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168-026
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Cc:Brooks, Phoebe L (OGC) Subject:FW: Trading Bay Unit G-09 (PTD 1680260) - AIO 5.014 Compliance Temperature Survey - April 2022 Date:Wednesday, May 25, 2022 9:42:36 AM Attachments:G-09 Temperature Survey Overlay Plot - 2022_04_23.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Thursday, May 19, 2022 12:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Trading Bay Unit G-09 (PTD 1680260) - AIO 5.014 Compliance Temperature Survey - April 2022 Mr Wallace, Per AIO 5.014 (Administrative Approval), Trading Bay Unit G-09 (PTD 1680260) requires a biennial temperature survey. The 2022 survey was completed on 4/23/2022. The survey data (see attached plot) is consistent with previous temperature surveys and confirms that all the injected fluids are being contained in the approved strata. Let me know if you have any questions or require additional information/data. Thanks Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: Field:04/23/2022Hilcorp Energy G-09 Grayling 50 60 70 80 90 100 110 120 130 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 Temperature (Deg. F)Depth-MD, (feet)Pressure (psia) 22 Pressure Perfs 13-3/8 9-5/8 7"TBG 16"Pressure 20 Psia 18 Temperature 20 Temperature 18 22 Temperature Pressure-Temperature Profile 1. Going in hole Overlay 2018 - 2020 - 2022 2. Shut-In 0 0 PTD 168O2 o (Hilcorp Alaska LLC I WeII:IG-09 I Field:IGrayling 104/28/2018 I Pressure (psia) 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 1000 .411.' Pressure-Temperature Profile — - lihmt 1. RIH 4-17-16 vs 4-28-18 2000 Ilk 2. Shut-In 3000 -- 1 I 4000 5000 6000 _ 11111/4 � 7000 :� 8000 t Q 9000 -_ r --11111111tik Jr- 10000 11000 12000Ain146.41L 13000 14000 = --,-- ,. _ llor" 15000 `.4 min- 16000 , I I I 1 I 1 50 60 70 80 90 100 110 120 130 Temperature (Deg. F) —4-28-18 Pressure – Perfs 13-3/8 9-5/8 7" TBG -16" —4-28-18 Temp —4-17-16 Temp Report date: 5/9/2018 SCANNED MAY 1 1 2010 0 w PrD 162026o Hilcorp Alaska LLC I WeII:1G-09 I Field:IGrayling 104/17/2016 Pressure (psia) 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 0 - 1000 _ Pressure-Temperature Profile 1. Going in hole Overlay 2000 2. Shut-In 3000 4000 :::::= 5000 6000 CD 7000 G 8000 A - Q 9000 O _ G — 10000 - 11000 i 12000 13000 14000 15000 T—...m. 16000 I I i i I I i 50 60 70 80 90 100 110 120 130 Temperature (Deg. F) - Perfs - 13-3/8 9-5/8 —7" TBG —16" 4-17-16 Pressure —4-17-16 Temp —4-05-14 Temp SCANNED FEB 1 6 2017 Report date:9/20/2016 A -To s Regg, James B (DOA) 79ct 6-07 (I68�)ZL-o) From: Larry Greenstein [Igreenstein@hilcorp.com] Sent: Tuesday, July 10, 2012 3:49 PM "r-1 To: Regg, James B (DOA) `r Cc: Brooks, Phoebe L (DOA) Subject: G-09 (PTD 168-026) Compliance Temp Survey Attachments: G-9 Temp Survey 03-20-12 vs 5-10-10.xls Hi Jim, Going through my records, Jim, I found a compliance temp survey that I had missed sending to you. We ran it about 6 weeks before it was due and it just slipped by me with all the other activities. Sorry... I did review it, but neglected to send it on through to you. Probably because it looked OK, it dropped off my radar screen. Well G-09 (PTD 168-026) was granted a return to injection under Administrative Approval (AIO 5.014) on July 29, 2008 with an anniversary date of 5/11/08. As required under the approval, a biennial temperature survey was run on 3-20-12. The survey (see attached) is consistent with the last survey run on 5-10-10, although we surveyed a little deeper this year. The current survey confirms that all injected fluids are being contained within the approved zones of injection. Please contact me if you have any questions concerning the survey. Larry 777-8322 Hilcorp Energy Well: G-9 I Field: Grayling 03-20-2012 Pressure (psia) 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 0 1000 2000 3000 4000 5000 6000 Q 7000 8000 IZ 9000 Q 10000 11000 12000 13000 14000 15000 16000 60 70 80 Pressure -Temperature Profile i. Going in holt 2. Shut -In F Pressure – Perfs 13-3/8 Report date: 7/19/2012 90 100 110 120 Temperature (Deg. F) 9-5/8 7 TBG —1E 130 140 150 Temperature A�;O S p7t UOf5ci-?_(,o r Hilcorp Energy Well: G-9 I Field: Grayling 03-20-2012 0 0 t 1000 2000 3000 4000 d 5000 F— t 6000 Q 7000 8000 9000 10000 11000 F- 60 70 80 Pressure — Perfs Report date: 7/19/2012 Pressure -Temperature Profile 1. Going in hole TV[ 2. Well Shut -!n 90 100 110 120 130 140 150 Temperature (Deg. F) 13-3/8 9-5/8 7 TBG 16 Temperature Pressure (psia) Ann onn 4nnn 4Cnn nn— nAnn n— I) 7C!l!l Ann^ AAnn 70 80 Pressure — Perfs Report date: 7/19/2012 Pressure -Temperature Profile 1. Going in hole TV[ 2. Well Shut -!n 90 100 110 120 130 140 150 Temperature (Deg. F) 13-3/8 9-5/8 7 TBG 16 Temperature ksv s P"rb 16 `15ozw Hilcorp Energy Well: G-9 I Field: Grayling 03-20-2012 Pressure (psia) 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 0 1000 2000 3000 4000 5000 6000 r W 7000 8000 t r >Z Q 9000 10000 11000 12000 13000 14000 15000 16000 60 Pressure -Temperature Profile 1. RIH Overlay 5-1 U-201 U vs 3-20-2012 - 2. Shut -In k. 70 80 90 100 110 120 Temperature (Deg. F) 3-20-12 Pressure 9-5/8 16 Report date: 7/19/2012 7 3-20-12 Temperature 130 i 140 13-3/8 TBG 5-10-10 Temp 150 i Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 13, 2010 8:45 AM To: 'Lambert, Steve A' Cc: Brooks, Phoebe L (DOA) Subject: RE: G-9 (PTD 168-026) AA Temp Survey Thanks Steve. I concur with your assessment. Tom Maunder, PE AOGCC From: Lambert, Steve A [mailto:salambert@chevron.com] Sent: Thursday, May 13, 2010 8:24 AM To: Maunder, Thomas E (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: G-9 (PTD 168-026) AA Temp Survey ' Well G-9 (PTD 168-026) was granted Administrative Approval (AIO 5.014) for continued water injection on July 29, 2008. As required under the approval, afollow-up survey was run on May 10, 2010. The survey, which is attached to this a-mail confirms that all injection is exiting the wellbore at the perforations. The well remains on injection. If you have any questions regarding the survey please contact me. e~ . ~y .t ~, ~, ~, L'n wWw tw La 3a. ~.ai~im~ ~f ;~, # ~ t~ ~,} 5/13/2010 Chevron Well: G-9 Field: Grayling 5-10-10 Pressure (psia) 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 0 Pressure-Temperature Profile 1 . Going in hole TVD 1000 - - --- _ 2. Well Shut-In 2000 - - ~l~ ~ t„~b ~~ c,~ c~~ 3000 Su~C'~1 ~ ~ g ~`~ ~1W cc` ~ ~ "'~ c~,t~,t~ l'EC Cf ~~ J l~'c x ' ~o ~ < c c 4000 - ~i t ~ , T ~ v ~ v. v ~ ~ . ~ ~3/ . ~c C ~ ` ~~ ~ ~ 5000 ~r r ~ S S - ~ ~ ~' .~ 6000 ~ Q D 7000 - 8000 9000 -- - 10000 - --- --- 11000 60 70 80 90 100 110 120 130 140 150 160 170 180 Tem erature De . F 5-10-10 Pressure - Perfs 13-3/8 9-5/8 7 TBG 16 5-10-10 Temp 3-7-08 Temp Report date: 5/13/2010 AiLC1~7~ OII! Alsil GAS 333 W. 7th AVENUE, SUITE 100 COI~TSERQA~1`IOAT COMMISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 1, 2008 Mr. Steve Lambert Sr. Advising Petroleum Engineer Chevron PO Box 196247 Anchorage, Alaska 99519-6247 ~`~"~~ A P R ~ ~ 2008 RE: 30-day Injection Test Trading Bay Unit G-09 and G-19 Dear Mr. Lambert: Your request to perform 30-day injection tests on Trading Bay Unit ("TBU") wells G-09 and G- 19 is approved. Chevron's letter dated February 22, 2008 indicates these injection tests are designed to gather additional information in support of an effort to enhance the MacArthur River field waterflood. Area Injection Order 5 authorizes the injection of water for enhanced oil recovery purposes in TBU and establishes rules for injection activities. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Trading Bay Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Both wells have injected as part of the MacArthur River field waterflood but have been shut in for an extended time period because of the limited water available for injection and because of mechanical integrity concerns (tubing-casing communication). Increased surveillance and continued monitoring of wellhead pressures must be an integral part of the injection tests to confirm fluids remain confined to the wellbore and the intended injection formation. The Commission finds that the 30-day injection tests are an appropriate additional step in gathering the information needed to design acceptable long term injection. The following conditions apply: 1. Water only injection is limited to 30 consecutive days once injection has commenced; 2. Temperature surveys must be run before commencing and after completing injection; 3. Chevron must monitor and record at least daily the tubing and all annuli pressures, and any pressure bleeds that occur; 4. The tubing-casing annulus (inner annulus) shall not exceed 1000 psi; 5. Any indication of pressure communication to the casing-casing annulus (outer annulus) m'.,:St be reported ~~m°a'2*°Iy *n tl,a (`nr~,riS3ivi'i; a deciSivri vvili be iiiade at that time if ~.ua tea. w u~. wi the injection test can continue. Mr. Steve Lambert April 1, 2008 Page 2 of 2 Information gathered during the 30-day injection tests must be provided to the Commission as part of administrative approval requests (each well) for long term water injection. Administrative Approval requests must also include sufficient detail from the reservoir simulation to confirm Chevron's findings that renewed injection in TBU G-09 and G-19 improve the efficiency of upstructure injectors and result in incremental oil recovery. A timeline for the restoration of mechanical integrity of wells G-09 and G-19 should also be addressed. If the decision is made to not pursue administrative approval for continued injection, Chevron must provide the information gathered within 60 days of completing the test injections. Sincerely, Daniel T. Seamount, Jr. Chair ~~ 1~ ~~~~ aye -,9 5 February 22, 2008 Steve Lambert Sr. Advising Petroleum Engineer MidContinent/Afaska • Chevron North America Exploration and Production P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7658 Fax 907 263 7847 Email salambert@chevron.com Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7t" Ave #100 ~(p Anchorage, AK 99501-3539 ~$~ ~ ~~~~ ~P~ ~ ~ 200 ~ Dear Tom: Chevron requests approval to perform 30 day injection tests on wells G-9 and G-19. These tests are proposed as the first step to returning these wells to long term injection. This increased injection is part of an ongoing effort to enhance the McArthur River waterflood. Both wells are believed to have tubing casing communication. - Well G-9 (API # 50-733-20098-00, PTD #168-026) was shut-in on July 13, 1995 due to concerns about the wellbore integrity and prioritization of available water injection capacity. The well was subsequently tested for 13 days in 2003. The last measured rate was 1,030 BWPD with 2,350 psi tubing pressure and 1,000 psi casing pressure measured on March 31, 2003. The well has been continually monitored since that time and is reported quarterly on the LTSI report. Well G-19 (API# 50-733-20178-00, PTD #169-026) was shut-in on November 22, 2004 due to pressure communication between the tubing and casing annulus. Due to limited water availability the decision was made to shut the well in. Since that time the well has been continually monitored and is reported quarterly on the report. Wells G-9 and G-19 are both down structure injectors. These wells have remained shut-in due to limited injection capacity and the less than optimum location of the wells. Chevron has begun a renewed focus on injection within the McArthur River Field and as a result the injection capacity on the Grayling platform is being expanded. A portion of the increased injection capacity is planned to be used for injection into G-9 and G-19. Reservoir simulation has shown that renewing water injection into these down dip wells improves the efficiency of upstructure injectors and results in incremental oil recovery. Following is the proposed procedure for bringing each well back on injection. 1) Run a baseline temperature survey. 2) Obtain permission to inject. 3) Inject until the well until injection rate has stabilized. (Limit the length of the test to 30 days.) MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com • • [Tom Maunder] [Alaska Oil and Gas Conservation Commission] [February 21, 2008 Page 2 4) Follow-up temperature survey. 5) Request an Administrative Approval to continue injection depending on results of the survey. Monitor well daily and repeat temperature surveys every two years. Sincerely, ,, ~ --- Steve Lambert Union Oil Company of California / A Chevron Company http://www.chevron.com ~-27-98 TUE 15'53 UNOCRL f"qET GR$ 6RP FfiX NO, 90726378~"' P. 0]/03 Unocal Corporation Agricultural Products 909 West 9'h Avenue, P O Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL Janua~., 27, 1998 Blah' Wondzell State of Alaska Alaska Oil and Gas Conservauon Comau~on 3001 Porcupme Drive Anchorage, AK 99501 Re: Gra:~ling G-9 MIT Approval Dear Blair' Attached is a copy of the MIT Test form and the pressure chart from 12/26/97 for the Grayling G-9 Well Please rewew this data ff it passes, send a copy of the approved form to my fax at 263-7874 othenv]se call me at 263-7830. Sincerely, Christopher A. Ruff Semor Reservoir Engineer Cook Inlet Waterflood Management RUG-22-97 FRI 15:56 UNOORL ~SSET G~$ GRP FRX NO, 90'72637874 Procedure for, MIT on Shut-in Grayllna Injector G-9. P, 02/04 1. Record daily tubing, casing, and outer casing pressures for a consecutive ten day period. Well #: [G-9 [ o// , , , Casing Pressure Outer Casing Pressure Da. te Tubing pre. ssure... 7" 9.518,, 13-318" 7/1197 0 900 80 , 0 , ,, 7~2~97 0 900 80 0 , ,, ,,,, 7~3~97 0 900 80,, 0 ..... ~ ,, 714197 0 900 80 ,,,0 7~5~97 , 0 ~, 900 ,80 0, 716!,9,,7 ,, ,0 , 900 ,,80 ......... 0 7/7/97 0 900 80 0 _~_7/8/,97 0 ,, 900 .... 80 .... 0 ,7/9/97 0 ..... 900 .... 80 0,, 7/10/97 0 900 80 ,,, 0 ,, , ,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical IMeurity Te~'__t OPERATOR*. Unocal Oii & eau Dlvlulon FIELD I UNIT I PAD: Cook Inlet t TBU ! Grayling Platform DATE: 12 / 20197 PRETEST START /[MJ~ ~1 MIN WELL ~P TYPE PACKER CASING TBG REQ TBG TIME TIME TIME START NAME ~S ANNULUS TVD SIZE I WT I GRADE SIZE TEST CSG TBG TBO 1'BO TIME P F FLUID MD PRESS PRESS C$O CSO CSG *N PRESS PRESS PRESS G. 9 " $ SaltH20 14,~4D' 9-5/8~'47#L -' 3-1/2' 2389 0 0" 0 0 ' ~12:3Spm X . . N-a0 & S-95 780 ~1'10 2 ! 10 2-11'~ .... COMMENTS ' " *' , .... I ....... !" I '1 I .......... ~o~~, 1 !, ,,, ,' --' '" t I~l ,l ' ....... , I ...... , , . ......... COUU£UTSi .... " , .... I , , , ~ . . , . . ,.., . x TUBI~ INJECTION FLUID ANNULAR FLUID: GRADIENT: WELL TEST; PRODUCE WATER INJ DIESEL Ir~,ial SALT WATER INJ GLYCOL MISCIBLE INJECTION SALT WATER .4388 4-yesr INJECTING DRILLING MUD Workover NOT INJECTING OTHER Other , OTHER AOGCC REP SIGNATURE JflN-27-98 TUE lB'B4 UNOCC~L ~¢°-SET Gets GRP FflX NO, 9072637~' P. 03/03 a/£'d OZI'ON ,t .-',~ '..! L ,gas Cons. Unocal Corporation ( Agricultural Products 909 West 9th Avenue, P O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALe Thursday, January 08, 1998 AOGCC Attn: Mr. Blair Wonzell 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wonzell: Our future plan, is to convert Well G-9 from a temporarily suspended shut-in well to a service well for the injection of non-hazardous oil field wastes (Class II) associated with drilling, production, and workover operations. G-9 was drilled in mid-1968. The G-9 was placed on injection in Hemlock Benches 1-6 in early 1970. Injection rates varied over this time period, but ranged predominantly between 8000 and 14000 BWPD. Profiles run on G-9 since 1978 indicate that over 70% of the water was being injected in to Hemlock Bench 2, which is the dominant producing bench in the Hemlock Formation. In an effort to reduce injection volumes in to Hemlock Bench 2 and alter the injection streamlines, the G-9 was shut-in in mid-1995 based on being the most off-structure Hemlock injector and its injection profile. At the time, the offset producers averaged 94% water cut. A review of the offset production in the area of G-9 indicates that aside from mechanical difficulties or recompletions in producers, or a normal decline rate of about 10%, no unusual negative impacts are attributable from this injector shut-in. Therefore, lost oil production is minimal. The off-structure location of the G-9 and relatively small volume of non-hazardous oil field waste proposed for injection will not adversely affect remaining Hemlock recovery. Sincerely, Hal Martin Reservoir Engineer AOGCC Inj Letter. DOC [ STATE OF ALASKA ~ ALASKA el AND GAS CONSERVATION OMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon' Suspend' Operabon shutdown Re-enter suspended well. Alter casing: Repair well' Plugging' T~me extension' Stimulate: Change approved program Pull tubing' Vanance Perforate Other. x 2. Name of Operator 5. Type of well: 6. Datum elevabon (DF or KB) Umon Oil of Cahfom~a (Unocal) Development: 42.6 KB feet 3 Address Exploratory: 7 Umt or Property name Strabgraphic: P.O. Box 196247 Anchorage, AK 99519 Service: X McArthur River F~eld "4 Locabon of well at surface 8. Well number 1382'FEL, 1886' FSL, Sec. 29, T9N, R13W G-9 At top of productive ~nterval 9 Permit number 1795' FEL, 2675' FSL, Sec 27, T9N, R13W ~.~ (~' --~) Z ~ At effecbve depth 10 APl number Same a TD 50-7733-200-9800 At total depth 11 F~eld/Pool 1290' FEL, 2380' FSL, Sec. 27, T9N, R13W McArthur R~ver Reid ., 12 Present well cond~bon summary Total depth' measured 15,238' feet Plugs (measured) true vertical 10,356' feet Effecbve depth' measured 15,208' feet Junk (measured) 15,208' true verbcal 10,283' feet Casing Length S~ze Cemented Measured depth True vertical depth Structural Conductor 369 369 Surface 580 16" 1300 sx 623 623 Intermediate 3001 13-3/8" 2300 sx 3044 2384 Producbon 10512 9-5/8" 4200 sx 10,555 7612 Dner 15285 7" 300 and 850 sx 15,328 10,356 Perforation depth, measured 14,460'-14,515', 14,535'-14,685', 14,685'-14,690' (sqz); 14,710'-14,930'; RECEIVED true verbcal g724'-g766', g782'-g8g6', g8g6'-ggo0', gg15'-10078'; 10093'-10258', 10273'-10314' Tubing (s,ze, grade, and measured depth) 4-1/2", 12.6 CC/fi, N-80, 14,211',JAN- 91998 3-1/2", 9 2 cc/fi, N-80 14,211'-14,317' Packers and SSSV (type and measured depth) Ohs BWD Parma-drill packer @ 14,240' A~aska 0il & Gas Cons. Commission Anchorage 13. Attachements Descnpbon summary of proposal x Detaded operabons program' x BOP sketch. Wellbore schemabc, letter 14 Esbmated date for commencing operation 15 Status of well classificabon as: 1-8-98 16. If proposal well verbally approved Od Gas Suspended Name of approver Date approved Service' Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned DaleHaines )/~~(_., ~1~/"' T,tle' Dr,lhngManagerORIGINAlDate 1-8-98 r FOR COMMISSION USE ONLY Conditions of approval Not~fy Commission so representabve may w~tness IApproval No_~ Plug ,ntegr, ty BOP Test Locat,on clearanceI .~'~" ¢--,~,.~ Mechamcal Integrity Test ~ Subsequent form required 10- /'~,~4: Approved by order of the Comm,ss,oner ~'-~ Comm,ssloner Date ///3) il~ Form 10-403 Rev 06/15/88 i Approvecl Cop~, SUBMIT IN TRIPLICATE ,..,,.'~. Retur_n~e_.d ....... / I /,Jlff g ; __ 7' "! UNOCAL ) Tradin( ay Unit Grayling 9 Water Injector Injection Test Procedure Revised 1/8/98 Revision #2 Objective: Identify if OBM and cuttings can be disposed of in the G-9 Hemlock 1, 2, 3, 4, 5, 6, 7, Benches. A simulated injection test will be performed by pumping a slurry consisting of the following: Filtered Inlet Water (FIW), Durogel (Bentonite), and Sluggits (CaCO3). The Sluggits is being used to simulate OBM cuttings. I. Equipment Rig-up; Wellhead and Casing Pressure Test: 1. Call-out Cameron wellhead personnel. 2. Document the pressures of all annuli. 3. Pressure test hanger neck seals to 250/5,000 psi using Cameron's test pump. 4. Pressure test hanger body seals to 250/5,000 psi. 5. Call-out 1 pallet of Durogel and 1 pallet of Sluggits (CaCO3) from M-I Drillings Fluids. 6. Mobilize Dowell personnel. 7. Hole pre-job safety meeting with appropriate personnel. . RU Dowell's 5,000 psi chicksans, from the cementing lines to the G-9 tubing by casing annulus. . RU chart recorder on casing for pressure test. Leave the recorder rigged up on the annulus so that it can be utilized for step-rate test 10. RU to FIW to Dowells' cement pumps. 11. Following UNOCAL's Lock-out/Tag-out procedures, close the wing valve and master valve. 12. Mix-up a 50 BBLS ofDurogel ~ 20 PPB. Shear slurry thoroughly. 13. Notify all platform personnel of pressure test and clear appropriate areas of people during pressure test and pumping. 14. Pressure test surface lines to 250/5,000 psi with FIW for 10 minutes. Walk-all lines and verify their pressure integrity. 15. Fill the casing and pressure test casing to 2,500 psi for 30 minutes with FIW. Note: Do not exceed 2,500 psi on the casing. Monitor tubing and 9-5/8" casing pressures during both tests. Document how many BBLS are required to fill annulus. G-9 Inj Test Proc doc Page 1 of 2 01/08/98--3 42 PM UNOCALe Tradin{' ay Unit Grayling 9 Water Injector Injection Test Procedure Revised 1/8/98 Revision #2 16. Bleed off annulus pressure and leave 500 psi. Document how many BBLS are bleed off. II. Step-Rate Injection Test: 1. RU chicksans to the G-9 swab valve. 2. Ensure Dowell has a chart recorder for the tubing and their PACR is operational. 3. Open swab valve, and pressure test surface lines to 250/5,000 psi. Walk-all lines and verify their pressure integrity. . Perform a step-rate injection test as per the following table. Ensure a stable injection pressure is achieved before increasing the injection rate. ~ Note: Do not exceed a maximum injection pressure of 4,500 psi. Volume Injection Rate Tubing Casing Fluid Description (BBLS) (BBL/Min) Pressure Pressure 60 1.0 FIW 120 2.0 FIW 180 3.0 FIW 240 4.0 FIW 300 5.0 FIW 50 3.0 Slurry l: 20 PPB Durogel 275 3.0 FIW 50 3.0 Slurry 2: 20 PPB Durogel and 1 sx/BBL Sluggits 100 3.0 FIW 50 3.0 Slurry 3: 20 PPB Durogel and 1 sx/BBL Sluggits 500 6.0 FIW using I~ 6 5' l~l.~ waterflood pumps Bleed off Monitor bleed off injection pressure pressures. 5. Record the final tubing and casing annulus pressures. 6. Isolate and secure the well. G-9 Inj Test Proc doc Page 2 of 2 01/08/98--3 42 PM 16" @ 62,5' @ 3044' 7" TIED BACK TO SURF 7" TOL @ 9-5/8" @ 10555' 10287' 7"L @ 15.328' G IB ! II Al KE~,,~'~IGAT0-00* B) Cjd~E:IGIfTlJBZIGffAHGEIAT 4%.40' .D) X3o3/8=, &%4, 1-00 CASZIG AT 3044' ~3 ~S/8', 404, 43054, 470, N-IQ, ~AT X0287' ~ DETAZL 4.X/2°, 3.2.G4, 1-80, TE-99 COATED, USS ~KP BITT~, TT,.C 'PA'IS' SC C::PLGS pERFOKATXOI Btu.coRD mm mamllameemmll 7/32./68 8/03/68 9/08/72 X4&&0*-14&90* 2.4595'-%4625; %446000%46%5 %473&*-%4740' %4808*-X48%8* %4900'-%49%0' 14950'02.$0S0' %4840*o%4930' 2 2./29/82' %/30/8:2 2./33./8:2 %.:~785*-%4840* %44&0*-%452.5' 7/3.6/8g %4460'-%45X$' 2.4S35'-X4648' 3.473.0 '-%47S3' 3.4753'-%4930' 2.4960* -%5072' 3.5076'-3.53.75' p~:Rf'ORATED X~ S ~ ; , 3.4535'-3.468S' '"-~. ~-- ,,~ ' %4685'-3.4690' ."~/.t/A.~ 14950° o3.5175 ' WELL TBUS C-9 INJECTOR COMPLETION ( 7-20-89 ) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) OPE:~ FOR OP~ FOR OP~ ~R X~X~ o~ ~R oP~ ~R X~Z~ oP~ ~R oP~ ~R X~E~X~ oP~ ~R OP~ ~R XH~O~ OP~ ~R Z~XOR 07~ ~ Z~~ OP~ ~R X~JE~Z~ op~ FOR OP~ ~R X~X~ OP~ ~R OP~ ~R OP~ ~R X~~ 0~ ~R X~~ OP~ ~R X~~ DRAWN: DAC SCALE: NONE DATE' 10- 15-89 ~ UNION 0IL COHPANY OF~~RN~ -- mo OPERATOR .~: ~mm,~ TRADING BAY UNIT STATE G-D, o, ~ , -- WELL ~ ~z -- ~,--~z FIELD HC ~' ~ ~ ~ rO ~ ~_.~~'~z. COUNt.,, ,, Z > O Z L~ATION C0 N D ~O~ .~O ~ O ~~,~ g ~c 29 Twp. 9,N .... Pge. ,1~.. Perma~nt~m~ PRODUCT I ON,, DECK , Elev.67'HLLS Elev.: RT. ~HS~ [~ ~r~ From R T, Drilli,~ ~sur~d Fr~ ...... RT , , ,~ G.L. , , , ,, , ,, , , , ,, , ~ ..... 7-28-68 :Ty~ Drm F~uU HUD Run N~." ' 0 N E , Fluid Level . F U L L ~P~--'Driller' 1~281 ....Max. R~." TemP. 214 '°F ' ~-- L~ge~ ,1 5278 Est. Ce~nt Top 1~7~0 ~, L~ Inte~al 1 5270 Equip. ~L~ation C-2~2 J .ALASKA Top L~ Inte~al 1 o~ .ol. S~z' ~ING REC. Size Wf/'Ft Grade TY~ Joint - Top Bo. om SUdace Sking g~" f0'-~'~-~7~N~OP & SEALLOCK SURFACE 10552 Prin. String - _ Pr~. String Liner ,, 7" , ,2~,,= N-80 BUTTRESS ,10287 15281, - PRIORY C~M'ENTING DATA , , , , STRING sUrface Protection Production Liner V01. of cement ~00 S , 'T~ of cement CLASS ' Addit[ve .... C F R - 2 ." ,. , , -Retarder Wafer Io~ ' '' TYpe fluid in csg. MUD Fluid ~. 7 5~ I II I_ I II I m 0 0 mmm April 16, 1990 ~ Rec~an Alaska Oil & Gas Conservation co~ission 3001 Porcupine Dr. A~chorage, AK 99504 At,n: 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, a~ S .~~u~' ~''~ G sh Regional Drilling Manager GSB / lew GRAYLING DISTANCE & DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL 2,502,352.30 212,272.70 1804 LEG #3: LAT = 60o50' 22.569" LONG =151°36' 46.519" 1 2 3 4 5 6 7 8 9 l0 ll 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 1810 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 212,277.68 G-36 1800 2,502,345.80 212,273.75 G-34 & RD 1798 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G-33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 LEG #4: LAT = 60°50' 22.832" LONG =151°36' 48. 042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 2O 21 22 23 24 2,502,374.34 212,196.66 G-14A 1825 2,502,376.65 212,192.79 G-19 1827 2,502,380.90 212,191.32 G- 1 3 1831 2,502,385.11 212,192.92 G-15 1835 2,502,387.30 21 2,196.85 G- 5 1838 2,502,386.45 212,201.28 1837 2,502,382.96 212,204.12 G-3 1833 2,502,378.46 212,204.05 G-2 1829 2,502,375.05 212,201.11 G-11 1825 2,502,378.50 212,198.27 G-lO 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 LEG ~/1: LAT -- 60°50' 23.575" LONG =151°36' 47.505" LEG #2: LAT = 60°50' 23.313" LONG --151°36' 45. 982" 2,502,455.60 212,226.40 1906 (Reserved for Compressors) 2,502,427. l0 212,301.20 1880 37 38 39 40 41 42 43 44 46 47 48 2,502,421.45 2,502,424.94 2.502,429.45 2,502,432.85 2,502,433.57 2,502,431.26 2.502,42?.00 2,502,422.80 2~502,420.60 ..... 2,502,425.63 2,502,429.40 2,502,426.27 FEL 1409 1413 1415 1415 1412 1408 1404 1402 1404 1408 1411 1409 1407 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 212,297.82 G-12, RD & 2 1874 1386 212,294.98 G-31 1878 1389 212,295.05 G-4 1882 1 389 212,297.99 G-1 1886 1386 212,302.44 G-9 1886 1 382 212,306.31 G-18 1884 1378 212,307.78 G-14 1880 1376 212,306.18 ...... G-30 .... 1876 _1378 .... 212,302.25 G-8 & RD 1874 1382 212,299.39 G-6 1879 1 385 212,300.83 G-32 1882 1383 212,303.38 G-16 1879 1 381 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI Operations pedormed Operation shutdown __ Sbmulate __ Plugging __ Pull tubIng __ Alter camng __ Repair well __ %nz~ne~ll Company of California (UN~ Nam of D er ~ ~peofWell Development ~_ / Exploratory __ Addr~.So. Box 190247, ~ch, Ak., 99519-044? Strabgrapmc__ / Serwce __ Perforate ~ Other 6 DS~r~§le~o~~ K~L 4 Locabon0fwellatsudace Grayling Platform, Leg 2, Conductor 40 1886' N, 1382' W f/SE cot., Sec. 29, T9N, R13W, S.M. At top of productive interval 2693' N, 3468' E f/SW cot., Sec. 27, TgN, R13W, S.N. At effect, ve depth 2463'N, 3880' E f/SW cot., Sec. 27, T9N, R13W, S.M. At total depth 2406' N, 3969' E f/SW cot., Sec. 27, T9N, R13W, S.M. 7 Un~9~d~~eUn£t feet 8 Well numb~ fw 9 PermIt number/approval number 68-16 10 APl number 50-- 733-20098 11 F~eld/Pool McArthur River Field 12. Present well condition summary Total depth measured true vertical 15,328 · feet 10,372' feet Plugs (measured) Effecbve depth measured true vertical 15,208 · feet 10,282 · feet Junk(measured) Casing Structural Conductor Surface Intermediate Production Liner Perforabon depth ~ngth 369' 623' 3044' 10555' Size 26" 16" 13-3/8" 9-5/8" Cemented Driven 1300sx 2300sx 4200sx 15328' 7" 1150sx measured true vertical Uppermost 14460' Lowermost 15175' Uppermost 9724' Lowermost 10259' Measureddepth 369' 623' 3044' 10555' 15328' True vertical depth 369' 620' 2394' 7162' 10372' Tublng(size. grade, an~m~u.re~d~!~#, N-80 (internal coated w/TK-99)@ 14245' 3 1/2 ", 9.2#, N-80 (internal coated w/TK-99) @ 14318' Packers and SSSV (type and measured d~t~s "BWD" permanent packer @ 14247 ' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment descnpbon including volumes used and hnal pressure DEC2019 9 Alas Oil & Gas Cons. 14. Pnor to well operation Subsequent to operation Representabve Daily Average ProductIon or Injecbon Data ~lm~u~a~= Od-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Injecting 8000 BWPD 3100 psi 3100 psi Injecting 10676 BWPD 800 psi 3100 psi 15. Attachments Cop~es of Logs and Surveys run __ Dady Repo~ of Well Operations __ 16 Status of well class~flcabon as: O~1 __ Gas __ Suspended __ 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Service S~gned <~D.' ~obe~~t~ I~)Tltle Form 10-404 Rev 06/15/88 Environmental Enginee~Date SUBMIT IN DUPLICATE Baroid Drilling Fluids, Inc. July 26, 1989 Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: Workover Fluids Recap G-9 Workover (Grayling) Dear Mr. Chudanov: Attached is the workover fluids recap for the above referenced wel 1. Please note the following comments as they apply: 1. G-9 was an injector worked-over with a 63+ pcf FIW system. 2. Brine loss to well during workover - 1,044 barrels. 3. No overboard discharge occurred. 4. Material usage limited to 5 sacks HEC for high viscosity sweeps. Please refer to the recap for specific details. If additional information is required, please advise. Very truly yours, BAROID DRILLING FLUIDS, INC. d. G. Rose Di stri ct Engineer cc: Bush/Neve' Ri g Copy File Attachment 2000 West Int'l. Airport Rd., Suite A-10 (99502) · P.O. Box 102492 · Anchorage, Alaska 99510 (907) 248-3511 · Fax (907) 248-5390 Baroid Petroleum Services COMPANY Unocal 0il & Gas Division STATE Alaska CASING PROGRAM 13 3/8mch a, 3044 ft WELL G-9 Workover COUNTY Kenai 9 5/81nch at 10553 ft. CONTRACTOR Grayling Platform LOCATION Cook Inlet SEC TWP RNG 7 Inch at 15326 ft. STOCKPOINT Rig Tenders Dock DATE 07/19/89 BAROIDENGINEER Kerr, Redford TOTALDEPTH 15,208 ft DATE DEPTH /VEIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CRC pH FILTRATION ANALYSIS feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake Sohds Oil Water % Mud Strip ~ Pm Pfl p,ip~ Cl CA REMARKS AND TREATMENT 19 8 9 __°F _°F 10 m~n APl ~°F 32nds % % % me/mt Meter O Mf ppm ppm (See Operations Sheet) 7-8 15208 63+ FILrERE) IN.ET WATER WITH 1% RESIDUAL KC1 FiROM PREVIOUS JOB8.0 17000 Perf tb.q @ 1~95 7-9 15208 63+ FIW WIT~ TRICE' OF <C1 8.0 15500 Nipple up s~_ 7-10 15208 63+ FIW WIT~ TR~CE OF <C1 8.0 15000 Fish for tub,,,q 7-11 15208 63+ FIW WIT~ TR~CE OF <C1 7.5 14500 Recover all but 2000' of tbg 7-12 15208 63.5 FIW WIT~ TR~CE OF <C1 TR 7.5 15000 Recover tubinq 7-13 14973 63.5 FIW WIT~ TR~CE OF <C1 TR 7.5 15000 Recover packer 7-14 15208 63.5 FIW WIT~ TR~CE OF (C1 TR 7.5 16000 Run csg scraper 7-15 15208 63.5 FIW WIT~ TR~CE OF <C1 TR 7.5 15000 Test casing 7-16 15208 63.5 NEW FIW SYSTEM 7.5 15000 Displace system 7-17 15208 63.5 NEW FIW SYSTEM 7.5 15000 Sei; packer 7-18 15208 63.5 NEW FIW SYSTEM 7.5 15000 Run 4~" tubing 7-19 15208 63.5 NEW FIW SYSTEM 7.5 15000 Complete workov( COST COST COST MATERIAL AMOUNT $ MATERIAL AMOUNT $ MATERIAL AMOUNT ~ ,. Baravis 5 677.90 Workover Ad~litives 796.7i' Caustic i 31.04 Tech. Servi :e 12 4~860.00 NIII Baroid Sapp i 87.77 Days@ $405/ Day/Man mm Petroleum Services Rework Char~'es 108.00 Delivery Ch~ r.(]es 55.00 Kenai Borou( h Tax 20.00 2 @ }10.00 ~iach MUD MATERIALS Used (Total) DRILLING MUD RECORD TOTA~COS~ 5,839.71 1 PRINTED IN U $ A Unocal Oil & Gas Division INVENTORY G-9 Workover Beginning Inventory Received Baravis 30 0 Barazan 10 0 CaC1 35 0 2 Caustic 4 0 Liteplug-R 66 0 Liteplug-F 42 0 Li tepl ug-X 80 0 Litesal 40 0 KC1 71 0 Polytec-S 5 0 Salt 694 0 SDI Defoam 4 0 Sapp 2 0 EZ Mud 0 20 Used Ending Inventory 25 10 35 3 66 42 80 40 71 5 694 4 1 20 Order Document Numbers: Charges- Q27017 Q27019 Q27025 Q27034 Credi ts: Q27026 Q27036 Q27038 Amount: $21,431.56 14,632.12 2,053.00 4,870.00 Total Charges $ 5,138.40 15,285.10 16,723.47 Total Credits RECEIVED mska OJ] & Anct orage $42,986.68 $37,146.97 Total Well Cost - $5,839.71 OPERATIONS · Unocal Oil & Gas Division G-9 Workover Date 7-7-89 7-8 7-9 7-10 7-11 7-12 7-13 7-14 7-15 Depth, Ft. Tour Start operations on G-9 @ 0700 hours, move rig and rig up lines, perf tubing @ 13,950' with Schlumberger, rig down .Schlumberger Circ hole volume (870 barrels) to production (unfortuantely, we were circulating through holes right near the top of the tubing instead of through our new tubing perfs), nipple down tree and nipple up BOP stack, test BOP's etc., (pulled tubing hanqer and 910' of tubinq~ test BOP's a.qain and stuck test plug Nipple down stuck~ change out spool, test stack, RIH with overshot and get on fish, rig up Schlumber~)er, but couldn't get wireline tools thru top of fish, blind backoff Recovered 775' of 3½" tubing from blind backoff, dress overshot and attempt to latch fish, no go, POH and redress overshot, latch fish @ 1691', rig up Schlumberger, no go with the wireline tool, perform blind back off and CO 463' of 3½" tubing, redress overshot and latch fish @ 2196', blind back off and recover 267' more tubing, TIH and latch fish @ 2423', POH with all but last 2000' of tubing. L/D 3½" tubing, P/U and RIH w/fishing tools, circulate hole and latch onto fish @ 12,063' tubing, plugged, could not circulate, POH L/D 109 joints 3½" tubing, P/U PMRT and RIH. CBU and work pipe on top of fish/packer, tubing fish @ 14,330', mill on packer and pull packer loose, circulate hi vis 25 barrels sweep, POH, L/D PMRT and packer, P/U 6" bit and 7" casing scraper, RIH to 14,973', CBU and pump 50 bbl hi vis sweep. POH, slowly w/high drag bit pluqqed~ could not circulate, M/U float sub and junk basket and RIH w/RR #1, ream 14,973' to 15~208'~ circ and clean hole. POH and P/U RTTS, RIH and spot RTTS @ 14,400', test csg @ 3000 psi for 30 minute test, OK, POH, P/U RR #3-1 and casing scraper, RIH and CBU for displacement. Circulate and displace system w/fresh FIW, displace old system to beach via production, displace until system reads 34 MTU, POH and' L/D bit and scraper, P/U Vann guns and RTTS & RIF DQte Depth, Ft. Tour 7-16 7-17 7-18 7-19 OPERATIONS · Page 2 Unocal Oil & Gas Division G-9 Workover Run correlation log and set packer, fire perf guns, reverse out DP, free packer and circulate, CBU thru choke, open well and CBU, observe well and POH, P/U casing scraper. RIH w/casing scraper, clean to bottom and CBU, POH, experiencing high fluid loss, P/U packer, RIH w/same and set packer, Poll Test BOE, P/U casers and run 4½" tubing Finish running 4½" tubing, displace annulus w/FIW and 1% Nalco 3900, complete workover BIT RECORD IOUNTY Cook Inlet ~ONTRACTOR ~ol Arctic Alaska___ ;PUD ~ T.D.__. Size ITOOL .~OINTS ZLL PIPE IFIELD McArthur River TRIGNO. ISTATE AK LINER ION ~OWNSHIP ~RATOR Unocal ~[PIJMP NO. 2 I RANGE LINER UMP OCATION ~~-~OOLPUSHER POWER IWELL NO. G-9 YPE MUD Type O.D. NUMBER DRILL COLLARS O.D. I.D. LENGTH DRAWWORKS POWER SIZE MAKE TYPE 1 6" SEC S33F JET 32nd DEPTH IN SERIAL OUT FEET HOUR FT/HR 385448 15208' 235 3 ACCUM WT. PUMP SPM DRLG 1000 pUMP OPER- HRS LBS R P M PRESS PUMP ~ ~ 3 20 40 MUD DULL. COND. WT VIS WL ~ ~ G OTHER 2 2 1 FORMATIONS REMARKS cLo Bit 6" SEC S33F 385448 Scraper run 6" SEC S33F 385448 Scraper run ~3 6" SEC S33F 385448 Scraper run ( NAME: Trading Bay Unit IDCATIC~: Grayling Platfo=m- }~nai, Alaska CAS]I~: 7" 29 ppf N-80 R£CEIVE ".SSk; Oil & ~ Oo, s, Co,mi Ancl~otage TU~IN~: 4-1/2" 12.6 ppf Tuboscope ~S BTC x 3-1/2" 9.2 ppf ~ ms mu N-80 n~ ~9 NO: 431/1011/02/89 July 19, 1989 (907) 283-7531 I-D- O.D. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. K.B. 3 · 90" 11.0" PUp Joint - 4-1/2" 12.6 ppf 3.95" 4.5" Pup Joint - 4-1/2" 12.6 ppf 3.95" 5.0" Four F~undred and Seventy-Nine (479) Joi~ts of ~ 4-1/2" 12.6 ppf 3.95" 5.0" Otis "XA" Sliding Side Door (P/N 121 ~ 126) 3 · 813" 5.65" One (1) Joint of Tubing 4-1/2" 12.6 ppf 3.95" 5.0" 4-1/2" ~S Impruved Buttress x 3-1/2" ~S Improved ~ Box x Box 41.40' .70' 2.21' 15.03' 14151.69 ' Otis Str. Slot Seal Assembly * A. Str. Slot Locator (P/N 212 S 40000-a) B. Seal Assembly (P/N 212 MSN 40000-a) ¢. Extension (P/N 212 X 40000-a) D. Seal Assembly (P/N 212 MSN 40000-a) E. Extension (P/N 212 X 40000-a) F. Seal Assembly (P/N 212 ~N 4000~a) G. Seal Assembly (P/N 212 M~ 4000~a) 4.48' ;~laptor - 3-1/2" NU Box x 3-1/2" BTC Pin * 29.82' One (1) Joint of Tubing 3-1/2" 9.2 p[Df W/Special ctearance 2 · 99" 5.0" 2 · 02 ' Otis '~' Selective Ianding Nipple (P/N 11 X 27560-A) 9.44' 2.99" 4.47" (1.20') 2.97" 4.04" (1.04') 2.97" 3.96" (2.04') 2.97" 4.04" (1.04') 2.97" 3.96" (2.04 ' ) 2.97" 4.04" (1.04') 2.97" 4.04" (1.04') One (1) Joint of Tubing 3-1/2" mu Pin W/Special ctearance coup].ing 2.44" 3.8" .78' 2.99" 3.86" 27.23' 2 · 75" 3 · 86" 2 · 02 ' 2.99" 3.86" 2g · 66' -0- 41.40' 42.10' 44.31' 59.34' 14,211.03' 14,215.51' 14,245.33' 14,247.35' 14,256.79' 14,257.57' 14,284.80' 14,286.82' NO: 431/1011/02/89 July 19, 1989 14. Otis Mule Shoe Re-Entry Guide (P/N 212 M 3) mu of Tubing Ta~ * Internal Plastic Coated W/TK69 2.99" O.Do 3.95" .90' PAGE2 14,315.48' 14,316.38' Packer Set on ~rill Pipe w~ulic setting Tool 7" 26-32 LB (P/N 212 ~D 70400-A) B. Otis Seal Bore Extension (P/N 212 C 7060) Bottom Of Packer arn Seal Bore Extension ** Drill Pipe Measuremant OrD. 5.88" 5.05" 3.93' 7.71' of Packer 14,240.00' ** 14,243.93' 14,251.64' --10 --11 --12 --13 --14 UNOCAL GRAYLING PLATFORM WELL#G- 9 SALTWATER /_NJECT ION 7/20/89 Replaced DCB Tubing Spool With New DCB Tubing Spool--New Tubing Hanger & Saltwater Tree--Tubing Hanger has 4½" EUE Top Threads x 4½" Tubuscope US Improved Buttress Bottom--1/8Control Line prep "EUE Lift Threads Inside " 51 FL CIW ltwater 4" 5k FL DCBS-N Ti, Pins Willi~ 2" 5k NX-Pr ep C IW-WF ×-Prep [..~haff er KD " 3k R~-57 1vo 13 3/8" 9 5/8" 4½" I STATE OF ALASKA it~ A oKA OIL AND GAS CONSERVATION COMM ,.,iON APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casIng __ Repair well __ Plugging __ Time extension ~ Sbmulate __ Change approved program ~ Pull tubing ~ Vanance ~ Perforate ~ Other ~ 2. Name of Operator ! 5. Type of Well Union 0il Company of California (UN~CAL) Dev~.oprnent~ ! Exploratory ~ 3 Address ........ 9 0A47 Strat~graph~c P.O. BOX 190247, Ancn, PK., ~D.L-1 Serv,ce-~- 4 Locabon of well at sudace 8 Well number Grayling Platform. Leg 2, CoQductor 40 188~' N, 1382' W f/SE cor., bec. 29, T9N, R13W, S.M. G-9 At top of productive ~nterval 2693' N & 3468' E f/SW cot., Sec. 27, TgN, R13W, S.M. At effecbve depth 2463' N & 3880' E f/SW cot., Sec. 27, TgN, R13W, S.M. At total depth 2406' N & 3969' E f/SW cor., Sec. 27, T9N, R13W, S.M. 6 Datum elevabon (DF or KB) 99' KB above MSL feet 7 U r~a~.~eunit 9 Permit number 10. APl number 50-- 733-20098 11 F~eld/Pool HcArthur River Field 12 Present well cond~bon summary Total depth measured true verbcal Effective depth measured true verbcal Casing Length Structural 369 ' Conductor 623 ' Surface 3044 ' I ntermed,ate 10555 ' Producbon Liner 15328' Perforabon depth: measured true verbcal 15328' feet 10372' feet 15175' 10259' ~et ~et Plugs (measured) Junk (measured) RECEIVED Alaska 0il & Gas Cons. Ca'nmissi0n S,ze Cemented Measuredde~th Anchora(~even,caldepth 26" Driven 369' 369' 16" 1300sx 623' 620' 13-3/8" 2300sx 3044' 2394' 9-5/8" 4200sx 10555' 7162' 7" ll50sx 15328' 10372' See attached Tubing (s,ze, grade, and measured depth) 4-1/2", 12.61~, N-80 ~ 10075'; 3-1/2", 9.2t~, N-80 ~ 144.= Packers and SSSV (type and measured depth) Baker "F-i" Perm Pkr ~ 14422' 13 Attachments Descnpt~on summary of proposal __ Detaded operabons program __ BOP sketch __ 14 Esbmated date for commencing operation 115. Status of well class~flcabon as' May 19, 1989 16 If proposal was verbally approved Od ~ Gas __ Suspended __ Name of approver Date approved Service INJECTIO[~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge %~d ~/,~,~ Roy D. Roberts Title Environmental Engineer Date FOR COMMISSION USE ONLY 4.121189 Conditions of approval Notify Commission so representative may witness Plug mtegnty ~ BOPxTest Mechanical Integrity Test.x. Subsequent form required 10- · \ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 IApproval No Approved Copy Returned -- Commissioner Date SUBMIT IN TRIPLICATE Bench G-9 Perforation Record (Hemlock) MD 14,460' - 14,515' 14,535' - 14,648' 14,648' - 14,685' 14,710' - 14,753 14,75N' - 14,9N0' 14,960' - 15,072' 15,076' - 15,175' TVD 9,724' - 9,766' 9,781' - 9,868' 9,868' - 9,896' 9,915' - 9,947' 9,947' - 10,078' 10,100' - 10,183' 10,185' - 10,258' O019n 1) 2) 4) 5) 6) 7) 8) 9) lO) 11) 12) GRAYLING PLATFORM G-9 WORKOVER PROCEDURE Move Rig #54 over TBUS G-9, Leg #2, Conductor #41. Kill well. Install BPVs, remove tree, install and test BOPE. Puli and lay down 4-1/2" x 3-1/2" single completion. Mill over and recover Baker F-1 packer and tall assembly. Packer set at 14300' DIL. Clean out to 15,175' DIL ETD with 6" blt and 7" casing scraper. Run casing inspection log from TD to surface. Pressure test 7" liner and 9-5/8" casing. Reperforate Hemlock benches i through 6 as directed. Current perforations are as follows: Bench 1 14,460' - 14,515' DIL (55') Bench 2 14,535' - 14,648' OIL (113') Bench 3 14,648' - 14,685' DIL (37') Bench 3 14,710' - 14,753' DIL (43') Bench 4 14,753' - 14,930' DIL (177') Bench 5 14,960' - 15,072' DIL (112') Bench 6 15,076' - 15,175' DIL (99') Perforate with tubing conveyed guns at 4 SPF. Run single 4-1/2" completion assembly. Remove BOPE and install single tree. Put well on injection. NOTE: SBHP anticipated to be 4025 PSI RECEIVED ?'~laska Oil & Gas Cons. Ar~chorage O019n 2" KILL LINE WITH (2) 2-5~ V^L¥[S LINE FROM MUD PMP & CEMENT UNIT 12" 3000 PSI ANNULAR BLIND RAMS PIPE RAMS q FLOWLINE 13-5/8" 3M FLANGE ADAPTER 3M x 5M 13-5/8" 5M FLANGE DOUBLE GATE 5M i 13-5/8" 5M FLANGE 4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE PIPE RAMS ',t~ r,t) J CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE RISER [ "'""-I SINGLE GATE 5M 13-5/8" 5M FLANGE 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL 13-5/8" DOPE 5M STACK ALL DRILLING OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL APP'D: GSB SCALE: NONE BATE: ;/~ STATE OF ALASKA COMMI(..,ON AI._~..,KA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon __ Suspend __ Alter casing ~ Repair well __ Change approved program ~ Pull tubing __ Vanance ~ 2 Name of Operator ! 5. Type of Well Development Union Oil Company of California (UN.AL) ExpLoratory 3 Address ! Strat~graph~c ~ P.0. BOX 190247, Anch, Ak., 99519-03t47 Serv,cez,. 4 Location of well at surface Grayling Platform, Leg 2, Conductor 40 1886' N. 1382' W f/SE cot., Sec. 29, T9N, R13W, S.H. At top of productive ~nterval 2693' N & 3468' E f/SW cor., Sec. 27, T9N, R13W, S.H. At effectwe depth 2463' N & 3880' E f/SW cot., Sec. 27, T9N, R13W, S.H. Operatmon shutdown __ Re-enter suspended well __ Plugging ~ Time extension ~ Sbrnulate ~ Perforate __ Other ~._ At total depth 2406' N & 3969' E f/SW cor., Sec. 27, T9N, R13W, S.M. 6 Datum elevabon (DF or KB) 99' KB above MSL 7 Umt or Property name Trading Bay Unit. 8 Well number 12 Present well cond~bon summary Total depth measured true vert~c~ 15328' feet Plugs (measured) 10372' feet Effective depth measured 15175' feet Junk (measured) true vertical 10259' feet Cas, ng Length S~ze Cemented Structural 369' 26" Driven Conductor 623' 16" 1300sx Surface 3044' 13-3/8" 2300SX Intermediate 10555' 9-5/8" 4200SX Production Liner 15328' 7" ll50sx Perforation depth' measured true vertical See attached feet R-9 9 Permit number 68-16 10. APl number 50-- 733-20098 11Reld/Po~ MCArthur River Field Hem]nck RECEIVED APR 1 1.q o Alaska.0il & Gas Cons. Commission Ueasu~e~d~il;h~0rage True vert,cal depth 369 369' 623' 620' 3044' 2394' 10555' 7162' 15328' 10372' Tub,ng (s,ze. grade, and measured depth) 4-1/2", 12.6#, N-80 $ 10075'; 3-1/2", 9.2#, N-80 $ 1445 Packers and SSSV (type and measured depth) Baker "F-I" Perm Pkr $ 14422' 13 A~achments Descnptlon summary of proposal __ Detailed operabons program ~ BOP sketch 14. Esbmated date for commencing operation May 19, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well class~flcabon as 0~1 __ Gas __ Service I-j ecl:ion Suspended __ 17 I hereby c.~rt~fy that the foreg(~g ~s true and correct to the best of my knowledge. v- - Rjby D. Robe.T.Y/~" TItle Environmental Engineer Signed Date /-' FOR COMMISSION USE ONLY 04/14/89 Conditions of approval Notify Commission so representative may witness Plug ~ntegnty ~ BOP Test __ Locabon clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SlGNE0 BY LONNIE C. SMITH Approved Returned Commissioner I Approval No ¢ -- ~ ~ Date o~Z..~,~O ._ ~¢ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bench 6-9 Perforation Record (Hemlock) HD 14,460' - 14,515' 14,535' - 14,648' 14,648' - 14,685' 14,710' - 14,753 14,753' - 14,930' 14,960' - 15,072' 15,076' - 15,175' TVD 9,724' - 9,766' 9,781' - 9,868' 9,868' - 9,896' 9,915' - 9,947' 9,947' - 10,078' 10,100' - 10,183' 10,185' - 10,258' 'Alaska Oil & 6as (:;o~s. 6ommisslor~ O019n GRAYLING PLATFORM WELL G-9 Request for Continued Operation Under the UIC program administered by the AOGCC, Unocal is required to notify the Commission of any injectors that do not conform to the UIC program. This is to notify the Commission that Well G-P, an active Hemlock Injector injecting approximately 5,500 BWPD, demonstrated a tubing leak during recent testing. Work to repair this injector is scheduled sometime during the month of May, 1989. This work is consistent with that presented on November 6, 1987 during the Trading Bay Unit injection review with the Commission. Form D-iOO1-A ET A No. LEASE TRADI~ BAY UNIT STATE WELL NO. G-9 CONTRACTOR PARKER DRLG. CO. FIELD McARTHUR RIVER TYPE UNIT NATIONAL 1320 BEGAN: 1/13/82 COMPLETED: 2/2/82 ELEVATIONS: GROUND 224' R.T. to M.L. PERMIT NO. 68-16 SERIAL NO. ADL 18730 CASING HEAD COMPANY ~INE~R W~-~OFFER-CR~WE_~L-BUm / TUBING HEAD APPROVED [~ ~'~--~.~.,~.~'~,~.,,,~'~.,..~../' ROTARY DRIVE BU~ING 99' to MMLW ,,,.-/ ............... (~ ~SING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS 16" 623 ' 75# 0-55 13 3/8" 3044 ' 61# N-80 9 5/8" 10,555' 40, 43.5 & 47# N-80 & P-110 7" 15,328" 29# N-80 4 1/2" & 3 1/2" 14,409' 12.6# & 9.2# N-80 Cmt'd w/ 1300 sx. Cmt'a w/ 2300 sx. Cmt'd w/ 4200 sx. Liner cmt'd w/ 300 sx - Tied back to surf and cmt'd w/ 850 sx. ABC modifiea couplings. F-1 pkr. set at 14,300' Dil. PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 7/30/68 14,660'-14,690' 15,281' DST #1 Sqz'd w/ 100 sx. 7/31/68 14,5~5'-14,625' 15,281' DST #2 Open for Injection. 8/03/68 14,460'-14,515' 15,281' Injection Open for Injection. 8/03/68 14,535'-14,595' 15,281' Injection Open for Injection. 8/03/68 14,960'-15,175' 15,281' Injection Open for Injection. 8/03/68 15,195'-15,250' 15,281' Injection Open for Injection. 1/09/70 15,195'-15,250' 15,281' Injection Open for Injectzon. 1/09/70 14,960'-15,175' 15,281' Injection Open for Injection. 1/10/YO 14,710'-14,930' 15,281' Injection Open for Injection. 1/lO/70 14,535'-14,685' 15,281' Injection Open for Injection. 1/lO/70 14,460'-14,515' 15,281' Injection Open for Injection. INITIAL PRODUCTION AFTER REPAIR DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS SEP 21. 'i.9B2 N~.sk~ 0'~ & GaS Cons. Oommissio~ Anchorage WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. COMPLETION DATE: 1/28/78 PRODUCING INTERVAL: Injection into Hemlock Benches 1-7. INITIAL PRODUCTION: LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: Tie back 7" casinq to cover casinq leak at 4590'. Form D-lOO1-B LEASE TRADING BAY UNIT STATE COMPLETION DATE DATE E.T.D. UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. 2 WELL NO. G-9 FIELD PARKER DRLG. CO. APPROVED DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS DATE INTERVAL 9/08/72 14,736'-14,746 9/08/72 14,782'-14,792 9/08/72 14,808'-14,818 9/08/72 14,856'-14,866 9/08/72 14,900'-14,910 9/08/72 14,914'-14,924 1/29/82 15,050'-15,170 1/30/82 14,950'-15,050 1/30/82 14,840'-14,930 1/31/82 14,785'-14,840 1/31/82 14,515'-14,460' ETD 15 281 15 281 15 281 15.281 15 281 15.281 15~208 15.208 15.208 15.208 15.208 (Junk) (Junk) (Junk) (Junk) (Junk) REASON PRESENT CONDITION Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Open Open Open Open Open Open Open Open Open Open Open for Injection. for Injection. for Injection. for Injection. for Injection. for Injection. for Injection (Bench 5). for Injection (Bench 5). for Injection (Bench 4). for Injection (Bench 4). for Injection (Bench 1). NOTE: ETD is 15,175' DIL. SEP 2 1 1, 82 A!~ska 0~1 & Gas Cons. Commissio~ Anchorage WELL HEAD ASSENBLY CASING HEAD: Shaffer 12" 3M x 13 3/8" SOW. Type KD. CASING HANGER: Shaffer 12" nominal 9 5/8". Model KD-KS. CASING SPOOL: CIW 12" 3M x 12" 3M "WF" w/ 7" slips and "X" seal. TUBING HEAD: CIW 12" 3W x 10" 5M DC-B. TUBING HANGER: CIW nominal 10" x 4 1/2" EVE up & 4 1/2" buttress down. TUBING HEAD TOP: 10" 5M CIW. Seal type R. ~ASTER VALVES: CIW 4" type "F" Block tree (single) w/ master and swab valve. CHRISTMAS TREE TOP CONN.: 4 1/2" EVE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT STATE WELL NO. G-9 FIELD McARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 1/13/82 15328' TD 15250' ETD 9 5/8" C. 10555' 7" L. 15328', Top ~ 10287' FIW DAILY COST: $ 17,600 ACC COST: $ 17,600 AFE AMT: $1,100,000 2 1/14/82 15~30' TD 15270' ETD 9 5/8" C. 10555' 7" L. 15~28', TOP ~ 10287' FIW DAILY COST: $ 18,590 ACC COST: $ ~6,190 AFE AMI: $1,100,000 ~ 1/15/82 15330' TD 15270' ETD (CMT) 9 5/8" C. 10555' 7" L. 15~28', TOP ~ 10287' FIW DAILY COST: $ 18,778 ACC COST: $ 54,968 AFE AMT: $1,100,000 4 1/16/82 DAILY COST: ACC COST: AFE ANT: 15330' TD 15270' ETD (CMT) 9 5/8" C. 10555' 7" L. 15~28', TOP ~ 10287' 65 PCF 40 SEC $ 62,776 $ 117,744 $1,100,000 Position Rig #54 over conductor #41, leg ~2, well TBUS G-9. Moved tools from Rig #55 to Rig #54. Positioned Rig #54 over TBUS G-9 WO. Installeo rotary table & misc drlg equip. Fin RU over TBUS G-9. RU Myers WL over tbg - WL unit broke down. Re- paired WL unit & opened "XA" sleeve [ 14390'. RD WL unit. CIRC FIW down tbg & up ann. Hao shut-in press of 250 psi on tbg & ann. Blt MW to 65 pcf. Circ weight mud around system. Checked well for flow - well is dead. SEP2 1 "-' '~ Oil & Gas Cons. Commission Anchorag~ UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT STATE WELL NO. G-9 FIELD McARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5 1/17/82 DAILY COST: ACC COST: AFE AMT: 15330' TD 15270' ETD (CMT) 9 5/8" C. 10555' 7" L. 15328', TOP $ 10287' 66 PCF 40 SEC $ 30,293 $ 148,037 $1,100,000 Circ 65 pcf comp fluid to kill well. Installed BPV, removed tree, in- stalled BORE. Tested hyoril to 1500 psi, pipe & blind rams to 3000 psi. RU to pull tbg. Pulled up to 21OM# - weight dropped back to 15OM#. POOH w/ 4 1/2" tbg. Found lge split & washout (l' X 1/2") in tbg. Circ & blt MW to 66 pcf. 6 1/18/82 15330' TD 15278' ETD 9 5/8" C. 10555' 7" L. 15328', top $ 10287' 66 PCF 38 SEC 1/2" & DAILY COST: $ 28,309 ACC COST: $ 176,346 AFE AMT: $1,100,000 7 1/19/82 15330' TD 15226' ETD (JUNK) 9 5/8" C. 10555' 7" L. 15328', TOP ~ 10287' 66 PCF 40 SEC DAILY COST: $ 34,976 ACC COST: $ 211,322 AFE AMT: $1,100,000 8 1/20/82 DAILY COST: ACC COST: AFE AMT: 15330' TD 15162' ETD (TOF) 9 5/8" C. 10555' 7" L. 15328', Top ~ 10287' 66 PCF 38 SEC $ 33,493 $ 244,815 $1,100,000 Continued to POOH & LD tbg. Rec 328 jts of 4 1/2" tbg & 142 jts of 3 1/2" tbg & seal assy. Changed pipe rams f/ 4 1/2" to 5". Repaired cat head & pipe spinner. RIH w/ BO shoe & packer picker while PU 3~" ~ DP. Continued RIH w/ BO shoe on 5" DP. Tagged pkr ~ 14409' DPM. Latched into pkr & began BO pkr. Shoe quit milling w/o pkr being free. Coulo not release f/ pkr. Milled & jarreO on pkr - pkr would not move. Fi- !nally releaseo f/ pkr & POOH. POOH & LD BO shoe. RIH w/ 6" pkr mill & boot basket. Tagged pkr e 14399' Milled on pkr & pushed to 15009'. MilleO & pushed on pkr to 15208' - could not get deeper. POOH - had twisted off in oil jars. Left mill, boot basket, B/S, & por- tion of oil jars in hole. TOF ~ 15162'. RIH w/ 5 3/4" OS w/ 4 5/8" grapple. SEP 2 l A!P. ska Oil & Gas Cons. Commission Anchorag~ UNION OIL COOl'ANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING CAY UNIT STATE WELL NO. G-9 FIELD McARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 1/21/82 15330' TD Attempteo to latch onto fish ~ 15208' ETD (JUNK) 15162'. POOH - no rec. Marks on 9 5/8" C. 10555' grapple indicated it was too small. 7" L. 15328', TOP ~ 10287' RIH w/ 4 3/4" grapple in OS. 66 PCF 38 SEC Latched onto fish ~ 15162' & POOH - rec entire fish. RIH w/ 6" bit on 7" csg scrpr to 15208'. DAILY COST: ACC COST: AFE AMT: 10 1/22/82 $ 22,537 $ 267,352 $1,100,000 15330' TD 15208' ETD (JUNK) 9 5/8" C. 10555' 7" L. 15328', TOP ~ 10287' 66 PCF 38 SEC DAILY COST: $ 46,537 ACC COST: $ 313,889 AFE AMT: $1,100,000 11 1/23/82 DAILY COST: ACC COST: AFE AMT: 15330' TD 14189' ETD (RBP) 9 5/8" C. 10555' 7" L. 15328', TOP ~ 10287' 66 PCF 38 SEC $ 30,060 $ 343,949 $1,100,000 Circ & POOH w/ 7" csg scrpr. RIH w/ 8 1/2" bit on 9 5/8" csg scrpr. Tagged TOL ~ 10320' DPM. Circ & POOH. RU Dresser Atlas & ran Cor- rosion Analysis Tubulars log f/ TOL ~ lO311' WLM to surf. Log showed extreme csg oamage f/ 4350' to 4720' (DV collar ~ 4610'). RD Dresser Atlas & RIH w/ 7" RBR on 7" RTTS. 8IH w/ 7" RBP on 7" RTTS pkr. Set RBP ~ 14420'. Attempted to test RBP - would not test. Retrieved RBP & POOH. RIH w/ 2nd RBP on RTTS pkr. Bet RBP ~ 14189' & tested to 3000 ~si - ok. Set RTTS ~ 12727' & testeo 7" liner to 3000 psi - ok. Reset RTTS ~ 12634' & tested 7" liner to 4000 psi - ok. Reset RTTS ~ 12614' & tested 7" liner - ok. Reset RTTS ~ 11591' & tested 7" liner to 4000 psi - ok. Reset RTTS ~ 10794' & tested 7" liner - ok. POOH w/ RTTS. RIH w/ 9 5/8" RTTS pkr & set 8 10243'. Tested top of 7" liner & liner lap to 4000 psi - ok. R £E!VED P 2 1 is8 Gas Cons. ¢omm!ssion Aqchorag9 UNION OIL CO,ANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY UNIT STATE WELL NO. G-9 S~EET D PAGE NO. FIELD NcARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12 1/24/82 15330' TD POOH w/ 9 5/8" RTTS pkr. RIH w/ 7" 10720' ETD (RBR) RTTS. Latched onto RBR 8 14189' & 9 5/8" C. 10555' reset ~ 14400'. Set RTTS ~ 14185' & 7" L. 15328', TOP ~ 10287' testeO 7" liner to 4000 psi - ok. 66 RCF 38 SEC Rec RBR & POOH. RIH w/ BOT 6 5/16" OD liner top dressing mill. Dressed $ 36,693 tie back receptical in TIW hanger f/ $ 380,642 10320' to 10322.5' DPM. POOH. RIH w/ 7" RBR & set ~ 10720'. Spotted $1,100,O00 12 sxs sd on top of R8R. 15330' TD 10669' ETD (Sd) 9 5/8" C. 10555' 7" L. 15328', TOP ~ 10287' 66 PCF 38 SEC $ 30,036 $ 410,678 DAILY COST: ACC COST: AFE AMT: 13 1/25/82 DAILY COST: ACC COST: AFE AMT: $1,100,000 14 1/26/82 DAILY COST: ACC COST: AFE AMT: 15330' TD 10276' ETD (FC) 9 5/8" C. 10555' 7" C. 15328', TB 6 10320' 66 PCF 38 SEC $ 372,239 $ 782,917 $1,100,000 Wait on sd to settle. Tagged top of so ~ 10669'. POOH. RIH w/ 9 5/8" RBP & set ~ 1000'. POOH w/ DP. Re- moveo BOPE & tbg hanger, Installed 12" 3M X 12" 3M csg spool. Could not get test on "R" seals, Changed to "x" seal & testeo to 500 psi, Reinstalled BOPEo RIH & retrieved 9 5/8" RBP ~ 1000' RIH W/ 7" BOT tie back seals on ~" DP. Set seals in receptical ~ 10322' & tested to 1000 psi - ok. POOH laying down DR. Completed LD 5" DP. Installed 7" rams in BORE. RU & ran 10320' (250 ~jts) of 7" 29# N-80 butt csg w/ BOT :tie-back seal nipple & FC. Landed ~in tie-back receptacle w/ FC ~ 10276'. Tested tie back to 1000 psi - ok. PU & broke circ. Cmtd 7" csg w/ 850 sxs cl "G" w/ 1% gel, 25 gal/lO0 sxs D-45L, 13 gal/lO0 sxs R-12L, 2 gal/lO0 sxs D-6L. Displ w/ FIW to bump plug w/ 3000 psi. Bled press back to 2000 psi & landed csg into receptable. CIP ~ 21:00 hrs. WOC. S EP 2 ~,,,~f<a 0~1 & Ga~ Cons. Co,'~mission ': ~c,horag9 ( UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING 8AY UNIT STATE WELL NO. G-9 FIELD McARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 1/27/82 15330' TD Held press on cmt job. Landed 7" 10689' ETD (SD) csg in slips w/ lO0,O00#. Cut off 9 5/8" C. 10555' 7" & installed DCB spool - tested to 7" L. 15328', T8 ~ 10320' 3000 psi. Installed BOPE. Changed 66 RCF 38 SEC pipe rams to 3 1/2". RIH w/ 6" bit while RU 3 1/2" DP. Tagged wiper plug ~ 10272'. Press tested csg to 2800 psi - ok. Drld out plug & hrd cmt f/ 10276' to 10322'. Drld out shoe. CO cmt stringers f/ 10322' to 10583'. RIH & tagged sd ~ 10660'. Washed sd oown to 10689'. DAILY COST: $ 40,278 ACC COST: $ 823,195 AFE AMT: $1,100,000 16 1/28/82 15330' TD 15208' ETD (JUNK) 9 518" C. 10555' 7" C. 15328', TB ~ 10320' 66 PCF 38 SEC DAILY COST: $ 22,550 ACC COST: $ 845,745 AFE AMT: $1,100,O00 17 1/29/82 15330' TD 15208' TD (DRM) (OUNK) 9 518" C. 10555' 7" C. 15328', TB ~ 10320' FIW DAILY COST: $ 24,332 ACC COST: $ 870,077 AFE AMT: $1,100,000 18 1/30/82 15330' TD 15208' ETD (OUNK) 9 518" C. 10555' 7" C. 15328', TB ~ 10320' FIW DAILY COST: $ 109,450 ACC COST: $ 979,527 AFE AMT: $1,100,000 Circ btms up & tested 7" tie back to 2800 psi - ok. POOH wi 3 112" DP. RIH w/ retrieving tool on 3 1/2" DP. WasheO sd f/ 10689' to 10720'. Latched onto RBP & POOH. RIH w/ 6" bit on 7" csg scraper to 15208'. Circ& changed over to clean FIW. POOH w/ bit & csg scrpr. RU Dresser Atlas & tested lub. RIH wi 30' of 4" OD guns & perf'd Hemlock Bench 5 ~f/ 15170' to 15050' GR-N (4 runs). !Note: ETD ~ 15175' WLM, 15208' DPM. Continued to perf HB #5 fl 15050' to 14960' GR-N (3 runs). Perfed HB ~4 f/ 14930' to 14840' GR-N (3 runs). SEP 2 1 1.':;82 (~!;,¢m Od & 6as Cons. Con~rn!ss~on ,'kpchorag9 LEASE SHEET O PA~E NO. UNION OIL 03MPANY OF CALIFORNIA WELL RECORD TRADING BAY UNIT STATE WELL NO. FIELD McARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 19 1/31/82 15330' TD Continued to perf Hemlock Bench #4 15208' ETD (OUNK) f/ 14840' to 14785' GR-N (2 runs). 9 5/8" C. 10555, Perfed Hemlock Bench ~l f/ 14515' to 7" C. 15328', TB ~ 10320' 14460' GR-N (2 runs). Ran 5.937" OD 66 PCF 38 SEC GR & OB to 14450'. POOH. RIH w/ Baker Model "F-I" prod pkr & set ~ 14300' DIL. POOH & RD WL. RIH w/ 2' of seals on 3 1/2" DP. DAILY COST: ACC COST: AFE AMT: 20 2/1/82 $ 63,484 $1,043,011 $1,100,000 15330' TD 15208' ETD (JUNK) 9 5/8" C. 10555' 7" C. 15328', T8 ~ 10320' 68 RCF 37 SEC DAILY COST: $ 25,263 ACC COST: $1,068,274 AFE AMT: $1,100,000 21 2/2/82 DAILY COST: ACC COST: AFE AMT: 15330' TD 15208' ETD (OUNK) 9 5/8" C. 10555' 7" C. 15328', TB ~ 10320' $ 275,946 $1,344,220 $1,100,000 RIH w/ 2' of seals on 3 1/2" DP. Stabbed into "F-i" pkr ~ 14325' OPM & tested pkr to 1800 psi - ok. Ricked up & displ hole w/ 66 pcf NaCL fluid. POOH LD 3 1/2" DP. Well began to flow & bubble w/ 2000' of pipe laid down. Increased MW to 68 pcf - well stopped flowing. Completed LD 3 1/2" DR. RU & ran 3 1/2" 9.2# N-80 ABC modifieo tbg. Ran 3 1/2" 9.2# N-80 butt tbg w/ ABC modified couplings & 4 1/2" 12.6~ N-80 tbg on top. Stabbed into pkr ~ _~4325' w/ tail ~ 14408'. Tested "F-l" pkr to 2000 psi - ok. RU ~yers WL & set "XN" plug in nipple ~ :14408'. Press tested tbg to 3000 psi - ok. POOH w/ "XN" plug. RD Myers WL. Unstab from pkr & changed ann over to pkr fluid. Spaced out & landed tbg. RetesteO pkr - ok. Removed 80RE. Installed & tested tree to 5000 psi - ok. ReleaseO rig from TBUS G-9 ~ 24:00 hrs 2/2/82. SEP 2 1 IS82 Oil & Gas Cons. Oomm!ss,0n i~choracj9 Form D-iO01-C UNION OIL CO. OF CALIFORNIA RERAIR RECORD SHEET C PAGE NO. 3 LEASE TRADING BAY UNIT STATE COMPLETION DATE 2/02/82 WELL NO. G-9 FIELD McARTHUR RIVER APRROVED DATE E.T.D. DETAILS OF ORERATIONS~ DESCRIRTIONS & RESULTS Ots 1 249 Description Length Top Btm B.O.T. 7" Tie-back Seal Nipple. 4.00' 10,318.00' 10,322.00' 7" 29# N-80 Butt. csg. 40.22' 10,277.72' 10,318.00' 7" BOT Float collar. 2.00' 10,272.72' 10,277.72' 7" 29# N-80 Butt. csg. 10,277.72' -2.00' 10,275.72' 7" cut-off. 42.50' 40.20' -2.00' Top of cut-off 40.20' -0-' 40.20' SEP 2 l Gas Cons. Commission UNION OIL COMPANY OF CALIFORNIA 5~HEET D PAGE NO. WELL RECORD LEASE TRADING BAY UNIT STATE WELL NO. G-9 FIELD McARTHUR RIVER DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3TS 455 NOTE: TUBING DETAIL DESCRIPTION LENGTH BOTTOM 3 1/2" mule shoe. .71' 14,409.36 3 1/2" Otis "XN" Nipple. 1.64' 14,408.65' 3 1/2" 9.2 #N-80 Butt. w/ 61.31' 14,407.01' Mod. ABC Couplings. Baker Seal Assembly. 20.70' 14,345.70' Baker 7" F-1 pkr. Set at 14,300' DIL (14,325' DRM). Locator sub. .45' 14,325.00' 3 1/2" Butt. pup. 5.10 14,324.55' 3 1/2" N-80 Butt. tbg. 30.59 14,319.45' 3 1/2" Otis "XA" Sleeve. 3.95 14,288.86' 3 1/2" N-80 Butt tbg. 13,975.94 14,284.91' 3 1/2" x 4 1/2" Butt X-over. 1.14 308.97' 4 1/2" N-80 Butt tbg. 30.18 307.83' 4 1/2" Otis "XN" Nipple. 1.42 277.65' 4 1/2" N-80 But~ tbg. 212.69' 276.23' 4 1/2 Butt pups (2). 25.04' 63.54' CIW tbg. hanger. 1.00' 38.50' Landed below K.B. 37.50' 37.50' All 3 1/2" tbg fitted with ABC Mod. couplings. TOP 14,408.65' 14,407.01' 14,345.70' 14,325.00' 14,324.55' 14,319.45' 14,288.86' 14,284.91' 308.97' 307.83' 277.65' 276.23' 63.54' 38.50' 37.50' --0-- SEP 2 1 TBUS ~-9 Otis "XN" nipple 276' 623' 16" 75# J-55 8 rnd 4 1/2" x 3 1/2" XO 308' 3044' 13 3/8" 61# J-55 Batt Otis "XA" Sleeve 12285' 7" liner the back 10322' 10555' 9 5/8" 409, 43.5~ & 47# N-80 & P-il0 Hemlock Perfs Baker F-1 pkrw/21' of seals I4,300' B-1 14,460' - 14,515' B-4 1~,785' - 14,930' B-5 14,960'- 15,170' __IEY. t OAI'E Otis "XN" nipple 14,408' Mule shoe 14,408' ,'\r, chor~go ou, w. ~ c;~. G-9 ^~".. Trading Bay Unit s~u o^~ 2-11-82 Well Schematic UNION OIL COMPANY OF CALIFORNIA (~ STATE OF ALASKA Cjr, i ALASKA ,._ AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL I-I OTHER 2 Name of Operator 7 Permit No UNION OIL COHPANY OF CALIFORNIA 68-16 3 Address 8 APl Number RO BOX 6247 ANCHORAGE AK 9~502 50- 733-20098 9. Unit or Lease Name TRADING BAY UNIT 4 Location of Well Cond. 41, Leg 2, 1886'N & 1382'W of SW corner, Section 29, TgN, R13W, SM. 5. Elevation in feet (~nd~cate KB, DF, etc ) RT 99' MSL 6 Lease Designation and Serial No ADL 18730 10. Well Number TBUS G-9 11 Field and Pool McArthur River Field 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF: (Submit in Trlphcate) (Submit m Dupl)cate) Perforate [] Alter Cas,ng [] , Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment D Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ~ (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, ~ncludlng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Completed well as follows: . 2. 4. e · 9. 10. 11. 12. 13. Moved rigiD4 over conductor #41, leg #2, TBUS G-9 & rigged up on 1/13/82. Killed well, installed BRV, removed tree, installed & tested BORE. Rulled & laid down existing completion equipment. Milled over and pushed 7" X 4" Baker model F-1 pkr f/ 14378' DIL to 15208'. Ran corrosion analysis tubulars log f/ lO311' to surface. RIH w/ retrievable bridge plug & retrievable pkr & pressure tested 9 5/8" csg. & 7" liner from 14400' to 10243' - ok. Ran 10320' of 0' 29# N-80 butt csg f/ 10276' to surface. Cmtd w/ 850 sxs cl "G". Tested to 3000 psi - ok. Drilled out sand cmt & sand to 15208' & tested to 2800 psi - ok. Rerfed Hemlock Bench 5 f/ 15170-15050', 14930-14785', & 14515-14460'. Set F-1 production pkr ~ 14325' & tested to 1800 psi - ok. Ran 3 1/2" 9.2# N-80 ABC modified tbg & 4 1/2" 12.6# N-80 tbg. Removed BOPE, installed & tested tree to 5000 psi - ok. Released rig from TBUS G-9 ~ 24:00 hrs 2/2/82. 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge The sp~e b'el;w for ' -u~e Commission Date 3/25/82 Conditions of Approval, if any Approved by. COMMISSIONER By Order of the Commission Date 2 Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" m Duplicate STATE OF ALASKA ~ ALASKACIL AND GAS CONSERVATION C~,,vlMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drllhng well [] Workover operation [] 2 Name of operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 68-16 3 Address 8 APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 733-20098 4 Location of Well 9 Unit or Lease Name at surface TRADING BAY UNTT Conductor 41, Leg #2, 1886'N & 1382'W of SE corner, Sec. 29, TgN, R13W, SN. 5 Elevation ~n feet (~nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No RT 99' IvI.SlI ADL 187.~o 10 Well No TBUS G-9 11 F~eld and Pool NcARTHUR RIVER FIELD For the Month of FEBRUARY , 19 82 i12 Depth at end of month, footage drdled, hsh~ng jobs, d~recUonal drdhng problems, spud date, remarks Released rig ~ 24:00 hrs on 2/2/82. 13 Casing or hner run and quantmes of cement, results of pressure tests None 14 Coring resume and brief descr,ptlon None 15 Logs run and depth where run None 6 DST data, perforating data, shows of H2S, m~scellaneous data None 17 I hereby ce.r.~Lfy that the foregoing ~s true and correct to the best of my knowledge ~/port on this form ~s required for each calendar month regardless of the status of operations, and must be filed in duphcate w~th the Alaska OII and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected. Form 10-404 Submit in duphcate ..,s,, co(' ,ss,o. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS''ra I Drdl~ng well [] 2 Name of operator UN[ON OIL COMPANY OF CALIFORNTA 3 Address 7 Perm,t No 68-16 PO BOX 6247 Workover operation [] ANCHORAGE AK 99502 4 Location of Well at surface Conductor 41, Leg f~2, 1886'N & 1382'W of SE corner, Sec. 29, T9N, R13W, SN. 5 Elevat,on ~n feet (~nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No RT 99' I¢SLI ADL 18777 8 APl N~h~r20098 50- 9 Unit or Lease Name TRADING BAY UNIT 10 Well No. TBUS G-9 11 F~eld and Pool HcARTHUR RIVER FIELD For the Month of JANUARY ,19 82 12 Depth at end of month, footage drdled, fmh~ng jobs, d~r~t~onal drdl~ng problems, spud date, remarks Positioned rig over conductor 1/13/82 Recovered fish from 15162'. 13 Casing or I~ner run and quant~tms of cement, results of pressur9 tests Tested 7" liner to 4000 psi - ok Ran 7" 29# N-80 butt csg f/ 10320 to surf - cmtd w/ 850 sxs cl "G". Tested to 2800 psi - ok. Tested 7" tie back to 2800 psi - ok. 14 Coring resume and brief description None 15 Logs run and depth where run Corrosion analysis tubulars log f/ lO311' to surf 1 6 DST data, perforating data, shows of H2S, m~scellaneous data Perfed 15170-15050' 15050-14960' 14840-14785' 14515-14460' 17 I hereby~C'er;if~y that the foregmng ~s true and correct to the best of my knowledge 2/.1.5/82 ,SIGNE ' . ..... ._ LE__~DRL___________~DIST --SUP___~, DATE NO/T~/eport on th~s form ~s required for each calendar month, regardless of the status of operations, and must be fded ~n duphcate w~th the Alaska O~d Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit ~n duplicate Rev 7-1-80 ' '~, STATE OF ALASKA O(w ALASKA ,L AND GAS CONSERVATION C ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER 2 Name of OPerator 7 Permit No UNION OIL COMPANY OF CALIFORNIA 68-16 3 Addre~o BOX 6247 ANCHORAGE AK 99502 8 APl Number 5o- 133-20098 4 L~at~on of Well Cond. 41, Leg #2, 1886'N & 1382'W of SE Corner, Section 29 T9N, R13W, SM. 5 Elevation ~n feet (~nd~cate KB, DF, etc.) RT 99 MSL 12 Lease Designation and Ser.al No ADL 18730 9. Umt or Lease Name TRADING BAY UNIT 10 Well Number TBUS C-9 11 F~eld and Pool McArthur River Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO: (Submit ~n Tmpl~cate) Perforate ]~] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well ]~] Change Plans [] Repairs Made Pull Tubing ]~1 Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) SUBSEQUENT REPORT OF: (Submit m Duplicate) [] Altemng Casing [] Abandonment [] Other [] 0 [] 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertment dates, mcluding estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) PROCEDURE: 1. Move Rig #54 over conductor #41, Leg #2, TBUS G-9 and rig up. 2. Kill well, install BPV, remove tree, install and test BOPE. 3. Pull and lay down existing completion equipment. 4. Mill over and recover 7" X 4" Baker model F-1 packer @ 14,378' DIL 5. RIH w/ retrievable bridge plug and retrievable pkr and pressure test 9 5/8" csg. If csE does not pressure test, locate leak (possible leak @ +4600'). Tie back 7" to surface if required to isolate leak in 9 5/8". 6. RIH w/ retrievable bridge plug and retrievable pkr and locate leak in 7" csg (temperature log showed possible leak @ 12,650'.). Sqz 7" csg leak. Reperf the following intervals w/ big-hole csg guns. Bench 1 14460-14515' Bench 4 14785-14930' Bench 5 14960-15170' . j that the best of my knowledge 14 I her the/f~ and correct to rego~j~s true:ert~fy DIST DRLG SUPT The spac~yelow for Commission use Condlt~ohs of Approval, ~f any Approved Copy Date 11/25/81 Approvedby BY L0[-~;~l[ [:. SI, tfT~J COMMISSIONER Returned .... By Order of the Commms~on Date,,, Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Tr~phcate and "Subsequent Reports" ~n Duphcate TBUS G-9 Sundry Notice 11/25/81 9. Isolate 7" csg leak w/ pkrs & complete well w/ 3 1/2" tbg w/ special ABC modified couplings. 10. Install BPV's, remove BOPE, install and test tree. 11. Place well on injection. Rotary table (110.60' qbove MLL~O_ · o Tubing Hanger @ 3841' 623' - 16' 75# J-55 8rd cemented to surface '~-----3044' - 13 3/8" 61# J-55 Butt cemented to surface Proposed 7" Liner Tieback to Surface -7" liner top at 10,287' Packers to isolate leak in 7" liner 10,555' - 9 5/8" 40#, 43.5#, 47# NT80 P-110 Seallock-DV @4609 ' RECEIVED NOV 2 5 i98l ?~.!;~.si<~ Oil & Gas Cons. WELL_SCHEMATJLC G-g WO McArthur River Field Proposed 1982 Completion 15,328' Bottom 7" 29# N-80 Buttress $ ~, Lc. Umon O~1 and Gas I~ .~lon Western Region Umon Oil Company of Cahfornla P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 union Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 13 RE: ~ TBUS G-17 -D,~A~T~'-V~, GRAYLING PLATFORM .... s~c TBUS K-23 Dear Mr. Gilbreth- Enclosed for your informtion are two (2) copies each of the Month Reports for the above captioned projects. Sincerely yours, 11 ender Dist. Drlg. Engr. CC: Marathon Oil Co. Atlantic Richfield Co. Chevron USA Getty Oil Co. Amoco Production Co. Phillips Petroleum Co. USGS Harry Lee RECEIVED ~q~n~ No P.--4 ~ B- 1-70 ( STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'I~EE SUBMrr l~ DUI~LI~A~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O.L,,LL [] 0'"'~" [::] 0,," injector NAMe- OF Union Oil Co. of California P. O. BoM §247, Anchorage, AK 99502 4 LOCATION OF WEI.,L Conductor 41, Leg 2' 1886'N & 1382'W from the SE corner. Section 29: T9N, R13W, S.M. APl NUi&{ERICAL CODE 50-133-20098 6 LF..ASE DESiGNA?ION A~D SETRIAL NO ADL 18730 7 IF INDiA],~ AL~Ti~:J~ O]~ TRIBE NAME 8 L.~IT F.~ OR LEASE NAME Trading J~,~y Urlit 9 WELL NO ?BUS G-9 (32-27) 10 . IELD A.ND P~L' OR WILDCAT McA~fh~ ~ vpr-Hpml o~k o~ Section 27, T9N, R13W, S.M. 12 PEP.MIT ~'0 68-16 13 REPORT TOTAL DEPTH AT END OF MONTH CH.A.NGES IN HOLE SIZE, CAqlNG AND C~/IKNTING JOBS INCLUDING DEPTH SET AND VOLUMES USED PF--=tFOHATIONS TESTS .~qD RESULTS FISHING JOP~ JU'~K IN HOLE AND SIDE-TRACKED HOLE A.ND A.NY OTttF_~ SIGNIFICANT ~G1~ IN HOI.~ CONDITIONS 1 1/05/78 15,328'TD 14,437'ETD (perm pkr) 9 5/8" csg @ 10,555' 7" liner @ 10,287-15,328', Commenced operation on G-9 @ 4:01 p.m. 1/05/78. Moved rig over conductor 41 in leg room 2. Loaded 4 1/2" tbg and 4 1/2" x 9 5/8" annulus with FIW and noted free communication between tbg and annulus. Installed BPV and 4 1/2" X-mas tree. 2 1/06/78 3 1/07/78 15,328'TD 14,395' ETD (cmt ret) 9 5/8" csg @ 10,555' 7" liner @ 10,287'-15,328' 15,328~TD 14,395 ' ETD (cmt ret) 9 5/8" csg @ 10,555' 7" liner @ 10,287'-15,328~ Finished removing X-mas tree in additional 5 hrs due to corrosion on studs and hold-down screws. NU 12" 3000 psi BOPE and tested to UOCO specs. Pulled 4 1/2" x 3 1/2" injection tbg. out of perm pkr @ 14,437' w/ 220,000#. Rigged to lay down tbg. but could not make 4 1/2" rental slips hold. Secured replacement slips after 5 hrs when weather cleared for chopper flight, Pulled and LD injection tbg. Found 3 large holes'in 4 1/2" tbg @ approx. 1050' v~/ majority of 4 1/2" tbg. severely scaled up and externally pitted. No coupling leaks or connection problems were found. 3 1/2" tbg. in satisfactory condition as corrosion problems lessened w/ depth, Ran 6" bit on 3 1/2" S-135 & 5" DP to 14,428~ w/o obstruction. Circ. hole clean -14 I hereby ce~y I~hat tl~ /oreg~tng~s true ,,o~~ ~. ~/~1/~~ Dist. Drlg. Supt. ,,~ 2/14/78 ~oT(--~ip*~i-oa ~'~ulred fo~ ~ calendar ~f~ regmrdless of t~e ltofus of opermtioms, mhd musf ~ filed In duplt~le ~if~ oil and gal conservatbn commiflee by the 15~ of the succ~dm9 mn~, ~le~ otherwise d~rected. 1/9/78 1/10/78 tr 'Pooh a~d RU "].L. q~q ~ 3/4" od qaqe rina t ,Junk kasket on !!.L. te 14,~'.,~5'. '~n 7" Baker stat. ret. on U.L. ¢ ~e~ @i"t.3°5' to isolate '4emlock injection nerfs frcm szueeze work. Ran 7" Baker retrievamatic on 3'1/2" x 5" _~P and set ,3kr ~lO,3nl' (!4' inside 7" liner). Pkr. would not hold Moved nkr to iq,35,t' and pressured DP to 12nO Dsi o.k. 7" liner ¢ (PI '3 12 cu.ft./min ~ 17nO osi). Attemnted to !n,£87'-1~,328' pressur? test g 5/t" csg ¢, 7" liner lad to 3500 esi and Pi ~ 1S cu.ft./min ,t lonO psi (apparent hole in o 5/8" csq or 7" lib, er lao leakinq). Moved pkr to 12,gO0' to locate hole in 7" liner and pkr would not hold - communicated around nkr to annulus. Checked pkr ~ 12,716', !2,685', 12.645' and r. br would not hold. 15,328'TD 14,395 'ETD (cmt ret) 9 5/8" csg @10,555' 7" liner @ 10,287'- 15,328' Checked 7" Baker retrievmatic final time @12,645' and communicated to annulus - pkr not holding. Pooh and repaired pkr. Re-ran 7" retrievamatic on 3 1/2" x 5" DP & set pkr @10,354' (67' inside 7" liner). PI DP @ 1 CFH & 1900 psi and PI 9 5/8" x 5" annulus @ 34 CFM & 1900 psi. Moved pkr down hole and located 7" , casing leak 12,635 -12,658'. Tested 7" liner from 12,658' to cmt ret @14,395' to 3750 psi - o.k. With pkr @12,635' PI 7" casing leak @16 CFM & 2500 psi and PI 9 5/8" x 5" annulus Ca 35 CFM & 1900 psi. Pooh w/ pkr. Rigged W.L. and set 7" Baker cmt ret @12,440' to squeeze hole in 7" liner. 15,328'TD 12,050' ETD (cmt plug) 9 5/8" csg @ 10,555' 7" 1 iner @10,287'- 15,328' Finished pooh and RD W.L. after setting 7" sqz. cmt ret @12,44p0I. Ran stinger on 3 1/2" x 5" DP and stabbed into ret. 7" csg leak 12,635'-12,658' @ 16 CFM & 2500 psi. Mixed and pumped 150 sx (172 cu.ft.) C1 "G" cmt w/ .3% D-19, .75% D-31 and .1% D-6. Squeezed 7" csg leak w/ 92 cu.ft. to lcok up @ max pressure of 5500 psi. Held pressure for lO min w/ no bleed off. Held 1900 psi on annulus by PI @36 CFM while squeezing.. Pulled out ~of ret and-dumped 80 cu.ft, cmt on ret to 12,050'. Pooh w/ DP. Ran 8 172" bit and 9 5/8" csg scraper on 5" DP to top of 7" liner @10,287'. Circ hole clean w/ FIW and pooh. RU Dialog W.L. and ran 64 arm casing caliper inspection log to 9 5/8" csg to DY tool @4609' and logging tool would not go deeper. Logged out of hole from 4568' to surface. RIH w/ 8 1/2" bit and 9 5/8" csg scraper on 5" DP. 1/11/78 ' 12/78 15,328 'TD 12,050' ETD (cmt plug) 9 5/8" csg @ 10,555' Finished RIH w/ 8 1/2" bit & 9 5/8" csg scraper and worked scraper through DV tool @4610' for 15 min. RIH to 4750' and circ hole clean. Pooh. Ran Dialog csg caliper inspection log in 9 5/8" csg to 8625' and tool stopped. Logged from 8625' to 45C~8' and pooh. Log showed jt above DV tool @4610' to be worn 7" liner @ to 8% (1/32") remaining wall thickness from 4610' to 4590' and lO,287'-15,328'remainder of 9 5/8" to be in usable condition. Ran Baker 9 5/8" retrievamatic on 5" DP and set @4501'. Tested 9 5/8" x 5" annulus to 3500 psi o.k. Moved pkr to 4710' and tested 9 5/8" csg from 4710' to 7" liner lap @10,287' to 3500 psi o.k. Moved pkr to 4501' and PI hole in 9 5/8" csg 4610'-4590' @ 30 CFM & 1500 psi. Squeezed hole w/ 400 sx C1 "G" cmt w/ .75% D-31, .3% D-19 & .1% D-6 pumping @ 16 CFM & 1600 psi decreasing to 6 CFM & 2000 psi. Displaced cmt and cleared hole w/ 40 cu.ft. water. Pressure held @1800 psi w/ pump off and grad. dec. to ' 1350 psi and holding there in 3 hrs. Released pkr and circ. hole clean. CIP @1:05 p.m. and now WOC 12 hrs. 15,328 'TD 12,050' ETD (cmt plug) 9 5/8" csg. @10,555' WOC from first sqz of 9 5/8" csg leak for total of 12 hrs. Reset 9 5/8" Baker retrievamatic pkr @4501' PI 9 5/8" csg leak 4610'-4590' @12 CFM & 2000 psi (before firs~ squeeze PI @ 36CFM & 1900 psi). Mixed & pumped 200 sx Cl "G" cmt w/ add. and w/ 80 cu.ft, of FIW displacement in DP plugged ret pkr. Could 7" liner @ not move cmt w/ 2000 psi on DP or ann. ( 9 5/8" x 5" ann. would lO,287'-15,328'hold 2000 psi - hole plugged w/ cmt chunks from DP). Released pkr and pulled wet string dumping all green cmt - no DP cmt'd up. Found pkr plugged w/ chunks of cmt sheath which was left 9n 5" DP from previous squeezes and peeled off inside of DP. Ran DP open ended to 4501' and pooh rattling and cleaning each stand of DP. Ran 8 1/2" bit on 5" DP and washed out cmt chunks fr( 4546' to 4620'. Circ. hole clean & pooh. Ran 9 5/8" Baker ret pkr on 5" DP and set @4501'. PI 9 5/8" csg leak @17 CFM & 1700 psi. Squeezed hole in 9 5/8" csg 4610'-4590' w/ 200 sx. C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6 and 7 1/2% sand pumping @16CFM & 1200 psi decreasing to 3 CFM & 3500 psi. Displaced cmt & cleared hole w/ 40 cu.ft, water. Press. held @2400 psi w/ pump off and grad dec. to 1400 psi in 3 hrs and holding there. Released press and had small flow back. Repressured to 1400 psi for 1 1/2 hrs and released press - o.k. no flowback. Released pkr and circ hole clean. Pooh and now WOC for 12 hrs. CIP @5:40 p.m. lO ll 12 1113178 1/14/78 1/15/78 1/16/78 15,328'TD Finished WOC total of 12 hrs after second sqz of 9 5/8" csg leak 14,395'ETD @4610'-4590'. Ran 9 5/8" Baker cmt ret on 5" DP and set (cmt ret) @4474'. PI csg leak @ 16 CFM & 2000 psi. Mixed and pumped 9 5/8" csg @ 300 sx C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6, and 5% 10,555' sand. Sqz. 9 5/8" csg leak 4610'-4590' pumping @ 2CFM & 7" L 10,287'- 4000 psi w/ 137 cu.ft, cmt below ret. Stopped pumping to 15,328' switch Howco pumps and could not move cmt again w/ 5000 psi. Held 5000 psi on hole for 5 min w/ no bleed off. Pulled out of ret and reversed hole clean. CIP @ 8:00 p.m. 1/13/78. Pooh and WOC total of 24 hrs. 15,328'TD Ran 8 1/2" bit on 5" DP and drilled cmt ret @4474'. Drlg hard 14,395'ETD cmt from 4474' to 4632' and stingers to 4753'. Circ. hole 9 5/8" C @ clean. Closed pipe rams and tested 9 5/8" csg leak to 3000 psi 10,555' o.k. RIH to top of 7" liner @10,287' and circ hole clean. Pooh. 7" L 10,287'- Ran Baker 9 5/8" retrievamatic pkr on 5" DP and set @1815'. 15,328' Tested 9 5/8" csg from 1815' to top of 7" liner @10,287' to 3600 psi o.k. 15,328 'TD 14,395'ETD (cmt ret) 9 5/8" csg @10,555' 7" L 10,287'- 15,328' Pooh w/ pkr. Ran 6" bit on 3 1/2" x 5" DP and tagged TOC in in 7" liner @12,010'. Drlg hard cmt from 12,010' to cmt ret @ 12,440' in 12 hrs. Pooh for new bit. 15,328'TD Finished TIH w/ new 6" bit on 3 1/2" x 5" DP. Drlg cmt ret 14,395'ETD @12,440' and hard cmt to 12,667'. Fell free and RIH to cmt ret (cmt ret) @14,395'. Circ hole clean and pooh. Ran 9 5/8" Baker 9 5/8" C @ retrievamatic on 5" DP and set @1880'. Attempted to pressure 10,555' test 9 5/8" csg leak and 7" liner leak squeezes to 3600 psi. 7" L @10,287' Held pressure for approx 1 min and broke back to 1500 psi. 15,328' PI @17 CFM & 1800 psi and held 1300 psi w/ pump off. Ran pkr to 4724' and tested 9 5/8" csg, 7" liner lap @10,287', and 7" liner leak sqz to 3600 psi o.k. PI 9 5/8" x 5" annulus @22 CFM & 1700 psi. Pooh w/ pkr. Ran 9 5/8" Baker cmt ret on 5" DP and set @6023'. Pooh and re-ran 9 5/8" retrievamatic on 5" DP, incomplete. 13 15 16 14 1/17/78 1/18/78 1/19/78 1/20/78 15,328' TD 6023' ETD (cmt ret) 9 5/8" csg @10,555' Finished RIH w/ Baker 9 5/8" retrievamatic on 5" DP. With 9 5/8" cmt ret @6023' & 9 5/8" retrievamatic @4445' tested 9 5/8" x 5" annulus to 2700 psi above pkr. PI 9 5/8" csg leak 4610'- 4590' @17 CFM & 1700 psi. Mixed 300 sx C1 "G" cmt w/ .3% D-19, · 75% D-31 and .1% D-6 @ll8#/CF and squeezed below pkr @16 CFM 7" liner @ & 1800 psi to 8 CFM & 2150 psi. Displaced cmt and cleared csg lO,287'-15,328'holes w/ 40 CF water. Held 1350 psi for 5 min w/ pump off. Released pressure w/ no backflow and reversed hole clean. CIP @3:00 a.m. WOC 12 hrs. Reset retrievamatic @4414' and PI 9 5/8" csg leak 4610'-4590' @17 CFM & 1700 psi. Mixed 300 sx. C1 "G" cmt w/ .3% D-19, .75% D-31, .1% D-6 and 10% sand @ll9#/CF and squeezed below pkr @3-4 CFM & 1600 - 3100 psi. Pressure rising and falling as formation fractures and squeezes repeatedly. Displaced cmt & cleared csg hole w/ 40 CF water @ final 4 CFM & 2400 psi. Held 1950 psi for 5 min w/ pump off. Released pressure w/ no backflow and reversed hole clean. CIP @5:10 p.m. Pooh w/ pkr and WOC 12 hrs. 15,328 'TD 4445' ETD (cmt ret) 9 5/8" csg @10,555' Finished WOC after second squeeze for total of 12 hrs. Ran 9 5/8" Baker cmt ret on 5" DP and set @4445'. PI 9 5/8" csg leak 4610'-4590' @ 15 CFM & 1950 psi. Mixed 300 sx C1 "G" w/ .3% D-19, .75% D-31, .1% D-6 and 5% sand @ll9#/CF and pumped to holes @ 8-4 CFM & 2100-3800 psi. Displaced cmt to ret 7" liner @ @ final lock-up squeeze pressure of 5500 psi after two - 2 lO,287'-15,328'minute hesitations. Held 5500 psi for 5 min w/ no bleed off to hole. Bled pressure to 2000 psi and pulled out of ret. Rev. hole clean and pooh w/ DP. WOC for 24 hrs before drilling ret. 15,328'TD WOC for total of 21 hrs after third squeeze of 9 5/8" csg 6023'ETD leak @4610'-4590'. RIH w/ 8 1/2" bit to TOC @4390'. Drlg (cmt ret) out cmt and cmt ret @4445'. Drlg hard cmt below ret to 4541' 9 5/8" csg aid stingers to 47~1'. RIH to cmt ret @6023' and circ hole @10,555' clean. ~est 9 5/8 csg to 2500 psi o.k. and pooh. RIH 7" liner @ w/ 9 5/8 Baker retrievamatic and set @1855'. Pressure lO,287'-15,328'tested 9 5/8" csg to 3400 psi and bled off to 2000 psi in 7 min. Repressured to 2500 psi and bled off to 1600 psi in 12 min. 15,328'TD 6023'ETD (cmt ret) 9 5/8" csg 010,555' 7" liner @ 10,287'- 15,328' Finished pressure testing 9 5/8" csg leak 4610'-4590' after third stage squeeze. Cs§ leak squeeze failed to hold 3400 psi bleeding to 1600 psi in 12 min. Pooh w/ ret pkr. Ran 8 1/4" burnover shoe and Baker pkr pickeron 5" DP and burned over 9 5/8" cmt ret @6023'. Pooh and did not recover ret. Ran 8 1/4" overshot w/ 5 7/8" grapple on 5" DP to top of 7" liner @10,287'. Engaged cmt ret several times but could not retrieve. Pooh and did not recover ret. Ran 9 5/8" Baker retrievamatic on 5" DP and set @4430'. PI 9 5/8" csg leak 4610'-4590' @13 CFM & 2000 psi. Squeezed csg leak w/ 200 sx Cl "G" cmt w/ .75% D-31, .3% D-19, .1% D-6, 10% sand mixed @ll9#/CF @ 4 CFH & 1200 psi to 2400 psi. Displaced cmt to 4530' @ final squeeze rate 4 CFM & 2000 psi. CIP @10'30 p.m. 1/20/78. Pressure bled to 1250 psi in 1/2 hr. Bled pressure to 0 psi w/ no backflow and rev out. 17 18 19 2O 21 1/21/78 10/22/78 1/23/78 1/24/78 1/25/78 15,328'TD 6023' ETD 9 5/8" @10,555' 7" liner 10,287'- 15,328' 15,328'TD 14,437' ETD (perm pkr) 9 5/8" csg @10,555' 7" liner @ 10,287'- 15,328' 15,328'TD 15,080' ETD (junk on fill) 9 5/8" csg @10,555' 15,328'TD 15,090'ETD (junk pkr) 9 5/8" csg @10,555' 7" 1 iner 10,287'- 15,328' 15,328'TD 15,259'ETD (fill) 9 5/8" csg @10,555' 7" liner @ 10,287'- 15,328' Pooh w/ pkr and rec small amt of cmt scale from inside of DP. WOC 12 hrs. Ran 8 1/2" bit on 5" DP and drilled out firm cmt from 4436' to 4662'. Tested 9 5/8" csg from surface to 10,287' to 1650 psi - o.k. RIH to 10,287' top of 7" liner and pushed cmt ret junk into 7" liner. Circ hole clean and pooh. RIH w/ 6" bit on 3 1/2" x 5" DP and drilled up cmt ret junk in top of 7" liner @10,287' in 5 1/2 hrs. Added 5#/1000 gal Dowel l FR to FIW to reduce torque. RIH to cmt ret @14,395' and drilled on ret for 3 hrs. Pooh for new bit. RIH w/ 6" bit on 3 1/2" x 5" DP and drilled on ret @14,395' for 3 hrs. Pushed ret to perm pkr @14,437' and started drilling on ret junk and perm pkr. Drlg on ret junk and perm pkr @14,437' and perm pkr came free. Chased junk & pkr to 15,078'. Drlg on junk @15,078' (apparent fill 15,078'-15,280') for 4 hrs and pooh for new bit. RIH w/ 6" bit on 3 1/2" x 5" DP and changed out 89 jts of 5" E DP for 5" S-135 DP due to high drag in hole @15,000'. Drlg on junk from 15,078'-15,080' in 6 hrs. Pooh for bit change after drlg on ret junk & perm pkr @15,080' for 6 hrs. Ran 30' piece of 3 1/2" DP w/ pin cut off on 3 1/2" x 5" DP to junk pkr @15,080'. Worked stinger thru pkr and worked pkr down to 15,090' in 2 hrs. Mixed 1/4#/bbl FR in FIW to reduce torque and drag and pooh. Ran 6" Servco flat btm junk mill, oil jars, bumper sub and three - 4 3/4" DC on 3 1/2" x 5" DP and tagged junk pkr @14,675'. Chased pkr to 15,090' and began milling up pkr. Finished milling up perm pkr @15,090' in two hrs and washed out sand fill to 15,194'. Circ hole clean and swept hole vT/ 40 bbl hi-vis pill. Pooh w/ mill. Ran 6" bit, 7" csg scraper, oil jars, bumper sub, and three 4 3/4" DC on 3 1/2" x 5" DP and washed from 15,194' to 15,259'. Circ hole clean and swept hole as above. Pooh w/ bit. Ran 5 3/4" gage ring and junk catcher on Go Int. W.L. to 10,57,5' and could not work deeper. Pooh w/ W.L. and recovered several chunks of DP rubbers in junk catcher. Ran 6" bit & 7" csg scraper on 3 1/2" x 5" DP to 15,226'. 22 23 24 1/26/78 1/27/78 1/28/78 15,328'TD 14,395' ETD (perm pkr) 9 5/8" csg @10,555' 7" liner @ 10,287'- 15,328' 15,328'TD 14,378'ETD 9 5/8''' csg @10,555' 7" liner @ 10,287'- 15,328' 15,328'TD 14,378'ETD (perm pkr) 9 5/8" csg 7" liner @ 10,287'- 10,555' nished RIH w/ 6" bit & 7" csg scraper to 15,226' to push rubber pieces to bottom and pooh w/o circ. No DP rubbers lost. Ran 5 3/4" gage ring and junk catcher on W.L. to 14,450' - o.k. Ran 7"x4" Baker F-1 perm pkr on W.L. and stopped @11,940'. Could not work deeper. Pooh and rig pkr for DP set. Ran same pkr on 3 1/2"x5" DP and set pkr @14,394' DPM (+14,378'DIL) w/ 3000 psi. Weight tested pkr w/ 25,000# - o.k. and pooh. No DP rubbers lost. LD 6 1/4" and 4 3/4" DC and Kelly. Changed rams in BOPE to 4 1/2" top x 3 1/2" bottom and tested to UOCO specs. Finished RU to run tbg. Ran 142 jts (4340.90') 3 1/2" 9.2# N-80 butt used tbg, 238 its (7288.91) 12.6# N-80 butt used tbg. Ran 90 jts (2732.21') 12.6# N-80 butt new tbg. Triple "D" hydrotested all tbg to 4000 psi above slips while RIH. Stung into Baker Model F perm pkr @14,422' tbg meas (14,378'DIL) and spaced out tbg. Tested pkr to 400 psi Pulled out of pkr and circ hole clean w/ FIW. Displaced tbg annulus w/ pkr fluid mixed.w/ FIW containinq 1% N~lco Visco 938, 1000 ppm Nalco Visco 1153 and 100 ppm Nelco Visco · 2656. Landed. tbg w/,end of 3 1/2" tbg @14,455', 3 1/2" Otis XN nipple @14~4§.3', Baker locator sub @14,421', ~_I1/2" Otis XA sleeve @14,386', top of 3 1/2" tbg @10,075' and ~ 1/2" Otis XN-nipple @328'. Installed BPV~and removed BOPE. Ins~talled 4.1/2" 5000 psi ¢IW X-m~s tree and tested to UOCO specs. Returned well t.o inject-ion. Began LD 3 1/2" DP. Released rig charges to G-17 @12:00 mid. On injection @5500 BPD rate & 2300 psi. Casing pressure 0 psi. Memorandum Union Oil Company o unlen I~fornia Please note - this Notice was mailed to your office 2/24/78 - but returned by Post Office 3/3/78 as undeliverable. FORM 1--OF15 (REV. 11-72) PRINTED IN U.S.A. (FORMERLY g35-A) RECEIVED MAR ~ 3 1~J7~ Umon Od and Gas I~ ~on Western Region Umon Od Company of Cahforma P 0 Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 unl, n February 24, 1978 Mr. O. K. G ilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 RE' TBUS G-9 GRAYLING PLATFORM Dear Mr. Gilbreth' Enclosed for your information are two copies of the Subsequent Sundry Notice for the above captioned project. Sincerely yours, Dist. Drlg. Supt. sm cc: Marathon Oil Co. Atlantic Richfield Co. Chevron USA Amoco Production Co. Getty Oil Co. Phillips Petroleum Co. USGS Harry Lee RECEIVED MAR- $1978 Division OT O~t and Sas 6ons~.tion Anchorage , Form ! 0-403 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for prol3osals to drill or to ~leel3en Use"APPLICATION FOR PERMIT--" for such prop_osal~). -- , t , r m O,L I--1 GAS r-I injector K~_(~klV~k) WELLI..mJ WELL I I OTHER 2. NAM.E. OF OPE,~.A.TO~ union Ull co. of California MAR - 3 1978 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99501~ision o! 0~1 and Gas ~t nnh~r~na 4oLOCATION OF WELL Atm,,ce Conductor 41, Leg 2- 1886'N & 1382'W from the SE corner, Section 29 T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' above MSL 14, Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20098 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit WELL NO. on TBUS G-9 (32-27) 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27' T9N, R13W, S.M. 12. PERMIT NO. 68-16 x)rt, or Other Data NOTICE OF INTENTION TO'. FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER I NG CAS lNG SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Cem~tl~l o~ Recompletion Report anci Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state &Il Dertlnellt ;letall~, end give pertinent dates, Including estimated date of starting any proposed work. Work commenced on January 5, 1978. Moved rig over well. NU and tested BOPE. Pulled and layed down 4 1/2" tbg. Ran 7" test packers and located hole in 7" liner 12,635'-12,658'. Set 7" cement retainer @12,440' and squeezed hole with 150 sx. to 5500 psi. Ran casing inspection log in 9 5/8" casing indicating holes 4610'-4590'. Ran 9 5/8" test packer and located hole in 9 5/8" casing 4710'-4501'. Squeezed hole with 900 sx. in three stages to 5000 psi. Cleaned out and tested squeeze to 3600 psi - o.k. Cleaned out 7" liner and tested squeeze 3600 psi - o.k. Tested both squeezes to 3600 psi and 9 5/8" squeeze 4710'-4501' failed. Resqueezed hole in 9 5/8" casing with 900 sx in three stages to 5500 psi. Cleaned out and tested squeeze to 3600 psi - no good. Resqueezed hole with 200 sx. to 2000 psi. Cleaned out and tested squeeze to 1650 psi - o.k. Drilled up 7" perm. packer @14,437'. Set new 7" perm. productibn packer @14,394'. Ran 3 1/2" & 4 1/2" injection tubing and hydrotested tubing to 4000 psi. Displaced annulus with packer fluid and returned well to injection. Work complete 1/28/78. Tniprfinn r~p R.RAA RWPI3 02.3QQ 16. I -~e;.6~ certify that the foregoing is true and ~rre~t SIGNED k~. L Dist. Drlg. Supt. 2/24/78 DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Umon O~1 and Gas( '~slon Western Region Umon Od Company of Cahforn~a P O Box 6247, Anchorage, Alaska 99502 Telephone (907) 276-7600 un, n December 6, 1977 ~r. O. K. ~lbr~th ~v~s~on of 0~1 ~ gas 3001 Porcupine Drive Anchorage, AK 99502 Dear Mr. Gilbreth' Enclosed for your approval are three (3) copies each of Sundry Notices for the above captioned projects. Sincerely yours, Jim R. Callender Dist. Drlg. Supt. sm RECEIVED Bi,-C '/ 1977' F~n 10-403 REV. 1-10-73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to d~epen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~LLLO GAS O OTHER WELL i nj ector 2. NAME J~F pPER~'[(~R ~ un]on u]/ co. of California ~ AOOR~S~.O~0"~T~L~47, Anchorage AK 99502 4. LOCATION OF WELL tsurface onductor 41, Leg 2' 1886'N & 1382'W from the SE corner. Section 29- T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 5. APl NUMERICAL CODE 50- ] 33-20098 99' RT above MSL !6. LEASE DESIGNATION AND SERIAL NO. ADL ]873O 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM ~ Tradin_~ Unit 9. WELL NO. TBUS G-9 (32-27) ~ FIELD AN~, OR WILDCAT McArthur River-Hemlock '11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27: T9N, R13W, S.M. 14. 12. PERMIT NO. 68-]6 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data SUBSEQUENT REPORT OF: NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZlNG ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (Other) (NOTE, Report results of multiple completion on Well Coml}letion or Recomplation Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent ~let&lls, and give pertinent dates, including estimate~l date of starting any proposed work. This well was converted to an injector in 1970. During a workover in 1972, holes were found in the 7" liner at 12,698'. They were squeeze cemented with 75 sx. of cement. In August, 1977, a large increase in water injection was noticed. An injection profile showed that there are holes in the tubing at 1,100'. Water was exiting through these holes and being injected through the squeezed off 7" liner holes at 12,698', which are opposite the "F" sands. To prevent the pressuring up of the "F" zone, G-9 was shut in early in August. It is proposed to repair the 7" liner holes with a cement squeeze and put the well back on injection. Attached are a wellbore schematic and a detailed plan of procedure. 16. I hereby ce/rtify that the fo~,eg'olng is true and correct TITLE Dist. Drlg. Supt. 12/2/77 DATE (This space for State office use) ~j*' CONDITIONS OF APPROVAL, IF A~J': TITLE P~-t~'~leum Engineer See Instructions On Reverse Side DATE 12-27-77 Retum~A PLAN OF PROCEDURE' le 2. 3. 4. 5. 6. 7. 8. OPERATING TIME: Move rig over conductor #41 in Leg Room 2. Load hole with FIW. Install BPV and remove X-mas tree. Install and test BOPE. Pull injection tbg. Set 7" cmt. ret. @+14,000'. Locate hole in 7" liner and squeeze with Class "G" cmt. Drill out cmt. and test squeeze. Cut over and pick cmt. ret. @+14,000'. Re-run injection equipment and return to injection. Workover 13 days START DATE- COMPLETION DATE- January 3, 1978 January 15, 1978 X~x 2¢" OP /~ 0 3&O'~ 9~e" 40. 4,~S, ~. ~05.5.4' ff'4zoo zx - Ov .t.,ol (~ 4t,~ d 14440'-EI5' 14emle~ 14 740 '- 930' t't) f,O'- tS/75' Hcm /od~ / 5 i 9S-£50 14em Dr~g. Permit No. Operator Alaskf il and Gas Conservation Committe~ · Field Inspection Report /~,,,.~ /:.* ,~ Well/P'l'a~~ Sec T Represented by ~¢,-~' -~m~ $'L-{_Name & Number Satisfactory Ty~e Inspection Yes No Item ( ) Location,General () () () () () () () () (~,,)' () () (,)' ('F () (,.), ( ) ( () () () () (') () () 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Rig ( .)' Safety Valve Tests 5. Surface-No. Wells . .. 6. Subsurface-No. Wells . ( ) Well Test Data 7. Well Nos.. , , -,, , 8. Hrs. obser , -_:Z__,__, 9. BS&W , ' ,, ~, .,. ,__ 10. Gr. Bbl'. ( ) Final Abandonment Satisfactory Type Inspection Yes No Item ( ) BOPE Tests () () () () () () () () () () () () () () () () () () () () () () () () () () 11. P&A Marker ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 13. Clean-up ( ) ( ) 15. ' "Casing set @ 16. Test fluid-( )wtr.-':--~)mud ( ) oil ' 17. Master Hyd. Control Sys.- . .psiQ 18. N? btls. , , , psiq 19. R~mote Control~-- 20. Drillinq spool- "outlets 21. Kill Line-( ).Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs fl~s 24. Chokes-( )Remote( )Pos.(~dj. 25. Test Plug-( )~.$ellhd( )cso( )none 26. Annular Preventer, psiQ 27. Blind Rams, .. psi.q 28. Pipe Rams psig 29. Kelly & Kelly-cock ~_psi.q 30. Lower Kelly valve psig ( ) ( ) 14. Pad leveled ( ) ( ) 31. Safety Floor valves-( )BV Total inspection observation time~'/ (}~¢'~}idays Total number leaks and/or e~uip, failures o Remarks , , , v ~/ :._:.. ./, ,~ ,, -' .,.:../.~ ,~ t~- ~ :',-,~ , ,~ · .~ ...... :~:.~.: .... ,,,~ .,~,~_~ ~ .... . ....... ..=...,, , .~ cc' ,' ¢/,,,. ,,,,, Notify in ays or when ready Inspected by,..'~ ,.~],.,~,),,,~;>. Date Memorandum I Union 0,1 Company ~, California June 18, 1973 TO WHOM IT ~RY COMCERN: Due to a mix-up in mailing lists and inconsistency in forms, all repair records and drilling well records since February 21, 1972 arc being redone and distributed. You will be receiving copies that you may or nay not have already received soon. Please replace those on file with the new records. JRC/sk Enclosures District Drilling Supt. C',IL,,,,_~,,D GAS ?RAGE Form P--3 REV 9-30-6 9 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Smbmit "Intentions" in Triplicate & 'Subsequent Reports" m Duphcate SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dlHl or to deepen Use APP-LICATION FOR PERMIr~" for such proposals ) OIL ~' GAS ~ j --ELL ~-- WELL OTHEB Water In ector 99501 NAME OF OPERATOR Union Oil Conmanv of California ADDRESS OF OPERA/eOR 909 ~qest 9th Avenue, Anchorage, Alaska AP1 NUM.Et~CAL CODE 50-133-20098 6 LEASE DESIGNATION A-ND SERIAL NO 3J3L - 18730 ? IF INDIA.N, A.LLO'l-r~-'~- OR TRIBE NAM.1E 8 UNIT, FA.RM OR LEASE NA~IE Trading Bay Unit 9 WELL NO State G-9 (32-27) 4 LOCATION OF WELL ^t su,~ce Conductor 41, Leg 2, 1886'N and 1382'W from SE comer. Section 29' T9N, R13W, S. M. 13 ELEVAFIONS (Show whether DF, RT, GR, etc 99' RT above MSL. 10 FTI~.T.n A2qD POOL, OR WILDCAT 11 SEC, T, R, M, (BO~ HO~ O~E~IVE) Section 27" T9N, R13W, S. ~I. 68-16 NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTLRE TREAT MULTIPLE COMPI ETE SHOOT OR ACIDIZE ] I ABANDONS REPAIR %% ELL CHANG~ PLANB t Other) SUBfmqUENT am'oaT o!~: WATER SUUT-Orr ~ REPAIRING WELL l, fRACTURE TREATMENT ~ ~.LTERING CASINO SHOOTING On ACIDIZlNO ~ ABANDONMENT* hole in 7" c~n~. soz. (Other) (No~[ Report re~ult~ of multlpl, eomp~tlon on Wall Completion or Reeompletlon Report ~nd Log form ) 15 D} SCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and ghe pertinent dates, including estimated date of starting proposed work, This procedure was designed to distribute the injected water over the entire 7 benches, provide improved profile and increase the injection capability. (P-7 Forms w/acid volume and stimulation details previously submitted). le 2. 5. 4. 5. 6. 7. 8. ,~ -,~ 9. 10. 11. 12. 13. 14. 15. PROCEDURE: Ran radioactive tracer survey. bloved over G-9 and killed well w/ Inlet water. Removed tree and installed BOE. Pulled tubing. Retrieved permanent packer at 14,417'. Perf'd individual benches w/2IWF. Rill w/ bit and casing scraper and CO to 15,281'*_ (7"scraper). Acidized w/straddle tool as per attached. Squeezed hole in 7" casing at 12,698' - tested ok. Set retrievable pa?kef at 14,400' and injected thru dp. Ran radioactive .sp~nner - tracer survey thru ap. Set 7" packer on wireline as indicated by profile logs. Ran 4 1/2" and 5 1/2" tubing, stab into packer. Set and tested packers. DI\'i3{C',,,' ,. ;: Gq..t-t'qO GAS /. ,',',"Nc') p ~. G~. Displaced annulus w/ diesel oil as packer fluid. 16. Plac~i.well on injection - tlemlock. Rig released 9/21/72. 16 I hereby ~ertffj~Jaat the. J~r~jn~ ~s~true and correct _ .i~~'~~~~Z--'.-'~:~TLE District Drle S~t. ~,,~ November 3 1972 (~1~ ~p&e~ for State omee APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See I,n.struOions On Reverse Side ]LL'~. 8- I-1'0 STAr OIL AND GAS CONSERVATION CON~Ir.~EE ~ r., n ~ ~ 50-)33-20098 AND WORKOVER OPERATI~ [~L - 18730 N~ OF OPhiR D~SION OF OIL A~ID GAS e ~[T ~.z OR LEASE ~nion Oil Con~y of Califo~ia ANC~O~'c~ Trading ~), Unit $ W~ NO 909 Ii. 9th Avenue. A~choraee. Alaska 99g01 ~CA~ON OF W~T .T. -- - Con~ctor 41, ~g 2, 1886'N ~d 1582'~V from fl~e S. ~. co~er, ~ction 29' TgN, RIS}V, S. H. REPORT TOTAL D.~-~H AT F-~TD OF l~1ON'i~-i CHA. NGF~ IN HOLE SIZE CA~ING AND CE, IVlF_,,N~'F!NG State G-9 (52-27) l0 FfI~'I~O A.ND POOL OR WILDCAT ,XlcCr thur River-Hemlock 11 SEC T R -~i (I~O~I'~OM HOLE Section 27' TDN, R131~i, S.M. 68-16 JOBS INCLUDING DEP,'I'~ SET A.N'D VOLLrMES USED PERFORATIONS TESTS A_N'D RESULTS FISHING JOltS Jr~.'NK L~I HOLE AND SIDE-TI~ACKIED HOLE AND A-~Y OTI~ER SIGNIFICA2qT ~G~ ~ HO~ ~ITIONS Co~anenced operatio~ on T~S well ~6-9 at 9'00 a9 8/51/72. ~erations from 9/1/72 to fl~e co~letion 0i ~:9 ar~ as ~ollo~s: co~leted profile logg~g. ~gg~ up Otis. ~ened sleeve above packer at 14,578'. Displaced diesel in ~ul~ ~/filtered Inlet Iiater. Removed ~s tree. I~tall~ ~P's. Tested ok. hlled 4 1/2" ~d 5 1/2" mbh~g str~gs plug packer seal assembly. Laid do~ s~ple its. of 4 1/2" robing for insp~tion. Fo~d wash out at bottom of 5 1/2" buttress coupl~g at approx~ately 9900'. Rill w/ ~ker packer picker. Hilled over Otis pe~ent pro~ction packer at 14,417 tool not operat~g properly. POll, duecked ~d re-r~ rebuilt ~ker packer picker, hilled on packer for 7 hours. Packer moved doxm 6 ft. ~d stopped. POH. Found retrieving collet ~mt, backed off. RIH w/tri-state packer picker. Retrieved i~er sleeve of packer. IH}I ~/ S 7/8" con,ye ~11. )lilled ~d pushed packer to 15,278'. Cir~lated hole cle~. PO~ w/ S 7/8" mill. Rill w/6" bit and 7" casing scraper. CO to 15,281'. ~ ti~,'co R~S tool ~d ~P on 5 1/2" D. O. to 15,200'. Set R~S at 15,185'. Could not break do~m inte~al w/2500~. Spott~ I0 bbl's. Acid across perf inte~al. Re-set R~S at 15,185'. Attcmpted to acidize. BI~ (15,195' - 15,175") confiscated. Re-set at 15,190', IS,19S', 15,180' ~d 15,175'. ~erienc~ coaication at ail sett~gs. ~t ~P at 14,950' ~d RTrs at 14,700' in 10' bl~. Pressured to 2000~ ~d bled to 1,250" in five minutes. Repressured io 2000~ ~d cirmlated aro~d bl~. S~tta 10 bbl's acid across perfs 14,460' to 14,515'. ~t R~S at 14,420 ~d ~P at 14,530'. Mck of pressure drop indicated RBP set ok. ~ed 4000 gallo~ 2 1/21 HCL ~d 5000 gallo~ 12-10 I-EL-t~ acid. Injected 550 bbl's water fl~h w/platfom system at 9 ~d 10 ft., 5/minute rate or 2567 BIiPD. ~t ~P above upper perfs ~ located hole w/ R~S t~l in 7' liner at 12,698', to be squeez~ follo~dng acid stimlation. ~H to reperf benches 5 ~d 4. Perforated 2 I~F dth Y' carrier gm (j~o jets) from 14,756 to 14,746, 14,782 to 14,792, 14,808 to 14,818, 14,856 to 14,866, 14,900 to 14,910 ~d from 14,914 ~ 14,924. w~h tool. Straddl~ ~te~al from 15,200 to 15,250. Cir~lated aro~d top ~ps on tool. ~lov~ tool ~/top c~s on tool at 15,195'. Circulated aro~d top ~s but at reduced rate. ~ed 2000 gallo~ 5~ }~L, 4000 gallo~ 12-10 }EL-I~ ~ 2000 gallons 51 IEL. Flush~ w/5000 bbl's filter~ I~et ~ater at 10~000 BkPD rate. POll to re-dress well st~ t~l. l~rm Ho P--4, I'LL"Y. 8- I-?0 STA( )F ALASKA OIL AND GAS CONSERVATION COMMI'rrEE SUBMIT IN DU'PLICAf MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,~,,,,.~ I--1 ~".._,_,. [-] o,~,,X ~ater Injection NAME OF OP~,ATOR Union Oil Company of California ADDRESS OF OPERJ~TOR 909 l~'. 9th Avenue, Anchoraae. Alaska 4 I23CATION OF Same 99501' AP1 NUMERICAL CODE .~.q- I "~3-20098 LgASE DF-~:GlstAk~ION AND SERIAl. NO ADL- 18730 IF INDIAN ALOT 1 ~ OR TRIBE 8 L.~IT FAP,~ OR LEASE NAME Trading Bay' Unit 9 WE~ NO State G-9 (32-27) 10 FIF~I~D A_~qD POOL OH WILDCAT _ McArtJ~ur River-IIemlock 11 SEC T R Ii (BOI"roM HOI.,E oa,m_.crnr~ Section 27' T9N, Rl3h', S. ,~I. 12 PER.MIT NO 68-16 13 P. EPORT TOTAL DEPTH AT ~qD OF MONTH, CHA_~GES IN HOLE SIZE CASING ANT) CY~WiF~_NG JOBS INCLUDING DEPTH SET AND VOLLrlVFES USED PERFOP. ATIONS TESTS A_N~D HESULTS FISHING JO]3~ JL~NK L~q HOLE AND SIDE-T1R~CKED HOLE AND AJaY OTKE~ SIGNIFICANT CHANGES IN HOLE CONDITIONS Cups on well stim straddle wash tool filed w/sand, mud and metal packer cuttings. Re- placed cups and reran tool to stimulate interval. No communication w/annulus. Slatted acid across interval. Injected at 2600# at 2 ft. S/minute rate. Pumped 1600 gallons HCL 4000 gallons 12-10 tEL-[~ and 1600 iCL. Pump~ 500 bbl's water flush at 2600# at 5 ft. 5/minute. Straddled interval at 14,850 to 14,880. Tested at 1500#. Spotted mud acid. Injected acid at 2000# at 2 to 4 cu. ft./minute. ~lushed w/ 15 bbl's water Pumped 1600 gallons 5% tEL, 4000 12-10 HCL-t~ and 1600 gallons 5% tEL. Flushed w/500 bbl's water at 2500# at 2 cu. ft./nfinute increasing to 1.8 BPBI. Experienced commnication around top cups on well stim tool as last 400 gallons 5% ICL injected. Flush was conducted w/ rmns closed on D. P. straddled interval 14,775 to 14,825. Tested tool to 1700# w/slow bleed off. ~ull comnmufication around top cups after injecting spotted acid. Straddled interval and tested to 2000#, bled to 1500#. Spotted I0 bbl's 12-10 lCL-l-~ and experienced conmmication, bbved tool to set top cups at 14,?09'. Injected spotted acid at 2 and 3 cu. ft./minute, rate at 1100#. Communication experienced. Spotted an additional 10 bbl's 12-10 tEL-t~ acid. No conm- unication. Flushed w/560 bbl's' water. POll w/well stim straddle tool, prep to profile. RIH w/ RBP and RTTS tool. Set RBP at 15,276' below perfs and RTTS at 14,404' above upper perfs. Injected and profiled at 8550' BP,PD w/schlumberger. Set RBP at 12,845' Spotted 25' sand on RBP. Set RTTS at 12,586' to squeeze hole in 7" liner at 12,698. Pmnped away 20 cu. ft. / minute at 2700# thru hole. Squeezed hole w/75 sx, class "G" cement to a final pressure of 5000#. Annulus backed up a /1000#. No commnnication indicated. CIP at 11:50, 9/10/72. Released took reversed and POll. Snail fluid flow to surface prior to squeeze. Hole now taking small amount of fluid. Set 7" Howco RTTS tool at 12,555'. Test casing - ok. POH. RIll w/6" bit and 7" casing scraper. Found cement at 12,478', firm cement to 12,548'. Stringers to 12,815'. Circulated sand off top of RBP at 12,845'. Cleaned pits. No fluid entry or loss following squeeze. Retrieved bridge plug. RIH with Howco 7" RTrs. Ran 6" bit and casing scraper. Cleaned out bridge from, 14,865 to 14,880. Circulated hole w/ clean filtered Inlet water. TIlt w/ RTrs tool to ETD at 15,281. Spotted 40 bbl's HCL acid across perforated interval to 14,500. Allowed acid to stay in place one hour. ~Porm ~o P---4 ~ B' 1-70 STA( .)F ALASKA OIL AND GAS CONSERVATION COMMI'I-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L.,L,. [] O.,.,.~ [--] o,,,,X Water Injection NAME OF Union Oil Company of California 3 ADDI:t~$ OF OPER.A. TOR 909 W 9th Avenue, Same Anchorage~ Alaska 99501 SUBMIT IN DUI~tJCA~ AP1 NL-AfERICAJ~ CODE 50-133-20098 LEASE DESiGI~AT1ON AXD SERIAL ~q)L - 18730 7 IF INDIAM ALOTi~I* OR TRIBE 8 L,~IT FA.R~I OR LEASE NAME Trading Bay Unit g ~vELL State G-9 (32-27) 10 FYI~3~D A_X:D P~L OR WI~CAT M~thur River-lieml~ 11 S~ T R M (~OM HO~ O~ ~ction 27" TgN, R15W, S. M. 12 PInt. MIT N'O , 68-16 53 REPORT TOTAL DIt~'TI-I AT F--'q~ OF MONrl'rl, CI-IA~;GES I,~ HOLE SIZE CA~ING AlhrD CI~NIE~.NG JOBS INCLL'DING DEI~I%I SET AN'l) VOLIYlVI~S USED PEI~FOP. ATIONS. T~$TS A2CD HESULTS FISHING JOB8 JL.~qK LN HOLE AND SIDE-TRACKED HOL~ A.N'D A.N'Y OTHEP. SIGNIFICANT C'HA~GES 17q HOLE CONDITIONS Reciprocated tool through perfs, and washed same. TIH to 15,281 w/RTTS tool - Spotted 2nd 40 bbl's HCL across perforated interval. Pulled toolup to 100' above top of nrfS and prepare to inject filtered Inlet water. Preparing to check injection rates jected at a rate of 8,800 BNPD w/5250 psi using platfom system. POll w/ RTrs tool ~nd picked up perforation washer to acidize 4 stages of perforations. Stage 1.- 15,025 - 15,075 Acidizedw/1,000 gallons 2 1/2" }EL, 2500 gallons 12-10% }EL-HF, 1,000 gallons 2 1/2 [EL followed by 500 bbl;s filtered Inlet water. Initial Water - 2 5~min. at 3,000 psi Acid 10 °/min. at 1,800 psi Final - 8 cu. ft. /min. at 2,700 psi. ~.- 14,948 - 14,998. Acidized same as Stage #1. Initial Water- 4,3fmin. at 2,200 psi Acid - 10?/min. at 2,000 psi Final Water - 9 ~/min. at 3,000 psi. Stage 3.- 14,876 - 14,926 Acidized smi~ as Stage 1 and 2. Initial Water - 3 33/min at 2,000 psi Acid 7 ./min~ at 2,000 psi Final Water 6 ~/min' at 3,500 psi Stage 4.-- 14,803 - 14,353 Acidized same as stages 1 2, and 3. 'initial Water- 2 3/min. at 2 000 ~si ' Ac~d - 11 }/mtn. at 1,000 psi Final Water - 16 °/min. at 3,SO0 psi Ran junk catcher and gauge ring to 14,550. Ran and set Baker Model FB-I, 7" x 4" packer at 14,457' l~I~Xl. Rigged up and ran 4 1/2" production tubing. Tae~ed Cacker at 14.47¢ tbs. meas. ~o~m No P--4 ~ 3-1-70 STAT~ )F ALASKA OIL AND GAS CONSERVATION COMMI'I-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS X Water Injection WKLL WKLL 2 NAME OF OPEB. ATOR Union Oil Company of California 3 ADDRESS OF OPEKATOR 909 W. 9th Avenue, Anchorage, Alaska 4 lOCATION OF WEIA. Same SUBMIT n~ DUPLICAT~~'''' 99~0 ! ~ AP1 NIJ~IERICAL CODE 50-133-20098 6 LEASE DES'-GI~A~ION AND SERIAL NO ADL- 18750 T IF INDIAN AI_<)TIL~E OR TRIBE NAME 8 I,,.~IT FAT~I OR LEASE NAJ~E Tradin~ Bay [Init State G-9 (32-27) 10 FLFA~ A.ND POOL OR WILDCAT McArthur River - tlemlock 11 SEC T R -~i (BOT~FOM HOLE O~~ Section 27' T~, R13W, S. M. 12 PERMIT NO 68-16 REPORT TOTAL DEPTH AT F--ND OF MONTH. CI-L~XGES IN HOLE SIZE CASING AND CF..WIF_.NT!NG JOBS INCLUDING DEPTH SET ~ VOL~ US~ P~O~TIONS. ~TS ~ ~SUL~ F~HIHG JO~ J~K LN HO~ AND SIDE-~CK~ HO~ ~ ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS t Set plug in "Q" nipple below packer at 14,437' Tubing failed to test. PCOH w/ tubing. Found I leak in 4 1/2" tubing, I leak 3 1/2" t~bing. Rigged up hydrotesters and Tilt testing stands full length to 4500 psi. Found 2 leaks 3 1/2" tubing. Now running 4 1/2" tubing at 12,500'. Testing to 4500 ,psi. Completed ming tubing, testing each jr. to 4500 psi. Stabbed into Baker wireline packer and tested ok. Displaced annulus with packer fluid. Landed tubing - removed BOPE m~d installed xmas tree. Put well on injection at 9:00 pm. Released rig at 12:00 pm on 9/21/72. hereby ri; 'y that tKe "r~g ~ ~'-~~,.z District Drlg Supt n,~ 10/14/72 s~ ....... Cai ....... ' i NOTE--Report on this fo~ Is required for eQ~ colend'or ~th~ regardless of the etatus of operatW~, and must ~ filed In duplicate with the oil Qfld got goniervatMn gommiflee by the 15~ of t~e succNdmg ~n~, ~IeM Othermle d~rected. ,T~'I U..IJ I:ATI,_0_N_.T R.EATM E N T REPORT ~ .WL-494-~ I~L~TF-I) IN U.$.Ao 5 HELL DIVISION OF THE DOW CHEMICAL COMP=~~ ' WELL NAME AND NUMBER .ATION ..... CUSTO-'~ME'--/~'~----EF--"~ ~NTATIVE ' :-/'-" .'/ /' ' /.-' -", ,, , / ," '/~ ' /;7' '-~ -' '"/ POD! '" IIrORMATION -,~, JOB DONE DOWN ADDRESS CITY. STATE & ZIP CODE REMARKS:__ J FOR CONVERSION PURPOSES' L~4 BBLS EQUA"~'S 1000 GALLONS ARRIVED ON LOCATION: TIME ~$ ',,~! INJECTION PRESSU RE TUBING I CASING I ANNULUS ', A~ .0 cO TYPE; OF WELL OIL. GAS AO DO AGE OF WELL Nr~w WELL REWOH,~ ^0 BEt CASING SIZE LINER SIZE OP~ HOLE CASING DE;PTH LINER DEPTH CSGoOR AN RL°VOL,, PA CK ER_.TY PE /I. TBG VOLUME /,,7 PERFORATEDINTERVALS TUBING DEPTH ,/.% ,, PACKER OEP'TH / ¢ / 'STATIC SHTo SERVICE ,LpG DEPTH NO. OF HOLES · TIME L£1rT LOCATION LIQUID INJ. RATE PRESSURE ]'AVGo PRESSURE / DOWELL LOCATION .// ?/ ~ ,7I il/T. ,".7 CX L~---~LI DA TI-' FINAL i:~.JMP IN. PRESSURE SHUT I" PRESSURE ,/ '"MED'AT~I 'SM'NUT'S i" ,. ,, ,, . DOWELL ENGINEER ~. is[Rv~c. ~u.~.ow. TEST ALLOWABLE J o~s TEST ALLOWAB~F t, ~;F. IM~J~EAYION~ ~ .. -..TREATMENT REPO~ l W L-494-J~NT[O IN PO0[ - C~NTY /2 7 cus~. ~ ~ ' ~ ' ADDRESS CITY, STATE ZIP CODE REMARKS:_ DATE }~ .?/.,.ELL DIVISION OF THE oow CHEMICAL. COMP.~ '" JJ~ /o C .~' .//P~' ~ oATION CUSTOMER REI~ -NTATIVE [TREATMENT NUMBER - -. - ' .-" , ~ _ ~. _''/.. / r FORM~kTION JOB DONE DOWN I ALLOWABLE PR~$SUIM: / 'TUBING I CASING ~ ANNULUS -,,,-r'/( A~ I ,o Ica ~TB~_.'~(*"*',~, ~. I ¢$G: OIL GAS WATER IN J. . . -"rT~'/('/7 A 0 "0 c 0 AGE OF' WELL TOTAL DEPTH CIRC. BHT. NEW WELL REWORK A n .~a /~.~ / *CASING SIZE CASING DEPTH IJBING SIZE FOR CONVERSION PURPOSES 24 BBLS EQUALS 1000 GALLONS ARRIVED ON LOCATION: INJECTION PRESSU RE TIME J LINER SIZE · / ? OPEN[ HOLE .r.I N ER DEPTH gSGoOR AN RL,,VOI.. I PACKER TYPE TBG VOLUME TUBING DEPTH PERFORATED INTERVALS DEPTH ! ..oOt£O:/ DEPTH /~ ,:.,,.~ I,---_ /.y.~,_? "~i! ,.,' ,,., .i-_ . d' :~ , (/ 4..-., /,,! .~.= x. .r ,;;-L. /,J, - "- '1- '[ I SERVICE LOG PACKER DEPTH ~-TX Ti C -DH T~ NO, OF' HOLES TIME LEFT LOCATIONIIAVG'L''~U'D INa. RATE [ SOLIDS ~C4 TOTAL rUU~O PUMPED I PROP~AND LIQUIDS INJECTED OIL J WATER Ty~ I ~ , . (~.l~.wc[ Ou...ow~ ,I TEST ALLOWABLE ~vs ~TEST ALLOWABLF f~' ' ST~MU LA1J0 N. ]'~ EATMENT REPORT BWL-494-J~' PRINTED IN WELL_,AME ?D .UFBE. - POOl ,c-,X,-.,,,.,/¢..,., ISTAT£ ,~pe ~OWELL DIVISION OF THE DOW CHEMICAL COMP_A_~,NY ,/ CUSTOMER RE~ EN TATIVE JOB DONE DOWN ~BING I CA~ING I ANNULU'A~ ~PE OF WELL GAS TREATMENT NUMBER ALLOWABLE PRESSURE TBG :.._..v/ (-"CS G: WATER IN J/. cO TYPE OF SERVICE NAME ,.. , -~' ADDRESS CITY. STATE & ZIP CODE REMARKS:__ AGE OF WELL .Ew WELL REWO.K An CASING SIZE CASING DEPTH TOTAL DEPTH /S 2~/ · TUBING SIZE ClRCo BHTo TUBING DEPTH FOR CONVERSION PURPOSES 24 BBLS EQUALS 1000 GALLONS ARRIVED ON LOCATION: L,. E)S,.Z.£ OPEN HOLE ,~////I /L/Z" CSGoOR ANRLoVOL. PACKER TYPE TBG VOLUME PERFORATED INTERVALS q ,/ I · ).-q 25,.: PACKER DEPTH STATIC BHT° NO. OF DEPTH I HOLES TIME . ,, ~?,: ,'~ INJECTION PRESSURE SERVICE LOG TIME LEFT LOCATIO~ AVG.LIQUI D INJ. RATE "~TE' SO'lOS ~"l O'L TOTAL 'L['O PU~'D I WATER PROPS AND LIQUIDS INJECTED TYPE · ISIZE OR PURPOSEI AMOUNT ,, . . ' ~ [ ( .r,X /:-Y' ...x.: ,_ CALLJDATE B__ACKI CUSTOMER REP. CONTACTED e ]CU 'ST~OMER n SATISFACTORY [P~ROD BEFORE TREATMENT IPROD. AFTER TREATMENT CONSI'ERED r-I UN SATI SFAC TORY, L! D IN J""'] S~,RVfC£ F'luNKNOWN I TEST ALLOWABLEI DAYSITEST ALLOWABLF STIMULATION TREATMENT REPORT, BWL-494oJ PRINTED IN U~.A. t~ELL NAME AND HUMBER co~ !ELL DIVISION OF THE DOW CHEMICAL COMPI" -uCATION O FOR?210N STATE ADDRESS CITY. STATE & ZIP CODE REMARKS:._~ ,4/o.vo//,,,~,' /,(~7'(-/0 //2,4'0 FOR CONVERSION PURPOSES 24 BBLS EQUALS 1000 GALLONS ARRIVED ON LOCATION INJECTION PRESSURE TIME CUSTOMER REP~%..y EN TATI VE JOB DONE DOWN 'nJBING I CASING IAHNULU$Ar'l sD cF1 TYPE OF' WELL OIL GAS AO eO AGE OF WELL WELL REWORK AO eO CASING SIZE CASING DEPTH ITREATMEN T NUMBER ALLOWABLE PRF. S~URE TBG: I CSG: WATER INJ. cO DO TOTAL DEPTH TUBING SIZE CIRC. BHT. TUBING DEPTH LINER SIZE LINER DEPTH PACKER TYPE PACKER DEPTH OPEN HOLE CSG.ORANRL.VOL, TSG VOLUME STATIC BHTo PERFORATED INTERVALS DEPTH DEPTH NO. OF HOLES, SERVICE LOG NO. OF DEPTH HOLES TIME LEFT LOCATION/¥/,LIQUID INJ, RATE DOWELL LOCATION ~.,~. ,., % AD..MNJ, RATE {SOLIDS INC,)I TOTA/ FLUID PUMPED ! I FNAL ~MP ~ ~SURE SHUT IN PRESSURE IMMEDIATE ~S MINUTES )WELL/ [NGINEER~_ .,' BACK PROPS AND LIQUIDS INJECTED 'FF?E IZ_Z CR F~P.?OS At, REP. CON~ACTED r-i SATiSFAETORY IPROD, BEFORE TREATMENT [] IPROD. AFTER TREATMENT ~ UNKNOWN TEST ALLOWABLE DAYS ST ALLOWABLE OIL AND GAS CONSERVATION CO~I~EE-, 50-133-20098 J C~ EN~-:~ MONTHLY REPORT OF DRILLING - AND WORKOVER OPERATIONS ~L - 18730 ~ 3 ENO ~ , iin~nn ~1 ~n~nnv n~ ~nl~n~n Trading ~y Unit ADDRESS OF OPhiR ' g ~V~ ~O 909 h'est 9th Avenue, ~orage, Alaska 99501 State. G-9 (32-2; )- j '-- ~v --j Conductor 41 , Leg 2, 1886'N ~d 1382'1V from SE co~er McArth~,r R~ver - l-l~l~ ~ction 29' T9N, ~3W. ~I. ,, S~o~ r. . ~., (~o~, Section 27' T9N 68-16 , 13 RF~ORT TOTAL Dlr~mrI AT F~CD OF MONTI~ CHA_NGF~S IN HOLE ~-~- CASING AN~D C~-~IF~¢TING JOBS INCL,;DING D~H SET AI~D VOL~ USED P]~P~FOI~ATIOI~S ~F~STS A_N-D RESULTS FISHING JOB~ $I~'~¢K I~ HOI~ AND SIDEoTRACKL~D HOL~E A~TD ANY OTHER SIGNIFICANT G~ZANG~ IN HOI~ COI~DITIONS Co~unenced operations on TNJS well #G-9 at 9'00 a~, 8/31/72. Moved rig from TBUS G-16 to TBUS G-9. Rigged up ~chiumberger. ~ Pro~i-ie logs ~nd rigged up to pull tubing. -i,S,G' h.~b~/~~.;~/~~_,.~ ........ ~,,h~,o.~.~ "~. ~ ~'~ .TL~ Dist. t)rilg..Supt ~ 9/14/72 ... N~lrE -- Report on this form i, reclu,,ed for each calendar month~ regardlet, of the ,totus o! operations, end must be filed In duplicate with the oil and gas conserver/on committee by the IBth of the eueceedmg month, uele~ Othetwiae chcected. ~.,;~ U,LA?'O N~TI~ EATM E NT REPORT IWL-494-J PRINTED IN U,$.AoI WELL NA_~E AHD NUMBER __ POOl /Y-×.:..-,,.,: /- "E L DIVISION OF THE DOW CHEMICAL COM ATIOH , CUSTO~R ~Ef ,, TAT, VE · /.- '//· ~' A- C /'- .i -/ ..... ' ,'.c FORMATION COUNTY' ~ ~',,- STATE / ~ _ ,4, ,z~' , / -/~ ~,.'// TYPE OF SERVICE CUST. NAME F - ' '~" ADDRESS J CITY, STATE & ZIP CODE REMARKS:__ FOR CONVERSION PURPOSES 24 BBLS EQUALS 1000 gALLONS ARRIVED ON LOCATION: Ii DATE '' i TRE4~TM EN T NUMBER '" JOB DONE DOWN ALLOWABLE PFIEsSUR£ I~PE OF WELL OIL GAS ~WATER INJw AD Dn cl-i or~ AGE OF WELL NEW WELl. REWORK An TOTAL DEPTH /~L' ~'.¢ CIRC. BHTo C~N~ SIZE CASING DEPI~ TUBII,~G SIZE TUIBING OEPTH L?R ~[ZE L NER D~.PTH ~ACKER ~PE P~HER ~D~PTH OP~M HOL~ ~SG.ORANRL.VOL, TBG VOLUME STATIC PERFORATED INTERVALS DEPTH NO. OF DEPTH HOLES TIME INJECTION PRESSU RE 2~ TIME LEFT LOCATION AVGoLIQUID IN Jo RATE MAX. PRESSURE JAVG. PRESSURE D~/~, ELL LOCATION / . .:, ,: ,- ..x CALLIDATL ~ / ~/, w' g /) SERVICE LOG <.. _,, // .. .z_., /~ c.., --"., ,'" £.:/' "'/'1 ' ' ~/-1: . -/,-' ' " 4~ ./'~ z , ":.'~' "/..',,/./,.; ,. '"",. .?/'~." - /'//../ ,>:: ' "/'/-! ,"'~ /) w,-.// , ///, .,. / / ,~/- '., :' PROPS AND LIQUIDS INJECTED FINAL PUMP IN PREE, SURE SHUT IN PRESSURE SOLIDS INC.)I TOTAL FLUID PUMPED I OIL t WATER [ ,' / IMMEDIATE ! 15 MINUTES DTELL ENGINEER ~, +*~,- -" , = ICUS TO'~I£R n SATISFACTORY [CONSIOERED D UNSATI SFAC TORY JSERVI CE: E) UNKNOWN JCUSTOMER REP. CON~FACTED TEST ALLOWABLE DAYS TEST ALLOWABLE - ~ ~ ~ SUBMIT IN DL ,ATE* E OF ALASKA ',se. other ln- ~t ructmn~ on OIL AN~t ~A EE N C~MMITTEE ~.,~ ...... ~e, '~ ~I N~c~ CODg 8 ~.E~SE D~GNA~ON ~D 8~ NO WELL COMPLETION O~~~P&~Tt~.~PORT AND LOG* ~L- 18730 la TYPE OF WELL ,,~ ~ ~*~o~%~ Q ot~o~ Injector ~ T~VZ OF CO~PLE~O~ AcSd Xx~It O~rB ~ EX B~CK gES%g Other Striation a UNITF~OR~SEN~IE ',ME OF OP,RATOR Trading ~y ~it 9 W~L NO ~ion 0il Co~y of California ,~ o, o~,~o, State G-9 (32-27) 909 West 9~ Avenue, ~orage, Al~ka 99501 '~0 F~ ~t ....~. 1886'N ~ 1382'W from S5 co.er ~ction 29' T9N, RI3W. ~n s~c,~,~,~, ~o~o~o~ S. M. · ~ ~o..~o~ ,.t....~ ~.o.~. ~.,o~ 803'N ~ 10117'~ of ~rface ~cation ~ction 27- T9N, RI3W, S. ~. ~t tot., ~.~ 10635'5 ~ 515'N of ~rface Location 68-16 8/~1/72 i 9/23/72 I 9/23/72 IRT oce~ floor - 235.60 a RT-~SL 99' MD & ~ ~ ~L'r~LE CO~L, [ 21 'INTERVALS DRILLED BY fOCAL 5~Z, ~ a TVD[9 PLUG, ~CK [ ~OW ~Y' 1~5~'~]-1fl571'~i IK~2R'~-1~5~'~ [ 0-~) [ , ''-- ' [ ~WAS D!RE~ONAL PRODUCING !H~VAL(S), OF ~IS COM~TIO~--TO~, BOSOM, NAME (~ AND (9779-9826'~); 14740-14950~ ~s 14460-14515'~ (9722-9765'~; 14555-14595'~ ~ su~ ~D~ (9936-10076'~); 14960-15175'~ (10098-10256'D); 15195-15250'~ (10270-~0312'~)original 24 TYPE ELECTRIC AND OTHE2% LOGS RUN GAMA RAY-CBL CASING RECORD (Report all strings set in well) CASI.NG SiZE 16" 9 g/g" · ' 75# [ J-SSl 623 I 22" I 1300 sx 61# / J-551 3045 [ 17 1/2T 1800 sx 14o, 43 ,,,~# N-~n{ losss: I 12 1/4'{' l 26 LINER lq~EC ORD 28 PEIiFOR. ATIONS OPTiN TO PRODU ON (Interval, s~ze and nurnber) 4 1/2" }H~I~ PRODUCTION 14460-14515 14535-14595 14740-14930 14960-15175 30 ! A~NIOUNT PULLET) NOne Nrta9 27 iUBING RE C~OP~D SCF~EE~N (MD) SIZE DEP~ SET (MD) ] PACIfiER SET (MD) GtL~ pepsi R l/2't l laa,7. . __ ........ ,{ 1~X7 2J ACID, SizOT, FiIAC2 GRE, C~dLNT SQUEXZ2, ETC D~I INI~V.~ (MD) AAiOUNC Z~D KIND OF M~TEP~L US~ i i DAlE FIRST PI%ODUCTION [ FRODUCT1ON MEIHO!) (Flowing, gas hfL, parnpmg--slze and type of pump~ .... [ Water Injection DATE OF T~ST, [HOURS TESTED ' [cnoxE SIZE [PROD'II FOR OIL--BBL GAS,--iVICF [ [ [TE~£ PEIL!OD 9/27/72 [ 24 [ .... ] ~_] >' { .... l ---~'~OV~', TUBING' [CAKING PRESSURE |CALCUI.~TED OI EEL GAS--?~ICF PT<ESS 3500 I .... 124'HOURRAT~E t~ .... I._ .... 31 DISPOSITION OF GAS (8old, used/or/uel, vented, ere ) NA LIST OF ATTACHMENTS ] VcELL STATUS (Producing or Testin~ W£JIq~R--BBL I GAS-OIL F~J%TIO .... [15700 i .... WAT~I~--BBL [ OIL GRAI/1T¥-A/~I (COLOR) WITNESSED 33 I hereby c~'~l(y that the foregoing and attached information is complete and correct as determined from all-a~ailable records sm~_ im k. Calienaer ~?,.~. Dist, Drilg. Supt. ~iT~ 9/20/72 *(See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS General Th~s form ~s cles~gned for submitting a complete and correct well completion report er, cl log on all types of lands and leases ~r'~ Alaska Item: 16: Indicate which elevation ~s used as reference (whe, e not otherwise shown) for depth measure- ments g,ven ,n ether spaces on th~s form and ~n any atl,~chments Items 20, anci 22 If th~s well ,s completed for separatc prcduct~on from more than one ,nterval zone (muir,pie core,pier,on), so state ~n ,tern 20, and ~n ~te.'~, ?o .~,how the p~cJuc~n9 ~nterval, or ~nte~vals, top(s), bottom(s) and name (s) 0f any) for only the ~nterval reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately ~dentlf~ed, for each additional ~nte~val to be seperately produced, show- ~ng the adid~t~onal data pert,nent to such ~nterval It®m26: "Sacks Cement" Attached supplemental records for th~s well should show the details of any mul- hple stage cernent~ng an5 the Iocat,on of the cementing tool Item 28: Submit a separate completion report on this form for each ~nterval to be separately produced (See ~nstruct~on for ~tems 20 and 22 above) AI~¥ OF FORMATION TE:~'i ~ IN/ I UI)IN(o INqFRVAI~ TE.~TEr) PHEF,~UHE DATA. A.N'D R3ECOVI/FIIES OF OIL ~AS 35 G EOL, OG IC WAT~q. AND MUD NAM~ ~ ~i~AS DEPT~. '~RU~ V~RT OgPT~i DATA. lm , Form P--3 f ~abrntt "Intentions" in Triplicate REV 9-30-69 ~ & 'Subseq~uphcate [$ AP1 NUMF_.IR/C~C~D~ OIL AND GAS CONSERVATION SUNNY NOTI~S AND REPORTS ,~z.~-~--~ ~L 187~0 (~ not u~ this fo~ for propo~l~ -,~ t .,~ ~ o~,,, water in~ector NAME OF OP~TOR - [ ~ ~ ~F" ~ 8UNI~ F~ OR ~SE N~E Union 0il Co. ay of California ~ c '-- ~ Trad'ing hy Unit ~~. ~ ~e., ~orage, Alaska 99b0 3 o~o~ ~ ~, State G-9 (32-27) LOCATION OF W~L ~ ~V~ 10 F~ ~ P~L, OR WI~CAT ~t~u,~c~ Con~ctor 41, ~g 2, 1886'N~~ _[~ H~thur River - He~ock ~ SE co~er Section 29, TgN~c~ n s~C.om~,v~ ~'R'~' (~OmM ~o~ ELEVATIONS (Show whether DF, RT, GR, etc ' 68-16 99' RT above MSL Check Appropriate Box To I,ndica~ N,ature of NOtice, Report, or Other Dafa NOTICE OF INTENTION TO: FRACTLRW, TRmlT MLLTIPLE COMP{RTE 8HOOT OR ACIDIZE J X~ ABANDON* REPAIR %%~LL CHAN(iE PLAN8 {__[ tother) I ~ Et, BSEq~ENT RmPOaT o~': WATER SltUT-Orr [ i REPAIRING WELL FRACTUR~ TRr-ATMENT ~[ ALTIr'RING CASI~IG 8HOOTIN0 OR ACIDIZINO ABANDONMENTS (Other) (NOTI~' Report results of multiple completion on Well Completion or Reeompletion Report and Log form ) 15 D~ SCRIBE PROPOSED OR COMPLETED OPERATIO.~S (Cleally state all pertinent details, and give pertinent dates, including estimated date of starting an3 proposed work. REASON FOR STI14ULAT ION: In-?rove profile and injection volume to maintain the maximum pressure efficiency for secondary recovery of the Hemlock reserves. }~igh pressure injection work on the Grayling injectors indicate there is almost no chance of stimulation and profile improvement aside from acidizing. The profile and injection volume was greatly improved by acidizing TBUS D-24, a Hemlock injector on the Dolly Varden Platfom. It is proposed to acidize the Grayling injectors using basically the same technique, of staging 12-10 mud acid, preceeded by a dilute (2.5%) hydrochloric 50-$0 solvent- in-acid dispersion and followed by a dilute (2.5%) hydrochloric acid. Diverting mterial will be run between stages to allow controlled treament of the entire interval. It is estimated that this proposed injection stimulation will result in an adequate amount of injection into the 26% (an average for the five injectors) of the producing intervals presently not taking any water and increase the injectivity into an additional 20% of the intervals which are presently receiving an inadequate amount. This treatment is necessary for an efficient secondary recovery of the }Iemlock reserves. Form P--3 REV 9-30-6 9 tJubmit "Intentions" in Triplicate & 'Sul:).~equent Reports ' m Duphcate STATE OF AI. ASKA 5 AP1 NUMEPACAL CODE OIL AND GAS CONSERVATION ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dlzll or to deepen Use APPLICATION FOR PER1VJlF--" for such pro~osals ) WELL L_.J WELLii OTHER NAME OF OPEB-&TOR ADDRESS OF OPERATOR (continued) 4 LOCATION OF WELL At su! face TBUS G-9 13 ELEVATIONS (Show whether DF, RT, GR, eec Check Appropriate Box To I,ndir. ate Nature of N~)tice, Re NOTICB OF INTENTION TO: FRACTLRE TREAT 'dULTIPLB COMPI,ETE 8H00T OR ACIDIZE J j ABANDONs n£PAIR ~ ELL CHANGE PLANB tOther) 6 I.,E,A$E DESIGNA'I'ION A_ND SERIAJ.~ NO ? IF INDIA.N, ALLO'rr~:~. OR TRIBE NAM2~ 8 UNIT, FARM OR 1.2gASE NAME 9 WELL NO 10 FI~.I-D AND POOL, OR WILDCAT 11 SEC , T, R, M . (BOTTOM HOLE OBJECTIVE) 12 PERMIT NO zoO, or O~her Data BUBSEQUENT REPORT OF: WATBa SaUT-orr REPAIRING WELL tRACTS'RE TREATMENT -- ALTERING CASI'~O SHOOTING 0a ACIDIZINO ABANDONMENT* (Other) (NOTE. Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15 D~SCRIBE PROPOSED OR COMPLETED OPERATIO.XS (Cleally state all pertinent details, and gi~e pertinent dates, including estimated date of starting an) proposed work. PROCESJRE: 1. Run wireline to detemine height of any fill in csg. If fill covers peris, circulate clean using mcaroni tbg run thru existing tbg. 2. Run i set Dia-Log wash down pack-off assembly w/sufficient 2-1/16" tbg to reach btm peris w/pack-off seated in X-nipple. 5. Acidize as directed, (60,000 gal 12-10 mud acid ~ 61,000 gal 2.5% ICL). 4. Reconnect well to injection system G inject wtr until all chemical is displaced into the formation and away from the wellbore. S. Retrieve pack-off assembly and 2-1/16" tbg stiner. 6. Return well to injection service. Profile and evaluate. ESTIMATED STARTING DATE: 2/1/72 f{I t~- ~-/mai( (This space for State ofl~¢(use) APPROVED BY ~/~ .... CONDITIONS O~PPROV~, I~ TITLE Dist. Drlg. Supt. D~.TE 8/12/71 See instructions On Reverse Side Approved Copy Returned "" '~,'~"VlLILAT10'N'°TI~EATMENT FIEP01:{T BWI..~-494-J PRINTED IN U.$oA. . ~NELI,: NAME AND NUMBER POOl /':' '/ .f",'. ,~'~,'~///-,' ',' _-v., -! r _:/:. NAME Z. / ~- -~' _ ~r"'OWELL DIVISION OF THE DOW CHEMICAL COM~'~ 'Y .~CATIOH CUSTOMER RE~, ~ENTATI VE ./t//-- < ' JOB DONE DOWN TUBIR=AE1 I CASINGBi_i I ANNULUScF1 I STATE_.// TYPE OF WELL ~/ , , / An B13 AGE; OF WELL NEW WELL REWORK FORM~./T I ON ' ( / / /, /,' D AT E TREATMENT NUMBER ALLOWABLE PRESSURE TBG: I WATER INJ. cO o!3 TOTAL DEPTH CIRC. BHTo CASING SIZE CASING DEPTH TUBING SIZE TUBING DEPTH ADDRESS CITY, STATE & ZIP CODE REMARKS:__ FOR CONVERSION PURPOSES 24 BBLS EQUALS 1000 GALLONS ARRIVED ON LOCATION: TIME INJECTION PRESSURE LINER SIZE LINER DEPTH OPEN HOLE ~SG.OR AN RL,,VOL, PACKER TYPE PACKER DEPTH TBG VOLUME STATIC BHTo DEPTH PERFORATED INTERVALS NO. DEPTH DEPTH HOLES SERVICE LOG IS:. / //(./- TIME LEFT LOCATION AVG. LIQUID INJ. RATE MAX I ./' .~,, ,//.~,....~, CA L LI DA T I- BACK{ , , ; TYPE o;ZE OR PdPPOSEt ,~':QU,N' F FINAL PUI~4P IN PR~SURE~ SHUT IN iPR[SSURE l . ,~0,,~ ,~ ~,.~ ]z-.' , - -~- .~ l/~:..- //... /~ - ~ . .:....,~ ~ CdS10~ER REP' CON~ACTED ~ONSIDERED, sERVicEJC~'STOMER ~ SATISFACTORY ' PROD' BEFORE TREATMENT ~ UNKNOWN ~ UNSATISFACTORY ~TEST ALLOWABLE~ IPR°D' AF~ER TREATMENTDAYS TEST~ ~LLOWABLF~ Form REV 9-30-69 Submit "Intentions" in Trtphcate J & 'Subsequent Reports" m Duphc~te STATE OF ALASKA OIL AND GAS CONSERVATION COMMII'I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dllll or to deepen Use APPLICATION FOR PER1VIII'---'" for such proposals ) o,L ~, oAe ,~, water injector W£LL ~_~ WELL OTHER NAME OF. OPERATOR Onion 0il Company of California ADDRESS OF OPERATOR 909 W. 9th Avenue, Anchorage; Alaska 99501 4 LOCATION OF wELL Conductor 41, Leg 2, 1886'N & 1382'W fm SE corner Section 29, T9N, R13W, SM. ~ APl NUWIF--~/CAL CODE 50=133-20098 ~6 LEASE DES/GNA/ION A-ND SERLa~L NO ADL 18730 T IF INDIA.N, A.I.J.,O'l-r~:~: OR TRIBE 8 UNIT, FA/{NI OR LEASE NAME Trading Bay Unit 9 WELL NO State G-9 (32-27) 10 F~W.I.~ AJq'D POOL, OR WILDCAT McArthur River - }temlock 11 SEC , T, R, M , (BOTTOM HOLE OBJECTIVE} Sec. 27, T9N, Ri3W, SM. 13 ELEVATIONS (Show whether DF, RT, GR, etc 12 PCB.MIT I~O 99 ' RT above ~L 68-16 ,4 Check Appropriate Box To I, ndica~e Nature of hk)tice, Re )orr, or O~her Daf, NOTICE OF INTENTION TO: TEST WATER 8~UT-OFF PULL OR ALTER CASINO ~ FRACTLRE TREAT MULTIPLE COMPI ETE SHOOT OR ACIDIZE ABANDONs tother) r ] SUBSEQUENT REPORT OF: 8H00TIN0 OR ACIDIZIN0 , ABANDONMEKT* (Other) (NOTE Report results of multiple completion on Well Completion or Recompletlon Report and Log form ) I5 D~ SCRIBE PROPOSED OR COMPLETED 0PERATI0%S (Clearly state all pertinent details, and gh'e pertinent dates, including estimated date of starting an} proposed work. Reference is made to original Sundry Notice of Intent submitted 8/12/72 and approved 8/25/72. Proposed program is listed as follows: RP~N FOR ST~LATION: Trading Bay Unit State G-9 is a ttemlock Zone injector on the East flamk of the field. The well is currently taking 12,550 B/D at 5450 psi. Over 60% of this water is entering the 1st and 2nd banches with no injection into the 6th or 7th benches. ~he recent attempt to acidize well G-19 down the existing tbg string proved unsuccessful, and indicated an ineffectiveness in diverting acifl to the various benches. To achieve aaequate stinnlation, each bench in the }iemlock must be acidized individually. high pressure injection work on the Grayling injectors indicate there is almost no chance of stimulation and profile ingrovement aside from acidizing. The profile aha injection volume was greatly improved by acidizing TBUS D-24, a Hemlock injector on the Dolly Varden Platform. It is proposed to selectively reperforate and acid stimulate individual benches ~Form I~LEV 9-30-6 9 Submit "Intentions" tn 'I~phc~te & Sut~sequent Reports ' m Duphcate STATE OF ALASKA OIL AND GAS CONSERVATION COMMII'[EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use th~s form for proposals to d~Hl or to deepen Use APPLICATION FOR pEB. MII'-~-" for such pro~msals ) OIL ~ 6A8 ~ WELL ~-- WELL~ OTHER N -kAIE OF OPERATOR ADDRESS OF OPERATOR 4 LOCATION OF WELL At sm face TBbS G-9 }~ I ~ ELEVATIONS (Show whether DF, RT, GR, etc 14 Check Appr~ia~ Box To Indkate Nature of N~tlce, Re! NOTICE OF INTENTION TO: TEST WATER RHUT*OFF PILL OR ALTER CARING FRACTLRE TREAT MULTIPLE COMPI ETE SHOOT OR ACIDIZE AEANDON$ REPAIR 'A ELL CHAWGE PLANS (Other) ~ Other) 5 AP1 NLFM.EPACA. L CODE 6 I.,E,A~E DESIGNA~CION A_ND SE, RIAL NO 7 IF INDIAN. A. LI.,Oi-r~:~. OR TRiBE NAME 8 UNIT, FA. H1VI OR LEASE NAME 9 W]g~L NO 10 F!EI.D A.ND POOL, OR WILDCAT Il SEC , T, R, M. (BOTTOM HOLE OBJECTIVE) 12 PgRI~LIT NO ~ort, or Other Data SUBaEQUENT RBPORT OF: WATER SItUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING , ABANDO,%MEIqIT* (NOTE. Report results of multiple completion on Well Completion or Recompletion Report and Log form ) D[ SCRIBE PROPOSED OR COMPLETED 0PERATIO.%S (Cleally state all pertinent details, and give pertinent dates, Including estimated date of 8tatting an) proposed work. using straddle packers. 1his procedure is designed to distribute the injected water over the entire 7 benches, provide improved profile and increase the injection capability. PROC~URE: l. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Run radioactive tracer survey. Move over G-9 & kill well w/Inlet wtr & CaC12 if needed. Remove tree & install B0k. Pull ~ i.d. all tbg. Retrieve permanent pit at 14,417'. Perf individual benches as per attached. RIH w/bit ~ csg scraper ~ CO to 15,281'+- (7" scraper). Acidize w/straddle tool (Lynes pkrs) as per attached. Set retrievable pkr at 1~,440' & inject thru dp. Run radioactive spinner - tracer survey thru dp. Set 7" pkr on wit, line as indicated by profile logs. Run 3-1/2" tbg w/hydroset pkr in 7", stab into lower pkr. Set ~ test pkrs. Oisp annulus w/diesel oil as pkr fluid. Place Well On injection - liemlock. BSTIMATED STARTING DAT~: 6/5/72 16 I hereby certify that the forego!nf la true_and correct (B~ E~ T~!ev~ ' (Thl~ space for State o~c~)~ TITLE Dist. Drl~. Supt. DATE TITLE DATE See Instructions On Reverse Side Df'/" C~' 3/10/72 Bench _ Total Sta,oe None 8 lO lO RECOMMENDATION TO ACIDIZE TBUS G-g GRAYLING PLATFORM- McARTHUR RIVER FIELD COOK INLET, ALASKA TABLE II _ Reperforate .i.ntefvai]- "Fe'e~ 14,484-504 2o None None 14,626-646 20 14,736-746 l0 14,782-792 l0 14,808-818 lO 14,856-866 lO 14,900-910 lO 14,914-924 lO None None 15,094-104 lO 15,110-120 l0 15,130-140 10 15,152-162 l0 15,212-222 10 !5,230-240 lO i - 14,484-15-240 160 Straddle Feet .I. nterva, l_ ~Treated ' 14,480-520 14,540-580 14,610-650 14,708-748 17,780-820 17,835-875 14,894-934' None 15,084-124 15,128-168 15,206-246 ii 26 25 20 20 20 Trea tmen,t Vol ume- Ga 11 OhS ]2'10, H'C~-HF' " 2-1'/2%j HCL' OVer'fluSh ,3900 1560 3750 1500 3000 1200 3000 1200 3000 1200 22 3300 1320 20 3000 1200 None None None 20 3000 1200 20 2O 213 3000 1200 3000 1200 i u _ 31,950 12,780. , 2/15/72 UNION 01I, CO OF C-*,l~;-O AI_\SKA DISTRICT Transmittal TO- - --~-o~-Alm~k~ FROX!' _l~to~_Otl..Cmspau3_o~X. alifornia Trep,$mltlcd hcr:,vilh are ~,h¢ following' DATE' WELL Run No. Sepia Blt~e Scale. Induction Electrical l.og Dual Induction Laterolog B}iC Sonic/Caliper Bi'lC Sonic/(;amma Ray B}IC Sonic/ Callpe./t, amma Ray Log Formatioa Sonic tog (Fs) Denait)'~Gamma Log Formation D:msily Log (Fd) Ncutron I.og Formation Neutron I.og CD51 or }!igh Resolution Dipmeter CDM Safe~y Print CISM or Printout CI;51 Polar Plots Pro.<i mi ty -?,Ii crol c2/Cal ip~r I,og Gamma Ray Coliar Log Cemon~ Bond Log 8~U~ 1 og Core Descriptions. Convc:~tion:~l, Core DescrSi~:io:~s, Side.-?!I Core A~a!>-si s Core Chil;s . St, mi,! t' Cut Dcj!i ~t(~, Form No P--4 REV 9-30-6~ STATE OF ALASKA OiL AND GAS CONSERVATION COMMITTEE tMONTrHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OtL ~ GA8 ,~ WELL ~- WELL OTHER SUBMIT II~ D~2~LICA/'E 2 NAME OF OPERATOR Union 0il Compan~ of California 3 ADDHESS OF OPEI~kTOR 507 W. Northern Lights Blvd., Anchorage, Ak. 99503 4 EOCA~ON OF WEL~ 1886'N & 1382'W from SE corner Section 29, T9N, R13W, SM. APl NL~IE~CAL CODE 50-133-20098 6 LEASE DESIGNATION A\-D SEHIAL NO ADL-18730 IF I.~DI~.N %LOl l~:E OR TRIBE NA.%IIE 8 L.~'IT,FAiR-M OR LEASE NA_ME Tradtn$ Bay Unit 9 WELL NO State C-9 (32-27) 10 Fr~ ~D POOL OR WILDCAT McArthur River - Hemlock 11 SEC, T, R, M (BOTTOM HOLE O~~ Sec. 27, T9N, R13W, SM 12 PERA{IT NO 13 REPORT TOTAL DEPTH AT END OF MONTH, CI4_A.NGES IN HOLE SI~E, CASING A_N-D CEMENTING JOBS INCLUDING DEPTH SET ~ VOLU1VIES USED, PERFORATIONS, TESTS AND HESULTS, FISHING JOB~, JI/NK IN HOLE A_ND SIDE-TRACKED HOLE AND ~Y Oq~{F~R SIGNIFICANT C~ES l~q HOL.~ CNDNI)ITIONS TPJ~DING BAY UNIT STATE (I,9 {,3,,2-,27,,),, Schlumberger perforated 4 holes per foot 14595-14625' for DST #2. Recovered 50 bbls of oil, 6% BS&W, 30" (1rarity. Perforated 4 HPF: 14460-14515'; 14535-14595'; 14740-14930'; 14960-15175'; 15195-15250'. Ran 3-1/2" tubing with top packer @ 14,329' and bottom packer @ 14650'. Set and tested packers - OK. Removed BOE installed Xmas tree and flow lines. Rigged up t; swab Hemlock zone water aquafer~[ Swabbed and recovered total of 800 bbls in 41-1/4 hfs from Hemlock aquafer. Released rig 8/7/68. Unable to run thru tubing wth wire line tools to set bottom plug and open oil zone for flow due to obstruction in tubing. Hoved rig back 8/9/68. Ran l-l/2" and 2-1/16" tubing inside 3-1/2" tubing. Circulated clean with wtr @ 14582'. Pulled and laid down 1-1/2" & 2-1/16" tbg. Set plug in tubing tail isolating water zone. ~ell shut in pending oil zone completion. RIG RELEASED 2:00 PM 8/11/68 AN('HO~AGE hereby certify ~/~e £o~ e !111// I I~ Dist. Drlg. Suptd, 9/10/68 SIG~ _~ ~ -- I. ~-~- - I ~ ...... DA'i E .. m-~ lalley / NOTE--Report on th~s ~rm ~s reqmred for each calendar month, regardless of the status of operatm~% an~ must ~ filed m d~phcate w~th the D~wmon 0f Mmes ~ Mmerals by the 15th of the succeedmg momth, unless othe~se d~rected Un~on Oil Compan( California 507 W. Northern Ughts Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 union · September 9, 1968 Mr. T.R. Marshall, Jr. Petroleum Supervisor Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Marshall: We are returning to you P-7 forms on Kenai Deep Unit #2 and~ B~¥ Unit S~o ~__o. We regret that these forms are incomplete but at present the necessary data is not available as both wells are temporarily shut in. Kenai Deep Unit ~2 will not be produced until all drilling is completed in the Gas Field. This should be in the fairly near future and at that time we will notify you and the form can be returned to us for completion. It may be a matter of months before TBUS G-9 will be worked on further. We will also notify you at that time. We thought it preferable to send you a somewhat incomplete form rather than wait for an indefinite period after completion of drilling before trans- mitting any completion information. /bg Very truly yours, , FORM 401-ANC-W (8/67) Form P~7 ' ~ SUBMIT-IN DUPE . STATE OF ALASKA , (se,~ orner ~ . ~ struct~ons on OIL AND GAS CONSERVATION C'OMMITTEE" ~,,~e WELL cOMPLETION OR RECOMPLETION PORT , ND LOG'* la. TYPE OF WELL. b. TYPE OF COMPLETION: N~.W ["--~ WORK [--'] YVELL 0% ER 2 NAME 0F OPERATOR Union 0il Company of California DEEP-[] PLUG[ DIFF [] ,~t '" BACK EN RESVR her -. AP1 NUM_ERICA~. ~ CODE 50-133-20098 6 LF~kSE DESIGNATION AND SERIAL NO _ ADL-18730 IF INDIA_~, ALLO~ OR ~IBE N~ 8. UNIT,FA~-VI OR LEASE NAME Trading Bay Unit 9 WELL NO ~cArthur River - Hemlock s A.DRESS Or OPERATO" State G-9 (32-27) ~ ~", .... 10 FIELD AZq'D POOL, OR W~T 507 W. Northern Lights Blvd,, Anchorage. ~~ ,~~.~' ~. LOCATION 0F WZLLq~port locdtton clearly and in ~[ordance ~tth'an~e ~q~e~S) ~' ~ -- ~2 "~ ~ ' ~~' f ; ', O~E~IVE) At top prod interval reported below 803'B a 1011Ia of ' ~. ~atto~ At total dep~ 10635'~ & 515'N of Surface Loca~ib~ ' ~', ~ ,~" ,'~ Se~. 27, TON, R13W, SM :~ :" 68-~ 4/22/68 [ 7/25/68 [ 8/~0/6$ ~ '? JRTi$C~ f~%or-~35.601 t RT-MSL 99' 18 T~ D~H, ~ & TVD~9 PLUG, ~K MD & ~D~. ~ ~LT~.CO~, -% ~ ~1 O INTERVALS DRILLED BY ] / ~OW ~-' 2~ { /ROTARY TOOLS .... I CABLE TOOLS 15330'~-10371'~I 15328'~-10369'~1 :2: ~ Z ' J :~ ,~ zO-TO [ - ~ PRODUCING ~V~(s). OF ~S COm~IO~--~,' BOSOM, N~i(~ A~' ~)% H~I.~~ ' ]m 'wAs DIRE~ON~ I~ .~ D" ~ ~w~ } SURVEY 14460-14515',~ (9722-9765'VD; 14535-14595'~}t¢779~98~6,'~)i 1~40-14930~ Yes Ga~ by-Neutron,, CBL - inside casgg~,~ ~ ~ ,..:' ,",, :: ,, C~G ~ (Re~ all stria%et m~ell) ' %2 9-f/W' ho. 3.5. 7 l s-so ! osss. I 28 PE~O~TIONS OP~ ~ PRODU ON (Inte~al, raze ~d numar) ~ -ACID, SHOT, F~'~, C~ SQU~E, DEF-TII I1TI~iRVAL (MD) AA/iOUNT A_ND FLIND OF lVIA. TE~.~IAL ~ 4 - 1/2"HPF v PI:~DUCTION _ .' DATE FIHST Pl%ODUCTION [ PRODUCTION ME'£HOD (Flowing, gas 11£'t, pampmg4~[slze and type of pump) ~aou-~s ~'~a~ 'lc~ox~. s~z~. IP~o~>'~ fOR Om--~iL. ~xs--~rcr I~V~r, TUBII~G; ~G ~S~ 1~~ O~BBL. G~~ 31 DISPOSITION OF GAS (8old, uled ~or fuel, vented, etc ) ' 14460-14515 14535-14595 14740-14930 14960-15175 15195-15250 32. LIST OF ATTACHMENTS A.NfOUATT PUl,? IWELL STATUS (Producing or ~nut-~n) Testing 8IGNED TITLE Dist. ,Drilling Superintenden~ATE 9/3/68 *(~ee Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS ,, Genei'al. Th,s form ,s des,g~.'ed fc}r su~m!tt,ng ~ complete: a;nd correct well co~n'l~'t~o report end log on ~11 tyl~es of lands and leases in Alaska ~ ~' , Item:' 16: Indicate which elevahon is ,~s6d as reference (where not otherwise-sh-~,,,Q'n~.for depth measure- C~4' ment~'g~ven mather spaces on th,~ form'~nd ~n any attachments ' _~.~. - :lternm' ~ 20, ~nd 2L2,.: If th~s well ~s' ~ompleted for, separato prC~duchon from. more than one ~nterval zone -.~ (mu.l.~.~ole'compl~,on). so state ,~ item~2~, an~l ,n ,tern _225"show the.~ prcduc,ng ,nterval, or ,ntervals, ~~"-~ . top.~, b~ttom(s)~nd name (~)(,f"~ny)/f~r only ~the int~-~l 'r~ported i~ ,tem 30 Subm,t a separate report L,... ~' _(~a.~e} o~ th,s f~im, adequately j~c~ent,;l:ied, for each ~ddlt~id~,~l inte, val to be seper~tely produced, show- ~.4...., -?-~n~ ~e..,~did~hon,~l data ,perhnent-to s~h interval ' ~:Z .~'~.lt®m26: ;'Sacks Cement": Attach;~l supplemental records for this well should showlthe details of any mul- .2~-tiple:stecje cem~n, hng and the Io~bhon oF the cementidg~todl. 'Item ~8: SulSmlt'a separate completion Feport bn this fdrm~for each ~nterval to be separately produced. "(See jnstruchon for items 20.'and 22 above) , ~ WATER AND MUD 35 GEOLOGIC MARKIIiI~ NAME DST //1: 14660-14690' - IflP 4'860#,.,IFp (1) 1201//, ~$IP 399211, IFP~ (2) 1777'~, ,,SAs ~,m Fr? (2) 992 ;: Fsn,' 4860t . Rgvef~eit,___ ___~_°dt rag hole flut& ghd salt wat~k'~- no oil~~ Top of Itemlock 14460 - -..- .(13,'670'-) '" ~ ;- ~ DST t12: 14595-14625' - IflP 4,95611, IFP (1) '48//, FF1~ (~1) 19211, ISIP 3968#, ' I1~ (2)~192//, FFP (t2) 1201#~ F$IP 3992#.,-FLIP 4956#. Rev~r~ed~ out 50 bblg oil, 6Z ,BS&W, 30°~iP~ ~i'avity.' Squeezed DST t11 pelfs thz~u-'~cehent reta~,n~,'r>~ 14,6Z~3 ** DST //2 perfs open for pr6~tict~ion "' ~ _ None ; ,. . UNOCAL WELL RECORD SHEET A PAGE NO. LEASE Tradinq Bay FIELD McArthur River WELL NO. G-9 LOCATION: Conductor 41 Leq ~2, 1886' N & 1382' W of SE corner, Sec. 29, T9N, R13W, S.M. PERMIT NO. 68-16 SERIAL NO. ADL 18730 TD 15328' TVD 10372' DEVIATION (BHL) 520'N & 10631'E F/Surf Loc. COMPANY ENGINEER Chudanov, Harness, Leon SPUD DATE 7-7-89 COMP. DATE 7-20-89 CONTRACTOR Pool Arctic Alaska RIG NO. 54 TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 3 1/2", 15.5~, E&S ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED 125' 228' 103' 23.3' 46.6' CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 16" 75~ Butt J-55 623' Cmt'd w/130Osx 13-3/8" 61~ Butt N-80 3044' Cmt'd w/2300sx 9-5/8" 40,43.5 & 47~ " N-80 & Pll0 10555' Cmt'd w/4200sx 7" 29~ " N-80 15328' Liner cmtd w/300sx Tie back to surf cmt'd w/850 sx PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 7/30/68 14660'-14690' 15281' DST ~1 Sqzd w/lO0 sx Open for Injection 7/31/68 14595'-14625' 15281' DST ~2 8/03/68 14460'-14515' 15281' Injection 8/03/68 14535'-14595' 15281' Injection 8/03/68 14960'-15175' 15281' Injection 8/03/68 15195'-15250' 15281' Injection 1/09/70 15195'-15205' 15281' Injection 1/09/70 14960'-15175' 15281' Injection 1/10/70 14710'-14930' 15281' Injection 1/10/70 14535'-14685' 15281' Injection 1/10/70 14460'-14515' 15281' Injection 9/08/72 14736'-14746' 15281' Injection 9/08/72 14782'-14792' 15281' Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS Water injection well WELL HEAD ASSEMBLY TYPE: DEC201989 Gas Cons. Commissic., CASING HEAD: Shaffer 12" 3M x 13-3/8" SOW. Type KD · CASING SPOOL: CIW 12" 3M x 12" 3M "WF" w/7" slips and "X" seal. TUBING HEAD: CIW 12" 3M x 10" 5M DCB TUBING HANGER: CIW DCB-FBB nominal 10" x 4-1/2" EUE up & 4-1/2" MMS us improved buttress TUBING HEAD TOP: CIW 10", 5M MASTER VALVES: CIW 4-1/8", 5M, FL Gate valves w/salt water trim CHRISTMAS TREE TOP CONN: 4-1/2" EUE UNOCAL WELL RECORD SHEET A PAGE NO. LEASE WELL NO. FIELD LOCATION: PERMIT NO. SERIAL NO. TD TVD DEVIATION (BHL) COMPANY ENGINEER SPUD DATE CONTRACTOR TYPE UNIT COMP. DATE RIG NO. DRILL PIPE DESCRIPTION ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION Open for Injection 9/08/72 14808'-14818' 15281' 9/08/72 14856'-14866' 15281' 9/08/72 14900'-14910' 15281' 9/08/72 14914'-14924' 15281' 1/29/82 15050'-15170' 1/30/82 14950'-15050' 1/30/82 14840'-14930' 1/31/82 14785 '-14840' 1/31/82 14460'-14515' 7/16/89 14460'-14515' 7/16/89 14535'-14648' 7/16/89 14710'-14753' 7/16/89 14753'-14930' 7/16/89 14960'-15072' 7/16/89 15076'-15175' 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) 15208'(junk) Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection Open for Injection INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARk WELL HEAD ASSEMBLY TYPE: CASING HEAD: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN: LEASE GRAYLING UNOCAL DRILLING RECORD ~ ALASKA REGION PAGE NO. 1 of 3 WELL NO. TBUS G-9WO FIELD McARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 7/7/89 15208' COMMENCED OPERATIONS ~ 0700 HOURS ON 7/7/89. Skid rig 54 over slot 41, leg 2, TBUS G-9. Modified rathole due to interference with well bay piping. Rig up wireline. Pressure test lubricator to 500 psi - OK. Ran in hole with tubing punch and perforate (7) each 1/2" holes @ 13950'. Circulate well with filtered inlet water. 7/8/89 15208' Continued circulating filtered inlet water-well on vacuum. Install back pressure valve. Remove CIW production tree. Install & test BOPE to UNOCAL specifications. Backed out holedown pins on tubing hanger. Pulled out of hole with tubing string - found part in 3-1/2" tubing @ 910'. Changed top pipe rams from 4-1/2" to 3-1/2". Set test plug & tested BOPE. Attempted to pull test plug. Plug stuck. Pick up oil jars & (3) each 4-3/4" drill collars. Jar on test plug - no recovery. Pick up 3-1/2" drill pipe while waiting on new CIW tubing spool. 7/9/89 1686' Continued picking up 3-1/2" drill pipe. Pumped filtered inlet water down annulus-well on vacuum. Pressure test between WE spool & DCB spool to 3000 psi - OK. Replaced 12" 3K X 10" 5K DCB spool. Pressure test secondary seals to 3000 psi - OK. Ran in hole with 3-1/2" overshot & engaged fish @ 910'. Worked stuck tubing with 40K overpull. Rig up wireline. Ran 2-3/8" jet cutter-stopped @ 910'. Ran APRS stringshot & performed backoff @ 1686'. Pulled out of hole laying down 3-1/2" tubing. 7/10/89 2416' Continued laying down 3-1/2" tubing-776' recovered. Ran in hole with 4-1/4" overshot & engaged fish @ 1686'. Overshot was slipping off fish. Trip for new overshot and engaged fish @ 1686'. Rigged up wireline. Ran CCL/JET cutter- stopped @ 2418'. Ran string shot-stopped @ 2419' Ran 2-1/4" chisel-stopped @ 2419'. Made mechanical backoff. Pulled out of hole with 3-1/2" tubing-464' recovered. Ran in hole with 3-1/2" overshot & engaged fish @ 2150'. Made mechanical backoff. Pulled out of hole with 3-1/2" tubing-267' recovered. Ran in hole with 4-1/4" overshot & attempted to engage fish @ 2416'-no success. Trip for 3-7/8" overshot & engaged fish @ 2416'. Pulled out of hole laying down 3-1/2" tubing. 7/11/89 12063' Continued laying down 3-1/2" tubing-9643' recovered. Ran in hole with overshot & engaged R~C~% ~ fish @ 12063'. Pul led free with 320K overpull. Attempted to circulate through fish-plugged. Drn%.Pulled out of hole wet. Laid down 3-1/2" ~~ ~ing, X-A, Stinger, X-N & mule shoe (full 0i~&GS$C0~$.~~'overy)- Set wear bushing. Ran in hole with ~ A~h0~ packer milling assembly. 7/12/89 14323' Continued running in hole with packer milling assembly & tagged packer @ 14323'. Mill on packer 3-1/2 hours. Pulled packer loose with 320K overpull. Circulated around a high LEASE GRAYLING NOCAL DRILLING RECORD ALASKA REGION PAGE NO. 2 of 3 WELL NO. TBUS G-9WO FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS viscosity sweep. Pulled out of hole with packer. Packer hung up in several places for first 15 stands.No problem through liner tieback. Made up & ran in hole with bit & casing scraper to 2000'. Slipped & cut drilling line. Continued in hole to 14400'. Broke circulation & washed down to 15023'. Had excessive torque & drag at bottom of hole. 7/13/89 15208' Plugged bit pulled out of hole. Repaired air supply to low drum clutch (12.5 hrs) run in hole with clean out assembly. Clean out from 14973' - 15208'. Still high torque & drag. Circulate @ 15208' ETD. Pull out of hole for RTTS. 7/14/89 15208' Pulled out of hole and layed down clean out assembly #5. Ran in hole with RTTS packer and set 14400'. Pressure tested 7" casing to 3000 psi for 30 minutes - OK. Released packer and pulled out of hole. Made up bit and casing scraper. Ran in hole to 15197' and broke circulation, circulated down to 15208' ETD - no fill. 7/15/89 15208' Cleaned active mud system. Circulated well with filtered inlet water, taking returns to well clean tank. Pumped a total of 1700 BBLS and the turbidity of returns was 35 NTU. Pulled out of hole with bit and scraper. Made up tubing conveyed perforating assembly and ran in hole filling drill pipe with FIW. Ran last 1786' of drill pipe dry (under balance for perforating). 7/16/89 15208' Rigged up test head, lubricator, and surface lines. Tested surface equipment to 3000 psi - OK. Rigged up wireline and ran correlation log. Set packer and re-ran correlation log - OK. Pulled out of hole and rigged down wireline. Opened Omni valve and pressured annulus to fire TCP guns. Guns fired with 2650 psi annular pressure. Perforated with 4HPF, 90 degree phasing, 32 gram charge the following: HB-1, 14460'-14515'; HB-2, 14535'-14648'; HB-3, 14710'-14753'; HB-4, 14753'-14930'; HB-5 14960'-15072'; HB-6, 15076'-15175'. Cycled Omni valve to reversing position. Reversed one tubing volume. Cycled Omni valve to well test position to check for flow - no flow. Pulled packer loose and circulate one hole volume - well taking fluid. Pulled out of hole with perforating assembly. 7/17/89 15208' Ran in hole with bit and casing scraper. Tagged fill at 15198' and cleaned out to 15208' ETD. Circulated well clean and pulled out of hole. Slipped and cut drilling line. Made up and ran in hole with an Otis "BWD" permanent packer. Spotted packer at 14240'. Dropped ball and pressured drill pipe to 2000psi to shear slip ins. Pulled 30K over pickup weight to finish ~7~%U~etting packer. Tested 7" casing and packer %~,__v against top pipe rams to 250 psi (low) and 3000 D~C~0_~ psi (high) - OK. Sheared out of packer with 80K overpull. Sheared out ball seat with 3000 Oo s. LEASE GRAYLING NOCAL DRILLING RECORD '~ ALASKA REGION PAGE NO. 3 of 3 WELL NO. TBUS G-9WO FIELD MCARTHUR RIVER DATE 7/18/89 7/19/89 7/20/89 E.T.D. 15208' 15208' 15208' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS psi. Circulated one casing volume and checked for flow - well taking fluid. Pulled out of hole. Pulled wear bushing and set test plug. Changed to 4-1/2" pipe rams. Tested BOPE to UNOCAL specifications. Pulled test plug. Rigged up tongs and hydrotest. Made up 3-1/2" tail assembly, otis seal assembly, one joint 4-1/2" tubing, and "X-A" sliding sleeve. Ran in hole with completion, hydrotesting 4-1/2" tubing to 4500 psi. NOTE: Tubing is internally coated with Tuboscope TK-99 coating. Connections are Tuboscope US Improved Buttress MMS Couplings. Continued running completion string. Hydrotested tubing to 4500 psi. String weight increased uniformly to 170K pickup and 70K setdown at 12200'. Pickup weight below 12200' increased 12K per 300' tubing to a maximum of 244K at packer. Changed 7" X 4-1/2" annulus over to 1% Nalco 3900 Packer fluid. Ran in hole, stabbed through packer at 14247', and tagged packer with seal assembly locator. Tested annulus to 500 psi. Picked back up and installed 18' of pups and tubing hanger. Landed tubing hanger in "DCB" spool. Locked down and packed off tubing hanger. Tested annulus to 5000 psi for 15 minutes - OK. Installed back pressure valve. Remove BOPE. Continued installing 4-1/16" 5m tree. tested flange connection to 5000 psi. Pulled back pressure valve. Installed double check valve and tested all tree connections to 5000 psi for 15 minutes - OK. RELEASED RIG TO WELL G-31 AT 0400 HOURS, 7/20/89. NOTE: Mike Mentder with AOGCC witnessed mechancial integrity test at 1600 hours, 7/20/89. Tested annulus to 3000 psi for 30 minutes - OK. 0026d RECEIVED LEASE UNOCAL DRILLING RECORD ~ ALASKA REGION PAGE NO. of WELL NO. FIELD DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS TUBING DETAIL JT~ DESCRIPTION LENGTH ~OTTOM TOP Otis 3-1/2" Re-entry Guide 0.90' 14317.80' 14316.90' 1 3-1/2", 9.2#, N-80 Otis 3-1/2" X-nipple (sc cplg top & bottom) 28.66' 14316.90' 14288.24' 2.02' 14288.24' 14286.22' 1 3-1/2", 9.2#, N-80 Otis 4" seal assy w/straight "J" locator X-over 3-1/2" Imp Butt pin x 4-1/2" Imp Butt pin w/3-1/2" std cplg & 4-1/2" sc cplg 28.75' 14286.22' 14257.47' 10.12' 14257.47' 14247.35' 2.02' 14247.35' 14245.33' 1 4-1/2", 12.6#, N-80 29.82' 14245.33' 14215.51' Otis 4-1/2" XA sleeve, ID=3.813", 4.48' 14215.51' 14211.03' OD=5.65", opens up 479 4-1/2", 12.6#, N-80 Pup 4-1/2", 12.6#, N-80 Pup 4-1/2", 12.6#, N-80 CIW tubing hanger 14151.69' 14211.03' 59.34' 15.03' 59.34' 44.31' 2.21' 44.31' 42.10' .70 42.10 41.40' Landed Below Zero 41.40' 41.40' RKB NOTES: 1) Ail tubing coated with TK-99 internal coating. Couplings are special clearance TKC USS Improved Buttress MMS. 2) CIW DCBS-FBB tubing hanger assembly # 156377-2-1-9 Al, 4-1/2" TKC USS. Improved buttress MMS-Bottom x 4-1/2" EUE 8rd-top. 3.980" BPV. 3.900" Bore. 3) Last pickup wt before landing = 225 K. RECEIVED DEC2O1989 & Gas C ns. commissar. chorage LEASE U~,./%L DRILLING RECORD ~ ALASKA REGION PAGE NO. of WELL NO. FIELD DATE E.T.D. DESCRIPTION DETAILS OF OPERATION, DESCRIPTIONS & RESULTS PACKER DETAIL LENGTH BOTTOM Otis "BWD" Perma-drill Set on DP w/hydraulic setting tool, 7" 26-32# (P/N 212 BWD 704000-A) Otis Seal Bore Extension (P/N 212 C 7060) TOP 3.93' 7.71' 14243.93' 14240' DPM DPM 14251.64' 14243.93' DPM DPM 'Anchorage i CASING AND AEANDONF~RT DETAI~ Z i ~ Al KELLY BUSHING AT 0.00' : C) ~6', 75~, ~-55 ~SZNG AT 623' i D) 13-3/8", 61~ N-80 CASZNG AT 3044~ E) 9-5/8', 40t, 43.5t, 47t, N-80, P-~10 CASZNG I TOP A~ Z0287~ i BOT~ AT 15328' ~ G) ~', 29~, TIE BACK CASINO AT ~0287~ ETD IS 15208' {JUNK) TUBING D~AIL D 2l 4-1/2' x 3-1Z2' CROSSOV~ AT 14245.33' 4) 3-1/2' OTIS WIRELZNE REENTRY GUIDE BO~OM AT 1431~.80~ 5) ~IS NODE~ 'gWD' PE~-DRILL PACKER AT 14240~ D~ A) OT~S SE~ ~ORE EXT~SZON ~R~ 14243.93 14251.64~ B) 4' ~IS S~L ASSY WITB S~IGHT ~J~ 7" TIED BACK 1 TO SURF ~ ~ 7"TOL ~ 10287' i ! i -- ~ ~ 7/30/68 14660'-14690' S~UEEZED ?/31/68 14595'-14625' OP~N FOR 14535'-14595' OPE~ FOR INJECTION 14960'-!5175' OPEN FOR INJE~ION 15195'-15250' OPEN FOR INJECTION 1/09/70 15195'-15205' OPEN FOR INJECTION 14960'-15175' OPEN FOR INJECTION 14535'-14685' OP~ FOR IKJECTZON -- 14460~-14515~ OP~ FOE INJECTION 9/08/72 14736'-14746' OPEN FOR IRJECTIO~ 14782'-14792' OPeN FOa INJ;CTIO~ 14808'-14818' OP;E FOE INJECTION 14900'-14910' OPEE FOR I~JECTIO~ -- 14914'-~4924' OPEN FOR INJECTION 1/30/82 1495D'-!5050~ OPEN FOR INJECTION ~ 14460'-14515~ OPEN FOR INJECTION 14753'-34930' OPEN FOR ~ 15076'-15175' OPEN FOR I~JE~ION =: := 14460~-[4515' OPEE FOR XE3E~O~ .... 14535'-14685' OP~ FOR I~JE~ION -, :: 14685'-14690~ SQUEEZED 1471~-14930~ OPEN FOR ZNJ~ION ~ ~ 14950'-15175" OP~ FOR INJE~ION 15195'-15208~ OPEN FOR INJE~ION 15208~-15~50~ COV~ED BY J~NK 7" L ~ 15328' WELL TBUS G-9 INJECTOR DRAWN: DAC UNION 01l_ CO. OF CALIFORNIA M.LL PJ,PAI R SHEET D PAGE; NO. '- LEASF WELL NO.(:-q l'(' FIELD '.*cqrl'~,~r !liver Field DATE t,/: l/72 9/1/72 9/2/72 9/3/72 9/4/72 915172 9/6/72 9/7/72 9/8/72 9/9/72 ETD. 15,350' T ]5,2b1'] 15,330"1' 15,281'1 15,550"1 15,2b1'1. 15,35U'T 15,281'1 15,330'T 15,281'1 15,330'T 15,281'1.' 15,350"I 15,281'E 15,550'2 15,281'1 15,330' ]5,281' 15,330'q 15,281' DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS I,loved ril,. fro~: (;-16 to d-9 at 9'00 am, 8/3]/72. Rig,?ed up Sc]-,]urq~er?er Ran prolJle logs and rigged up to pull tubing. ) Co~.q)leted profile logging. Rigged up Otis. Opened sleeve above pact~er f~itereu Inlet water. ri) at 14,378'. Displaced diesel i~ romulus w/ ' ' '~ .~ Removed x-mas tree. Installed 17)PE. Tested to 2000 psi. Pulled 4 ]/2" I'!) and 3 1/2" tubing strings plug pad;er seal assembly, l,aid dorm. sm"~ple its. of 4 1/2" tubing for inspection. Found xnsh out at bottom of 3 1/2" buttress coupling at al)proxinately 9900'. lll' w/ Eal~er oacker pic]~er. Attempted to mill over ()tis pe]~mxent production ~oac]:er. at 14 ,417' , tool not operating properly. Pooh. Checked mid re-ran rebuSJt Bal'e¥ pncl.~er picker. Uil]ed on packer for 7 hours. Packer moved dox~n 6 ft. and stopped. Pooh. Pooh w/ Baker packer picker. Found retrieving co]let n~t-¥ac] ed off. Till w/ Tri-State packer pic].er. Retrieved ira. er sleeve of ]0ac] er. P.!I! w/ S 7/8" concave mille. }Iil].ed and pushed pac]:er to 15,278'. Circ. hole clean. 0 Pooh w/ 5 7/8" mill. Rill w/ 6" bit m~d 7" casing scraoer. Cn to 15,281'. rD Pooh. Rm~ Ilowco RTFS tool and IlBP on 3 1/2" DP to 15,220' m~d set PZP. Set R'ITS at 15,185' Could not brea], dok~ interval w/ 2500#. Spotted 10 bbls acid acriss peQf. intewal. Reset RWS at 15,1~5'. Attempted to acidize. Bland (15,195'.-15,175') cor~icated. Reset at 15~190', 15, 195' ~d 15,170'. I]xperienced co~tmicatjon at all settings. Set IU]P at ld,950' and PdTS at 14,700' in ]0' blank. Pressured to 20~0#. D Bled to 1,250# in five minutes. Rcpressurcd to 2000# ~md cir. arotmd h]an Spotted 10 bk]s acid across ]ocrfs from 1~,460' to 14,515'. Fet WITS at ~ll~ set o,,. 14,420' R];C at 14,520'. Lac], of pressure' drop indicated ~ P~ped 4000 pollens 2 1/2% I:CI, ~d 500~ -a]lons 12-10 I%L-I'.F a~id. Injected 550 bbls water flush v'/ platfo~ system at q to I0 ft'/mipute rate or 2567 B??D. Set hl~P above upper per~s and located bole w~ tool in 7' ]inet at !2 698' to kc squeezed follo~'in~ acid stSr'ntlatiop. Pooh to reperf l,encl~es #3 m~d #4. Reperforated 2 I?F with 4" carier gtms (jt~ho jets) fron 14m736' to 14m746' i'D 14,782' to 14,792', 14,808' to 14,818', 14,856' tn 14,866', 14,90n to 14,910', ~md 14,914' to 14,924'. Ran x:ell stir, wash tool. Straddled irter- ~ ~n, Cfirc. orotund top c,~s on too] ' va1 fret 15,200' to ~,~ ....... tool w/ tel cups on tool at IS,10S'. Circ. arotmd top cups ~-ut at reduced 4000 ca]lops ]?-lq iTL-IT and rate. Ptu,?cd 2000 l;allons ,~o I'CL, ,, gallons ~o . , ,~v t,CL Flushed w/ 5000 bb]s :filtered Inlet v'ater at ]0 I;I'.?D rate. Pooh. Redressed well stim tool. l'nat~le to reset too]. ~ 3 Fotmd cups on well sti]n straddle x:ash too] fi]ed x,,/ sand and Pud and 1I'13 mtcl metal lxtc],er cuttinEs. Replaced ct~s ~d rerar tool to stipulate interval, 14,890 to 14,934'. get tool ~z/ top ct~ps at 1~ ooo, cop~a'a~icat~on w/ annulus. Spotted 10 hbls 12-10 i'('],-!'F acid across ~tter- ca]. Injected at 2600# at 2 ft.~/mim~te rate. P~q~ed 1600 ?.al]o,,~ d000 gallons 12-10 I:CL-IT ~d 1600 IiCL. ptnjDed So0 N,ls water at 2600ii at 5 ft.5/minute. [3 il'l) Straddled interval 14,830' to 14,880'. 'rested at 1500# Spotted lO t;t,ls 12-10 ~.~ttd acid. Injected acid at 2000# at 2 to 4 cu. fl./minute. Flusl~ed w/ 15 blds water. Ptm~ped 1600 ~,allons 5% I:CI,, 4000 12-]0 I'CI,-t'F · and 1600 ?,allons 5% IICI,. Flush w/ 500 1,bls water at 2500# at 2 cu. ft./ ,mimtte increasin~l to 10 cu. ft./minute. ]xq~erienced copm,tmications top cups on well stim tool as last 400 pollens ,~-,, was con~lucted x.'/ rams closed on l~P. Straddled i~terval 14,775' 1,1,825'. Tested tool to 1700/;.w/ slow bleed off. Fpotted IICL-I[I:. Full coccus,tm[cation arotmd top c~s after injectinF 5 bbls of UNION OIL CO. OF CALIFORNIA ~]LL Ri',PAIR SI-I EET D PAGE NO LEASE ']~'~ldili!,, l,nX_l, lnit State WELL NO. (]-9 l'c'; FIELD DATE 9/9/72 cont. 9/10/72 9/ii/72 9/12/72 9115172 9/i4/72 9115172 ETD 15,330 ' T]~ lb,2al'l;l 15,330'T[ ?, 15, ~81 'ET 15,330 'TI 12,843 15,330'TY !5,281 'l;'l! ] 5,33 O ' 7'I! 15,281 'li~ 15,330 'TI' 15,231 'l;~ 15,330'T] ~81 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS the spotted acid. Straddled 5~tervals from ]3,703' to 14,753'. Tested to . 2(~00f,, bled to 1300#. Spotted l0 ]',bls 12-10 IICL-I'.F. l'~erienced coi~n~ication. ~loved tool to set top cups at 14,709'. lnjected spotted acid at 2 to 3 cu. ft./minute rate at 1100~). Connmmication experienced. Spotted an additional 10 bbls 12-10 !'C'I.-I'F acid. ~micat/on. Flushed w/ 300 bbls water. Pooh w/ well st]m straddle tool. l~rep, to profile. Rlti w/ RI;P and IYFI'S tool. Set RBP at 15,276' Fe]ow perfs and PfTE at 14,404' al.eve upper perfs. Injected and profiled at 8550' F.?]'9 (stnhJ]ize¢' rate) w/ Schlumberger. Set RI]P at 12,843'. $~otted 25' sand on RBP. Set P, Trs at 12,386' to squeeze hole in 7" l~ner at 12,693' Pta,reed away 20 cu. ft. minute at 2700# tl~ru hole. 5aueezed ]:o]e ~/ 75 sx. class "6" cement to a final pressure of 3000#. Pdmulus backed up at 1000~". No con.~nunication indicated. CIP at 11:30 pm, 9/10/72. P. eleased too, reversed and Pooh. Small fluid flow to surface prior to squeeze. I'ole now taking small amount of fluid. Set 7" Ilowco RTI'S tool at 12,353'. Tested casing above PTTS to 3000#-0]:. , D Pressured below IITYS to top of cerent at 12,478' to 3200# - o]:. Pooh. I',II; w/ 6" bit and 7" casin~ scraper. Formal cement at 12,478' Firn ce~nent to 12,548'. Stringer,s, to 12,$15'. Cic. said off top ;f Pdq~ : at 12,843'. Cleaned pits~ .,,o fluid entry or loss followip,E soueeze. : Retrieved t~ridge plug at 12,843'. RII: w/ tlowco 7" P. TI~$ tool and set in liner top at 10,645'. Pressured 9 5/8" romulus to 1500#. Squeezed 9 gallons t,owco i)lug plastic 1],to seal area of tub~np ]lead to stop co~:~,lt~lication bett:een 13 3/8"- 9 5/8" an~u]lls mrd 9 ~/o~°" I{Ili iv/ llowco 7" RTTa. StoDned a~ 14,865'. lln, aI)]c to circ. dol~ Pooh. Ran 6" bit and casip~ scraper Cleane~ out bridoe ~ron 14,8a0'. l','ashcd to 15,281' mid circ. ho~e w/ c!cal filtered Inlet w~tor. Recovered s]~all a~tomit of silty oily sm~([ x:hile c]r, anin- ol~t ?o~ Fpotte(t 40 Pooh ~,:/ bit and scraper. TII D bbls I ICL ¢c~d across pe~o~nted i~)te~al to 14,300'. Al loi.-ed ac~d to stay in place one hour. Reciprocated tool t]-~rot~]~ peres ~md ~:as]~ed s~e. Ch~gcd out fluid to clca~n Ciltcrod Inlet water. TI!' to 15,281' ~/ R~S tool - Fpotted 2nd 40 bbls I~CI, across perforated interval. Pulled tool un to 100' above to~ oF perfs and prepare to in- ject filtered Inlet x:ater. Injected at a rate of 8,800 BI'J'D w~ 3250 esi usip? platform s,~ster'. Pooll w/ q!'Fl'S tool axd picked up perforation washer to acidize 4 stao. es o [ perforati oas. Stage 1 - 15,025' - 15,07,5' - Acidized w/ 1,fl00 gallons. 2-1/2" IiCI~, 2500 gallohs 12-10% t'.CL-I;F. r 1,000 gallons 2 1/2% I~CL follox.'ed by ,~0(, l,Fls filtered Inlet water. Initial lfater - 2 cu. ft/minute at 30,00 psi Acid - 10 cu. ft/ninute at 180,0 psi Final - 8 cu. ft/mSnute at 2700 psi Stage 2 - 14,948' - Acidized same as Stage tl Initial Water - 4 cu. ft/minute ~t 2200 psi. Acid - 10 cu. ft./mim~te at 2000 psS. Final Water - 9 cu. ft./minute at 3000 psi Stage 3 - 14,876' - 14,926' - Acidized same as Stage l and Initial h'ater - 3 cu. ft./minute at 2000, Acid - 7 cu. ft./minute at 200,0 psi Final Water - 6 cu. ft./ mim~te at 3500 psi. UNION OIL CO, OF CALIFORNIA I;~LL I~t"A IR SHEET D PAGI~ NO zl. _ rl'~;ldi~l~, ]',ay lMit State LEASI,] ' G-!~ l,c~ ?'cArtl~.tl? River Field WELL NO.. FIELD . DATE 9/16/72 9/i7/72 0/18/72 9/19/72 9/20/72 9/21/72 9/22/72 9123172 9/24/75 ETD ] 5,330 ] 5,281 ' 15,53(I "i']: 15,281 't!1 15,330 'Ti) 15,281 'ET 15,330 'TI~ 15,2,5 l 'IiT 15,330'TD 15,281'I51' 15,530"N) 15,2"1o 'LT 15,330'TE 15,281'1:] 15,330'TE 15,281'1i'1 15,350'T1' 15,281'I2 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Sta~;e 4 - 14,803' - 14,353' - Acid/zed sane as Stages 1,2,and 3. Initial Water - 2 cu. ft/ nJpute at 20on psi. Acid - 1] cu. ft./rip, ute at 10n0 psi. }:inal lhter - 16 cu. ft./minute at 3500 psi. tlnable to off load ~my eqt~ipment to r,a]~e room to lay dram drill pipe due to gigh ~,jnds. ],aid dorm drill pipe. Rip,?ed up Dresser At]as. Rmq jun]: basket and gauge ring. Unable to get below 10,400'. Reran jtmk basket and gauge ring - unable to get below 10,9s0'. Ran Pagnet on wireline -tmabie to get below 11,990'. Pooh. No recovery. Ran 6" bit and scraper on tubing. Till wi bit and scraper to 14,571'. No indication of jtmk. Pooh ) Laid dram bit and scraper. Rigged up Dresser At]as. Ran junk c~tcher ,o¢.el FB-], 7" x ~" 1 and gauqe ' ,, . r~no to 14,550' P~n and set BaRer ?~ ~ . pac.-er oroduct5 on tubing. at 14,4~7'N21. Rigged up and ran 4 1/2" and 3 1/2" . Tagged packer at 14,474'. Unable to test packer. Set plug in "Q" Nipple be]ow pad:er at 14,437'. Tubi~o failed to test. ') ()tis tmable to c]teck "XO" sleeves due to excess line drag. Rigged up Otis tools on Dresser Atlas electric line unit. TI!T. Closed lower "XO" sleeve and chectced upper sleeve. Ok. TuLing failed to test. Pooh w/ 4 1/2" & 3 1/2" tubipg. Found 1 collar washed out at + 9,700'. Completed Pooh w/ tubing. Fmmd 1 leak ip 4 1/2" tubing, 1 leak D 3 1/2" tubing. Rigged up bydrotesters and TII~ testing stands full length to 4500 psi. Found 2 leaks 3 1/2" tub.ipg. Completed rmming tul0ing, tesing each jt. to 4500 psi. Stabbed into BaLer wireline packer and tqsted ok. Picl~ed up out of packer and displaced romulus wi pac]~er fluid, l,m~ded tubing-removed BOPE and installed x-mas tree. Put well on injection at Rate stat)ilized at 14,500 BI,I'D at 3200 psi at midnight. PII,FASFD RIG AT 12'00 Df, 9/21/72. FI>5% Pd:PO!:T. Increased injection pressure to 3500 psi - rate stab51ized at 15,350 BI',PD. Rigged up Scbltm,.berger m~d ran injection profile over desired interval to cover benches #1 thru ~7 - fjP~al report. Skidded Rig 54 over I'ell g-16. ];egm~ v:ipterJzJng q55 54 for st:ut- D do~m period. Completed ¥-ork at ]2'00 7", 9/24/72. Y UNION OIL CO. OF CALIFORIklIA SHEET D PAGE NO.= ~ ,__ LI£ASI'% ..~VELL NO.C-9 ' ','~. FIELD DATE f2 'r D DETAILS OF OPERATIONS, DESORIPTIONS & RESULTS 3 1/2" ~iu]e 5 1/2" Otis "Q" 3 ]/2" N-SO !klttress Pup Jt. Bal,er 4" Sea] Asser, bly Baker Locator Sub 3 1/2" Seal loci, x 3 1/2" ]]uttress X-over 3 1/2" N-80 ]klt~ress Tubing 4 1/2" ]kittress x 3 1/2" ]_;uttress X-over 4 1/2" N-80 l;uttress Tul=ing 4 1/2" Buttress Pup Jr. 4 ]./2" Buttress Ptrp Jt. Tubing I Ianger Lmided Below Zero 165 307 .75 1.70 4.05 2-.50 .75 · 5O 497'8.35 1.20 9431.67 21.67 2.90 1.00 38.50 14,>0~.54 50? ] 4,50]. 09 14,4 97.04 ]4,47(,.54 14,475.79 14,47.5.29 9,496.94 9,495.74 64.07 42.40 39.5() 38.50 -0- Rotary Table (110.60' above bILLg~-~-----~--~ ..... 0' Tubing ! hunger 38.50' 623' - 16" 75# J-SS 8rd Cemented to surface 3044' - 13 3/8" 61# J-SS Buttress Cemented to surface. 3 1/2" Buttress x 4 1/2" Buttress X-over 9496'. 7" liner top at 10,287'. 10,555' - 9 5/8" 40# 43.5# 47# N-80 and P-Il0 Seallock - DV at 4609'. 3 1/2" Seallock x 3 1/2" Buttress X-over 14,475'. 3 1/2" Otis "Q" Nipple ID=2.625-14,501 3 1/2" Mule Shoe-14 503' Tail Bgttom ' 14,504 . REV. DAT~ 14,474' - 7" x 4" Baker FB-1 pakcer and 20.50' of seal assembly w/ locator sub. 15,328' - 7" 29# N-80 Buttress l'vIiLL SCt ~tITIC TRADING BAY UNIT STA2Z G-9 l~g 9/23/72. UNION OIL COMPANY OF CALIFORNIA . 247 (14f ~,' 5/G6) Di~,WN __ CKD ....... --: APP'D, SC. ALE ~j/ fu/ I 0/J .... ~ /q,~._YZ P ~P .0 300. ".'' ~'oo z-~a UNIO OIL CO. Of CAllFO { i' ia DRILLING RECORD SHEET A PAGE NO. LEASE . TRADING BAY UNIT ST.WELL NO. G-9 FIELD McArthur Rive= LOCATION Kenai Borough Leg 2 Conductor 41 SPUD DATE 4/22/68 .... COMP. DAT~ CONTRACTOR. WOD ECO TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 8/11/68 RIG NO. 54 ELEVATIONS: WATER DEPTH PERMIT NO. 68-16 SERIAL NO. ADL-18730 I%T. TO OCEAN FLOOR R.T. TO MLLVg i10.60 T.D. 15330 ' T.V.D. R.T. TO DRILL DECK 19.30 DEVIATION (B.H.L.) R.T. TO 42.60 COMPANY ENGINEER APPROVED: 5" Hughes X hole 235 BIT RECORD '~ rMdD VE~.. DEPTH & DEVIATION BlT JET DEPTH ' I I/ VERTICAL E] DATE DEPTH NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. JET DIRECTIONAL 4/22/68 359 1 15" SEC S3J Open 640 281 6 - - Bottom of conductor 369 23 359 HO1 22" SERVC£,EXP Open 640 281 5-1/2 - - 24 640 2 15" t{TC OSC3A 3-18 2108 1468 ]5 115 258 25 146'8 3 15" SEC S3J 3-3/4 2184 76 5 Dynadril] 25 2184 4 15" HTC OSC3A-2 3-18 3101 917 14-]./2 115 258 26 3101 [IO2 18" SRVCO EXP Open - SheaFed ar~ pin stuck _~n casing ..... 26 3101 HO3 18" " " Open 1805 ]182 17 70 - T-3; B-2 27 3101 HO4 18" " " " 2515 710 7-1/2 70 - T-A, B-3 28 3101 ~i05 ],8" " " " 3079 564 6-1/2 70 - Run 13-3/8" csg 29 3101 WOC and n{nr~led un 30 3101, 5 12-1/4" R~d YT~AJ 3-16 4215 1114 10-1/2 130 380 T-3, B-2 _ 5/ 1/68 4215 6 12-1/4" }ITC OSC3A 3-16 4586 371 5-1/2 130 380 T-2, B-2 -.- ~. 4586 7 " HTC ODG !3-16 5173 587 7 130 380 T-3,, B-2 2 5173 8 " HTC ODG ~3-16 6019 846 9-1/2 130 380 T-4, B-2 3 6019 9 " hTC ODG 3-16 6420 401 9-1/2 130 380 T-3, B-2 4 6420 10 " Reed STIAG 3-24 6575 155 6-1/2 130 - T-2, B-1 Dynadril 1 4 6575 11 ,, Globe ST3G i3-16 7098 523 9 130 380 T-3, B-2 5 7098 12 " HTC X1G 3-24 7161 63 4-1/2 130 - T-3, B-1 Dynadrill 5 7161 13 ,, HTC ODG 3-16 7224 63 2 130 380 T-2, B-1 Change DA .... 5 7224 14 " HTC ODG 3-16 7405 181 17 [130 380 ~-3~ B-1 6 7405 15 " Globe S2 2-1/2 7520 115 3 120 410 I-3, B-2 - 2 cones / 6 7520 ,16 " HTC XIG 3-16 7821 301 8-1/2 130 380 ~-3, B-1 / 7 7821 17 " Reed STIAG 3-18 7944 123 8-1/2 130 380 r-3, B-1 7 7944 18 " Reec~ STIAG 3-18 8094 150 7-1/2 150 380 !-3, B-2 8 8094 19 " SEC S4TGJ 3-18 8215 121 3-1/2 140 350 Left'in hole 10 7942 20 " HTC XDG 3-24 8010 68 5-1/2 115 - 1-3., B-5 DD Lost 2 con-_e 11 8010 21 " SEC M~LG Open 8036 26 1-1/2 115 - ~-1, B-1 DD 12 * 8059 22RR " REED SI!AG 3-18 18059 0 1 115 260 ~-4, B-i, Drilled on ~-n 13 8059 23 " Reed STIAG 3-18 i8221 162 4 115 260 ~-3, B-1 13 822l 24 " " " " 8&74 253 7-1/2 115 260 T-3, B-2 14 8474 25 " HTC XDG 3-i8 8753 279 8-1/2 115 260 T-3, B-3 14 8753 26 " HTC ,MDG 3-18 8935 182 6 115 260 ~-3, B-2 15 8935 27 " Reed SSIG 3-18 ~053 118 8 115 260 T-2, B-2 16 9053 28 ,, Reed SSIG 3-20 9182 129 10 115 220 T-3, B-2 17 9182 29 " HTG KDG 3-18 9424 242 6-1/2 125 279 T-2, B-2 17 9424 30 ,, Reed STIAG 3-18 9546 122 8-1/2 125 279 T-3, B-3 17 9546 31 " SEC DS-J 3-18 9641 95 6 125 279 I-2, B-1 18 9641 32 ~ SEC DS-J 3-18 9766 125 9-1/2 125 279 T-2, B-1 ]9 9766 33 " SEC DS-3 3-20 9951 185 11-1/2 125 226 T-3, B-2 20 99~1 ~4 " SEC DS-J 3-20 10039 88 6-1/2 125 226 T-2, B-1 21 10039 35 ,, HTC KDG 3-20 10249 210 13 125 226 T-2, B-1 22 10249 36 " Reed STIAG 3-24 1,0275 26 9 100 - T-2, B-1 Dyna. drill 23 10275 37 " HTC KDG 3-20 10384 109 6-1/2 125 226 T-3, B-2 26 103g4 38 " SEC DS.! 3-20 1. O493 ]..O0 !l .... .~2~: ~'226 T-? - 27 10493 39 " SEC DSJ 3-20 10631 138 15-1/2 1.25 7_26 T-3. B-1 28 10631 40 " Reed STIAG 3-24 1_0631 0 2 135 - Clean out for 31 10593 41 8-1/2 Reed ~TIAC, 3-14 10744 151. 6 1_70 248 31 10744 49~ " Reed STIAG 3-24 10764 20 5 170 - ~vnadri, ll T-4. B-2 6/ 1/68 10764 43 " HTC XDC 3-14 10870 106 b 1190 284 r~3, B-2 2 10870 44 " HTC ×DR 3-24 10g00 30 2-1/2 170 - Dyne. drill T-4,. B-3 2 10900 45 " }ITC ODV 3-14 10959. 59 3-1/2 . 119.O 3 10959 46 " -HTC XDG 3-24 11033 ' 7& ', Ll, 7O - Dynadrill 'T-3, ___3 llOqq 47 " }ITC X'DG 3-24. 11094 61 ~ 1170 -- " T-2,i D-I 4 llf)O4 48 " NTC XDC ;q-lA 11232 1'18 ~ 125~ 976 _r-2_ B-~ S 117~o ,'.q " R~d _qTIAC, [q-14 J!376 144 [5-1/2 ?~Sfi 376 r-2. B-! 5 11370 50 ,' HiC XDG ~-24 ~1446 70 5 .~ - Oynadrill UNiC OiL CO. Of CalifOJ qia DRILLING RECORD SHEET A PAGE NO. LEASE TRADING BAY UNIT STATEwELL NO. G-9 FIELD McArthur River Field LOCATION N1886', W1382' from SE corner Section 29, T9N, R13W, SM. Le~ 2, Conductor #41. PERMIT NO. 68-16 SERIAL NO. ADL-18730 T.D. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER SPUD DATE 4/22/68 COMP. DATV~ 8/11/68 CONTRACTOR. WODECO RIG NO. 54 TYPE UNIT . National 1320 DRILL PIPE DESCRIPTION 5,' Hu§hes x hole ELEVATIONS: WATER DEPTH R.T. TO OCEAN FLOOR R.T. TO MLLW R.T. TO DRILL DECK R.T. TO APPROVED: ' 125 235 ilO.60 19.30 42.60 // ~MUD/ "VEL/. DEPTH & DEVIATION BIT R ORD BlT JET DEPTH / VERTICAL [] DATE DEPTH NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. JET DIRECTIONAL [] ,/6/68 11446 51 8-1/2" HTC XDG 3-24 11484 38 6 170 - I)ynadrill ... 7 ** 11484 52 " HTC XDG 3-14 11508 24 1/2 250 376 ]~ollow up run 8 11671 54 ', Reed STIAG 3-14 11832 161 9-1/2 250 376 9 11832 55 " Reed STIAG 3-14 11920 88 7 250 376 9 11920 56 " Reed STIAG 3-14 12135 215 9 250 376.. 10 12135 57 " Reed YTIAG 3-14 12330 195 8 250 376 11 12330 58 " Reed STIAG " 12386 56 2 " " 11 12386 59 " [ITC KDC, " 12500 114 5-1/2 " " 12 12500 60 " Reed STIAG " 12609 109 5 " " 12 12609 6]. " Ree~d STIAG " 12737 128 4-1/2 190 300 13 12737 62 " Reed STIAG " 12868 131 8-1/2 " " T-4, B-2 ... 14 12968 63 " ~TC XDG " 13001 133 6-1/2 " " T-4, B-2 _ 14 13001 !64 " HTC XDG " 13105 104 4-1/2 " " Locked, lost bearinz_ 15 ] 3]05 65 " HTC ODV " 13201. 96 6 " " T-3, B-4 15 13201 66 " Reed STIAG " Stu~:k @ 1. ,250' 16 Fishing _ 17 Fishin~ _ 18 12780 52R[ " HTC XDG Open 12898 Poll hed Pl~g Plugzed baok 19 12898 67 " Reed STIAG 3-3/4 12898 Pi~e wall sl:icki,:~ DD - Pulled for wS 1.9 128~8 68 6-]./8" HTC O~W Reg 12920 22 1-1/2 Dri.ling off whipstock ~O 12920 HO6 8-1/2 SEC 3 Pt. Re~ ]2958 38 1/2 HO run .. 20 12920 RR67 ,' Reed STIAG 3-1/2 12958 38 1/2 165 360 Follow up run 20 112958 RR6~ 6-1/8 HTC OWV ~Reg 12972 14 4-1/2 165 - Whipstoc.k run 21 112958 ,'i9 8-1/2 ;Reed STIAG '3-12 13023 65 10-1/2 165 1360 Dvnadrill run 22 1.3023 7o ,, " " " 13062 29 1-1/2 165 i360 Gilligan run .~3 !].3062 71. ,, " " '" 13182 121 ,7 190 360 Drilling 8-1/2" hol~'l' 23 113182 7? " IHTC XDG " 13266 84 !7 190 360 Lost in hole 27 110698 73 " " " 3-24 10703 4 1/2 - - Polish Plug 28 ]~703 74 " Reed STIAG " 10794 91 4 - - Dynadrilling - ' ~29 10794 73R~ " HTC X~G 3-!2 10827 33 1 210 347 Gilligan ~0 10827 75 " Reed STIAG 3-11 10961 134 3-1/2 210 416 _ 30 10961 76 ', ,, ,, 3_14 1110! 140 3-1/2 210 347 T-3,, B-2 _ 1 11101 77 " ,, .YTiAG ,, 11246 145 4-1/2 210 255 T-2, B-2, O.G. 1/8. 1 112&6 78 " Slnith K2HJ " 11416 170 7 2]0 255 T-3, B-2 _ 2 ].,].416 79 ,, ,, ,, ,, 11558 142 5-1/2 210 255 T-4~ B-2~-O.G. 1/8 2 11558 $0 " Reed YTIAG 3-12 11740 182 5 210 367 3 11740 81 " Reed YTIAG 3-11 Stuc~ pipe runnin~ in ~ole Not recovered 4 Fishing 5 Fishing & Plug back 6 52P.} " HTC XDG Ooen 11202 Pol~',h cemer~t pltlg to 11202' 7 ] ] 202 82 " Reed STIAG 3-24 11272 70 5 - - Dynadrill _ 8 11272 83 " Sm%th K2!{-J !3-11 11466 164 7-3/4 ].25 380 T-3, B-3,. O.G. 1/4 9 . 11466 84 " Reed YTTAG ~ ~/,~ 11604 ]38 5 1125 380 T-3~ B-3, Gau~e OK 9 .~1604 ~5. ,, ,, " " 111764 it60 -~ 7 .................., 10 11764 86 " " " " 11981 217 7 125 390 T-3, B-3, Gau~e OK ]1 11qg1 B7 '" " " " 12213' 232 8.-1/2~ 125 390 T-2, B-3 11 12213 R8 " " " " 12321 3.08 5 125 3.90 T-2, B-3 12 12321 g9 " SEC S4TG 3-1.1 12510 189 6-1/2 170 391 T-3, B-3 12 17510 90 " " " " 12590 80 3-1/2 170 391 ,Pulled to rerubber 1 3 12590 91_ " ,, ,, ,, 12850 260 6-1/2 170 301 __ 13 12850 92 " " " " 130~8 188 6 170 391 ' -- I ' 3 ~~ T--4 B'2 14 1 ~o~g 93 " " " " ] 3197 159 5-1/2 170 o~ . g-2 0 C, 1/8" _1 5 I q107 94 " " " " 13263 66 5-1/2 170 391 T-A, , .... ]5 1~76~ 35 " S~ith KPH-.T " 1~354 91, 6-1/2 170 391 T-3. B-2, Cause OK 16 1335'~ 96 ,, " " " 13564 210 6 170 391 T-4, B-3, O..G. i/S ~ ~'~.A a'~ " " " " 13785 221 6 170 391 T-Z, B-3, O.G. i/S" UNIO OIL CO. OF CALIFO <IIa DRILLING RECORD SHEET A PAGE NO. 3 LEASE FIELD TRADING BAY UNIT STATEsvELL NO. McArthur River G-9 LOCATION N1886'~ W1382' Section 29, T9N, R13W, SM Leg 2,. Conductor #41 from SE corner SPUD DATE 4/22/68 COMP. DAT~ 8/11/68 CONTRACTOR WODECO RIG NO. 54 TYPE UNIT - National 1320 DRILL PIPE DESCRIPTION 5" Hughes X hole ELEVATIONS: WATER DEPTH 125 PERMIT NO. 68-16 SERIAL NO. ADL-18730' tLT. TO OCEAN FLOOR 235 ILT. TO MLLW 110.60 T.D. T.V.D. R.T. TO DRILL DECK 19.30 )EVIATION B.H.L.) ' 42 60 COMPANY ENGINEER APPROVED:I ~ ~ '~/ BIT JET DEPTH / VERTICAL [] DATE DEPTH NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANI~. JET DIHECTIOI~AL r/17/68 13785 98 8-1/2" Smith K2H-J '3-11 L3916 131 4-1/2 170 391 T-4, ~-3~ 0.G, 1/8" 18 13916 99 " Sec. S4TG " 14002 86 3 170 391 T-4, B-I~ Gauge OK 18 14002 100 " Smith K2H-J " 14117 115 3 170 391 T-4, B-3, O.G. 1/4":. 19 ~41.17 101 " HTC XDR-J ,, 14169 52 5 170 391 T-3~ B-2 .. 19 [~169 102 " Smith ~2H " 14256 84 3 170 391 T-3, B-2 20 14256 ].03 " Reed YTIAG " 14372 .116 7-1/2 170 391 T-3. B-3 ... 21 14372 !10A " geed YTIAG " 14500 128 6 170 391 T-3, B-3 22 l. AS00 1.05 " .~TC X55R 14744 244 15-1/2 106 475 .... 23 1A744 106 " Smith SS5 3-10 15000 256 21-1/2 106 475 T-3, B-l, broken tee~ P3 1~000 107 " Smttb SS5 3-11 15261 261 18-1/2 106 475 .T-3 B-2. locked con~ 24 1.5261 108 " Reed YSIG 3-12 15330 69 6 106 475 T-2, B-2 28 ].52R1 lOq 6" }{TC OWV O.nen Cond. mud in liner 5/I2/68' 8036 22 12-1/4 Reed STIAG 3-24 805q 23 2 115 - T-l, R-~ nn ~/7/68'* 11508 53 g-l./2 +{TC YqC 3-14 ~.671 163 5 ?~0 376 ! · _ , , _ ,,. , _ __ ,,~ · ,, , , ,, UNiO]' OiL CO. OF CaLiFOrNiA MUD RECORD SHEET B PAGE NOi LEASE TRADING BAY UNIT STATE WELL NO. G-9 FIELD McArthur River TYPE Lignosulphonate DIS.TRIBUTOR IMC DATE I DEPTH WEIGHTI VISC. W.L. PH SALT OIL SA~DI SOLIDS REMARKS 4/24/6[ 640 75 45 )---25--- 1800 78 '~58 7.2 9.0 950 4 1-1/~ 16 26 2458 79 50 6.8 9.2 900 5 2 16 28 3101 77 50 6.4 9.5 850 4 1-1/2 16 , 28 3101 79 56 6.0 9.7 900 5 ] ].7 ripening ! 5"he !c'k~ " 29 3101 78 47 6,.2 9.5 900 5 1-1/~ 16 Ooen hole - ran 13-3/8" cs~. 30 3101 Nippled up and waited (n cement 5/ 1/6'8 4560 77 55 5,0 10 !000 5 1-1/l 15 Drilled 12-1/4" hole 2 5505 79 55 4,5 9,2 700 5 1 15 " " " 3 6407 81 50 4,0 9,4 600 5 1/2 , 15 " " " iii 4 6575 82 50 3.8 9.6 700 6 1/2 13 " " " .... 5 7135 81 50 3.6 9.6 700 6 I ]4 " " " ~ 7368 82 52 3.3 9.7 600 6 1 14 " " " 7 7751 82 53 3.0 q. 5 600 6 1. 16 " " "' 8 7q&& 87 52 2.R q.4 6DO 5 q/4 ] 5 " " " 9 R1 20 82 52 2_6 q. 5 650 5 1 1 6 " " " ]1 ~C11~ R~ 57 q.O 10.(] 600 q 1-1/_', 16 Tw~.~t~ oFF~ pI,,sE~H 12 8060 89;5 5& 9 A O_R 60~ 6 1 16 Dr~ll~ 19-1/A" bole 13 fiOan ~ 89 55 ? & 9:~, 6on 6 ~/& ~7 " " " la 8469 ~9 56 9.& 9:5 a5n 5 ~/9 ~6 " " " 15 R935 R~ 54 9 a 9.6 600 7 1/2 16 " " " 16 9053 82 57 2,6 9,6 600 7 1/2 16 " " " 17 9582 81 50 2.4 9.7 600 6 1/2 15 " " " 18 9640 81 50 2,4 9.7 600 6 1/2 15 " " " 19 9705 81 50 2.4 9.7 600 6 1/4 15 " " " .. 20 9954 82 53 2,4 9.7 600 6 1/2 16 " " " 21 10060 82.5 56 2.2 9.7 650 6 1/2 t7 " " " 22 10049 82 57 2,4 9,6 600 4 1/2 16 " " " 23 10270 82,5 59 2.6 9.5 600 4 1/2 17 Dynadrilled 26 10380 82 58 2.4 9.8 500 4 1/2 16 Drilled 12-1/4" hole ! 27 10493 82,5 56 2,6 9.5 600 3 1/2 16 " " " 28 10631 83,0 50 2.8 9.5 550 3 1/2 16 " " " 31 10650 83 50 3.£ 1l 600 3 1/2 15. Dr!d out cmt (9-5/8" cs~) '6/ 1/68 10750 82 48 3,0 10,5 600 6 1/2 14 Drlg. 8-1/2" hole 2 10872 83 47 2,9 9,7 600 6 3/4 15 " " and Dvnadrl~. 3 10900 8~ 47 2,4 9,5 600 6 1/2 15 " " " 4 11087 82 47 2,4 9,5 600 6 1/2 14 " " " 5 11266 82 47 2.4 9.5 600 6 ]/4 13 " " ." 6 ] 1430 82 48 2.6 9.4 600 5 ]/4 12 " " 7 11508 82 45 2.5 9.4 600 5 1/4 12 " " " . 8 11550 80 45 2.5 9.5 600 5 1/4 ll " " " 9 11g11 g0 46 2.6 9.4 600 5 1/4 12 Dr~].l~ng lO 120q7 80 47 2.5 q.5 600 5 1/4 13 Drilling 1~. 17500 81 A6 ?.g g.g 500 5 1/2 14 lq ]?6&fl SO 44 q_O q.8 500 ~ 1/2 15 Drilling - 14 19900 R1 %0 9.R 10 500 .2. 3/L 17 Dril! ing - 17 13950 gl 50 ? .6 10 550 2 1 I4 16 Fi.~hing 21 12958 $1 55 2.6 9.8 500 2 Tr 16 WhiDs rocking ?? ]2982 80 59 2.8 9.6 550 Tr 1/2 ,17 krhipstocking 22 13061 81 59 2.8 9,5 500 0 [1/2 17 Dyna Drill run 2~ 1.3250 79 54 2,6 9,6 500 0 1/2 16 DrillinK 96 I q950 80 50 2.6 10 7O0 0 1/4 17 Fishin~ oR 1070~ 71 33 3.2 10 500 4 Nil 3 Condition mud & Polish ?q 10703 7] 33 3,2 10 550 4 Nil 4 ~C' ] ,~ g ~) 7 7ii.~ ~41 3.8 !0 650 4 1/4 6 D}madrill ~7/! ~'68 !]!01 71.5 41 3,7 10 650 5 1/2 6 2 11368 72 45 3.7 10 550 6 1/4 8 .... ~ 3 11656 74 43 3.4 10 600 5 1/2 9 UNIC OiL CO. OF CaLIFO Ila MUD RECORD SHEET B PAGE NO. LEASE T~%DING BAY UNIT STATE WELL NO. c,-q FIELD McArthur River TYPE Lignosulphonate DISTRIBUTOR IMC DATE I DEPTH WEIGHT I VISC. W.L. PH SALT OIL SAND SOLIDS REMARKS 7/5/68 11740 71 44 2.3 10 550 9 Tr 9 6 - 71 46 3.1 10 500 8 Tr 8 Polish cement plug 7 11202 72 42 3.8 10.8 600 7 1/4 7 8 11289 72 43 3.6 10.6 600 7 ~1/4 6 9 11604 71 45 3.4 10.2 500 7 1/4 7 10 11900 70,5 44' 2.9 iO.C 500 7 11/2 6 11 12190 71 46 3.0 9.7 500 7 11/2 6 12 12415 70 49 3.0 9.5 450 7 3/4 7 13 12592 72 54 3,0 9.5 500 6 '1 8 14 13035 70 50 2,8 9.8 400 6 1/2 6 15 1 3250 69 49 2.8 9.6 300 7 1/4 5 16 13460 69 48 2.7 10 550 7 1/4 6 17 13785 70.5 54 2.9 10 450 7 3/4 6 ].8 14002 71 52 2.6 9.8 400 7,5 3/4 6 lg 141&q 71 5'~ 2.8 9.5 450 8 3/4 7 ?0 14256 71 5_9. 2.8 9.5 400 7 3/4 6 ?] ]&A77 71 54 2.6 30 400 6.5 3/4 5,5 2~ l&71R 79 49 2.0 1'0 300 7.5 3/4 6 23 1509~ 7~ 59 9,g 10 ~00 8.5 l 6.5 9a 152~1' 73 , 54 2.g 10 250 8 1-3/~ 7 .. , 25 I ~qla 7~ AR 9 ,R 11 9~0 7 3/4 7 Raised vis. to clean hole (coal) 26 ~6 ~3 6~ 2.8 11 250 7 3~4 7 TO, log and run liner ...... 27 - 73 66 3.0 11 250 7 1 8 29 - 73 48 3.0 9.5 300 7 1/2 7 ._ _ _ -- _ _ _ _ , · , UNION OIL CO. OF CALIFORNIA WELL RECORD PAGE NO. ,EASE TRADING BAY UNIT STATE WELL NO. G-9 . FIELD MC ARTHUR RIVER CASI THREAI 75# 8rd 'J-55 623 Buttress Seal Lc 10555 N-80 15328 REMARKS Installed 20" hydri~~ below RT II II !1 I! II II " Tubing " PERFORATING RECORD ~~l-- ~ --~ Sqzd w/80 sx .30-68 .31-68 14595-14625 DST #2 Open .3__-68 14460-14515 Production Open 14535-14595 Production Open 14960-15175__ Wtr, In',]_~____~_pOen 15195-15250 Wtr, In__~,__~Oen i INITIAL PRODUCTION~ Testin~ TYPE:_ E E E CASING HEAD: Shaffer 12" - 900 Series K-D CASING HANGER: Shaffe~' 12" Nominal'9-5/8" Model K.D-K.S.~ ....... CASING SPOOL:_ TUBING HEAD: TUBING HANGER: Cameron Single 4-1/2" DC-B12 3000# WP X 10" 5000# WP Nominal 10" X 3-1/2" EUE UP 3-1/2" EUE Do~m Cameron TUBING HEA~ TOP' 10" 1500 Cameron assembly Seal Type "R" J MASTER VALVES: Cameron 3" type "F" '3 I /,)it 1:;'1T'~' · t LEASE UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE Trading Bay State VgELL NO. G-9 FIELD McArthur River DATE 4-22-68 4-23-68 · 4-24-68 4-25-68 4-26-68 4-27-68 4-28-68 E.T.D. DETAILS OF OPERATIONS, DESCRIPTION~ & RESULTS 596' 640' 13~4' 2395' 3101' 3101' 3101' Spudded well G-9 @ 1600 hours 4/22/68. Dyna drilled 15" hole from 359' to 596'. Dyna drilled and surveyed 15" hole from 596' to 640'. Opened 15" hole to 22" from 359' to 640'. Ran 19 its. 16" 75# JSS 8rd csg. w/Baker flexiflow shoe on bottom of Joint #1 and cast iron baffle plate at bottom of Joint #2. Landed casing @ 623.25' w/baffle @ S92.79'. Cement- ed casing w/1300 sacks Class G cement mixed w/inlet water. Last 300 sacks mixed w/2% CaC12. Bumped HOWCO plug on baffle plate w/400#. Float O.K. Good cement returns to surface. CIP @ 1S00 hours 4/23/68. 16" Baker Flexiflow Shoe 2.18 623.23-621.00 18 Jts. 16" J55 75# 8rd Csg. 605.65 621.00- 15.40 Landing Jt. Landed Below Rt. 15.40 15.40- 0.00 Installed 20" hydrill [ tested to 500# for 15 minutes. O.K. Drilled baffle plate, cemented in Joint #1 and shoe. Drilled and surveyed 15" hole to 926'. Dyna drilled and surveyed 15" hole from 926' to 1189'. Drilled and surveyed iS" hole to 1364'. Drilled and surveyed 15" hole to 2108'. Dyna drilled from 2108' to 2184'. Drilled and surveyed IS" hole to 2395'. Drilled and surveyed 15" hole to 3101'. Ran Servco 18" tt.O. Pulled into csg. to make connection. Arms would not close. Stuck same. Worked hole opener out of hole. Opened 15" hole to 18" from 623' to 2258'. · Opened 15" hole to 18" from 2258' to 3079'. Ran ~ cemented 72 its. 13-3/8" 61# J-55 buttress csg. Landed shoe @ 3044', float collar @ 2999' [ diff. collar @ 2954'. Cemented through shoe w/900 sacks "G" premixed w/lO% gel, 1% CFR-2 ~ 2% CaC12; followed w/900 sacks CFR-2 and in turn followed w/500 sacks "G" w/2% CaC12. Ali cement mixed w/sea water. Good returns to surface. Bumped-plug w/1200 psi. Released press. - Floats held O.K. C.I.P. 11:00 P.M. 13-3/8" Casing Detail Jts. 13-3/8" HOWCO Float Shoe 13-3/8" 61# J-SS Buttress Csg. 13-3/8" HOWCO Float Collar 15-3/8" 61# J-SS Buttress Csg. 13-3/8" }IOWCO Diff. Collar 13-3/8" 61# J-SS Buttress Csg. 1.95 3044.47-3042.52' 1 41.58 3042.52-3000.94 1.68 3000.94-2999.26 I 42.77 2999.26-2956.49 2.06 2956.49-2954.43 70 2916.43 2954.43-38.00 38.OO-00.00 Landed below zero 38.00 72 3044.47' UNION OIL CO. OF CALIFOrNiA DRILLING RECORD SHEET D- PAGE NO.. LEASE Trading Bay State WELL NO. G-9 FIELD ~l~Arthur River DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE 4-29-68 4-30-68 5-8-68 5-9-68 5-10-68 5-11-68 S-12-68 5-13-68 5-14-68 5-21-68 5-22-68 5-23-68 S-24-68 5-25-68 5-26-68 5-27-68 5-28-68 5-29-68 E. T. D. 3101' 8094 ' 7842' Est. PBTD 7994' · 8036' 8059 ' 8462' 10,249' 10,277' 10,291' 10,291' 10,315' 10,475' 10,631' 10,631' 10,631' Instalied 12" 900ix 13-3/8" K.D. head. Tested same w/3000 psi. 10 min. O.K. Nipp?d Bp ~.O.E. ~ rizer system. Tested blind rams w/1500 psi. 15 min. O.K. Tagged top of cement @ 2952'. Pressure tested pipe rams ~ hydril w/1500 p~i.. 1S min. O.K. Directionally drilled 3101' to 8094'. Twisted off while drilling at 8215'. P.O.H. Found bit, 2 12-1/4" stabilizers, lead collar left in hole. Lead collar twisted off @ bottom of box. R.I.H. w/overshot, bumper sub, hydraulic jars. Unable to get over fish. P.O.H. Ran in open-ended DP & pu~ed 300 §acks CFR 2 cement w/2% CaC12 and 15% sand mixed w/inlet water. CIP 10 P.~t. 5/9/68. WOL. Rill. Found plug at 7893'. Polished same to 7944'. Ran dyna drill. Kicked off plug & dyna drilled to 7994'. Dyna drilled to 8010'. P.O.tt. Found two cones missing from bit#20. R.I.H. w/junk basket. No recover7. Ran 11-3/4" flat botto~ mill. biilled on junk. Ran short tooth bit to check for junk. Drilled to 8036'. Picked up dyna drill and started in hole. Dyna drilled to 8059'. R.I.H. w/drilling assembly, drilled on junky P.O.It. Found junk marks on drill collars and stabilizers. Picked up junk basket and R.I.H. w/same. Cut 3'. Started out of hole. Finished out w/junk basket. Recovered one cone. Drilled ~ surveyed 12-1/4" hole. Directionall7 drilled 8790' to 10,249'. Ran dyna drill. On first orientation survey gand line parted. Pu!led 45 stands to recover line. Repaired same. Dyna drilled from 10,249' to 10,277'. Due to severe wail sticking, unable to continue dyna drilling. Had considerable difficulty getting out of hole. Drilled 12-1/4" hole from 10,275' to 10,291'. Lost AC power. Pulled up into shoe of 13-3/8" casing w/drilling assembly. Shut down due to loss of AC power. AC power restored @ 7:30 P.bl. Drilled and surveyed 12-1/4" hole from 10,291' to 10,315'. Drilled and surveyed 12-1/4" hole from 10,315' to i0,475'. - Drilled and surveyed 12-1/4" hole from 10,475' to 10,631'. P.O.li. w/drilling assembly. Rigged up Schlumberger. Ran DI~, CF DL, and ttRD logs. Schlumberger found bottom @ 10,561'. Finished logging. Made trip to condition hole for 9-5/8" casing as follows: UNION OIL CO. OF CALiFOrNIA . SHEET D DRILLING RECORD PAGE NO.. · LEASE Trading Bay State Vv-ELL NO. G-9 FIELD McArthur River DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS S-30-68 S-31-68 6-1-68 6-2-68 6-3-68 6-4-68 6-5-68 6-6-68 6-7-68 6-8-68 4609' (D.V.) 10,744' 10,870' 10,959' 11,094' 11,232' 11,418' 11,484' 11,832 9-S/8" Casing Detail Jts. 9-5/8" HOWCO Sealock Float Shoe 9-5/8" 47# NS0 Seal Lock Tubing 1 9-5/8" HO%VCO Seal Lock Float Collar 9-5/8" 47# NS0 Seal Lock Csg. 1 9-5/8" [tOh'CO Sea! Lock Side Fill collar 9-S/8" HOWCO Seal Lock Plug Adapter 9-S/~" 47# NS0 Seal Lock Csg. 34 9-S/8" 43.5# N80 Seal Lock Csg. 67 9-5/8" 40~ N80 Seal Lock Csg. 41 9-5/8" HOWCO Seal Lock DV Cementer 9-S/8" 40# NS0 Seal Lock Csg. 110 9-S/8" 47# N80 Seal Lock Csg. 1 RT to Tubing Head , 1 2.07 41.21 1.87 41.86 2.10 .85 1411.98 2756.50 1686.20 2.11 4528.24 42.59 38.00 10,555.58-10,553.51 10,553.51-10,512.30 10,512.30-10,510.43 10,510.43-10,468.57 10,468.57-10,466.47 10,666.47~10,465.62 10,465.62-9,053.64 9,053.64-6,297.14 6,297.14-4,610.94 4,610.94-4,608.83 4,608.83-80.59 80.59-38.00 38.00-00.00 256 10,555.58 Installed centralizers at 10,SS0', 10,520', 10,490', 10,470', 8,080', 7,750'~ 7,480', 7,990', 6,850', S770', 4,650', 4,560', 4,340', 4,130', 3,600' 2,800', 2,700', 2,600'. Metal petal basket installed at 4,§20'. Cemented thru shoe with 1200 sacks Class "G" w/l% CFR-2 followed by 1000 sacks Class "G", all mixed with fresh water. Pumped plug with lSd-psi, at 2400'. Floats held. ~ol. Cemented with 1000 sacks Class "G" w/l% CFR-2 followed by 1000 sacks Class "G" with 2°~-~aCl_, all mixed with fresh water. Close~--~ tool with 2000 psi. at 02452blay 30. tleld O.K. Set slips and packing in Shaffer casing head. Installed Cameron tubing head ~ nippled up B.O.E. Tested blind rams w/1S00 psi.- 10 mins. O.K. RI to DV. Tested pipe rams w/1S00 psi. - 10 mins. O.K. Drilled DV RI to float collar. Tested hydril ~ casing w/1S00 psi. - iS mins. O.K. · Drilled out cement ~ shoe. Drilled 8-1/2" hole from 10,593' to 10,744'. Dyna drilled from 10,744' to 10,764'. Difficult to orient dyne drill due to excessive torque and drag. After dyne drilling 20', P.O.H. Found bit to be completely bald. Ran drilling assembly & drilled 8-1/2" hole from 10,764' to 10,870'. Dyna drilled from 10,870' to 10,900'. Center of bit cored out. Ran building drilling assembly and drilled 8-1/2" hole from 10,900' to 10,959'. Dyna drilled from 10,959' to 11,033'. P.O.H. for bit change. Dyne drilled from 11,033' to 11,094' to correct right hand turn. Drilled 8-1/2" hole to 11,232'. Pulled into csg. Shut rig down to repair Union electric panel. -_ Drilled & surveyed 8-1/2" hole to 11,376'. Dyne drilled from 11,376' to 11,446'. Dyna drilled and surveyed 8-1/2" hole from 11,418' to 11,484'. ~Iade follow up run from 11,484' to 11,508'. Ran in with LOR Stabilizers and rc2med from 10,758' to 11,832'. UNION OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE .NO. ! · LEASE Trading Bay' State WELL NO G-9 FIELD Mc^rthur River DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6-9-68 6-12-68 6-13-68 6-14-68 6-15-68 6-16-68 6-17-68 6-18-68 6-19-68 6-20-68 6-21-68 6-22-68 6-23-68 6-24 -68 12,659' 12,867' 13,105' 13,250' 13,250' 13,250' 12,898' 12,958' 12,962' 13,061' 13,182' 13,266' Drilled an~d s.uFveyed 8-I/2" hole from 11,832' to 12,659'. Drilled and surveyed 8-1/2" hole from 12,659' to 12,867'. Laid down 2 drill collars due to excessive drag in hole. Drilled and surveyed 8-1/2" hole from 12,867' to 13,105'. Hole drag decreased after dropping two D.C. out of string. Drilled $-1/2" hole to 13,250'. Pipe torqued and stuck while drilling. Working torque do~m string for free point,rotary bushing jmmp~d out permitting pipe to back lash and back-off; dropping pipe and sticking wire line. Screwed into pipe. Pulled wire line out of hole. Ran string shot~backed-off @ 1507'. P.O.H. Replaced two bad joints. Screwed back into pipe @ 1507'. Free point and backed-off @ 13,159'. Left 1-SDC, 2 monels, 1-LOR stabilizer and 8-1/2"~bit in hole. Ran 2 sets oil jars, bumper sub and jar accelerator. Screwed into fish @ 13,159'. Unable to move fish by jarring. Ran free point. Drill collar stuck at 13,165'. Backed-off @ 13,159'. Left X-over sub in hole. Top of fish @ 13,158'. Ran opened drill pipe to 13,081'. Plugged back with 130 sacks Clas~ "G" cement mixed with 12% sand. (300' plug plus 30% excess.) C.I.P. @ 6:30 A.M. Tagged top of (soft) cement @ 12,780', firm cement @ 12,812'. Polished plug to 12,898'. Conditioned hole and mud 6 hrs. Short trip into shoe of 9-5/8" hole in fair condition. Maximum hook load coming off bottom was 330,000#. Ran 6-1/4~' dyna drill. While removing Kelly after circulating (3 mins. total), pipe was wall stuck. Unable to pull loose. Bumped down and freed pipe. Pulled dyna drill out of hole. Ran and set doubleset whipstock @ 12,898'. Drilled 6-1/8" hole to 12,911' w/whipstock set 110° left. Drilled 6-1/8" hole off whipstock to 12,920'. Opened hole from 12,900' to 12,920'. Made follow run w/8-1/2" bit from 12,920' to 12,958'. Bit seemed to be drilling down mud ring from 12,935' to 12,958'. P.O.H. w/whipstock, ran dyna drill. Dyna drilled from 12,982' to 13,023'. Ran Gilligan to follow dyna drill run. Drilled from 13,023' to 13,061'. P.O.tt. w/Gilligan at 13,061'. R.I.H. w/drilling assembly w/string reamer approx. 300' above bit. Drilled from 13,061' to 13,182'. Drilled from 13,182' to 13,266'. P.O.H. for bit change. Stuck drilling assembly w/bit @ t2,418', top-of mortals 8 12,345' and string reamer @ 12,116'. Backed-off drill pipe @ 11,386'. UNION OIL CO. OF CALIFORNIA DRILLINg RECORD SHEET D PAgE ~O.' I ~ LEASE Trading Bay .State IarELL NO. 6-9 iFIELD McArthur River DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6-25-68 6-27-68 6-28-68 6-'29- 68 6-30-68 7-1-68 7-2-68 7-3-68 7-4-68 7-5-68 7-6-68 7-7--68 10,900' 10,703' P.B. 10,727' 10,827' 10,972' 11,272' 11,558' 11,740' 11,740' 11,550' 11,202 ' 11,289' R.I.H. w/drill collars, jars, bumper sub and drill pipe single. Screwed into fish. Unable to back fish off. Stuck fishing string. Backed-off top sub and stabilizer. Top of fi'sh @ 10,962'. R.I.H. w/ washover pipe. Washed down to stabilizer on bottom of 3rd collar. Spotted pipe lax over fish. Attempted to back-off w/Lebus latch tool. Unable to get to bottom w/back-off shot. Wash pipe stuck while attempt- ing to back-off. Backed-off above drive bushing in top of wash pipe. Recovering X@ sub, bumper sub a~d jars. With open end drill pipe @- 10,900', mixed 1S0 sacks CFR 2 cement w/1S% sand and 100 cu. ft. water. Preceeded mix w/100 cu. ft. water mixed w/100# caustic. Displaced w/ 1048 cu. ft. mud. C.I.P. @ 2,145' 6/26/68. P.O.H. w/drill pipe, BS, jars .and X@ sub. Theoretical plug top, 10,S12'. Tagged top cement @ 10,699[. Polished plug to 10,703'. Cleaned all mud pits. Conditioned mud. Completed dropping mud weight & conditioning same. Dyna drilled from 10,703' to 10,727'. Dyna drilled from 10,727' to 10,794'. Followed dyna drill with "Gilligan" and drilled to 10,827'. Reamed dyna drill hole and drilled and surveyed 8-1/2" hole to 10,972'. Had some problems with hole caving. Drilled and surveyed 8-1/2" hole from 10,972' to 11,272'. Two trips w/out problems. Drilled and surveyed 8-1/2" hole from 11,272' to 11,558'. Had some difficulty breaking angle building tendency. Hole in good condition. Drilled and surveyed 8-1/2" hole from 11,558' to 11,740'. Stuck pipe running in hole w/new bit. 'Ran free point. Stuck at bottom stabilizer and bit. Backed-off @ 11,693' leaving bit, stabilizer and one monel D.C. in hole. R.I.H. w/2 its. 7-5/8" wash pipe and fishing assembly. Stuck wash pipe while rotating through tight hole @ 11,626'. Backed-off safety joint leaving rotary shoe and 2 jts. wash pipe in hole. Top of fish ~ 11,550'. R.I.H. and hung open ended drill pipe @ 11,541'. Cemented with 150 sacks DFR-2 w/12% sand added. C.I.P. 6'15 P.M. 7-5-68. Ran in w/drilling assembly to polish cement plug. Reamed tight hole from 11,002' to I1,165'. Top of cement at 11,165'. Polished plug to 11,202'. Conditioned hole and mud. Ran in w/dyna drill. Stuck survey instrument on first orientation survey. Sand line parted leaving instm~ment [ 3,000 ft. line in hole. P.O.H. Recovered line [ instru- ment. Spliced sand line. R.I.II. w/dyna drill & kick sub. Oriented $ dyna drilled from 11,202' to 11,272'. P.O.ll. Picked up Gilligan. R.I.H. Drilled from 11,272' to 11,289'. LEASE UNION Oil GO. Of caLifOrNia DRILLING RECORD , SHEET D PAGE l~lO..i 6 Trading Bay State WELL NO. G-9 · ,FIELD McArthur River DATE E.T.D. 7-8-68 7-9-68 7-10-68 7-11-68 7-12-68 7-13-68 7-14-68 7-16-68 7-17-68 7-24-68 7-25-68 7-26-68 11,491' 11,764' 12,108' 12,321' 12,590' 12,919' 13,354' 13,785' 15,261' 15,330' 15,330' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS P.O.H. to change D~A. R.I.tl. and drilled from 11,289' to 11,466' P O.H. for bit cha~ge. R.I.H. w/bit #84. Drilled 11,466' to 11,~91'. Drilled from 11,49~' to 11,764' w/trip for new bit @ 11,604' and 11,764'. Drilled ~ surveyed~8-1/2'' hole ~rom 11,764' to 12,108' w/trip for new bit @ 11,981'. Drilled from 12,108' to 12,213' w/trip for new bit @ 12,213'. Reamed tight hole from 11,423' to 12,215'. Hole very sticky. Drilled from 12,213' to 12,321'. Excessive torque ~ drag in hole. Pulled out of hole for D.A. 5 bit change. Drilled 5 surveyed 8-1/2" hole from 12,321' to 12,510'. P.O.H. for bit change.' Removed every other rubber on D.P. in an attempt to decrease torque. Drilled to 12,590'. Due to excessive torque & drag, P.O.it. 5 re-rubbered drill pipe. Torque ~ drag decreased by re-rubbering & additional rubbers added. Drilled 5 surveyed 8-1/2" hole from 12,590' to 12,919'. Drilled & surveyed 8-1/2" hole from 12,919' to 13,354'. ! Drilled & surveyed 8-1/2" hole from 13,354' to 13,785'. On trip for bit @ 13,785', had tight hole from 13,685' to 13,585' (Coal). Directionally drilled from !3,916' to 15,261'. Drilled ~ surveyed to 15,330'. Raised Vis. to clean upcoal section around 12,000'. Conditioned hole for logs. P.O.H. Ran O.K. Could not get below II,S00'. Ran in w/drilling assembly. Conditioned hole. Ran 120 its. 7" 29# NS0 spec. clearance buttress casing as liner (see detail) Installed centralizers on collars at 15,281', 15,200', 15,120', 15,040', 14,950', 14,870', 14,800', 14,710', 14,630', 14,550'. 7" Liner Detail Baker Model "G" Diff. Fill Shoe 7" 29# NS0 Spec. ¢lea~ Butt. Baker Model "G" Diff. Fill Collar TIW l. anding Collar 7" 29# N80 Spec. Clear. Butt. TIW Liner flanger Jts. 2.40 1 41.89 1.80 0.91 119 4969.44 24.35 15,328.00-15,325.60 15,325.60-15,283.71 15,283.71-15,281.91 15,281.91-15,281.00 15,281.00-10;311.56 10,311.56-10,287.21 120 5,040. UNION OIL CO. OF CaLiFOrNIa DRILLING RECORD SHEET D PAGE NO. , LEASE Trading Bay State WELL NO G-9 FIELD McArthur River DATE E.T.D. 7-27-68 7-28-68 7- 29 - 68 7-30-68 7-31-68 . 8-] -68 8-2-68 8-3-68 8-4-68 8-5-65 8-6-68 8-7-68 15,281 15,281' 15,281' 14,643' 14,643' 15,281' · 15,281.' 15,281' 15,281' 15,281' 15,281' 15,283' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Cemented w/300 sacks Class "G" w/CFR-2. Full returns. CIP @ 0600. Floats held. P.O.t[. Ran Schlumberger GR-N. Would not go below Il,S00'. R.I.tt. w/bit to cond. mud. Cond. Mud. Ran GR-N, CBL. Schl~nberger perforated 14,660' - 14,690' w/4 JSPF w/csg, guns. Made up ttOIVCO test tools. R.I.tt. w/test tools, set packer at 14,579'. Dist.#1 opened tool @ 0707, closed @ 0717. Opened @ 0850, closed @ 1650. Reversed out 13,670' rathole fluid and salt water. No oil. IH 4860, FP 1201, ISI 3992, FP2 1777 - 3992, FSI 3992, FI! 4860. · Pulled loose @ 01S0. P.O.H. Ran HOWCO cement retainer on Schlumberger wire line, set at 14,643'. R.I.H. Stabbed in, broke down w/4800 psi. Pumped 12 CFM ~ 3600 psi. Squeezed w/100 sacks Class "G" w/CFR-2. Displaced 73 CF past retainer. Final pressure 5600 psi. Reversed out 72 CF cement. P.O.H. R.I.H. w/RTTS tool, looked for leak. Found none. Tested liner lap w/i2S0# O.K. P.O.H. RU Schlumbergem Perf. 14,595' to 14,625' 4 H/PF w/scallop gun. R.I.H. w/HOWCO Dst. tools for Dst.#2 14,595' to 14,625' w/RTTS @ 14,486'. Tool open 8 hrs. Rev. out. Recovered 50 BO 6% B S & W, 30°API. IttP 4956, IF 48#, FF 192# CIP 3968#, IF2 192#, FF2 1201#, CIP2 3992~, Ft[P 4,956#. R.I.H. w/bit CO retainer @ 14,643'. RI to 15,281'. Circulated hole clean. Displaced mud w/inlet tt20. Adding salt. Building weight up to 68#. P.O.H. R~ Schlumberger. Perforating. Perforated 4 holes/ft..w/2" scallop gun, 14,460 - 14,515, 14,535 - 14,595, 14,740 - 14,930, 14,960- 15,175, 15,195- 15,250'. R.D. Schlumberger R.I.tl. w/6" bit & scraEer. P.O.H. Laid down 3-1/2"D.P. RU to run tubing. Running 3-1/2" tubing. Finished running tubing. Ran Schlumberger collar locater thru tubing. Respaced tubing. (See Otis Tubirig Detail on Next Page) Reverse circulated inlet water to contract tubing. Dropped Otis test plug, chased to bottom & set w/wire line. tlOWCO set packers w/5250 psi. Tested annulus to 800 psi, held O.K. Pulled Otis plug. Installed ball valve. Removed BOPE, installed X-mas tree RU ~ began swabbing perfs. 14,740' - 15,250'. Continued swabbing; fluid level at 500'. Continued swabbing. Total recovery 800,661 salt water (600 Bbl. net hemlock water) in 41-1/4 hrs. Rigged down swabbing gear. Released rig 0 1300 hrs. 8-7-68 Moved to G-12. UNION OiL CO. OF CaLifOrNia DRILLING RECORD SHEET PAGE NO. LEASE Trading Bay State f WELL NO. G-9 FIELD HcArthur River DATE 8-8-68 8-9-68 8-10-68 E.T.D. 1S,281' 15,281' 15,281' DETAILS Of bPERATIONS, DESCRIPTIONS & RESULTS Tried ~o get to O~is CX Mandrel at 14,378' w/wire line shifting tool. Could not get bellw 3000#. Found parrafin on tools, Began moving rig _fyom G-12 @ 0900. Installed 3-1/2" riser, BOPE. Picked up 1-1/2" ~ 2-1/16" tubing. Ran to 14,S82' breaking circula- tion at 2330 and SS2S'. At 2330', reversed out approx. 1BBL heavy emulsion. At 14,S82', circulated inlet water around twice, diesel around twice. Displaced diesel with inlet water to kill well. P.O.H. laying down tubing. Ran Otis shifting tool. Opened sleeve at 14,378'. Released rig. Displaced inlet water with diesel. OTIS TUBING DETAIL Jts. 2-7/8" BU Collar 2-1/2" Otis N Nipple Otis 7" Permitrieve Packer 2-7/8" EU x 3-1/2" EU Xover 3-1/2" EU x 3-1/2" Butt. Coup. 3-1/2" Butt. Tubing Otis 3-1/2" X Nipple 3-1/2" Butt. Tubing Otis 3-1/2" CX Mandrel 3-1/2" Butt. Tubing Otis Turn Single Packer 3-1/2" EU x 3-1/2" Butt. Xover 3-1/2" Butt. Tubing 3-1/2" CX ,~Iandrel 3-1/2" Butt. Tubing Expansion Joints fClosed) 3-1/2" Butt. Tubing Ball Valve Nipple 3-1/2" Butt. Tubing 3-1/2" Butt. Pup Jts. 3-1/2" Butt. Tubing 3-1/2" Butt. x 3-1/2" EU Xover Cameron Tubing Hanger RDB to THF Elevation 5 1 1 461 9 1 479 43 1.10 6.11 .90 .42 29.53 1.30 30.10 5.80 155.35 4.60 1.28 31.68 5.80 29.27 12.48 13,973.19 3.60 268.73 16.20 31.78 · 90 1.00 38.62 14,650.17 14,650.17-14,649.74 14,649.74-14,648.64 14,648.~4-14,642.53 14,642.53-14,641.63 14,641.63-14,641.21 14,641.21-14,611.68 14,611.68-14,61.0.38 14,610.38-14,580.28 14,580.28-14,574.48 14,574.48-14,419.13 14,419.13-14,414.53 14,414.53-14,413.25 14,413.25-14,381.57 14,381.57-14,375.77 14,375.77-14,346.50 14,346.50-14,334.02 14,334.02-360.83 360.83-357.23 357.23-88.50 88.50-72.30 72.50-40.52 40.52-39.62 39.62-38.62 0-00. UNION ,,OIL CO. OF CALIFOF ., .IA DRILLING RECORD SHEET D PAGE NO.i LEASE DATE /7/?0 '1/8/70 Trading Bay Unit S£ate E. T. D. 15281' 15281' %%tELL NO. G-9 W.O.FiELD blcArthur DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIG RELEASED from G-30 @ 9'00 am 1/7/70. Opened sleeve @-14,381' w/Otis wireline. wtr. Removed Christmas tree. NU BOE. · NU BOE & riser. Pulled & layed down tbg. Moved rig over well G-9. Killed well w/filtered Inlet RIH w/Otis pkr retrieving tool 1/9/70 1/10/70 1/11/70 1/12/70 1/13/70 15281' 15281' 15281' 15281' 15281' on dp. Retrieved pkr from 14642'. RIH w/6" bit & 7" csg scraper. RIH w/bit & scraper. Circ hole clean. POH. RU D-A.. Perfd 2 1/2" hpf, from 15250' to 15195'; 15175' to 14960'; 14930'-to 14710'; . Perfd 4 1/2" hpf from 14685' to 14535'; 14515' to 14460'. All perforations w/NCF II Kone shot 4" guns. RD D-A. RIH w/bit & scraper to 15281'. Circ hole clean. POH. Laid down dp. Set Otis pkr @ 14380' w/da. RU & ran & hydro tested 3-1/2" & 4-1/2" tbg. Ran & hydrotestd to 5200~, tapered string of tbg w/20' seal assembly, per tbg detail. Displaced annulus w/diesel & landed tbgw/tail pipe @ 14469'. Spaced locator @ 14415', Otis w.l. set pkr @ 14417', tbg measurements, & !landed tbg. Remove riser & BOP, install tree & test 5000~OK. RELEASED RIG to move to Leg ~3 @ Noon 1/13/70. .. .. Tubing Detail · .98 .75 29.60 1.25 .75 20.56 1.25 1.30 30.10 3.70 4842.93 1.35 9482.56 12.60 1.00 (1 jr) (1 jr) (160 its) (309 its) (1 pup it) Otis Guide Shoe X Over 3-1/2" buttress tbg 9.24f N-80 Otis "X" Nipple . X Ove~ - Seal Assembly (stabbed into pkr @ 14417' tbg measrmt) S.A. Locator X Over 3-1/2" butt. tbg 9.2~ N-80 "-XO" Sliding Sleeve 3-1/2" butt. tbg 9.2,~ N-80 3-1/2" butt. x 4-1/2" butt. X over 4-1/2" butt. tbg N-80 12.6~. -- 4-1/2" butt. tbg N-80 ]2.6f: Tubing lila nger 14430.68 '38.00 (471 its & I pup it) 3-1/2" & 4-1/2" buttress tubing Landed below KB. 14468.68 K.$· UNION OIL GO. OF CaliFOrNia DRILLING RECORD SHEET D PAGE NO., Trading Bay Unit State LEASE DATE E.T.D. G-9 McAr thur River V~ELL NO.. FIELD 3/9/69 2O DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Checked pressure in 9-5/8" x 13-3/8" annulus. Shut in pressure equaled 450 psi, bled to 0 psi. 12 hr build up to 430 psi. 9-5/8" x 13-3/8" annulus, 480 psi. 9-5/8" x tubing, 100 psi. Pressure between 9-5/8" & 13-3/8" will bleed down from 480# to 0# instantly. Connected Halliburton unit to well & pressured annulus to 2800# w/ 3 ft3 water. 5 minutes pumped an additional 1 ft3 w/pressure increasing to 3000#. No decrease in pressure after 15 minutes. Released pressure. Recovered 3-1/2 ft3 of water. Repressured annulus to 3000#. No breakdown. Released pressure. 5 minute shut in, 0#. After 4 hrs, 430#. After 12 hrs, 510#. Unable to squeeze cement. While attempting breakdown, 9-5/8" x tbg annulus remained @ a constant 100#. No communication between csg strings. UNION OIL CO. OF CALIFORNIA SHEET A REPAIR RECORD PA(;E NO. LEASE Trading Bay Unit State WELL NO G-9 CONTRACTOR_ Parker __ FIELD McArthur River TYPE UNIT_ National 1320 ]/5/78 COMPLETED. ]/28/78 ELEVATIONS: GROUND 224' RT to ML BEGAN: PERMIT NO68-]6 SERIA3~ NO. ^DL ]8730 CASING HEAD //~ COMPANY '~INEEB ,, _Cirri s_w~l.~/Wa,ts0/P0/~..~. ! _ / TUBING HEAD , / APPROVED¥/'A~./~/~~-/ W~,,~%. /~r~',/~'.~_~;~L{/u' ROTARY DRIVE BUSHING. 99 RT toML', / ' // CASING & TUBING RECORD SIZE DEPTH. WEIGHT ~, 2%RADE REMARKS ,. ]6" 623' 75# J-55 Cmt'd w/1300 SXS w/additives (see prey. history) 13 3/8' 3044' 61# N-80 Cmt'd w/2300 SXS w/additives (see prev. history) 9 5/8' 10555' 40-43 1/2 & 47# N-80&Pll0 Cmt'd w/4200 SXS w/additives (see prev. history) 7" 15328' 29# N-80 Cmt'd w/300 SXS w/additives (see prev. history) 4 ½-3 ½ 14455' 12.6&9.2# N-80 Injection tubing PERFOR, ~TING RECORD -~AT'E INTERVAL E.T.D. REASON ~RESEi~¥ CONDITION 7/30/6~ 14660-14690 15281 DST #1 Sqz'd w/100 SXS 7/31/6~ 14595-14625 15281 DST #2 Open for Injection 8/03/6~ 14460-14515 15281 Injectior " " " 8/03/6( 14535-14595 15281 " " " " 8/03/6~ 14960-15175 15281 " " " " 8/03/6~ 15195-15250 15281 " " " " 1/09/7[ 15195-15250 15281 " " " " 1/09/7( 14960-15175 15281 " " " " 1/10/7( 14710-14930 15281 " " " " 1/10/7( 14535-14685 15281 " " " " 1/10/7( 14460-14515 15281 " " " " 9/08/7~ 14736-14746 15281 " " " " 14782-] t 4808-1 DATE II~T~_.RVAL NET OIL CUT (~RAV. C.P. T.P. CHOKE MCF GOR I~EMARIfS 2/2/78 HEMLOCK 8703 BWPD , -' , WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. 2 COMPLETION DA~: 9/23/72 PRODUCING INTERV~: Hemlock Injector INITIAL PRODUCTION: ~ LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: Repair CSg. leak Form D-1001-B ~JNJON LEASE Tradin9 Bay Unit State COMPLETION DATE: 1/28/78 DATE E.T.D. DATE 9/08/72 9/08/72 INTERVAL 14900-14910 14914-14924 CO. OF CALIFORNIA REPAIR RECORD PAGE NO ,WELL NO. G-gw0 FIELD McArthu~ Rive~ APPROVRD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ETD 15281 15281 Perforating Record (con't) REASON PRESENT CONDITION Water Injection 4 HPF Reperforated open for II II II II II II II II TYPE: CASING SPOOL: ~BING HEAD: Cameron single 4 1/2" DC-812 3000 psi ~ TUBING HANGER: Nomi ri'al n Came )~ 4 1/2 EUEFu'~"'4 1/2" " Buttress Dow r " ' ' "~ ~ '""' ' ' ~ sea TUBING HEAD'TOP: 10"' Came on assembly 1 Type MASTER VALVES: 'Cameron 4" Type "F" Block ~ree (_single) w/master and swab valve :, ~'~., 4 1/2" EUE ~.. ., ; :~,~. .... ,_. ~.-, ..,,- ,, .... ~,,,. ,,.,. ~/.,,..,_.,,.-¥ CHRISTMAS TREE TOP CONN.: "' , - ?/,, ?iL,- "::,,~:-.~"' S EET PAGE UNIC!I OIL OF CALIFOPCIIA I,ELL I, uORD LEASE Trading Bay Unit State FIELD McArth,,r River DATE 1 1/05/78 2 1/06/78 3 1/07/78 4 1/08/78 5 1/09/78 6 1/10/78 ETD 1 5,328' TD 14,437' ETD (perm pkr) 9 5/8" csg @ 10,555' 7" liner @ 10287'-15328' 15,328' TD 4,395' ETD (cmt. ret) 9 5/8" csg @ 10,555' 7" liner @ 10,287'-15,32~ 15,328' TD 14,395' ETD (cmt. ret) 9 5/8" csg. @ 10,555' 7" liner @ 10,287'-15,32. 15,328' TD 14,395' ETD (cmt. ret) 9 5/8" csg. @ 10,555' 7" liner @ 10,287'- 15,328' 15,328' TD 14,395' ETD (cmt. ret) 9 5/8" csg. @ 10,555' 7" liner @ 10,287'- 15,328' 15,328' TD 12,050' ETD (cmt. plut) 9 5/8" cs§. @ 10,555' 7" liner @ 10,287' 15,328' DETAILS OF OPEP~TIONS, DESCRIPTIG~IS ~ RESULTS Commenced operation on G-9 @ 4'01 pm 1/05/78. Moved rig over conduc- tor 41 in leg room 2. Loaded 4 ½" tbg. and 4 ½" X 9 5/8" annulus with FIW and noted free communication between tbg. and annulus. Installed BPV and 4 ½" X-mas tree. Finished removing X-mas tree in additional 5 hrs ~lue to corrosion on studs and hold-down screws. NU 12" 3000 psi BOPE and tested to UOCO specs. Pulled 4 ½" × 3 ½" injection tbg. out of perm. pkr. @ 14,437' w/220,000#. Rigged to lay down tbg. but could not make 4 ½" rental slips hold. Secured replacement slips after 5 hrs when weather cleared for chopper flight. Pulled and LD injection tbg. Found 3 large holes in 4 ½" tbg. @ approximately 1050' w/majority of 4 ½" tbg. seYerly scaled up and externally pitted. No coupling leaks or connection problems were found. 3 ½" tbg. in satisfactory condition as corrosion problems lessened w/depth. Ran 6" bit on 3 ½" S-135 & 5" DP to 14,428' w/o obstruction. Cir. hole clean w/FIW. Pooh and RU W.L. Ran 5 3/4" od gage ring & junk basket on W.L. to 14,445'. Ran 7" Baker cmt. ret. on W.L. & set @14,395' to isolate Hemlock injection perfs from squeeze work. Ran 7" Baker retrieYa- matic on 3 ½" × 5" DP and set pkr @ 10,301' (14' inside 7" liner). Pkr. would not hold. Moved pkr. to 10,354' and pressured DP to 1200 psi o.k. (PI-@ 12 cu.ft./min & 1700 psi). Attempted to pressure test 9 5/8" cs§. & 7" liner lap to 3600 psi and PI @ 15 Cu.ft./min & 1900 psi (apparent hole in 9 5/8" csg. or 7" liner lap leaking). Moved pkr to 12,800' to locate hole in 7" liner and pkr would not hold - communicated around pkr to annulus. Checked pkr @ 12,716', 12,685' and pkr. would not hold. Checked 7" Baker retrievamatic final time @ 12,645' and communicated to annulus - pkr not holding. Pooh and repaired pkr. Re-ran 7" retrievamatic on 3 ½" X 5" DP & set pkr @ 10,354' (67' inside 7" liner). PI DP @ 1 CFM & 1900 psi and PI 9 5/8" X 5" annulus @ 34 CFM & 1900 pis. Moved pkr down hole and located 7" casing leak 12,635'-12 658'0. Tested 7" liner from 12,658' to cmt. ret. @ 14,395 to 3750 ps~ k. With pkr @ 12,6'35' PI 7" casing leak (al6 CFM & 2500 psi and PI 9 5/8" × 5" annulus @ 35 CFM & 1900 psi. Pooh w/ pkr. Rigged W.L. and set 7" Baker cmt ret @12,440' to squeeze hole in 7" liner. Finished pooh and RD W.L. after setting 7" sqz. cmt. ret. @12,440'. Ran stinger on 3 ½" x 5" DP and stabbed into ret. PI 7" csg. leak 12,635'-12,658' @ 16 CFM & 2500 psi. Mixed and pumped 150 SX (172' cu.ft.) Cl "G" cmt w/ .3% D-19, .75% D-31 and .1% D-6. Squeezed 7" csg leak w/92 cu.ft, cmt. to lock up @ max. pressure of 5500 psi. Held pressure for 10 min w/no bleed off. Held 1900 psi on annulus by PI @ 36 CFM while squeezing. Pulled out of ret and dumped 80 cu ft. cmt on ret to 12,050'. Pooh w/DP. Ran 8 ½" bit and 9 5/8" c~g scraper on 5" DP to top of 7" liner @10,287'. Circ. hole clean w/FIW and pooh. RU Dialog W.L. and ran 64 arm casing caliper inspection log in 9 5/8" csg. to DY tool @4609' and logging tool would not go deeper. Logged out of hole from 4658' to surface. RIH w/ 8 1/2" bit and 9 5/8" csg. scraper on 5" DP. S EET PAGE UHIC!I OIL CCI"?/ 'IY CS CALIFORIIIA ,ELL I',ECO[ D LEASE Trading Bay Unit State I'~LL l IO, G-9 FIELD McArthur River DATE 7 1/11/78 8 1/12/78 9 1/13/78 10 1/14/79 ETD 15,328' TD 12,050' ETD (cmt. plug) 9 5/8 csg. @ 10,555' 7" liner @ 10287'-15328' 1 5,328' TD 12,050' ETD (cmt. plug) 9 5/8" csg.@ 10,555' 7" liner @ 10287'-15328' 1 5,328' TD 14,395' ETD (cmt. ret) 9 5/8" cs§. @ 10,555' ~" liner @ -287'-1 5328' 5,328' TD 4,395' ETD 5/8" C @ 0,555' '" liner @ 0827 ' -15328' DETAILS OF OPEP~qTIONS, DESCRIPTIO~IS & RESULTS Finished RIH w/8 ½" bit & 9 5/8" csg. scraper and worked scraper through DV tool @4610' for 15 min. RIH to 4750' and circ hole clean. Pooh. Ran Dialog csg. calliper inspection log in 9 5/8" csg. to 8625' and tool stopped. Logged from 8625' to 4568' and pooh. Log showed jt above DV tool @ 4610' to be worn to 8% (1/32") remaining wall thickness from 4610' to 4590' and remainder of 9 5/8" to be in usable condition. Ran Baker 9 5/8" retreivamatic on 5" DP and set [a4501'. Tested 9 5/8" X 5" annulus to 3500 psi o.k. Moved pkr to 4710' and tested 9 5/8" csg. from 4710' to 7" liner lap @ 10,587' to 3500 psi o.k. Moved pkr to 4501' and PI hole in 9 5/8" csg. 4610'-4590' @ 30 CFM & 1500 psi. Squeezed hole w/400 S× C1 "G" cmt w/.75% D-31, .3% D-19, & .1% D-6 pumping @ 16 CFM & 1600 psi decreasing to 6 CFM & 2000 psi. Displaced cmt and cleared hole w/40 cu.ft, water. Pressure held @ 1800 psi w/pump off and grad. dec. to 1350 psi and holding ther~ in 3 hrs. Released pkr and circ. hole clean. CIP @1:05 pm and now WOC 12 hrs. WOC from fist sqz of 9 5/8" csg leak for total of 12 hrs. Reset 9 5/8" Baker retrievamatic pkr @4501'. PI 9 5/8" csg leak 4610'-4590' @ 12 CFM & 2000 psi (before first sqz PI @ 36 CFM & 1900 psi). Mixed & pumped 200 SX C1 "G" cmt w/add, and w/ 80 cu.ft, of FIW displacement in DP plugged ret pkr. Could not move cmt w/2000 psi on DP or ann. (9 5/8" × 5" ann. would hold 2000 psi - hole plugged w/cmt chunks from DP). Released pkr and pulled wet string dumping all green cmt. - no DP cmt'd up. Found pkr plugged w/chunks of cmt sheath which was left 6n 5" DP from previous squeezes and peeled off inside of DP. Ran DP iopen ended to 4501' and pooh rattling and cleaning each stand of DP. IRan 8 ½" bit on 5" DP and washed out cmt chunks from 4546' to 4620'. Circ. hole clean & pooh. Ran 9 5/8" Baker ret pkr on 5" DP and set @ 4501'. PI 9 5/8" csg leak @ 17 CFM & 1700 psi. Squeezed hole in 9 5/8" cs§ 4610'-4590' w/200 sx. C1 "G" cmt w/.75% D-31, .3% [I-19, .1% D-6 and 7 1/2% sand pumping @ 16 CFM & 1200 psi decreasing to 3 CFM & 3500 psi. Displaced cmt & cleared hole w/40 cu.ft, water. Pres_~ held @ 2400 psi w/ pump off and grad dec. to 1400 psi in 3 hrs and holding there. Released press and had small fl ow back. Repressured to 1400 psi for 1 ½ hrs and released press - o.k. no flowback. Re- leased pkr and circ hole clean. Pooh and now WOC for 12 hrs. CIP @ 5:40 pm. Finished WOC total of 12 hrs after second sqz of 9 5/8" csg. leak @4610'-4590'. Ran 9 5/8" Baker cmt ret on 5 "DP and set @ 4474'. PI csg. leak @ 16 CFM & 2000 psi. Mixed and pumped 300 SX C1 "G" Cmt w/.75% D-31, .3% D-19, and .1% D-6, and 5% sand. Sqz. 9 5/8" :sg leak 4610'-4590' pumping @ 2 CFM & 4000 psi w/137 cu.ft, cmt )elow ret. Stopped pumping to switch Howco pumps and could not move :mt again w/5000 psi. Held 5000 psi on hole for 5 min w/no bleed off. )ulled out of ret and reversed hole clean. CIP @ 8:00 pm 1/13/78. )ooh and WOC total of 24 hrs. ~an 8 ½" 'bit on 5" DP and drill ed cmt ret @4474'. Drlg hard cmt From 4474' to 4632' and stingers to 4753'. Circ. hole clean. ]losed pipe rams and tested 9 5/8" csg leak to 3000 psi o.k. RIH ~o top of 7" liner @ 10,287' and circ hole clean. Pooh. Ran Baker 5/8" retreivamatic pkr on 5" DP and set @1815'. Tested 9 5/8" csg from 1815' to top of 7" liner @10~2~B7' to 3600 psi o.k. D ?AGF UNICN OIL CC '? ih' OF CALIFOPCIIA I,£LL LEASE Trading Bay Unit State ¥~LL ,,0, G-9 FIELD McArthur River 11 1/15/78 12 1/16/78 13 1/17/78 14. 1/18/78 15 1/19/78 ETD 15,328' TD 14,395' ETD (cmt ret) 9 5/8" csg @10,555' 7" liner @ 10287'-15328' 5,328' TD 14,395' ETD (cmt ret) 9 5/8" csg @ 10,555' 7" liner @ 10287'-15328' 15,328' TD 6023' ETD (cmt ret) 9 5/8" csg @10,555' 7" liner @ 10287'-15328' 15,328' TD 4445' ETD (cmt ret) 9 5/8" cs§ @10,555' 7" liner @ 10287'-15328' 5,328' TD i023' ETD (cmt ret) 9 5/8" csg @10,555' liner @ 0287'-15328' DETAILS OF OPEP~TIONS, DESCRIPTIG~IS & RESULTS Rooh w/pkr. Ran 6" bit on 3 1/2" × 5" DP and tagged TOC in 7" liner @12,010'. Drlg had cmt from 12,010' to cmt ret @12,440' in 12 hrs. Pooh for new bit. Finished RIH w/new 6" bit on 3 1/2" × 5" DP. Drlg cmt ret @12,440' ~nd hard cmt to 12,667'. Fell free and RIH to cmt ret @ 14,395'. Circ hole clean and pooh. Ran 9 5/8" Baker retrieYamatic on 5" DP and set @1880'. Attempted to pressure test 9 5/8" csg leak and 7" liner leak squeezes to 3600 psi. Held pressure for approx 1 min and )roke back to 1500 psi. PI @17 CFM & 1800 psi and held 1300 psi w/pump ff. Ran pkr to 4724' and tested 9 5/8" csg, 7" liner lap @10,287', and 7"liner leak sqz to 3600 psi - o.k. PI 9 5/8" × 5" annulus @22 CFM & 1700 psi. Pooh w/pkr. Ran 9 5/8" Baker cmt ret on 5" DP and set @6023'. Pooh and re-ran 9 5/8" retrievamatic on 5" DP, imcomplete. Finished RIH w/Baker 9 5/8" retrievamatic on 5" DP w/ 9 5/8" cmt ret !6023' & 9 5/8" retrievamatic @4445' tested 9 5/8" X 5" annulus to !700 psi above pkr. PI 9 5/8" csg leak 4610'-4590' @17 CFM & 1700 psi Mixed 300 SX C1 "G" cmt w/.3% D-19, .75% D-31 and .1% D-6 @118 #/CF and squeezed below pi<r @ 16 CFM & 1800 psi to 8CFM & 2150 psi. Dis- )laced cmt and cleared csg holes w/40 CF water. Held 1350 psi for 5 win w/pump off. Released pressure w/no backflow and reversed hole clean. CIP @ 3:00 a.m. WOC 12 hrs. Reset retrieYamatic @4414' and PI 9 5/8" csg leak 4610'-4590' @ 17 CFM & 1700 psi. Mixed 300 S× C1 "G" cmt w/.3% D-19, .75% D-31, .1% D-6 and 10% sand @119 #/CF and squeezed below pkr @3-4 CFM & 1600 -3100 psi. Pressure rising and falling as formation fractures and squeezes repeatedly. Displaced :mt & cleared csg hole w/40 CF water @ final 4 CFM & 2400 psi. Held 950 psi for 5 min w/pump off. Released pressure w/no backflow and · eversed hole clean. CIP @ 5:10 p.m. Pooh w/pkr and WOC 12 hrs. --inished WOC after second squeeze for total of 12 hrs. Ran 9 5/8" 3aker cmt ret on 5" DP and set @ 4445'. PI 9 5/8" cs§ leak 4610'- 4590' @ 15 CFM & 1950 psi. Mixed 300 S~( C1 "G" w/.3% D-19, .75% D-31, .1% D-6 and 5% sand @119 #/CF and pumped to holes @8-4 CFM & _~100-3800 psi. Displaced cmt to ret @ final lock-up squeeze pressure ~f 5500 psi after two - 2 min. hesitations. Held 5500 psi for 5 min ~/no bleed off to hole. Bled pressure to 2000 psi and pulled out of ret. Rev. hole clean and pooh w/DP. WOC for 24 hrs before drlg ret. ROC for total of 21 hrs after third squeeze of 9 5/8" csg leak @4610'- ~590'. RIH w/8 1/2" bit to TOC @4390'. Drlg out cmt and cmt ret ~4445'. Drlg hard cmt below ret to 4541' and stingers to 4701'. RIH ~o cmt ret @6023' and circ hole clean. Test 9 5/8" cs§ to 2500 psi o.k. and pooh. RIH w/9 5/8" Baker retrievamatic and set @1855'. Pressure tested 9 5/8" csg to 3400 psi and bled off to 2000 psi in 7 min. Repressured to 2500 psi and bled off to 1600 psi in 12 min. SIqEET D P^ r_ UHIC[I OIL CCIP/ ih' CF CALIFOP 'IIA ,£LL I',ECO LD LEASE Trading Bay Unit State I. LL r IO, FIELD McArthur River 16 1/20/78 17 1/21/78 18 1/22/78 19 1/23/78 20 1/24/78 21 1/25/78 ETD DETAILS OF OPEP~TISNS, DESCRIPTIG~IS & RESULTS 15,328' TD Finished pressure testing 9 5/8" csg. leak 4610'-4590' after thrid 6023' ETD stage squeeze. Csg leak squeeze failed to hold 3400 psi bleeding to (cmt ret) 1600 psi in 12 min. Pooh w/ret pkr. Ran 8 1/4" burnover shoe and 9 5/8" csg @ _D,a.ke~r pkr picker on 5" DP and burned over 9 5/8" cmt ret @6023' , /4" 10,555 Pooh and did not recover ret. Ran 8 1 overshot w/5 7/8" grapple 7" liner @ on 5" DP to top of 7" liner @10,287' Engaged cmt ret several times 10827'-15328' but could not retrieve. Pooh and di~ not recover ret. Ran 9 5/8" Baker retrievamatic on 5" DP and set @4430'. PI 9~ 5/8" csg leak 4610'-4590' @13 CFM & 2000 psi. Squeezed csg leak ~v/200 S~( C1 "G" cmt w/.75% D-31, .3% D-19, .1% D-6, 10% sand mixed @119 #/CF @ 4 CFM & 1200 psi to 2400 psi. Displaced cmt to 4530' @ final squeeze rate 4 CFM & 2000 psi. CIP @10:30 p.m. 1/20/78. Pressure bled to 1250 psi in 1/2 hr. Bled pressure to 0 psi w/no backflow and rev. out. 15,328' TD Pooh w/pkr and rec small amt of cmt scale from inside of DP. WOC 6023' ETD 12 hrs. Ran 8 1/2" bit on 5" DP and drilled out firm cmt from 4436' 9 5/8" csg to 4662'. Tested 9 5/8" csg from surface to 10,287' to 1650 psi - @ 10,555' o.k. RIH to 10,287' top of 7" liner and pushed cmt ret junk into 7" 7" liner @ liner. Circ hole clean and pooh. RIH w/6" bit on 3 1/2" X 5" DP and 10287'-15328' drilled up cmt ret junk in top of 7" liner @10,287' in 5 1/2 hrs. 15,328' TD Added 5#/1000 gal Dowell FR to FIW to reduce torque. RIH to cmt ret 14,437' ETD @14,395' and drilled on ret for 3 hrs. Pooh for new bit. RIH w/6" (perm pkr) bit on 3 1/2" x 5" DP and drilled on ret @14,395' for 3 hrs. Pushed 9 5/8" cs§. ~ ret to perm pkr @14,437' and started drilling on ret junk and perm pkr 10,555' 7" 1 iner @ 10287' -15328' 1 5,328' TD 1 5,080' ETD ',junk on fill) 9 5/8" csg @10,555' Drlg on ret junk and perm pkr @14,437' and perm pkr came free. Chased junk & pkr to 15,078'. Drlg on junk @ 15,078' (apparent fill ~,5,,078'- 5,280') for 4 hfs and pooh for new bit. RIH w/6" bit on 3 1/ x 5" DP and changed out 89 its of 5" E DP for 5" S-135 DP due to high drag in hole @ 15,000'. Drlg on junk from 15,078'-15,080' in 6 hrs. 15,328' TD 15,090' ETD (junk pkr) 9 5/8" csg. @ 10,555' Pooh for bit change after drlg on ret junk & perm pkr @15,080' for 6 · Ran 30' piece of 3 1/2" DP w/pin cut off on 3 1/2" x 5" DP to junk pkr at 15,080'. Worked stinger thru pkr and worked pkr down to 15,090' in 2 hrs. Mixed 1/4#/bbl FR in RIW to reduce torque and drag and pooh. Ran 6" Servco flat btm junk mill, oil jars, bumper sub and 7" liner @ three - 4 3/4" DC on 3 1/2" X 5" DP and tagged junk pkr @14,675'. 10287'-15328' Chased pkr to 15,090' and began milling up pkr. 15,328' TD 15,259' ETD (fill) 9 5/8" csg @ 10,555' Finished milling up perm pkr @15,090' in two hrs and washed out sand fill to 15,194'. Circ hole clean and swept hole w/40 bbl hi-vis pill. Pooh w/mill. Ran 6" bit, 7" csg scraper, oil jars, bumper sub, and three 4 3/4" DC on 3 1/2" × 5" DP and washed from 15,194' to 15,259'. Circ hole clean and swept hole as above. Pooh w/bit. Ran 5 3/4" 7" liner @ gage ring and junk catcher on Go Int. W.L. to 10,575' and could not 10287'-15328' :work deeper. Pooh w/W.L, and recovered several chunks of DP rubbers in junk catcher. Ran 6" bit & 7" csg scraper on 3 1/2" X 5" DP to 15,226'. S EET PAGE UNIC[I OIL CCI:? ; Y OF CALIFOR 'IIA ,£LL LEASE Trading Bay Unit State I'~LL ~I0, G-9 FIELD McArthur River DATE i ETD 22 1/26/78 23 1/27/78 24 1/28/78 1 5,328 TD 14,395' ETD (perm pkr) 9 5/8" csg @10,555' 7" liner @ 10,827'-15328 1 5,328' TD 14,378' ETD 9 5/8" csg. @ 10,555' 7" 1 iner @ 10287'-15328' 5,327' TD 4,378' ETD (perm pkr) 9 5/8" csg liner @ 10287'-15328' DETAILS OF OPEP~TIONS, DESCRIPTIG~IS & RESULTS Finished RIH w/6" bit & 7" csg scraper to 15,226' to push DP rubber pieces to bottom and pooh w/o circ. No DP rubbers lost. Ran 5 3/4" gage ring and junk catcher on W.L. to 14,450' - o.k. Ran 7" x 4" Baker F-1 perm pkr on W.L. and stopped @11,940'. Could not work deeper. Pooh and rig pkr for DP set. Ran same pkr on 3 1/2" X 5" DP and set pkr @ 14,394' DPM (+14,378' DIL) w/3000 psi. Weight tested pkr w/25000# - o.k. and pooh. No DP rubbers lost. LD 6 1/4" and 4 3/4" DC and Kelly. Changed rams in BOPE to 4 1/2" top X 3 1/2" bottom and tested to UOCO specs. Finished RU to run tbg. Ran 142 its (4340.90') 3 1/2" 9.2# N-80 butt used tbg, 238 jts (7288.91') 12.6# N-80 butt used tbg. Ran 90 jts (2732.21') 12.6# N-80 butt new tbg. Triple "D" hydrotested all tbg to 4000 psi above slips while RIH. Stung into Baker Model F perm pkr @14,422' tbg meas (14,378' DIL) and spaced out tbg. Tested pkr to 400 psi. Pulled out of pkr and circ hole clean w/FIW. D~splace~ tbg annulus w/pkr fluid mixed w/FIW containing 1% Nelco Visco 938, 1000 ppm Nalco Visco 1153 and 100 ppm Nelco ¥isco 3656. Landed tbg w/end of 3 1/2" tbg @14,455', 3 1/2" Otis ×N nipple @14,453', Baker locator sub @14,421', 3 1/2" Otis ×A sleeve @14,386', top of 3 1/2" tbg @10,075' and 4 1/2" Otis XN nipple @328'. Installed BPV and re- moved BOPE. Installed 4 1/2" 5000 psi CIW X-mas tree and tested to UOCO specs. Returned well to injection. Began LD 3 1/2 DP. Released rig charges to G-17 @12:00 mid. On injection @5500 BPD rate & 2300 psi. Casing pressure 0 psi. SREET PAGE UHIC!I OIL C;F CALIFOPCIIA ,ELL ',ECO D LEASE TRADING BAY UN IT I'2LL r:0, , wo FIELD DATE WEBSTER AFE: 3R14n4, ]/?R/7F~ ETD DETAILS OF OPEP. ATIONS, DESCRIPTIO~IS & RESULTS JTS 1 141 238 81 9 DESCRIPTION LENGTH BOTTOM Mule Shoe OD 3.865 10 2.992 .80 Otis 3 1/2" XN OD .85 3 1/2" BTRS Collar .70 3 1/2" 9.2#N-80 BTRS Pump Jt 10.01 Baker Seal Assy 4" x 3" 20.60 Baker Locator Sub 4 1/4" x 3" .75 X-O 4 1/2 BTRS 4 1/4" x 3" .47 3 1/2" 9.2# N-80 BTRS 30.93 Otis 3 1/2" "XA" 4.10 3 1/2" 9.2# N-80 BTRS 4309.97 X-O 3 1/2" BTRS x 4 1/2" BTRS 1.13 4 1/2" 12.6# N-80 BTRS (used)7288.91 4 1/2" 12.6#N-80 BTRS (New) 2456.18 Otis 4 1/2" "XN" 1.38 4 1/2" 12.6#N-80 BTRS (New) 276.03 4 1/2" 12.6#N-80 Pup Jt 6.05 4 1/2" 12.6#N-80 Pup Jt 7.30 Cameron Single 4 1/2" BTRS down 4 1/2" EVE Ord Up .75 Landed Bel ow "0" 38.41 Pick up 235m# S/O 82m# TOP 14455.32 14454.52 14454.52 14453.67 14453.67 14452.97 14452.97 14442.96 14442.96 14422.36 14422.36 14421.61 14421.61 14421.14 14421.14 14390.21 14390.21 14386.11 14386.11 10076.14 10076.14 10075.01 10075.01 2786.10 2786.10 329.92 329.92 328.54 328.54 52.51 52.51 46.46 46.46 39.16 Total TBG 39.16 38.41 38.41 - 0 - Perm Packer @ 14,422' DPM/14,378 DIL Packer - Baker Model F-1 (7" x 4") 142 JT's 3 1/2" 9.2# N-80 Buttress (Used) 238 JT's 4 1/2" 12.6#N-80 Buttress (Used) 90 JT's 4 1/2" 12.6#N-80 Buttress (New) 470 JT's 4,340.90 7,288.91 )10,021.12/238 2,732 21 ) JTS 14,862.02' FILE NO BIT RECORD SALESMAN: Page of - CONTRACTOR RIG NO. RIG MAKE COLLARS: OD X ID X LENGTH ~O&~ ~,,(~O~ / DAY / YR. ,T.P.-DRILLERS CoMPA~ ~m .~O S~z~ . x~x~ ~ / / ~ ~ STATE COUNTY. PUMP NO. 2 DRILL PiPE UNDER ~m~,. ~/ / W~TE, SOU,C~ sec / T'SHIP/;ANOE ~D TYPE. j TOOL JOINT. TOTAL DEPTH ~/~/ FUEL SOURCE Ver ~ aJETSR-32ndSor RO DEPTH FEET CUM. ~'10~ R P M. PUMP PUMP NO 1 PUMP NO 2 MUD PROPERTIES Der Dull Cond ~ ~/~ Dote RUN SERIAL SIZE MAKE TYPE _e; PRESS Liner SPM Lm~r SPM WI WL F V. P.V Y P T B G NO 1_ 2 3 OUT FEET HOURS PER HOURS ~, HOUR LBS I . .- ........ .... ........... , ,~ _ I ~,,~ Form No SES 51 (Rev 9/65) Tr,plicate Form G E T I N Y O U R D R I L L I N G DONi. D ~- ITZ · Rotary table (110. 60' above MLL~)_ Tubing Hanger @ 3841' CASING HOLE SQUEEZES 1/10/78 7" csg, 12 634'-12658', Squeezed 150 SX Cl '~G" w/.3% D-19, .75% D-31, and .1% D-6. 1/11/78 9 5/8" csg, ,4,6~,0'-4590' squeezed w/400 SX Cl G cmt w/.~5% D-31, .3% D-19, .1% D-6. 1/12/78 9 5/8" csg, 4610'-4590', squeezed w/200 S× C1 "G" Cmt w/additives. squeezed w/200 SX Ci~ cmt w/add. w/.75% D-31, .3% D-19, .1% D-6 and 7 1/2% Sand. 1/13/78 9 5/8" csg. ,4,6~,0'-4590', squeezed w/300 SX C1 G Cmt w/add. 1/17/78 9 5/8" csg. 4610'-4590', squeezed w/300 SX C1 "G" cmt w/add. 1/18/78 9 5/8" csg. 4610'-4590', squeezed w/300 SX C1 "G" cmt w/add. 1/20/78 9 5/8" csg. ,4,6~,0'-4590', squeezed w/200 SX C1 G Cmt w/add. .. W ELL_S CH EMA_II C__G_-9_ WO ............. .'~ McArthur River Field . __; ' Started 1/5/78 Compl__e_t__ed_!/_2_8/_78 , 623' - 16' 75# J-55 8rd cemented to surface 3044' - 13 3/8" 61# J-55 Butt cemented to surface 7" liner top at 10,287' ~o~T80, P-110 Seallock-DV 14,378 DIL 7" × 4" Baker model F-1. 14,422 DPM Perm pkr. 15,328' Bottom 7" 29# N-80 Buttress i ~ i . · ~ - .... ~---' '--' - -' - ~,,,,~,~ .... $~',L~ ...... ;..~MIFi~O. 0,; Jr, ......S_.RIAf, NO.A~ - ltT'~ .'.D ..... J [' ~ 'fi' T.'V.D. ] (I, ~/l '-- PA£;[: I':O._ ll.T. TO DR[I,L DECK n.'T. TO P~ODUCTiON DECK ~PROVI,;I): -- --: "-," ,-., CASING & TUBING ~ECORD TIII1EAD Seal I,o" :it FF D E P T } [ 5 [" 4 4 FFr: 1. 0, ~ 2% CaC12. (]]it'd ~ 500 sx '%" + ]P' CFn2 · . "-80 P]ERFOHATII,~G RECO~D d,.!,th-14,504'. ,Cee ,\ttacl',Ld ' ~ ' . t 1/2" 9 25 12 6i; J;uttrdss , ..... ~ouall 7/50/~: 14 (z(L0=l,'l O 90 15,291' ])FT · /31/6 14593 14625 " _De , llater 1]]iect:.on _ , ../~/6~; 1446(~4515 ,.,, . ,~ ,, , ,, ~/~/o,,. ~AS~-145f15 -- l:ater I~dect.~or, ';/~/6~ ]4060-] ~]75 " tater 4:/5/6R~5~50 " l~ter In]ect:Lon " " " ".. I! ]/n/vn 1~g5-1525~ l:ater TriSect'or, 2 IPF - Penorforated - o~m For ~qectScm--- ' '~" '" -- " ',~ ..... ~'n/ n 1'~960-15175 l;ater Infect:on ,, ,, ,' 5,/!OJ~, 14710-14930 hater In)ed't Dn ........... ~/10/7~ ]qS35-14695 " lqater Iniect:Lon 4 IPF - " " " " " ~1 ~ ~ ........ 2/10/7 '~1460-14515 ,, "'ater ~' ],1736-1.4740 l;ateT N~ject on ,, ,. ,, ,' ,' " :',~/72 1~'~"? 1479v " '" ' ' '" " " " ""' .... " ~~ 4,o_- ~ ~,,ator Inject: Oil ., .... .'/o//L 1'~ " " F~teI oct:on " " " " " " , , , :~/8/77 ] 4~;56-14o00 " Water In] ect:~on .- . ..... 11 , . ...... ~,/8/72 1,1900-14910 l,'ater Tniect}_on " " " " " " , INITIAL PNODUCTION 'DATE I:fTERVAL _N_E_T_OIL CUT GBDV. I C.P. T,P.. q C~?_O;~:Z ~._C-F GOB I ,REAi?~,%$ , , ...... ...... · , .. -., = ,, L. ".,1 .....I. Bi L,:,"'b ii /N't IF WELL_ ~E~ A~g~~ ~[ ~ ........ ~ tYPE: JU?i 2 - ..u~, [:eries CASING HEAD: S,]:arrer 1'" n,',,, ....... ,,~ GAS CASING HANGER: £]~aF£er l?'' ,~opinaI 9 CASING SPOOL: -1,1- 30fi011 ~,,? }, 10' 50O0f' :? TUBING IIEAD:_ Ca:'ler°n Sin/,,le 4 1/2'; ])C ' o , ,' , TUBING IIANGER:_ '2~min;].l lO'! x 4 1/2". l].q. !P A, 1/0''. = Yuttr~s~...~., *~m.~. _ Far'crop.. .... ' '~ T~T TM - IUB,~,G tlEAB TOP: 10' 1500 t,mneron asscPb]y Sea] txq~c . , ..... 1,1oc,, Tree (sinyle) x'/ r:aster and st. al, valve ,.t.qo t ER VALVES:_ (:aPeron ,1" t.We "1:" · " ' CllE!STM:\S 'I'RI,:E TOP C()NN.:__~i_I/_2~" "R" Seal at top of 9 5/8" stub leal.ed. Sealed Tested to' lb0() psi. Ptn'pod in throuf;}t 2" outlet 5~,. sup-veld ]2"-900 cr,.,.~5~? ]mad. · . JOB NO REPORT and P~N of SUB-SURFACE SURVEY UNION OIL COMPANY T.B.U. G-9 COOK INLET, ALASKA RECEIVED DIVISION OF MINES & M, INERAL$ ANCHORAGE JULY, ]968 DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA DRILLING CONTROL CORP. s.££T NO._ flURVEY DATA SHEET COMPANY Union Oil Company,. DATE....ghly 1968 ~Oa NO. WELL_ T.B.U.S. Gra~g _~9 _ FIELD, ~ ~et COUNTY STATE ~ ~TANG~R C~~A~ ~ASU~ DRI~ ~DE~A~ON DRI~ VER~CAL CO~E D~ON RE~~ DE~ ANG~ DEP~ NO~ ~ SOU~ EAST ~T ' 15 ~95 ~o ~ 395 00 47 N 72° E 1~ ] ~ 4~ 4° ~5, 467 80 5 41 FAST ~15 ~ 521 7° 30' 520 35 6 92 S 88° E ' 09 12 78 552 9° ~5' 550 95 4 98 N 89~ E 0 00 17 76 583 ]3o 00' 581 38 5 92 N 88° F 21 23 7~6 i4° ~C' 700 78 29 75 S 88° F ~3 g~6 lg° ~' 971 93 55 62 S 84° E ~ ~ 6 ~4 !0~ 72 9q~ ?]o 0~' 968 0~ 36 92 N 88° E ~ 5 35 145 ~2 }0~3 22° 00' 1055 25 35 21 N 80° E 76 ]8~ 29 : , 1i~6 23° 00' I]13 24 24 62 N 73© E 7 96 ~ 203 ~3 I-3~3 27° 30' 1305 72 100 19 N 72° F 38 92 299 !2 ]676 37© 00' 1555 6~ 188 36 N 70° E 103 34 476 12 ~ ' ]86~I 43° 00' 1693 18 128 22 N 72° E 142 96 598 07 !95~ 45° 45' 1758 77 67 33 N 71© E 164 88 661 73 2108 49° 30' 1856 18 114 06 N 71° E 202 02 769 57 2141 50° 30' 1877 i7 25 !46 N 72° E 209 89 793 79 =~95 37© 00 2015 50 213 03 N 77° E 257 82 1001 37 2586 S5© 45' 2122 99 157 88 N 77° E 293 34 1155 21 2907 54° 30' 2251 32 179 92 N 76° E 336 86 1329 79 3101 53° 00' 2428:25 234 79 N 78° E 385 67 1559 44 3213 53° ~0' 2495 65 89 44 N 78° E 404 26 1646 92 ~ 3494 53° 30' 2662 79 225 90 N 78~ E 451 22 1867 87 3870 54© 00' 2883 80 304 18 N 79° E 509 26 2166 45 4215 53© 30' 3089 Ol 277 35 N 81° E 552 64 2440 39 DRILLING CONTROL CORP. sS££T NO. flURVEY DATA COMPANY. U~i~ Oil CO[r~V DATE L'J~]y ]96~ AOB NO. WELL_~;B.[T.~. Cra_a_V1]mc #9 FIELD ~DOk //lle% COUNTY STATE TRUE DEVIATION DRIFT RECTANGULAR COOED]NATES MEASURED DR]FT VERTICALJ REMARKS DEPTH ANGLE COUBSE DIRECTION DEPTH NORTH SOUTH EAST WEST 4bS6 53° 15~ 3310 98 297 28 N 79° E 609 36 2732 20 $049 5~o ~0, 3605 49 357 25 N 80° E 671 38 3084 02 5173 49° 3~' 3686 02 94 29 N 83~ E 682 87 3177 60 56~1 4R° 00, 3999 16 347 77 N 83° E 725 26 3522 76 6019 46° 00' 4261 76 271 90 N 87° E 739 48 3794 28 6420 47° 00~ 4535 23 293 29 N 89° E 744 61 4087 51 6469 45° 00' 4569 89 34 65 N 84© E 748 23 4121 97 6532 44° 00' 4615 21 43 76 N 81° E 755 07 4165 19 6723 4~° 00' 4752 60 132 169 N 82° E 773 54 4296 59 6911 47° O0' 4880 82 137 50 N 84© E 787 91 4433 33 7098 52° 00' 4995 96 147 136 N 87° E 795 62 4580 48 7186 ~0o 00, 5052 53 67 41 N 7~° E 809 63 4646 41 ~ 7218 20~ 45' 5072 78 24 78 N 77© E 815 21 4670 56 7405 5~o 00' 5190 46 145 32 N 80~ E 840 44 4813 67 7520 50° 00? 5264 38 88 09 N 81° E 854 22 4900 68 7821 51° 00' 5453 80 233 91 N 81° E 890 80 5131 71 ?944 ~l© 00, 5531 20 95 58 N 82° E 904 10 5226 36 7983 50° 15' 5556 14 29 98 N 79° E 909 82 5255!79 ~017 49° 45' 5578 i1 25 95 N 78° E 915 15 5280!88 8221 4S° 30' 5713 28 152 80 N 81° E 939 05 5431 80 8474 47° 45' 5883 40 187 27 N 84° E 958 62 5618 04 8753 55° 45' 6040 42 230 S2 N 86° E 974 72 5848 11 ~935 53° 45' 6148 04 146 76 N 88© E 979 84 5994 78 9053 53° 15' 6218 64 94 55 N 88° E 983 14 6089 27 9]R2 52° 30' 6297 18 102 35 N 88° E 986 71 6191 56 i DRILLING CONTROL CORP. a. EET no. 3 SURVEY DATA SHEET COMPANY Union O~1 Cc~o._~nv DATE ,~_~!~/ !968 JOB NO. WELL F.~.U.S. qra-.line ~9 FIELD, ~ ~let COUNTY, STATE ~.ska , . ~UE ~T~GU~R C~~A~ ~ASUR~ DR~ DEVIA~ON DRI~ VER~CAL REMA~ DE~ ANGLE COUPE D~~ON DEP~ NO~ SOU~ EAST ~T 0424 ',~.~ 30~ 6447 ~3 189 39 N ~9© E 990 02 g380 9~46 ~1© 00' 6524 60 94 81 S ~9° E 988 36 6475 70 9639 ~]_~ 1~, 6582 fil 72 53 ~ST 988: 36 6.~4F~ 2 97b~ ~1~ 15~ 6659 17 95 15 ~ 988 36 6643 39~ ~2© 0{%' 6786 62 163 12 S 89© E 985' 51 6~06 47 i0,24~ 31~ 4~' 6960 59 220 67 S 84° E 962 45 7025 93 20,374 :%5° 00~ 7049 16 101 88 S 88© E 958 89 7127 75 lO,~,~ 4g© 20 7121 38 81 64 S 89© E 957 46 7209 ] 6.~] ~go ~ 7212136 103 75 S 88© E 953 84 7313 10,703 4~~ 15' 7259~36 54 54 S ~8© E 951 94 7367~57 }~ ~i7 ~1~ ~-' 7333 78 86 37 N 84~ E 960 97 ~ 4~ ~,~2 ~o . ,~ ~' 7417 97 118 :04 ~ 85© g 971 26 7F71 :1,;,~1 5~° Q0~ 7~95 71 115 23 ~ 84© ~ 9R3 30 7~85 ii,z~,2 :,/~ 30' 7549 9~ 85 18 ~ 85© E 990 73 7770 51_ ]1,2/{9 <6~ {~0' 7598 63 72 13 N 78© E ]005 73 7~41 iI,~]66 ~o 15' 7691 77 150 52 N 78© E 1037 02 7988 28 11,6U4 ~%7° 00' 7766 92 ~15 74 N 80° E 1057 11 8102 26 11,7~j4 -3~ 00, 7863 21 127 78 N 82° E 1074 90 8228 80 ii, ~, 30 7992 2~ 174 45 N 85° E 1090 !1 8402 59 :2,2]3 %l~ 00 ~1~8 z8 180 29 N 87° E 1099 54 8582 63 12,q]0 51~ 00' 8325 18 230 80 S 89© E 1095 50 8813 39 I~,~5~ 46© 00' 8961 3R 244 56 S 870 E 1082 71 9057 60 13,197 47© 30' 8795 8i 255 84 S 82° E 1047 10 9310 96 13,354 46© 30' ~903 ~9 113 89 S ~1° E 1029 29 9~23 45 13,564 46© 00~ 9049 78 151 05 S 78© E 997 89 9571 19 DRILLING CONTROL CORP. s.,.£'r no.. 4 8UR¥EY DA?A I~HEE? COMPANY UDion Oil Cc~sny DATE July 1968 Jos NO. WELL~.U.S, '~rayl~ ~9 FIELD ~ T~]D~_ COUNTY. STATE A]~c~ ~ ~T~G~R C~~A~ ~ASU~ DRI~ DEVIA~ON DRI~ DE~ ANG~ VER~CAL COUPE D~ON RE~~ DE~ NO~ SOU~ EAST ~T 13,785 42° 45~ 9212 06 150 01 S 74° E 956 ~5 9715 39 ~ 13,916 41° 00' 9310 93 85 95 S 73° E 931 ~2 9797 58 14,002 40° 15' 9376 57 55 57 S 73° E 915 17 9850 72 14,117 4[° 15' 9463 03 75 82 S 71© E 890 48 9922 41 < 1~,256 ~0© 45' 9568 34 90 74 S 70° E 859 ~5 10,007 68 14,37~ 40© 45' 9656 22 72 72 S 68© E 831 ]9 10,007 89 14,500 39o 45' 9754 63 81 84 S 65© E 796 50 10,152 06 ~ 14,744 ~0© 15' 9940 85 157 65 S 63° E 724 33 10,292 53 15,000 42° 30' 10,129 60 172 95 S 61© E 641 ]8 10,443 79 ~ 15,261 42° 45' 10,321 25 177 17 S 57° E 544 ~9 10,592 38 ]5,330 42° ~0~ 1~,372 12 46 62 S 57° E 519 ~0 10,631 48 ~ ~S~ '.0,636 '30' N 87© 12' E DRILLING CONTROL CORP. SHEET NO.., 1 8VRV:gY DATA 8trg~-T SIDETRACK HOLE #1 COMPANY Union Oil C~y maw~ ~ly 1968 ..... JOB NO. WELL ~~_G~!~q g9 FIELD. ~k ~let COUNTY. 8TATE~~Ska ~ ~T~G~R C~~A~ ~ASU~ DRI~ D~A~ON D~ DE~ ANGLE VER~CAL COUPE D~ON REMA~ DEP~ NO~ SOU~ EAST ~T V9~4 5531 20 904 10 5226 36 809~ 50° 30' 5627 ii 115 32 N 84° E 916 15 5341 05 82!5 50° 00~ 5718 54 92 69 N 84° E 925 84 5433 23 PRG~C~D DRILLING CONTROL CORP. S.££T no. I , ..... I~UIkVEY DATA SHEET SIDETRACK HOLE #2 COMPANY Ur~_'on O.i_l C(~T?~y DATE July ]968 JOB NO. wE-t T.B.U.S. ~ravl~n.q #9 ~IE-D. Cook Inlet COUNT¥~ STATE. Alaska · TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIA~ON DRIFT VER1~CAL REMARKS DEPTH ANGLE COUBS~. D~T~ON DEPTH NORTH SOUTH EAST WEST 12,852 8826 20 908 38 8826 98 13,001 40° 30' 8939 50 96 76 S ~1e F 893 25 8922 55 ]3,105 41° 00' 9017 99 68 23 S 79° E 880 23 8989 29 13,2q0 4]° 00' 9127 42 95 13 S 78° E 860 45 9082 34 ~ROJECTED , ,, DRILLING CONTROL CORP. 8.EET no. 1, SURVEY D&T& 8H'EET SIDETRACK HOLE #3 COMPANY.- Union Oil qa~,,any DATE JUly 1968 jos NO. WELL~,B.U.S. C~aylinc #9 FIELD. Cook Inlet ........ COUNTY STATE, Alaska , TRUE BECTANGULAfl COORDINATES MEASUP~/) DR~T DEVIAtiON DRIFT VERTICAL REMARKS DEPTH ANGLE COUBSE D~ON DEPTH NORTH SOUTH EAST WEST ~-~ - ~'*' 10,631 7212 36 953 84 7313 06 10,744 49° 45' 7285 37 86 24 S 87° E 949 33 7399 18 10,871 51° 30' 7364 43 99 39 S 87° E 944 13 7498 43 10,959 50° 45' 7420 11 68 15 S 87° E 940 57 7566 48 11,202 45° 15, 7591 18 172 58 N 86° E 952 62 7738 65 11,376 48o 15' 7707 05 129 82 S 89° E 950 35 7868 44 11,419 45° 00' 7737 46 30 41 N 87° E 951!94 7898 81 11,508 43© 15' 7802 28 60 98 N 88° E 954 07 7959 75 11,641 42° 15' 7900 73 89 43 N 86° E 960 31 8048 97 11,802 41° 00' 8022 24 105 63 N 88° E 964 00 8154 54 12.135 40° 00' 8277 32 214 05 S 88° E 956 53 83~8 46 12,330 4~° 00' 8426 69 125 35 S 84° E 943 43 8493 12 12,386 40° 15' 8469 43 36 18 S 87° E q41 54 8529 25 12,579 39° 45' 8617 81 123 40 S 86° E 932 93 8652 35 %~, 12,722 40° 00, 8727 35 91 92 S 82° E 920 13 8743 38 12,852 40° 30' 8826 20 84 42 S 82° E 908 38 8826 98 12,958 40° 30' 8906 80 68 84 S 81° E 897 61 8894 ~7 .13,061 42° 30' 8982 74 69 59 $ 89° E 896 39 8964 55 13,182 44° 00' 9069 78 84 06 N 89° E 897 86 904~ 59 ]3,266 44° 45' 9129 44 59 14 EAST 897 86 9]07 73 ~ PRO3ECTED - DRILLING CONTROL CORP. 8H£ET no., 1 8URVEY DATA SHEET S~DETRACK HOLE #4 COMPANY ~_~T~©n Oil Ccm~any , DATE .~1]V 196R JOB NO ..... WELL i'.B.U.S. Graylinq .~9 FIELD Cook Inlet COUNTY 8TATE__~_~_~ska ..... . TRUE RECTANGULAR COORD~ATES MEASURED DRIFT DEV]AT~ON DR/FT DEPTH ANGLE VEfllqCAL COURSE D~T~ON REMARKS %., DEPTH NORTH SOUTH EAST WEST 11,101 7495 71 983 30 7685 65 11,246 58° 00' 7572 55 122 96 N 86Q E 991 88 7808 3] 11,416 58° 00' 7662 63 144 16 N 86Q E 1001 94 7952 12 11,558 61° 0O' 7731 47 124 19 N 87° E 1008 44 8076 14 11,740 56° 00' 7833 24 150 88 EAST 1008 44 8227 02 PROJECTED · Form No P--4 1%EV 9-30-6~ { STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ~MONTrHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DEPLICATE OIL ~'~ GA8 ~ WELL ~ WELL I.--~ OTHER 2 NJ~E OF OP~TOH Union Oil Company of California 3 AI~DRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage. Alaska 99504':. 4 DCATION OF WTM N1886, W1382' from SE corner Section 29, T9N, R13W, SM AP1 NL~iE~CAL CODE 50-133-20098 6 LF~4SE DESiGNA/ION A\-D SE1RIAL ADL-18730 IF INDI ~.N, %LOTTEE OR TRIBE NA.%IE 8 LLNIT,F.~R-M OR LEASE N'A_ME Tr~dinl Ray Unit 9 WELL XO State C-9 (32-27) 10 FIELD A-\'D POOL OR WILDCAT McArthur River - H-mlock i1 SEC, T, R, M i BOT'FO.M HOLE OBJECTIVEi Section 27~ T9N~ R13W, SM 12 P~FdVIIT NO 68-16 13 REPORT TOTAL DEPTH AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING A_N-D CL--WIENTING JOBS INCLUDING DEPTH SET ~ VOLI3/V~ USED, PFflKFORATIONS, TESTS ~hrD RESULTS FISHING JOt~ JUTqK IN HOLE ~D SIDE-/qKACKED HOLE AND A~Y OTHER SIGNIFICANT CI-L~NGES IN HOL~ CONDITIONS TRADING BAY UNIT STATE C-9 (32-27)~,, ,JULY 1968 Redrilled 8-1/2" hole to 11740'. Stuck bit @ 11725'., Ran free point, found pipe stuck @ top of bottom stabilizer. Backed off @ 11693', ia~z ~t~ stabilizer and one monel in hole. Ri with wash pipe. Stuck wash pipe above fish. Attempted to release from safety joint @ 11551'. Ran Dialog back off shot and backed off @ 11548'. Top of fish @ 11550'. RIM with open end drill pipe, plugged 11550-11165 w/150 sx CFR-2 w/12l sand. Tagged plug @ 11168', polished plug to 11202". Redrilled to 13260' and drilled to 15330'Tb. Ran Schlumberger DIL, unable to work past 11500'. Ran 120 Jts 7" 29# N-80 buttress casing. Hung with shoe @ 15328', float collar @ 15281'; liner hanger @ 10287'. Cemented thru shoe with 300 sx class "G" with CFR-2. Checked top of cement @ 15270' Ran Schlumberger GRN and CBL. Perforated 4 - 1/2" hpf 14660-14690' for DST #1. Recovered 13760' salt water, no oil. Squeezed perfs 14660-14690' w/82 sx class "G" cement. Now testing liner lap. RECE[VEO DIVISION OF MINF. S & MINEP, b~L,~ ANCHORAGE 14 I hereby certtiy true and correct /'~'// /Ii11111 Dist. Drilling Superintendent NOTE--Repon on th~orm ~s reqm~ed ~o~ each ca~e~dar m0flth, re§a~dless of the status of 0peratm~s, an0 must be filed m d,p[kate w~th the D,ws~on of M~nes/& Minerals by the 15th of the succeed,ng month, unless otherw,se directed / Form No P---4 REV 9-30-6; STATE OF ALASKA O]L AND GAS CONSERVATION COMMII-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL ~'~ GAS ~ WELL ~ WELL ~ OTHER N;uME OF OP~XD.a~TOR SUBMIT IAT DIgPLICATE Union Oil Company of California 3 ADI~I~_$ OF 507 W. Northern Lights Blvd., i-choraee. Alask~ 90~n2 4 LOCATION OF WI~.T.T. - - N1886, W1382' from SE Corner Section 29, TDN, R13W, SM 13 RF. PORT TOTAL D~IPT~{ AT F2~D OF MON'i'ii, CI-~GES IN HOLE SI~E, CASING AiNTD CE2VIENTSNG ADL-18730 7 IF II%-DI -~..~, %ixD 1 ~ ~ O~ TRIBE 8 I~-'~,'IT,F-~tL%{ OR LEASE N.A_'klE Trading Bay Unit 9 %VELJ~ NO State C-9 (32-27) 10 FIET.T~ AND POOL OR WILDCAT McArthur River - Ho-lock 11 SF_~, T, H, M I BOTTOM HOLE O~FVE~ Section 27, TDN~ R13W, SM 12 PI~RiVIIT NO 68-...ia~ ~'- (. JOBS INCLUDING DEPTH I SET ~ VOLU~ USED, PEP. FORATIONS, ~-ESTS A/WT) RESULTS, FISHING JO~.S, JI3/~K LN HOLE AND SIDE-T~CKED HOLE ~ ~J~Y O~{F2{ SIGNIFIC~NT C~G]~ IN HOL~ CONDITIONS _TRAI)_ I,NG BAY UNIT STATE G-9 (32-27),,, JU~E 196.° Drilled 8-1/2" directional hole to 13,250' Stuck drill pipe while drilling, free circulation. Ran Free Point Locator, Backed off dp @ 13,159' (91' of fish in hole). RI w/jars and screwed into fish. Jarred. No improvement. Backed off fish @ 13,159'. RI w/ open end drill pipe ta 13,081'. Plugged 8-1/2" open hole above fish w/130 Sx class "G" cement w/12I Sand. Estimated top cement 12,781'. WOC. Located top @'12,780'. Trimmed plug to 12,898'. RI w/dynadrill and sidetracked fish. Redrilled 12,898-13,250,' Drilled 13,250-13,266' Stukk drill pipe coming out of hole w/bit @ 12,418'. Ran' Free Point Locator, ba~ked off,:.dp @ 11,386'. RI w/Jars, screwed into fish,' jarred, stuck fishing assembly. Ran Free Point and backed off @ 10,950'. RI w/wash pipe. Washed over fish to 11,040' Wash pipe stuck while attempting to back off. Backed off at top of wash pipe @ 10,900'' (fish 10,900-12,418'). RI w/o~en end drill pipe . Plugged 8-1/2" hole 10,900-10,512'' w/150 sx cement w/151 sand. WOC. Found top of cmt @ 10,699', trimmed to 10,703'.' RI w/dynadrill and sidetracked fish. Nov redrilling. Redrilled 8-1/2" hole 10,703-10,827'. DiViSION OF: ~INES & ANCHORAGE. , , 14 I hereby eert[fy/~_l~_ thel/old~[~4l~s true ~ ~ ' " ]~ -ll~ District Drilling Su erintendent NOTE--Report on th operations, and must ~ fded m dupli~te w~th the Dw~s~on of Mines & Minerals by the 15th of the succeeding month, unless othe~se directed Form No P---4 I~LEV 9-30-6'; STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATK MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W~LL ~ WELL N~E OF OPhiR Un,on O~1 Compan7 of California ADDR~S OF OPhiR 507 ~. Norghern L~ghts Blvd., ~chorage~ Alaska 99503 ~CA~ON O~ W~ N1886, W1382' from SE corner Section 29, T9N, R13W, SM APl NL-AIER/CAL CODE 50-133-20098 6 LEASE DESIGNATION AND SE%RIAL NO ADL-18730 7 IF I.~DI-kN, %.LOl I kE OR TRIBE L~IT,F.~::tM OR LEASE N.~ME Trading Bay Unit WELL NO State G-9 (32-27) 10 .t,-~,:i.l'~ AND POOL OR WILDCAT McA~ghur River - HemLock 11 SEC , T, R 1%{ (BO/'TOM HOLE OBJECTIVE~ Section 27, T9N, R13W, SM 13 REPORT TOTAL DEPTH AT END OF MONTH, CI-LA-NGES IN HOLE SI~E, CASING AND CEi%IF_2qTING JOBS INCLUDING DEPTH SET AND VOLLrNfE$ USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS, JUNK IN HOLE AND SIDE-/q:LACKED HOLE A-N'D A.NY OTHER SIGNIFICANT CHAN'C_,ES IN HOL~ CONDITIONS TRADING BAY UNIT STATE G-9 (3,2-27), MAY 1968 Drilled 12-1/4" directional hole to 8215', lost 500# pump pressure. Pulled out, found bit, 2 stabilizers, 10' lead collar left in hole. Top of fish @ 8196'. Failed to recover fish. Plugged 12-1/4" hole w/300 sx cmt w/15% sand. Found top of plug @ 7893' Trimmed to 7944' Redrilled 12-1/4" hole 7944-8215' · · ' drilled to 10,593'. Ran Schlumberger D~L, FDC, HRD logs· Ran 256 joints 9-5/8" casing and hung w/shoe @/10056' and DV @ 4604'. Cemented thru shoe w/1200 sx CFR-2 and 1000 sx neat cement· Opened DV and cemented w/ 1000 sx CFR-2 and 1000 sx neat cement· Drilled 8-1/2" directional hole to 10,629'. Now drilling. RECEIVED JUN 10 1968 DIVISION OF MINES & MINI/RAtS ANCHORAGE 14 I hereby cert~/y that re o e ~i co ~~~ District Drilling Superintendent Ma__y .31, 1968' SIGNED ~ ~r ~ ~;-- [ TITLE ~ ~ ~ DA'rE ~ _ __ n. ~. ~=.v/ NOT£--Report on th~$ forum reqm~ed for each calendar mo~th, ~ega~dle~s ot the status ot o~erat,on% an0 taus% be tded m duphtate w~th the Dw~$~ou of Mines ~ M~erals by the 15th o{ the succeedm9 mo~th, uuleas o~he~se d~ected (( Fo~ No P--4 STATE Of: ALASKA SUBMrr I~ DEPLICA,T~ REV 9-30-6'; O~L AND GAS CONSERVATION COIWVUTYEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2 NAME OF OPEI~ATOR Union 0il Company of California 3 ADDI~ESS OF OPEI:~TOR 507 W. Northern Lights Blvd.. Anchorage. Ala.~k. qqS03 4 ~OCA~ON OF W'-'-'- -- ' N1886, W1382 from SE corner Section 29, T9N, R13W, SM AP1 NL~IE~CAL CODE 50-133-20098 6 LEASE DESiGNAilON A\-D SERIAL NC) ADL-18730 IF INDI ~N, %I.X)TTEE OR TRIBE 8 U'NIT,F.~:C%{ OR LEASE NA, AIE Trading Bay Unit 9 %VELL State G-9 (32-27) 10 FIELD A_N'D POOL OR WILDCAT McArthur River - Hemlock 11 SEC , T , R , MI BO~TO,M HOLE OBJ'EC'rIVE ~ Section 27, T9N, R13W, SM 13 REPORT TOTAL DEPTH AT END OF MONTH, CH.A.NGES IN HOLE SIZE, CASING A/XT'D CEMENTING JOBS INCLUDING DEPTH SET ~ VOLI. IM'ES USED, PE~{FO~TIONS, TESTS ~%rD RESULTS FISHING JOBS, JUNK IN HOLE ~ND SIDE-T1R_~CKED HOLE A3CD ~I%IY OTIiER SIGNIFICANT C~GES rN HOL~ CNDI%rDITIONS TRADING BAY UNIT STATE G-9 (32-27), APRIL 1968 SPUDDED 4:00 PM 4/22/68 Drilled 15" hole to 640' Opened 15" hole to 22" to 640'. Ran and cemented 16" 75~ J-55 Buttress casing @ 623' w/1300 sacks. Drilled to 3101'. Opened hole to 18" to 3079'. Ran and cemented 13-3/8" 61# J-55 Buttress casing @ 3044' w/2300 sacks. Drilled to 3184'. Now drilling. RECEIVED MAY 7 1968 ~NI$10N OF MINES & ///[7~ //l/YJl,I Dist. Drilling Superintendent_ SmWSD ~ ~ ~ ~"~--'x =TL~ __. mA'~ 5/2/68 NOl£--Report on th~$ f/tm ~s reqmred for each calendar month, regardless of the ~tatus o~ operauon% and mu~t be filed m duplicate w~th the Dwmon of M,ne$ /t~ Mmerah by the 15th of the succeed,n§ month, unles~ otherw,~e d~rected Union O~1 Cor,'n, panv .,a,lf-,~ 2805 Denall Streot, 'i-r,lephnr'lr, i907) · April 24, 1968 WEST FORELAND AREA State of Alaska ADL 18730, I~/Fore-5 Do,q y ~ I T ' In accordance with the provisions of the captioned Oil and f]'zs I.ease, Trading Bay Unit State G-9 (32-27) drilling the (;ravlzng Platform located on State Loase ADL 17594 was spudded on Apr~l 22, 1968. The proposed bottom hole locat:~)n o£ sa~d well ~s approximately 1990'S and oF the NI~ corner of_ SectSon 27, T9N, R13W, S.M. on said Very truly yours, Robert T. Anderson FoFm P---3 (~ REV. 9-304~ Submit "Inlentions" in Tripli~ate & "Sul~equent Reports" in Dupllcat~ STATE' OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (De not use th,-~ form for proposals to drill or to deepen or plug back to a chfflerent reservoir Us~ "APPLICATION FOR PEI~IIT~" for such proposals ) I OIL ~-~ GAB [~] WELL WELL OTHER 2 NAME OF OPERATOR Hn4nn Oil CnmnAnv o~ Cnlt~or~ia 3 ADDRESS OF OPERATOR 507 W. Northern Lights Blvdo, Anchorase, Alaska 4 LOCATION OF WELL Atsurfa~ N1886, W1382 from SE corner Section 29, TgN, R13~, SH 13 ELEVATIONS (Show whether DF, RT. GR. etc 99'RI ~bove HSL 14 5 AP1 ~CAL CODE 50-133-20098 I-~-~s~Sl~. D]~":~,IGNATION AND SERIAL NO ~L 18730 ~ ~I~, ~~ OR ~BE N~ 8 U~, F~ OR ~E N~E ~ading Bay Unit 9. ~NO S~ate ~9 (32-27) ' m ~.n '~ ~h. oa wm~ ~rthur River Field - H~lock 11 ~,T,R.,M, (~M O~VE) Section 27, T9N, R13~, SM Check Appropriate i~ox To I,n~i~te Kat'ure of N~fice, Re ~rt, or Ol'h~ Data NOTICE OF INTmNTION TO: TEST WATER SHUT-OFF It PULL OR ALTER CASINO FRACTLRE TREAT -- MULTIPLE COMPI,ETE SHOOT OR ACIDIZE -- ABANDON* REPAIR WELL CHANGE PLANS lO,her) LOCATION CHANGe- I~UBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEKT* (Other) NOTE' Report results of multiple completion on Well .repletion or Recompletlon Report and Log form.) 15 DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an~ proposed work. ,, CORRECTED LOCATION At Surface: 1886'N and 1382'~ from the SE corner Sec 29, T~, R13~, SM (Conductor il, Leg 2) DIVISION OF MINES & MII"~RA~ ANCHORAGE 16 I hereby eer, tlf}r that the fore~oin~ is ~ue and correct I'l o AJ · Dist· Drilling Superintendent TITLE DATE /,/22/68 APPROVED BY ti ,.~ ~' J z'''' CONDITION~ OF APPROVAL, IF TITLE / / See {nstructions On Reverse Side For~n P--3 ( ~ 9-30-67 STAT~ OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" m Duphcate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use th~ form for proposals to drill or to deepen or plug back to a difflerent reservoir Use "APPLICATION FOR PERMIT--" for such proposals ) OIL ~-] OAS ['~ WELL WELL OTHER NAME OF OPERATOR Union 0il Company' of CalLfornia ^DD~'SS OF OPm~.TOR 507 W. Northemm Lights Blvd,,. Anchorage, Alaska 99503 ( AP1 NLr~CAL CODE 50-133-20098 LEASE DESIGNATION AND SERIAL NO ADL 18730 ? IF ITTDIA-W, ALLO~ OR TRIBE NAME 8 UNIT, FAf{NJ OR I~E N~dVtE Trading Bay Unit 9. V~L NO State G-9 (32-27) 4 LOCATION OF w~ Ats~aee Conductor #41, Leg ~J2, 1886'N & 1382'W from SE corner Section 29, T9N, R13W, SM. 13 ELEVATIONS (Show whether DF, RT, OR, etc 99' - RT to MSL Check Appropriate Box To Indi'cate Niature of N~ofice, Re 10 F~,~ ~ POOL, OR WILDCAT McArthur River - Hemlock 11 SEC , T , R, M , (BOTTOM HOLE OBJECTIVE) Sec. 27, T9N, R13W, SM. 12 PER1VIIT NO 68-16 ~, or Other Da~a NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTUR~ TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDONs CHANGE PLANS EUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL [~.J FRACTURE TREATMENT ALTERXNO CASINO SHOOTING OR ACXDIZINO ABANDONMElqT® (Other) (OtherCOnvert for wtr injector test (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15 D~:SCRIBE I'ROPOSED OR COMPLETED OPERAT~O.~S (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, It is proposed to conduct a water injection test, Trading Bay Unit State G-9 (32-27), Hemlock Zone, subject to decisions rendered as a result of Conservation Order #71. Proposed Procedure: Estimated Startin8 Date: 1. Set "Q" plug in tbg tail @ 14,648' & open sleeve @ 14,574' (between pkrs). 2. Commence injection test into Hemlock Oil Zone 14,460'-14,515' & 14,535'- 14,625'. 3. Pull "Q" nipple & close sleeve @ 14,574'. 4. Commence injection test into Hemlock Water Aquafer 14,960'-15,175' & 15,195'-15,250'. 5. Open sleeve @ 14,574' & resume injection ~nto both Hemlock 0il & W~r_ ;ntervals. July 1, 1969 MCE~ APR 10 OIL AND GAS 16 I hereby c th ore$oing Is true and correct SIGNED Iff~II)]JJll/ Talle¥) TrrLE Dist. Drl~. Su~;. ~!11/ i ~' "7 -' (This space for Si APPROVED BY CONDITIONS Ol APPROVAL, IF TRM - OKG ~ KLV ._/_k_~. HWI( ~ See l~nstrucfions On Reverse Side FILE D.~ 4/~/69 ~pptove~ Returned FORM SA- I B 125 5M 8/67 MEMORANDUM TO: J-' FROM: State of Alaska DATE : SUBJECT= FORM SA- I B 125 5M 8/67 MEMORANDUM State of Alaska TO: J-- FROM: DATE : SUBJECT: A~rtl 9, 19~ ~ Oil ~ o! Call~ora~, Hr. Stober~ T. Aude~oou Dtscrie~ 1.and Jtsnager Union Oil Compmry of Cali£~a ~q~, ~1~ 99503 Very truly yours, Thomas It.. Mmr~, Jr. l~etrolmm Sup~rvtoor For~ P--1 REV ~-~0-~ STATE OF ALASKA t SUBMIT IN TRIPL~ (Other instructions~J reverse side) OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 18. TYP~ 0~" WORK DRILL IX] DEEPEN I--1 PLUG BACK I--1 b. TYPgOF WgLL OIL J~} O&~l D 8INGLJ ~] M[LTIPLJ ~ WgLL W~LL OTHER ZON~ ZONE 2 NAME OF OPERATOR Union 0il Company of California 3 ADDRESS O~ OPEI~k~R 2805 Denali Street, Anchorage, Alaska 99501 ~,u,~e ~'N ' W from the SE corner Sec. 29, T9N, R13W, S.M. A~p~o~sedp=~ ~o=~ Top Hemlock' 1980'S and 1980'W of the NE corner Sec. 27, T9N, R13W, S.M. 13 DISTANCE IN MILES AND DIRECT!ON Ff~OM NEAREST TOWN OR POST OFFICE* 23 air miles NW of Kenai, Alaska AP1 50-133-20098 5. 6 LEASJ~ DESIGNATION AND -~ NO ADL 18730 ?. IF INDIAN. ALLO~rEE OR ~ NA~ 8 UNIT, FARM OR LEASE NA-M~ Trading Bay Unit 9 V~ELL NO State G-9 (32-27) il0 ~iiLD AND POOL, OR WILD~AT Hemloc~ McArthur River Field,Pool 11 SEC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec. 27, T9N, R13~, S.M. 14 BOND INFORMATION Statewide TYPE United Pacific Insurance Company B-55372 Surety and/or No 15 DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT 1800 (Also to nearest drag, umt, if any) 18 DISTANCE FROM PROPOSED LOCATION* .... TO NEAREST WELL DaILLmG, COMPLeTeD. OR APPLIED FOR, FT 3500 ' from G- 1 · il8 NO. OF ACRES IN LEASE 5,840 9 PROPOSEI) DEPTH 5,100'MD, 10,270'VD $100,000.00 NO ACRES ASSIGNED TO THiS WELL 160 20 ROTARY OR CABLE TOOLS Rotary 21 ELEVATIONS (Show whether DF, RT, CR, etc ) 22 APPROX DANTE WORK WILL ST.~RT* 99' Rt above MSL April 12, 1968 23. FrROPOSED CASING AND ,~EMEN~['ING PROGRA1V[ SIZE OF HOLE SIZE OF C~SING V~EIGHT PER FOOT GRA]~E t SETTING DEPTH QUANTIT! O~ CEMZN~ 22" 16 75 J-55 600 1200 sacks 18 13-3/8 61 J-SS 3000 1200 " 12~ 9-5/8', 40-43.5-47 N & 'P 12000' 1500 ,,r .,~.~'~//2bf' ~9~ 8% 7 .... 29 N-'8'0"',il~00"' 15100 '4'00 "' Cement 16" casing at 600'. Install 20" Hydril. Drill 15" directional hole to 3000'; open to 18". Cement 13-3/8" casing at 3000'. Install B.O.P.E. Drill 12¼" directional hole to 12,000'. Run electric logs. Cement 9-5/8" casing. Drill 8½" directional hole to 15,100'. Run electric logs. Cement 7" liner and complete in Hemlock Zone for production, Bottom Hole location: Approximately 1900' S and 1200' W of the NE corner Section 27, T9N, R13W, S.M. IN ABOVE SPACE DESCRIBE PROPOSED PROGRA1Vi If proposal is to deepen or plug back, g~ve data on present productive zorte and proposed new productive zolle. If proposal ~s to drill or deepen dlrect.onally, g~ve pertinent data on subsurface locatwns and measured and true vertical depths. G~ve blo~-out preventer program 24 I hereby certtfy that j~he Fgregomg is True an~Correct ! NED DATE J Apri 1 4, ~vv ~, ' , (Th~s space for State offxce use) CONDITIONS OF APPROVAL, IF ANY 1968 District Land Manager j SAMPLES AND CORE CHIPS l~U~ [] YES ~ NO DIRECTIONAL SURVEY REQUTH2gD ~ YES [] NO OTHER RE~U~ A P I NUMERICAL CODE DATE r (,, G-lO (14-29) G-5 0 ( / (34 -29) UNION- MARATHON ADL- 17594 D-I p ( $4 - 22) / / / ! ~ (~4-2~) 2?. ...-- .-..- ( 32- 2_7) 'I-lVFD 15~ I00' TVD lOs 270' b "' '-0 (34-2-a) '~- G-O TgN- RI3W UNION - MAR A TH 0 I', ADL 18730 D-2 ~ ..u (22--5) /V JNION OIL COMPANY OF CAL'IFORNIA ALASKA DISTRICT WELL LOCATION MAP UNION OIL CO. OPERATOR UNION TRADING BAY STATE UNIT G-9 ( 32 - 27 ) DATE APRIL 1968 , 0 I000' 2-000' SCALE I": 2000 I /"l I I I i i I l~
