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Home My WebLink About174-002P i D 17�-OC) 2cD Hilcorp I Well: D -14R5 I Field: I Dolly Varden 03/26/2020 1W Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) 2020 Press - Perfs PKR -133/8" 9 5/8" T 3 1/2" 2020 Temp 2018 Tern Report date: 10/6/2020 • • P-1"1) 1-74.0020 IHilcorp Alaska, LLC Well: D-14RD Field: Dolly Varden 05/13/2016 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1000 ____ilm Ni Pressure-Temperature Profile 2000 — 1 RIH 4/26/16 vs 5/13/16 1( 2. Well Shut-In -- 3000 4000 5000 r Ysono r - Ce ca 7000ca si t 8000 CI _ 9000 10000 11000 - 12000 13000M .."--- 14000 I I I I I I I I I 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) -5-13-16 Pressure — Perfs x PKR -13 3/8" 9 5/8" 7" 3 1/2" —5-13-16 Temp —4-26-16 Temp Report date:9/20/2016 S`PNNED FEB 1 62017, • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, March 08, 2016 9:22 AM To: 'Dan Marlowe' Cc: Larry Greenstein Subject: RE: D-14rd Shut-in due to possible IA casing communication (PTD 174-002) Dan, Approach is acceptable. Let us know of the results. The question I will have before you approach a temp survey decision is what is the well repair plan and schedule. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue SCANNED Anchorage,AK 99501 MAS 8 2016 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Dan Marlowe [mailto:dmarlowe@ hilcorp.com] Sent: Friday, March 04, 2016 9:52 AM To: Wallace, Chris D (DOA) Cc: Larry Greenstein Subject: D-14rd Shut-in due to possible IA casing communication (PTD 174-002) Good morning Chris, We shut in D-14rd yesterday morning due to possible tubing x IA communication. We would like to request time to do well diagnostics. 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. 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. Attached are the well's schematic and 90 day TIO plot. Let me know if you have any further questions , . Thanks 1 0 0 0 0 0 0 0 0 0 ..r. c-, eq ..-. c.., c... .-. .r., .. ,.." . - ...., .. .,-.. 0 Ts, •-•• C.• hi -r.I1 c...., a _ ..... 0 .7....E- cr. ki in .3 co ei in I ....... a g ..i 0 .0 * 0 0 I 0 10 I.• .41 1 i 0 e, i 7 _c..2 I.- I em•' .......- ) .4' -..... ....... .. g.., 0 0 01 0 0 0 0 cs• 1.41 0 .=. Inc. 0 c, c:, .2, C., VI r•JI Iry ..-. cr. In ....-. . • H . i McArthur River Field,TBU SCHEMATIC • Well: D-14RD Hileorp Alaska,LLC As Completed: 5/10/1987 CASING DETAIL RKB to TBG Head=40.80' Size Wt Grade Conn Top Btm 13-3/8" 61 J-55 Butt 45.30' 2,545.69' ] 1 2 40 N-80 Butt 43.50' 5,513.41' 9-5/8" 47 N-80 Butt 5,513.41' 6,966' 7" 29 N-80 X-Line 6,735' 13,579' Tubing Detail 3-1/2" 9.3 N-80(IPC) Gatorhawk 40.80' 12,861' 055 HTC I DV collar JEWELRY DETAIL @ 6408' No Depth Item `x/ u 1 40.80' CIW type"D"tubing spool,3-1/2"DCB Cameron Tbg hgr,3-1/2"8rd EUE top and bottom ✓ \ / \ 2 40.80' Xover,3-1/2"8rd pin x 3-1/2"D55 HTC pin 3 12,778' Tubing locator with 16.5'seal assembly stabbed into packer and seal bore 4 , 4 12,775' Baker FB-1 perm packer with 4"x 15'seal bore ext with tailpipe attached 5 12,829' Otis S-1 nipple,2.875"ID 6 12,861' Btm of tailpipe,1/2 muleshoe PERFORATION DETAIL Zone Interval SPF Date Comments HB-1 12942' 12952' Top perf=9546'TVD HB-2 13000' 13074' HB-3 13092' 13126' HB-3 13155' 13165' HB-3 13175' 13190' HB-4 13210' 13258' HB-4 13265' 13303' Btm perf=9816'TVD 13425' 13427' Sqz below retainer @ 13387' _ _1 3 _ 4 111 5 6 Last fill tagged at 13360'on 5/14/Oi TD=13600'MD,PBTD= 13387' Max Hole Angle=60°@ 9700'MD Hold Angle=42°@ PBTD Updated 2014-11-05 DEM KOP=1100' MEMORANDUM State of Alaska Packer Depth Pretest Initial Alaska Oil and Gas Conservation Commission TO: Jim Regg {, P.I. Supervisor lG� I �l L DATE: Friday, September 28, 2012 SUBJECT: Mechanical Integrity Tests Type Inj HILCORP ALASKA, LLC D-14RD FROM: Jeff Jones TRADING BAY UNIT D-14RD Petroleum Inspector 2390 2390 " Src: Inspector Reviewed By: 1740020 P.I. Supry NON -CONFIDENTIAL Comm Well Name TRADING BAY UNIT D-14RD API Well Number 50-733-20164-01-00 Permit Number: 174-002-0 Insp Num: mitJJ120927202802 Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 8/31/2012 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well D-14RD Type Inj 9411 IA 420 2400 2390 2390 " PTD 1740020 Type Test ;lp( 2352 OA 210 310 340 350 nterval 4YRTST P Tubing 3200 3175 3200 3200 ' _ Notes: I well room inspected; no exceptions noted. SWNED Friday, September 28, 2012 Page I of 1 • Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) p 1 7 H -6oz_ Sent: Wednesday, April 25, 2012 11:39 AM To: 'Tom Fouts - (C)' Cc: Keith Elliott; Ted Kramer; Larry Greenstein; Juanita Lovett Subject: RE: Sundry Cancelation for TBU D -14RD Will do... sundry 312 -111 for a FCO and acid job will be withdrawn. Guy Schwartz Senior Petroleum Engineer AOGCC 5AAMNED MAY 2 a Z 14 793 -1226 (office) 444 -3433 (cell) From: Tom Fouts - (C) [mailto:tfouts @hilcorp.com] Sent: Wednesday, April 25, 2012 10:20 AM To: Schwartz, Guy L (DOA) Cc: Keith Elliott; Ted Kramer; Larry Greenstein; Juanita Lovett Subject: Sundry Cancelation for TBU D -14RD Guy, Hilcorp Alaska, LLC requests to withdraw Sundry 312 -111 for TBU D -14RD which was approved on 3/29/2012. Thanks, Tom Fouts !Construction Manager Iiiicorp Alaska, LLC tfouts @hilcorp.com Direct: (907) 777-8398 Mobile: 1907) 351 -5749 4/25/2012 • • SEAN PARNELL, GOVERNOR ,E1,81011L\L ®1114 LI® Cril5 333 W. 7th AVENUE, SUITE 100 CI DRIMEEFEWI ORT CI IIORT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Elliott Asset Team Leader Hilcorp Alaska, LLC n0 a' 3800 Centerpoint Drive, Suite 100 I [7 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU D -14RD Sundry Number: 312 -111 Dear Mr. Elliott: SCANNED APR C, 2 A112 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 • . Foerster Chair DATED this z9 day of March, 2012. Encl. • Ws 3/7..1I t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension 111 Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 1151 - Alter Casing ❑ Other. Clean Out 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 174 -002 . 3. Address: Stratigraphic ❑ Service 0 _ 6. API Number. 3800 Centerpoint Dr., Suite 100 Anchorage, Alaska 99503 50 -733- 20164 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No © Trading Bay Unit D-14RD ` ` �'# 9. Property Designation (Lease Number): 10. Field / Pool(s): .. ADL0017579 t McArthur River Field/ Hemlock Oil Pool - BAR • 11. PRESENT WELL CONDITION SUMMARY tag s G 3 4. o , Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): (4) tx jj Aku9k (measured): 13,600 10,025 13,251 10,655 N/A ,1 , 1,�). Casing Length Size MD TVD Burst Collapse r Structural Conductor Surface 2,543' 13 -3/8" 2,543' 2,410' Intermediate Production 6,966' 9 -5/8" 6,966' 5,796' 12,390psi 8,850psi Liner 6,844' 7" 13,579' 10,022' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Sheet See Attached Sheet 3 -1/2" 9.21b/N -80 12,861' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FB -1 packer and N/A 12,777(MD)/ 10,302(TVD) and N/A 12. Attachments: Description Summary of Proposal 1511 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 151 Exploratory ❑ Development ❑ Service el 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/1/12 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ 151 GINJ ❑ WAG p Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Dunn Phone 777 -8382 Printed Name Keith iott Title Asset Team Leader Signature .-- hone 276 -7600 Date 3/23/2012 COMMISSION USE ONLY z Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3l1— 11 Plug Integrity ❑ BOP Test ®' Mechanical Integrity Test ❑ Location Clearance ❑ Other: , . OO J (SL, f� p� �' Subsequent Form Required: / d .-ii on APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 3 -2.� — I Z 10-403 -4 Revised 1/ APR 2010 2012 „ 3—.2'9' f L O ` tttJJJ VVV ►.[ I G I I\1 A L �� Submit in Duplicate 4-7,v‘ll: 0 • • Perforation Data D -14RD MD TVD Top Bottom Top Bottom 12,942 12,952 10,425 10,432 13,000 13,074 10,468 10,523 13,092 13,126 10,536 10,562 13,155 13,165 10,583 10,591 13,175 13,190 10,598 10,609 13,210 13,258 10,624 10,660 13,265 13,303 10,665 10,693 13,425 13,427 10,784 10,785 14 • D -14RD CTCO Procedure McArthur River Field Hikorp Alaska, LLC March 15, 2012 WELL: D -14RD JOB SEQUENCE: No. 7 of 7 (Second job in Leg B -1) OBJECTIVE: Clean out fill over lower Hemlock perforations. Wash the perfs of Iron sulfide scale with Xylene and 10% HCI acid. Restore injection rate to full capacity. BACKGROUND: D -14RD is an active injector, currently injecting about 3000 bwipd while supporting D -8RD and D -12RD with waterflood. The well took as much as 4000 bwipd in December 2002. Recent SL diagnostics indicate fill covering most of HB -4 perfs. A sample was taken and most (68 %) of the fill was organics (crude components) with a small amount (9 %) of Iron Sulfide. The casing will be cleaned out to PBTD with coiled tubing. CURRENT STATUS: Current BHP: 4303 psi @ 9450' TVD — based on a 91 day shut -in survey on 5/15/00 Max Downhole Pressure: 4303 psi @ 8480' TVD (No new perfs being added) MASP: 29Q.psi (based on a pressure gradient of .435/ft back to surface) Leg: B -1 (SE Corner) RKB to MSL: 106.2' BHT: 185 °F Max Deviation / Max Dogleg: 59.75° at 9,700' MD / 4.99 °/100 ft. at 11,900' Maximum TD with coil: 13,387' Recent intervention: Fill was tagged at 13251'. Sample taken with 2" bailer. It appears that approximately 50' of HB -4 perfs are covered with fill. The tubing pressure was noted to be on a vacuum, with 0 psi pressure. HIGH LEVEL PROCEDURE SUMMARY: 1. If this is the first CT operation on the platform, notify AOGCC at least 48 hours in advance of well operations ✓ to witness test of BOPE and to inspect equipment. 2. MIRU Coiled Tubing Unit. Spot tanks, fill with 8.5 ppg Filtered Inlet Water (FIW). 3. Install BOPE on top of tree. Test BOPs to 3000 psi per standard procedure. Record pressures. Notifiy AOGCC (if not present) of successful test. 4. RIH with 1 -3/4" coiled tubing and down jet nozzle and tag fill. With sweeps, N2, and /or foam as necessary to clean hole, wash and jet down from fill tagged at 13251' to PBTD at +/- 13387'. CBU into Separator 5. 5. If the fill is hard and unable to be jetted, prepare for and pump a Xylene and 10% HCL treatment to dissolve the solids. CBU with N2 and foam as necessary. 6. If considerable scale is observed, squeeze 10% HCI behind the perfs to dissolve any calcium carbonate and or iron sulfide scale that might be present. 7. Once several bottoms up have been pumped, take returns to open top tank to inspect returns for solids. If none, POOH. 8. RD CTU. D -14RD CTCO Procedure Page 1 of 9 T.Fouts 03.23.2012 • • D -14RD CTCO Procedure McArthur River Field Hikorp Alaska, LLC March 15, 2012 Attachment A — Wellbore Schematic RKB to TBG Head = 40.80' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 1 2 13 -3/8" 61 0 2543' 9 -5/8" 40 -47 N- 80 /AR -95 0 6966' 9 -5/8" DV tool at 6408' 7" 29 N -80 Butt 6735 13579' Tubing: 3 -1/2" 9.2 N -80 (IPC) DSS HTC 0 12861' 1 DVT @ 6408' JEWELRY DETAIL \/ x NO. Depth Item /\ 1 40 3 -1/2" DCB Cameron Tbg hgr, 3 -1/2" 8rd top and bottom L 2 40 Xover, 3 -1/2" 8rd pin x 3 -1/2" DSS HTC pin 3 12779 Tubing locater with seal assembly stabbed into packer and seal bore. 4 12777 Baker FB -1 perm packer with 15' seal bore ext with tailpipe attached 5 12829 S -1 nipple, 2.875" ID 6 12861 Btm of tailpipe, 1/2 muleshoe PERFORATION DATA 3 TOP BTM ZONE SPF DATE COMMENTS 4 12942 12952 HB -1 Top Perf = 9546' TVD 13000 13074 HB -2 6 13092 13126 HB -3 13155 13165 HB -3 13175 13190 11B -3 'Last fill tagged at 13251' on 2/20/12 13210 13258 HB -4 13265 13303 HB -4 Btm perf = 9816' TVD 13425 13427 Sqz below retainer @13387' VANNATAW 4 •VA1WPW AVIANNWINWic TD = 13,600' MD, PBTD = 13,387' Hole Angle = 42 °at PBTD Max Hole Angle = 60 @ 9700' MD KOP = 1100' D -14RD CTCO Procedure Page 6 of 9 T.Fouts 03.23.2012 0 0 D -14RD CTCO Procedure McArthur River Field 1likorp Alaska, LLC March 15, 2012 Attachment 2 — Dolly Varden CTU BOP Stack Mill Q Q JI P x1► I 96000Seneck i - --. 1 c.o.) 4 ,ip A J iliIIr• MI It 0 NI :A IN ,�, S& S 800L Injector Head - 4r Hydraulic Stripper 4116" 10K 1111 • Crossover 41/16" 10K x 51/16" 10K 41/16" 10K Lubricator I .i 41/16 "15K Combi BOPs 4 Blind/Shear Ram j • el P ipeISl ip Ram 1 I l ' '` • • (4 1115' 1 CV Flaw Cross t 4 1/16" 10K Safeties Blind/Shear Ram D -14RD CTCO Procedure Page 7 of 9 T.Fouts 03.23.2012 MEMORANDUM • To- Jim Regg !7 P.I. Supervisor ~~ ~ ~ ~~~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 23, 2008 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-14RD TRADING BAY UNIT D-14RD Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ }~p-- Comm Well Name: TRADING BAY 1JNIT D-14RD Insp Num: mitLG080912102324 Rel Insp Num: API Well Number 50-733-20164-OZ-00 Permit Number: 174-002-0 ~ Inspector Name: Lou Grimaldi Inspection Date: 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ D-IaRD :Type Inj. j w TVD 941 I IA 300 2450 2aao zaao ~ P T naooz° TypeTest srT Test psi zaso pA ~ o z ~ z z j j Interval 4YRTST per, F ~ Tubing . z7oo z7oo I z7oo z67s j Notes• Good test. Observed pretest conditions for I S minutes "OK". Well pressured up with water flood, checked before hand for fluid to surface in IA. "~~~~~ ~ `~ ` 70CJF Tuesday, September 23, 2008 Page 1 of i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \<VA '11':2ì . P.I. Supervisor I 'f-lq DlC4 DATE: Monday, September 13,2004 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-14RD TRADING BAY UNIT D-14RD FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :~~ Comm NON-CONFIDENTIAL Well Name: TRADING BAY UNIT D-14RD API Well Number: 50-733-20164-01-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40908164016 Permit Number: 174-002-0 Inspection Date: 9/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-I4RD Type Inj. s TVD 9411 IA 380 2400 2380 2380 P.T. 1740020 TypeTest SPT Test psi 2352.75 OA 0 0 0 0 Interval 4YRTST P/F p Tubing 2850 2850 2850 2850 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Monday, September 13,2004 Page I of I ._... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Reque'st: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: X (convert to prod.) 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 106' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: X Trading Bay Unit 4. Location of well at surface ,/' .,/ ,/~ 8. Well number 671' FSL & 1215' FWL of Sec.6, T8N, R13W, SM Dolly Varden D-14RD At top of productive interval 9. Permit number 210' FNL & 911' FWL of Sec. 17, T8N, R13W, SM 74- ,2y/' At effective depth 10. APl number -,~ 538' FNL & 905' FWL of Sec.17, T8N, R13W, SM 50- 133-20164-01 At total depth 11. Field/Pool 680' FNL & 876' FWL of Sec.17, T8N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary Total depth: measured 13,600' . feet Plugs (measu red) 13387'-13600' cmt true vertical 10,025''/' feet Effective depth: measured 13,387' feet Junk(measured) None 0RIGli~AL true vertical 9865' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2543' 13-3/8" 2400 sx 2543' 2410' Intermediate Production 6966' 9-5/8" 3400 sx 6966' 5796' Liner 6844' 7" 1100 sx 13579' 10022' Pe rfc ratio n depth: measu red 12942'- 12952', 13000'- 13074', 13092'- 13126', 13155'- 13165', 13175'- 13190', 13210'- 13258', 13265'- 13303' true vertical 9546'-9553', 9589'-9645', 9658'-9759', 9705'-9713', 9720'-9732', 9~7~7~2'EiVED 9788'-9816' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 @ 12,861' Packers and SSSV (type and measured depth) Baker FB-1 perm packer @ 12777' Alaska 0il & Commission 13. Attachments Description summary of proposal: x Detailed operations program: BOP sket(j~r~c~lc, rag8 14. Estimated date for commencin9 operation 15. Status of well classification as: 3/10/00 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: x (intend to convert to G-zone producer) 17. I hereby~,a~rtify tha, t th~ Ji~'egoing is true and correct to the best of my knowledge. Signe~j[~ ~l~~~Williamson~]' Title: Drilling Manager Date:~,"/~-~? ~ - -' ~ ..... FOR COMMISSION USE ONLY Conditions of approval: Notify eom mission so rep resentative~ may witnessI'..-~-4~'-I A%ro~N~. Plug integrity.~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~'~ ORIGINAL SIGNED' BY Approved by order of the Commissioner Robert N. Christensort Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL Dolly Varden Well #D-14RD Rig Workover Proposed Workover Procedure Objective: The objective of the workover on D-14RD is to convert the well from a Hemlock injector to a G-zone producer. The well is currently a water injector in the Hemlock Benches 1 through 4. The proposed workover will remove the tubing and packer and clean out fill below the lowest HB-4 perforations. A scab isolation packer assembly will be installed to isolate the HB-1 and HB-2 perforations which are currently thief injection zones. A plug will be placed in the tailpipe below the lowest isolation packer to block the lower Hemlock perforations. New 3-1/2" tubing with gas lift mandrels will be run. After the rig workover, the G-3, G-4 and G-5 intervals will be perforated and the well will be placed on production. Future Plans: After the G zone has been depleted (in possibly 1-2 years), the plug below the isolation assembly will be removed and the well will be converted back to an injector in the G zone and HB-3 and HB-4 intervals. Proposed Workover Procedure: 1. Pressure test annulus to 2350 psi. 2. Shut-in injection. Punch holes in tubing above injection packer at 12777'. 3. Circ kill weight brine down tubing and up annulus. 4. Pressure test wellhead. 5. Install back pressure valve. ND tree. Move in rig. 6. NU BOPE, pull BPV and install 2-way check. Test BOPE with 24 hr notice given to AOGCC for witness. 7. Pull 2-way check valve. Engage tubing hanger with landing joint. 8. Pull tubing 10' and monitor well, circulate FIW down tubing and up annulus (1-1/2 well volumes) to ensure well is clear of gas. 9. POOH laying down tubing. 10. RIH with mill and drill up packer at 12777'. POOH with mill. 11. RIH and retrieve packer and tailpipe with spear. 12. Clean out fill below lowest perf at 13303'. Anchorage 13. If necessary, set storm packer and replace wellhead. ' 14. RU E-line. MU lower isolation packer with plugged tailpipe. Set lower packer at 13083'. 15. RIH with middle isolation packer and 3-1/2" scab liner. Stab into lower packer and set middle packer at 12976'. 16. RIH with upper isolation pakcer and 3-1/2" scab liner. Stab into middle packer and set upper packer at 12850'. AOGCCprocD- 14rd.doc 2/! 1/00 UNOCAL ) Dolly Varden Well #D-14RD Rig Workover 17. Run 3-1/2" completion with GLMs. Set completion packer with tailpipe at appx 12180'. 18. ND BOPE, install and test tree. Release rig. 19. Install gas lift lines and production flowline. 20. RU E-line unit. Perforate G zone as follows: G-3 12369'-12418' G-4 12453'-12512' G-5 12720'-12751' 21. Begin gas lifted production of G zone intervals. AOGCCprocD- 14rd.doc 2/11/00 UNOCAL Dolly ~arden Platform Well D-14RD As Completed 5-10-87 RKB to TBG Head = 40.80' 1 2 DVT @ 6408' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 0 2543' 9-5/8" 40-47 N-80/AR-95 0 6966' 9-5/8" DV tool at 6408' 7" 29 N-80 Butt 6735 13579' Tubing: 3-1/2" 9.2 N-80 (]PC) DSS HTC 0 12861' JEWELRY DETAIL NO. Depth Item 1 40 2 40 3-1/2" DCB Cameron Tbg hgr, 3-1/2" 8rd top and bottom Xover, 3-1/2" 8rd pin x 3-1/2" DSS HTC pin 3 12779 4 12777 5 12829 6 12861 Tubing locater with seal assembly stabbed into .packer and seal bore. Baker FB-1 perm packer with 15' seal bore ext with tailpipe attached S-1 nipple, 2.875" ID Btm of tailpipe, 1/2 muleshoe PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 12942 12952 HB-1 13000 13074 HB-2 Top Perf = 9546' TVD RECEIVED 13092 13126 I-IB-3 13155 13165 HB-3 13175 13190 HB-3 13210 13258 HB-4 13265 13303 HB-4 Last fill tagged at 13303' on 12/19/96 TI) - 13600' MD, PBTD = 13387' Hole Angle -- 42°at PBTD Max Hole Angle = 60° @ 9700' MD KOP = 1100' D-14RD schematic 5-10-87.doc REVISED: 2/11/00 2000 Alas1(~ Oil & ~as Co~.s. Co~missio~ Anchm,ag~ Btm perf= 9816' TVD DRAWN BY: TAB UNOCAL ) RKB to TBG Head = 40.80' SIZE WT Dolly Varden Platform Well D- 14RD Proposed Workover, 3/00 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8" 61 0 9-5/8" 4047 N-80/AR-95 0 9-5/8" DV tool at 6408' 7" 29 N-80 Butt 6735 2543' 6966' 13579' Tubing: 3-1/2" 9.2 L-80 Imp Butt 0 12180' 3-1/2" 9.2 DVT @ 6408' NO. 1 40 2 300 3 L-80 Imp Butt 12850' JEWELRY DETAIL Depth Item 4 12110 5 12829 6 12180 13153' 3-1/2" DCB Cameron Tbg hgr SSSV 3-1/2" GLMsw/R-2 valves and RK latches (eleven total at to be determined depths) Baker SAB perm packer with MOE and K-22 tbg anchor seal assembly 3-1/2" X nipple, 2.813" ID 3-1/2" tubing tail, WLEG 7 12850 8 12976 9 13083 10 13123 11 13153 Baker FB-2 top isolation packer Baker FB-2 middle isolation packer Baker F- 1 bottom isolation packer 3-1/2" X nipple, 2.813" ID with "PX" plug in place 3-1/2" tubing tail, WLEG TOP 12369 12453 12720 ~ 12942 -- ~-~ ~.13000 8 t~.~2~ · I 13092 9 t%~%% 13155 J 13175 ~ 13210 -- 13265 TD = 13600' MD, PBTD = 13387' Hole Angle = 42°at PBTD Max Hole Angle = 60° @ 9700' MD KOP = 1100' D-14RD proposed schematic 3-00.doc REVISED: 2/11/00 PERFORATION DATA BTM ZONE SPF DATE COMMENTS 12418 G-3 12 Proposed after WO 12512 G-4 12 Proposed after WO 12751 G-5 12 Proposed after WO 12952 HB-1 Isolated during WO 13074 HB-2 Isolated during WO 13126 HB-3 13165 HB-3 13190 HB-3 13258 HB-4 13303 HB-4 RECEIVED Btm perf= 9816' TVD Ft-..u l 5 000 Alaska Oil & (las Cons. Cornmissior~ Anchorage DRAWN BY: TAB 20' 18'-7" 18' RIG FLOOR BOTTOM ROTARY TABLE BTM RT BEAM BOTTOM TROLLEY BEAM ] ~PITCHER NIPPLE TO TRIP TANK~ ~ TO FLOW LINE / I IR.,ISER CHOKE CELLAR FLOOR DRILL DECK FLOOR HYDRIL 3-5/8" GK ANNULUR PREVENTER 15-5/8" SM DOUBLE GATE BOP ( TOP PIPE RAM BLIND I 15-~" x 11" 5M CROSSOVER SPOOL RECEIVED FEB l 5 ""*'"' 0il & C~as Cons. Anchom,qe DOLLY VARDEN PLATFORM CDBK INLET, ALASKA CONTRACTOR CONTR. JOB NO. SOl. ....... DOLLY VARDEN PLATFORM ..... BLOW OUT PREVENTER ....... D-14RD .~'D. DB,',mNO NO. .... ,,TS UNOCALe D-DV-01 5 ~^-m 1/30/98 ~s 1 OF 1 Unocal North Americ~ Oil & Gas Division ~,,~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, RG~~~rS~.h~ 1 ~ i~ ~an~ager GSB/lew CONDUCTOR DOLLY DISTANCE & DIRECTIONS FROM SE .CORNER SEC. 6, T8N, "Y" COORD. "X" COORD. WELL # ~ _ LEG #A-1: LAT: 60°48' 28.272" LONG :151°37' 57.620" 2,490,836.22 208,461.20 1 2 3 4 5 6 7 8 9 l0 ll 12 R13W FSL 757.5 LEG #A-2' 1 2 3 4 5 6 7 8 9 l0 ll 12 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' .D-32 762.9 · 2,490,837.76 208,467.60 D-40 759.2 2,490,833.28. 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 2,490,835.42 208,381.20 754.7 LEG ,B-I' LAT : 60°48, 27.485" LONG =151°37' 57.564" 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 ' D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD.& 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752'.5 1 2 3 4' 5 6 7 8 9 lO ll 12 2,490,756.22 208,462.00 " 677.5 LEG #B-2: 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 ~ 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 .2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382. O0 (Reserved for Compressors) 674.8 FWL ,, 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132 1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 12l'9.5 1215.4 121l.l 1208.5 1208.9 1212.l 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 Marathon Oil Company August 11, 1987 Alasl~a~.,~strict Prod,uction United States RO. Box 102380 Anchorage. Alaska 99510 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: Pursuant to UIC regulations administered by the state of Alaska, mechanical integrity tests were successfully performed on four water injection wells during the second quarter workover program on the Dolly Varden Platform. The wells in the workover program included D-6RD, 9RD, 14RD, and 29RD. The results of the mechanical integrity test for all wells, except D-29RD, were. included with the subsequent Sundry Notice on each well. This was omitted in error for Well D-29RD. A recap of the four mechanical integrity tests is as follows: The test was performed on Well D-29RD on March~,, 1987. The 9-5/8", 47#, N-80 casing and 7", 29#, N-80 liner were tested to~-~~si for 30 minutes with no detectable pressure loss. The AOGCC waived~he right to witness the test. ' )~.~p(~))~>~~' The test was performed on Well D-6RD on April 24, 1987. The 7", 29#, N-80 casing was tested to 2,500 psi for 30 minutes with no detectable loss of pressure. The AOGCC waived the right to witness the test. The test was performed on Well D-9RD on APril 30, 1987 The 7" 29# N-80 casing was tested to 2,300 psi for 30 minutes with no detectable loss of pressure at surface. The AOGCC witnessed this test. RECEIVED /tUG ! ~ 1987 Alaska Oil & (~as Cons. Commlssio~ Anchorage . . Mr. Blair Wondz~ August 11, 1987 Page 2 The test was performed on Well D-14RD on May 10, 1987. The 9-5/8", 40# and 43.5#, N-80 casing and 7", 29#, N-80 liner tested to 2,400 psi for 15 minutes with no detectable pressure loss. The AOGCC waived the right to witness the test. Should you have any further questions, please contact Paql Mazzolini at 564-6433. Sincerely, D. K. Corlett District Operations Engineer PEM/DKC/em/468/OE22 RECEIVED AUG 1 4 ]987 Alaska 011 & Gas Cons. Commlssl~ Anchorage STATE OF ALASKA A~KA OIL AND GAS CONSERVATION C_~,MISSION REPORT OF SUNDRY WELL OPERATIONS ~1. Operations per. formed: Operation shutdown ~ Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Opera~tor UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg B-l, Cond. #3 Dolly Varden Platform 671' FSL, 1,215' FWL, Sec. 6-8N-13W-SM Attop ofproductiveinterval 210' FNL, 911' FWL, Sec. Ateffective depth 538' FNL, 905' FWL, Sec. Attotaldepth 680' FNL, 876' FWL, Sec. 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Casing Length Structural Conductor Surface 2,543' Intermediate Production 6,966 ' Liner 6,844' Perforation depth: measured true vertical 17-8N-13W-SM 17-8N-13W-SM 17-8N-13W-SM Trading Bay Unit 7. Well number 8. Approval num~berv 7-322 9. APl number 50-- 133-20164-01 13,600' feet Plugs (measured) 10,025 ' feet 10. Pool Hemlock 13,387' - 13,600' CMT 13,387 ' feet Junk (measured) None 9,865 ' feet Size Cemented Measured depth 13 3/8" 2,400 sx 2,543' 9 5/8" 3,400 sx 6,966' 7" 1,100 sx 13,579' See Attachment #1 Tubing (size, grade and measured depth) 3 1/2" 9.3# DSS HTC N-80 tubin~ @ 12,861' Packers and SSSV (type and measured depth[ 2,410' 5,796' 10,022' Baker 7" x 4" 29# "FB-i" Packer w/15' sealbore extension (4" ID) @ 12,795' 1Z Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casi'ng Pressure Prior to well operation 5/6/87 123 223 1108' 1120 Subsequent to operation6/10/87 6'029 ~bing Pressure 100 psi 3300 psi 14. Attachments: fl2 & fl3 Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.~ .. * Marathon, Oil Company- Sub Operator Form 10-404 Rev. 12-1-85 '- Date 6/25/87 Submit in Duplicate True Vertical depth B-1 B-2 B-3 B-3 B-3 B-4 B-4 ATTACHMENT 1 Dolly Varden Well D-14RD Perforations 12,942' - 12,952' MD 13,000' - 13,074' MD 13,092' - 13,126' MD 13,155' - 13,165' MD 13,175' - 13,190' MD 13,210' - 13,258' MD 13,265' - 13,303' MD 9,546' - 9,556' TVD 9,589' - 9,644' TVD 9,658' - 9,684' TVD 9,705' - 9,715' TVD 9,720' - 9,732' TVD 9,746' - 9,780' TVD 9,788' - 9,816' TVD NEF/em/35A/Sundr2 Attachment 2 Daily Report of Well Operations Well D-14RD 5~8~87 Pumped 878 bbl FIW down tbg to kill well. Set BPV and SI SSSV. ND X-mas tree. NU BOPE. 5/9/87 Pull tbg. out of packer. Circ to kill well. POOH & LD 3-1/2" production tbg & GLM's. 5/10/87 Set RBP @ 1,833'. ND CIW type "F" tbg spool, NU CIW type "D" tbg. spool. RIH, pull RBP. PU & test to 5,000 psi w/Gatorhawk 3-1/2", 9.3#, DSS-HTC, N-80, IPC tbg. 5111187 Finish running 3-1/2" injection tbg. Space out. Test annulus to 2,400 psi as per AOGCC regulations. ND BOPE, NU tree & test to 5,000 psi. Release rig @ 0600 hrs., 5/11/87. NEF/em/35A/Sundr2 o~ AT'I'ACHMEN T {~3 TRADING BAY UNIT Well D-14RD Cameron 3-1/2" DCB tbg. hgr. top & bottom EUE 8rd 13-3/8" @ 2,543' 3-1/2" 9.3 ~DSS HTC N-80 tbg. Top of~ 7" Liner @ 6,735' 9-5/8" @ 6,966' Baker Locator w/16.6' seal assy. ~ 12,778' tbg. meas. Baker 7" x 4", 29# FB-1 Prod. Pkr. ~12,775 DPM w/4" seal bore extension (15') Otis Position "S-i" nipple (2.875") @ 12,829' 1 jt. 3-1/2" 9.2# EUE 8rd w/one-half cut mule shoe @ 12,861' Perforations (DIL) Bench 1 12,942' - 12,952' Bench 2 13,000 - 13,074' Bench 3 13,092' - 13,126'- 13,155' - 13,165' 13,175' - 13,190' Bench 4 13,210' - 13,258' 13,265' - 13,303' PBTD @ 13,387' TD @ 13,579' NEF 6/17/87 STATE OF ALASKA AL/ ' A OIL AND GAS CONSERVATION CO ISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown F1 Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operajor UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg B-l, Cond. #3 Dolly Varden Platfor~z 671' FSL, 1,215' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trmd~n~ Bay Unit 7. Well number D-14RD 8. Approval number 7-161 9. APl number 50-- 133-20164-01 At top of productive interval 210' FNL, 911' FWL, Sec. At effective depth 538' FNL, 905' FWL, Sec. At total depth 680' FNL, 876' FWL, Sec. 17-8N-13W-SM 17-8N-13W-SM 17-8N-13W-SM 10. Pool Hemlock 11. Present well condit Total depth: ion summary measu red true vertical 13,600' 10,025' Effective depth: measured 13,387 ' true vertical 9,865 ' Casing Length Structural Conductor Surface 2,543 ' Intermediate Production 6,966 ' Liner 6,844' Perforation depth: measured true vertical feet feet feet feet Plugs (measured) 13,387 ' Junk (measured) None Size Cemented t3 3/8" 2,400 sx 9 5/8" 3,400 sx 7" 1,100 sx See Attachment #1 Measured depth 2,543' 6,966' 13,579' - 13,600' CMT Feet Tubing (size, grade and measured depth) 3 1/2" 9.2#, N-80 tubimz @ 12,830' Packers and SSSV (type and measuKed depth) Baker 7" 29# "FB-I" Packer @ 12,777' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED MAY 1 8 i987 Alaska 0il & Gas Cons. Commission Anchorage ~ue Verticaldepth 2,410' 5,796' 10,022' 13. Representative Daily Average Production ofxtm~ Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Well shut-in since 11/84 Subsequent to operation 4/27/87 126 271 714 1210 120 14. Attachmentsl hereby certify foregoing correct my knowledge Daily Report of Well Operations [] Attach 2 & 3Copies of Logs and Surveys Run [] 15. that the is true and to the best of * Marathon Oil Company - Sub Operator Ut ~ Signed ~ ,~/~.~.y.~' Title Environmental Engineer Date. 5/15/87 Form 10-404 RS'v. 12-1-85 ~ '' Submit in Duplicate B-1 B-2 B-3 B-3 B-3 B-4 B-4 ATTACHMENT 1 Dolly Varden Well D-14RD Perforations 12,942' - 12,952' MD 13,000' - 13,074' MD 13,092' - 13,126' MD 13,155' - 13,165' MD 13,175' - 13,190' MD 13,210' - 13,255' MD 13,265' - 13,303' MD 9,546' - 9,556' TVD 9,589' - 9,644' TVD 9,658' - 9,684' TVD 9,705' - 9,715' TVD 9,720' - 9,732' TVD 9,746' - 9,780' TVD 9,788' - 9,816' TVD NEF/em/35A/Sundr2 Attachment #2 Daily Report of Well Operations Well D-14RD 3/28/87 Have pumped a total of 985 bbl of FIW to kill well. 3/29/87 Pumped 700 bbl FIW, well not dead, mixed 3% KCL water to 8.6 ppg. Bull heading 3% KCL water now to kill well. 3/30/87 Killed well w/3% KCL water. ND Xmas tree, NU BOPE, tested BOPE. Pulled tbg hanger, 3 pup jts, 7 its of 7-1/2" tbg and one pup jt. Threads on bottom of lowest pup j t OK. PU screw-in sub. Presently RIH. 3/31/87 RIH w/OS. Unable to catch fish. Modified screw in sub. RIH, circ, screw into fish, pump 160 bbl into tubing, no returns to surface. POOH, RIH w/5-1/2" OS, tried to work fish out of sealbore. Unable to do so. Released OS, POOH. RIH w/4-1/2" tubing. RU wireline, attempt to pull WRSSV. Run impression block. Impression block showed control line clamp in change over. Presently RD WL. 4/1/87 LD 4-1/2" tubing N-80, 12.6#/ft ASL. 412187 POOH & LD 4-1/2" & 3-1/2" tubing and production equipment. PU packer plucker and RIH. Presently milling on packer at 12,747'. 4~3/87 Finish milling packer. POOH. LD packer. RIH w/9-5/8" casing scraper & 8-1/2" bit to TOL @ 6,731', POOH. RIH w/7" casing scraper & 6" bit. Presently RIH. 414187 retreivamatic packer. Presently RIH. ~ ?, i"]] ~ _ Page 2 4/5/87 Set test packer @12,808', test casing & liner to 2,350 psi, OK. PU TCP guns & packer, RIH. Correlate w/GR. Presently POOH w/WL. 4~6~87 Finish running correlation (GR). Rig down WL. Space out perf guns. set packer. Perforate Bench #1 13,942' - 12,952', Bench #2 13,000' - 13,074' Bench #3 13,092 - 13,126' 13 155' - 13,165' 13 175' 13,190', Bench #4 13,210' - 13,255', 13,265' - 13,303'. Flowed well back 2 hrs. Had good blow in bubble bucket. No fluid to surface. Released packer. Reversed 180 bbl to production, circ 550 bbl. POOH. Make up FB-1 packer & tail assembly, RIH. Set packer @ 12,775', test annulus to 1500 psi, OK. Presently POOH. 417187 Finish LD DP. PU seal assembly, GLM's, and 3-1/2", 9.2#, N-80 buttress tubing. Externally testing to 5,000 psi. 4~8~87 Finished running 407 its of 3-1/2" tbg, 11GLM's, and FM SSSV. ND BOPE. NU Xmas tree & test to 5,000 psi. RELEASED RIG @ 0400 hrs, 4/8/87, to skid rig to D-6RD WO. NEF/em/35A/Sundr2 RECE]V :D MAY 1 ,Alaska Oil & Gas Cons. Cc~:'~mi?,sion Anchor~ Attachment # 3 Well D-14RD Completion SchemaEic 41' Cameron 4-1/2" ASL x ASL Type "F" Hanger 288' Otis Series i0 Type "FM" TR Safety Valve 3-1/2" 9.2 N-80 Tbg. Ail Mandrels are Otis WB 1" sidepocket 2,657' - GLM #1 4,765' - GLM -~2 6,387' - GLM #3 7" Liner Top @ 6,735' 9-5/8", 40-43.5# @ 6,966' 7,550' - GLM #4 8,564' - GI~M #5 9,353' - G~{ #6 10,150' - GLM #7 10,797' - GLM #8 11,3484 - GLM #9 11,872' - GLM #10 12,435' - 12,777' ~ 12,780' - 12,828' - 12,830' - Baker 7" 29# "FB-I" pkr Seal Bore Extension (SBE) Otis Pos. "S-I"' Nipple 3-1/2" 9.2# EUE 8rd w/l/2 cut mule shoe Perfs (MD) B-1 12,942' - 12,952' B-2 13,000' 13,074' B-3 13,092' - 13,126' 13,155' - 13,165' 13,175' - 13,190' B-4 13,210' - 13,255' ~-t3,265~ - 13,303' PBTD @ 13,387' TD @ 13,579' NEF - 4/15/87 t ~ STATE OF ALASKA ALA~,,A OIL AND GAS CONSERVATION COIV~I~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operawtor UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg B-l, Cond. #3 Dolly Varden Platfort 671' FSL, 1,215' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading B~y Unit 7. Well number D-14RD Attop of productiveinterval 210' FNL, 911' F[~, Sec. Ateffective depth 538' FNL, 905' FWL, Sec. Attotaldepth 680' FNL, 876' FWL, Sec. 17-8N-13W-SM 17-8N-13W-SM 17-8N-13W-SM 8. Permit number 74-2 9. APl number 50-- 133-20164-01 10. Pool ' Hemlock 11. Present well condition summary Total depth: measured true vertical 13,600' 10,025' feet Plugs (measured) feet 13,387' - 13,600' CMT feet Effective depth: measured 13,387 ' true vertical 9,865 ' feet Junk (measured) feet None Casing Length Structural Conductor Surface 2,543' Intermediate Production 6,966 ' Liner 6,844' Perforation depth: measured true vertical Size Cemented Measured depth ~ueVerticaldepth 13 3/8" 2,400 sx 2,543' 2,410' 9 5/8" 3,400 sx 6,966' 5,796' 7" 1,100 sx 13,579' 10,022' See Attachment #1 RECEIVED ~bing(size, grade and measured depth) 3 1/2" 9.2#, N-80 tubing @ 12,830' Packers and SSSV ~ype and measured depth) Baker 7" 29# "FB-i" Packer @ 12,777' MAY 1 i ]987 Naska 0ii & Gas Cons. Commission Anchorage 12.Attachment~:#2 & 3 Description summary of proposal [] Detailed operations program [] BOP sketch ~ Attachment #4 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Lonnie C. Smith Name of approver Date approved 5/7/87 15. I he. reby certify that the foregoing is true and correct to the best of my knowledge Signed ? _ . Title Environment81 Engineer '~y u. ~ooer~s Commission Use Only Date 5/7/87 Conditions of approval [] Plug integrity [] BOP Test ho~n Mechanical Inlegrity Test * Marat Oil Company - Sub Operator Approved by [J¥ Lfi~J[ J~. SJJJJJ Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Location clearance 7 Commissioner JApproval No. 7 -- ~ ~ ~ by order of the commission Date~,~-'" Submit in triplicate B-i B-2 B-3 B-3 B-3 B-4 B-4 ATTACHMENT 1 Dolly Varden Well D-14RD Perforations 12,942' - 12,952' MD 13,000' - 13,074' MD 13,092' - 13,126' MD 13,155' - 13,165' MD 13,175' - 13,190' MD 13,210' - 13,255' MD 13,265' - 13,303' MD 9,546' - 9,556' TVD 9,589' - 9,644' TVD 9,658' - 9,684' TVD 9,705' - 9,715' TVD 9,720' - 9,732' TVD 9,746' - 9,780' TVD 9,788' - 9,816' TVD NEF/em/35/Sundr2 RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage Attachment #2 Application for Sundry Approval Well D-14RD Workover Procedure It is Marathon's intention to convert Hemlock producer D-14RD to injection. The production tubing string will be pulled and an injection string run. Procedure: 1. Skid Rig #76 over Well D-14RD. 2. Fill tubing and casing with FIW. Perforate circulation holes in tubing @12,600'. Kill well by circulating FIW. 3. Set BPV. ND X-mas tree. NU and test BOPE. 4. POH and LD tubing. 5. Run completion assembly on premium thread internally coated tubing. 6. ND BOPE. NU and test new waterflood X-mas tree. 7. Perform casing integrity test to be witnessed by an AOGCC represen- tative. 8. Commence water injection. Run injection profile after rate stabi- lizes. Note: BHP is 3,750 psi @ 9,450' TVD. Workover fluid will be seawater and/or KC1 brine weighted to keep the well overbalance. Sized salt kill pills will be used as necessary to prevent excessive fluid loss. NEF/em/35/Sundr2 RECEIVED ATTACHMENT ¥/3 Well D-I4R~ Current Completion 8che~cic 4L' Cameron 4-1/2" A~L x ASL Type "F" Hanger 288' Otis Sertu 10 Type "F~" TR Safety Valve 3-1/2" 9.2 N-80 All Mandrels are O~is WB 1" sidepocket 2,6~7' - GI.M 4,765' - GLM '#2 6,387' - GLO! 43 . Liner Top ,~ 6,735' 9-5/8", 40-43.52 @ 6,966' 7,550' - GI.M #4 8,564' 9,353' - G~ ~6 10,150' - ~! #7 10,797' - GI.M #8 11,348~ - GI~H ~9 11,872' - GL~ #10 12,435' - GLM '#11 12,777' ~ ~aker 7" 29~ "F~-I" pkr 12,780' - Seal Bore Excensio~ (SBE) 12,828' -Octe Pos. "S-l" Nipple 12,830' - 3-1/2" 9.2~ EUE 8rd w/1/2 cut mule shoe Perle (M~D) B-I 12,942' - 12,952' B-2 13,000' - 13,074' B-3 13,092' - 13,126' 13,155' - 13,165' 13,i75' - 13,190' B-4 13,210' - 13,255' ..13,265; - 13,303' Well D-i4RD Proposed Completion Schematic 41' Cameron 4-1/Z" ASL x ASL Type "F" Hanger 288' Otis Series 10 Type "F~" TR Safety Valve 3-1/2" 9.2 N-80 Tbs. Liaer Top ,~ 6,735' 9-5/8", 40-43.5# @ 6,966' RECEIVED Alaska Oil & Gas Cons, CommJssio,~ Anchorage 12,777' ~ Baker 7" 29g "FB-I" pkr 12,780' - Sea/ Bore Extension (SBE) 12,828' ~ OctaVos. "S-l" Nipple 12,830' ~ 3-1/2" 9.2~ EUE 8rd v/172 cuc mule shoe Perle (~D) B-I 12,942' - 12,952' B-2 13,000' - 13,074' B-3 13,092' - 13,126' 13,155' - 13,165' 13,175' - 13,190' B-4 13,210' - 13,255' 13,265; - 13,303' PBTD @ 13,387' PBTD @ 13,387' TD @ 13.579' NEF - 4/15/87 TD @ 13,579' NEF - 4715787 - MARATHON Oil_ GO.- ATTAC[K4ENT .:i:4 Veil D-14RD .Mucl Pan Mippl~ -- DOLLY VARDE:'q PLAT FORN -- 0 O 0 0 13 ~/~".~ 5,ooo~ . .C. lc~mp Bolt C,omp l Conneorors j " %,-- 2_ Ff. Spool __ 1-"/ !'-! - ~-L'_,_ -.. 0 "0'' 0 ~ 12" ~ 5,:'000~ Casin9 Nead w/FJon~6d Outlets 'Me..il Room Floor----% Collar IB Ys* Surface C, asin~q ~ 3~' C'onduc?,or STATE OF ALASKA ALASi~,COIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [~ Amend order [] Perforate [] Other [] 5. Datum elevation (DF or KB) 2. Name of Opera~or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. LocationofwellatsurfaceLeg B-l, Cond. #3 Dolly Varden Platfor~ 671' FSL, 1,215' FWL, Sec. 6-8N-13W-SM Attop of productiveinterval 210' FNL, 911' FWL, Sec. 17-8N-13W-SM Ateffective depth 538' FNL, 905' FWL, Sec. 17-8N-13W-SM Attotaldepth 680' FNL, 876' FWL, Sec. 17-8N-13W-SM 106' KB above MSL 6. Unit or Property name 7. Well number D-14RD 8. Permit number 74-2 9. APl number 50-- 133-20164-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 13,600' feet Plugs (measured) 10,025' feet 13,387' - 13,600' CMT Effective depth: measured 13,387 ' feet Junk (measured) true vertical 9,865 ' feet Casing Length Size Cemented Structural Conductor Surface 2,543' 13 3/8" Intermediate Production 6,966' 9 5/8" Liner 6,844 ' 7" 1,100 sx Perforation depth: measured true vertical None Measured depth 2,543' 6,966' 13,579' See Attachment #1 WueVerticaldepth 2,410' 5,796' 10,022' ~bing(size, grade and measured depth) 4 1/2", 12.6#, N-80 @ 6,511', 3 1/2" 9 2# N-80 @. 6,511' Packers and SSSV(type and measured depth) ° ' Otis WD Perm. Pkr. @ 12,747', 4 1/2" WRL - DKX BV @ 290' · 12.Attachment~ 2 & 3 Description summary of proposal [] Detailed operations program [] BOP sketch [] Attachment #4 13. Estimated date for commencing operation March 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,,~ertif~ tl]~ ~he f_QLegoing Signed R~¥(/D. Ro~Derts is true and correct to the best of my knowledge Tit le En'¢iro~tal ENgiDeer Commission Use Only Date 3/10/87 Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. .,.,// / [] Plug integrity [] BOP Test [] Location clearance '"~ ~ Approved Co!~y ~; .~~; *Marathon Oil Company- Sub-Operator ,et.rrred _ ~ ; ,,,~=.-_.,.~~J~7 .... "by order of ~, / Sl i~tt~t ~' ~J~' ~ Commissioner the commission Date ¢-/¢ --~71 ....... Submit in triplicate B-1 B-2 B-2 B-3 B-3 B-3 B-3 B-4 B-4 B-4 ATTACHMENT 1 Dolly Varden Well D-14RD Perforations 12,942' - 12,952' MD 13,004' - 13,034' MD 13,044' - 13,074' MD 13,092' - 13,102' MD 13,114' - 13,126' MD 13,155' - 13,165' MD 13,175' - 13,190' MD 13,218' - 13,238' MD 13,248' - 13,258' MD 13,270' - 13,303' MD 9,533' - 9,540' TVD 9,579' - 9,602' TVD 9,609' - 9,632' TVD 9,645' - 9,652' TVD 9,661' - 9,670' TVD 9,692' - 9,699' TVD 9,707' - 9,718' TVD 9,740' - 9,755' TVD 9,762' - 9,770' TVD 9,779' - 9,803' TVD MDC/em/35/Sundry ATTACHMENT #2 Application for Sundry Approval Well D-14RD Workover Procedure le Me e 5, e Ye 8, 9, Activate Rig 76 over D-14RD. Kill well and NU BOPE. Pull top 296' tubing. Fish tubing at 300'. POH and lay down tubing. Fish permanent packer at 12,747' and clean out to PBTD at 13,387'. Perforate Hemlock Benches 1 through 4. Run packer and completion assembly (gas lift system). Rig down and place well on production. Run production logs and pressure surveys as needed. NOTE: BHP is 3,750 psi @ 9,450' TVD. Workover fluid will be seawater and/or KCI brine weighted to keep the well overbalance. Sized salt pills will be used as necessary to prevent excessive fluid loss. WLBleml91BAR ATTACHMENT #3 Well D-14R~ (Current) ... ... Cameron ~-1/2" ASL x ASL Type F Hanger · ~-----290' 4-1/2" WRL - DKX BV ~ ~ 296" Probable parted Tbg ( .. 2,543' 13-3/8" 4-1/2" 12.6# N-80 ASL Tbg 6,511' 4-1/2" x 3-1/2" x-over 6,735' 7" liner top 6,966' 9-5/8" 40-43.50 3-1/2" 9.2# N-80 ASL Tbg 12,747' DIL Otis WI) perm. pkr. 12,824' Mule' shoe Perforations (DIL) · 12,942" - 12,952"B~nch 1 13,004' - 13,034' 13,044' - 13,074' Bench 2 ' 13,092' - 13,102' 13,114' - 13,126' Bench 3 13,155' - 13,165' 13,175' - 13,190' 13,218' - 13,238' 13,248' - 13,258' 13,270' - 13,303' Bench 4 13~288 Fill (10/8/81) 13,387' PBTD 13,579' 7" 29g x-line liner (PropoSed) Cameron 4-1/2" ASL x ASL Type F hanger -+ 300' 3-1/2" TRBV 2,543' 13-3/8" 6,735' 7" liner Top 6,966' 9-5/8", 40-43.5# 3-1/2" 9.2# N-80 Tbg ¢ ~12,800' ~" perm. pkr. -+12,860' Tbg Tail Perforations (DIL) · 12,942' - 12,952' Bench I 13-,004' - 13,034' · 13,044' - 13,074' Bench 2 13,092' - 13,102' 13,114' - 13,126' Bench 3 13,155' - 13,165' 13,175' - 13,190' 13,218' - 13,238' -13,248' - 13,258' Bench 4 '~3,270' - 13,303' 13,387' PBTD 13,579' 7'" 29# x-line liner ATTACHMENT #4 ~ Well D-14RD MARATHON OIL GO.- Pon _ i D~illin~ Hippie. -- DOLLY VARD£N! PLATFORM -- U. (Nydril) ,,' ~ I I ~Bi~'~d ~a~S) ~ / __ . ~ -B,000 -Kill Lin~ , Dr~il Deck'Fioor ~ o ' - Oi~m ' Riser ~BOP ~f~ck For , t0 ~ , oj ~'~.~'=,=,,~ ~', ....... -- Drilling' Fro~ Uhd~ .' ' _ n I ! nt Alssk~ 0:~ & (~':-;~;- Lt;:,'-; ;? ;:":::'~-':' O 0 O ,! I Well Room w/Fign~ed Outlets E \/alvcs Collar' lB s/B" Surface C,c~sin8 33' C, onduc±or Union Oil and Gas fision: Western Region Union Oil Company of California P.O. Box 6247. Anchorage. Alaska 99502 Telephone: (907) 276-7600 unl, n November 3, 1984 Mr, Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SU, NDRY NOTICe'S ~ D-3RD2 & D-i4RD Attached for your approval is a Sundry Notice to workover D-3RD2, McArthur River Field & Subsequent Report for D-14RD for your information and file. Piease return the approved Sundry Notice to the undersigned. Very truly yours, Lawrence O. Cutting - ENVIRONMENTAL TECHNICIAN LOC/tj Attachment RECEIVED DEC Osl. Alaska Oil & Gas Cons. Commission Anchorage STATE Of ALASKA ALASKA ~TrL AND GAS CONSERVATION COOl'MIssION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Union Oil Company of California* 74-2 3. Address 8. APl Number P,0. Box 6247 Anchorage, AK 99502 50- 733-20164-01 OTHER [] 4. Location of Well Surface' Leg B-l, Cond. #3, Dolly Varden Platform 671' FSL, 1215' FWL, Sec. 6-SN-IOW-SM 5. Elevationin feet (indicate KB, DF, etc.) 106 ' KB above MSL I 6 . Lease Designation and Serial No. ADL-17594 9. Unit or Lease Name Tradinq Bay Unit 10. Well Number D-14RD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 6, 1984, an attempt was made to reperforate the well as approved in the Sundr.y Intent of May 14, 1984. The well was not reperforated because of an obstruction at 8,522' MD, approximately 4,430' above the intended reperforation interval. RECEIVED Alaska Oil & Gas Cur't~ Cr:~ni,,nissto~-~, l~nchoraa,~ *Marathon Oil Company - Suh (lnPrator 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~--~ ~ ~~'~_ '" Title Environmental Techni clan The space below for Commission use 12-04'84 Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Dale Submit. "Intentions" in Triplicate Form 10-403 Rev. 7-1 q]0 and "Subsequ'ent Reports" in Duplicate STATE OF ALASKA , ALA~.A OIL AND GAS CONSERVATIOI~COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL,~g~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 74-2 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 99502 50-733-20164-01 Leg B-I, Cond. #3, 671'FSL, 1215'FWL, 4. Location of Well Surface: Dolly Varden Platform Sec. 6-T8N-R13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL I 6 . Lease Designation and Serial No. ADL-17594 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-14RD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It 4 HPF, 0° phasing, is Marathon's intention to reperforate the well with 2-1/8" guns, under drawdown. Bench 1 Bench 3 12,942'-12,952' DIL 13,092'-13,102' DIL 13,115'-13,125' DIL 13,155'-13,165'~ DIL 13,175'-13,190' DIL If the production rate has not and Bench 4 will be perforated RECEIVED Alaska 0il & Gas Cons. Commissibn Anchorage increased significantly then Bench 2 as above. Bench 2 !3,000'-13,030' DIL 13,050'-13,075' DIL Bench 4 13,208'-13,238' DIL The March, 181 BOPD, 1984,' production tes 351 BWPD. [ *Marathon Oil Company -- Sub-Operator ; - ~below for Commission use ' litions of Approval, if any: t'averages were: 532 BFPD, 66% WC, Subsequent Work F,c{~ortcd o. Date IF/ LOltl~lE C. $Iti!11t ~,,, Order Of Approved by., COMMISSIONER the Commission Apprdved Cop), · ~eturn. ect . Form 10-403 Rev. ?-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate DATE March Sl~ 1975 M ATHI3 IL 13 Y · HISTORY OF OIL OR GAS WELL BLOCK WELL NO. D-14(RD)LEASE Trading Bay Unit SEC. (11-17) PARISH STATE Alaska COUNTY Kenai Peninsula Borough FIELD McArthur River K.B. ELEV. 106.9' i ToP OF OIL STRING ~ ELEV.. MEASUREMENTS TOP OF ROTARY TABLE~ ELEV. TAKEN FROM [GRD. OR MAT. ELEV. ~ 7 TWP. RN HISTORY PREPARED BY Ken Thoma ~ TfTL£ Drilling Engineer Ail Measurements from KB 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 (1974) 9/12 9/13 9/14 9/15 9/16 9/17 9/18 9/19 9/20 SUPPLEMENTAL HISTORY OF WELL D-14 REDRILL AFE #4363 Report as of 7:00 AM for previous 24 hrs activity. TD 12,700', PBTD 12,618' - Rig released from Well D-24 to move to D-14 at 12:01 AM, 9/12/74. Rigged up lubricator, tested - OK. Rigged up Otis and pulled ball valve from 298'. RIH with Otis shifting tool and attempted to open circulating sleeve ~' at 11,691'. TD 12,700', PBTD 12,618' - Made four runs, but couldn't open circulating sleeve at 11,691'. Rigged Go-International wireline unit and RIH with gun to perf tubing. Attempted to perf at 11,650' - gun didn't fi~e. Rewired gun and shot gun at 11,650'. POH and gun fired OK. Pressured tubing to 2000 psi - couldn't break circulation. RIH with second gun and perfed tubing at 11,550~. Pumped 33 BBLS of filtered Inlet water, but tubing pressured to 2000 psi - wouldn't circulate. RIH with gun and perfed at 11,360'. TD 12,700', PBTD 12,618' - Filled annulus with Inlet water, then displaced hole with 710 BBLS of mud down tubing through holes at 11,360'. Started off-loading pipe racks, mud tanks, etc. in preparation to skid rig. TD 12,700', PBTD 12,618' - Finished off-loading equipment and jacked Rig 76 from Leg A-1 to Leg B-1 over Well D-14. TD 12,700', PBTD 12,618' - Began installing pipe racks and mud tanks on platform. Unable to load all equipment from boat to platform due to high winds. Installed back pressure valve in tubing and removed x-mas tree. Began flanging up BOPE. TD 12,700', PBTO 12,618' - Finished flanging up BOPE and tested to 3,000 psi - OK. Continued loading equipment from boat to platform. Finished installing pipe racks. Pulled BP valve and unseated tubing hanger. Pulled hydraulic packer loose with 190,000# - tubing weight was 170,000#. Began pulling and laying down 4-I/2" OD, tubing. TD 12,700', PBTD 12,618' - Finished unloading supply boat - spent 5 hrs repairing crane. Installed wind walls and guard rails. Finished pulling 4-1/2" - 3-1/2" tubing and packer. No holes at 11,650' where GO had perforated to circurl, ate, but had holes at 11,550' and 11,360'. Tubing in good condition. Picking up and RIH with 3-1/2" DP and began picking up 5" DP. TD 12,700' PBTD 11 746' - Finished in hole with 3-1/2" - 5" DP to 12,230' , , · Rigged BJ and spotted 125 sacks .froM_.~g_~.~._2_30' 3_p_to 11,746' through .open-ended DP. Pulled up and reverSed 'out a trace 0~-'~me~{~]%~,~6'. Began POH. TD 12,700' PBTD 11,740' - Pulled 6 stands, closed pipe rams, and held 2000 psi on cement plug for 6-1/2 hrs. RIH to 11,740' and tagged cement plug. POH. Rigged up Dresser-Atlas and ran Cement Bond Log from 6500' up~ to 5000'. RIH with 8-1/2" bit to 6300' to circulate and condition mud. POH. (SEE ATTACHED SHEETS) KE E VED OCT 21 1982 Al~ska 0~! & Sas Co,~$ ,~, . H"/story of Oil Well D-14 Continued 9/21 9/22 9/23 9/24 9/25 9/26 9/27 9/28 9/29 9/30 l'O/1 10/2 10/3 10/4 10/5 TD 12,700', PBTD 7,121' - Finished out with 8-1/2" bit. Reran CBL from 7500' to 6500' because of poor bonding and coal sections throughout interval 6500' to 5000'. Ran gauge ring and junk basket on D-A wireline to 7200'. Using D-A unit, set cast-iron bridge plug at 7130' (WL measurement). Tested casing to 2500 psi - OK. RIH with 9-5/8" sectiOn mill and tagged BP at 7121' (DP measure- ment). Pulled up to 7076' and changed over to higher viscosity mud. ~ TD 12,700', PBTD 7,121'- Finished building mud weight and Viscosity. ~Began milling window~t.~.~b~'. Milled to 6996'. Circulated and worked section mill through top of window at 6966' and pulled out of hole. RIH with 8-1/2" bit to 6996' and circulated and conditioned mud. POH. TD 12,700', PBTD 7,121' - RIH with section mill #2 - reamed and washed from 6966' to 6996'. Return line plugged with cuttings. Unplugged flowline and milled from 6996' to 7028'. Circulate bottoms.up. Repaired electrical panel on rig (1 hr) and POH. Started in hole with section mill #3. RD 12,700' PBTD 7 121' - Finished in hole with section mill #3 - reamed from 7018' to 7028'. Milled 9-5/8" casing from 7028' to 7046' (total window from 6966' to 7046' - 80 ft.). Circulate and condition mud and POH. RIH to 7046' -~{~"~Pen -ended DP and circulate for half hour. Spotted 120 sacks of Class "G" cement with 1% D-31, 0.4% R-5, 10% sand - 16#/gal slurry. Pulled up to 6746' and reversed out 14 BBLS of cement contaminated mud. Pulled to 6463', closed pipe rams and pressured to 2000 pSi on plug. Bled off to 1550 psi and held. WOC. TD 12,700', PBTD 7,121' - WOC for 24 hours holding pressure on cement plug. Repaired oil seal on rig clutch (3-1/4 hrs) and POH. TD 12,700', PBTD 6,984' - Finished out of hole laying down Grade "G" DP. RIH with 8-1/2" bit and found top of hard cement at 6780'. Drilled out hard cement to 6984', circulated and conditioned mud. POH. RIH with Dyna-Drill and 8-1/2" diamond sidtracking bit - installed DP rubbers. TD 7,058' - Set Dyna-Drill on plug at 6984' Drilled from 6984' to 7026' · , surveyed, and drilled to 7058'. POH to change BHA. TD 7,280' - Finished out of hole. Slipped drilling line. RIH with drilling assembly. Repaired generators (4 hrs). Reamed from 6984' to 7058', drilled from 7058' to 7177' and ran survey. Worked on generators Drilled to 7280' , · · Running survey. TD 7,530' - Finished surveying. Drilled from 7280' to 7414' and POH. Changed BHA, RIH and drilled from 7414' to 7530'. TD 7,651' - Drilled from 7530' to 7549', surveyed, and POH. Changed BHA. Re- paired mud line (3/4 hr) and drilled to 7651', Running survey. TD 8,038' - While in hole with survey tool, spliced sand line. Pulled survey and drilled to 7834'. Ran survey and drilled to 8038'. POH. TD 8,180' - Finished out of hole and changed BHA (added a second roller reamer above bit). RIH to 6966' and repaired mud pumps (1 hr). Finished in hole to 8038' and drilled to 8153'. Took survey and drilled ahead to 8180'. TD 8,475' - Drilled to 8276'. Circulated and sUrveyed then made an 8-stand short trip. Ran to bottom and drilled to 8475'. Surveyed and POH - measured out - no correction. Changed BHA (moved lead collar between roller reamers). RD 8,580'- Tested BOPE to MRO specs - OK. RIH to 5700', cut off 1800' of sand-line & spliced same. RIH to 8475' & drilled ahead to 8580'. TD 8,811' - Drilled to 8589'. Ran survey. Drilled to 8702' & made short trip. Drilled to 8811', dropped survey instrument, & POH. OCT 2 1 1982 Alaska 0il & History of Oil Well D-14 Continued 10/6 TD 8,980! - Finished out of hole & changed BHA. RIH to 9-5/8" casing shoe at 6966', cut, & slipped drilling line. RIH to 8811' & drilled to 8819'. Ran repeat survey to check survey taken at 88117. Drilled to 8913' & surveyed. POH to 6000' & repaired drawworks motor (2-3/4 hrs). POH & changed BHA. RIH to 8913' & drilled to 8980'. 10/7 TD 9,237' - Drilled from 8980' to 80867 & surveyed. Drilled from 8986' to 9061' & surveyed. POH & changed BHA. RIH & reamed 30' to bottom at 9061'. Drilled ahead to 9137' & surveyed. Drilled to 9237~. 10/8 TD 9,363' - Drilled to 9242', POH, & changed BHA. R IH and drilled to 9300'. Lost 700 psi pump pressure. POH .and found jets washed out of bit. RIH and drilled to 9325', circulated, and surveyed. Drilling ahead. 10/9 TD 9,503' - Drilled to 9419' and surveyed. Drilled to 9450'. POH to change BHA (moved stabilizer from above monels to between monels). Slipped drilling line 45'. RIH and drilling at 9503'. lO/lO TD 9,726' - Drilled to 9511' and surveyed. Drilled to 9575' and surveyed. Drilled to 9635' and surveyed. Drilled to 9697' and surveyed. POH to change BHA (added 10' lead collar between roller reamers above bit trying to get hole to turn south). RIH and drilling at 9726'. lO/ll TD 9985' - Drilled ahead 9957' with surveys at 9769', 9832' and 9926'. Repaired mud pump (3 hrs). Drilling ahead at. 9985'. 10/12 TD 10,331' - Drilled to 10,331' with surveys at 10,O50' and 10,207'. lo/13 TD 10,362' - Drilled to 10,362'. Circulated bottoms up & POH. Repaired brakes. Layed down drilling assembly. Tested BOPE - 3000 psi - OK. RIH w/Dyna-drill to 10,362'. Oriented Dyna-drill & attempting to drill. TD 10,409' - Unable to drill with Dyna-drill. POH. Changed BHA. RIH with Dyna-drill and bit. Oriented Dyna-drill. Drilled from 10,362' to 10,394'. Ran survey. Drilled to 10,409'. POH. TD 10,522' - Finished POH & changed BHA. RIH & reamed from 10,362' to 10,409'. Drilled to 10,486'. Ran survey. POH for BHA change. RIH & drilled to 10,522', lO/16 TD 10,556' - Drilled to 10,556'. Circulated & surveyed. Ran check survey - sand line parted. POH to 6,000'. Spliced sand line. Pulled survey. POH & changed BHA. RIH to lO,O00'. Ran sand line to splice @ lO,O00'. lO/18 TD 10,572' - Ran Eastman multishot survey. Retrieved survey. Survey tool failed. Circulated & conditioned hole. Dropped multishot survey. Retrieved survey - OK. POH to change BHA. RIH & reamed 90' & drilled to 10,572'. TD 10,598' - Drilled to 10,598'. Circ & Surveyed. POH. Rih Wdiamond bit &Dyna-drill. Oriented tool. 10/19 TD 10,685' - Unable to drill w/diamond bit & Dyna-drill. POH. Changed BHA. RIH. Drilled to 10,677' & surveyed. Drilled to 10,685'. 10/20 TD 10,793' - Drilled to 10,740'. Circ & surveyed. Had electrical problem on rig console. POH. Changed BHA. RIH to 7000'. Slipped & cut drilling line. RIH & drilled to 10,793'. 10/21 zo/ 3 TD 10,867' - Drilled to 10,804'. Circ & surveyed. Drilled to 10,867'. Circ & surveyed. POH. Lost cone off bit. Tested BOPE to 3000 psi - OK. Changed BHA. RIH. Started reaming @ 10,527'. TD 10,913' - Drilled 8-1/2" hole to 10,913'. Surveyed & POH. PU& RIH with Dyna-drill. Attempted to orient tool, sandline parted 50' above survey tool. POH w/wet string - repaired sandline. RIH w/Dyna-dri il. Slipped & cut drilling line. Circ. @ 10,913'. before orientling Dyna-drill. 10/22 TD 10,906' - Reamed from 10,527' to 10,867'. Drilling on junk to 10,869'. POH & PU 8" junk basket. RIH & cored l' of hole to 10,870'. POH & no recovery of junk basket. RIH w/8-1/2" bit. Worked around junk & drilling. Histoz7 of Oil Well D-14(RD) Continued 10/24 TD 10,986' - Oriented Dyna-drill @ 10,913' & drilled to 10,937' and ran check survey. Drilled to 10,969' & POH. Changed BHA. RIH & reamed from 10,913' to 10,949'. Drilled to 10,986'. o/25 TD 11,103' - Ran survey @ 10,986'. Drilled to 11,017' and surveyed. POH for BHA change. RIH and reamed from 10,857' to ll,O17'. Drilled to ll, 103' and ran survey. POH. lO/26 TD ll,170' - Finished out of hole and changed BHA. RIH with Dyna-drill. Oriented tool @ ll,103'. Drilled to ll,120' and ran check shot. Drilled to ll,151' and ran heck shot. Drilled to ll,l?O' and POH for BHA change. Cut and slipped drilling line. RIH. .o/27 TD 11,250' - RIH with bit and reamed Dyna-drill run from ll,103' to ll,170'. Drilled to ll,210' and surveyed. Drilled to 11,241' and surveyed. POH for Dyna-drill. RIH with Dyna-drill, oriented @ 11,241' and drilled to 11,250'. Lost torque at surface on Kelly while working Dyna-drill. Started orienting tool again. Hole in good condition. lO/28 lO/29 TD 11,264' - Finished orienting tool @ 11,250'. Drilled to 11,264'. Oriented Dyna-drill and sand line parted. POH. Replaced sand line and changed brake blocks. RIH with drilling assembly. · TD 11,431' - RIH with BHA and reamed from 11,188' to 11,264'. Drilled and surveyed @ 11,304' 11,335' 11,366' and ll 431' lO/3O TD 11,434'- Surveyed @ 11,431'. POH to change BHA. RIH. Reamed hole' from ll,091' to 11,431'. Circulated and attempted to pick up junk (bearings). Dripped survey & POH. No recovery in junk sub. Changed BHA. RIH. 10/31 TD 11,589' - Drilled to 11,461' and surveyed. Drilled to 11,525' and surveyed. Drilled to 11,589' and surveyed. POH - measured out. Tested BOPE. Started in hole with Dyna-drill. ll/1 TD 11,623' - RIH with Dyna-drill to 6900'. Slipped and cut drilling line. RU Dresser-Atlas rotating head. RIH to 11,589'. RU Dresser-Atlas and RIH w/steering tool. Oriented Dyna-drill and drilled 34'. Pulled steering tool. POH. Changed BHA. RIH to 6900'. RU Kelly. RIH and started reaming @ 11,490'. 11/2 TD 11,759' - Reamed to 11,533' and hung up @ 11,597' - jarred loose. Reamed to 11,623'. Drilled to 11,631' - repaired mud pumps, drilled to 11,653' and surveyed. Drilled to 11,684' and surveyed. Drilled to 11,745' and' surveyed. 11/3 TD 11,844' - Drilled to 11,779', surveyed & POH. Changed BHA. RIH to 6900'. Repaired wear plate on blocks. RIH and drilled to 11,844'. Surveyed. POH. 11/4 TD 11,896' - Finished out of hole. Changed BHA. RIH with Dyna-drill#8 to 6900'. RU rotating head. Slipped drilling line. RIH to 11,844'. RU and ran steering tool. Dyna-drilled to 11,896'. Pulled steering tool. POH. Changed BHA. RIH. ll/5 TD 12,091' - RIH to 11,845'. Reamed to 11,896'. Drilled to 11,933' and surveyed. Drilled to 11,998' and surveyed. Drilled to 12,059' and sur- veyed. Drilled to 12,091' and surveyed. 11/6 TD 12,202' '~'i'Finished survey. POH to change BHA. RIH. Drilled to 12,192' and ran survey. Drilled to 12,202'. ll/? TD 12,294' - Drilled to 12,289' and surveyed. Drilled to 12,294'. POH. RIH with Dyna-drill. RU and ran steering tool. 11/8 TD 12,394' - Drilled from 12,294' to 12324' with Dyna-drill. POH w/steer- ing tool. RD Dresser-Atlas. POH for BHA change. RIH. Reamed hole from 12,294' to 12,324'. Drilled to 12,376' & surveyed. Drilled to 12,394'. History of Oil Well D-14(RD1 Continued ll/9 TD 12,567' - Drilled to 12,439' and surveyed. Drilled to 12,4~8'. POH for BHA change. Cut and slipped drilling line. RIH to 12,294'. Reamed to 12,448'. Drilled to 12,544' and surveyed. Drilled to 12,567'. 11/10 TD 12,705' - Drilled to 12,697' and surveyed. Tripped for new bit and BHA change. Reamed from 12,657' to 12,697'. Drilled to 12,705'. 11/11 TD 12,925' - Drilled to 12,780' and surveyed. Drilled to 12,860'. Repaired mud pumps. Drilled to 12,925'. 11/12 TD 13,014' - Drilled to 12,937' and surveyed. Drilled to 13,014' and surveyed. POH - leaving one cone in hole. RIH. n/13 TD 13,050' - Finished in hole - drilled on junk to 13,050'. POH and changed BHA. Laid down washed out monel DC & stab. RIH to 6900'. Repaired clutch. (Junk basket empty - no recovery of cone.) 11/14 TD 13,127' - Repaired clutch. RIH to 13,027'. Reamed to 13,050'. Drilled to 13,127'. 11/15 TD 13,220' - Drilled to t3,172' & surveyed. .Drilled to 13,220' & POH. 11/16 TD 13,428' - Finished in hole. Drilled to 13,428'. 11/17 TD 13,600' - Drilled to 13,452'. Dropped survey. POH. Measured out. Changed bit. RIH to 6900'. Cut and slipped drilling line.~ RIH to'13,384'. Reamed to 13,452'. Drilled to 13,600' TD. POH for short trip. ll/18 TD 13,600' - Completed short trip. Circulated and conditioned mud. POH. RU Schlumberger and started logging. Finished DIL. WL TD - 13,583'. 11/19 TD 13,600' - Finished logging. Rigged down Schlumberger. RIH to 6900' filled pipe, cut and slipped drlg line. Thawed mud line. RIH and reamed btm 60'. Circulated and conditioned mud. POH. 11/2o TD 13,600' - POH. RU to run csg. Ran 175 jts 7", 29#, N-80, X-line csg, BOT shoe, float collar, hanger, and packer. Pipe stopped @ 13,579'--21'off btm. Top ~ i. 6735' (231' of lap). Tested csg in hole w/Gater Hawk to 4000#--no leaks. Started circulating hole prior to cementing. 11/21 TD 13,600' - Finished circulating hole clean. Dropped ball and set BOT hanger. Cemented csg with 800 sacks Class "G" cement, 4% gel, 1% D-31, and .3% R-5 followed with 300 sacks Class "G", 0.4% R-5, 1% D-31 pre- flushed with 50 sacks Class "G" ll#/gallon flush. Displaced DP and liner with 372 BBLS of mud. Cement job complete at 11 AM, 11/20/74. Set BOT packer. POH. Layed down 105 joints 5" DP, 27 joints HW, jars, 6 drill collars, stabilizers and reamers. WOC. ii/22 11/23 TD 13,600' - WOC. RIH to top of liner @ 6735' with bit--no cement. WOC total of 30 hrs. Reversed out 50 BBLS contaminated mud. Pressure tested liner lap to 2000 psi, OK. POH. RIH with Baker packer and set same at 6642'. Pressured liner lap to 4000 psi--held for 1 min. then broke and bled to 1200 psi. Pumped into lap at rate of 3/4 BPM at 2200 psi. Bled off pressure. Reset Baker packer at 6548'. TD 13,600"' Squeezed liner lap with 100 sacks Class "G" cement with 1% D-31 and 0.4% R-5. Pumped cement into formation at 3/4~BBL/min at 3200 psi. Final pressure 2200 psi at 1/4 BBL/min. Pressure bled to 1950 psi in 8 min. and held. Bled off pressure. Reversed out - no cement. Cement below lap, 16.5 BBLS, leaving 3.5 BBLS in 9-5/8" csg. Pulled 10 stands. Pressured Squeeze to 500 psi for 6 hrs. Bled pressure off and POH. WOC ahd PU 3-1/2" DP. 11/24 TD 13,600' - WOC & RIH. Drilled cement from 6627' to 6735' (top of liner). ~ Circulate and condition mud. POH. RIH with Baker packer and set @ 6485'. ,,.~ Tested liner lap to 3000 psi-bled off slowly. Pumped into lap @ rate of C<<~:~% 1-1/2 ~P~ @ 3800 psi. ~eset pkr @ 65~8 , Squeezed liner lap with 150 sacks ~ '~f~ Class G cement with 1% D-31 and 0.4% R-5. Pumped 28 BBLS cement behind ~ <~lap leaving 2 BBLS in 9-5/8" casing. Max. pressure 4400 psi @ 1 BPM. Final ~?~ squeeze pressure-3500 psi-held for 7 m~n.-no bleed off. Bled off pressure. "~ ~ Reversed out and recovered trace of cement. Job complete @ 9:30 PM, 11/23/74. '~,~ WOC-picking up 3-1/2" DP. Cleaning mud tanks. .,History of Oil Well D-14 (RD) Continued 11/25 TD I3,600' - Waiting on cement. RIH with 8-1/2~t bit and tagged cement @ 6564'. Drilled hard cement to top of liner @ 6735t. Circulated and con- ditioned mud. POH. RIH with Baker packer and set @ 6450t. Pressured lap to 4000 psi. Held pressure for 15 minutes. Bled pressure off. 11/26 TD 13,600' - POH. RIH with DST tools for liner lap test and set packer @ 6450'. Opened tool @ 3:35 PM for 10 min.--weak blow for 3 min.--then no blow. Closed tool for 20 min., open 1 hr.--no blow. Closed for 2 hrs.~ POH and had 80' total rise in drill pipe. Pressures recorded: IHP - 2795 psi, IFP - 35 psi, ISIP - 59 psi, FFP - 35 psi, FSIP - 94 psi,°and FHP - 2789 psi. RIH with 6" bit and tagged cement @ 6735' and drilled to 6765~. RIH to 13,534' and drilled to 13,536~. Circulated and conditioned mud'. 11/27 TD 13,600' - Circulated and conditioned mud.' Tested 9-5/8" and 7" casing to 2000 psi-30 min. O.K. POH. Rigged up wireline-unit and ran Cement Bond Log from 13,509' to 6600'. POH. Ran in hole with gyro to 9500' and logged to surface. Unable to get below 9500'. Now installing, additional sinker bars to run to PBTD. 11/28 TD 13,600' - Finished running gyro from surface to 13,509~ (Wireline measure- ment). Rigged down wireline unit. Rigged up and ran perforating gun and perforated for block squeeze from 13,425~ to 13,~4_~?, 2 shots:per foot with casing gun. POH and rigged down wireline unit. RIH with Halliburton cement retainer and set @ 13,387'. Broke circulation. Set back into retainer and broke down perfs @ 4800 psi. Pumped 1-1/2 BBLS mud into formation @ 1/2 BPM @ 4800 psi, pressure bled to 3700 psi and held. Pulled out of retainer. Mixed and spotted 100 sacks Class "G" cement with 1% D-31 and 0.4% 'R-5 (16# slurry). Set into retainer and unable to pump into formation @ 5000 psi. Pulled out of retainer and reversed out cement. Recovered all cement. 11/29 TD 13,600' - Finished out of hole. Rigged up wireline unit and perforated for block squeeze 13,317'-13,319' with casing gun 2 shots per foot. RIH with Halliburton cemented set @ 13,270'. Established break down @ 4500 psi. Pumped in ~ 2 BPM @ 3500 psi. Pulled out of retainer. Mixed 100 sacks cement with 10 BBLS water ahead. Cement Class "G" with 1% D-31 and 0.4% R-5 - 16# slurry. Five BBLS water behind. Set into retainer, started squeeze with 2300 psi @ 1/2 BPM. Pumped 8 BBLS and pressure increased to 5000 psi. Pulled out of retainer and unable to reverse out. POH and found 5" x 3-1/2" crossover plugged with cement scale. Had all cement in 3-1/2" drill pipe with small amount of water on bottom. Layed down 3-1/2" drill pipe. 11 / 30 TD 13,600' - Finished picking up 3-1/2" drill pipe. Circulated mud. Ran 25 stands 5" drill pipe. Hammering. out cement scale. Circulated and condi- tioned mud to remove cement scale. Pulled out of hole to 3-1/2 - 5" cross- over - sub full of cement scale. RIH. Layed down 51 joints, 5" drill pipe and RIH 25 stands 5" drill pipe. Hammering out cement scale. Circulated and conditioned mud. Pulled out of hole to crossover sub. Picked up 3-1/2" drill pipe. POH. Ran in hole with retainer stinger. 12/1 TD 13,600' - Finished in hole with cement retainer stinger. Set into retainer and pumped into perfs @ 2 BPM with 2800 psi. Pulled out of retainer. Mixed and spotted 100 sacks Class "G" cement with 1% D-31 and 0.4% R-5 (15.5# per gallon slurry). Set'into retainer and squeezed perfs @ 1-1/2 BPM @ 2500 psi, decreased to 1/2 BPM @ 3200 psi and held. Pulled out of retainer and reversed out 3 BBLS cement. Squeezed 75 sacks cement into perfs. POH. Rigged up and perf'd for block squeeze from 13,150'-13~2 shots.per foot. Ran in hole with Halliburton cement retainer and se~ @ 13,110'. Broke down perfs @ 5000 psi. Pumped into perfs @ 1 BPM @ 5000 psi - pressure bled to 4000 psi and held. Pulled out of retainer. Circulated and conditioned mud. 12/2 13,600' TD - Finished changingvalves on choke manifold. Set. into-retainer and pumped into perfs 1 BPM @ 5000 psi. Mixed and spotted 75 sacks Class "G" cement with 1% D-31 and 0.4% R-5. Set into retainer. Squeezed perfs with 10 BBLS cement to 4800 psi. Pulled out of retainer. Reversed out approximately 10 BBLS cement. Circulated and conditioned mud. POH. Rigged up and perforated-for block squeeze from 12,980'-12,982', 2 shots per foot. Ran in hole with Halliburton cement retainer. History of Oil Well D-14 .(,RD) Continued 12/3 TD 13,600' - Finished in hole with cement retainer & set @ 12,960'. Pulled out of retainer & broke circulation. Set into retainer & pumped into block perfs @ 2 BPM @ 3900 psi. Pulled out of retainer. Mixed & spotted 100 sacks Class "G" cement with 1% D-31 & 0.4% R-5. Squeezed perfs with 11 BBLS cement to 5000 psi. Reversed out 9 BBLS cement. Circulated hole clean. POH. Rigged up wireline unit & perf for block squeeze 12,920'-12,922', 2 shots per foot. RIH with Halliburton cement retainer & set @ 12,900'. Pulled out of retainer & broke circulation. Set into retainer & broke · down formation @ 4800 psi. Pumped into perfs @ 1-1/2 BPM @ 4800 psi. Mixed & spotted 75 sacks class "G" cement with 1% D-31 & 0.4% R~5. Squeezed perfs with 8 BBLS cement to 5000 psi. Reversed out 5 BBLS cement. Circulated & conditioned mud. 12/4 TD 13,600' - Finished circulating & conditioning mud. POH. RIH with bit & drill collars to top of retainer #1 @ 12,900'. Drilled retainer & hard cement & RIH to retainer #2 @ 12,960'. Drilled on retainer #2 for 1/2 hour. Tripped for new bit & additional drill collars & junk sub. Finished drilling retainer #2 & drilled hard cement to 12,984'. RIH to retainer #3 @ 13,124~. 12/5 TD 13,600' - Finished drilling retainer #3 @ 13,124' & hard cement to 13,154'. RIH to 13,276'. Circulated & conditioned mud. POH. RIH with RTTS DST tools & 6000' filtered Inlet water. Set packer @ 12,846'. Opened tool for initial flow for 10 min. - slight blow for 5 min. No blow for 5 min. Shut tool in for 20 m~n. Opened tool for final flow - 1 hour - no blow. Shut tool in for 2 hours. Reversed out water cushion. POH. 12/6 12/7 12/8 12/9 TD 13,600' - Finished out of hole with DST tools. Slipped & cut drilling line. RIH with 6" bit to 13,276'. Drilled retainer @ 13,276' & hard cement to 13,324'. RIH to 13,387', circulated & conditioned mud. POH. RIH with bit & 7" casing scraper to 13,387'. Circulated & conditioned mud. POH. DST results: IHP - 4916, IF - 1781, ISI - 2211, FF'- 1781, FSI - 3019 (slow buildup), FHP - 4869. TD 13,600' - Finished out of hole. RIH with RTTS DST tools with 5500' water cushion. Set packer @ 13,245' to dry test perfs @ 13,317' to 13,319'. Opened tool for 10 min. - light blow for 3 min. - no blow for 7 min. Closed tool for 20 min. Opened tool for 1 hour - no blow. Closed tool for 2 hours. Reversed out water cushion. POH. Rigged up Dresser-Atlas & ran Cement Bond Log. TD 13,600' - Finished running Cede/Bond Log. Rigged down wireline unit. RIH with bit & scraper to 13,387'~ Displaced hole with filtered Inlet water. Displaced water with diesel. Started out of hole with bit, laying down drill pipe. TD 13,600' - Finished out of hole laying down drill pipe. Rigged up & ran potential log from 6500' to surface. Started running Caliper Log. 12/10 12/11 TD 13,600' - Finished running Caliper Log. Ran 9-5/8" basket on wireline made 2 runs & recovered small amount of rubber & junk. Attempted to run 7" junk basket - unable to get into 7" liner. Rigged down wireline unit. Rigged up to run tubing. Started in hole with tubing, string. TD 13,600' - Continuing t'o run tubing string. 12/12 TD 13,600' -Finished in hole with tubing string. Installed tubing hanger & tested s'afety valve line to 5000 psi - OK. Landed tubing with packer @ 12,809'. Attempted to set packer - circulated diesel - unable to set packer. Rigged up D-A & RIH with circulating sleeve shifting tool & collar locator. Checked sleeve & closed same if in open position. PQH. Attempte .to set packer - circulated diesel. RIH with 2" sinker bars to packer seating nipple & ball in position. POH. Pumped down tubing & circulated diesel. Started out of hole with tubing string. 12/13 TD 13,600' - Finished in hole with tubing string. Found ball split and one half of ball in seating nipple of packer. Circ. valve - OK. Packer - OK. Started back in hole with tubing string. 2/14 TD 13,600' - Finished in hole with tubing string and set packer. Installed BPV in tbg hanger. Removed BOPE & installed x-mas tree. Tested tree to 5000 psi - OK. Unloaded well down to 2520' - top gas lift valve. Preparing perforate i~ i:~.! ~i ~ ~i ~ ~i:~ i? Alaska Oil & S.~.s Cons. History 12/15 of Oil Well D-14 (RD) Continued / TD 13,600' - RIH with 3-1/2" tubing gauge ring to 13,387' (PBTD). POH. RIH with 2-1/2" Dresser-Atlas jumbo jet bar gun & perforated Hemlock Bench ~3 from 13,150' to 13,160'. POH. Unloaded & ~ested. Well produced @ rate of 28 BPH, 3% water, after unloading to bottom valve. Rate de- clined & cut declined to 0.3% mud. Last 2 hrs - no prod. RU & ran pres- sure survey. Well shut in @ 12:30 A.M. 12/16 Finished buildup survey. POH. RU to perf. RIH and perforated Bench#4 from 13,286' to 13,299' with 2-1/2" jumbo jet - 2 shots/ft. Tested well for 6-1/2 hrs. Last 2 hrs rate of 1050 BPD & 0.5~ BS&W. CP - lllO psi., TP - 170 psi. RU to perf. and ran 20' gun. Gun stopped @ 8015'. POH. Gun bent on bottom. RIH with 10' gun and gun stopped. POH. RIH with 10' of sinker bars on 20' of gun & perf'd from 13,266' to 13,286'. POH. RIH with 10' gun and 10' of sinker bar. Gun stopped @ 11,253' (Circ. sleeve). POH. TD 13,600' - Laid down 10' gun. Placed well on production for 4 hrs - meter failed - no rate, 0.3% BS&W. RU lO"gunw/10' sinker bar on btm. Had problem getting by circ sleeve & pkr. Fired gun & POH - gun failed to fire. RU 20' gun& RIH. Perf'd Bench#4 from 13,214' to 13,234'. POH. Left 2' of carrier in hole A'5' of sinker & 2' of gauge bar. RU 10' gun & RIH. Hung gun@ 12,817'. Attempted to work gun loose - unable to free gun. Placed well on production & attempted to work gun free. Well on production 5 hrs - average rate of 130 BPH or 3120 BPD, 0.8%wtr, TP - 160 psi, CP - ll40 psi. Pulled gun free & POH. One jet broken off in carrier, but hanging on primer cord. Placed well back on production to clean up. 12/18 TD 13,600 - Flowed well @ 3049 BPD, 0.6% BS&~, CP - 1100 psi, TP - 140 psi., lift gas - 2870 MCF, formation gas 554..~MCF, GOR - 182, while running gradient survey. Shut well in @ 9 PM for 12-hr build-up. 12/19 TD 13,600' - Finished build-up survey & POH. Flowing BHP @ rate of 3312 BPD was 1435 psi. Shut-in BHP @ 12 hrs was 3328 psi. RU Wireline unit & RIH w/2-1/2" jumbo jet bar gun, 2 shots/ft & perforated Bench#4 from 13,244' to 13,254'. POH & placed well on test. Well produced @ rate of 3600 BPD w/0.7% BS&W, CP - ll40 psi., TP - 150 psi. Shut well in & RIH w/perforating gun. Gun stopped @ pkr. POH. RIH w/perf, gun & perforated Bench#3 from 13,110' to 13~122'. POH. Left 2" gauge guide, 5' sinker bar & 10' of the bar gun. Started in hole w/perf, gun. 12/20 TD 13,600' - Finished in hole w/perf gun & perforated Bench#3 from 13,170' to 13,185'. POH. Unloaded & cleaned well to test separator. RU & ran gradient survey w/well producing @ rate of 3720 BPD, 0.8% BS&W w/1596 MCF of lift gas. Well producing some sand; FBHP - 1770 psi (field reading). Rigged down wireline unit. Placed well on test. Well producing @ rate of 3984 BPD, 1.5% BS&W, TP - 140 psi, CP - 1140-1150 psi., lift gas - 1526 MCF, formation gas - 1410M CF, GOR - 354. Summary of Perforating Bench Depth (CBL) Depth ,(DIL) 3 13~150-13,16~ Y3,155-13,165 3 13,170-13,185 13,175-13,190 3 13,110-13,122 13,114-13,126 4 13,286-13,299 13,290-13,303 4 13,266-13,286 12,370-13,290 4 . , 13,244-13,254 ~ 13,248-13,258 4 13,214-13,234 13,218-13,238 12/21 TD 13,600' - Well produced @ rate of 3900 BPD w/1.4% BS&W, TP - 140 psi., CP - ll40 psi. Released rig to Well D-24A@ 12:01 AM, 12/21/74. Production prior to RD: 550 BOPD, 261 BWPD, & 32% BS&W. FINAL REPORT. Document Transmittal Union Oil Company of Califor, unlCn "E)'~TE SU~BMITTEE) ACCOUNTING MONTH 7/7/82 ..... -FO FROM Alaska Oil & Gas Conservation Commission R.C. Warthen AT *T p, 0. Box 6247 Anchorage, AK 99504 Anchorage, AK 99502 TELEPHONE NO. TRANSMITTING THE FOLLOWING: 1 ea blue and 1 sepia of each of tl~e fnl!n~ing' ~" and 5" dual induction late-o!og 2" and 5" Borehole sonic 2" and 5" comp. form. density PLEASE SIGN AND RETURN ONE COP~ ~ r ~ ~ , ~,~ ~ K~LEIVEU ~C'~~~ -~~~~- J U i 2 i~ 182 RECEIVED: DATE' ~.~ 0il & ~a~ Comm~: FORM 1-2M02 (REV. 1 1-72) PRINTED IN U.S.A. STATE OF ALASKA '~.x ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLXI~ OTHER [] 2. Name of Operator 7. Permit No. Union 0il Company of California* 74-2 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50_733-20164-01 4. Location of Well Surface: Leg B-I, Cond //3, Dolly Varden Platform 671' FSL, 1215' FNL, Sec 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 06.2' MSL I 6 . Lease Designation and Serial No. ADL 17579 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-14RD 11. Field and Pool McArthur River Field .- Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting permission to perforate Bench I, and reperforate Benches 2, 3 and 4 in the Hemlocko Perforate: Bench #1 Reperforate: Bench //2 Bench //3 Bench //4 12,942'-12,952' 2.6" Gun, 4 HPF, 13,044'-13,074' 2.6" Gun, 4 HPF, 13,092'-13,190' 2.6" Gur{, 4 HPF, 13,218'-!3,238' 2.6" Gun, 4 HPF, 180° phasing 180° phasing 180° phasing 180° phasing Estimated start-up date: September 24, 1981 ~,o. ~-~ ~a~.0il.~.~ *Marathon Qil Company - Sub-Operator 14.1 here~; ;a;~;e fo~g~e and correct to the best of my knowledge. Signed ~V~V~ '~, ~~~[,~le D~ST DRLG SUPT Date The space~w ~r C~mission use Condition~of Approval, if any: Apprcved Copy · Returned / BY LONNIE C. SMITil B¥Orderof Approved by. COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10403 Rev. 7-1-80 STATE OF ALASKA ALASKa' )IL AND GAS CONSERVATION ( ._,MMISSION SUNDRY'NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WEL~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 74-2 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50-733-20164-01 4. Location of Well Surface: Leg B-i, Cond #3, Dolly Varden Platform 671' FSL, 1215' FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2' MSL 12. I 6. Lease Designation and Serial No. ADL 17579 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-14RD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or'Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (NOte: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) . I~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 10/8 - 10/9/81 Bench 1 was perforated and Benches 2, 3, & 4.were reperforated under drawdown at the following intervals (as noted in Sundry Notice, Intention of, dated 9/21/81) with a 2-1/8" enerjet gun set at 4 HPF: ' ' Perforate: Bench #1 Reperforate: Bench #2 Bench #3 Bench #4 12,942 '-12,952' 13,044 '-13,074 ' 13,092 '-13,102 ' 13,114'-13,126' 13,175'-13,190' 13,218 '-13,238 ' Production prior to Reperforation: 1836 BFPD, 80% BS&W, 367 BOPD Production after Reperforation: 2012 BFPD, 76% BS&W, 483 BOPD RECEIVED *Marathon Oil Company - Sub-Operator O u~ 2 3 ].98'I ~Jaska 0il & (~as Cons. Commission 14. I hereby certify that the foregoing isj;rue and correct to the best of my knowledge. Signed~,/~v /~ ~/~1~~,~.~I~/~"/ Title Df, ST DRLG SUPT The spa~e below for Commission use Date 10/16/81 Conditions of Approval, if any: By Order of Approved by_ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate t ,.;~ ', --- " ' TUBI. NG/CASING DETAIL WELL NO. DATE BY: Item Description Set ' .J__ts Si ze Wt Thread Gra.de, ,Rang,,e Condition Length From ,,. To · . ~e_,~, ~-~i~ % --/...,-~ < ~J 4.~...~oi ~..7- . .. 4.:~. ~£ _ .+-b~'~ ~. x ,&~L .-c~:'~ ¢~&;~ J~-~,' . ?~- .+l,~ · .- ~j -J , .,. 4-1/2~'~ 12., ~,.,t,f A.~,L .' N-,~O t:)~.~,-~ ~_,' .~'.4-~ 42, ~zS, ~t-5, ~ ...... i J II I I II II ......... i J 4-~~ _. a~ p;~ N-8o ~... ' ~ ...,D~ ~,~ ,.4 ~" ' ' ~0 .&-~' 1.~,~~ ASL ~0 Z ,., ~ . i~.~1 ~oJ, 7¢ ~ ~z..u /~.~~ ~~ ~-80 ~ ~ 4.~ Z2~.2~ . c-/.~ ~~- ~ ~7~7- 7~ /7. c A ~ U ~ -86 ~ z · / z~. o+ ~7¢~.7/ ¢~vz .7~ F,e:~;arks: Up ,.ok 1'~8~oo0 'if- ~ ZtocV..~ t8 ~ooo --/r Alaska Oil& Gas Cons. Commission . : "' TUBI, NG/CASI. NG DETAIL "- WELL NO. :...._'L"~ - DATE: BY: .. Item Description Set Jt,s_ Si ze Wt Th,.r, ead Grade Range , Con.cli tion Length .... From To . . Iz +-~' /z.C~ A~ ~-~ - z ~' .~¢.~z ~r~.¢~_ .~°~.z~- . ... .~_1~/ ~.2~ ~L ~-~0 ~~ ' ~ ~.~7~ ~l~',~ ~l~.lJ ~- ~" S.Z~ ~ ~b N-a6 ~o~ .~ x. ~z ~a,~t ~za ~,~_~ ~ ~ ~- /6'.'~ ~ . 2~ ASa . N-~ ~ . . / . . ........ ~.0~ ~Z~. ~ ~~.~1 " . .... / g~ ~ ' t/z't D. 2 ~ A s¢ N-BO . . Remarks: NOV 7 1980 Alaska 011 & Gas Cons. Commission TUB I, NG/CA.S I. NG DETAIL Item Description ts Size · : Wt Thread Grade Range Condition Length lc - p,c], . Set ' From To irks- NOV ? I 7;J_, o7_ ' 19~0 TUBI, NG/CASI. NG DETAIL DATE: __J -Z:~_2.~_m~ ....... BY: _~~' _ ,o Item Description Set ts Size Wt Thread. G .fade R, a. nge Condition .,, Length~ From To I I . ....... . ~ ,. . .... ~-~7~.'~_~~_ . A~L N,Ro ~~ ~ 4.2~ ?2.7&1 ~4 ~~ "- ~L ~'- C ~ '' ..... '_~5.'t ~~~q~ '~-~o ~°~' / -7~ !~7~.~5 I~_~ . . e ....... __O~k~ x _ ~,~ Je_ ~/g~,~~ ~;~ ~,~ x-'~& ~ 2.,~ '.c~' 2~2'.-5.1.. . '~ ~a~'~ ' ' ' t_ _.. ~-t~z' _B_._~__&.~- '~ N-ao ~ ! &,_OD J2;.7~Z.~Z_zl2__~,~_.k ., . ...... cpi~ 4- vz ~o ~_.~_.. 4-~/~ ~ ~ e& ~.7~X,:.oo .¢s ~_ t~. 3.8_ i . ' . ,_ . ....... j .................. ................................................................... ~ 1 II ~.h' STATE Of ALASKA - --'ti *~ -,~-~~oM~,~ · '~ ALASKA~,f'L AND GAS CONSERVATION CG,MMISSION SUNgRY NOTICES AND REPORTS O'N WELLS RES //~O~ ' ~j' 1'LNG" 1. DRILLING WELL [] COMPLETED WELL [] ~ , ,.~ 3 LNG 7. Permit No. ~-'~1 4 EN 2. Name of Operator Un ion 0i I Company of California * 74-2-'L~ I GEOL 3. Address 8. APl Number ."' ....... '~ 2'GEO~. P. O. Box 6247, Anchorage, Alaska 99502 50-733-20164-01 ~'i i] 3GEOL__ 4. Location of Well 9, Unit or Lease Name ~I'Ai I I:~ Tradinq Bay Unit ~i. STATTE( Conductor //3, Leg B-1 Dolly Varden Platform r l0. Well'Number ' CONFER: 671' N & 1215' E Sec 6' TBN, R13W, SM D-14 Ri-) ......... - -~. 11. Field and Pool FILF: McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. __ KB 106.2 MSLI ADL 17579 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing D Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~7~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting anY' proposed work, for Abandonment see 20 AAC 25.105-170). Received verbal approval from Mr. Russ Douglas on 10-3-80 to Tony Swan. Work commended 10-15-80; completed 10-27-80 ~.? 1. RU to tree, & pumped 20 bbl pill of Imco safe ::~: ~ Seal - suspended in KCL water with 10 ppb Imco Dri I-S. Displaced with 157 bbl · 2. RU DA & RIH and pert tbg with 4 HPF, (12,760' - 12,761') 3. Set bbv, ND Tree, NU & tst BOPE.____ .:..~.:~,~.t~- ~". -!;?!~, 4. Pul led PKR and Ld tbg and GL Valves.~' --~'~ ~'~:,!/, 5. Recovered fish - 23' of Camco gradient survey tools. · : . ~:.::..:~ 6. NIH with Bit and washed fill to 10,350'. ,~111.~1~.1:,~=:~,~ 7. Set PKR at 12,747'. ~ ~~ 8. RIH with prod tbg, install bpv, ND stack, NU & test tree. ~'~' ~ ~?'~ 9. Returned well to production. BFPD BOPD FORM GAS TP CP Production Before Repairs- 2444 793 459 160 1200 Production After Repai rs- Subseq_uent Wo~l~ 1~¢_Po~2e~2 802 535 210 1240 Attachment: Tbg detai I o~ ~'o~m ~qo. ------- D~tecl --/---/--- · MARATHON__Oi I Company - Sub-contractor. ., . )Z;z, Th. ~b~ ~or Commi~sio. Con~s of Approval, if any: · · By Order of Approved by COMMISSIONER the Commission Date __ F crt 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports,' in Duplicate ~tS 7 Item Description Size _~ Wt Thread . . _ /2. ~*I ,,q 5 z . .- /2. ~~ /lX L ' 12.~'~· _/2, ,Z/ ,4£z- ,45Z. Grade Range Cond i t i on A £ E .,.,'2___ ',;ELL ,~0.' DATE ' BY: Set _._ '/_/.. o o From 2z~.. 8'3 ~":· ,92- To ql. O0 3-2._~ ~- __ 300. lO . . ':3 ~_~._.0~ 3o~. 7~ ..... -~//. 8o .... 2 ~7Z.20 - · 5.~. // _ ~~. o8 _ ~ ~ 73-. 7/ ._ ....... ' TUBI. NG/CASING DETAIL WELL NO. DATE BY: It :m Descri>tion Set Jts . .S.i ze Wt Thread Grade Range Condition Length From T,o ~ " W,~~ ~J~ ~0 .~. /l~/.ff~ ~4q...~, ~ " X o.~ ~~ ~ .,~ ~ ~.,~' ' ~,oo '~ q~...?2. . . ~ , ~ . . . , .. ~ .. " 6z~ ~ ~.~mt' af ~,~ / ~.~1 g'HIH, H%.. _ / " /z. ~ ~ ~-go ' z.' 33..o~ ~'~1, ~ ~ . . ..... . . " y::. /, / ~.~ y ~,>z /~,,-~ s-.l/ 9&~/.~3.. :~¢ma rks: TUBI, I,IG/'C.AS lNG DETAIL .. WELL NO.: DATE: BY: tern Descri ~tion Set Jts Size Wt Thread Grade Range Condition Length From To · i~l'- ' 3 ' /~ " ~/. 2~'/l S ~ /v - ~o ~- q / 3 . 2 5-e ~ ~ ~ . ~ ~ . yo ~ ¢/ ~ X A~z ~,~ . q. o 7 . ' /oo.~o.~ ,,, -. /~' ", ~.2~ ~z l~-~a ~ ~y/. 7~/ , , : lo?z/. ~,~ . . . . , , , " ¢z~ ~ //-~a¢r ~ '~ ~,~ ~ ~./*/ 107¢3 zS. , . ~ ~ Xo-/~x~ ~ox x A~I ,~,¢ q, tU ~1 o,~ ~,~,~, n~x/ ~/ 12 Ma, coC~.~'~~ , / ,. ..% Remarks: 4,- or~f~c~ WELL NO.: ~-~xm~9 DATE: ~/~,~/~'o Item Description Set Jts Size Wt Thread Grade ,Range Condition Length From To I " ~.2~ ~SL O-~r 'Z 2~. !¢ : I1~ .26 " XO- ~fZ, ~or ;' ~-fir/'~'~ ~.~o ll~73.qG I · . . · .. "' o-. I z?. ¢3 11~2 B. o7 , ,,, , , . . .' .. : . . ,, , -. . , , , . ,, , , ,,,, , , -. ,, Remarks; ,o STATE OF ALASKA <See other in- structions on Di¥[~101~ 0~Ii01I~N[[~A~,..~NSERVATIONCOMMITTEE ..... 'se side)5. APIN~~CODE 50-133-2016~-01 .......... ~O!a~.~g~ , , , WELL COMPL[IION OR R[~OMPLEIION REpORI AND LOG* I iii i i i la. TYPE OF WELL: ou: ~ uAs ~ W ELL W ELL DR Y Other b, TYPE OF COMPLE~ON: WELL OrE8 EN ~ACK RESVR. Other ~ :, ~,,,~ o~ o~,~o~ Trading Bay Unit Union 0il Company of California * ~. w~o. D-14 RD 909 West Ninth Avenue, ~Anchorage, Alask~ 99~01 . 4. t,oc~r~on or W~:LL (Re~ort toaation clearly and in accordance with any State requirements)* g~Y~ ~SL & 1215' F~, Sec. 6, T8N, R13W, SM At top prod, interval reported below 209.92' F~ & 910.98' F~, Sec. 17, T8N, R13W, SM At total dep~ 680.19~ ~L ~ 876.32~ ~, Sec. 17~ TS~ R13~, S~ ~2.~m~o. 7~-2 9/16/74 11/17/74 12/21/74 +106.2' ~ (~SL). ~ +62.7' '~'~ ~ ~ aOW~' ROTARY TOOL8 CABLE TOOL8 10,025' T~ . ~,865' T~ -- All' PRODUCING XN~RVAL(S), OF ~I$ CO~TION--~P, BO~O~, N~E (D AND ~)* ~, WAS DIRE~IONAL ~ SURVEY ~ADE Hemlock: 11,655~12~060' ~ or 9,453-9,841' T~ ~ Yes 6. LEASE DESIGNATION A2qD SERIAL NO. ADL-1757 9 7. IF INDIA2q, AX~LOTTEE OR Ti~IBE NAZVLE 10. FIELD AND POOL, OR WILDCAT McA~thur River - Hemlock Sec. 17, T8N, R13W, SM 24. TYPE ELECTEIC AND OTHER LOGS RUN Sonic/GR/Calip., DI.L/S~ DensitT/GR/Calip.; CBL~ Magnelog. Casing Potenti.al Profile Log. "'25. ' CASING RECORD (Report all strings set in well) ee rec°~d DEPTH SET (MD)] HOLE CASUq£; S1ZE ] WEIGHT. LB/FT. ~ GH~DE , I SIZE[ C~MLNTING RECO~ - 26 and ~tt e~ent I · ~' ,, 26. LINER RECO~ ] 27. TUB~G 8IZ~ TOP (~{D) ~ BOTTO~ (MD) [SACKS CEM~T* SC~E~ (~D) SIZE DEP~ SET (~D) ~ PACKE~ SET 7~ d;D. 6,735' 13,579' . I See Attac~ 14-1/2"0D [ merit I ii i i i 28. PERFOIRATIONS (~PEN TO PRODU ON (interval, size and number) See Attachment II ii iii i 30. PRODUCTION PULLED - -- 6,677 ' [ (x-over) [3-1/2"0D 12~850'[ 12,810' 29. -ACID, Si!O~, Fi~ACTLYRE, CEZ, IE:NT SQUE_~Z'~, ETC. DI~,T~T'Ii i~TiiIRVAL (MD) [ AA'IOUNC 2~D }lIND OF MA~PIAL US~ See Attac~entii DATE FiP, F~T P!:()DUCTI.ON [ PI%ODUCTION MEIHOD (Flowii~.g, gas lif~, pumping--size and type of pump) lWELL STATUS (Producing or 1211511975 [ Gas Lift ] ~ucing r,'~;' or' ':rzs~, l'a6uns U-r;ST~m '[CnOXE SI~E [PROD'N FOR OIL---E, DL. G-~%S--lViCF. ViATER--BBL. [GAS-OIL P~.*nTIO __1./8:11/75 [ 96 I 0pen. I 10,603 I 3,972 i 328 I 375 FLOW, TUBING- [CASING PRESSURE [CALCUI+~T~D OIL--BBL. GAS~-rdIC~. WATER--BBL. IOIL GRAVITY-API (~OR~,) Iq~ESS. 1 124-HOUIt RATE ' ,12o sig I 1,o8o psig! ~ 2,650 I 993 I 207 ] 37° APl 31. DISPosITioN OF CAS (SOil'S' Used .for fuel, vented, etc.) '" t TEST WITNESSED BY Delivered to Marathon-Union Gas Gathering System C.D. Ramsey I - Liner & Cementing Record; II - Perforating Record, III - Directional Survey "' 2.q. ! hereb~(~trtify that the foreg,oing and attached information is complete and correct as determined from all:available records sw,~ ~ T~,~ ~st. Drl~. Supt, ~ . ~irn R .'.,, ,Ca. lle. ncl, er ,:, ,,, . , *(See Instructions and Spaces [or Additional Data on Reverse Side) DATE _2 / 2_4_/_Z5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and ir~ any attac!~ments. Items 90, and 22:: If this well is completed for separate, prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcJuci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported i~ item 30. Submit a separate report (page) on this form, adequately identified, for each additior~at ir~te~val to be seperatety produceJ, show- ing the adiditional data pertinent to such interval. Item]6: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20'and 22 above). 34. SUMMARY OF FORMATION TF, S'~'S INCLUI)IN(; INTERVAL TF~STED', pRESSURE DAT~ ~ ~OVERI~ OF OIL GAS, 35 GD~GIC MARK~ WAT~ AND MUD , NA~ .. Liner Lap Test - 6,450-6,735'. IHP - 2,795 psi, IFP - 35 psi, ISIP - 59 psi, ~.~s~s. ~ ~v~.~ FFP - 59 psi, FFP - 35 psi, FSIP - 94 psi, F~ - 2,789 psi. Recovered 80' ..... total rise in drill pipe. Hemlock 12,940 ' 9,531 ' ~.. Dry test (DST) of squeeze perforations 12,900-13,270'. I~ - 4,916 psi, IFP - 1,781 psi, ISIP - 2,211 psi, FFP - 1,781 psi, FSIP - 3,019 psi, FHP - "G" Zone 11,755' 8,675' 4,869 psi. Recovered no fluids. Test 0K. ~. Dry test (DST) of perforations 13,317-13,319'. Recovered water cushion. I~ - 5,105 psi, IFP - 1,522 psi, ISIP - 1,571 psi, F~ - 1,522 psi, FSIP - 1,571 psi, F~ - 5,056 psi. Recovered no fluids, test OK. ~. C~RE DATA. A]'I'AC[[ B~EF D~C~ONS L]TtlOLOGY. PORO~TY. FRRC~ APP~N~ ~ ,,.,~ .... TBUS WELL D- 14(REDRILL) LINER & CEMENTING RECORD Attachment I 1. On 11/19/74, ran 6,844' (175 jts) 7" OD, 29#/ft., N-80, X-line casing. Top of liner at 6,735', screw-set packer at 6,741', liner' hanger at 6,743', collar at 13,536', and shoe at 13,579'. Cemented with 800 sacks of Class 'G' cement with 4% gel, 1%'D-31, and 0.3% R-5, followed by 300 sacks of Class 'G' cement with 0.4% R-5, 1% D-31 - 16.0#/gal. 2. A pressure test of the 7" - 9-5/8" liner lap bled from 4,000 psi to 1,200 psi in one minute. The liner lap was cement squeezed with a total of 350 sacks of Class 'G' cement (additives as above) in two (2) separate squeeze jobs. The lap was pressure tested with 4,000 psi and held OK. ~A subsequent dry test (DST) of the lap recovered no fluids--test OK. 3. The intervals 12,920-12,922', 12,980-12,982', 13,150-13,152', 13,317-13,319', and 13,425-13,427' were perforated for block squeezes in each interval. Cement could not be pumped into formation through perforations 13,425-13,427'. Remaining intervals were cement squeezed with total of 220 sacks of Class 'G' cement (additives as above) in individual squeeze jobs. After drilling out all cement retainers, a dry test (DST) of all block squeeze perforations recovered no fluids--test OK. Attachment II TBUS WELL D-14 (REDRILL) PERFORATING RECORD DATE 12/14/74 12/15/74 12/16/74 12/16/74 12/18/74 12/:1.8/74 12/19/74 HEMLOCK BENCH INTERVAL, MEASURED DEPTH 3 2 13,150-13,160' (10') 4 ? 13,286-13,299' (13') 4 ~ 13,266-13,286' (20') 4 ? 13,214-13,234' (20') 4 S 13,244-13,254' (10') 3 ~ 13,110-13,122' (12') 3 t 13,170-13,185' (15') HPF TYPE GUN & HOLE SIZE 2-1/2" Jumbojet Bar Gun .40" Holes 1! 1! '! I! Il Total of 100' shot with 200 holes. VISION OF OIL AND C-AS ANCi!f~RAgE $ REPORT of SUB-SURFACE DIRECTIONAL SURVEY JOB NUMBER AMO 1174 0-20 MARATHON OIL COMPANY COMPANY TRADING BAY UNIT D-14 R.D. COOK INLET WELL NAME LOCATION Tangential Method of Computation TYPE OF SURVEY DATE ' 11-25-74 SURVEY BY Shyam Talwar OFFICE 045 Alaska -COMPLETION REPORT -- 11/27/74 ............... -NARATHON OIL CO. ................... TRADING BAY-UNIT WELL D-t4 REDRILL -GYROSCOPIC-SURVEY .................................. K. B. ELEV. 106.2-F~m--- -TANGENTIAL COHPUTATION -PREPARED FOR EA,THAN WHIPSTOCK BY F. H. LINDSEY-AND-A$$OCm .. ..... ..................... RECORD OF SURVEY ALL-CALCULATIONS--PERFORMED BY I B M ELECTRONIC.COMPUTER .... ............... TRUE .................................... . --IVtEA$., ..... DRIFT-VERTICAL ........ SUB ..... DRIFT --- TOTAL COORDINATES ........ C L-O $-"U'"R E-'$ --DEPTH-.ANGLE ........ DEPTH ......... SEA ........... DIREC D ....... M ............................................. DEG, DOG- LEG SEVER I TY SECTION STANCE ............ ANGLE .... DEG/IOOFT~D I'STANC ............................. D ..... M ...... -$ 0---0 ...... 0--- ...... 0.00 ....... -106.20 ..... NI 0 W ................. 0.00 S -- O,O0'W ................. 0.00 5~'0 .... 0~~ 0,000 ---lO0 .... 0--0 ......... 100.00 6.19- N 0 W ..... 0,00 S 0.00 W OmO0 S ........ 0" 0 .....O"~W .......... 0.000 -200 .....0 .... 0 ...... 200.00 93.80 N 0 W -- 0.00 S 0.00 W OmO0 S--- 0 -'0-' O"W ......... OMO00 -300 .... 0"'"30 .....299.99 '--193e79 N 1'7 W .... 0m83 N 0e25 W 0.87 N"'[6'-'59 59'W'--0'.500-- 0~ 01~ 0~-0¢ O,'OC 400 0 40 --399,98 293,78 N 58 W · 500-.0 30 ~99,98 393.78 N 54 W '&O0--O 4~ ......... 599.97 .... ~93.77 N 75 W -- '700 ..... 0 ~0 699,97 593,77 N 60 W -800 ..... 1-0" ' 799.95 693.75 N 87 W · 900--' ~ -~9 ....... $99m9~ 793.7~ N 55 W --"1000' 1 ~0 " 999.89 89~,69 S 28 E 1100-5 0 1099.51 993m31 S 43 E --t200-'-6 ~0 "[[98,87 1092.67' $ 50 E ---1300 8 3'0 1297,77 1191.57 S 52 E · 1~00 10 0 1~96.25 1290,05 S 55 E --1500 12 15 1493.98 1387,78 S 51E ..... 1600 15 0 1590,57 148~,37 S ~7 E 1700 17 ~0 1685,94 1579,74 S ~9 E .... 1800 20 20 1779.71 167~,51 S 49 E ..... 1900 2~ 0 1871.76 1765.56 S 51 E -2000 26 15 ~961.~4 1855,2~ S 53 E ~ 2[00 29 0 2048.91 ~9~2.?~ $ 5~ E ..... 2200 ~1 45 2133,94 2027.7~ $ 52 E 1.~5 N 1.24 W -- 1,91 N 40 ~6 .... 33 W ........0.~40 1.96 N 1.95 W 2.77 N 64-47 26 W ......... 0m175 2.~0 N 3.21 W .............3e95 N 5~ 22 .... 7"W 0.~35 2.74 N 3.97 W 4.82 N 55 23 6 W ........... 0.297 2.83 N 5.71 W ' ' 6.37 N 63 ~7-48 W ......... 0.599 ~.08 N .... 7.50 W ................. 8.5~ N 61 26-'2'W ...... 0.665 1.77 N 4.60 S 11.87 S 20.97 $ 19.98 E 30e93 $ 3~.21 E 44.29 $ 50e70 E 61e9~ $ 69.63 E 81..66 $ 92.32 E 10~,~7 S 118,55 E 129e06 $ 1~8.92 E 155.68 $ 18~m2~ E 184.85 $ 222.96 E 217.25 S 264.4~ E '-2', 73 ~'3~72 -7 6.27 W 6.51 N 7~+ 12 53 W ......... 2.675 ....... -5,OR 0.32 W ........ ~+.61 S -4 ' 5 59 W ......... 3.572 8.3~+ E ...........1a,.51 .% 35 4-5'/ E ..... :1.653' 28.97 S ~3 37 8 E ............ 2.017 46.12 $ 47 52 ~5 E .......... 1.575 67.32 $ 48 51 ~ E ........... 2.377 9~.19 $ 48 20 42 E - - 2.905 123.26 S 48 30 17 E .............. 2.562 158.02 $ ~8 36 ~9 E ............ 2.8~0 197.06 $ ¢9 5 12 E ..... 2.760 ............. 191',3l 2~1.2! $ 49 48 13 E 3.355 ........... 289.63 $ 50 20 18 E ........ 2.750 ........ 279.'6~ 3~2.23 S 50 35 38 E --2.796 .......... 330.0] ........................................... · --t4.5] 28'. 6 e 90.7~ t'19.91 '153,'7~ ...................... RECORD OF'- SURVEY ............ ALL 'CALCULATIONS PERFORMED BY I 15 N ELECTRONIC COMPUTER ..................... ...... ........ TRUE -NEASe-.DRZFT VERTICAL- SUB -DEPTH ANGLE DEPTH SEA .... D M DR IFT D[REC DEG, ---2300 34 0 2216,84 2110,64 S 52 E .... 2400-36 15 2297,49 2191,29 S 51E --2500-38 0-2376.29-'2270,09 S 51E ..... 2600' 38 30 2454,55 2348.35 $ 50 E .... 2700 39 15 2531,99 2425,79 S 50 E --"2800"39'45 2608,87 2502.67 S 51E -'2900 40 30 2684,92 2578,72 S 53 E "3000 41 15 2760,10 2653,90 S 51: E ---3100 42 10 2834,21 2728,01 S 51E .... 3200 43 0 2907,35 2801,15 S 52 E .... 3300 4! 45 2981,96 2875,76 S 53 E ..... 3400 40 0 3058,56 2952.36 5 53 E 3500 40 15 3134,88 3028,68 S 53 E -- 3600 40 45 9210.64 3104.44 S 52 E TOTAL COORDINATES 251,68 S 288*89 S 327,63 S 367,65 S 408,32 S 448*56 S 487,64 S 529,14 S 571,39 5 653,45 S 692,13 S 731,02 S 771,20 S ...... DOG LEG C L O S U R'E'-'S .... SEVERITY .... SECT*ION DISTANCE .... ANGLE- -DEG/IOOFT ...... DISTANC ..... D M S 308.49 E -- 398,13 S'50 47"29-'E .......... 2.250 .... 383~-56' 354,45 E 457,26 S 50 49 6' E ........ 2,322 402,29 E 518.83 S 50 50'23 E ....... 1.750-- ~49,98 E -" 581.08 S 50 44 59'E ...... 0.796 498,45 E '644,34 S 50 40 34"E ........ 0,750 548,14 E ........708,28 S 50 42-19 E ..... 0,809 600,01 E 651.25 E 703.42 E 757,16 E 810.34 E 861.68 E 913,28 E 964.72 E --~99eTZ 559,92 621-10 682~'6~ 744.49 807.94 773,18 S 50 53 53 E ........ 1.491 839,12 S 50 54 22 E ...... 1,508 906.25 S 50 54 47 E ........ 0,920 ...........872,55 974.44 S 50 59 21 E ......... 1,071 ..... 937,86 1040.99 S 51 7 4 E ......... 1.420 ...........1001.27 1105.23 S 51 13 38 E ....... 1.750 ............ 1062.49 1169.82 S 51 19 ~0 E ....... 0.250 ....... 1124,.02 1235,09 S 51 21 38 E ........ 0,820 ........ 1186.52 ..... 3700 40 30 3286,68 3180,48 S 53 E ...... 3800 39 50 3363,46 3257.26 S 52 E ....... 3900 40 15 3439,79 3333.59 S 52 E --4000 38 45 3517.78 3411,58 S 50 E .... 4100 37 10 ~597e46 ~491,26 S 51E - 4200 37 30 3676,80 ~570,60 S 51E ---4300 38 15 3755.33 3649,13 S 50 E 4400 38 0 3834.13 3727,93 S 50 E ....... 4500 38 15 9912.66 3806,a6' S 51E - 4600 98 30 3'990,92 3884,72 S 50 E .... 4700 39 15 .068,36 3962,16 $ 49 E .... 4800 39 30 4145,52 4039,32 S 49 E ..... 4900 .0 0 4222,13 ~115,93 S 49 E -- 5000 40 15 4298,45 4192,25 S 50 E 5100 40 ~5 4374,21 4268,01 $ 49 E 810,29 S 1016,59 E 849,73 S 1067,07 E 889,51 S 1117.98 E 929.74 S 1165,93 E 967,77 S 1212.89 E 1006,08 S 1260.20 E 1045,87 S 1307.62 E 1085,45 S 1~54,78 E 1124,41 S 1402,90 E 116~,"2 S 1450,58 E 1205,93 S 1498,34 E 1247.66 S 1546,34 E 1289,83 S 1594,85 E 1331,36 S 1644e35 E 1374,19 S 1693.61 E 1300,01S 51 26 33 E 1364,07 S 51 28 7 E ..... 0,923 ................ 1309.72 1428,68 S 51 29 34 E-* 0,410 ....... 1371.58 1491.25 S 51 25 48 E ........ 1.967 1432~'1! 1551,67 S 51 24 48 E -' 1,695 ....... :1490.2~ 1612,54 S 51 23 52 E-' 0,330 ............ 1548,8~ 1674,43 5 51 20'46 E ..... 0,969 ........ 1608i7! 1735.98 S 51 17 54 E - 0,250 ........... 1668,2~ 1797,89 5 51 17 17 E .... 0,666 ...........1727,8~ 1860,13 S 51 14 42 E 0,669 ............ 1788.02 1923,35 5 51 I0 16 E 0,978 ............ 1849,4~ ~986.92 5 51 6 6 E 0.250 .......... 1911,2~ 2051,15 5 51 2 9 E ...... 0,500 ...........1973,7C 2115,75 $ 5l 0 15 E- 0,691 ............ 2036.1~ 2180,99 5' 50 56 39 E ........0,820 ....... 2099~5f · ........................... RECORD OF SURVEY ALL CALCULATIONS-PERFORMED BY I B H ELECTRONIC COMPUTER ........................ TRUE ---NEAS,. DRZFT-.VERTICAL SUB .... DRIFT --DEPTH-ANGLE.- DEPTH - SEA DIREC ...... D M ...... DEG. ....................... DOG-LEG TOTAL COORDINATES ........ C L-O--.$-U.R.E.*-S ............... SEVERZ'TY--------SECTZON DISTANCE ---ANGLE .... DEG/ZOOFT ..... DISTANC ..... D M S -5200 40 45--4449,96 4343,76 -S 49 E - 1417e0! S 1742,88 E ---5300-4! 0--4525,43 4419,23 $ 48 E --5400-41 15-.4600e62 4494,42 S 69 E ---5500--41 30 4675,51-4569.31 $ ~8 E --5600 42 15 4769,54 4643,36 S 48 E ---5?00 42 30 6823.26 4717e06 S 48 E 5800 42 15 6897e29 679~.09 $ 47 E -5900 ~! 30 ~972,18 6865.98 S ~? E --6000 62 45 5066,?9 ~9~0.59 S ~? E '-6100 40 0 5123,39 5017,19 $ 48 E '6200 40 15 5199,71 5093,51 S 4~ E ---6300 60 0 5276,32 5170,12 S 44 E --6400 39 30 5353,~8 5267,28 $ 63 E · 6500 39 45 5a3'0.37 5324.27 S 42 E ~'6600 39-0 "5508,08 5601~88 S 43 E 6700 38 50 5585,g7 5679,77 S 63 E ...... 6800 37 30 5665,31 5559.11 S 42 E .... 6900 37 30 5744,64 5638*~4 S ~2 E .... 7000 38 0 5823,44 5727~24 S 42 E -7100 41 30 5898*36 5792e[4 $ 38 E -' 7200 45 25 5968,74 5862,54 S 38 E 7300 67 0 6036e94 5930,76 S 38 E .... 7~00 50 30 6100.55 5~94,35 S 39 E ..... 7500 52 45 6161,08 605~*88 S 39 E -' 7600 53 25 6220,91 611a,71 S 40 E .... 7700 52 30 6281.78 6175~58 S 99 E ..... 7800 5[ 45 6363,69 6237,69 S 38 E .... 7900 50 90 6407,30 630[,10 $ 38 E ---8000 50 25 6671,25 6365,05 S 39 E · 22~6,23 S 50 53-16 E ....... 0,000 ..... 2162-~98 2460,91S 1791,63 E 2311,76 S 50 48 11E ...... 0,701 '" 2226"*-97 1506,17 S 2842,39 E* 2377,66 S 50 65"20 E ........ 0,704 15~8.51 $ 1890.6~ E 2443,85-$ 50 60 52 E ........ 0.707 .... 2355-~-63 1593,50 $ 1960.60 E 1638,70 S 1990.81E 1684.56 S 2039.98 E 1729,75 S 2088,4~ E 1775.26 S 2137.16 E 1818.17 $ 2184.91 E 2864,65 $ 2229,79 E 2910,89 S 2276.45 E 1957.~1 S 2~17.83 E 2004,93 S 2360.61 E 2050,95 S 2603.53 E 2096,82 S 2446.30 E 2142.06 S 2487,04 E 2187.30 S 2527,77 E 2233,05 $ 2558.97 E 2285,27 S 2509,75 E 2341.23 S 265~,69 E 2398,85 S 2698.51 E 2~58,83 S 2747.07 E 2520,69 $ 2797.17 E 2582,07 $ 2848.67 E 2643.73 S 2898.60 E 2705.61 S 2966.95 E 27~6,61S 299~.65 E 2826.16 $ 3062.84 E 2511,01 $ 50 36 33 E ...... 0,750 -- 2~21%-2~ 2578,50 S 50 ~2 27 E ............ 0.250 ..... 248.7~10 2645,61 S 50 27 3 E- 0,719 ....... 2552,93 2711.76 S 50 22 0 E 0.750 ...... 2617.80 2778.2~ S 50 17'*10 E ...... 0.250 2582~99 2862,66 S 50 1~' 4 E .......... 1,868 27~5"*'68 2906.70 S 50 5"46 E ......... 2,590 ' 2809~5~ 2970~63 S 49 57~52 E .............. 0,250 ......... 2873'~*07 3033.77 $ 49 ~9 7 E .... 0.812 ......... 293'6,09 3097,~6 S ~9 39 28 E ......... 0,685 ........... 2999~-59 3159,65 S ~9 32 32 E ..... 0.982 .....---306I~95 3221,97 S 49 23 55 E .......... 0,260 .... 3282,35 S 69 15 ~3"E ............ 1,476 ...... 3362,74 S 49 7 48 E ......... 0.000 ............. 3603,8~ S 49 0 5 E 0,500 ........ 3~06~13 3468,91S 48 ~7 33 E 4,33~ ............. 3372,32 3538.70 S 48 34 38 E ...... 3,750 ............. 3610,61 S 68 21 51 E 1.750 ............ 3516.3C 3686.77 S 48 10 8 E 3,580 ............. 3593,3C 3765,37 S 47 58 36 E * 2.250 ...... 3672.73 38~4,76 S 47 ~8 37 E .... 0,962 ..............3752.5E 3923,16 S ~7 37 58 E -' 1,095 ...........383t~'7~ 6000,60 S 47 26 61E .... 1,089 ............ 3910,1E 4076,74 S 47 16 0 E-' 1.250 ............ 3987.2~ 4152,8~ S 47 6 51E .... 0.810 .............. 4063,9E ...................... RECORD OF SURVEY .... ALL' CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER ........... TRUE · -MEASo--DRIFT-VERTICAL '-. SUB - DRIFT -DEPTH'~-ANGLE- DEPTH 'D M ........ DEG, ............................. DOG- LEG TOTAL COORDINATES .... C L*'-O-$-'U-R-E*S ......... -SEVERITY-- SEC-T'~'-ON- D I STANCE ...... ANGLE ....... DEG/10 OFT------D I STANCI ........... D M '-S --8100 50-10-- 6535030 ..... 6429010' $ 38 E '- 2886068 S 3090012-E ....... 4228,68'"S-'46'-56-5~'E --8200-52 0 .... 6596,86 6490,66 S 37 E 2949,61 $ 3137,54'E ..... 4306,32 S 46-46" 5-E ....... 1,989 3014065 $ 3184,79 E ..... 4385,32 S'46 34"19-E ...... 1,698 3081052 S 3233.38 E 4466.60 S 46- 22 39'-E ......... 2.250 3148.12 S' 3283.56 E 4548,89-S 46 .... 12'23""E .... 1.119 3210.86 S 3334,37 E .... 4629.00 S'""46 ..... 4 ..... 51'-"E .... 36126 3274,01 S 3381.96 E 4707,10 S ~5 55'*-$~*E ..... 20254 3335.98 $ 3426,98 E 4782,57 S 45 46 15-E ........ 2,381' 3398,73 $ 3470,92 E 4857,85 $ 45 36 ..... 7 E~0,766-- --'8300'"53'-30-6656,35 6550,15 S 36 E 8400 55 45 6712,63 66060~3 $ 36 E - 8500 56 30 .... 6767082 6661062 S 37 E ---8600 53 50 ...... 6826,82 -6720,62 -S 39 E 8700 52 15 6888,05 6781,85 S 37 E --8800 50 0 6952,32 6846,12 S 36 E ---8900 50 0 7016,60 6910,40 $ 35 E '~299F82' --4465-8~ --462 5i-42- 4778 9000 51 30 7078,85 6972065 S 36 E ----9100 53 30 7138,34 7032,14 S 36 E ---9200 53 0 7198,52 7092,32 S 35 E .... 9300 53 0 7258,70 7152.50 S 36 E ---9400 56 15 731~.26 7208,06 S 37 E ---9500 58 30 7366.51 7260,31 S 36 E ..... 9600 58 30 7418,76 7312,56 $ 35 E 9700 59 45 7&69,13 7362,~3 S 34 E --~-9800 59 45 7519,51 7413031 S 35 E -~9900 59 30 7570,26 7~64,06 $ 36 E -'10000 59 30 7621.02 7514082 S 36 E ~-'10100 59 0 7672,52 7566,32 S 35 E 10200 58 0 7725,51 7619,31 S 94 E -10300 56 45 7780,34 7674,1~ $ 35 E .... 10400 57 0 7894,81 7728,61 S 92 E 10500 58 0 7887,80 7781,60 S 32 E 10600 59 0 7939,30 78~3,10 S 33 E ..... ~0700 57 15 7993,40 7887,20 S 31 E -.-~0600 53 0 8053,5'8 7947,38 S 29 E '---~0900 52 15 8114.80 8008,60 $ 32 E 3462,05 S 3515.92 E 3527,08 S 3564,17 E 3592,50 S 3609.98 E 3657,11 $ 3656,92 E 3723,52 S 3706,96 E 3792,50 $ 3757,08 E 3862,34 S 3805,98 E 3933.96 S 3854,29 E 4004,72 S 3903.84 E 4074,42 S 3954.48 E 4144,13 S 4005,13 E 4214,39 $ 4054,29 E 4284,65 $ 4101,71 E 4353,16 S 4149,68 E 4424,28 S 4194,12 E 4496.20 S 4239,06 E 4568,09 $ 4285,75 E 4640,18 $ 432g,06 E 4710,03 S 4367,78 E 4777,08 S 4409,68 E 4935,03 S 45 27 I"E ...... 1,688' ~'856'~88' 5014,34 S 45 17-58 E ........ 2e000 .... ~937~25 5092.94 S 45 8 20-E ......... 0,94~'-- '5017,"1Z 5171,80 $ 44 59 54 E ......... 00799 ............. 5096'~'9'~ 5254,16 S 44 52'20 E .............. 30351 5t80w08 5338,42 S 44 43'*52 E .......... 2,402-~52~5w3# 5422,47 S 44 34 44 E ...... 0,853--- 5507,41S 44 24'-50'E ........... 1,516 5592,65 S 44 16 9'E ....... 0,864 5677,93 S 44 8 38 E ........ 0,898 ......... 5609'i'50 5763,24 S ~4 1 22 E ...... 0,000 ......... 5695'i'$6 5847,91 5 43 53"27~E .... 0,99~ 5781'~37 5931,47 S 43 45 ! E- 1,31¢ .............. 5866~-i6 6014,14 S 43 37 44 E ...... 1,507 ........ 5949',79 6096,31 S 43 28 12 E -'2,525 ........... 6033i"52 6179,44 S 43 18 50 E 1o000 .......... 6263,79 S 43 10 24 E ' 1,314 ........... 6203,8'4 63¢6,03 S 43 0'48 E ..... 2,439 .......... 6287',7~ 6423,54 S 42 50 27 E .... 4,555 ....... 6367,~Z0 6501,22 S 42 42 35 E ...... 2,~99 .......... ...................... RECORD OF SURVEY ALL CALCULATIONS PERFOEMED BY .... TRUE -MEAS*-DRIFT-.~ERTICAL SUB DRIFT ~EP.TH ANGLE-- DEPTH SEA DIREC ......... D M ..... DEG, B M ELECTRONIC COMPUTER · TOTAL COORDINATES -11000 52 30 8175,68 8069,48 S 28 E 4847.13 S -11100 53 50 8234.68 8128.48 S 28 E 4918,42 S -i1200 53 30-- 8294,17 8187,97-$ 24 E 4991,85 S -ll300 50 0 '8358,45 8252,25 S 24 E 5061,84 S --11400 47 0 8426~65 8~20,45 S 19 E-. 5130,99 S -.11500 45 15 .... 8497,05 '"8390,85 -'S 16 E 5199,25 S --11600 46 45 8565~57 8~59,37 S 15 E 5269,61 .... 11700 45 0 8636,28 8530.08 S 14' E 5338,22 11800 45 15 8706,68 8600,48 S 11E 5407,93 S -11900 45 30 8776.77 8670.57 S 4 E 5479,08 5 12000 46 0 8846.23 8740.03 $ 3 E 5550.92 -.12100 46 15 8915.39 8809.19 S 3 E 5623.06 $ --12200 45 15 8985,79 8879,59 S 2 E 5694,03 .... 12300 44 0 9057,72 8951,52 S 4 E 5763,33 S -12~00 43 0'9130e8.6 9024.66 S 2 E 5831,49 S -12500 43 45 9203809 9096,89 S I E 5900,63 S --12~00 42 30 9276,82 917o.62 $ 1E 59.68,18 S -12700 41 30 9351.72 9245.52 S 1W 6034,43' 5 12800 41 45 9426.32 9320.12 S 1W 6101,01 -12900 41 30 9501.22 9395.02 S 0 W 6167,27 $ -13000 41 30 9576.11 9469.91 S 0 W 6233,53 S 13.100 41 30 9651,01 9544.81 S 1W 6299e78 -13200 4.1 30 9725.90 9619.70 S 3 W 6365,95 -'13~00 41 45 9800,51 9694.31 $ 5 W 6432,29 S --13~00 41 30 9875,~1 9769.21 S 7 W 6498,06 5 13500 41 30 9950,30 9844,10 S 7 W 6563,83 -BOTTON HOLE CLOSURE 8036.69 FEET AT $ 35 14 27 E .............. 4446.93 E 4484.83 E 4517.53 E 4548.69 E 4572.50 E 4592.07 E. 4610,92 E 4628,03 E 4.641.58 E 4646.56 E" 4650.32 E 4654,10 E 4656,58 E 4661.43 E 4663.81 E 4665,01 E 4666.19E 4665.04 E 4663,87 E 4663,87 E 4663,87 E- 4662,72 E 4659,25 E 4553.~5 E 4645,37 E 4637.30 E ............. DOG LEG - .C L 0 S U R E.S ...........SEVERITY .......... SECTiO~ DISTANCE - ANGLE DEG/IOOFT ....... DI-STANCt D M- S ............. · 99 S 42 ,17 S 42 ,51 S 42 · 35 S 41 ,76 ,81 ,10 ,08 .71 ,07 ,66 32- 3-'E ........ 3,178 ..... 21 35"E ........ 1,340 ....... 8'40'E ...... 3,240 56 37'E ........ 3,500 · 09 5 38 6577 6656 6732 6'805 6872 '6936 7002 7065 7126 7184 7241 7299 7355 7412 7467 7521.95 7575,79 7627,38 7679'46 7732,20 7785,16 7837,62 7888.85 7939,08 7987,76 8036,6.9 6'524~75- 6604%-84- --6 683'i-69' 6758 ~ 82' S'41 42'21 E ........ 4,797 ........ 6829~04- S 41 27 ...... 5'E ........ 2.782 68'96'~'0c~ S 41 ].1' 9 'E ............]..664 .........6964.43' S 40 55 26 E 1,891 ......... 7030~'34- S 40 38 21 E '2,140 .......... 7095"*'09' .S 40 17 59 E .............. 4,987 ............ 7156e0'8- 5 39 57 17 E ..... 0,874 ...........7216,92 5 39 36' 50" E ........... 0.250 ................ ~7278i01' S 39 16 34 E ..... 1,230 ........... 7337~'42 S 38 57 58 E ...... ~.880 ........... 7396~8r 39 .... 5'E .......... XeTO~ S 38 19'47 E .... ~'1,0~7 75~I'*01 $ 38 1'11 E le250 756'6i'87 S 37 ~2 23 E ................ ~,67~ ..... 7620i3T 5 37 23 ~5 E 0,250 .............. 767~02 5 37 5 5~ E 0.7~0 ...........7728~1~' 5 36 48 ~2 E ............ 0~000 ........ 7782~26' 5 36 30 23 E 0,663 ........ 7835-70 5 36 12 i E 1,325 ............ 7887i'75 S 35 53 2 E ...... ~e352 ..... 7938*'5'? 5 35 33 37 E ' ~.352 ...... 7987,~3' $ 35 ~ 27 E OEO00 ........ :8036~6'9 ........ ..... INTERPOL'ATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES"FOR' GIVEN DEPTHS ..... ~--'-- TRUE .................. --CODE .............. MEASURED' VERTICAL TOTAL COORDINATES C L' O S U R-E 'SOB -NAME ......... DEPTH DEPTH DISTANCE '- ANGLE .................. SEA-- ........... D N- $ .... _ .... · ,, , -MEASURED-DEPTH-AND.OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, .................. TRUE -- -MEASURED VERTICAL SUB MD-TVD DEPTH .......... DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL ---COORDINATES 206 ........ 206, 100, 0 -306 .......... 306* 200, 0 406 ...... 406,---300, 0 506 ........ 506, ......600, 0 606 ................. 606. 500. 0 706 ............... 706, ..... 600, ..... 0 806 ..................... 806*- 700. ...... 0 906 .................... 906, .... 800. ......... 0 1006 ................. 1006. 900. ..... 0 1107 ....... 1106. 1000. 1 ........... 1207 ................. 1206. 1100. ' 1 1309 ...............1306. 1200. 1410 ........ 1406. 1300. 1513 .......... 1506. 1400. 1616 1606. 1500. 1722 1706. 1600. 1829 ........ 1806e 1700, 1938 1906. 1800. 2051 ....... ' 2006. 1900, 2167 ............ 2106, 2000, 2287 2206, 2100, 2411 .......... 2306. 2200. 2538 ............ 2406, 2300. .............. 2667 ........... 2797 2928 .......... .......... 3062 ......... 3198 3332 ......... 3462 ........... 3594 2506. 2400. 2606. 2500. 2706. 2600, 2806. 2700. 2906. 2800. 3006, 2900. 3106. 3000. 3206. 3100. 3725 ........ 3306, 3200. 3856 ....... 3406. 3300. "' ' ............... 3985 3506. 3400. 4111 ............. 3606. 3500. 2 ~4 6 10 15 23 32 45 61 81 105 132 160 190 222 256 292 325 356 388 419 450 479 505 0 0 0 0 0 " O 0 0 0 - 1 0 1 2 4 5 8 9 16 20 24 27 28 30 ~2 -36 32 29 26 0,05 N -- O,O1-W 0.87 N- - O,31-W 1.68 N - *- 1*29 W- 1,98 N 2.03 W-- · -- 2.33 N ........ 3.26-W .... 2.74-N ....... .... 2.91N ........ 5.82 ....... 3.93 N ....... 7.42-W - 1.37 N ............. -' 5.08 S ......... 0*25 E ........ :" 12.55 S ........ 9*20 .... E 21,82 S ..... 21.20 E 32.29 S 35,89 E ............... 46,52 S ...... 53.09 'E 65.17 $ ..... 73.35 E 86e59 S -' 97,99 E 111.54 S .... 127.29 E- 139.28 $ 162,48 E 170e60 $ 204,05 E 206.68 S ..... 250.90 E' 247.25 S 302,83 E .................. 293.17 S '- 359.73 E 342.92 S - 420,51 E 394.77 S 482.30 E ............ 447.16 S 546,41 E ........... 499.39 S --- 614.51 E .... 555,41 $ 612.71 S 665.69 $ 716.40 S 768.85 S 820.31 $ 872.00 $ 923.77 S 971'98 S 683.70 E 756.32 E 826,,,59 E 893,88E 961,70 E 1029,42 E 1095,58 E 1158.81 E 1218,10 E -MEASURED'DEPTH AND OTHER OATA ..................... TRUE ........ MEASURED VERTICAL SUB MD-TVD .... DEPTH ...... DEPTH SEA DIFFERENCE 423? 3706. 3600, 531 4365 .......... 3806, 3?00. 558 -4492 ......... 3906, 3800, 586 4620 -- 4006. 3900. 614 4749 ..... 4106. 4000. 643 4879 ..... 4206. 4100, 673 5010 ........ 4306, 4200, 704 5142 4406, 4300e 736 5275 ......... 4506. 4400. 768 5407 ........ 4606. 4500. 80-1 5541 ................ 4706, 4600, 835 5677 4806, 4700, 871 5812 .... 4906, 4800, 906 5945 .......... 5006, 4900. 939 ................ 6078- -- 5106, 5000, 971 6208 5206, 5100. 1002 6339 .... 5306, 5200, 1033 .......... 6469 5406. 5300. 1062 ......... 6598 --. 5506, 5400. 1091 6725 ...... 5606. 5500. 1119 ........... 6852 5706. 5600, 1145 ........... 6978 5'806. 5700, 1172 7Ill 5906. 5800, 1205 ............... 7255 6006, 5900, 1249 .............. 7409 6106, 6000. 1303 .............. 7575 6206. 6100, 1369 ...... 7739 6306. 6200, 1433 ............... 7898 6406, 6300, 1492 ................... 8055 6506. 6400, 1548 .... 8216 6606. 6500, 1609 -- 8389 670'6. 6600, 1682 856.5 6806, 6700, 1759 ............. 8728 6906e 6800e 1822 ............... 8884 ?006, 6900. [8?8 9046 ...... 7106. 7000, 1940 FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, .............. VERT I CAL CORRECTION TOTAL 26 27 28 28 29 32 36 35 31 29 29 28 26 27 54 66 64 59 56 77 56 62 COORDZNATES 1020,97 $ 1277,95 E' 1071,42'S 1338.07 E 1121,20 S 1398,94 1172.61 S '1460.00 E 1226.39 S 1521,87 E .... 1281.06 S 1584,76 1335.74 S 1649,38 1392,27 S .- 1714,41 1449.72 S '- 1779,20 1507.47 $ 1845,06 1567.15 S"' 1911.35 1628,24 $ 1979,19 1689.93 $ 2045,75 1750.45 $ 2110.65 1808,52 S 2174,19 1868e56 $ 2233e57 1928e90 $ 2291e24 1989e99 $ 2347e16 2049e84 S 2402e49 210B,35 S 2456,69 2165,38 $ 2508e03 2223,04 $ 2559e95 2291e51 $ 2614e64 2372,88 S 2678e22 2464.60 S 2751,75 2566e98 $ 2836,01 2668,13 $ 2917e66 2765,.36 $ 2993e63 2859.18 S 3068,64 2959,82 S 3144e95 3073.88 S 3227e83 3188,92 $ 3316,61 3291,51 S 3994,67 3388,57 S 3463,81 3491,94 $ 3538.64 E 'E E__ E E E E E E E E E E E- -MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. -. ........... TRUE ...... MEASURED VERTICAL SUB MD-TVD DEPTH ...... DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL- ..... COORDINATES ...... 92[3 7206, 7100, 2007 9385 ........... 7306, 7200, 2079 9576 - 7406, 7300, 2[?0 9774 - .7506, 7400, 2267 9971 ...... 7606. 7500, 2365 10164 -. 7706. 7600, 2457 10347 ..... 7806. 7700, 254! 10536 .............. 7906, 7800, 2630 10721 ........... 8006. 7900, 2715 10886 -- 8[06, 8000, 2780 11052 ........ 8206. 8100. 2846 11219 8306, 8200, 2913 11370 8406, 8300, 2964 11513 ............ 8506, 8400, 3007 - 11657 - 8606* 8500. 3051 11799 8706. 8600. 3093 11942 ......... 8806, 8700. 3136 12087 8906. 8800, 3181 12228 9006, 8900, 3222 12366 ............. 9106, 9000. 3260 12504 12639 -- 12773 12907 ......... 13040 13174 ..........13308 9206. 9100. 3298 9306, 9200, 3333 9406. 9300. 3367 g506. 9400. 3400 9606. 9500e 3434 9706. 9600. 3467 9806. 9700e 3501 67 72 91 97 98 92 8~. 89 85 65 66 67 53. 43 42 43 38 38 35 33 33 34 3600,74 S 3615.97 E 3713,88 $ 3699.70"E-' 3845.55 S 3794,23 E 3986.01 $ 3890.74 E ........... 4123,77 S 3990,33 E ............ 4259.02 S - 4084.42 E - 4386.92 S 4170,78 E 4521.87 S 4255.74 E 4655,03 S -4337.30 4767.65 4884.00 5004,95 5110.25 5208.65 5309.03 5407.46 5509.52 5613e47 4403.79 E ............ 4e66.53 E 4523.36 E .............. 4565,36 E .... 4594.59 E ........................... 4620.75 E ....... 4641,49 E .... 4648.15 E 4653.60 E 5713.69 S 4657.96 5808.50 S 5903.47 S 5994.16 S 6083.05 $ 6171.67 $ 6260,1~ S 6348.54 S 6437.28 S 4663.00 E .................... 4665.06 E ............... 4665.74 E .......... 4664*19 E .......... 4663.87 E .................... 4663.41E 4660.16 E 4652.83 E ...... ......... -~NTERPOL-ATED--VALUES--FOR-'EVEN [000 FEET OF'MEASURED DEPTH, ' -TRUE - MEASURED ............ VERTICAL ....... SUB '-DEPTH ....... DEPTH ........ SEA TOTAL COORDINATES .... 1000 ......... 999, .....8'93, .... [.77 N ' .... 2000 ...... 1961, 1855, 155,68 S -' 3000~; --' 2760, 2653, 529,14 S~...---' 651, 4000 ............. 3517, " 3~11, 929,?4 6000 .......... 50~6* ..... 4940, 1775,16 ?000 ............ ~_8__23, --5717, ....... 2233,05 8000 ......... 64710 ---6365. ...... 2826,'16 S 3042. 9000 .................7078. .... 6972. 3~62,05 $ 10000 7621. ..... 7514. .... 414~.13 S 4005. 11000 .............. 8175. .... 8069, ~847.13 S ~2000 ................... 88~6. .......8740. ........... 5550.92 S" 13000 ................... 9576. .......... 9469. ................ 6233.53 S 2'/ 2~+ E .................... 25 93 E 35 E ,,,-~ ..................... 1~+ E~ .......................... 97 E~.,~ ............. 8~+ E ................ 92 E ...................... 13 E .............. 93 E .................. 32 E ........................ 87 -E VERTICAL SECTION SCALE I'!: ~000' MARATHON OIL COMP.~Y TBU WELL D-14 REDRILL TANGENTIAL METHOD " i TVD-. 9,950' TMO= I $, 500" SCALE I"= 500' MARATHON OIL COMPANY TBU D-14 REDRILL TANGENTIAL METHOD TVD -' 9,950' TMD: 13,500' F~rm ~o. P--4 R~V. $'1-70 STATE o~ALA~KA SUBMrT IN BUPLICA'I~ OIL AND GAS CONSERVATION COMMII-i'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WKLL WKLL 2. NAME OF OPII~ATOR $$ Union 0il Company of California 3. AbDRESS OF OPEP,,ATOR 909 West Ninth Avenue, Anchorage, Alaska 99501 LOCATION OF WELL Surface: 671' FSL & 1215' FWL of Sec 6, T8N, R1BW, S.M., Conductor #3, SE Leg of Dolly Varden Platform Proposed Hemlock Top: 620' FNL & 800' FWL of Sec 17, T8N, R1BW, SM APl NI.r~Im~CAL bODE 50-133-20~64-01 LEASE DESIGNATION AND SERIAL NO. ADL-17579 7 IF INDIA]~. ALOTAEI~ OR TRIBE NAME 8. L~IT F.~"t~ OR LEASE NAME Trading Bay Unit 9 WELL KO O-14 Redrill (ll-17) 10 FIELD ~ND POOL. OR WILDCAT McArthur River Field~ Hemlock I1 SEC., T., R., M.. (BO~TOM HOLE oamcTnr~ At TD: 1100' FNL & 1010' FWL of Sec 17, T8N, R13W,SM 12. PERMIT NO 74-2 '"13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND C~A./IF~NTING JOBS INCLUDING DEP~'~I SET AND VOLUMES USED. PEB2'OHATIONS. TESTS AND H.ESULTS FISHING JOB~ JUNK IN HOLE AND SIDE-TRACKED HOLE AND A~I¥ OTHER SIGNIFICANT CI4A~G~ IN HOLE CONDITIONS TRADING BAY UNIT WELL ~D-14.: REDRILL - DECEMBER 1974: Set into retainer @ 13,270' & squeezed 75 sacks cement into perforations. Perforated 13,150-13,152' for block s~ueeze & squeezed interval w/lO BBLS cement. Perf'd 12,980-12,982' for block squeeze. Set retainer @ 12,960' & squeezed perfs w/ll BBLS cement. Perf'd 12,920-12,922' for block squeeze. Set retainer @ 12,900' & squeezed w/8 BBLS cement. 12/4-8 Drilled out cement & retainers 1, 2, & 3. RIH.~o 13,276'. Set packer @ 12,846' for dry test of squeeze perfs 12,920'-13,152'. Test was dry. POH w/DST tools. Drilled retainer @ 13,276' &Hard cement to 13,324'. RIH w/DST tools w/5500' water cushion. Set packer @ 13,245' & dry tested perfs 13,317-13,319'-0K. Ran CBL log. 12/9-1 Ran Potential Log & Caliper Log. Ran 3½" tubing string & landed tubing w/packer @ 12,809'. Unable to set packer. POH w/3~ tubing string & found packer setting ball split. Reran 3½" tubing string & production equipment. 12/15-18 Removed BOPE & -installed x-mas tree & tested to 5000 psi--OK. RU Dresser- Atlas. RIH w/Jumbo Jet bar gun & perf'd Hemlock Banch 3 from 13,150' to 13,160' w/2 SPF. Production tested interval. Ran Pressure Buildup Survey. Flowing BHP - 1435 psi @ 3,312 BPD. SI BHP 3,382 psi. Perf'd Hemlock Bench 4 from 13,286' to 13,299' & production tested interval. Perforated Bench 4 from 13,266' to 13,286' & production tested interval. Perforated Bench 4 from 13,214' to 13,234' .& ran production test, gradient & pres- sure buildup survey. · 12/19-21 Perforated Bench 4 from 13,244' to 1B,254'~~& ran production test. Perf- orated Bench 3 from lB,110' to 13,122' & from 13,170' to 13,185' & placed well on test. Released ri~. Dec. 21: 1974.. Marathon Oil CO. ~Sub-Operator · '~ · , DATE ~mmm~~"~Jl.~'_ ,, ~ - au~ Dist Drlg. Supt. ...,.,.. ,. .,_ _,,...,-., ,. . ~'~OTE ~c~rm No. P--4 ~'. ~- 1-70 STATE OF ALASKA SUBMIT IN ~rPLICA'I~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, W~LL NAMe. OF opm~Toa *Union 011 Company of California ADDRESS bF' O~'ER~TOR ' 909 West Ninth Avenue, Anchorage, AK 99501 4. LOCATION' OF WFA~ Surface: 671' FSL & 1215' FWL of Sec 6, T8N, R13W, SM, Conductor #3, SE Leg of Dolly Varden Platform. Proposed Hemlock Top: 620' FNL & 800' FWL of Sec 17, T8N, R13W, .SM $ APl NlYl~ERICAL ~ODE 50-133-20164-01 LEASE DESIG~AT'ION A.'<D SERIAL NO. ADL-17579 IF INDIA~, ALOTTEE OR TRIBE NAME 8. L,~IT. FARM OR LEASE NAME Trading Ba7 Unit 9 WELL N'O ~ D-14 Redrill (11-17) 10 F~ A-ND POOL. OR %VILDCAT _ McArthur R~ver Field n. SF.C, T., ~., ~.. (BOrro~ HOL~ o~_.c-"rrv~ At TD: 1100' FNL & 1010' F-WL of Sec 17, T8N, R13W, SM 12. P]~RMIT !~rO. 74-2 ,, 13. RE~ORT TOTAL D~:PTH AT END OF MONTH, CHANGES IN HOLE SIZE. CASING ANI) Cl~MENTING JOBS INCLUDING DEPTH SET AND VOL~ USED. I:'ERFORATIONS. TESTS AND HESULTS FISHING JO]~ JUT~K IN HOLE AND SIDE-TI:~ACKED HOLE A~D ANY OTHER SIGNIFICANT CHANGES IN HOLE COBrDITIONS. TRADING BAY UNIT WELL D-14.~. REDRILL - NOVEMB. ER~ 1974: 11/1-17 Drilled 8-1/2" sidetracked hole from 11,589' to 13,600' TD. 11/18-2o Ran DIL Log from 6,966' to 13,583' TD (WLTD). Ran 175 its 7", 29#, N-80, X-line casing, BOT shoe, float collar, hanger, and packer. Pipe stopped 21' off bottom, shoe at 13,579', float collar at 13,536', top of liner hanger at 6,735'. ii/2i-24 Set BOT hanger and cemented casing with 800 sacks. Tested liner lap with 4000 psi--broke and bled. Squeezed liner lap with 100 sacks cement. Drilled cement from 6,627' to top of liner at 6,735'. Set packer at 6,548' and squeezed lap with 150 sacks cement. 11/25-27 Tagged cement at 6,564'. Drilled hard cement to 6,735'. RIH with DST tools and set packer at 6,450'. Tested liner lap at 6,735' with WSO test--OK. Drilled out liner to 13,536' PBTD. Tested 9-5/8" & 7" casing to 2000 psi for 30 minutes, OK. Ran CBL Log from 13,509' to 6,600'. 11/28 Perforated 13,425-13,427' with 2 SPF with casing gun for block squeeze. Set retainer at 13,387' and broke down perforations with 4800 psi. Spotted 100 sacks cement but unable to pump into forma- tion. Recovered all cement. 11/29-30 Perforated 13,317-13,319' as above for block squeeze. Set retainer at 13,270'. Established breakdOwn at 4500 psi. Mixed 100 sacks cement and started squeeze. Pumped 8 barrels and pressure increased from 2300 psi to 5000 psi. POH. Found drill pipe plugged with cement scale. Now hammering out cement scale. *Maratb~n 0il Comuany --- ~ub-O~eratnr 14. I h~l'eby ~l'tt~ ~.t the fo~~e ~~ ~- .,~ ~'~~~ .Dist_~lg~Supt. .~= 12/9/74 ~/ ,Jlm ~. t;a/la~~ ~ ~ ~ n ~n ~ ~ .... -~- -- ,., ~E--Report on this ,o. ,. ,..uire, .~ .~~,~g~4ot~'}ta,. of operatbn., and must. filed in duplicate with the otl and gal ~onltrvatlon ~on.lfl~hl ISB of the SuQc~ding mon~em otherwise directed, '' BEC DIVI~IGN Of OIL Form No, P---4 I~'V. 8- I-?0 STATE 0~I.A~KA OIL AND GAS CONSERVATION CO/VVVHTTEE SUBMIT I~ DUPLICA'I~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL [] GAB [] OTHEE WELL WELL 2. NAME OF OPERATOR ~Union 0il Company of California ~. ~Dd~ss OF OPE~TOa 909 West Ninth Avenue~ Anchora~e~ Alaska 99501 4. ~OCA~',ON OF wF~L Surface: 671' FSL i 1215' FWL of Sec 6, T8N, R13W, SM, Conductor #3, SE Leg of Dolly Varden Platform. Proposed Hemlock Top: 620' FNL & 800' FWL of Sec 17, T8N, R13W, SM $ AP][ NU~IERICAL ~ODE 50-133-20164-01 LEASE DES!CleArON A%'D SERIAL NO. ADL-17579 ? IF INDIA]~, ALOTiEi~ OR TRIBE NAME 8. L.~IT. FAI'~I OR LEASE NAME Trading Bay Unit 9 %VELL D-14 Redrill (11-17) 10. F1F2Ld) AND POOL. OR WILDCAT McArthur River Field n s~:c., T.. R., m.. macram At TD: 1100' FNL & 1010' FWL of Sec 17~ T8N~ R13W~ SM... 19-. P~RNIIT N'O. 74-2 REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGF, S IN HOLE SIZE. CASING AND CI!;MF_~TING JOBS INCLUDING DEPTH SET A~ VOL~ USD, P~O~TIONS. ~T5 ~ ~SULTS FISHING JO~ J~K ~ HO~ AND SIDE-~CK~ HO~ AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. TRADING BAY UNIT WELL D-14, REDRILL -.OCTOBER, 1974: lO/i-is lo/i6-2i Drilled 8-1/2" sidetracked hole from 8,038' to 10,556'. Ran multi-shot survey to check single-shot surveys. Drilled 8-1/2" sidetracked hole from 10,556' to 10,867'. Lost cone off bit. Drilled on junk to 10,869'. Picked up 8" junk basket. Ran in hole and cored' l' to 10,870'. No recovery in junk basket. 10/22-31 Drilled 8-1/2" sidetracked hole from 10,870' to 11,589' ahead on 10/31/74. Nrlv ".'z ,- ,,.,iL ^ND AN(~HQRA~ - . Drilling ENO ! ENG ~ ENG ..~ I31~NO Jp~ J 4 ENO -~.. --I-3 r--' I .... ---j' DRAFT U._ J SEC J CONifER: FILE: *Marathon Oil Company --.- Sub-Operator szo~ /',";~ ~i~~~~ Dist. Drlg. Supt. ~A~ 11/12/74 NOTE--Report on this fo~ is required for ~ calendar ~th~ regardless of the status of operations, and must ~ filed Jn duplicate with the oil and gas conservatbn commiflee by the 15~ of the suQc~ding mn~, ~le~ otherwise directed. Uhion Oil and Gas D' '~ion: Western Region Union Oil Company of California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union October 10, 1974 Mr. Homer Burrell Division of Oil & Gas State of Alaska 3001 Porcupine Dr. Anchorage, Alaska 99504 RE: TBUS D-14 TBUS D-24 DOLLY VARDEN PLATFORM Dear Mr. Burrell: Enclosed for your f!l~c~.~~are copies of the Monthly Reports (Form P-4) for TBUS D-24 and~~ Also enclosed is the Sundry Notices & Reports on Wells-~5'~-24. Very truly yours, Jim R. Callender District Drlg. Supt. sk Encl. (6) CC: Rodney Smith - USGS Marathon Arco Socal Phillips Skelly Amoco OCT n i97, DIVISION OF OIL AND OAS ANCHORAO5 lPorm No. P--4 R~"V. 5- I-?0 STATE OF'ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS SUBMIT IN DIYPLICA'I~ AP1 NUA'iERICA/. CODE 50-133-20164-01 LEA~E D~SlONA~ION AND S~RTAL NO. ADL-17579 WW, LL 2. NAME OF OPERATOR *Union 0il, Company of California ~. 'kfJ~REss OF ovz~,~To~ " 909 West Ninth Avenue., Anchorage, AK 99501 4. U:~CA'nO~ ov w~ Surface: 671' FSL & 1215' FWL of Sec 6, T8N, R13W, SM, Con~ ductor #3, SE Leg of Dolly Varden Platform. Proposed Hemlock Top: 620' FNL & 800' FWL of Sec 17, T8N, R13W, SM 8. I..~IT.F.~'~ OR LEASE Trading Bay Unit 9 W~L~L NO D-14 Redrill (11-17) 10. ~ AND POOL. OR %VILDCAT McArthur River Field n. s~c., T.. ~., ~.. (~o~ o~~ At TD: ZZO0~ ~L & ZOZO~ ~L n~ gpo ]7: TS~: ~lgW~ SH 12. P~IT 74-2 13. REPORT TOTAL DEPT~ AT END OF MONT~, CIIA~NG~S IN HOLE SIZE, CASING AND C~MENTING JOBS INCLUDING DEPTH SET Abrl) VOLUIVrE~ USED. PF~IFORATIONS, TESTS ANT) RESULTS FISHING JOB~ JU/~K IN HOLE AND SIDE-/~R-ACKED HOLE AND A.I~Y OTHER SIGNIFICANT CI~.~NGES IN HOLI~ COI~rDITIONS TRADING BAY UNIT WELL D-14~ .RE. DRILL - SEPTE.MBER~ 1974: 9/12-14 Pulled ball valve, attempted to open circulating sleeve at 11,.691' with no success. Perforated tubing at 11,360' and 11,550' and killed well with mud circulating through tubing perforations. 9/15-18 Skidded rig over well, installed back-pressure valve, removed x-mas tree and installed BOPE. Tested to 3,000 psi - OK. Pulled BP valve. Pulled tubing and packer from well. 9/19-21 RIH with drill pipe and spotted 120 sacks of cement from 12,230' to 11,740' to isolated Hemlock perfs. Ran CBL Log from 5,000' to %,500' across 9-5/8" casing. Set cast iron bridge plug at 7,121' and tested casing to 2,500 psi - OK. 9/22-25 Milled window in 9-5/8" casing from 6,966' to 7,046' with section mill. Spotted 125 sacks of cement across window from 7,046' up to 6,780'. WOC. 9/26-30 Drilled and polished off cement plug from 6,780' to 6,984'. Kickoff cement plug at 6,984' in a sidetracked hole and drilled new hole (8-1/2") to 8,038'. Drilling ahead on 9/30/74. OCT n !97,'! ANCHORA~ *Marathon Oil Company --- Sub-Operator 14, I hereby c~y that the to~egoi~ i~ true and OOITeCt mc~ ~'~f~/Y~ =~ Dist. Drlg. Supt. _ n.~ 10/9/74 ~E--Report on this fern is required for ~ calendar ~thT regardless of the status of operations, and must ~ filed in duplicate With the oil and gal conservation commi~ee by the 16~ of the suecNding ~n~, ~le~ Otherwise directed. 1974 Trading Bay Unlt $?. D-14 t~ (1I-t7) Union 0ti Company of Callfornta~ ~rato~ Perml? No. 74-2 Mr. Robert Anderson Union 011 Co. of Cattf. 909 W, ~h Avenue Anchorage, Alaska 99501 Dear Sir= Enclosed Is the approved appltcatlo~ for pemlt to drill ~ above referenced ~11, on ~ a~ut Janua~ 15, i974, f~ the ~tt? Va~ Ptatfom. Poi lutlon of any ~fers of ?~ $~ is p~lbi?~ by AS 46. Chapter C~, Ch~ter 70) end by f~ F~al ~ater ~I!~'I~ ~tml ~f, as Prlor to ~nclng o~lons y~--m~ ~ ~~ by a r~~fafl~ of ~a~n? of End--tel In the e~t of su~enston ~ ~~n? p!~ ~1~ ~is off i~ advance ~t!fl~tl~ so t~t ~ my h.~ a ~lt~ Very truly yours, . ,. Hoeer L. Burrell Chalrean Alaska 01I and Gas Conservation ~t~ee, E~l~u~ cc: ~ar~nt of Fish a~ ~, ~t~t ~t;~ ~a~nt of Envlm~fat ~seretl~ ./o enct. Pon-n P--I ~. 9-30-67 APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLL~' BACK 'la. TYPE OF WORK DRILL J~J RD DEEPEN [] PLUG BACK I--J b.TYPE OF WELL WELL WELL OTH]~R ZONE ZO NE STATE OF ALASKA 2.NAME OF OPE~R~TOR Union Oil Compa.ny of California (Marathon Sub-Operator) 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION O'F WELL Atsurface Conductor 3, Leg B-I, 671'N & 12151E of the SW corner. Section 6: oTn~8N j~l~eW~ S.M. Atproposedprod. z fO lock: approx. 6640'S & 4540'E of Sur. Loc. or 779. IS & .775'E of NW corner. Sec. 17:' T-SN', RI~W, S.M. 13. DISTANCE IN MILES AND DIRECTION F.-~OM NEA~REST TOWN OR.POST OFFICE~ 21 miles NW of Kenai, Alaska 8. UNIT~FAR1VI OR LEA~E NAME Trading Bay Unit State D-14 RD (11-17) 10, FIEI-ZD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM ectlon I/: T8N,R13W, S.M. Btm. Ho]e: 1360'S & 1000' i,.. of the NW corner ,=o,,.~ $100,000.00 17. N~O..ACR-'ES ASSIGNED 14. BOND INFORMATION: TYPE S tat ew i de surety a,d/or No. Un i ted Pac i f i c I n s u ra nce C°.~ B- 55502 15. DISTANCE FROM PROPOSED'" '[16..ATO. OF AOI:J~ IN-LEASE[~' ' ",'' LOCATION TO NEAREST 1,000' PROPERTY OR LEASE LINE, FT. (Also %o nearest drig, unit, if any) 18. DISTANC~ FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIET) FOR, FT. 21. ELEVATIONS (Show whether DF, RT. CR, etc.) KB 106.2 MSL t 5,-t2o. Ig. PROPOSED DEPTH ;~ '- ' TMD 14,000. TVD 1-0,202 -- .~ · 1 , 700-' 23, PROPOSED CASING AND CEN[ENTING PROGIR3dV~ ..... ~ 8o TO THiS WELL 20. ROTARY OR CABLE TOOLS ~Ro-t a r y 22. APPROX. DATE WORK WILL START* January 15, 1974 8½" 7" Liner 29// N-80 r5950-13,927" 5....0.0 SXRet CL 'G neat ~m ~'~.~.~ , ~, ' ', i , ," ' ~' ,,.. , t ~ ,, 1. Abandon present wellbore and sidetrack hole. in 9-S/8'' csg. at 6~ 2. Drill 8-1/2'l directional hole to 14,000' 3. Run required logs. 4. Run 7" liner from 5,950' to 13,927' and cement as r~'quired. 5. Recomplete well as Hemlock producer. EST. TOTAL TIME:. Redrill-49 days Completion-14 days TOTAL TIME-63 days ABOVE SP~CE DESCRIBE PROI~OSED PRO~RA1VI: If p~l ~ ~ dee~n or plug ~, give ~ on presen~ p~ive ~ ~d propos~ ~w p~du~ive ~. If propel ~ ~ ~fll or d~n d~e~lo~ly, give ~ent ~ on ~bs~a~ ~t~ ~d mea~d ~d ~ue ve~ical dept. Give blo~ut preventer program. 24. I hereby certl£y that~ F~g is '/'~rue and Cort;ect S! G NCD.~.~~~/~' ~ DATE J an. uary .9, !97h. (T~is spac; ,or State o~'flce use/). " CdNDIT~ONs OF APPROVAL] IF ANY: [] YES ~NO SEE TRANSMITTAL LETTER DIRECTIONAL SURVEY RE~ J A.P.I. NUMERICAL CODE P~'vn:~:~o_ '7'//`- ~ m~PROV~DATE JANUARY 15, 1974 APPROVED BY . · _ TITLE. DATE .~.,~.~ District Land Manager t .32 D-II D-30 I \~ /~ (43X-32) G-36 D-I D-? (34-32) ~ (14-33) g-12 Rd X,,, \ .. G-14 (14-32) · ~ N.'R. I j . -TSN. '' TD 11,281' ~--.~s // //(~2-6) ...... · D:2 '-- -- /D:20/ / "~ " / ~(2EX,6)/ ,-'D-3 . ~,~/,/~ .. (42-6) (43x-5)! UN;ON-MARATHON DOLLY D-I7 ~--4~ ~. D-lO -- ~ (44-6)~J (24-5) ~.~ j (44-5) 5 x-5) R '1:3 W J8 /,~ D-22 (33X- 18)/ I RISW D- D- 42-7). '~~ D-8 RD (13-8) ~D - 14 \\ (44 -7) , Hemlock \ \ TMD 15,000 · T VD 9466 U-M PPSS D-8 (24-8) ADL -6 9 JAH' 0 ~974 N · D-14RD ~ x,~ll- 17) ~ PBH TMD I]3¢02 XTVD 14.000 (12X-17) \ \ ~.D-21 j/~' ( 24 X-17) ~]OT'1'OM HOLE LOCA'~ w~ UNION WELL LOCATION MAP MARATHON SUB-OPERATOR TRADING BAY STATE UNIT (11-17) ! o . ~doo -SCALE: I"= 2000' ~ 26 DEC73 D - 19 (22-4) Lease & Well No. _ .Z-~/./. ~w~ Z)-/~z~Z). ,, CHECK LIST FOR NEW WELL PERMITS Yes No Remarks Is well to-be located in a defined-pool ........ · · · · · · · · · Do statewide rules apply ........................ · Is a registered survey plat attached .................. , Is well located proper distance from property line ........... Is well located proper distance from other wells ............ 1'~ sufficient undediEated acreage available in this pool ........ Is well to be deviated ......................... Is operator the only affected party ............ Can pem~it be approved before ten-day wait ...... ; ........ · '. Does operator have a bond i"n force ........... · Is 'conductor string provided ............ · Is enough ceme~t used to circulate on conductor and surface . . · Will cement tie in surface and intermediate Or production' strings · ~,/1 cement cover all possible productive horizons ........... rf . · Will su ace casing cover all fresh water zones ............ . Will surface csg. internal burst equal .5 psi/ft, to next string · .Will all casing give adequate safety in collapse and tension ...... · Does BOPE have sufficient pressure rating ...... .. · · · · ditional Requirements: Approval Recommended: T~) .... ~ ,<,d~ t,,/1 OKG . I-(WK '~'~' . LCS HHtt --~~ - -JCM