"2250 ...................................... '?'-;"3'~" 7. o 7 B. 39 9 ~. 09 S 0.90 60~.50 7.20 5.76 B.23 93.75 8~.12 mAGE 2 rtARATHON DIL SDMPAN¥ .... TBU 0-15 MCARTHUR RIVER .... KENAI,AN'~SKA qLAC 3ATA EVERY 1S~9~LES 5937,1 6045,50 G0~6.00 6046.50 G0~7.00 60~7.50 6U'{8.00 RXO RIL'4 RIL9 Sm 7.WU ~.71 7.Z1 96.02 87.95 ..................................................................................................................................... 9 · ? ~ ..... ~':¥~ .... ~ Z~-~ ........... ~YT?~ .... ~i~-~ ............................................................................ ................................................................................................................................ 5,68 V.7~ 5.50 98.05 GO~9,O0 5.77 ~,~2 5.05 9B.06 9q,52 6049,50 5,65 ~,25 ~,85 98,06 9~,90 6050.00 5,56 ~,11 ~.71 97.96 9~.56 6051,00 5.72 5o53 ~,51 96.95 6052,00 5,~3 ~,63 ~,~2 96,~9 88,~2 ~053.00 5.33 3,V5 V.O! 96.09 ~7.54 605q.,00 q., LI. 5 ~.50 3.85 96,06 :~::i~~: :::~:~::~::i5:!0 :i~:::!~:8 ~ :~:,.:::~5:~ ~.,:,~::~?:7 6055,00 ~.20 3,58 ~.69 96,16 80,90 G056,00 ~,6q 5,~ ~,55 96,97 6 o e o. o o~. ~ ~3Z2~%~~iZZ:2':~ ~ ................... -~gY;"'O~' ..................................... ':gT~a ,.~:~ ::::~':~ ::~:~, ~:~" 60G2.00 ~.07 3.B6 3,91 9~,55 75.~0 GOG3.00 3.75 ~.57 ~.56 93,7~ GOG~.O0 ~.10 ~.78 5,0~ 92,21 76,02 GOG6.00 5,~ ~,90 G.28 91.B5 81.59 ~O~T.O0 ~.GO 5.~9 G.6~ 92,55 G068.00 ~.~3 5,B7 ~.29 93,68 ~:~ ~OT"'-'~ ", ......... F ......... ?':'~~i~: ........... ~: ~='"'?~ 6069,00 5.18 5,G1 G.90 93.1E 95.31 ~070.00 5.91 5.~G 7,72 91.73 92.55 ~AGE 3 MARATHON OIL C3MPA~Y .... fBU 2-15 SD ~ MCARTHUR RIVER .... KENAI,AL'~$KA qLA,C 5937.1 ]&TA EVERY I SAMPLES 6071.00 ~071.50 6072.00 G072,50 6073.5O $074.00 GO7{..50 RXO RIL~ ~ILD SP GRI 5.79 5,26 7.78 92,q'2 98,96 5.~8 5,1~ 7,5q. 92.S7 99.9~ ....... ~7~ ~ ...... ~20'~ ........ %';T~- - -~';~- ...... ~ 9.9 ~ .................................................................... .................................................................................. -- 5.q.$ ~.8! ~.~ 9~,09 99.05 .... ~-;~- ....... ~. 56 ..... ~' 9~, ~ ...... ~.~ ....................................................................................................... ................................................ 5.q.8 ~.~ 5.25 92.97 97,08 ........................................................................................................................... .................................................................................................................................................................................................... ................................... 6075,00 4,03 q'.22 q.,6% 93,70 96,7r+ G078.50 {.lq. 5.q.7 5.15 G079.50 ~.GO 6.07 $.09 ~].58 ~6.66 G090,50 ~.70 G,G5 ~.9~ 92,8~ 6081.50 ~.86 6.91 7.58 92.17 81,19 ................................................................................................................................................................. 5. %0 8.00 90,B~ 80. 6082,50 G083,50 60~5.50 . 5.9f 5.03 ......... ~,~,~>.~,.~ ....... ~ ................. ~ ........... .;~,,~.,... ~.~.~ ..... ............ :;~..,~:;. ................ $087,50 q..65 G.11 9.76 91.81 50.68 G088,50 13.q. 6 5.q.l 18.71 92.10 29.16 G089,50 17,78 11.6& 1~.59 92.7~ 29,72 5090.50 2~,58 16.11 ~1.7~ 91.50 ~6.9~ ............................... .: J::J.,.,,,-~,,..:LL,.i: ..... . ...................... :L _.::i:i:;:~:::::.::::~:L..._...:~: ........................................... ~L~.._...._L..:~ .................................... ~i~ }2~;:&&:: ................................................ ........... ::::~. '" .i:.2:!~:2::~':i:::i~?:~::::~:::~:i.:. ............................... ~091,50 13.55 13,39 15.9~ 90.55 57,70 G092.50 9,1~ ~.GG 11.1a 89,~G 75~0G 6093,50 7,12 6.51 5.3~ 88.51 82,25 ~.~,~"~ 2~-'~?~,Z:"~--~;~?:~: ~"-'"~ ~"'""~ ~'~::~2~,~,~LY ................. ,~ .............. ~ ........... ~ .......... 'Y'":: ......................................... G09~.50 5.97 5.~5 ~.8~ 87.5~ 90.52 G095.50 5.25 ~.90 6.05 87.~ ~1.7~ ~AGE 4 MARATHON OIL COMPA~Y .... TOU 0-15 BD ~ MCARTHuR RIVER .... KE~AI,AL{SKA HLAS 5957.1 DATA EVERY 1 SA~LES RXO S096.50 ~.89 RILM RYLD SP GRI G097.00 $097.50 GO'~8.O0 6O98.50 G039.00 ~099.50 GiO0.O0 S100.50 6101.00 6101.50 GIO2.0U 4.73 4.97 %.95 86.59 8~.90 .82 .92 ...... 85.79 5.05 %.9B {.84 85.52 79.09 ............................................................................. 4.98 5,10 %.90 84.59 72.81 5,3~ 5,15 ~,99 85,75 70,53 5.35 5.01 5.3& 8~75 $8.$0 ........................................................................................................................................................................... 5.18 4.95 S.uO 85.52 65.2~ 6103.00 5.27 5.20 $.5& ~2.39 63.52 GlO~.O0 5,57 5,%0 S.7~ 84,01 60,05 G105.00 5.58 5.%9 S.98 85.01 55,$0 GIOG.O0 5.59 5.53 S.95 B5,59 52.55 S107.00 5.~5 5,5~ 7.00 85.09 ~8.02 · ~., ................................... .............................................................................................................................................................. ~108.00 5,3; 50 7.01 8~,9# ~7. $109.00 5. 6110.00 5. $111 O0 5 ~{ .& ................. .~:.,., ............... .... L ........................... .~; .................................................................... Gl12.00 5.12 GllS.O0 ~.95 5,G2 ~,76 B6.lO ~9,93 Gll4.00 4,81 5.~B G,B6 8~,72 50,90 G115.00 ~.GG 5.55 G.~B B3.G8 Gl16.00 ~.67 5.73 7.1~ B3,%6 51.6S GllT,00 ~.93 5.B7 7.59 83,16 51,66 Gl18,O0 ~,81 5.9S 7,S8 B2,BO 51,5~ Gl19,O0 4,88 6.0~ 7.71 82,69 51,30 11 000000 7777777777 000000 7777777777 11 000000 7777777777 000000 7777777777 llll O0 O0 77 O0 O0 77 1111 O0 O0 77 O0 O0 77 11 O0 0000 77 O0 0000 77 1i O0 0000 77 O0 0000 77 11 O0 O0 O0 77 O0 O0 O0 77 11 O0 O0 O0 77 O0 O0 O0 77 11 0000 O0 77 0000 O0 77 tl 0000 O0 77 0000 O0 77 1! O0 O0 77 O0 O0 77 il O0 O0 77 O0 O0 77 111111 000000 77 000000 77 llllll 000000 77 000000 77 bSbbb6 000000 44 44 5555555555 333333 bbSbbb 000000 44 44 5555555555 333333 6b 00 00 44 44 55 33 33 66 00 00 44 44 55 33 33 bb O0 0000 44 44 555555 33 66 00 0000 44 44 555555 33 6666666b O0 O0 O0 4444444444 55 33 bbbbb6b6 O0 O0 00 4444444444 55 33 bb 06 0000 00 44 55 33 6b 66 0000 O0 44 55 33 66 bb O0 O0 44 55 55 33 33 bb 66 O0 O0 44 55 55 J3 33 6b6b6b 000000 44 555555 333333 bb6666 000000 44 555555 333333 *START* USER PCAb [10707,60453] jOB SHIP SEQ. ¢128 OAT& 05-dUN-80 20:39:50 MONITOR S~S kLlOE37 APR-80. *START* *STARI* USER PCA~, [10707,6045~] JOS SHIP SEQ. 4128 DATE 05-dUN-80 20:39:50 MONITUR 6WS Ki, lOk.t7 APR-80. *START* V¥ VV YV VV VV VV VV VV VV VV VV VV VV VV VV VV VV EEEEEEEEkE RRRRRRPR VV EEEEEEEEE~ RRRRRRRR VV ~E RR RR VV EE H~ RR VV kk RR RR VV EE R~ RR VV EEkEEEEE RRRRRRRR VV EEEEEEEE RRRRRRRR VV k~ RR RR V¥ Ek RR RR EE RB RR EEEEEEEEEE RR RR 1Iiii1 IIIIII I1 I1 II II II II 1I Ii ii II IIIIii iliiii FF PF FFP~[P'~ [F~rPFP~ FP F~ ~F XY XY Y¥ XX YX Y¥ YY XY X¥ YY 000000 000000 222222 000000 000000 222222 O0 O0 O0 O0 22 22 O0 O0 O0 O0 22 22 O0 0000 O0 0000 22 O0 0000 O0 0000 22 O0 O0 O0 O0 O0 O0 22 O0 O0 O0 O0 O0 O0 22 0000 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 00 00 00 00 22 000000 000000 2222222222 000000 000000 2222222222 *START* USER PCA6 [10707,6045J] dOB SHIP SEQ. MONITOR bwS KLIO~J7 APR-dO. *START* FIbE: DSKHIVERIFX.O02<05Z>[10707.6045~] CREATED: PRINTED: 05-JUN 80 20:40:05 QUEUE SWITCHES: /FILE:[ORT /CUPIE8:I /6PACING:I /61MI1':~7 /FORMS:NORMAL 4128 DATE 05-JUN-BO 05-JUN-80 20~35:08 20:39:50 SCNLUMBERGER COMPUTING CENT~H 10707,6045] LENGTH: 132 BYTES H~EL NAME: P.C.A.b. SERVICE NAME: EDIT REEL, CONTLNUATIUN NUMBER: 01 PRF, VIOUS REEL NAME: C(IMMENTS: LIS FORMAI CUSTOMER TAPE DATE: 80/ 6/ 5 TAPE HEADEB LENGTH: 112 BYTES TAPE NAME: 6045] DATE: 80/ 6/ 5 SERVICE NAME: EDIT TAPE CONIINUATIUN NUMBER: 01 PR£VIOU$ IAPE NAME: COMMENTS: TAPE COMMENT6 CASING SIZE /].37/SU~TM DRILLER 2250/BIT SiZE 12.25/ fLUID TYP~ SP~R-R~$/DEN$ 9 6/VI$C 48/PH 10/FLUID LOSS 10.2 M~/ RM 3-88@70 F/RMF ].18~68 P~RMC 68 ~/ MAX REC TEMP 117 ~/ TAKEN f'ROM RUN#i Dib bOGkD 26MARL0 GR 16 BAD ~ROM 2250 TU 3~70 AND ~ROM 427 LOF FIL~, HhADER LENGTH: 62 BYTES FILE NAME: ~DIT .00! ~AXiMUM PHYSICAL R~CURD LENGTH: PREVIUU$ FILE NAME: 1024 BYTES WELL SITF. ]N~OHMATION RECORD LENGTH: CUMPANY: WELL: f'IELD: RANGE: TOWN: ~'f~ I fql~l · 178 B~TES MARATHON OIL CO. TBU 0-15 RD#2 MCAR~HUR BLYEB 8N STATE: ALASKA DATA f{JRMAT SPkCIf ICArlON LkNGTH; 610 BY'I'kS ~N'rRY BLOCKS: T2PE 0 6iZ~ RkP COD5 ~NTR2 1 66 0 DATU~ SPECIFICATION BLOCKS: ENTRY IC TUUb OkPT 2 SP ILD 4 ILM DIL 5 SFLU DIL 6 GR 7 UT GR CNL 9 CALl CNb 10 DRHO fDC 11 NPHI CND 12 RHOB CNL 1] N~A1 CNb NCNL CNL 15 ~CNL CNL UNITS APl AP1 AP1 AP1 FILE# 61ZE EAP PROC SAM REP OEPT 8~I~T FT 0 0 0 0 0 4 0 0 1 68 0 0 MV 7 I 0 0 0 4 0 0 1 b8 0 0 OHMM 7 12 46 0 0 4 0 0 1 68 0 0 OHMM 7 12 44 0 0 4 0 0 1 68 0 0 0~ ; 22 1 0 0 4 0 0 1 68 0 0 GAPI 7 31 32 0 0 4 0 0 i b8 0 0 US/F 7 52 32 0 0 4 0 0 1 68 0 0 GAPI 42 31 32 0 0 4 0 0 1 68 0 0 IN 62 28 1 0 0 4 0 0 I b8 0 0 G/C] 42 44 0 0 0 4 0 0 I 68 0 0 PU 4~ 68 3 0 0 4 0 0 1 ~8 0 0 G/C3 42 35 I 0 0 4 0 0 1 68 0 0 C/C ~2 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 ~ 0 0 1 68 0 0 CPS 42 34 93 0 0 q 0 0 1 68 0 0 Dt, PTH 6018,000 6000,000 5900,000 5800.000 57O0.O00 5600,000 5500,000 5400,000 5300,000 5200,000 5100.000 MNEMONIC SP GR NCmL SP GR DRHU NCNb SP DRHLI NCNb SP GR DRHU NCNb SP GR DRHO NCNb SP GR DRHU NCNb SP DRHO NCNb SP DRHO NCNb SP GR DRHO NCNb SP GR DRHU NCNb SP GR DRHO NCNb VAL -15 39 0 3268 -70 39 0 3268 -73 52 0 2574 -90 48 -0 2960 -52 bO 0 2154 -48 46 0 2O78 -61 84 0 1084 -05 70 0 2504 -71 43 0 2406 -71 38 0 3110 -112 36 0 2548 UE .188 .281 .O59 .000 .875 .281 .048 .000 .125 .531 .033 .000 .688 .500 .002 .000 .313 .969 .022 .000 .875 .938 .030 .000 .938 .750 .042 .000 .875 .125 .066 .000 .938 .250 .010 .000 .438 .719 .014 .000 .125 .b56 .028 .000 MNEMUNIC ILO NPHi ~CNL ILD DT NPH1 FCNb ILD DT NPHi ILD DT NPMI FCNL ILD UT NPHI ~CNL ILD DT NPHI fCNb 1LD DT NPHI fCNL iLD UT NPHI ~CNL ILD DT NPHI FCNL ILD DT NPHi fCNb ILD DT NPHI FCNL VALll 10. 42. 929. 10. 98. 42. 929. · 100. 26. 881. 10. 95. 24. 1047· · 93. 35. 621. i 96. 33. 580. · 104. 45. 405. · 99. 36. 643. · 97. 29. 812. 4 96 26 1074 1 109 29 854 820 750 773 000 766 750 432 000 516 750 025 000 414 188 316 000 805 188 010 000 955 188 887 500 059 188 361 5O0 852 750 816 000 461 563 736 000 .965 .375 .563 .000 .984 .000 .199 .500 MNkMONIC IbM GR RHUD ibm GR GR RHO8 1bM GR RHOB IbM RHOB IbM GR RHOS GR RHOB GR RHOB IbM GR RHO8 GR RHOB ILM GR RHOB VALUE 8.836 71.375 2.172 8.836 71.375 2.158 9.602 53.750 2.344 9.703 49.438 2.328 7.961 73.813 2.45~ 2.861 46.844 2.336 6.430 98.688 2.283 b.785 82.250 2.393 5.527 44.344 2.338 4.598 43.594 2.373 2.217 41.531 2.28] MNEMUNIC SFLU CALk NRA~ ~f'bU CAbI NRAT SFLU CALl NRAT SFbU CALl NRA~ SFLU CALl NRAT SFLU CALl NRAT 6FLU CALl NRAT SFLU CAbI NRAT SFLU CALl NRA'£ SFLU CALl NRAI SFLU CALl NRAT VALU~ 1·512 12.250 3.299 1.512 b.383 3.299 11.b09 13.86/ 2.736 10.375 12.96i 2.b00 b.971 13.383 3.281 2.789 14.578 3.248 7.340 13.i80 3.850 5.828 13.453 3.381 5.9~4 12.992 2.961 5.027 12.664 2.742 4.548 12.516 2.910 DEPTH 5000,000 4900.000 4800.000 4700.000 4600.000 4500,000 440O,O00 4{00,000 4200.000 4100.000 4000.000 MNEMONIC SP GR DHHU NCNb SP GR DIRHtJ NCNb SP DRHO NCNL SP DRHO NCNb SE' GR DRHU NCNb SP GR DRHO NCNb SP GR DRH[J NCNb SP GR DRHU NCNb $P GR DRHU NCNb GR DRHO NCNb SP GR DRHU NCNb VAL -67 18 -0 1290 43 0 2440 -58 43 -0 1366 -56 50 0 2023 -58 0 1768 -61 101 0 1250 -59 147 0 2190 -56 141 0 1511 -104 36 0 1923 -62 68 0 1840 -89 ]9 0 2482 UE .625 .328 .00q .000 .188 .781 .017 .000 .125 .906 .005 .000 .188 .656 .065 .000 .375 .250 .045 .000 .875 .O00 .005 .000 .500 .5O0 .032 .000 .75O .500 .047 .000 .375 .625 .023 .000 .188 .563 .080 .000 .438 .031 .022 .000 MNEMONIC OT NPHI {~CNL ILD DT NPHI FCNL ILD DT NPHI FCNL lbo DT NPHi ~CNL ILD DT NPHI FCNL 1LD DT NPHI fCNL ILD DT NPHI ECNL ILD OT NPHi ~CNL iLO DT NPHI fCNL DT NPHI FCNL ILD UT NPHi FCNL VALUE 220.125 130.125 73.877 235.875 2.584 100.750 27.246 818.500 21.297 128.500 59.912 293.750 4.531 87.188 28.027 092.500 b.414 109.188 44.189 447.750 Bb.lBB 130.125 69.141 218.750 8.289 110.o00 42.090 543.500 5.695 115.563 43.408 398.250 5.000 112.563 30.615 609.500 b.219 105.188 44.189 452.000 3.855 110.563 32.129 740.50O IbM GR RHOb GR RHOB IbM GR IbM GR RHUb GR RHUB ILM GR RHOB GR RHO~ ibm GR RH00 ILM GR RHO~ iLM GR RHOB IbM GR VALUL 805.000 21.500 1.364 2.721 41.594 2.277 18.047 45.344 1.758 4.258 50.875 2.422 5.930 70.375 2.301 63.531 13.805 1.402 7.539 64.088 2.297 5.977 56.063 2.307 4.906 41.563 2.219 5.500 73.938 2.577 4.043 41.813 2.273 MNEMONIC SFLU CALl NRAT SFLU CALl NRAT SFLU CALl NRAI' 8FLU CALl NRAr SFbU CA6I NRA2 $FLU CALl NRAT SFLU CALl NRAT $~6U CALl NRAI SFLU CALl NRA'I SFLU CALl NRAT ~FLU CALl NRAT VALUL 511.000 13.383 5.438 4.742 12.563 2.785 25.018 12.969 4.652 U.000 12.820 2.846 7.223 13.213 3.789 408.~50 13.102 5.168 /.195 12.781 3.058 6.020 14.531 3.775 b.355 13.688 3.039 5.281 14.1/2 3.809 b.102 12.633 3.113 7 D~PTH :{900.000 ]800.000 3700,000 3600.000 3500.000 ]400.000 3300.000 3200.000 3100.000 3000.000 2900.000 N N E M O l',l lC SP GR DRHO NCNb, SP GR DRHU NCNb SP OR DRHO NCNb SP GR DRHO NCNL DRHO SP GR DRHO NCNb, SP GR DRHO NCNb, SP GR NCNb, GR DRHO NCNb, $P GR DRHiJ NCNb SP GR DRHU NCNb VALU~ -64.813 49.813 0.023 2136.000 -66.188 56.281 0.043 1877.000 -55.875 49.719 0.063 1747.000 -49.875 58.500 0.055 1934.000 -78.938 57.125 0.011 2468.000 -59.188 62.563 0.019 2072.000 -76.563 38.344 0.066 2256.000 -72.563 132.125 -0.02! 3460.000 -73.938 153.125 -0.000 2144.000 -62.438 139.875 0.119 1397.000 -73.813 i44.875 0.030 1687.000 MN EMON lC DT NPHI 1LD DT NPHI FCNb ILD DT fCNL, iLD DT ~CNL ILD DT NPHI iL,D DT NPHI fCNL, IL,D DT NPHI ~CNL, DT NPMI FCNL, IL,D DT NPHI FCNL lbD DT NPHI fCNL IL,D DT NPHI fCNL VALUE 5.039 112.000 36.523 652.000 7.293 115.375 44.287 475.000 7.012 115.188 48.389 424.750 6.]36 110.750 37.402 586.500 8.195 115.750 37.744 655.000 5.320 116.563 33.789 586.000 5.328 123.000 32.617 722.500 5.246 86.375 30.762 981.500 b.258 121.000 36.621 633.000 7.645 131.750 52.881 310.500 7.262 139.750 41.504 446.000 MNLMONIC GR 1LM GR RHO~ RHOB GR GR RHOD IbM OR RHOB IbM GR GR GR GR RHOB VALUE 4.965 53.719 2.299 b.469 66.500 2.352 b.227 64.063 2.307 5.863 59.656 2.338 b.867 49.781 2.264 4,668 66.063 2.271 5.035 41.688 2.299 5.539 46.531 2.355 5.836 63.094 2.244 7.070 56.025 2.158 b.164 58.281 2.254 SFL,U CALl NRAT SFhU CA6I NRAT SFL,U CALl NRA1 SeLL CALl NRAT SFbO CALl NRAT SFLU CALl NRAT SFL,U CALl NRAT SFLU CAb1 NRAT SFbU CALl NRAT CALl NRAT $FbU CAL, 1 N RAT VAbUE 4.652 13.219 3.359 b.027 13.867 e.656 13.805 4.031 5.977 13.016 3.402 7.828 12.523 3.410 4.74b 12.820 3.197 5.758 12.453 3.141 7.Bib 12.563 3.020 8.063 12.033 3.350 5.746 13.172 4.266 5.660 13.500 3.b43 DEPTH 2800.000 2700,000 2600.000 2500.000 2400.000 2300.000 2200.000 2157.000 MNEMONIC SP GR DHHU NCNL, GR DRHU NCNb GR DRHU NCNb DRHU NCNb SP GR DRHO NCNL SP GR DI~HO NCNL SP DRHO NCNb, GR DRHO NCNb VA -8 14 219 -7 14 2:tl -8 13 217 -6 14 237 -6 14 188 14 2O9 -20 12 150 -96 -99 104 LUE 3.063 1.750 0.077 4.O0O 7.750 3.375 0.023 8.000 9.813 8.500 0.020 4.000 9.313 0.125 0.006 4.000 5.625 5.125 0.034 9.000 b.938 1.750 0.071 0.000 3.375 1.000 0.504 6.000 9,250 9,250 0.688 1.000 MNEMONIC 1LD DT NPHI fCNL NPH] ~CN6 DT NPHi FCNL DT NPHI ~CNL DT NPBi FCNL DT NPHI ~CNL DT NPH! ~CNL ILD DT NPHI FCNb VALUE 5.746 129.125 36.328 649.500 8.023 123.750 38.~30 648.000 8.039 liS.000 36.570 b10.500 6.215 125.750 35.791 6]8.500 5.434 124,56] 35.645 468.000 6.418 130.125 34.717 545.000 2000.O00 6].594 49.56! 349.500 -999.250 -999,250 73.486 174.875 MNEMONIC GR GR GR RHOB kLM GR RHOO IbM GR HHOU G~ RHO~ GR RHO~ GR ~HUB VALUE 5.b17 57.750 2.225 7.359 57.156 2.281 7.901 60.750 2.293 5.973 54.875 2.258 4.859 56.531 2.250 5.813 56,250 2.246 20OO.O0O ]9.719 2.129 -999.250 24.2~9 1.227 MNEMONIC SFLU CALl NRAT SFbU CALk NRAT 6FLU CALl NRAT SFLU CALl NRAI SFbU CAbi NRAT SFLU CALL NRAT SFbU CA6I NRAT SFLU CA6I NRAr VALUE 5.977 lb.l/2 3.42b 1.000 14.406 ].492 9.00O l~.Olb 3.36~ 5.484 13.984 3.33~ 7.035 15.602 3.373 5.219 21,516 3.479 2000.000 12.bi; 4.060 -999.250 12.586 5.395 SUMMAB¥ U~' DATA P, ECURDS NUMBLR (]~ RECORDS: 483 LLNGTM OF RECORDS: 966 BITES LENG1H OF LAST RECORD: 666 BYTES FiLE IHAILER LENG3H: 62 BXTE$ ~ILE NAME: ~DIT .00! MAXIMUM PHXSICAL PECURD LENGTH: NEXT ~ILE NAME: Etl[. TAPE TPAILkR I, ENGTH: 132 TAPE NAME: 60453 SEHVICf, NAME: EDIT TAPE CUNIINUATIUN NUMBER: O1 NEXT TAPE NAME: C(]MMENT$: 1024 DATE: 80/ b/ 5 11 000000 7777777777 .--000000 11 000000 7777777777 000000 1111 O~ O0 77 O0 O0 1111 0 O0 77 O0 O0 11 O0 0000 77 O0 0000 11 O0 0000 77 O0 0000 11 O0 O0 O0 77 O0 O0 O0 11 O0 O0 O0 77 O0 O0 O0 11 0000 O0 77 0000 O0 11 0000 O0 77 0000 O0 11 O0 O0 77 O0 O0 11 O0 O0 77 O0 O0 111111 000000 77 000000 111111 000000 77 000000 7777777777 7777777777 77 77 77 77 ? 77 77 77 77 77 660666 000000 44 44 5555555555 066660 000000 44 44 5555555555 66 O0 O0 44 44 55 66 O0 O0 44 44 55 66 O0 0000 4~ 44 555555 66 O0 0000 4 44 555555 66666666 O0 O0 O0 4444444444 55 6bOb66h6 O0 O0 O0 4444444444 55 66 66 0000 O0 44 55 66 66 0000 O0 44 55 66 66 O0 O0 44 55 55 66 66 O0 O0 44 55 55 66~666 000000 44 555555 666666 000000 44 555555 11 11 1111 11il 11 I1 11 11 11 11 11 11 111111 111111 SSSS F~ ~ ~ F L PPPP RRRR U U DDDD H H OOO gLEEE S F L P P R R U U D D H H O O E S F b P P R R U U D D H H O 0 E ~SS F~ ~ ~ h ..... PPPP RRRR U U D D HHHHH O O LEEE S ~ b P R R O U D D H H O O E S F L P R R U U D D H H O O E SSSS F Lbl, bb P R R UUUUU DDDD H H UUO EEEEE *SIART* USER PCAL [10707,60451] JOB SHIP SEO. 1096 DATE 08-MA¥-80 05:59:59 MONITOR SW$ KL10E]4 dUb-79. *START* *START* USER PCAG [10Z07,60451] jOB SHIP SEQ. 1096 DATE 08-MA¥-80 05:59:59 MtJNIT(J~ SW$ KL10E]4 JUL 79. *START* VV VV VV VV VV VV VV VV VV VV VV VV VV VV VV VV VV EEEEE~EEEE RRRRRRRR VV EEEEEkEE~.E RRRRRRRR VV k~ ~R RR VV EE R~ RR VV EE RR R~ VV EE PR RR VV EEEk~kE~, RRRR~RR VV EEEEEEEE RHRPRRRR VV EE R~ RR VV EE ~H RR EE R~ R~ EE R~ ~ EEEEEEEEEE RR RR EEEEEEEEEE R~ R~ Illlli IIIIII II II II 1I II II Ii 1 II iiiiii IIIIII F~ f l" ~ fFf FF I~1~ Ft~ ~F Ff YY YY YY YY YY YY YY YY YY YY YY YY Y¥ YY Y~ 000000 000000 222222 000000 000000 222222 00 O0 00 00 22 22 00 00 00 00 22 22 00 0000 O0 O000 22 00 0000 O0 0000 22 00 O0 00 O0 00 00 22 O0 O0 O0 O0 O0 22 800 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 O0 O0 O0 22 000000 000000 2222~22222 000000 000000 2222 22222 MONITOR 8wS KL10E34 JU6-79.-o-~RT* ' fILE: OS~H:VERI~.002<057~10707 60451] CREA~ED: P~INTED: 0B-MAY-or 06:06:17 OUEUE MWlTCHE$~ /~ILE:~O~T /COPIE8:I /$PACING:I /LIMIT:86 /FORMS:NORMAL 1096 DATE 08-MAY-80 08-MAY-80 05:57:40 05:59:59 SCHLUMBERGER COMPUTING CENTER 10707,60451 REEL HEADe~R I,ENGIH: ! ]2 bYTES PEEL NAME: P.C.A.L. SERVICE NAME: EDIT PEEL CONI'INUATIUN NDMBER: 02 PREVIOUS REEL NA~E: COMMENTS: L1S FORMAT CUSTOME~ TAPE DATE: 80/ 5/ 8 TAPE HEADER LENGTH: 112 ~YTE6 TAPE NAME: ~0451 DATE: 80/ 5/ 8 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: PREVIOUS TAPE NAME: C[~MMENTS: TAP5 COMMENTS TYPE FLUID ~ILTERED 1NLE~ ~ATER/ALL OTHER INFO NOT AVAILABLE/ PILE HEADER LENGTH: 62 BYTES fILE NAME: EDiT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIO{IS ~ILE NAME: 1024 BYTES WEI,I, SITE INFORMATION [~ECORD LENGTH: C(]MPAN~: WELL: FIELD: RANGE: TOWN: SECTION: COUNTY: STATE: 178 BYTES MAPATHON OIL CO. TBU D-15 RD#2 MCARTHUR RIVE~ 6 KENAI ALASKA DATA ~[JR~AT 8PkCIFICAIiON [,~,NG~I H ·' 450 BYTES ENTRY FsL(ICF S: ~[~PL 0 8iZL RLP CODL ENTR~ 1 66 0 DATUM SpI;.CIf. ICAT£[.IN Bh[ICKS: iC TUUb DEFT G~ TDT TAU TDT TPAT TDT S]G~ TDT N{TD TDT ~2TD TDT N3TD ~DT ?lTD TDT ~2TD TDT ~3TD TD[ SVURD# UNITS AP1 AP1 API API FILL# SiZ~ EXP PROC SAM HEP DEFT SHIF3 FT 0 0 0 0 0 4 0 0 1 b8 0 0 GAPI 51 ~l ]2 0 0 4 0 0 1 68 0 0 US 51 4~ ! 0 0 4 0 0 1 b8 0 0 C/C 51 4 1 0 0 4 0 0 1 08 0 0 CU 51 40 1 0 0 4 0 0 1 68 0 0 CPS 51 39 1 0 0 4 0 0 1 68 0 0 CPS 51 39 2 0 0 4 0 0 1 b8 0 0 CPS 51 39 ] 0 0 4 0 0 1 68 0 0 CPS 51 ]9 1 0 0 4 0 0 I 68 0 0 CPS 51 39 2 0 0 4 0 0 I b8 ~ 0 CPS 51 ]9 ] 0 0 4 0 0 1 68 0 10~,15.000 10]O0.000 10200.000 1O100°O00 10000.000 9900.000 9800.000 9700.000 9600.000 9500.000 q400.000 9300.000 9200,000 9100.000 M N E~IUN ] C N1TD F2TD GH N11D f2TD N1TD f2TD G~ N1TD f2TD GR N1TD ~2TD GR N1TD ~2TD N1TD f2TD GR N1TD GR N1TD F2TD N1TD GR N1TD GR N1TD F2TD NITD f2TD GR N1TD F2TD VAL -999 -999 -999 -999 -999 -999 54 1708 196 23 966 215 25 1088 205 26 940 203 28 1142 240 26 1110 246 39 1604 180 33 1204 204 25 1326 233 41 1498 2b0 37 1856 207 32 1630 lb4 UE · 000 .000 .000 .000 ,000 ,000 ,000 ,000 .000 .700 .000 .000 o000 .000 o000 .900 .000 .000 ,5OO ,000 ,000 .900 .000 .000 .600 .000 .000 ,100 ,000 ,000 .700 .000 .00o .5OO .000 ,000 .9O0 .000 .000 .700 .000 .000 MN EMtiNIC TAU N~TD N2TD F3TD TAU N2TD f3TO ~AU N2TD F3TD TAU N2TD f3TD TAU N2TD f3TO TAU N2TD f3TD £AU N2TD f3TD 7AU N2TD f3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD TAU N2TD f3TD TAU N2TD f3TD VAL -999 -999 ,,999 -999 -999 -999 168 978 60 318 596 52 244 704 57 301 600 49 231 790 68 286 770 62 170 996 58 37 2814 59 235 890 66 188 1056 79 150 1166 71 173 1086 60 UE o000 .000 .000 .000 .000 .000 .758 .000 .000 .068 .000 .000 .040 .000 .000 .255 .000 .000 .995 ,000 .000 .449 .000 .O00 .000 .51b .000 .000 .006 .000 .000 .331 .000 .000 .941 ,000 .000 024 .000 ,000 MNhMUNIC TRAT N3'ID TRAT N3TD TRAT NSTO TRAT N3TD TBAT N3TD ~RAT N3TD 'IRA 1' N3TO TRAT N~TD TRAT N 3TD TRAT N]TD TRAT h 3TD TRAT N3TD TRAI N lID TRAI N3TD VALUE -999.000 -999.000 -999.000 -999.000 3.b55 284,000 1.815 25b.000 2.670 300.000 1.900 320.000 2.380 380.000 1.900 380.000 3.795 438.000 2.450 428,000 2.495 488.000 t,850 512.000 4.270 520.000 4.360 504.000 MNEMONIC SIGM FITO SIGM F1TD SIGM lTD $1GM F1TD SiGM F1TD SIGM [;'lTD SIGM F1 FD 81GM F 1 TD 81GM F 1 I'O SIGM P1TD SIGM [;lTD SiGN [;'lTD $IGM F 1 'rD 81GM F1TD VALUE -999.000 -999.000 -999.000 -999.000 2b,975 288.000 14,275 319.000 18.~25 309.000 15.050 294.000 19.875 321,000 15.950 348.000 2~.775 26 .000 19.200 273.000 19.350 318.000 24,625 345.000 ]0.050 299.000 20.475 248.000 DEPTH qO00oO00 8000.000 8800.000 8700,OO0 8600.000 8500.000 8470.000 MIN EMON 1C N1TD f2TD GR N1TD F2TD GR P2TD N1TD F2TD G~ N1TD f2TO GR N1TD f2TD G~ N1TD F2TD VALUE 29.400 1240,000 202.000 33.600 1450.000 203.000 58.100 2028.000 214.000 54,200 1968.000 192.000 ql.900 lbt4.000 242.000 57.800 1866.000 192.000 -999.250 -999.250 -999.250 MNEMONIC TAU N2TD f3TD TAU N2TD ~3TD N2TD ~3TD TAU h2TD f3TP TAU N2TD f 3TD TAU N2TD f 3TD TAU N2TD F3TD VALUE 257.842 862.000 64.000 198.871 974.000 74.000 142.680 1318.0 0 78.000 1240. 67.000 171.769 1148.000 87.000 141.907 1214.000 72.00O -999.25O -999.25O -999.250 MNEMONIC TRAT N]TD TRAI N3TD TRAT N3fD TRAT N3ID TRAT N3TD TRAT N3TD N3TD VALUE 2.610 500.000 ].210 490.000 ,.g oo 578. 4.475 544.000 3.590 560.000 3.815 5b0.000 -999.250 -999.250 MNEMONIC $IGM F1TD 8IGM F1TD $iGM FITD SIG~ F1TD $iGM F1TO SiGM FITD S1GM F1TD VALUE 17.700 270 .ooo 22.950 262.000 ~1.925 3 3.000 3~.550 27 .000 27.050 315.000 32.100 307.000 -999.250 -999.250 SUMMAA~ [1~ DATA RECURD$ NU~BL~ O~ RkCOIqDS: 161 I,ENGI'I-t {}F I~LCORDS: 101~. BYTES l,~,NGlit UI' LAST IqECORL): 490 BYTES fILE I'~AILE~ I,EN(;TH: 62 B~TES FILE NAM~: ED1T .001 MAXIMUN PH~SICAL RECURD bENGTH: NEXT ~ILE NAME: 1024 BYTES ~ II,~, H[~,ADEF LENGTH: 62 BYTES ~ILE NAMe: EDiT ,002 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS ~ILk NAME: 1024 BYTES WELL SITE IN~URMATJ. ON RECORD LENGIH: C[]MPAN¥: WELL: FIELD: RANG~: TOWN: SECTION: COUNTY: STATE: 178 BYTES MARATHON U1L CO. TBU D-15 RD#2 MCA~THUR RIVER 8N KENAI ALASKA D~TA PORMAT SPECIfICAtION [,P, NGT[I: 450 SITES ~,NrRi IYPE 0 81ZE ! REP CODE bb ENTRY 0 DATUH ,SPECZPZCAI~ZUN UG(JCK,.S~ ~NT~Y DEPT GR TDT TAU TOT 'rR~t Ior SIGN ToT N1TD TDT ~2TD TOT N]TD TOT ~ITD TDT P2Tfl TDT P]TD TDT SVORD# UNITS AP1 APt API APt FILE# SIZE EXP PROC SAM REP DEPT SHIFT FT 0 0 0 0 0 4 0 0 1 08 0 0 GAPI 51 31 ]2 0 0 4 0 0 1 68 0 0 US 51 41 I 0 0 4 0 0 1 68 0 0 C/C 51 42 1 0 0 4 0 0 1 68 0 0 CU 51 40 1 0 0 4 0 0 1 68 0 0 CPS 51 39 1 0 0 4 0 0 1 68 0 0 CPS 51 39 2 0 0 4 0 0 1 b8 0 0 CPS 51 39 3 0 0 4 0 0 1 68 0 0 CPS 51 39 I 0 0 4 0 0 1 68 0 0 CPS 51 ]9 2 0 0 4 0 0 1 08 0 0 CPS 51 t9 ] 0 0 4 0 0 1 68 0 0 10~15.000 10300.000 tO200.000 lOlO0.O00 10000,000 9900.000 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 9200.000 9100.000 MNEM{INIC GR N1Ti) ~2TD G~ N1TD ~2TD GR N1TO f2TD GR NITD GR N1TD f2TO GR N1TD f'2TO GM N1TD ~2TD GR NITD P2TD GR N1TD P2TD GR N1TD f2TO GR N1TD f2TO GR N1TD P2TD G~ N1TD F2TD GR N1TO f2TO VALUE 0.400 4006.000 2004.000 0.400 4010.000 2005.000 54.500 1414.000 176.000 28.100 1084.000 242.000 26.700 1268.000 289.000 30.000 1006.000 201.000 30.200 1030.000 214.000 26.200 1152.000 250.000 43.000 1744.000 188.000 36.000 1226.000 214.000 28.100 1232.000 203.000 39.600 1360.000 231.000 41.100 1690.000 201.000 35.800 1842.000 187.000 MNEMONIC TAU N2TD F3TD TAU N2TD ~3TD TAU N2TD f3TD TAU N2TD f3TD TAU N2TD F3TO N2TD f3TD TAU N2TD f3TD TAU N2TD f3TD TAU N2TD f3TO TAU N2TD f'3TO 3AU N2TD ~3TD TAU N2TD ~3TO TAU N2TD f3TD TAU N2TD f3TD VALUE 298.745 4006.000 1997.000 298.745 4006.000 1997.000 184.065 928.000 71.000 bl.O00 222.208 960.000 81.000 :000 53.000 258.093 814.000 68.000 289.460 000 :ooo 163.990 1152.000 70.000 46.048 68.000 76.000 246.048 896.000 68.000 188.833 990.000 88.000 158.720 1110.000 71.000 168.507 1220.000 76.000 ~N~MON1C TRAT N3TD N3TD TRA~ N3TD TRAY N]TO TRAT N3TD TRAT N3TD TRAT N3TD TRAT N3TD TRAT N3TD TRAT N3TD TRAT N3TD ~RAT N3TO TRAT N3TD TRAT N3TD VALUE 4.87O 4008.000 4.870 4012.000 3.585 466.000 2.445 548.000 1.990 470.000 2.330 504.000 1.870 516.000 4.050 580.000 2.330 550.000 2.450 590.000 3.505 566.000 4.1bO 580.000 3.820 622.000 MNEMUNiC $IGM F1TO $IGM f'lTO SiGM FIfO SIGM F1TO 6IGM F1TD 8IGM F1TD SIGM F1TO SIGM FIfD SIGM FITD $1GM F1TO 8IGM F 1 TO SIGM FITD SIG~ flTO SIGM F1TD VA6UE 20.050 2003.000 20.050 2004.000 24.700 205.000 14.~25 32b. 00 20.525 334.000 15.400 284.000 17.925 293.000 15.725 348.000 27.150 274.000 18.375 284.000 18.450 280.000 24.625 316.000 2B.b00 302.000 26.850 260.000 DEPTH qO00.000 8900.000 8800.000 8700.000 ~600.000 8500,000 8{70.000 MNEMONIC GR NiTD ~2TD G~ NITD ~2TD GR N1TO ~2£D GR N1TD ~2TD NJTD ~2TD GR N1TD ~2TO GR N1TO ~2TD VALUE 33.900 11u2.000 199.000 40.800 1496.000 201.000 57.2OO 1902.000 216.000 59.100 1928.000 182.000 48.600 1658.000 253.000 61.400 1958.000 228.000 -999.250 -999.250 -999.250 LMONIC tAU N2TD f3TD ~AU N2TD f3TD TAO N2TD ~3TD TAU N2TD f3TO TAU N2TD ~3TD TAU N2TD f3TO TAU N2TD f3TO VALUE 000 7~ .000 196.863 1050.000 70.000 140.173 1268.000 75.000 140.652 1246.000 76.000 172.522 1180.000 89.000 140.903 {274.000 84.000 -999.250 -999.250 -999.250 MNEMONIC TRAT N3TD TRAT N3TD TRAT N]TD TRAT N3TD TRAT N3TD TRAT N3TD TRAT N]TD VALUE 2 485 504~000 3.030 612.000 3.800 622.000 4.540 610.000 3.620 640.000 3.775 650.000 -999.250 -999.250 MNEMONIC SIGM F1TD 61GM F1TD $IGM $iGM F1TD 8iGM F1TD SlGM SIGM ~ITD VAbUL 16.975 275.000 23.175 280.000 31.200 307.000 32.125 266.000 26.950 314.000 32.150 328.000 -999.250 -999.250 SUMMARY UF DATA RECUI~DS NUMBLR OF RECORDS.' 161 L~.NGIH (.J~' RECORDS: 1018 IJENG'IH OF LAST I-iECURD: BYTES 490 BYTES ~ II,E TRAILER LF, NGTH: 62 BYI'ES ?ILE NAME: EDIT .002 MAXIMUM PHYSICAL RECORD LENGTH: NEXT i~ILE NAME: ~II~E HEADER LENGTH: 62 BYTES FILE NAME: MAXIMUM PREVIOUS 1024 BYTES EDIT .003 PHYSICAL RECORD LENGTH: ~ILE NAMk: 1024 B~TES WELl, LENGth: C(IMPANY: WELI.,I ~IELD: RANGE: TOWN: SECTION: STATE: IN~tJRMATiON 178 BYTES RECORD MARATHON UIL CO. TBU D-15 RD#2 MCARTHUR RIVER 13W 8N 6 KENAi ALASKA DATA PURMAT SPECIFICATION i, kNGTH: 450 BYTES ENTRY BLOCKS: TYPE 0 SIZE REP CODE ENTRY 1 66 0 DATIIm MPkCI~ ICATIUN ~bOCK$: IC TO[IL DRPT GR TDI TAU ~OT TRAT TDT SIGM N 1 TD TOT N2TD TDT N 3'rD TOT .I; 1 TD TD r ~ 2TO TOT ~ lTD TDT SVIJRD# UNITS AP1 APl AP1 AP1 FILE# SIZE EXP PROC SAM REP DEP'I' SHI~T FT 0 0 0 0 0 4 0 0 1 b8 0 0 GAPI 51 31 ~2 0 0 4 0 0 1 ~8 0 0 US 51 41 1 0 0 4 0 0 1 68 0 0 C/C 51 42 1 0 0 4 0 0 i b8 0 0 CU 51 40 1 0 0 4 0 0 1 68 0 0 CPS 51 39 1 0 0 4 0 0 1 b8 0 0 CPS 51 39 2 0 0 4 0 0 1 68 0 0 CPS 51 39 ~ 0 0 4 0 0 1 b8 0 0 CPS 51 ]9 I 0 0 4 0 0 1 08 0 0 CPS 51 39 2 0 0 4 0 0 1 68 0 0 CPS 51 39 3 0 0 ~ 0 0 1 68 0 0 DkPI'H 10315.000 10100.000 10200.000 10100.000 10000,000 9900.000 9800.000 9700.000 9600.000 9500,000 9400.000 q300,O00 9200.000 9100.000 MNEMONIC GR N1TD ~2TO N1TO ~2TD GR N1TD ~2TD GR N1TD ~2TD GR N1TD F2TD GR NITD ~2TD NI~D ~2TD N1TD ~2TU N1TD N1TD F2TD GR NITD ~2TD GR NITD ~2TD N1TD F2TD GR N1TD ~2TD VALUE 9 .000 -999.000 -999,000 -999.000 -999.0OO 56,400 1750.000 204.000 29.500 1036.000 228,000 29.900 1184.000 242.000 32.200 998.000 224.000 31.800 1152.000 229.000 28.100 874.000 193.000 42.800 1904.000 223.000 37.800 1154.000 180.000 29.b00 1352.000 236.000 47.000 1440.000 255.000 45.900 1698.000 20b.O00 34.800 1766.000 168.000 EMONIC TAU N2TD f3TD TAU N2TD F3TD TAU N2TD F3TD 3AU N2TD f3TD N2TD ~3TD IAU N2TD F3TD TAU N2TD ~3TD TAU N2TD ~3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD F3TD TAU N2TD ~3TD TAU N2TD F3TD 1AU N2TD ~3TD VALUE ~99,000 : 09.000 -999.000 -999.000 -999.000 -999.000 165.997 1122.O00 78.000 312.547 748.000 bl.000 238.770 862.000 71.000 291.217 756,000 59.O0O 8.000 75.000 337.641 674.000 63.000 1 .000 76.000 47.804 66,000 76.000 237.265 956.000 80.000 186,324 1052,000 88.000 159.975 1148.000 75.000 172.271 1186.O00 74.000 MNEMON lC TRAT N3rD TRAT N3TD TRAT N3TD TRAI 'rRAI N3TD TRAT N3TD T~AT N3TD TRAT N3TD TRAT N3TD I'RAI N3TD I'RAT N]TD TRAT N3TD I. RA'I N3ID TRAI' N3TD VALUE 999. -999.000 -999.000 3,525 532.000 1.905 464.000 2.515 518.000 1,995 500.000 2.290 540.000 1.815 538.000 3.875 640.000 2,210 572.000 2,425 592,000 3.945 618,000 4.110 600,000 3.770 612.000 MNEMONIC SIGN F 1 'rD SIGN F1TD SIGN FITD 81GM F1TD SIGN FITD SIGN F1TD SIGN F1TD SIGN F1TD SIGM FITD SIGN F1TD SIGN FITD SIGN FITD ~IGM FII'D $1GM F1TD VAbUE - 99. OO -999.000 -999.000 27.300 310.000 14.525 304.000 19.250 323,000 15.650 297.000 19.325 327.000 13.450 280.000 28.025 283.000 18.375 277.000 19.075 312.000 24.900 335.000 28.325 2?4.000 26.475 207.000 DLETH 9000. 000 8qO0.O00 RSO0.O00 8100.000 gbO0.O00 R500.O00 8470.000 MN EMONIC GR NITD 1~ 2TD GR N1TD [~2TD GP N1TD F2TD GR NITD ~ 2TD GR N:{ TO [~ 2TD OR NITD 1' 2'ID GR N1TD [2TO VAL 33 1274 202 41 1350 192 04 1902 220 60 1990 197 7 18z~8 263 63 1860 185 -999 -999 -999 UE .200 .000 .000 .000 .000 .000 .300 .000 .000 .200 · 00O .000 .100 .000 · 000 .100 .000 .000 .250 .250 .250 MN LMONIC TAU N2TD f3TD TAU N2TD f3TD TAU N2TD f3TD TAU N2TD f3TO N2TD F3TD TAU N~TD f TD TAU N2TD f3TD VAL 257 962 73 206 976 76 146 1312 74 139· 1300. 78. 162. 1262. 92. 14]. 1260. 80. -999. -999. -999. UE .591 .000 .000 .650 .000 .000 .675 .000 .000 649 000 000 484 000 000 413 000 000 250 250 250 MNLMONIC TRAT N3TD TRAT N]TD TRAT N3ID TRAT N3TD TRAT N3TD TRAT N3TD TIkAT N3TD VALUE 2.470 616o000 3.190 590.000 3.830 672.000 4.~70 050. 00 3.7]0 65b.000 4.225 012.000 -999,250 -999.250 MNEMONIC SiGM F1 rD SIGM F1TO $iGM FITO SIGM F1TD F1TD $1GM FITO SIGM F1TD VAbUE 17.750 2~5.000 22.025 204.000 31.050 ]09.000 32.~00 278. 00 28.450 344.000 31.925 283.000 -999.250 -999.250 v SUMMARY OF DATA RECORDS NtJ~B~k OI' k~CORDS: 161 LENG[H OP RE,CORDS: 1018 BYTES I,f:NGTH (Jr LAST RECURD: 490 BYIES ?ILE TRA!LE~ [,ENGT~: 62 BYTES FILE NAME: EDIT .OOJ MAXIMUM PHYSICAL RECURD LENGTH: NEXT fILE NAMe: 1024 BYTES fILE HEADER I,ENGTH: 62 FILE NAME: ~DiT MAXIMUM PHYSICAL R~URD L~NGTH: PREVIUUS fiLE NAMe: 1024 BYTES WELL 6ITE [NPURMA~ION RECORD I,ENGIH: COMPANY: WELL: FIELD: PANGE: SECTION: COUNTY: STATE: 178 BXTE$ MARATHON OiL CO. TBU D-15 RD#2 MCARTHUR RIVER 8N KENAI ALASKA TYP~ 0 SIZE REP CODE ENTRY 1 66 0 v OATIIN ~PEC[~ICA~IUN BI,UCES: E~TRY 1C ~['DLI [, ~VU~D[t 1 DEPI 2 GR TAU TOT 4 TRA] 5 $IGM TDT N1TO TOT 7 N2TD 8 N3TD TDT g ~)TD TDT 10 ~2TO TDT 11 FjTD TDT UNITS AFl AP1 AP1 APt FILE# SIZE EXP PROC sAM HEP DEPT SHIbT FT 0 0 0 0 0 4 0 0 1 b8 0 0 GAPI 51 31 B2 0 0 4 0 0 168 0 O US 51 41 I 0 0 4 0 0 [ b8 0 0 C/C 5i 42 I 0 0 4 0 0 1 b8 0 0 CU 51 40 1 0 0 4 0 0 168 0 0 CPS 51 39 1 0 0 4 0 0 168 0 0 c ~ ~,~ ~o o ~o o ~ ~ o o c~,~ ~ ~ ~o o ~o o ~ ~ o o c~ ~,~ ,o o ~o o ~ ~ o o CPS 51 39 3 0 0 4 0 0 I ~ 0 0 0 DEPTH 10315.000 10~00.000 10200.000 10100.000 10000.000 9900.000 9800.000 9700.000 9600.000 qso0.000 9400.000 9300.000 9200.000 9100.000 MNEMUNIC GR N1TD ~2TD GR NITO P2TO GR N lTD GP N1TD P 2TO GP N lTD F2TD GR N1TD F2TD GR N1TD F2TD GP NITD [;2TD GR N1TD ~2TD GR NITD f2TO GR N1TO b2TO G~ NITD ~2TD GR N1TD ~2TD GR N1TD ~2TD VAL 0 4010 2007 0 4010 2007 50 1626 214 27 1042 221 942 236 31 1024 200 30 1038 199 32 1006 213 44 1890 189 41 1446 219 30 1402 212 49 1368 237 45 1642 194 33 1758 173 LIE .400 .O00 .000 .400 .000 .000 .300 .000 .O00 .700 .000 .000 .500 .000 .000 .500 .000 .000 .700 .000 .000 .500 .000 .000 .200 .000 .000 .700 .000 .000 .100 .000 .000 .500 .000 .000 .700 .000 .000 .700 .000 .000 MN EMONIC TAU N2TD f3TO 3'AU N2TD ~3TD TAU N2TD f3TD TAU N2TD F3TD TAU N2TD f3TO 'tAU N2TD f3TD TAU N2TD f3TO TAU N2TD F3TO TAU N2TO F3TD TAU N2TD F3TD TAU N2TD f'3TD TAU N2TD ~3TD TAU N2TD ~3TD TAU N2TD ~3TD VALUE 1026.474 4004.000 1997.000 1026.474 4004.000 1997.O00 171.267 1078.000 70.000 309 536 7682ooo 64.000 289.210 656.000 123.000 95.734 38.000 63.000 268.130 826.O00 71.000 311.292 782.0OO 71.000 156.964 1254.000 75.000 223.212 1028.000 85.000 231.995 996.000 79.000 203.890 1038.000 91.000 162.233 1130.000 66.000 1 .000 71.000 MNLMt)N lC TRAT N3TD TRAT N3TO TRAT lq lTD I'RAI N3TD TRAI N]TD IRAT N3TD TRAT N3TD TI~AT N 3TD TRAT N]TD RAT 3TO TRAT N3TO TRAT N3TD TRAT N3TD TRAT N3TD VALUE 4.875 4012.000 4.875 4012.000 3.515 528.000 1.835 474.000 2.800 440.000 1.950 522.000 2.385 536.000 1.770 538.000 3.905 626.000 2.485 616.000 2.545 bO8.000 3.775 624.000 4.080 624.000 3.850 648.000 MNEMUNIC SIGM 'rD $iGM F1TD 8IGM F1TD SIGM F1TD SIGM F 1 'rD F1TD $iGM F1TO SIGM F1TD 6iGM F1TD $1GM FITD $1GM F1TD $IGM FI?D SIGM F1TD SIGM F1TD VAbUE 0.000 200b.O00 0.000 2006.000 26.625 273.000 14.b75 310.000 lb.500 282.000 15.300 293.000 17.225 301.000 14.650 306.000 29.000 278.000 20.400 324.000 19.600 299.000 22.725 308.000 21.875 263.000 26.625 270.000 V~ DEPTH 9000.000 8900.000 8B00.O00 ~700.000 8600.000 9500.000 8470.000 MN~MON1C G~ N1TD ~2TD GR NiTD ~2TD G? NITD F2TD GR N1TD ~2TO GR NITD ~2TD GR N1TO f2TO GR NJTD F2TD 13 2 14 1 21 2 19 1 2 20 2 -9 -9 -9 ALU ]5. 20. i9. 40. 24. 97. 59. 30. 27. 57. 90. 86. 55. 88. 64. 69. 40. 17. 99. 99. 99. 800 000 00o 400 000 000 200 000 000 9O0 000 000 800 000 000 400 000 000 250 250 250 MNEMONIC TAU N2TD ~3TD ~AU N2TD ~3TD TAU N2TD F 3TD TAU N2TD F3TD TAU N2TO ~3TD TAU N2TD f3TD TAU N2TD f3TD VALUk .000 77.000 200.376 1036.000 80.000 141.907 1394.000 92.000 138.645 1318.000 84.000 159.975 1274.000 99.000 137.139 1358.000 86.000 -999.250 -999.250 -999.250 MNEMON lC TRAT N 3'['0 TRAI N3TD TRAT N3TD TRAT N]TD TRAT N3TD TRAT N]TD TRAT N3TD VALUE 2.515 570.000 3.075 632.000 3.830 700.000 4.490 654.OOO 3.755 648.O00 3.905 650.000 -999.250 -999.250 MNkMONIC 5IGM F1TD 8IGM F1TD $1GM F1TD $IGM F1TO SIGM F 1 TO SIGM F1TD 8iGM [~ITO VALU~ 18.150 303.000 22.825 274.000 31.825 329.000 32.b50 254.000 29.050 324.000 33.150 299.000 -999.250 -999.250 SUMMAP¥ LIJ' DATA RECLJRDS NIIMBEP Of RECt)[-iDS: 161 LkNGTH LJ~ [~ECtIRDS: lOll4 O'iTES I,ENGTH OF ],AST I~[<CURD: 490 BYTE8 FILE TgAILF, R LENGTH: 62 BYTES FILE NAME: E, DIT .004 MAXIMUM PHYSICAL ~ECORD LENGTH: NEXt fiLE NAME: 1024 BYTES F I[,E I..tEADEP LENGIH: 62 bYThS FILE NAME: EDIT .005 ~AXIMUM PHYSICAL REC(JRD LENGTH: PRE¥1UUS FILE NAME: 1024 BYTES WELl, SITE IN$ORMATION RECORD LENGTh: CQMPAN¥: WELL: FIELD: RANGE: SECTION: COUN7¥: STATE: 178 BYTES ~ARAiHON OIL CO. TBU D'I5 RD#~R MCARTH1]R ON 6 KENA/ AbAS~A DATA ~UPMAT ,SPIgCI~'ICAT1UN LgN(;tH: 450 B~TE, S LNTR,~ BbOCKS; 0 SIZk REP CODE ENTRY 1 66 0 DATUt~ 6PECIFICATION BLf)CKS: ENTR~ 1 2 4 5 6 7 8 9 JO 11 IC TOOL DEPT GR TD~ TaU TDT TRAT TDT SIGM TDT NITD TDT N2TD TDT N]TD TDT ~ ~TD TDT ~ 2TD P 3'rD TDT UNITS AP I AP1 APl APl I~T 0 0 0 0 GAPI 51 31 32 0 US 51 41 1 0 C/C 51 42 I 0 CU 51 4O I 0 CPS 51 39 I 0 CPS 51 ]9 2 o CPS 51 ]9 ] 0 CPS 51 39 1 0 CPS 51 ]9 2 0 CPS 51 39 3 0 FILE# 6iZ E EXP PRUC SAM REP DEPT 4 0 0 I 68 0 4 0 0 1 58 0 ~4 0 0 1 68 0 4 0 0 1 b8 0 4 0 0 1 68 0 4 0 0 1 68 0 4 0 0 1 b8 0 4 0 0 1 68 0 4 0 0 1 68 0 4 0 0 1 08 0 4 0 0 1 68 0 SHIFT DEPTH 10]15.000 1O300.O0O 10200.000 10100,000 10000.000 9900,000 9800,000 qT00.O00 9600.000 9500,000 q400.O00 9300.000 9200.000 9100,000 MNEMONIC G~ N~TD F2TO GR N1TO f2TD GR N1TD F2TD Gk N1TD f2TD GP N1TD ~7'rD GR N 1 TD [' 2TD GR NITD F2TI) GR N1TD F2TD GR N1TD F2TD GP N1TD ~2TO GR N1TO P 2TD GR N1TD E2TD GR N1TD f'2TD GR N1TO F2TO VA L, -099 -999 -999 -999 -99q -999 56 1590 187 27 1084 217 32 1150 244 34 1058 216 31 1112 23] 34 1042 261 43 1876 216 40 1134 188 33 1260 229 4~ 1592 288 42 1818 206 39 1570 156 UE .000 .000 .000 ·000 .000 .000 · 700 .0o0 .000 .900 .000 .000 .000 .000 .000 .600 .000 .000 .900 .000 .000 .500 .000 .000 .700 .000 .000 .9OO .000 .000 .500 .000 .000 .900 .000 .000 .200 .000 .000 .600 .000 .000 MNEMONIC TAU N2TD E3TO ~AU N2TD f3TD TAU N2TD f~3TO TAU N2TD f3TD TAU N2TD f'3TO TAU N2TD f3TD 1AU N2TD ~3TD TAU N2TD ~3TD TAU N2TD F3TD TAU N2TD ~3TD TAU N2TD f3TO TAU N2TD f3TD TAU N2TD f 3TD TAU N2TD ~ 3TD VAL -999 -999 -999 UE .000 .000 .000 -999. -999. -999. 174, 1094, 79. 310. 822. 69. 245. 876. 71, 284. 830. 71. 252. 898. 76. 306. 808. 75. 161. 1244· 75. 255. 862. 75. 48 · 28. 76. 182. 1154. 98. 154, 1210. 7b. 11 . 72. O00 000 O00 529 000 000 038 000 000 044 000 O00 944 000 000 321 000 O00 524 000 000 481 000 000 082 000 000 557 O00 000 O58 000 000 956 000 000 039 000 000 MNEMC)N IC TRAT N]TD TRAT N3TD TRAT N]TO TRAY N3TD TRAT N]TO 'IRA N]TD TRAI N3TD TRAT N]TD TRAT N]TD THAT N3TD TRAT N]TD TRAT N]TD TRAT N]TD TRAT N3TD VALUE -999.000 -999,000 -999.000 -999.000 3.570 592.000 1.850 558.000 2.500 576.000 2.025 576.000 2.265 596.000 1.755 608.000 3,715 692.000 2 295 2 2ooo 2.335 640.000 3.810 678.000 4.160 660.000 3.775 648.000 MNEMONIC SIGM F 1 'rD 81GM F1TD 81GM F1TD $1GM F1TD $IGM F1TD SIGM F1TO 8IGM F1TD 8iGM F1TO SIGM FITD SIGM F1TO SIGM F1TD 8IGM F1TO S1GM F1TD ~IGM F1TO VAbU~ -999.000 -999,000 -999.000 -999.000 2b.050 271.000 14.675 324.000 18.700 326.000 lb.000 300.000 18.250 321,000 14.800 347.000 2U.000 30b.000 17.800 239.000 18.225 296.000 25.425 342.000 29.025 302.000 25.700 246.000 DEPTH 9000.000 8qO0,O00 8~00.000 8700.000 8600.000 8500.000 8470.000 MNEMONIC GP N1TD F2TD GR N1TD F2TD GR NITD P2TD GR N1TD F2TD Gh N1TD F2TD GR N1TD ~2TD GR N1TD ~?TD VALUE 37.900 1222.000 186.000 41.800 1846.000 283.000 61.700 1880.000 ?00.O00 b{.O00 2164.000 193.000 51.000 lb92.000 252.000 0.000 0.000 O.000 -999.250 -999.250 -999.250 MN EMONiC TAU N2TD ~3TD TAU N2TD ~3TD TAU N2TD P3TD TAU N2TD ~3TO TAU N2TD f3TD TAU N2TD F3TD TAU N2TD F3TD VALLIE 262.]59 934.000 73.000 171.016 1396.000 111.000 148.432 {270.000 88.000 134.630 1428.000 87.000 .000 103.000 -1.129 0.000 0.000 -999,250 -999.250 -999.250 MNEMONIC rRAT N3TO N lTD TRAr N3TD TRAT N3TD 'rRAT N3TD TRA~ N{TD TRAT N3TD VALUE 2.490 642.000 3.030 752.000 3.820 680.000 4.625 718.000 3.255 678.000 0.000 0.000 -999.250 -999.250 MNEMONIC SIGM F1TD F1TD SIGM F1TD S1GM F1TD SIGn F1TD SIGM F1TD SIGM F1TD VAbUk ~7. 2bl .0OO 26.475 332.000 30.550 285.000 33.525 293.000 25.525 329.000 0.000 0.000 -999.250 -999.250 $1)MN1AR~ OE' I.)A'£A RECORDS NIIMBEP LIf, F~f<COROS: le, 1 I,F, NGTH JIF HECORD,5: 1018 BYTES I,ENG'IH [}F I,AST R_P,CORD.* 490 BYTES F1L~ IRAIL£k I,ENGTH: 62 BYTES [' II,F, NAME: F.,DIT .005 MAXIMUM PHYS1CAL RF~CI. JHi) LENG'IH: NILXT ~]BE NAME: TAP~ I'~AILER I,ENGI'H: 132 B~TE8 TAPE NAME: 604E~iT SERVICE NAME: TAPE CONTINOATiOM NUMBE~: O1 NEXT 'IAPE NAME: COMMENTS: 1024 BYTES DATE: 80/ 5/ 8 I 1 000000 11 000000 ! I 1 1 O0 O0 { 111 O0 O0 11 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 O0 O0 I I 1111 000000 I I 1111 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 000000 7777777777 000000 7777777777 00 00 77 O0 O0 77 O0 0000 77 O0 0000 77 O0 O0 O0 77 O0 O0 O0 17 OOOO O0 77 0000 O0 77 O0 O0 77 O0 O0 77 000000 77 000000 77 66566~ OOO000 66 O0 O0 t, 6 O0 O0 6 (> 00 0 t) 00 66 00 0000 b (,.,bb 6566 O0 O0 UO 60be.,b666 ¢)0 O0 O0 6e) t~6 0000 O0 6,6 b6 0000 0O 65 bt.) O0 O0 66 6(:.~ O0 O0 6bbbb6 0OO000 b6b666 000000 44 44 44 44 44 44 44 4:1 44 44 44 44 4444444444 4444444444 44 44 44 44 44 44 5555555555 5555555555 11 55 1111 55 1111 555555 11 555555 11 55 11 55 l 55 1 55 11 55 55 11 55 55 11 555555 111111 555555 111111 ,SCAR1* OSEl-' {-'CAb [10707,b04151J. JOB {qllf,{I I'lJF 6w5 E[.,10~,:14 ,JIJL-19. *S ART* ,SIAR'r* U,SF, P ['CAI, [10707,b0451JT dUB Iqf,NIT(IP, Sw,5 KI,IOE34 JUL-79. *STAR *' U O R U U R U O i} U [J O U U R U U U U U SHiP SHIP DDOD D O D O D D D D D D DDDD 1131 1131 H H £}OO 5KEEE H H U O k HHHHH O O EEEE h H U £) k H H O 0 k H h [}00 LEEEE DATk OS-MAY-B0 05:41:44 DArk 08-MAY-80 06:41:44 VV V V Isis t'.t, LLF~ L LL P,R RRRP, P, R V V V V b,[' t..i...t.i-.F.k6~ VV VV I-,k ~F, RR VV V V ~ ~: ~B VV vV F,k HIR VV VV ~i~, RP VV V V 1. [' [<t..Ek['.,['. H~I~RPRRR v V V v [, !~. HR RR VV vV [,. i,o ~N VV VV 1'[' I~N kg VV VV t,,~ ~P PR VV LEkLLL?.ELL IRk RR iiiii1 llIllI 11 11 I! I1 II 11 II II Il I[III1 iiiiii YY YY ¥¥ XY OUoO00 000000 5555555555 00¢)(}00 000000 5555555555 0¢) O0 O0 O0 55 OO O0 O0 O0 55 O0 O00O 0() O00O 555555 O0 00()0 O0 0000 555555 u 0 00 00 0 0 00 O 0 55 O0 O0 O0 oO O0 O0 55 0()00 O0 0000 O0 55 O()O0 O0 0000 O0 55 0 (') U 0 00 ¢) 0 55 55 0() O0 O0 O0 55 55 0000o0 goO000 555555 0000o0 OOOO00 555555 *~.il'Al-{'l'* IlSLP, PCAb [10707,60451]i, JOB SHIP fltll~llliR Swh hLlOE, 34 JtJL-79. ,STAR , PRINTF, t): 08-MAY 80 06:4~:01 {~I~LU[ SWlTCHf, S: /FII,f,:FURT /COPIES:I /SPACING:I /L1MII:S6 /FORMS:NORMAb 1131 DAlE 08-NAY-80 0b:41:44 OR-MAY-BO 06:3B:16 SCHLUMBkRGkI~ CI.INIpIJTING CkNTS~ 10707,60451 P, Ekl, HEADER DATL: 80/ 5/ 8 TAPk Iti~,ADLP o I DATE: 80/ 5/ 8 WAIER/A[,b ()THER ]NFO NOT AVAiLABbE/ F ]I,F. HkADER I,I~,NGTH: 62 BYTF, S F [l,g NAMIng: Ei)JT .001 IqfiXl~U~ PHtS1CAh RIt, CURD LENGTH: PI~I~:VIUUS Flhk NAMF,: 1024 wi", [,I, L': 1 T F. I,F,N (; ri-,i: Ctli~FAN l: W F,I,L: l, IF l,O: P A p~ (; t"..: 'I {1W N: (,' lJ(l N'I' Y: ~ rAT~: ]N~'I;RP, ATILJN R~.CORD ~ARATHI~N till CO. [BL} D-15 RD#2 MCARI'HIjR HIVkR SN 6 K~NAJ ALASKA 0 SIZE 1 REP 66 C(]Df~ ENTRY 0 [CATION L {,1 T f~ ¥ J. C 1,. IPA'I' ]'DT RI'ID N31'D l'l.)l [" ? I'D II)T l' 3 ! D UNIIS ~PI APl ~Pl ~P! t'T 0 0 0 0 (;AP1 51 31 32 0 US b I 41 1 0 C/C 51 42 1 0 Ct~ 5~ 40 1 0 CPS 51 39 1 0 CPS 51 39 2 0 CPS 51 39 3 0 CP~ 51 39 1 0 CPS 51 39 2 0 CPS bl 39 ~ 0 t~ 1 I,L# SIZ~ LAP PR{.)C SAM REP 0 1 0 1 08 1 0 1 68 0 1 68 0 1 68 0 1 68 0 1 0 I 68 0 1 b8 DEPT SHlf I) E P'I H I 0 ] ! 5. 000 1o ~00.0()0 1,12()0. 000 10100 o O00 10000. 000 gq()o. 000 9~00. 000 9700.O00 0600.O00 9500. 000 9400. 000 9300.000 q)O0.O00 91 O0.09O GR t,~ 1 T L) ~ 2TD GR NITi) ~ 2TI) N 1 ri.'[) t'2TD GP I',~1 q'l: 2'1'1) GR NITD [. 2'ID GP N 1 T [) GR N 1 'I' l) [' 2TD NI~JD k ?TD GR N 1 'I [3 I. 2'rD GR f~ 1 'FD F2TP GR 1'~ 1 T D N 1'1 b I' 7TD GR N 1 TD P 2TI) VALUE -999.00O -999.000 -999.000 -999.000 -999.00(} -999.000 54.00O I ?O8.0O0 1 ~6. 000 qtb.O00 2 1 b .0()0 25.000 0~8.000 205.000 26.900 7O3.000 28.500 1142 .()OO 240. 000 26.900 1110.O00 246.00O ]9.600 1604 · 000 180.000 ] 3.100 I 204.000 204.000 25.700 73 ]. O O 0 41.5o0 1498.000 250 · out) 37. 900 1850. O00 207.0(,')0 ~2. 100 1630.000 1 b4.0()() PNEMONiC TAU N2TO ~ 3TO N2'ID .~ ~ T D TI) TO T A U iq 2 T D ~' 3~t) '1 AU N 2TO ~3TD 'tAU r,~ 2 'r ~ 31'0 '1' At) N 2 'fl) [.3rD IAu N2ID ~3ID tAU N2TD ~3I'D TAU N2 I'D ~3IO TAU N2rD r 3TD ALI N2I D ~3ru 1AU N2TI) [' 3TD '1 All N211.~ VAL[JE -999.000 -999.000 -999.000 -99q.000 -999.000 -999.000 108.758 978.O00 bO.D00 318.058 596.O00 52.O00 244.040 704.00O 57. 000 301.755 b00.0OO 231.995 790.000 68.000 286.44') 770.000 62.000 170.013 996. 000 58. 000 237.516 814. 000 59.000 235. O06 890.000 bb. O00 1 OhO. O00 Iq. ODD 150.941 I 166.000 71. 000 17].024 10Se,. 00o 60.000 MN~MON1C TRAT N~I'O TRAT N3ID TRAT N3TO I'RA'I N3'ID .L'RAI IRAI TR~ 1 IRA'I' N 31 O IRA£ N~,ID 'rRA 1' N 3'rD TRAI' N 3'ID TRAT N 3 T D TRA 1' N3 rio IRAI N~I'D VALUE -999.000 -999.000 -999.000 -999.000 3.655 284.000 1.815 255.000 2.670 300.000 1.900 320.000 2.380 380.000 1.900 380.000 3.795 43B.000 2.450 428.000 2.%95 488.000 ].850 512.000 4.270 520.000 4.360 504.000 MNkMON1C 81 GM l;lfO 81GM F1TO SIGM F1TD SiGM F1TO SIGM ~ITO ITu SI GM F1TD S 1 Gl'4 lTD SIGM [''lTD SIGM FITD $I Gl,t f 1 TO S [Gt4 [' 1 f I) SIGM ITl.) $iGM ~lro VAbU~ -999,000 -99N.000 -999.000 -999.000 2b.975 288.000 14.275 319.000 lU.825 309.000 15.050 294.000 19.875 321.000 15.950 348.000 20.775 262.000 19.200 273.000 19.350 318.000 24.b25 3~5.000 30.050 299.0OO 20.415 248.000 9000.(}00 8900. ()00 8700.000 ~600. 000 ~500. 000 q470.()O0 Iq N E i',1 {) N I C N ] r D }. 2 ['U II l T D NlfD }. 2TI) N 1 T D [~ 2 T fJ GF f41 T D f 2 l' 0 GP N 1 I'1) F y'rD I',' 1 TO VALUE 29.40() 1 ? ~{}. 0OO ? 02.00 0 33.600 1450. 000 20 ~. O()O 58. I O0 2028. 000 214.000 54. 200 19o8 .uOO 192.0Or) 41.900 I 6 J 4. 000 2'-)2 .()nO 57.80() 1~00.00{) lqY.000 -999.250 1999,250 TAU lq 2 T D ~ 3TD 'I AU N21D ~ 3'rD Tg U i,,~ 2 T D PlrD '! AU N2TD [~ 3TD ]AU N2TP },31'O '[ A tJ N2 rD b 3TD TAU a Z 'I D l~}IP VALU}.. 257.842 6~.000 198.811 974. 000 7 i,. 000 142.660 1319.000 78.000 14().)5~ 1240. 000 67.000 171.769 1148.000 87.000 141.q07 1214.O00 72.000 -999.250 -999.250 -9g9.250 MN 5MtJN I C ThAT N3 I'D TRAI N lTD ThAI N3~ID T RAT N3TD ThAI N3TO 1RAT 1'~ lTD ThAI N 3 I'L) VADUk 2.b10 500.000 3.210 49b.000 3.920 578.000 4.475 544.000 3.590 560.000 3.815 560.000 -999.250 -999.250 MNEMUNIC $iGx'~ Fll'O SIGM },'lTD 81GM },lTD 8IGM }, lTD $1GM };lTD 81GM F l'rD $IGM F1TD VALUE, 17.100 210.000 22.950 202.000 31.925 303.000 32.550 2'~3.000 27.050 315.000 32.100 307.000 1999.~50 -999. 50 SUM~iAt~Y UP I)AI'A RE, CURD5 490 ~¥T~,S F ti,I", I~AILI'~ 1024 ii,F; HE, A Dt:,R I.E, NGI'H: 62 II.E, NAME: Et)Ir .002 MAXI~u[,~ pI4¥,SJCAL P,E.CIJI~D LE'NGIH: PRkV l{.Jl~q 1: II, b 1024 v~EI,[, ,SITE II~t"IJRMA'IION RLCOPP I,~.NGJ'H: I '78 t4y CIIMPAI'i~; MARATHON ~,J~,,I,i~: IgU D-J5 1- [[.,I,D: MCARTHIJP r~JWN: 8 N S[~,CT 10N: 6 C(IUNT¥: KE, NAI stare,: AbASKA 015 CU. RD~2 RIVER f'{~PMAq ,SP~.CII;JCAI'lt}N 450 I'¥PE 0 SIZE NEP CODE ENI'RX I 66 0 DAI'IJM ,~P~',CIFJCATI(tN BblJCK,5: j 2 (., R 'l I-)T ~ 1 AU I uT 4 I F'A']' 5 SIG~ ~[O'[ 6 H 1 "i'D I'I)T ? h 2 ~ b 'I l)T 8 N 3 ] D 'I D 3_ c) I- I ID 10 ['2TI) ']L)'l 1 I .{: cl"l'D q DT UI',IJ.I'S AP1 APl AP1 APl FII.,E;{{ ,.5IZB EXP PROC ,..qA~! REP I){E, PT F [' 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 51 31 32 0 0 4 0 0 1 68 0 0 O,S 51 4, l 1 0 0 4: 0 0 1 b8 0 0 C/C 5{ 42 I 0 0 4 0 0 I b8 0 0 C~,I 5 l 40 1 0 0 4 0 I,) 1 68 0 0 CPS 51 39 1 0 0 4 0 0 I 68 0 0 CPS bl 39 2 o 0 4 0 0 I 68 0 0 CPS 51 39 3 0 0 4 0 0 1 68 0 0 P$ 5 1 ~ 9 1 0 0 4 0 0 1 6 8 0 0 PS 51 39 2 0 0 4 0 0 1 68 0 0 CI-'S 51 39 3 0 0 4 0 0 1 68 0 0 [)~ PTH 1 n ~ 1 5. OO0 10~00.000 I a?oo, 000 10 1 O0. 000 10000,000 9q00.O00 9~00.000 9700.00{) 9500.O00 qSO0.O00 9 ~O0. 000 q ~09.000 q 1 O0. 000 k, Mt)N lC NITP N 1 T D [' 2TO NITD P 2'rD GP 141 T D P?TD GR 1- 2TD f 2TL) N1 ?2TD (314 N1TD l- )TO GR I'01 T D I'2TD GR N 1 T D N1 TD t2TO [' ?TD GP h I "[ L) f2TO GP Il 1 TD VAUUt', 0. 400b. O00 2004.000 0. 400 4010. 000 2005.0O0 54.5o0 141 1.00(I 176.O00 28.1OO 1 o84.000 242. 000 26.70O 126H.000 2H9.000 30. 000 1006 · n00 ?01. 000 JO. 2(t0 10 JO. 000 214,000 26.200 1152.O00 250.000 43.00 0 17 ~,4.000 188. COt) 3o.000 1226.000 214,000 78.100 1232.000 20].00¢) 39.6O0 13bO.O00 231.O00 41.100 le90.OOO 201,000 35.8o0 1 P 42. 000 18 ?. 000 MN ElY,(iN] C '1 A !J N2TD F3TD TAU N 2TD [~ 3TD N2TD I'AU a21U '1 AU f~21'12 1 AU N2'I'D ~ 3ID N2TO 'fA U 2 r D lTD A t} N2TD 3'1'O TAU N2TD N21'D t' 3TO '1 All N2TD t' I'AU N2TI) fi 5TI) H2'I'D 3'ID V AbUE 298.745 4006.000 1991.000 298.745 4006.00O la97.000 184.065 928.000 7~ .000 50~.262 772. 000 61 .O00 222.208 960.O00 R1.O00 294.730 728.000 5t.O00 258.093 Hl 4.O00 08. 000 2~9.4b0 832.000 71.000 lb~.ggo 1 I 5 . 000 70.000 246.048 868 .o00 70.000 246 .O48 896. 000 6q .OO0 188.fl33 990.000 88.000 158,720 11 10.O00 71.000 1h8,507 1220. 000 76. MNEMOI~ lC T R A T N 3 'I'D tRAI N3TD RAT N3TO 'IRA']' N 3"rD TRAI' N 3TD 'l HAT 'I'R Al' N3TD TRA'f N ;JI'U '1 HA 'I N lTL} 1R A'I.' N 3 T D TRA'I N31'D THAI N JlD TRA'I 1~ 3 'I' U fHA[ VALUE 4.B70 4008.000 4.870 4012.000 3.585 456.000 1.885 482.000 2.445 548.000 1 990 o:ooo 2.330 504.000 1.810 510.000 4.050 580.000 2.3~0 550.000 2.450 590.000 3.505 565.000 4,100 580,000 3. 820 622.000 MNEMONIC 81GM FIID $1GM F1TD 6IGM S1GM SIGN FITD SIGM P1TD SI. GM ['lTD SJGM ~l'rv SIGN Fl'rD SIGM F1 'ri) S [ ["lTD S 1GIq ~l£O S/Ga FITU SIGM F1 rD VALUE 20.850 2003. 00 20.050 2004.000 24.700 255.000 14.925 326.000 20.525 334.000 15.400 284.000 11.925 29~.000 15.725 348.000 2 1. 150 274.000 18.375 284.000 18.450 280.000 24,625 3lb.O00 2B.b00 302,000 20,850 200,000 9000.O00 ~qO0.O00 ~800.0o0 ~ 700. 000 g~oO.O00 aSO0. 000 ~470.000 ~NLM()NiC GF N 1 TI) l' 2TD GR NITD ~ 2'rD GP GP lu I 'T 0 N1 TD 21'o [' 2TP 11 1 14 19 2 ]9 1 lh 19 -9 -g AL J3 q9 40 90 01 57 02 16 59. 48. 58. 53. 61. 58. q9. ~9. 99. .9 .0 .2 .0 00 O0 O0 00 O0 O0 ()() 0 (} O0 0 () 00 00 0 o O0 OO Oq O0 0 (,) 50 5O 50 MNt,,MtIN lC TAil N2TU F3TD 'F A U N 2TD F3TD I'AU N2TD TAU N2TD f 3TD TAU N2TD 1' }TD '.['Al) N2TD ~ 3'r 1 At) N2'I'D 1' 3TD 1 10 1 12 l 12 I 11 1 12 -9 -9 -9 AblIF. 62.000 72.O00 qb.8O3 50.000 70.000 46.173 b8.O00 75.000 40.652 46.000 /6.000 72.522 80.000 89.000 40.903 74. 000 B 4. 000 99.?50 99.250 99.250 MNkMUNIC TRAI N 3TD TRAT N~TD TRA T N3TD N 3TD ~IRAI N~![D tJ IRA£ VALUE 2.485 564.000 ].030 612.000 3.8OO 622.000 4.540 610.000 3.620 b40.O00 3.775 650.000 -999.250 -999.250 MNEMONIC &IGM F1TD SIGM FlrU $1GM FITD SIGM F1TO SiGM FIT[) F1TD SiGM VAbUE lb.975 2/5.000 23.175 286.000 31.200 307.000 ]2.125 266.000 2b.950 ~14.000 ~2.150 328.000 -999.250 -999.250 SIII~]MA~¥ UJ' DATA NII~BI"~ U[' P, gCOt41)$: 1 61 I,i, NG'IH (JF FtJ,,CUIaDS: I()IR ~Y'rF, s I.t',NGIH LI[, LA~I He, COF',L): 490 ,i, ,t 4 * * * * t- II,F, I HA I l,~,H I.F. NG'I h: 62 H~TF~ F IUF. NAHE,; FDIl' HAX1r,'~U~ PHYSLCAI.., HkCt]HI) NF, XI' [' I l,k, NAblF., j 1024 ,I, * ,I, , ,1, t * * * F ]I,F, HE, ADF. R I,EI'JG .1"~ ." ~2 15¥ TF,$ F Il,F, l,~Ar,4[.,,." FpI1' .O0~ PRI,,V l uU$ 1, 11,1-, t,~Al'.~l".,: O24 Wl.,l,b 5 I,[..' N (.; 1' H ("(i~IPAN WF, I,I.,: RAN(;[' TtJ~N; ,%1,,(' I' I C~)IIN l STAT[" ITF, 1NFIJPt4AI'ILI~'~ ¥,, PF,CURL) t'.'~ARATH(jN (ill, CO. IF/L1 D-15 RL)#2 [,'lC AR l~tt(IR ~IVkR 1 3~',' i', F,N A ] AL, ASKA f' ('.II~',MA I ,SPEC 1~ ICA I'IiJN TYPE SiZE 1 REP CODE (DO 0 DA'I'{i~,I 6PECI[; ICAT.ItJ,,J BIJtJCK,S; ENTRY 1 5 ? IC [tJl}L I)[-,P T G P '1 l)T T A U 3 DT qRAT TDI SIGH 301 I,II'IL) JUT hZ.FI) Tl)'l N 3'I'D q'DI ~ lTD t' 2 '[' I') T b 1' UNIT,fi AP1 APl AP/ AP1 FILEN 0 0 4 0 0 0 4 0 0 0 4 0 0 0 ti 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 q 0 () 0 4 0 0 0 4 0 PRUC ,SAM REP DE;Pr 8HJI~T 0 1 68 0 0 0 1 b8 0 0 0 I 68 0 0 0 1 68 0 0 0 1 b8 0 0 0 1 b8 0 0 0 I b8 0 0 0 1 b 8 0 0 0 1 b8 0 0 0 I 68 0 0 0 I b8 0 0 D k I-' Itt { 0 { { 5. 000 10 ]00. 000 10200.000 I t) I O0 o O00 1 r, o00. ()00 qgo0. 000 9 iq 00. ,') 00 c) )o0. 000 O6U0. 000 q%00oO00 q <~ 00. ¢) o 0 q ] 00.000 q?O0. 000 q 100. ¢)O0 I~NEMtjNIC GP N 1 'I l) 1~ 2'I'D Git N] [, f,, 1TU ? ?TD 'ID 21'L) NITD f'Y1D 21I) tdl II) td 1 F21I{ r,~ 1 TD [,' 2'TI) II 1 F'YTD (oF Ill '1 D l- GH N1 TO F 21D G R r41 Ti.) t 2Tu N1 l'I~ f 21'L~ -999 -99 ,) -999 -q99 -999 1750 29 22~J 29 1184 ]2 998 22~, jl 1152 )29 )d 193 42 19u4 31 1154 I UO 2q 47 1 440 255 UL .000 .000 .0 tJ t) .000 .00() · 000 .0()0 . O00 .5 () 0 .000 . C)()0 .9(.)0 . ()00 .0¢)0 .20O .00() .00() . ~00 .000 .()00 .1 o() .00 0 . O c) 0 · 000 . o 00 800 .DO0 .0o() 6o0 00¢) 000 . o 00 .0 () 0 , OD() 45. lbq8. 2 o~. 1766. 900 000 000 ;~ 00 000 MN EMU N lC TAU N2TD F3TD TAIl N2TD ~ 3TO I ALI N2TD '} AlL) i' JlD IAI) N270 F ]I?D IAiI N21D 'J t' 3'1'[) 1AtJ N2TD [,, l ~ 3TD 1_ AL_) N2'I'I) F]qD 'i AU N2TD [~ 3II) 1 AL) N2TD [. 3'1 I.) 'l ALI N21D [. 3rLD !Ail N2TI.) 1; 3"I L) VAbIJk -99q.000 -999.o0o -99g. 000 -999.000 -q9g. 000 -999. 000 165.991 1122.000 78.00 o 312.547 148.O00 61 .~)00 230.770 862.000 7 l. 000 291 .217 150.o00 59.000 238.519 878.000 75.00u 3~7.b41 674. t)O0 (~3.000 158.218 125').()00 /b.()O0 241.~04 Bb6.()00 7o. (')00 2 ~7. 265 956. 000 HO.()O0 186.~24 ~ O52 .()00 88. 000 159.q75 1148.O00 75.000 172.211 1188.00O 74. 000 MNkMC)N lC r t'~ A T VALUE -999.000 -999,000 -999.000 -999.000 3.525 532.000 1,905 404.000 2.515 518.000 1.995 506.000 2.290 540.000 1.815 538.000 3.875 6~0.000 2.210 572.000 2.425 592.000 3.945 618.000 o.110 600.000 3.770 612.000 MNEMUN lC 8 F'ITD 8IGM flTO SJGM F1TD SIGM [.lTD $1GM i" lTD 51GM F1TO S i GM ~ lTD SIG~4 F1TD $1GM F l "fO 81GM [''lTD 5iGM [''lid 8lGtq F1 SIGM [. lTD SIGM [.ltd VALUE -999.000 -999.OO0 -999.000 -99Y.000 27.300 310.000 14,525 304.000 19.250 323.000 15.050 291.000 19.325 327.000 13,450 2~0.000 2U.~25 263.000 18.375 211.000 19.075 312.000 24.900 335.000 28.325 214.000 20.475 207.000 r 9000.000 8900.000 RRO0.O00 R70() ·()00 ROOt,. ()0() qSO0. 000 MN GR N1 P2 N1 GP N 1 GP N 1 N 1 ~NIC T D '[ 1} FL, '1' D TO 'l't) TD 1' [' 'FD 'ID VAL 1274 202 41 1350 192 1902 22u 1990. 47. 1H28. 26~. -999. -9~q. -qq9. IJL .200 · 00 0 · DO0 .000 · 000 . OUt.) .300 .OOO . 200 OO t) 1 O0 000 000 1 0 0 000 0 O0 250 25o 250 MN EMt)NIC tAU [.d 2 T D ~3TD TAU N2TD ~' 3q'l) TAIl N2TD ~ 3TD IAtl N2TD F TAU N2 rE) ~ ]'Ft.) TAll N 2 T D l~ 3'rD 1 AU N2TD VADU 257. 902. 206 o 976. 76. 140. 1312. 74. 1~J9. 300. 78. 162. 1262. 92. 143. 1260. 80. -999. -999. -999. 591 o00 000 050 000 000 675 000 000 649 o0o 000 48't 000 000 413 000 000 250 250 25O MNEMONIC TNA'F N3TD TRAI N3TD THAI' N3TD ~ HA 1' N 3'F D ffRA'I N3TD TRAT h31'D VALUE 2.470 610.000 3.190 590.000 3.830 O72.000 4.370 650.000 656.000 4.225 612.000 -999.250 -999.250 MNEMONIC Sl GM 1- 1 i'D S1GM f'l I'D SIGM SIGM flTD SIGM F1TD SIGM Fl'FO SIGM F1TD VALUE 17.750 215.ooo 22.025 2~4.000 31.050 309.000 52.400 278.0O0 28.450 3~4.000 31.925 283.000 "999.250 -999.250 ,%I~,~,INAt-~ LJf' I)ATA I,[.,,NGIH [J~ P,E, CLIHI),S'. 1018 [,t.',N(;Jft [1[; i.~A~T PJ".CUPLJ: ~gO f II,P, IFAJLI',R LEDGTH: J024 BITES F ll,P HI., ADE, R 102~ P 1L~,, NAMf',: ILDJ.'r . O0 4 MAXI~.IUf4 [,.;HfSICAb P, ILCtJHL,' LENGTH: [PP,~',V ] f. JJ.lfi [' ! LE 1,1A['4~'. J JTE. IN?tJ~ATIflN HI~,C{IRD I,F.N(;'i H CtI~',PAN¥ fEI,Df SI<C' T JUl',' CflIJN I ¥ 178 ~YIE$ ~AI~ ATHON TBU D- 1 5 r'~CARTHUR 13~ ~ENAI AI~A,SKA Ulb C{J. [~A'I'A [- t]kI,~AI' ~Pi:.C IF ICA I,I./NG I I.t: 4.50 F, i'l'l P, ¥ BLIICt~ S: I 0 SIZE 1 ENTR~ 0 118 AP I AP I AP1 AP1 [~i 0 0 0 0 GAP I 51 31 32 0 08 51 41 1 0 C/C 51 42 1 0 Ct~ 51 40 1 0 CFS 51 39 ! 0 Ci'S 51 39 ~ 0 CPS 51 39 3 0 CPS 51 39 I 0 CPS 5 l 39 2 0 CPS 51 39 3 0 F lhE,# alZk EXP PROC SAM REP D~Pr SHIFT 4 O 0 1 68 0 0 i 0 0 1 68 0 0 0 0 I ~8 0 0 4 0 0 1 08 0 0 4 0 0 I 68 0 0 4 0 0 1 68 0 0 4 0 0 1 b8 0 0 4 0 0 1 08 0 0 4 0 0 1 68 0 0 4 0 0 1 68 0 0 4 0 0 I 68 0 0 DE t-'"i' h 10 ~, (') 0. 000 1 qTOO. 00(.) 10100.000 1 nO00. 000 qgO0. 000 9700.000 q600. 000 q500. 000 q 400. 000 qlO0.000 q )00. 000 q i ()(~. 000 MNt.[ItlN lC N 11' D t' 2 T D GP hlTD F 2TD N 1 Gk N1TO I. 2TD N l T D ~ 2'¥0 1,) 1 T [) I11 TD ? GP NITD ?'2TD ~ 1 TD 1' 2 T D G~ NI1'D Gk hl I'D ~ 2'lO l'q I 'I'D t' 2TD 9 AL 0 4010 200 1 0 4010 2(.)07 5O 1626 714 27. 1042. 221. ]5. 942. 2'16. ~1. 1024. 20(). 30. 199. ]2. 1 O06. 213. 1~90. 189. 41. 1440. ?lc). 30 o 712. t9. I ~68. 237. 45. 1642. 194. 53. 175R. 113. 40O OO() 000 .400 .0OO .000 . tO0 .000 .000 70o 00 o 0 t) 0 500 OOt) 000 500 000 000 7 O0 00() OOO 500 000 000 200 o00 000 7 O0 000 O 00 1 O0 (} 00 0OO 500 00 r) 0()0 7 O0 000 000 7 O0 0 o o 000 MNEMUN ] C '.[AU t. 3TD 'I AU N2TD [" 31D tAU 1~ 2TD ~ 3 TD '1. AU ~',~ 2'1D [.' 3'£D '1 Al} N2'l/) t' 3"1' D IAtJ N2TD 1~ 3TD N ~ r D 1~ 3TD TAIl N2TD P 3TD TAU h 2 T 1) P 3 'I L) N2TD I'3TD ~2I'D 1' lTD 1 AU N2 T A L) N 2Tt} I' 31'O I A U N2li) VALUE 1026.474 4004.o0o 1997.O00 102~.474 400q. O00 1997.000 171.267 1078.000 70.000 .~tOq.536 768 .O00 ~4.000 2~9.210 e, 56.ooo 12~.O00 295.73~ 7~8.000 63.000 268. I 30 820.000 71.000 31 1.292 782. r) 00 71. o00 156.964 1254.000 15.O00 22].212 102,~.000 85.000 2~1 .g95 996. O00 19.O00 20 3. ~9() 10 ~8.000 91. 000 162.233 1130.000 66. 000 I 71.016 I 184.000 71.000 MNEMONIC TRAI ~AbUE 4.875 4012.000 4.875 4012.000 3.515 528.000 1.835 474.000 2.800 440.000 1.950 522.000 2.385 536.000 1.770 538.000 ].905 626.000 2.485 616o000 2.545 608.000 3.775 624.000 4.080 624.000 3.850 648.000 MNkMUNIC 8LGM Fl'rD 81GM 1~ lid 81GM ['lTD 8IGM ~ lTD ,51GM 8IGM F1 rD $1GM I. lro $1GM I~ITD 6iGM F11D SI GM F 1TD SIGM ~lrO SlGM ~II'D $IGM F1TD 8IGM t' I 'ID VAbU~ 0.000 2000.000 0.000 2006.000 2b.b25 273.000 14.075 310.000 16.500 282.000 15.300 293.000 17.225 301.000 14.650 300.000 29.000 218.000 20.400 324.000 19.600 299.000 22.125 308.000 27.875 203.000 20.625 270.000 DkF'I H qO00.000 ~900. 000 H~O0.O00 870U. o00 ~600.000 8500.000 NNEM[JN lC N1TD [" ?'I'D G~ NlrD ~ 210 (; k ' NI[D [, 2TD GR N 1 TD ?2TO GF NI Ti.) t~ 2 T D 1 T D 2'10 N1 fD ? 2ti) ]3 2 ~4 21 2 lq 1 17 2O -9 -9 -9 AL ]5 2O 19 40 24 59 ]0 27 57. go. 55. 88. 64. 11. 99. qg. 99. .8 .4 .0 .0 .2 .0 o0 ¢) 0 0 ¢) O0 O0 00 OO O0 O0 00 O0 00 OO OO O0 00 O0 50 5O 5 () MNENUN IC TAU N2TD [" 3'I'D IAU N2TD FJTD TAU N2TD F 3TD T A ti TAU iq 2 T D ~ 3'rD TALI 1~ 2 T D ~3I'O '1 ~U lq 2 'I D J;31D VAb 251 962 2 O0 1036 141 1~94 92 138 1318 84 159 127~ 99 137 135~ -999 -99<4 -999 IJE .006 .000 .000 .37b .000 .000 .g07 .000 .000 .645 .000 .000 g75 . .000 .000 .1 30 .00() .000 .250 .250 .250 MNEMONIC TRAT N31D RAT 3TD 'rRA Y N3'IO N 3'ID TRA'I N]ID TRA£ VALUE 2.515 570.000 3.075 632.000 3.830 700.000 4.490 654.000 3.755 648.000 3.905 650.000 -999.250 -999.250 MNEMONIC 81GM P'I I'D S1GM F1TD SIGH FlrD SiGH ~ 1 'tO SIGH i" lTD SIGH ['lTD SIGH lTD VAbUE 18.150 303.000 22.825 2/~.000 31.825 329.000 32.650 254.000 29.050 324.000 33.150 299.000 -999.250 -999.250 ,.ql]I'4~,AEY L)f' DATA I kNGlti [~l. t4I._CIJ~Db~ 1018 I,F.NGIt~ L,F I,AS'I [~[.,('LIED: 490 F II,E IPAJLEH LFNG'i[I: 62 BX']E$ F [1,~ NAHL: l,,Dl']' .094 HAXI. Mt~bl PId~SICAI., ~I-,CIJED NI,,XI' l'Jl,E NAME: L, kNG I'H: ["II~?, HEADEP 024 BY TI~,5 I,F, NGI td: ~.2 B Y'FL,3 I~JLI., N A/'.IE: I: DJ 1' PRFVJUU~ FII, L NANE: 1024 BXTE$ ~t, Ll,l, $lq2L INI'(JR~'IAT/(-tN I,F, NGIH: 178 BY'CFS Ct,~/F'ANY: MAPAI'H{}N DIL CO, w LI,[.,: 'IBU b-15 MANGL: 13w l'l)W,q: 8N bI-'C'T 1 ON: fl ( iIUN'I'Y: ,c, TA l'k,: A L,A,SK A DAg'A I;'£JHNAT hPP-.Cll- ICATll3~'~ I',F'NG'I H; 450 Id~'['E$ F :',ITI-,,~' BI,UCF:S: TYPk 0 1 REP C (Ii')E ENTRY 0 DA'IUM ,",FLCJI: ICA'I'JUN BLIK'K,S: Y 1C ['UOL bVLIRDt~ I £> [= P ]' 2 (; Iq '] D'i } T A U ']' D T 4 'IFAT 'If) T % $1GP1 7t) l' 6 N 1 T b '1 O'! N ~ I D 'I D'I g ~ I IL) 'I'D[ i" ? ~ D 'f t)'l I F lTD '1 UNITS APl AP1 AP1 I~T 0 0 0 (.;APl 51 31 32 OS 51 41 l C/C 51 42 1 CU 51 40 1 CPS 51 39 1 CPS 51 39 2 CPS 51 39 3 CFS 51 39 1 CPS bl ~q 2 CPS 51 39 3 AP1 FILL# SiZE EAP PROC 0 0 4 0 0 0 0 4, 0 0 0 0 4 0 0 0 0 4 0 0 0 0 4 0 0 0 0 ~ 0 0 0 0 4 0 0 0 0 4 0 0 0 0 4 0 0 0 0 4 0 0 O 0 4 0 0 SAM REP DLPI fiHI~T 1 b8 0 0 I OB 0 0 I 68 0 0 1 68 0 0 1 68 0 0 1 b8 0 0 1 b8 0 0 I 08 0 0 1 68 0 0 1 68 0 0 1 b8 0 0 DkPq H 10~15.000 10~00.000 I 0200. 000 10190.000 :100()0. 000 9900. 000 9700. 000 q600. 000 9500. O00 9100.0()0 q 300. 000 9700.000 q 1 O0. 000 MNk, Mt)N lC I',11 I'D F 2TD N 1 T i) ? 2 TL) TI) 2TD GF [- NJ'ID l. G~ r,) I l D [- 2TD GP N1 TD ['2TO N1 TD [~ 2'I'D G P tJ 1 'r O F2TD GR hli'D F NJ TI) F2TD GR l',~ 1 T i) [' ?TD I'D AL, tIE -q99.O00 -999.000 -999.000 -999.000 -999.000 -999.000 50.700 159().000 187.000 27.900 I 21 I. O00 32.0()0 150. 000 244.000 34. 600 1058.00(') 210,000 9OO 000 O00 34.50() 104 2. 000 2e 1 .000 43.70o 1870.000 216.000 40.900 llJ4.000 188.000 ~3.500 1200.000 229.0O0 qb. qO0 I 592. O00 288.000 42. 200 I 818. 000 20(:,. 000 39. 600 1570.0OO 150. 000 NNkMIIN lC N2TD ~3TL) IAU N2TD [,3TD N2TD t, 3TD 'I AU k 2TD ~ 3TO 'tAU N 2TD .~ 3TD AU 'I'D 3TL) IA[I N2I'D ~ 3TO TAU I~21D [' ilL) N 2 T D F 3 TD I'A U N2TD f ]"I'D TAU N2TD ~' 3TD TAU P 3!'1) I'AU m210 b 3'ID qAU P 3 T D VALUE -999.000 -ggq. O00 -999.O00 -999.000 -999.000 -999.000 174.529 1094.()00 79.0O0 310.038 8Z2.000 69.000 245 .O4t 810.000 71. O00 284.944 830.000 71.000 252.~21 898.000 70.000 30h.524 808.000 75.000 161.481 1244.O00 75.000 U .000 75.000 248.557 928.000 76.000 182.O58 1154.000 154.956 1210.000 76.()OO 177.039 1134.(')00 7 ?. OOC) Mi,{ b.M(J N 1 C TRAI N 3TD I'RAI N3TD T~AT IX{ THA1 N )I'D N3TD TRAI' N 3 I'D TRAI N3TD IHAT N3TD TIeAT N3TU N3TD 'IRA] N3tD IHAT N3TD N3TD I'RAT N3[[D VALUE -999.000 -999.000 -999.000 -999.000 3.570 592.000 1.850 558.000 2.500 576.000 2.025 576.000 2.265 596.000 1.755 608.000 3.715 692.000 2.295 622.000 2.335 640.000 3.810 678.000 4.160 660.000 3.775 048.000 MNEMONIC $1Ga F1TD SIGH F1TD 81GM F1TO $1GM 81GM lTD S IGI~ FII'D SIGM F1 £0 S1GM F1 'rD SIG~ ~ITD SIGH F1TD 1 GM lTD SiGH [;lTD SIGH Fl rD $1GM F1 'I'D VAbUE -999.U00 -999.000 -999.000 -999.000 26.050 271.000 14.675 324.000 18.700 320.000 16.000 300.000 18.250 321.000 14.800 347.000 28.000 306.000 11.600 239.000 18.225 296.000 25.425 342.000 29.025 302.000 25.700 240.000 DEPI H qOOO. 000 ~9~0.000 ~00.O00 ~ 700. ¢) 00 Rh00,O00 ~500.000 RlT0,O00 M N Gk N1TD ~2TO N 1 Ti) t. 2I'D GP ~'J 1 'I'D t' ?I'b 1~ 1 T O N1TD 2'I D GR N ITl) N1TD ? 2'to VA 122 18 '4 184 b 2O 6 210 19 5 lb9 25 -q9 -99 -99 LUE 7.90O 2 .O00 b,000 1.800 b.O00 3. OO O I, 700 0.000 0.000 1.000 4.000 {. OOO I. 000 2 .oon 2.000 0.000 0.000 0. 000 9.25¢) 9.25o 9.250 MN TAU N2T ~3T TAU N2T ~ ~T 'IL A U N2T i'JT IAU b 2'r [. {'I' ]All h 2']'0 [. 3 '[' 1) N2TD ~,' 3TD IAU N2Ti) ~3FD N1C VAbUk · 0 O0 7].000 171 016 111.0OO 148.432 1270,O00 88,000 1 ]4.630 1428.000 87.000 1.81,054 1208.000 10 ~. 000 -1.129 0.000 0.000 -99q.250 -999.250 -999.250 MNkMUNIC TRAI N3TD 3RAI' N 3TO IRAT N ~,TD TRAT 3TO '].'RAT N 3TD T P A T '1 R A T N3TO VALUE 2.490 642.000 3.0~0 752.000 ].820 680,000 4.b25 718.000 3.255 678.000 0.000 0,000 -999.250 -99g.250 MNEMONIC $1GM F1TD SIGM lTD SIGM F1TO S1GM F1TO $IGM F1TO SIGM F1TU SLGM F 1 TO VALUE 1~.~00 2o .000 26.415 332.000 ~0.550 285.000 33.525 293.000 25.525 329.000 0.000 0,000 -999.250 -999.250 1024 [APl'. i,[ NGIH: 132 PAl-'}., NAHE: 00't. 51 SI. hV ICh, N A ~'ll-,: EL) i. 1 rAPE C()~'I I. NIJAI'It)N ~LJ;,i~ RI I'II-,Y'r 'l APE I'.At4P.: O) 80/ 5/
