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Home My WebLink About175-016CAUTION: 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-22 (PTD 1750160) - AIO 5.030 Compliance Temperature Survey - April 2022 Date:Wednesday, May 25, 2022 9:43:35 AM Attachments:G-22 Temperature Survey Overlay Plot - 2022_04_22.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-22 (PTD 1750160) - AIO 5.030 Compliance Temperature Survey - April 2022 Mr Wallace, Per AIO 5.030 (Administrative Approval), Trading Bay Unit G-22 (PTD 1750160) requires a biennial temperature survey. The 2022 survey was completed on 4/22/2022. 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:Grayling Date:04/22/2022HilcorpG-22 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Temperature (Deg. F)Depth (feet)Pressure (psia) 22 Pressure Perfs RKB 20 Pressure 26" 20"13-3/8"9-5/8"TBG 18 Pressure 22 Temperature 20 Temperature 18 Temperature Pressure-Temperature Profile 1. RIH Overlay - 2018, 2020, 2022 2. Well Shut-in Report date: 5/19/2022 Wallace, Chris D (CED) From: Holly Tipton <hotipton@hilcorp.com> Sent: Friday, April 3, 2020 2:24 PM To: Wallace, Chris D (CED) Subject: Grayling Compliance Temp Surveys AIC) 5.030 & 5.005 Attachments: G-22 Compliance Temp Survey 2-13-18 vs 2-25-20.xls Hi Chris, A compliance temp survey was recently completed on the Grayling G-22 well (PTD 1750160), per condition #3 of AIO 5.030. The attached temperature survey plot, overlaying G-22 temp surveys on 2/13/18 and 2/25/20, indicates downhole containment of the injection fluids with no significant temperature anomalies. As this well injects produced water, the temperature anomaly of interest would be a heat spike above the perfs indicating a loss of fluids. No such anomalies are visible meaning fluid containment is intact. Also notable is that the two temp surveys run two years apart nearly overlay one another— another good indicator that nothing has changed regarding casing integrity and all injected fluids are still exiting the casing at the perfs. My apologies for the delay in getting this survey to you, the wireline unit had mechanical issues with the encoder and depth file needed to be adjusted. A compliance temp survey was attempted multiple times on the Grayling G-16 well (PTD throughout February and March, as required by AIO 5.005. Wireline was unable to get past 11,427' (packer is at 11,892'), so this well has been shut-in and is no longer injecting. Thank you and please let me know if you have any questions! Holly Tipton Regulatory Tech - CIO Asset Team Hilcorp Alaska, LLC o: (907) 777-8330 1 m: (281) 543-8964 e: hotipton@hilcorp.com 0 Hilcorp I Well: G-22 I Field: Grayling I Date: 02/25/2020 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 Temperature (Deg. F) RIH Pressure -- Perfs RKB __26" 20" 13-3/8" 9-5/8" TBG 18 Press RIH Temperature 18 Temp Report date: 4/9/2020 111 Press u re -Tern peratu re Profile1. RIH Overlay - 2012, 2018, 2020�>.2. Well Shut-in fit ON will 111 oil Elk �a=----- onMill on IIIIIIIIIIIIPAL X111 MM 4 too ' �V _■ BECAME .111 1 1 _s _�� ■ -- �--_ A 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 Temperature (Deg. F) RIH Pressure -- Perfs RKB __26" 20" 13-3/8" 9-5/8" TBG 18 Press RIH Temperature 18 Temp Report date: 4/9/2020 Cannery Loop Unit 04/05/2020 Cannery Loop Tubing hanger, SMB -22 CLU #15 ported, 11 X 4 % DWC susp X 5.250-4 stub acme left hand 16 x 10 % X 7 5/8 X 4 1/2 lift, 4" H BPV, 7" extended neck BHTA, OTIS, 4 1/16 5M X 6.5 Otis quick union top Valve, Swab, CIW-FC, 4 1/16 5M FE, HWO, DD trim Valve, Upper Master CIW-FC, 4 1/16 5M FE, HWO, DD trim Valve, Master, CIW-FC, 4 1/16 5M FE, HWO, DD trim Multibowl Wellhead, SMB - 22, 11 5M top X 10 %Slip on weld bottom, w/ 4- 2 1/16 5M SSO 16" 10%" 7 5/8" 4 %" Cannery Loop Unit 04/05/2020 Tubing hanger, SMB -22 Cannery Loop CLU #15 ported, it X 4'/: DWC susp X 16 x 10 % X 7 5/8 X 4 1/2 5.250-4 stub acme left hand lift, 4" H BPV, 7" extended neck BHTA, OTIS, 4 1/16 5M X 6.5 Otis quick union top Valve, Swab, CIW-FC, 4 1/16 5M FE, HWO, DD trim Valve, Upper Master CIW-FC, 4 1/16 5M FE, HWO, DD trim Valve, Master, CIW-FC, 4 1/16 5M FE, HWO, DD trim Multibowl Wellhead, SMB - 22, 11 5M top X 10 % Slip on weld bottom, w/ 4- 2 1/16 5M SSO 16" 10%" 7 5/8" 4 %" Cannery Loop Unit 04/05/2020 Cannery Loop Tubing hanger, SMB -22 CLU #15 ported, 11 X 4 % DWC cusp X 16 x 10 %X 7 5/8 X 4 1/2 5.250-4 stub acme left hand lift, 4" H BPV, 7" extended neck BHTA, OTIS, 4 1/16 5M X 6.5 Otis quick union top Valve, Swab, CIW-FC, 4 1/16 5M FE, HWO, DD trim Valve, Upper Master CIW-FC, 4 1/16 5M FE, HWO, DD trim Valve, Master, CIW-FC, 4 1/16 5M FE, HWO, DD trim Multibowl Wellhead, SMB - 22, 11 5M top X 10 % Slip on weld bottom, w/ 4- 2 1/16 5M SSO 16" 10%11 7 5/8" 4 %" • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, February 26, 2018 11:01 AM To: 'Larry Greenstein' Subject: RE: Request for RTI for G-22 PTD# 1750160 Larry, As discussed on the phone,you are approved for an additional 30 days injection for diagnostics and monitoring. If all looks good after this we can continue with injection operations while Hilcorp applies(hardcopy required)for an Administrative Approval for continued injection operations. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Monday, February 26, 2018 10:41 AM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: Request for RTI for G-22 PTD#1750160 �A � r ` Hi Chris Hilcorp is requesting AOGCC to allow the Grayling G-22 to return to continuous EOR service per Rule 9 of AIO 5.000. As noted below and the attached TIO plot, the well appeared to develop tbg x IA communication late last month. This was confirmed, after approval to perform diagnostic testing and injection, by bleeding down the IA during injection and monitoring the resultant climb in IA pressure. A 12 hr shut-in temperature survey was performed and confirmed that the injected fluids are exiting the casing at the perforations and are contained in the approved injection strata. This is demonstrated in the attached survey by the large temperature drop at the perf depth on the 2007 baseline and this new survey showing only gradient based thermal changes above the perfs and packer. The G-22 injector supports one of the biggest producers in McArthur River, the M-34 well. The M-34 currently produces -350 BOPD and 10,000 BWPD. This voidage is offset by the G-22 injection of-12,000 BWPD. The G-22 was offline from 5/2016 to 7/2016 and we saw the M-34 gross rate decline from 8400 BFPD to 7400 BFPD during that short time frame. The G-22 clearly provides support to the M-34 well and will have a negative effect on oil production without its operation. Hilcorp is currently studying the waterflood at MRF in order to determine which wells are the most important for injection. We are currently working to put together an injection reactivation/repair program for McArthur River and scheduling to fit our 2018/2019 budget. We ask to continue to operate this well as we work through this process. 1 If approved for continuous injection, the G-22 well will remain on daily pressure monitoring with monthly TIO reports sent to AOGCC documenting the trailing six months of daily pressures. These reports are analyzed for any pressure or rate anomaly that could indicate a secondary integrity issue with the well. The monthly report analysis proving containment of the injected fluids to the approved injection strata will be confirmed every other year with a temperature survey. Thank you Larry From:Wallace,Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Wednesday,January 31, 2018 9:55 AM To: Larry Greenstein<Igreenstein@hilcorp.com> Subject: RE:Grayling G-22 Request for Administrative Approval (PTD#1750160) Larry, Request to restart injection for diagnostics and monitoring for up to 30 days is Approved. At the end of the 30 day period, Hilcorp can shut in the well,apply for additional time for monitoring and diagnostics,or provide a hardcopy Administrative Approval request to AOGCC with accompanying supporting documentation including: 1. Applicable AIO and Administrative Approval Rule allowing AOGCC to consider this request 2. review of testing completed and diagnostics performed with conclusions, with special attention to confirming competent barriers to the release of well pressure and in zone confinement 3. review of utility/importance of this well to the EOR process and why this EOR cannot be achieved through compliant EOR wells 4. options considered to repair the well and reasons a repair is not being completed, or repair schedule to bring this well back to routine service 5. proposed ongoing testing and monitoring restrictive conditions Several examples of formats for AA requests can be found in our files but I include a recent one from Conoco for your review. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent:Wednesday,January 31,2018 9:18 AM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject:Grayling G-22 Request for Administrative Approval (PTD#1750160) Hi Chris As we discussed yesterday, with the recent tubing x IA communication in the Grayling G-22 well, this well has been shut- in. The reservoir engineer would like to keep EOR water going into the ground at this well's location, so we would like to request an Admin Approval (AA)to get that accomplished. This would entail a few steps as follows: 2 • As this well already has a good baseline temp survey, we'd like to temporarily restart injection (1-2 weeks)to establish a stable downhole temperature profile. Run the standard 12 hr shut-in temperature survey and leave the well shut-in pending the results of the comparison of this new survey with a previous baseline temp survey. If all the water appears to be contained in the approved injection strata, and upon agreement from AOGCC, return this well to continuous waterflood injection with an approved AA. If this approach to returning this well to EOR service meets with your approval, please let me know. Larry 3 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday,January 31, 2018 9:54 AM To: 'Larry Greenstein' Subject: RE:Grayling G-22 Request for Administrative Approval (PTD#1750160) Attachments: CRU CD2-30 AA Request 12-17-17.pdf Larry, Request to restart injection for diagnostics and monitoring for up to 30 days is Approved. At the end of the 30 day period, Hilcorp can shut in the well,apply for additional time for monitoring and diagnostics,or provide a hardcopy Administrative Approval request to AOGCC with accompanying supporting documentation including: 1. Applicable AIO and Administrative Approval Rule allowing AOGCC to consider this request 2. review of testing completed and diagnostics performed with conclusions, with special attention to confirming competent barriers to the release of well pressure and in zone confinement 3. review of utility/importance of this well to the EOR process and why this EOR cannot be achieved through compliant EOR wells 4. options considered to repair the well and reasons a repair is not being completed,or repair schedule to bring this well back to routine service 5. proposed ongoing,testing and monitoring restrictive conditions Several examples of formats for AA requests can be found in our files but I include a recent one from Conoco for your review. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:Igreenstein@hilcorp.com] SCAN '1:4;-, Sent:Wednesday,January 31, 2018 9:18 AM i ' To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Subject:Grayling G-22 Request for Administrative Approval (PTD#1750160) Hi Chris As we discussed yesterday, with the recent tubing x IA communication in the Grayling G-22 well, this well has been shut- in.The reservoir engineer would like to keep EOR water going into the ground at this well's location, so we would like to request an Admin Approval (AA)to get that accomplished. This would entail a few steps as follows: As this well already has a good baseline temp survey, we'd like to temporarily restart injection (1-2 weeks)to establish a stable downhole temperature profile. 1 • • • Run the standard 12 hr shut-in temperature survey and leave the well shut-in pending the results of the comparison of this new survey with a previous baseline temp survey. If all the water appears to be contained in the approved injection strata, and upon agreement from AOGCC, return this well to continuous waterflood injection with an approved AA. If this approach to returning this well to EOR service meets with your approval, please let me know. Larry 2 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COME` .ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other 0 Return to Injection Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver El Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Wefl❑ 2.Operator 14.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 175-016 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20272-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/G-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,335 feet Plugs measured 10,980 fe=..I. EC L ® " D true vertical 9,989 feet Junk measured 11,254 feet FEB 262015 Effective Depth measured 10,980 feet Packer measured 9,950&10,968 feet true vertical 9,674 feet true vertical 8,797&9,664 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' 2,692 psi Conductor 629' 20" 629' 629' 1,530 psi 520 psi Surface 5,548' 13-3/8" 5,548' 4,977' 3,090 psi 1,540 psi Intermediate Production 11,335' 9-5/8" 11,335' 9,984' 6,870 psi 4,750 psi Liner Perforation depth Measured depth See Schematic feet same „ ,1 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 10,023'(MD) 8,858'(TVD) Packers and SSSV(type,measured and true vertical depth) Pkr 9,950'(MD)8,797'(ND)&10,968'(MD)9,664'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 9761 2270 2500 Subsequent to operation: 0 0 10749 260 2670 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ El SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-467 / Contact Dan Taylor Email dtaylor(47hiIcorp.com Printed Name Dan Taylor.,--------) ..--.• Operations Engineer Signature ,/' ;-11Phone (907)777-8319 Date 2/26/2015 RE/Digq- MAR - 2 2015 Form 10-404 Revised 10/2012 =,e '(- 1-S— Submit Original Only .��(3— trading Bay Unit . 14 Well: G-22 HikoroAlaska,LLC As Completed: 2/2015 CASING AND TUBING RKB to TBG Hngr=40.6' Tree:Single 4_1/2"5,000# _ CSG Wt(Ib/ft) Grade Conn ID(in) (Top) Btm(MD) 26in (lin wall) 24 0 356 20in 94 Butt 19.124 0 629 13-3/8in 61&68 _ H-40 Butt 12.415 0 5,548 9-5/8in 47 N-80 Butt 8.681 0 7,016 9-5/8in 47 P-110 Butt 8.681 7,016 _ 10,087 9-5/8in 47 S-95 Butt 8.681 10,087 11,335 Tubing: 4-1/2in 12.6 L-80 Butt 3.5 41 10,023 JEWELRY DETAIL No. Depth(ft) ID(in) Item 41 3.958 Cameron DCB 4-1/2"Tubing hanger.4-1/2"Butt x 4-1/2"EUE top 1 9,950 4.950 9-5/8in 36-53#Liner top packer(Ni Coated) Seal Bore Locator Assym at 9,920ft. Seal bore total length 19.3ft h; 2 9,993 2.813 3-1/2"Otis"X"Nipple,w/3.75"No Go >C ,>C 1 3 10,023 3.958 3.5in EUE tbg joint cut bottom(end @ 10,023) x 2 4 10,968' 4.0" Otis"BWH"Perm Pkr (10,961'DIL) G-1 5 10,980' 2.635" 3-1/2"Otis"XN"Nipple,w/2.75"PXN plug J 3 - 6 10,981.55' 2.99" WLREG __ G• -2 ▪ G• -3 G-4 PERFORATION DETAIL ▪ G-5 Top Btm TOP Btm Zone Amt SPF Date Status (MD) (MD) (TVD) (TVD) G-1 10,061' 10,095' 8,891' 8,919' _ 34' 4 11/19/1989 Open for Injection G-1 10,065' 10,092' 8,894' 8,917' 27' 6 9/11/1998 Open for Injection G-1 10,065' 10,092' 8894 8917 27 5 2/3/2015 Open for Injection G-2 10,115' 10,154' 8,936' 8,969' 39' 4 11/19/1989 Open for Injection G-2 10,118' 10,133' 8,939' 8,951' 15' 6 9/11/1998 Open for Injection G-2 10,118' 10,133' 8939 8951 15' 5 2/3/2015 Open for Injection G-2 10,122' 10,137'(DIL) 8,942' 8,954' Open for Injection IT i B-1 G-2 10,146 10,154 8,962 8,969 8' 5 2/3/2015 Open for Injection G-2 10,162 10,174 8,975 8,985 12' 5 2/3/2015 Open for Injection = B-2 G-3 10,178' 10,218' 8,989' 9,022' 40' 4 11/19/1989 Open for Injection - G-3 10,184 10,220 8,994 9,024 36' 5 2/3/2015 Open for Injection 32.1ft,2.5in RCT, _ B_3 G-3 10,190' 10,220' 8,999' 9,024' 30' 6 9/11/1998 Open for Injection On Btm 1/14/15 = G-3 10,190 10,220' (DIL) 8 999' 9,024' 30' 4 5/4/08 Open for Injection = B-4 G-4 10,230' 10,280' 9,032' 9,074' 50' 6 9/11/1998 Open for Injection 0-4 10,230' 10,280' 9032 9074 50' 5 2/3/2015 Open for Injection Weis III 1111 k111111 4 G-4 10,230' 10,300' 9,032' 9,091' 70' 4 11/19/1989 Open for Injection IG-5 10,370' 10,430' 9,149' 9,199' 60' 4 11/19/1989 Open for Injection si G-5 10,375' 10,430' 9,153' 9,199' 55' 6 9/10/1998 Open for Injection G-5 10,375' 10,430' 9,153 9,199 55' 5 2/3/2015 Open for Injection `„;,, 5 G-5 10,590' 10,592' 9,335' 9,337' 2' 4 6/24/1975 Sqz for Isolation • 6 B-5 B-1 10,584 10,629 9,330 9,368 45' 5 2/3/2015 Open for Injection 0 B-1 10,595' 10,629' 9,339' 9,368' 34' 4 11/16/1989 Open for Injection B-2 10,643' _ 10,734' 9,380' 9,459' 91' 20/8/4 11/16/1989 Open for Injection = B• -6 B-2 10,742' 10,752' 9,466' 9,475' 10' 4 11/16/1989 Open for Injection B-3 10,762' 10,815' 9,483' 9,529' 53' 16/4 11/16/1989 Open for Injection --------"--- Top of Junk ---- Ca3 CD3 ©11,254' B-3 10,765 10,838 9,486 9,414 73' 5 2/3/2015 Open for Injection ..---"` ' B-4 10,827' 10,952' 9,540' 9,649' 125' 16/12/8 11/16/8 9 Open for Injection RT to MSL ELEV=99' B-5 10,984' 11,022' 9,678' 9,711' 38' 4 7/4/1975 Isolated TD=11,335' ETD=10,980' B-5 11,081' 11,082' 9,763' 9,764' 1' 4 6/22/1975 Sqz for Isolation MAX HOLE ANGLE=34.51@ 4200' B-6 11,115' 11,145' 9,794' 9,820' 30' 4 7/3/1975 Isolated REVISED: 02/20/15 DRAWN BY: DRT Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 ,Daily Operations: 01/04/15-Sunday Finish securing clamps on master skid beams. R/d jacks off of master skid.Clean cellar and between rig and booster package.Skid rig south 6'secure rig to beams and r/d jacks. Install ODS catwalk. Finish secure clamps, install stairs on ODS landing, R/u catwalk and beaver slide. R/u heaters start heating cellar. R/d rig floor and R/u handrails around opening in floor. Install choke line and circulating line to pits.Attempt to set BPV, unable.Start shooting fluid levels and recording.Wk on winterization of circulating lines. 01/05/15-Monday Start monitoring fluid level in well,while continue rigging up electrical lines to rig.Spotting tools for R/d of tree,winterizing &housekeeping. R/d tree and clean threads on hanger. Unable to install BPV, but was able to thread x-over sub. Remove sub dope box and R/u riser and BOP'S torqueing same. R/u scaffolding around BOP'S.Continue R/u halls head bell nipple, flow line. Install drip pans and rig floor. 01/06/15-Tuesday PTSM.Cont. R/u flow line. Install beaver slide.Service choke manifold&standpipe manifold valves. R/u FIW t/pits.Check nitrogen pressure in accumulator bottles,all good. Re-spot heaters at rear of sub. M/U 4 1/2 test jt. Fill stack w/fluid. Found issues w/PVT system. Function test BOP accumulator. Noise coming from electric pump. Wk on accumulator. Tighten drive chain.Clean "Y"strainer,top w/fluid,function test good. Work on PVT system.C/o monitor issues not solved.Sending more parts from town.Attempt shell test, unable to hold pressure.Trouble shoot.Appears to be leaking past lift threads. Pull TJ change configuration&re-dope&tape. Re-test, no good. Blow down lines and clean around cellar deck, rig floor and pit room.Sending more parts from town for PVT system this morning. 01/07/15-Wednesday Cont.wk on PVT system.Clear obstruction from remote panel control cable. Re-route,install&function test,good. Finished repair on PVT system tested good.Contacted AOGCC inspector&Jim Regg about a rolling test,ok to proceed testing according to approved sundry rolling test procedure. Tested choke manifold&floor valves,200 low,3000 high, good.Tested gas detection system,good.Checked PVT alarms,good. M/U 4 1/2 tj, performed rolling test w/annular 2500 psi, pipe rams 200,3000 no visual leaks or flow to pits, pumped at 14.9 GPM. R/d test joint. M/u landing jt,to hanger and B/o L/d pins. P/u to 75k,unseated hanger,cont. pulling t/135k came free weight 125k to 127k. Pull hanger to floor& L/d. M/u test plug, landed test plug s/o wt 78k, pulled landing jt m/u test jt. Fill up stack and close annular,shell test 250 psi low and 2500 psi high good.Service equipment and housekeeping while waiting on AOGCC to witness BOPE test. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number •Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 01/08/15-Thursday Cont.wait for AOGCC inspector to witness test(choppers on weather hold). Inspector Jeff Jones,AOGCC waived witness @ 8:40 am. Test BOPE as per Hilcorp&AOGCC regulations,tested w/4 1/2&3 1/2 test jt, 200 low,3000 high,annular 200 low,2500 high. Change out choke, HCR valve,leaking out stem. M/u test joint,fill stack. Cont.test BOPE.Test HCR 250 psi low,3000 psi high,good. Had 2-FP. Pull test plug to surface and L/d same. Blow down lines. POOH L/d 4-1/2" 12.6# completion string 120,000 up wt. Unload Boat transfer diesel to production. Continue POOH with completion string, L/d 200 jts,6,194'. Note that holes start to appear on tubing at joint 38 @ 1,175'. 01/09/15-Friday OOH with total of 254 jts,7,868'.TOF @ 7,908', last jt missing approx 1/3 of pin. Clean&clear floor, pipe rack. Prep BHA. Unload&back load boat. P/U BHA#2,Overshot dressed w/5 1/8,xo, bumper jar,oil jar,6-4 3/4 Drill collars,xo=215.53'. TIH with 3-1/2" PH-6 workstring t/7,887',up wt 130,dn wt 85k. R/u CBU x 2, @ 3.5 BPM,300 psi. TIH to engage fish @ 7,925', pick up to 140,000, 10k over string weight weight fell off to 133,000. POOH with 3,000#increase in weight. Shut down and remove draw works chain on drillers side due to bad bearing on hydromatic. Continue POOH. L/d BHA, have fish in overshot, laying down fish. 01/10/15-Saturday Cont. L/d fish, recover 3 jts,93.88'.Shuck overshot& L/d tools. Clean&clear floor&pipe rack. Test BOPE as per Hilcorp& AOGCC regulations.Test witnessed by AOGCC inspector,Jeff Jones. 3 1/2 test jt,200 low,3000 high,annular 200 low, 2500 high,all good.Tested gas alarms&pvt system,all good. M/u test jt,set test plug,fill stack&manifolds. Blow down, pull test jt. Install wear bushing.Wk on d/w hydromatic. Remove drum shaft,find bad bearing,clutch pads damaged. Install new clutch on hydromatic&install new bearing to drum shaft and M/u to draw works.While installing d/s drum shaft bearing came apart. Remove drum shaft,take to welding shop to remove broken bearing and wait on new one from beach. Receive bearing, install bearing&re-install drum shaft. 01/11/15-Sunday Cont. repair hydromatic& test run good. P/U BHA#3,Overshot dressed w/5 1/8,xo, bumper jar,oil jar,6-4 3/4 Drill collars,xo=215.53'. TIH t/7,982'. CBU x2 @ 4bpm,460 psi,spot 30 bbl nw 50 pill. TIH t/8,010' up wt 134,dn wt 83. M/u TIW valve. Respond to Production gas alarm drill. TIH tag TOF @ 8,019',engage. P/u &let jars bleed off.Cont p/u 9k over, came free,drag 1-3k over. POOH. Held safety valve drill,well secured,48 seconds.Continue POOH. Ooh with fish. Recovered 5 joint of 4-1/2"tubing=154.75'of fish.Clean rig floor. M/u BHA#4=pup joint,xo,overshot dressed w/5- 1/8"= 11.74.TIH t/4,613'up wt 72 dn wt 62. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 01/12/15-Monday Cont.TIH t/8,148', up wt 126,do wt 82. R/u CBU, @ 3bpm, 265psi. TIH t/tag TOF @ 8,172',engage fish, pull 11k over, came free. POOH, L/d BHA, recover 2 jts 4 1/2 12.6#tubing,62.20', new TOF 8,234'. Clean&clear floor. Redress overshot. P/U BHA#5=pup joint,xo,overshot dressed w/5-1/8"= 11.74. TIH t/8,220', 128k p/u weight,82k s/o weight. R/u and pump 15 bbls down tubing. TIH engage fish @ 8,234'set down 2-3k, pull up in 2000#increments to 150k 2x no movement. Decided to R/u eline to cut tubing. E-line unit on King Platform and can't load out due to 40+mph winds.Clean rig floor and work area. Winds at 30 mph, boat headed to King.While waiting on eline unit r/u slick line and TIH w/2.5"GR. 01/13/15-Tuesday RIH w/2.5" GR t/8,450'.Set down,worked free, POOH. L/d wireline. R/U e-line. M/u 2"tubing punch. TIH to 8,454'tag. P/u punch hole's in tubing,top shot @ 8,413', POOH. M/u 2-1/2" RTC TIH.Seeing no obstruction at 8,454'cont.TIH t/tag @ 9,070'. P/u w/3k op.CCL not reading. POOH. Reconfigure tool string&c/o CCL. RIH correlate,cut at 9,035'. POOH and r/d eline equipment. P/u to 150k 2x. P/u to 156k tubing came free. Pipe weight at 138k. POOH with fish. L/D BHA. L/d 4 1/2" 12.6#fish. L/d 14 jts 468.28' @ 6:00, multiple holes in tubing. 01/14/15-Wednesday Cont. L/d fish. L/d 30 jts total,932.82'. New TOF 9,167'. Clean&clear floor. P/U BHA#6=pup joint,xo,overshot dressed w/5-1/8"= 11.74.TIH t/3,370'. Wind @ 57 mph blowing blocks into derrick.Shut down wait for wind to die down. Wind down t/35-40 mph.Cont.TIH t/9,156'. CBU x2 136 bbls p/u weight 141k,s/o weight 88k. R/U e-line. Work tubing from 60k to 191k no movement on tubing.Call out W/L to fish tools. TIH,Tag fish at 9,167'dpm, pick up in 2k increments to 161K 2x.Tubing not free. TIH with 2"radial cutter to 9,167'tag set down 2x. Pick up with no overpull on the third try tools stuck.Work tools and pulled out of rope socket. POOH and r/d eline. 01/15/15-Thursday Cont.wk pipe. Rig up W/L. RIH w/11/2 JDC t/9,146'wlm. Latched fish jarred 4x came free. Re-latched, jarred free. POOH. P/U 21/2 GS w/Bait sub&overshot. RIH latch,jar several times had some movement up t/9,138'wlm then solid. Pumped 4 BPM 1200 psi. No wt change.Shear off. POOH. Cut wire. P/u 21/2 GR. RIH t/9,142' latch, beat down had movement back down t/9,148'wlm.Stopped,unable to go down.Shear off. POOH. RIH w/GS latched jarred up t/9,138'stopped solid. Sheared off. POOH r/d W/L. Wk string t/60k over pumping 4 BPM no go. R/U power swivel. Put 7k ft/lbs torque into string,work pipe holding torque f/215k down to 160k repeatedly. Pipe spent free on down stroke. P/U weight showing 9k over string wt. L/D power swivel&prepare to POOH. POOH with 3.5"work string. Break down overshot&L/d 4.5"btc tubing inspecting jts for lost wireline fish. Recover 18 jts,558.45'. Pin on last jt missing. New TOF 9,726'. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 01/16/15-Friday Break fish out of overshot&redress.Clean&clear floor. Close Blind rams. Run in lock's. Remove floor panels. Install hand rails. Remove drip pan,flow nipple&flow line. N/d annular. Waiting on Annular to arrive. Rig maintenance. Plumb steam heaters in cellar. Unload&back load boat. N/U annular, install turn buckles, n/u flow line&drip pan. Remove rig floor hand rails&install floor plates. P/U test joints, retrieve wear bushing,set test plug&m/u test lines. Test BOPE per AOGCC regulations with 3-1/2"tubing.Tested BOPE from main to 250 low&3000 psi high on chart. Functioned tested rams from remote.Witness waived and allowed to test early by Jim Regg on 1/16/15. Pull test plug,install wear bushing&I/d 3-1/2" test assembly. R/U e-line with lubricator,p/u 8" LIB, RIH same. 01/17/15-Saturday RIH w/8" LIB t/9,721 wlm.Came back w/no impression. RIH w/6" LIB t/9,722 picked up w/overpull,came back with no impression. Discuss options w/town. Prep&p/u BHA#7-8 1/8 wavy btm shoe,6 jts wash pipe,top sub,xo,bumper jar, oil jar, 6-4 3/4 drill collars,xo=408.01. TIH slowly with 3-1/2"tubing to 9,694'. Install stripper rubber&p/u power swivel. Break circulation in reverse pumping 4 bpm@400 psi.Circulate across fish top @ 9,726'(2 tbg volumes). Wash over fish top @ 9,726'.Continue washing&swallowing fish from 9,726'to 9,885',reverse circulating 4 bpm @ 600 psi, rotating 10 rpm with 5000 ft/lbs torque.Getting sand back over shakers.Circulating bottoms up each kelly down due to excess sand. Reverse circulate sand from tubing @ 4 bpm,preparing to change out stripper rubber. Change out busted stripper rubber. 01/18/15-Sunday Cont.w/d f/9,885't/9,895'.Tag TOP,cbu @ 4bpm,500 psi. L/D swivel, POOH.Tight f/5,980'-5,690'. L/d BHA. Clean& clear floor. Rig maintenance. P/U BHA#8-overshot w/5 1/8 grapple, upper ext,xo,3 1/2" pup jt=14.74. TIH with 3-1/2" tubing,space out&engage fish top @ 9,726'.Set down 4k&latch fish. P/u wt=154k,s/o wt=90k. R/U power swivel. Put 6k ft/lbs torque into work string,work fish f/160k-215k(61k over string wt.). Had no movement. R/D power swivel. R/U slickline with lubricator. RIH with 2.49" LIB.Tagged up @ 9,727'POOH,Got impression in center of block. R/d W/L. 01/19/15-Monday R/U swivel, p/u t/180k,wk 6k tq into string,wk f/180-t/140 rotate anchor free. L/D swivel, POOH. L/D BHA&fish, recover 4 jts 4 1/2" BTC tubing, pup jt&anchor locator=175'. R/U W/L, P/U 8" LIB, RIH&tag @ 9,905'slm. POOH, had no impression. P/U 2.50" bailer, RIH to 9,980'(packer assembly clear), POOH. R/D slick line. Change out foster tongs,shuck overshot&break down. Measure Pioneer packer assembly&prepare to TIH. P/U Pioneer packer picker BHA assembly, packer picker,(2)7" boot baskets, bit sub,string magnet, bumper&oil jar,(6)4-3/4"drill collars,&x-o sub.Total BHA= 235.75'. TIH with 3-1/2"work string t/9,816', up wt 170k,do 92k. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 01/20/15-Tuesday R/U power swivel & break circulation pumping down tubing at 3.5 bpm&400 psi. Tag top of packer @ 9,896'. Rotate& work sphere into top of packer. Establish parameters, mill over packer f/9,896'to 9,898.5'(30 inches) rotating 70 rpm with 5-7k ft/lbs torque, 12k weight on mill, pumping 3.5 bpm @ 400-500 psi. Continue milling over packer from 9,898.5'to 9,899' (total of 36 inches made). Continue to try& mill on packer, unable to make any footage. Pull 40k over string wt.to free packer, sheared off of sphere. L/D power swivel&prepare to pooh. POOH with 3-1/2"work string to 8,521'. Slip& cut drill-line. 01/21/15-Wednesday Cont. cut drill line&service rig. Cont. POOH f/8,521'. L/d Pioneer milling assembly. Cleaned boot baskets&magnet. Recovered 4 gal metal.Changed out mill head&mandrel (f/6.97 to 5.78)on assembly. BHA#10: packer picker,(2)7" boot baskets, bit sub,string magnet, bumper&oil jar, (6)4-3/4" drill collars, &x-o sub.Total BHA=234.56'. TIH with 3-1/2" tubing out of derrick to 9,877'. R/U power swivel. Engage fish @ 9,899', begin milling on packer with 70 rpm&7k ft/lbs torque,4-10k weight on mill,3.5 bpm @ 350 psi.Continuously changing parameters to establish penetration. Made approximately 2" @ 0600 hrs. 01/22/15-Thursday Continue attempting to mill over packer changing parameters. Unable to establish torque,decision made to shuck off& POOH. Shuck sphere from packer. L/d power swivel & prepare to POOH. POOH with 3-1/2"tubing on different break. Pipe tight,change out Foster tongs to McCoy to prevent tubing scarring. Continue to POOH to BHA. Break down packer picker assembly, had marks cut on sphere mandrel, mill worn 10%.Strap&caliper ITCO sphere. Clean rig floor& prepare to p/u BHA&TIH. P/U ITCO sphere dressed with 4.805"grapple,jars, &drill collars.TIH with 3-1/2"work string to 2,216', heard loud noise in draw works. Take guards off of draw works,found bearing out on secondary shaft(off drillers side). Begin taking chain guards&chains off to change out bearing. 01/23/15-Friday RIG DOWNTIME: CONTINUE CHANGING OUT BEARING ON SECONDARY SHAFT. 01/24/15-Saturday CONTINUE INSTALLING SPROCKET CAP,SPROCKET, &CHAIN. INSTALL CHAIN GUARDS&TEST RUN RIG. POOH WITH 3-1/2" WORKSTRING& BHA. PULL WEAR BUSHING. P/U TEST PLUG&TEST ASSEMBLY. TEST BOPE PER AOGCC REGULATIONS. TEST WITH 3-1/2" &4 1/2"TUBING.TEST ALL BOPE TO 250 LOW&3000 HIGH.TEST FROM REMOTE& FUNCTION TEST MAIN.TEST WITNESS WAIVED BY JIM REGG. L/D TEST ASSEMBLY. INSTALL WEAR BUSHING& PREPARE TO TIH. TIH WITH ITCO SPHERE ON 3-1/2"TUBING.TAG @ 9,836'TUBING MEASUREMENT WITH 15K DOWN. PUSH OBSTRUCTION DOWN HOLE. DID NOT SEE PACKER @ 9,907'. CONTINUE PUSHING PACKER DOWN HOLE TO 10,511'.SET DOWN 35K& P/U 20K OVER STRING WEIGHT(INDICATING SPHERED INTO PACKER).CHASE PACKER TO 10,545'.SET DOWN 40K THREE TIMES. DECISION MADE TO POOH. POOH WITH 3-1/2"WORK STRING DRAGGING 15-40K. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 01/25/15-Sunday CONTINUE POOH WITH 3-1/2" WORKSTRING TO SURFACE. DID NOT RECOVER PACKER&GRAPPLE MISSING FROM MANDREL. R/U SLICKLINE. RIH W/6" LIB.TAG @ 4,708'SLM. POOH. P/U 4.5" MAGNET&RIH. POOH (NO RECOVERY). P/U 4" MAGNET&RIH (RECOVERED FINE METAL& PIECE OF PACKER RING). RIH W/4" MAGNET(RECOVERED PACKER RING WITH BURN SHOE MARKS). RIH WITH 4" MAGNET(NO RECOVERY). P/U 8" LIB& RIH (HAD FAINT MARKINGS BELIEVED TO BE PACKER TOP). P/U & RIH WITH 2.5"GR, 5'STEM CENTRALIZED WITH 5" BOWSPRING. STING INTO PACKER AT 4,709', SLIDE INSIDE PACKER TO 4,715' & BOTTOM OUT WITH CENTRALIZER. POOH. P/U 3.5" GR W/5"CENTRALIZER. RIH,WORK GR INTO PACKER TOP @ 4,709',SLIDE 3.5"GR INSIDE PACKER TO 4,715'SLM. POOH & R/D SLICKLINE. P/U ITCO SPHERE ASSEMBLY W/4.80"GRAPPLE,JARS, & DC.TIH WITH 3-1/2"TUBING DEPTH AT 6: 00 8,400'. 01/26/15-Monday CHASE PACKER DOWN HOLE WITH ITCO SPHERE TO 10,545'.WORK BUMPER JARS SITTING DOWN 60K. POOH WITH 3-1/2" TUBING, PACKER DRAGGING UP TO 65K OVER STRING WT. RACK BACK DRILL COLLARS& L/D JARS. RECOVERED PACKER ASSEMBLY&TWO JTS OF 4-1/2" BTC. L/D SAME. RECOVERED 1/2 THE PIECES OF GRAPPLE LEFT IN HOLE. R/U SLICK LINE. RIH WITH 6" LIB TO 10,515'SET DOWN. POOH (NO INDICATION OF CLEAN W/L TOOL FISH). P/U 3-1/2" MAGNET&RIH (1ST RUN RECOVERED PACKER RINGS& PIECES). RIH (SECOND RUN RECOVERED 1/4 PIECE OF GRAPPLE& BROKE PIECES). RIH (THIRD RUN RECOVERED PACKER PIECES& FINE SHAVINGS). RIH (FORTH RUN RECOVERED PIECE CUP ON FROM PACKER AND FINE METAL). RIH WITH RUN#5 RECOVERED TOTAL 22 POUNDS METAL. 01/27/15-Tuesday CONTINUE RUNNING 3-1/2" MAGNET RETRIEVING PIECES OF METAL. R/D WIRELINE.TOTAL 7 RUNS, 23 POUNDS METAL RECOVERED. P/U CABLE SHOE, (2)8-1/8"JTS OF WASHPIPE,TOP BUSHING,JARS, (6)JTS OF 4-3/4" DC'S,&X-0 SUB. TOTAL BHA=280.58'.TIH WITH 3-1/2"WORK STRING FROM DERRICK. L/D 5 STDS FROM DERRICK TO WASH WITH. P/U POWER SWIVEL. INSTALL STRIPPER RUBBER ADAPTOR. WASH F/10,483'TO 10,609'. REVERSE CIRCULATING 4 BPM @ 550 PSI. TUBING PACKED OFF WHILE CIRCULATING BOTTOMS UP AT 10,609'. ATTEMPT TO WORK PIPE& BLOW OUT TUBING, PRESSURING UP TO 3000 PSI. CHECK ALL SURFACE LINES(OK). L/D POWER SWIVEL& REMOVE STRIPPER RUBBER. PREPARE TO POOH. POOH WITH 3-1/2"TUBING(WET STRING) DEPTH AT 6 AM (7,500'). 01/28/15-Wednesday CONTINUE POOH WITH 3-1/2"TUBING (WET STRING FROM 8,515'TO SURFACE). CLEAN OUT 5 JTS OF 3-1/2"TUBING PACKED OFF WITH SCALE&SAND. L/D WASHPIPE&CLEAN OUT SAND,SCALE,& METAL PACKED OFF IN LAST 1T OF WASH PIPE&CABLE SHOE. CLEAN & DISPOSE OF SCALE,SAND, & METAL OFF RIG FLOOR.CLEAN RIG FLOOR& PREPARE TO TIH WITH TEST PACKER. P/U HALLIBURTON 9-5/8"TEST PACKER&TIH SAME TO 9,997' DPM. SET PACKER @ 10,005' KB MEASUREMENTS WITH 20K DOWN.TEST 9-5/8" CASING TO 2500 PSI ON CHART FOR 30 MINUTES(TEST GOOD). UNSET PACKER& PREPARE TO POOH. POOH WITH 3-1/2"WORK STRING. DEPTH @ 0600 HRS=8,500'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 01/29/15-Thursday CONTINUE POOH WITH 3-1/2"TUBING. L/D HALLIBURTON 9-5/8"TEST PACKER. CLEAR RIG FLOOR& PREPARE TO P/U CLEAN OUT ASSEMBLY. P/U 8-1/8" CABLE SHOE,(2)JTS OF 8-1/8"WASH PIPE, BUSHING,JARS, (6)4-3/4" DC'S, &TIH SAME.TIH WITH 3-1/2"TUBING FROM DERRICK TO 1,500'. P/U HALLIBURTON STORM PACKER&SET SAME 200' BELOW MUD LINE.TEST TO 1500 PSI ON CHART. RELEASE& POOH WITH 200'OF TUBING. GATHER TOOLS TO N/D BOP'S, REMOVE FLOOR PLATES, INSTALL HAND RAILS, N/D FLOW-LINE& BELL NIPPLE, N/D RAMS FROM RISER&SET TO SIDE. BREAK&CUT STUDS FROM EXISTING TUBING HEAD. REMOVE& L/D TUBING HEAD SAME. DRESS CASING HEAD. INSTALL SEABOARD 11" 5M X 13-5/8" 5M TUBING HEAD&TIGHTEN SAME.TEST VOID TO 3000 PSI.TEST GOOD. N/U RISER&BOP. 01/30/15-Friday CONTINUE TIGHTENING BREAKS ON BOP& RISER. INSTALL FLOW LINE &TURN BUCKLES TO STACK. INSTALL DRIP PAN, FLOOR PLATES. SHELL TEST BOP BREAKS TO 1500 PSI FOR 15 MIN ON CHART.TEST GOOD. TIH & ENGAGE HALLIBURTON STORM PACKER @ 200' BELOW MUD LINE, UNSET, POOH, & L/D SAME. TIH WITH 3-1/2" 12.95#WORK STRING F/1,500' TO 10,550'. INSTALL STRIPPER RUBBER ADAPTOR. P/U POWER SWIVEL& PREPARE TO START WASHING. WASH FROM 10,580'TO 10,705' REVERSE CIRCULATING 4 BPM @ 550 PSI, P/U WT=168K,5/0 WT=98K, PUMPING 5 BBL HIGH VIS SWEEP EVERY 50'OF HOLE MADE. BEGAN LOSING FLUID @ 10,705'. CONTINUE WASHING FROM 10,705'TO 10,767', CIRCULATING 1.5 TUBING VOLUME BEFORE EACH CONNECTION.TOTAL LOSSES=74 BBLS(24.6 BBLS PER HR). 01/31/15-Saturday CONTINUE WASHING FROM 10,767'TO 10,877', REVERSE CIRCULATING 4 BPM @ 500-600 PSI,CIRCULATING(2)TUBING VOLUMES BEFORE EACH CONNECTION. CIRC COMPLETE HOLE VOLUME. L/D POWER SWIVEL& REMOVE STRIPPER RUBBER. PREPARE TO POOH, POOH WITH 3-1/2"TUBING, RACK BACK DRILL COLLARS& L/D WASH PIPE.CABLE FROM SHOE WAS WASHED OUT. NO RECOVERY. TEST BOPE PER G-22 SUNDRY 250 PSI LOW&3000 PSI HIGH. CHANGE PACKING ON STEM OF CHOKE MANIFOLD VALVE DUE TO NO TEST. CHANGE OUT 3-1/2"TIW(SERIAL#GM25081, KP7779)TAKE OUT OF SERVICE DUE TO STEM ON VALVE LEAKING.TEST PIPE RAMS&ANNULAR WITH 3-1/2"AS WELL AS 4-1/2"TUBING. 02/01/15-Sunday CONTINUE TESTING BOPE TO 250 LOW&3000 HIGH. PERFORM KOOMEY DRAW DOWN TEST. WITNESS OF TEST WAIVED BY JIM REGG,AOGCC. PULL& L/D TEST PLUG&TEST ASSEMBLY. R/U SLICKLINE UNIT. RIH WITH GS PULLING TOOL&4.5" BELL GUIDE,TAG @ 10,863'SLM. P/U& HAD 200 LBS OF OVERPULL. LOST WEIGHT,SLACK BACK OFF&TAG @10,842 SLM. WORK TOOL. POOH & HAD NO RECOVERY. R/D SLICKLINE & PREPARE TO P/U TCP. HOLD PREJOB SAFETY MEETING&JSA WITH RIG CREW. BEGIN P/U TCP ASSEMBLY. P/U HALLIBURTON TCP ASSEMBLY WITH GAUGES. P/U 35 SECTIONS OF 4-5/8" 6 SPF=773.40' OF LIVE SHOT&TIH SAME. TIH WITH 3-1/2"WORK STRING, DRIFTING STANDS OUT OF DERRICK. DEPTH @ 10838' BOTTOM SHOT AND TOP SHOT @10065' Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 02/02/15-Monday HELD JSA ON RIGGING UP E-LINE EQUIPMENT AND SERVICE RIG. RIH WITH 1 11/16"GAMMA RAY CCL TOOL. LOG GUNS ON DEPTH, FOUND 81'SHALLOW. POOH WITH E-LINE. LAVED DOWN SHEAVES. P/U 3 JTS RIH. P/U SHEAVES. RIH WITH GAMMA RAY, CORRELATE GUNS ON DEPTH. DIDN'T HAVE TO MOVE PIPE. POOH WITH E-LINE. DROPPED BAR PERF WELL 10,838'TO 10,065'6 SPF. WELL ON VACUUM. FILL BACKSIDE.TOOK 12 BBLS TO FILL. POOH ABOVE PERFS. R/U AND REVERSE OUT 1 1/2 TBG VOLUMES. GOT BACK DARK WATER NO GAS OR OIL. POOH WITH 3 1/2"WORK STRING TO PERF GUNS. R/U AND LAY DOWN PERF GUNS.ALL GUN SPACERS FILLED WITH TRAP PRESSURE AND FLUID. NOTE ALL SHOTS FIRED. R/U PRESSURE WASH AND CLEAR RIG FLOOR. REMOVE ALL PERF GUN HANDLING EQUIPMENT FROM RIG FLOOR. HELD PRE JOB SAFTEY MEETING AND JSA WITH TRIPOINT ON P/U PACKER. M/U 9 5/8" LINER TOP PACKER. P/U 3 1/2' JOINT WITH MULESHOE. TIH WITHPACKER AND 3 1/2"WORKSTRING. DEPTH AT 0600=2,200'. DRIFT ALL PIPE OUT OF DERRICK(HOLE TAKING 4 BBLS PER/HR). 02/03/15-Tuesday TRIP IN HOLE 9 5/8" LINER TOP PACKER ON 3 1/2"WORKSTRING TO 9,900'. SPACE OUT PLACING PACKER @ 9,950'. BROKE CIRC. DROP 1 1/4" BAR,ALLOW 10 MIN TO FALL. PRESSURED UP TO 1500 PSI,WAITED 5 MIN. PRESSURED UP TO 2500 AND 3500 PSI, HOLD 5 MIN. BLEED PRESSURE OFF,SLACK DOWN 10K AND P/U 15K.TEST BACKSIDE TO 2500 PSI FOR 30 MIN ON CHART.TEST GOOD. BLEED OFF PRESSURE. ATTEMPT TO PLACE 12 TURNS TO RIGHT WITH FOSTER TONGS. R/U POWER SWIVEL. WORK 12 ROUNDS DOWN, PACKER CAME FREE. PULL ABOVE. R/D SWIVEL. RIGGED DOWN FOSTER TONGS AND RIGGED UP Mc COY TONGS. POOH. L/D 76 JTS TBG TO MAKE ROOM TO RUN PRODUCTION TBG. CONT POOH RACKING BACK IN DERRICK. L/D TRIPOINT RUNNING TOOL.ALL CAME BACK. R/U FLOOR TO RUN TBG. P/U GATOR HAWK PIPE TESTER AND R/U Mc COY TONGS. P/U TRIPOINT SEALS AND BEGAN P/U 4 1/2" BTC L 80 11.6#POLYCORE TBG, DRIFTING SAME. WORK ON McCOY TONGS HYD.TONGS DIDN'T WANT TO BITE ON TBG.TESTING EACH CONNECTION TO 3500 PSI WITH GATOR HAWK AND 3200 TORQUE ON TBG. DEPTH AT 6 OCLOCK( 25 jts 850') 02/04/15-Wednesday CONTINUE RUNNING IN HOLE WITH 4 1/2" 11.6#L-80 BTC PRODUCTION POLYCORE TBG. CONTINUE RUNNING IN HOLE WITH 4 1/2" 11.6#L-80 BTC PRODUCTION POLYCORE TBG. TOTAL JTS 240. DEPTH 7,940'. NO FAIL CONNECTIONS TESTING WITH GATOR HAWK. 02/05/15-Thursday CONTINUE_TAI LY AND DRIFTING 4-1/2 @TC PQLYCORE 11.6#TUBING AND EXTERNAL TESTING CONNECTION TO 3500 PSI WITH GATOR HAWK. M/U PUMP IN SUB ON JOINT 319. START CIRCULATING WHILE SLACKING OFF. PRESSURE CAME UP, i1/4 .—_/A VERIFIED SEALS IN PACKER @ 9,950'. SLACK OFF SETTING 15K ON PACKER.TEST ANNULUS AND,SEALS TO 250.0 PSI AND, CHART FOR 30 MINS._TEST GOOD._ STING OUT OF PACKER AND START CLEANING PITS FOR PACKER FLUID, HAVING TO REMOVE SAND OUT OF PITS. FILL TANKS WITH FIW AND ADD CORROSION INHIBITOR. BEGIN CIRCULATING IN REVERSE FIW AND CORROSION INHIBITOR TO WELL CLEAN TANK AT 2BPM @6OPSI. FINISH CIRCULATING.TOTAL 600 BBLS. RIG DOWN LINES AND POOH L/D 3 JOINTS TO SPACEOUT. P/U PUPS AND LAND HANGER. 148,000#. PICKUP 96,000#. SLACKOFF 6,000#BLOCK WEIGHT. LOCK DOWN HANGER AND TEST ANNULUS TO 1500 PSI. RETIGHTEN TUBING SPOOL BOTTOM BOLTS, RETEST. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-22 50-733-20272-00 175-016 1/4/15 2/6/15 Daily Operations: 02/06/15-Friday HOLD JSA SAFETY MEETING W CREW. RIG UP SLICKLNE.TIH W 2"JDC AND SAT DOWN @ 9,972'. WORK THROUGH AND ATTEMPT TO LATCH BAR @ 10,042' POOH.TOOL SHEARED. RIH WITH 2" RS TOOL AND LATCH BAR @ 10,042'. POOH AND LAY DOWN BAR.TIH WITH 3" GS LATCH PLUG @ 10,047'. POOH AND R/D SLICKLINE. R/D MCCOY TONGS AND LAY OUT LANDING JOINTS.SET BACK PRESSURE VALVE. R/D RIG FLOOR. RIG DOWN BOP AND HANG OFF SAME. R/D RISER. HOLD JSA SAFETY MEETING. RIG UP TREE AND WING VALVE AND CHOKE.TEST TREE TO 5000 PSI FOR 15 MINS GOOD TEST. R/U INJECTION LINES AND HAVING TO MODIFY LINE FOR CORRECT PLACEMENT.SPOT JACKS WHILE WAITING ON WIND TO DIE DOWN 50 MPH+. CURRENTLY PREP RIG TO SKID TO G-33 WELL. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,March 02,2015 TO: Jim Regg '3/6( SUBJECT: Mechanical Integrity tyTestsP.I.Supervisor j HILCORP ALASKA LLC G-22 FROM: Jeff Jones TRADING BAY UNIT G-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supryge.._- NON-CONFIDENTIAL Comm Well Name TRADING BAY UNIT G-22 API Well Number 50-733-20272-00-00 Inspector Name: Jeff Jones Permit Number: 175-016-0 Inspection Date: 2/21/2015 Insp Num: mitJJ150226152110 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well" G-22 • Type lnj I w-ITVD 8797 - Tubing2675 2675 - 2675 _ Ij 27007 T PTD 1750160 "Type TesttSPT Test psi I 2199 - " IA I 375 2490 2490 . 2490 - 1 ] — Interval I1N TAL P/F 1 —P "11 OA I 176 f 175 i 175 175 Notes: Pretest pressures monitored for 30 minutes and stable Post work over MIT ,/ SCANNEV - .j Monday,March 02,2015 Page 1 of 1 j Z� �-ZZ 171-C L Regg, James B (DOA) From: Harold Soule - (C) <hsoule@hilcorp.com>��eelq II�3li� Sent: Friday, January 09, 2015 6:48 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: BOPE Test Report i ✓ Attachments: Moncla 301 1-8-15.xlsx; G-22 test charts 1-8-14.pdf; G-22 rollling test chart 1-7-15.pdf Harold Soule 907-776-6754 SC' .SAN 1 120 15 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to:iim.re, _ CD_alaska.gov eq AOGCC.Inspectors(a)alaska.gov G Phoebe. brooksaa.alaska. qov Contractor: Moncla Rig No.: 301 DATE: 1/8/15 Rig Rep.: Anthony Edmond Rig Phone: 776-6639 Operator: Hilcorp Op. Phone: 776-6754 Rep.: Harold Soule E -Mail hsoule@hilcorp.com Well Name: TBU G-22 PTD # 1750610 - Sundry # 314-467 Operation: Test: Test Pressure (psi): Drilling: Initial: x Rams: 250/3000 Workover: x Weekly: Annular: 250/3000 Explor.: Bi -Weekly: Valves: 250/3000-'MASP: 2570 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: NA Test Result Test Result P Quantity Test Result Location Gen. P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. NA Ball Type 2 P ' ending Order Posted P Misc. NA Inside BOP 2 P ' P P #4 Rams FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5\8" P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5 P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 31/8 P Inside Reel valves 0 NA HCR Valves 2 31/8 FP Kill Line Valves 2 31/821/16 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi) 3000 P CHOKE MANIFOLD: Pressure After Closure (psi) 1800 P Quantity Test Result 200 psi Attained (sec) 41 P No. Valves 11 P Full Pressure Attained (sec) 193 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (# and psi): 4@2200 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 2 Test Time: 9_5 _ Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: 2 failures 1) Re -tested kill & choke HCR valves (same test) 2) Later changed out choke HCR due to leak developed at stem. This test follows rolling test procedure approved in sundry 314-467 conducted prior to this test because BPV thread's bad & hanger threads would not hold pressure. Annular tested t/ 2500 psi pumping @ 15 AOGCC Inspection hr Notice Yes Date/Time 1-3-15/16:34 Test Start Date/Time Test Finish Date/Time: 1/8/2015 9:00 (date) (time) 1/8/2015 18:30 Waived By Jeff Jones Witness u�e�- An AP Form 10424 (Revised Revised 06/2014) 2015-0108_BOP_Moncla301_TBU_G=22 xsx Moncla 301 BOPE Test —1/8/15 TBU G-22 (PTD 1750610) - Hilcorp Remarks from BOPE Test Report 2 failures 1) Re -tested kill & choke HCR valves (same test) 2) Later changed out choke HCR due to leak developed at stem. This test follows rolling test procedure approved in sundry 314- — �bt IS7 467 conducted prior to this testb_ ecause BPV thread's bad & hanger threads would not hold pressure. Annular tested t/ 2500 psi pumping @ 15 gpm, pipe rams tested t/3000 psi pumping at 15 gpm using 4 1/2 TJ. Gas detection system & PVT systems tested on 1-7-15, results recorded on this form. Note test time reflects 3 1/2 hrs changing out choke HCR valve. Sort 06 ., —4000 �s X3500 IG i000 500 30 t -b- t r s . » •��oo _ _ L �. �°oo 0 •._�,� v �� `ASO f X500 :- . � t+g'00 b S ,. �u Liy�lulti 0 1NR � �• MC Mp-S0 �- T�gr 80o ONP -Coll a o a N aFF O W• aNpR�Ptac� M t� i (700 , �••�� - F ooc,2 o£ PS Y6 5 Si --w 0 09 Mv)lG (A 30 ( 7 'tom C�-zy �PNb 1750(-i0) THE STATE of -t7 GOVERNOR SEAN PARNELL Dan Taylor Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 CC'rn.S;�- r-, 7 7 a Anch iia Oil and Gas a i,'iF.-E-fC-n'. Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU G-22 Sundry Number: 314-467 Dear Mr. Taylor: West Seventh Avenue ge, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ave?9 Daniel T. Seamount, Jr. Commissioner DATED this day of August, 2014. Encl. V1ECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 14 2014 APPLICATION FOR SUNDRY APPROVALS 00 AA(` 7G ')An 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Q Pull Tubing 0 Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Return to Infection 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service (] 175-016 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20272-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No 121 Trading Bay Unit / G-22 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017594 I McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,335 9.989 10,857 9,566 10,980 10,968 Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' 2,692 psi Conductor 629' 20" 629' 629' 1,530 psi 520 psi Surface 5,548' 13-3/8" 5,548' 4,977' 3,090 psi 1,540 psi Intermediate Production 11,338' 9-5/8" 11,335' 9,984' 6,870 psi 4,750 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft)74-1'/2" ing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 12.6# / L-80 9,978 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): BOT Model "3HP" and Otis BWH Pkr 9,898' (MD) 8,753' (TVD) / 10,980' (MD) 9,674' (TVD) 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/1/2014 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ WINJ 0 GINJ ElWAG ElAbandoned E]Commission 16. Verbal Approval: Date: Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor(cb-hilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature — Phone (907) 777-8319 Date 8/14/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: y LA Plug Integrity ❑ BOP Test Q Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes No ❑ Subsequent Form Required: f — Ll / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: l /it 811911 / � Submit Form and Form 10-403 (Revised 10/2012) Apl oreRpil6a` is vapid for 12 months from the date of approval. h is i 1ic "t Ilileorp Alaska. LLI Well Prognosis Well: G-22 Date:8/14/2014 Well Name: G-22 API Number: 50-733-20272-00 Current Status: Injector Leg: 3 Estimated Start Date: September 1, 2014 Rig: NA Reg. Approval Re 'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 175-0160 First Call Engineer: Dan Taylor 907 777-8319 O 907 947-8051 M Second Call Engineer: James Young 907 777-8421 O AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary 3,500 psi @ 9,324ft TVD / 12,515ft MD 3,500 psi @ 9,324ft TVD / 12,515ft MD 2,570 psi 0.38 psi/ft at mid -pert, Survey 2006 0.38 psi/ft at mid -pert, Survey 2006 BHP - 0.1 psi/ft' TVD Grayling G-22 is an injector into both the G -Zone (G-1 thru 5) and Hemlock (Bench 1-6). This program calls for the removal of the current completion, perforating, recompleting and bringing the well back on as an injector. G-22 serves as primary support for the Steelhead well, M-34 which is currently producing +/-900bopd. Procedure: 1. Bleed off well. 2. Rig up a -line. 3. Run in hole and punch holes in tubing at +/-9,881ft a. Last tag 6/24/14 with 1.75in slick line swedge 9,337ft. b. Recent tag below tubing tail 5/18/12 at 10,825ft. c. Continuous scale build up problem. 4. Circulate down filtered inlet water to kill (round trip +/-536bbls). a. Shoot and record fluid level. 5. Set back pressure valve. 6. Nipple down tree / nipple up BOP. I ow 7. Perform BOP Test: 250psi low and 2,600p-si high. a. If back pressure valve will not set with tree on refer to attached rolling test procedure. 8. Pull hanger and lay down. 9. Rig up and run in hole with cutter to +/-9,877ft and make cut. 10. Pull out of hole laying down production tubing (dry string wt, 125klbs). 11. Pick up packer pulling tool. a. Burn over and latch packer . b. Work over fluid will be filtered inlet water unless conditions dictate otherwise. 12. Circulate bottoms up and pull out of hole. a. Close bag and spot lost circulation pill if needed. 13. Pick up 9-5/8in 47# clean out assembly. a. Trip in hole to +/-11,150ft cleaning out 9-5/8in casing. -- i. Bottom perforations located in Hemlock Bench 6. ii. Injection Survey dated 8/2007 shows 87% of injection to Hemlock Bench 2. 14. Circulate bottoms up and pull out of hole. 15. Pick up 9-5/8in test packer. a. Trip in hole to +/-10,OOOft and set. b. Test casing, hold, and chart for 30min. 16. Pull out of hole to +/-6,OOOft laying down work string. 17. Pick up storm packer. a. Trip in hole to +/-100ft, set, and test storm packer to_,I, �'p s i. S 18. Change out well head and test. �rw �-�1,�,(t /�,,r ['I, 19. Pull storm packer and lay down. 20. Pull 9-5/8in packer assembly and lay down work string. 21. Pick up tubing conveyed perforating assembly spacing out shots over the following intervals (+/-) to perforate; llileorp Alaska, LL Well Prognosis Well: G-22 Date: 8/14/2014 Zone Top (ft) Btm (ft) - Amt - SPF Date J G-1 IO,Obo 10,092 27 6 fBD G-2 10,118 10,133 15 6 TBD G-2 10,146 10,154 8 6 TBD G-2 10,162 10,174 12 6 TBD G-3 10,184 10,220 36 6 TBD G-4 10,230 10,280 50 6 TBD G-5 10,375 10,430 55 6 TBD B-1 10,584 1 10,629 1 451 6 TBD B-3 10,765 10,862 97 6 TBD B-4 10,875 10,952 77 6 TBD 22. Pick up mule shoe, nipple, 9-5/8in completion packer and 4-1/2in lined tubing and trip in hole. 23. Set completion packer at +/-9,950ft. 24. Land hanger and test. �, a , - I= A 10 T__ it911- P 5- l 25. Turn well over to production. 26. Perform Mechanical Integrity Test. , —1 `' ' l y Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. Rolling BOP Test Procedure 4. Well Head Diagram 5. Proposed Well Head Diagram RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# 1 19 20" 94 8 61 & 68 9-5/8" 2 B-5 47 3 B-6 4 a ---w C(; Top of Junk @ 11,254' CASING AND TUBING DETAIL 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) G-1 MD MD 5 GRADE G-2 Sand Fill on PXN plug G-3 G-4 G-5 B-1 B-2 B-2 B-3 B-4 RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.59 A 4200' G-22 Schematic 2008-05-12 26" 19 20" 94 8 61 & 68 9-5/8" 47 B-5 47 9-5/8" B-6 9897' a ---w C(; Top of Junk @ 11,254' RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.59 A 4200' G-22 Schematic 2008-05-12 26" 1" wall 20" 94 13-3/8" 61 & 68 9-5/8" 47 9-5/8" 47 9-5/8" 47 Tubing: 4-1/2" 12.6 1180 Imp. Butt 3.958 40.6' 9978' 8746' NO. Depth JEWELRY DETAIL ID Item tding Bay Unit 40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt Btm .. ell # G-22 SPF x 4-1/2" EUE top 1 9897' Actual Completion (11/98) CASING AND TUBING DETAIL 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) 3 MD MD TVD GRADE CONN ID TOP BTM. BTM 5 9978' 24.0 Surf. 356' 356' 10,968' Butt 19.124 Surf. 629' 629' H40 Butt 12.415 Surf. 5548' 4977 N-80 Butt 8.681 Surf 7016' 6231' P-110 Butt 8.681 7016 10,087' 8915' S-95 Butt 8.681 10,087' 11,335' 9984' 1180 Imp. Butt 3.958 40.6' 9978' 8746' NO. Depth JEWELRY DETAIL ID Item PERFORATION DATA 40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt Btm Amt SPF x 4-1/2" EUE top 1 9897' 3.958" Baker Anchor Tubing Seal Assy. (P/N45140-9999) 2 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) 3 9903' 4.820" Baker 5.22' Millout Ext. (P/N 995-09-9999) 4 9945' 3.813" Baker "X" Nipple (P/N 995--08-9999) 5 9978' 3.958" Baker Ball Seat Sub (P/N 469-21-999) 6 10,968' 4.0" Otis `BWH" Perm Pkr (10,961' DIL) 7 10,980' i 2.635" 3-1/2" Otis "XN" Nipple, w/ 2.75" PXN plug 8 10,981.55' 2.99" WLREG REVISED: 5/12/08 DRAWN BY: BCA PERFORATION DATA Zone Top Btm Amt SPF Date Present Condition G-1 10061' 10095' 34' 4 11/19/89 Open for Injection G-2 10122' 10137'(DIL) G-2 10115' 10154' 39' 4 11/19/89 Open for Injection G-3 10178' 10218' 40' 4 11/19/89 Open for Injection G-3 10190' 10220' (DIL) 30' 4 5/4/08 Open for Injection G-4 10230' 10300' 70' 4 11/19/89 Open for Injection G-5 10370' 10430' 60' 4 11/19/89 Open for Injection G-5 10590' 10592' 2' 4 6/24/75 Sqz for Isolation B-1 10595' 10629' 34' 6/4 11/16/89 Open for Injection B-2 10643' 10734' 91' 20/8/4 11/16/89 Open for Injection B-2 10742' 10752' 10' 4 11/16/89 Open for Injection B-3 10762' 10815 53' 16/4 11/16/89 Open for Injection B-4 10827' 10952' 125' 16/12/8 11/16/89 Open for Injection B-5 10984' 11022' 38' 4 7/4/75 Isolated B-5 11081' 11082' 1' 4 6/22/75 Sqz for Isolation B-6 11115' 11145' 30' 4 7/3/75 Isolated G-5 10,375' 10430' 55' 6 9/10/98 Open for Injection G-4 10230' 10280' 50' 6 9/11/98 Open for Injection G-3 10190' 10220' 30' 6 9/11/98 Open for Injection G-2 10118' 10133' 15' 6 9/11/98 Open for Injection G-1 10065' 10092' 27' 6 9/11/98 Open for Injection REVISED: 5/12/08 DRAWN BY: BCA PROPOSED Well: ing Bay Unit Well: G-22 IIi1corpAlaeka,LLC As Completed: 11/1998 RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# G-1 G-2 G-3 c G-4 G-5 B-1 B-2 B-2 B-3 B-4 B-5 B-6 Top of Junk @ 11,254' RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.51 @ 4200' CASING AND TUBING CSG Wt (Ib/ft) Grade Conn ID (in) (Mp) Btm (MD) 26in (lin wall) 2 ±10,090 2.813 24 0 356 20in 94 G-1 Butt 19.124 0 629 13-3/8in 61 & 68 H-40 Butt 12.415 0 5,548 9-5/8in 47 N-80 Butt 8.681 0 7,016 9-5/8in 47 P-110 Butt 8.681 7,016 10,087 9-5/8in 47 S-95 Butt 8.681 10,087 11,335 Tubing: 11/19/1989 Open for Injection G-2 10,118' 10,133' 8,939' 4-1/2in 11.6 L-80 TPL4040 3.75 1 41 1±10,130' IFWFIRY DFTAII No. Depth (ft) ID (in) Item 41 3.958 Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt x 4-1/2" EUE top 1 ± 9,950 4.000 Hydraulic Pkr. 2 ±10,090 2.813 3-1/2" Otis "XN" Nipple, w/ 3.5" PXN plug 3 ±10,130 1 3.958 1 WLREG REVISED: 08/14/14 DRAWN BY: DRT PERFORATION DETAIL Zone Top (MD) Btm (MD) TOP (TVD) Btm (TVD) Amt SPF Date Status G-1 10,061' 10,095' 8,891' 8,919' 34' 4 11/19/1989 Open for Injection G-1 10,065' 10,092' 8,894' 8,917' 27' 6 9/11/1998 Open for Injection G-1 ±10,065' ±10,092' ±8894 ±8917 27' Future G-2 10,115' 10,154' 8,936' 1 8,969' 39' 1 4 11/19/1989 Open for Injection G-2 10,118' 10,133' 8,939' 8,951' 15' 6 9/11/1998 Open for Injection G-2 ±10,118' ±10,133' ±8939 ±8951 15' Future G-2 10,122' 10,137' 8,942' 8,954' G-2 ±10,146 ±10,154 ±8,962 ±8,969 8 Future G-2 ±10,162 ±10,174 ±8,975 ±8,985 12' Future G-3 10,178' 10,218' 81989' 9,022' 40' 4 11/19/1989 Open for Injection G-3 ±10,184 ±10,220 ±8,994 ±9,024 36' Future G-3 10,190' 10,220' 8,999' 9,024' 30' 6 9/11/1998 Open for Injection G-3 10,190' 10'220' (OIL) 8,999' 9,024' 30' 4 5/4/08 Open for Injection G-4 10,230' 10,280' 9,032' 9,074' 50' 6 9/11/1998 Open for Injection G-4 ±10,230' ±10,280' ±9032 ±9074 50' Future G-4 10,230' 10,300' 9,032' 9,091' 70' 4 11/19/1989 Open for Injection G-5 10,370' 10,430' 9,149' 9,199' 60' 4 11/19/1989 Open for Injection G-5 10,375' 10,430' 9,153' 9,199' 55' 6 9/10/1998 Open for Injection G-5 ±10,375' ±10,430' ±9,153 ±9,199 55' Future HK -1 ±10,584 ±10,629 ±9,330 ±9,368 45' Future G-5 10,590' 10,592' 9,335' 9,337' 2' 4 6/24/1975 Sqz for Isolation B-1 10,595' 10,629' 9,339' 9,368' 34' 4 11/16/1989 Open for Injection B-2 10,643' 10,734' 9,380' 9,459' 91' 1 20/8/4 11/16/1989 Open for Injection B-2 10,742' 10,752' 9,466' 9,475' 10' 4 11/16/1989 Open for Injection B-3 10,762' 10,815' 9,483' 9,529' 53' 16/4 11/16/1989 Open for Injection HK -3 ±10,765 ±10,862 ±9,486 ±9,414 97' Future B-4 10,827' 10,952' 9,540' 9,649' 125' 16/12/8 11/16/89 Open for Injection HK -4 ±10,875 ±10,952 ±9,582 ±9,649 77' Future B-5 10,984' 11,022' 9,678' 9,711' 38' 4 7/4/1975 isolated B-5 11,081' 11,082' 9,763' 9,764' 1' 4 6/22/1975 Sqz for Isolation B-6 11,115' 11,145' 9,794' 9,820' 30' 4 1 7/3/1975 Isolated REVISED: 08/14/14 DRAWN BY: DRT Hilrnrp Alaeka, LL(; Grayling 22 20 X 13 3/8 X 9 5/8 X 4 1/2 Valve, swab,Barton, 4 1/16 5M FE, HWO, T-24 Tee, stdd, 4 1/16 5M X 4 1/16 5M Valve, master, WKM-M, 4 1 i1 R F^^ FE, HWO, Test good 250/5000psi 2/15/2.012 Tubing head, CIW- 135/83MX1151' 2- 2 1/16 5M SSC C bottom prep w/ R 1 '/z VR profile Casing spool, CIW-' 21 % 2MX135/8; w/ 2- 2 1/16 5M EF PP bottom prep Casing head, CIW-V 21'Y42MX20"SO1 bottom, w/ 2- 2 1/16 EFO Grayl►..6 Platform G-22 Current 02/15/2012 BHTA, CIW, 4 1/16 5M FE X Internal Acme knockup C4%t�" Tubing hanger, CIW- DCB, 11 X 4'/z EUE 8rd lift and 4'/2 IBT susp, w/ 4" type H BPV profile, 7" EN, ''/4" non continuous control line V-FBB, 11 5M iM, prepped for I neck, 1/2npt line port alve, CIW-FC, 2 1/16 5M FE, HWO, AA ;t good 2/15/2012 250/2500psi Test good 2/15/2012 — 250/1000psi .P ball valve Hilrnrp A14t■ka,1.1.4; Grayling 22 20X133/8X95/8 X 41/2 BHTA, Bowen, 4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, FF trim Valve, Master, WKM-M, 4 1/16 5M FE, HWO, FF trim u s>� Tubing head, S-8, 13 5/8 3M Iw— x 11 5M, w/ 2- 2 1/16 5M �QSSO, w/ BG bottom w/ 1- 2 1/16 5M WKM-M valves Casing spool, CIW-WF, 21X 2MX135/83M, w/ 2- 2 1/16 5M EFO, PP bottom prep Casing head, CIW-WF, 21 Y4 2M X 20" SOW bottom, w/ 2- 2 1/16 2M EFO s 00 • Grayli..g Platform G-22 Proposed Inj 08/14/2014 Tubing hanger, SME -CL, 11 X 4 % EUE lift and 4 %= TC -2 susp, w/ 4" Type H BPV profile, 2- 3/8 CCL, 6 A extended neck, 17-4PH stainless steel Valve, Wing, WKM-M, 3 1/8 5M FE, w/ 15" Safeco operator, FF trim Full Stainless Steel Adapter, Seaboard, it 5M FE X 4 1/16 5M, w/ 6 Y. pocket, 2- Y: CCL exits, Full Stainless Steel 2"LP ball valve Al, 2 7/8 5 Rams I ileorp Alaska. LLC. Attachment #1 Moncla 301 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. Contact Mr. Guy Schwartz and Mr. Jim Regg with the AOGCC prior to rolling test. AOGCC may elect to send inspector. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) Hileorp Alaska, LIX Moncla 301 BOP Test Procedure Attachment #1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. James B (DOA) From: Wallace, Chris D (DOA) Sent: Monday, August 11, 2014 8:31 AM To: 'Larry Greenstein' Subject: RE: Request for G-22 (PTD #1750160) AA (AIO 5.006) compliance extension - Approval Larry, Thank you for providing the additional information and evaluation. We are able to APPROVE the request of the continued injection and extension of the MIT/Temp survey requirements until the anticipated well workover or until December 31, 2014. No Admin Approval or order amendment is required at this point. Please keep this authorization for your records and we will do the same. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue SCANNED Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient (s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Wednesday, August 06, 2014 2:23 PM To: Wallace, Chris D (DOA) Subject: FW: Request for G-22 (PTD #1750160) AA (AIO 5.006) compliance extension Good talking with you, Chris. Here is the WSR I mentioned - all the runs were made on 6/24 & 6/25/14. With the OD of the temp tool at 1 11/16", we normally use a 2" GR (or in this case a 2.25" GR) to verify we won't stick the tool in the well. When the 2.25" GR didn't make it deep enough, we tried a 2" GR and finally a 1.75" swedge which both got deeper, but still not deep enough. Even the POOH of the 1.75" swedge was not a smooth retrieval as the tool got stuck overnight @ -9337 RKB. The risk of running the temp tool and getting it stuck became too great at that point which is why we are asking for a variance on the timing of this temp survey. Thank you Larry From: Larry Greenstein Sent: Tuesday, August 05, 2014 3:23 PM To: Chris Wallace @ AOGCC Subject: Request for G-22 (PTD #1750160) AA (AIO 5.006) compliance extension Hi Chris, We're going to have a timing problem with one of our important AA wells on the Grayling platform. We would like to see if we can continue to inject for up to 3 months after the anniversary date of the AA which would give us time to get the WO rig on this well and regain the mechanical integrity. The G-22 waterflood well provides critical pressure support to the recently completed M-34 ESP well on the Steelhead (-900 bopd). The anniversary date for the G-22 two year compliance temp survey is next month on the 14th of September. Because the WO rig will be on that leg at that time, we tried to get our temp survey done ahead of time. We were unable to get a gauge ring deep enough in the well (- 9800' MD) to allow the temp survey to prove where the water is being injected. Normally this would mean that the G-22 well would have to be shut-in by the 9/14 anniversary date, but we are asking for some extra injection time. The G-22 well is on the schedule for a WO before the end of the year as the rig will be on that leg and this well and others are already budgeted. We would like to keep water going into the ground up until we shut the well in for its WO to provide as much pressure support to M-34 as possible. This extra injection doesn't pose any additional stress to the overall integrity of the well. We have previous temp surveys that don't show any issues and the monthly reporting on this well doesn't show any anomalies indicative of a secondary loss of integrity. To continue injection for up to 3 months past the anniversary date until this well can be fixed seems very low risk.. To put it simply, we would like permission to continue injection into the G-22 well until mid-December as we fully expect to have the well shut-in before then as part of its WO to reestablish mechanical integrity. As we expect to get the G-22 WO done this year, a 'sunset clause' built into any kind of extension would be understandable. We are preparing the 10-403 for this WO currently and you should be seeing it very soon. What do you think Chris?? We did a similar thing for K-22 a few years ago, when we couldn't get the temp survey run deep enough, and put a 'shut-in or fix' date in the approval to keep a limit on the extra injection time while maintaining the monthly reporting requirements. Larry UNOCALO RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# 1 PERFORATION DATA Trading Bay Unit me Top 2 Amt Well # G-22 3 Present Condition 4 10061' Actual Completion (11/98) 34' 4 CASING AND TUBING DETAIL Open for Injection G-1 10122' 5 MD MD TVD G-2 G-3 G-4 G-5 B-1 B-2 Sand Fill on B-2 PXN plug B-3 B-4 VA 8 6 B-5 B-6 Top of Junk x-1'1 f @ 11,254' RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.59 (til 4200' G-22 Schematic 2008-05-12.doc REVISED: 5/12/08 DRAWN BY: BCA PERFORATION DATA Trading Bay Unit me Top Btm Amt Well # G-22 Date Present Condition 1 10061' Actual Completion (11/98) 34' 4 CASING AND TUBING DETAIL Open for Injection 2 10122' 10137'(DIL) MD MD TVD SIZE WT GRADE CONN 2 II) TOP BTM. BTNI 26" 1"wall 4 11/19/89 24.0 Surf. 356' 356' 20" 94 Butt 4 19.124 Surf. 629' 629' 13-3/8" 61 & 68 H-40 Butt 30' 12.415 Surf. 5548' 4977 9-5/8" 47 N-80 Butt 10300' 8.681 Surf 7016' 6231' 9-5/8" 47 P-110 Butt 10370' 8.681 7016 10,087' 8915' 9-5/8" 47 S-95 Butt 5 8.681 10,087' 11,335' 9984' Tubing: 4 6/24/75 Sqz for Isolation 1 10595' 4-1/2" 12.6 L-80 Imp. Butt 11/16/89 3.958 40.6' 9978' 8746' 10643' 10734' AB Mod 20/8/4 11/16/89 Open for Injection 2 10742' 10752' 10' 4 11/16/89 Open for Injection 3 10762' JEWELRY DETAIL 53' 16/4 NO. Dentb ID Item 10952' 125' 40.60' 3.958" Cameron DCB 4-112" Tubing hanger. 4-1/2" Butt 5 10984' 11022' 38' 4 x 4-1/2" EUE top Isolated 1 9897' 3.958" Baker Anchor Tubing Seal Assy.(P/N451-40-9999) 4 2 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) 11145' 3 9903' 4.820" Baker 5.22' Millout xt.(P/N 995--09-9999) 5 4 9945' 3.813" Baker "X" Nipple ( 995--08-9999) 9/10/98 5 9978' 3.958" Baker Ball Seat Sub P/N 469-21-999) 50' 6 10,968' 4.0" Otis `BVH" Perm Pkr (10,961' DIL) 10190' 7 10,980' 2.635" 3-1/2" Otis "XN" Nipple, w/ 2.75" PXN plug Open for Injection 8 .10,981.55' 2.99" WLREG REVISED: 5/12/08 DRAWN BY: BCA PERFORATION DATA me Top Btm Amt SPF Date Present Condition 1 10061' 10095' 34' 4 11/19/89 Open for Injection 2 10122' 10137'(DIL) 2 10115' 10154' 39' 4 11/19/89 Open for Injection 3 10178' 10218' 40' 4 11/19/89 Open for Injection 3 10190' 10220' (DIL) 30' 4 5/4/08 Open for Injection 4 10230' 10300' 70' 4 11/19/89 Open for Injection 5 10370' 10430' 60' 4 11/19/89 Open for Injection 5 10590' 10592' 2' 4 6/24/75 Sqz for Isolation 1 10595' 10629' 34' 6/4 11/16/89 Open for Injection 2 10643' 10734' 91' 20/8/4 11/16/89 Open for Injection 2 10742' 10752' 10' 4 11/16/89 Open for Injection 3 10762' 10815 53' 16/4 11/16/89 Open for Injection 4 10827' 10952' 125' 16/12/8 11/16/89 Open for Injection 5 10984' 11022' 38' 4 7/4/75 Isolated 5 11081' 11082' 1' 4 6/22/75 Sqz for Isolation 6 11115' 11145' 30' 4 7/3/75 Isolated 5 10,375' 10430' 55' 6 9/10/98 Open for Injection 4 10230' 10280' 50' 6 9/11/98 Open for Injection 3 10190' 10220' 30' 6 9/11/98 Open for Injection 2 10118' 10133' 15' 6 9/11/98 Open for Injection 1 10065' 10092' 27' 6 9/11/98 Open for Injection REVISED: 5/12/08 DRAWN BY: BCA HILCORP ALASKA WELL SERVICE REPORT Date: Work being done: Supervisor: Wireline Unit Number: Tree Connection Size/Type Tree condition Fluid Level if Identified Zero Wireline at: Minimum Tubing ID: Start Tbg. & Csg. PSI 6/24/2014 Well Number: Location: AFE# / Charge Code: Pollard Wireline Crew: Total Wireline Miles: Wire Test: Max Depth (KB): Well KB: Max Tool OD: Ending Tbg & Csg PSI G-22 MIT GRAYLING ZACH ROLPH C014719 DOLLY wiLL. ERNEST. CODY B 4 1/2 INT 11 GOOD NA UKNOWN 9817' T. HANGER 40 2.75" 2.25" 0-0 0-0 Time Operation Details W/L valve GOOD 4:30 ARRIVE AT PWL SHOP - PICK UP TOOLS AND CREW 5:30 STAND BY FOR CHOPPER TO GRAYLING 6:15 FLY TO GRAYLING - SAFETY MEETING W/ PRODUCTION - MOVE EQUIP - RIG UP 8:45 PRESS TEST - GOOD 9:00 RIH W/ 2.25" G. RING TO 7922'KB - SET DOWN - WORK TOOLS - FALL THRUOGH TO 7951'KB WORK TO 7953'KB - FALL TO 7981'KB - W/T - TOOLS STICKING - POOH -SCALE IN G. RING 10:00 RIH W/ 2" G. RING TO 7985'KB - SET DOWN - WORK TOOLS FOR 20 MIN - CANT FALL THROUGH - POOH - OOH W/ G. RING - HAS CURVED MARK ON BOTTOM EDGE 12:15 RIH W/ 2.25" LIB TO 7925'KB TAG - HIT ONE TIME POOH - OOH W/ NO IMPRESSION 13:15 RIH W/ 2" LIB TO 7985'KB TAG - HIT 1 TIME - POOH OOH W/ MARK ON BOTTOM EDGE LOOKS LIKE PARTED TUBING - STAND BY FOR INSTRUCTIONS FROM TOWN 16:45 LAY DOWN FOR DRILLING TO USE CRANE - C/O TO 1.5" TOOL STRING - RIG UP 17:30 RIH W/ 1.75" SWEDGE TO 7985'KB - HIT ONE TIME - FALL THROUGH WORK TOOLS UP AND DOWN - ABBLE TO MAKE HOLE - WOULD SET DOWN AND HANG UP IN VERIOUS SPOTS BUT STILL MAKING HOLE - WORK DOWN TO 9817'KB - SET DOWN - CANT PASS - POOH HANG UP AT 9337'KB - CAN FALL DOWN HOLE - CANT GET UP PAST 9337'KB - WORK FOR 1 HOUR - TALK W/ SUPERVISER - GET CUTER BARS TO HELIPORT - CONT TO WORK TOOLS UP TO 2000# - 10:45 TOOLS CAME FREE - SLOWLY MOVING AT 1700 TO 2000# TO 7985'KB - WEIGHT CAME DOWN TO 900# - POOH - OOH W/ SW EDGE 11:30 JOOH - LAY DOWN - SECURE WELL FOR NIGHT Work String Detail:1.75" Size and Length TS- RS STEM STEM KJ OJ SJ 6" 5' 5' 8" 3' 7' Description of any NONE tools or debris left in the hole: Brief Summary of TRY TO GUAGE TUBING - HUNG UP - WORK FREE Total Work Completed otal Hours Worked 1 19 1 Total Tool Cost $ 392.00 1 Total Hour Costj $ 5,255.00 Ticket # :I Daily Cost: P-6599 Day #: Cumulative Cost: 1 $ 5,647.00 Well Downtime Hr. Shut in NA H2S PPM 0 Approved by: Zach Rolph Code: C014719 2500 1121 1500 - 500- A -J 00 0-J 08/2013 TBU G 022 - [50.0596.0082] 11/2013 02/2014 05/2014 Tubing — 9 5/8 133/8 20 — 26 — Water Injection 9000 X000 »000 3000 2000 1000 0 08/2014 Regg, James B (DOA) From: Larry Greenstein [Igreenstein@hilcorp.com] Sent: Tuesday, May 29, 2012 10:38 AM To: Regg, James B (DOA) Subject: Compliance Temp Survey G-22 (PTD # 1750160) Attachments: G-22 Schematic 5-12-08.doc; G-22 Temp Survey 5-18-12 vs 4-26-07.xls Hi Jim, Sorry for the delay in getting the temp survey completed, but we finally got room for the wireline unit to rig up. Well G-22 (PTD 175-016) was granted Administrative Approval (AIO 5.006) on September 14, 2005. As required under the approval, a compliance temperature survey was run on 5-18-12. The survey (see attached) confirms that all injected fluids are being contained within the zones of injection. Per the monthly TIO plots, there isn't any indication of a loss of integrity in any of the other casings strings in this well. I would be glad to discuss the nuances of this temp survey as there is some room for <: interpretation in the 8000' - 9500' area. For your review is a temperature shifted overlay and a close up of the area open for discussion. Our feeling is that, although smoothed out in the current plot, the cooling dip in this area was indicated in the earlier temp survey and does not demonstrate a change in the containment of the injected fluids. Clearly the injected fluids are entering the perfs as indicated in the large cooling kick starting at 10000'. With this well scheduled for a WO in March/April of 2013, we are asking to continue to inject into this well as is and use the daily monitoring and monthly reporting to maintain surveillance for a loss of fluid containment downhole. Larry -----Original Message ----- From: Larry Greenstein Sent: Wednesday, May 02, 2012 2:59 PM To: 'Regg, James B (DOA)' Subject: RE: FW: TBU G-22 (PTD # 1750160) - Hi Jim, Sorry, it's been crazy around here today. Talked with the field folks about G-22 this afternoon. The Grayling had already started, what they are calling, the Derrick Down program. It will hit a bunch of the platforms in turn, but they started on the Grayling almost 2-3 weeks ago. While this program is going on, they are physically unable to rig up on G-22 to get the temp survey. It appears it will be about 2 more weeks before they will have that area clear enough to get wireline on at well. That means almost 7 weeks of injection will have occurred before we would e able to shut-in this well and get the temp survey. I'm sorry to report this, Grayling wasn't the first platform planned to start the Derrick Down program (the King was), but they changed the order for other reasons. 1 Hilcorp Well: Field: Date: 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Pressure-Temceratune Profile 1. RIH Overlay, 2007 vs a shifted 2012 2. Well Shut-in 5-66-1 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 Temperature (Deg. F) 5-18-12 Pressure - Perfs RKB 25' 20 13-318" 9-518" TBG 5-18-12 Temp -Shifted 4-26-07 Temp qw-- Reort date: 6/7/2012 Hilcor Well: JGFieldIGr Date: Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Q 5000 v�- 5500 CL d 6000 Q 6500 7000 7500 8000 8500 9000 9500 100000 10500 11nnn Pressure -Temperature Profile 1. RIr verlay, J7 v 2. Well Shut-in 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 Temperature (Deg. F) 5-18-12 Pressure Perfs RKB 26" 20"-13-318" 9-5/8" TBG 5-18-12 Temp 4-26-07 Temp RR rt date: 6/7/2012 0 7000 7500 8000 ,.� 8500 CL 9000 9500 10000 10500 Well: I I Field: I Date: Pressure (psis) 500 1000 1500 2000 2500 3000 3500 4000 4500 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 Temperature (Deg. F) 5-18-12 Pressure — Perfs RKB 26" - 20" 131w 9-5/8" TBG 5-18-12 Temp -Shifted 4-26-07 Temp R-14- f� date: 6/7/2012 1 Pressure -Temperature Profile 1. RIH Overlay, 2007 vs a shifted 2012 2. Well Shut-in i I 4-Z6t7 > 5- f,A7- t t I 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 Temperature (Deg. F) 5-18-12 Pressure — Perfs RKB 26" - 20" 131w 9-5/8" TBG 5-18-12 Temp -Shifted 4-26-07 Temp R-14- f� date: 6/7/2012 RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# 1 3 4 5 G-1 100(911,0- G-2 G-3 G-4 G-5 NO. Death JEWELRY DETAIL ID Item 40.60' Trading Bay Unit Well # G-22 Actual Completion (11/98) Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt CASING AND TUBING DETAIL Zone x 4-I/2" EUE top 1 9897' 3.958" Baker Anchor Tubing Seal Assy.(P/N451-40-9999) MD MD TVD SIZE WT GRADE CONN ID TOP BTM. BTM 26" 1" wall Baker"X" Nipple (P/N 995--08-9999) 5 24.0 Surf. 356' 356' 20" 94 4.0" Butt 19.124 Surf. 629' 629' 13-3/8" 61 &68 H-40 Butt 12.415 Surf. 5548' 4977 9-5/8" 47 N-80 Butt 8.681 Surf 7016' 6231' 9-5/8" 47 P-110 Butt 8.681 7016 10,087' 8915' 9-5/8" 47 S-95 Butt 8.681 10,087' 11,335' 9984' Tubing: 4 11/19/89 Open for Injection 3 G-5 4-1/2' 12.6 L-80 Imp. Butt 3.958 40.6' 9978' 8746' B-4 G-5 10590' AB Mod 2' 4 6/24/75 G-1 100(911,0- G-2 G-3 G-4 G-5 NO. Death JEWELRY DETAIL ID Item 40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt Zone x 4-I/2" EUE top 1 9897' 3.958" Baker Anchor Tubing Seal Assy.(P/N451-40-9999) 2 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) 3 9903' 4.820" Baker 5.22' Millout Ext. (P/N 995--09-9999) 4 9945' 3.813" Baker"X" Nipple (P/N 995--08-9999) 5 9978' 3.958" Baker Ball Seat Sub (P/N 469-21-999) 6 10,968' 4.0" Otis `BWH" Penn Pkr (10,961' DIL) 7 10,980' 2.635" 3-1/2" Otis "XN" Nipple, w/ 2.75" PXN plug 8 10,981.55' 2.99" WLREG RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.59 (a) 4200' G-22 Schematic 5-12-08 REVISED: 5/12/08 DRAWN BY: BCA PERFORATION DATA I Zone Top Btm Amt SPF Date Present Condition G-1 10061' 10095' 34' 4 11/19/89 Open for Injection G-2 10122' 10137'(DIL) B-1 G-2 10115' 10154' 39' 4 11/19/89 Open for Injection B-2 G-3 10178' 10218' 40' 4 11/19/89 Open for Injection Sand Fill on B-2 G-3 10190' 10220' (DIL) 30' 4 5/4/08 Open for Injection PXN plugB G-4 10230' 10300' 70' 4 11/19/89 Open for Injection 3 G-5 10370' 10430' 60' 4 11/19/89 Open for Injection B-4 G-5 10590' 10592' 2' 4 6/24/75 Sqz for Isolation B-1 10595' 10629' 34' 6/4 11/16/89 Open for Injection B-2 10643' 10734' 91' 20/8/4 11/16/89 Open for Injection 17r6 86AC&5 B-2 10742' 10752' 10' 4 11/16/89 Open for Injection B-3 10762' 10815 53' 16/4 11/16/89 Open for Injection 1Zi0o�- t;lam', B-4 10827' 10952' 125' 16/12/8 11/16/89 Open for Injection 8 ��[cye�� B-5 10984' 11022' 38' 4 7/4/75 Isolated 30o s B-5 11081' 11082' 1' 4 6/22/75 Sqz for Isolation B-5 B-6 11115' 11145' 30' 4 7/3/75 Isolated G-5 10,375' 10430' 55' 6 9/10/98 Open for Injection G-4 10230' 10280' 50' 6 9/11/98 Open for Injection B-6 G-3 10190' 10220' 30' 6 9/11/98 Open for Injection yj Top of Junk g 11 254 G-2 10118' 10133' 15' 6 9/11/98 Open for Injection G-1 10065' 10092' 27' 6 9/11/98 Open for Injection RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.59 (a) 4200' G-22 Schematic 5-12-08 REVISED: 5/12/08 DRAWN BY: BCA • iii - zz PT 7 !f ® 7 � Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Wednesday, May 02, 2012 5:54 PM !� SI iv To: Regg, James B (DOA)C/� �- Subject: RE: FW: TBU G -22 (PTD # 1750160)-Update ( l Attachments: Master Well List TIO Report 2012 05 01.xis Thanks Jim. We'll get this done as soon as possible. I've started to prepare the monthly TIO plots, so I'll get the group that includes the G -22 well done first. Everything is looking proper with the well on the plot. Here's the G -22 well's plot. There may be other Derrick Down conflicts this summer, so I'll dig into those possibilities when I get some breathing room over here. Larry Original Message From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 02, 2012 3:43 PM To: Larry Greenstein Subject: RE: FW: TBU G -22 (PTD # 1750160) - Update We'll wait this one out since it would not make much sense shutting in now. Unless you are ready to submit the monthly TIO pressures report for waivered injectors, please send data & plot for TBU G -22. Guess someone should check schedules of MITs and SVS to make sure there are no looming conflicts created by the Derrick Down program. Jim Regg AOGCC JUN 0 6' 2OIL D 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 r` 907 - 793 - 1236 Original Message From: Larry Greenstein [ mailto :lgreenstein @tiilcorp.com] Sent: Wednesday, May 02, 2012 2:59 PM ,` To: Regg, James B (DOA) Subject: RE: FW: TBU G -22 (PTD # 1759160) - Update Hi Jim, Sorry, it's been crazy around here today. Talked with the field folks about G -22 this afternoon. The Grayling had already started, what they are calling, the Derrick Down program. It will hit a bunch of the platforms in turn, but they started on the Grayling almost 2 -3 weeks ago. While this prow/6m is going on, they are physically unable to rig up on 1 • • • 175t. G R*6 slz( Plot Pressure & Rate vs Time - Well G-22 - 10000 2500 - 9000 -9 5/8" 13 3/8" 0" -20 r - 8000 26" 41111•■ Tubing 2000 •■••.yol 7000 - 6000 v. 1500 - = 1/1 n - 5000 a 11.) co - 4000 1000 - 3000 2000 500 1000 0 OA c C 7 3 co 8 co 0.1 CO CD CO - izic‘j Regg, James B (DOA) 01'�) 17S CA- ,, From: Regg, James B (DOA) Sent: Wednesday, May 02, 2012 3:43 PM�— To: 'Larry Greenstein' l Subject: RE: FW: TBU G-22 (PTD # 1750160) - Update We'll wait this one out since it would not make much sense shutting in now. Unless you are ready to submit the monthly TIO pressures report for waivered injectors, please send data & plot for TBU G-22. Guess someone should check schedules of MITs and SVS to make sure there are no looming conflicts created by the Derrick Down program. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message ----- From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Wednesday, May 02, 2012 2:59 PM To: Regg, James B (DOA) Subject: RE: FW: TBU G-22 (PTD # 1750160) - Update Hi Jim, Sorry, it's been crazy around here today. Talked with the field folks about G-22 this afternoon. The Grayling had already started, what they are calling, the Derrick Down program. It will hit a bunch of the platforms in turn, but they started on the Grayling almost 2-3 weeks ago. While this program is going on, they are physically unable to rig up on G-22 to get the temp survey. It appears it will be about 2 more weeks before they will have that area clear enough to get wireline on that well. That means almost 7 weeks of injection will have occurred before we would be able to shut-in this well and get the temp survey. I'm sorry to report this, Grayling wasn't the first platform planned to start the Derrick Down program (the King was), but they changed the order for other reasons. If you need, we will shut-in this well until we have a better window to get the temp survey done. Otherwise, I'd suggest we continue with the injection and then shut-in for the survey at the earliest possible time. Leave the well shut-in until we analyze and review the overlay surveys with you and make the RTI decision at that point. That is where we stand today, Jim. I was hoping we'd have the temp survey by now, but the Derrick Down program caught us on this well. Larry -----Original Message ----- From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] 1 Sent: Wednesday, May 02, 2012 11:16 AM To: Larry Greenstein Subject: RE: FW: TBU G-22 (PTD # 1750160) - Update Could you give me a status update of injection and temp survey for G-22? Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message ---- From: Regg, James B (DOA) Sent: Wednesday, March 28, 2012 4:14 PM To: Larry Greenstein Subject: RE: FW: TBU G-22 (PTD # 1750160) - Update Larry - I am going to hold off responding to the original TBU G-22 request dated 7/27/2009 (put on injection without performing temp survey; continue to inject as long as no deviation from monitored TIO pressures trends). , Appropriate action will be completed once Hilcorp completes run 'ng the required temp survey 7 in April and results have been evaluated. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message ----- From: Regg, James B (DOA) / Sent: Monday, March 26, 2012 1:54 PM To: Larry Greenstein Subject: Re: FW: TBU G-22 (PTD # 1750160) - Update Thanks. Good news regarding G-22. I got your voice message too. Temp survey for G-22 is an acceptable approach. I'll call you tomorrow afternoon to further discuss injector mechanical integrity issues. Larry Greenstein <lgreenstein@hilcorp.com> wrote: Hope you enjoyed your 3 day weekend. /I left you a voice mail about this well, Jim. In planning our CTU work for theayling, we wanted a sample of what was blocking the tubing and preventing us from getting a emp survey on G-22. In running the bailer, the crew was making headway down the tubing, so they continued. After the better part of a day, they broke through the blockage and, after one more bridge, were able to make it out the tubing tail. 2 Regg, James B (DOA) From: Regg, James B (DOA) <? *e/, , Sent: Wednesday, March 28, 2012 4:14 PM To: Larry Greenstein Subject: RE: FW: TBU G-22 (PTD # 1750160) - Update Larry - I am going to hold off responding to the original TBU G-22 request dated 7/27/2009 (put on injection without performing temp survey; continue to inject as long as no deviation from monitored TIO pressures trends). Appropriate action will be completed once Hilcorp completes running the required temp survey in April and results have been evaluated. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message ----- From: Regg, James B (DOA) Sent: Monday, March 26, 2012 1:54 PM To: Larry Greenstein Subject: Re: FW: TBU G-22 (PTD # 1750160) - Update Thanks. Good news regarding G-22. I got your voice me age too. Temp survey for G-22 is an acceptable approach. I'll call you tomorrow after no to further discuss injector mechanical integrity issues. Larry Greenstein <lgreenstein@hilcorp.com> wrot,E�: Hope you enjoyed your 3 day weekend. I lef// you a voice mail about this well, Jim. In planning our CTU work for the Graylin ', we wanted a sample of what was blocking the tubing and preventing us from getting a temprvey on G-22. In running the bailer, the crew was king headway down the tubing, so they continued. After the better part of a day, they brok through the blockage and, after one more bridge, were able to make it out the tubing tail We believe the well could now be logged to verify whether injected water is being contained or not. / Because it has been shut- ' for a few years, we would want to bring water injection on line for 3-4 weeks and run a emp survey to compare against the last compliance temp survey completed on the well. The field guys are putting a choke back on this well and prepping the tree for injection. Once again we come/to the question you have about the validity of temp surveys to prove durational fluid.containment without the benefit of a snapshot positive pressure test (CMIT). We are still grappling with the stuck tubing tail plug in G-5RD and would like to avoid similar issue with other wells by relying on a comparison of temp surveys and the monthly TIO plots t monitor injected fluid containment. 1 I1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, March 26, 2012 1:54 PM�Cq 317�`I z� To: Larry Greenstein 1 Subject: Re: FW: TBU G-22 (PTD # 1750160) - Update Thanks. Good news regarding G-22. I got your voice message too. Temp survey for G-22 is an acceptable approach. I'll call you tomorrow afternoon to further discuss injector mechanical integrity issues. Larry Greenstein <lgreensteinphilcorp.com> wrote: Hope you enjoyed your 3 day weekend. I left you a voice ma' about this well, Jim. In planning our CTU work for the Grayling, we wanted a s ple of what was blocking the tubing and preventing us from getting a temp survey on G-22. In running the bailer, the crew was making headway do the tubing, so they continued. After the better part of a day, they broke through the blo kage and, after one more bridge, were able to make it out the tubing tail. We believe the well could now be logged to ver' y whether injected water is being contained or not. Because it has been shut-in for a few year , we would want to bring water injection on line for 3-4 weeks and run a temp survey to c mpare against the last compliance temp survey completed on the well. The field guys re putting a choke back on this well and prepping the tree for injection. Once again we come to the questio you have about the validity of temp surveys to prove durational fluid containment wit out the benefit of a snapshot positive pressure test (CMIT). We are still grappling with th stuck tubing tail plug in G-5RD and would like to avoid similar issues with other we s by relying on a comparison of temp surveys and the monthly TIO plots to monitor inject d fluid containment. The ultimate fix is a WO to replace tubing and this is being planned, but without a rig on contract, the timing i fuzzy. This summer and fall are the targets but, until we get closer, which platfor s and which wells we work on are in the planning stage. As you know, we have lots of wel s in a similar type condition to this well and would like to incorporate your concerns int our future plans. Thanks Jim and all anytime. A group of s are in BLM training downtown on Tuesday morning, but I'll be back in the office that after oon. Larry 777-83'22 From: Larry Greenstein Sent: Tuesday, February 28, 2012 6:00 PM To: 'Regg, James B (DOA)' Subject: RE: TBU G-22 (PTD # 1750160) 1 1-6� G-zz Rig, James B (DOA) From: Larry Greenstein [Igreenstein@hilcorp.com] Sent: Monday, March 26, 2012 1:37 PMS To: Regg, James B (DOA) l Subject: FW: TBU G-22 (PTD # 1750160) - Update Hope you enjoyed your 3 day weekend. I left you a voice mail about this well, Jim. In planning our CTU work for the Grayling, we wanted a sample of what was blocking the tubing and preventing us from getting a temp survey on G-22. In running the bailer, the crew was making headway down the tubing so the continued. After the better part of a day, they broke through the blockage and after one more bridge, were able to make it out the tubin il. We believe the well could now be logged to verify whether injected water is being contained or not. Because it has been shut-in for a few years, we would want to bring water injection on line for 3-4 weeks and run a temp survey to compare against the last compliance temp survey completed on the well. The field guys are putting a choke back on this well and prepping the tree for injection. Once again we come to the question you have about the validity of temp surveys to prove durational fluid containment without the benefit of a snapshot positive pressure test (CMIT). We are still grappling with the stuck tubing tail plug in G- 5RD and would like to avoid similar issues with other wells by relying on a comparison of temp surveys and the monthly TIO plots to monitor injected fluid containment. The ultimate fix is a WO to replace tubing and this is being planned, but without a rig on contract, the timing is fuzzy. This summer and fall are the targets but, until we get closer, which platforms and which wells we work on are in the planning stage. As you know, we have lots of wells in a similar type condition to this well and would like to incorporate your concerns into our future plans. Thanks Jim and call anytime. A group of us are in BLM training downtown on Tuesday morning, but I'll be back in the office that afternoon. Larry 777-8322 From: Larry Greenstein Sent: Tuesday, February 28, 2012 6:00 PM To: 'Regg, James B (DOA)' j Subject: RE: TBU G-22 (PTD # 1750160) Thanks for the request for info, Jim. We had kind of let this one rest for the time being and left the well shut-in a added it to our LTSI list for monitoring. We had plenty of water going into the ground at the time, even if it wasn't in a prime locations, but that has certainly changed recently. The reasoning behind the request (from Steve Lambert — now tired) is in the validity of the TIO plots for monitoring the well for a 'secondary failure', (ie where the downhole contro f injected fluids is not maintained). We did use this pressure/rate monitoring MIT technique to continue injec n into K-22 for a while until a WO to repair the tubing was able to be performed. This request is similar in that Hilcor s fully planning on repairing a number of waterflood wells over the next few years (as was Chevron, at the time). Bot rayling and King waterflood wells are top priorities as we obtain a rig to do this kind of work efficiently. Regg, James B (DOA) From: Larry Greenstein [Igreenstein@hilcorp.com] Sent:Tuesday, February 28, 2012 6:00 PMZ� To: Regg, James B (DOA) L Subject: RE: TBU G-22 (PTD # 1750160) Thanks for the request for info, Jim. We had kind of let this one rest for the time being and left the well shut-in and added it to our LTSI list for monitoring. We had plenty of water going into the ground at the time, even if it wasn't in the prime locations, but that has certainly changed recently. The reasoning behind the request (from Steve Lambert – now retired) is in the validity of the TIO plots for monitoring the well for a 'secondary failure', (ie where the downhole control of injected fluids is not maintained). We did use this pressure/rate monitoring MIT technique to continue injection into K-22 for a while until a WO to repair the tubing was able to be performed. This request is similar in that Hilcorp is fully planning on repairing a number of waterflood wells over the next few years (as was Chevron, at the time). Both Grayling and Ki—ng-waterflood wells are top priorities as we obtain a rig to do this kind of work efficiently. If anything, with the recent loss of G-19 to injection being able to use this well for localized waterflood support (as the spot of their pump curves would be original request extols), but also to keep the waterflood pumps operating Fn --a swee of big help on the platform. It's part of why we're also going after a RTI for G-5RD. Steve and I discussed this at length prior to him sending in that original request in 2009 and we felt the TIO monitoring was and remains a highly effective (but not infallible) tool in monitoring the downhole fluid containment. Please feel free to call, Jim, so we can discuss these concepts. This is an 'out of the ordinary' request, for sure. Larry From: Regg, James B (DOA) [mailto:jim.reggC&alaska.gov] Sent: Tuesday, February 28, 2012 4:18 PM To: Larry Greenstein Subject: TBU G-22 TBU G-22 has an Admin Approval (AIO 5.006) issued 9/14/2005 for TxIA communication; requires temp survey every 2 years. Appears we have never responded to request to operate G-22 without temp survey and MIT. [Original request came in July 27, 2009]. Found some notes from review that Tom jotted down about well's configuration. Is it Hilcorp's intent that this well be operated without the ability to perform an MIT or temperature survey, relying solely on TIO data? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, October 14, 2011 7:31 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Martin, J. Hal; Lambert, Steve A; Ayer, Phil M; Ross, Gary D; Quick, Mike [ASRC]; Hallett, Trudi R. Subject: 2011 Third Quarter's LTSI Well Monitoring Report Attachments: Master Well List TIO Report 2011 10 01.xls Hi Tom & Jim, Here is the third quarter's report for the LTSI wells utilizing pressure monitoring in lieu of an MIT to determine any mechanical integrity problems. O'Z ` lts The wells G -29RD, G -27, G -22 & G -5RD have been moved to this LTSI report as their downhole problems (like parted tubing) do not allow a temp survey to be run to the proper depth to confirm water entry into the perfs. As a result, they are all shut -in and will remain so for now. The An -17, An -29, Ba -16 & GPP 33 -14RD wells showed increases in the 13 3/8" annulus, but they all have leveled off lately. Ba -17, after an MIT, was used in August to disposed of some fluids collected during the well kill operations on Baker. It may be used again in October for fluids collected during a well abandonment operation. I have left this well on the LTSI well list because after this usage, the well will revert to being shut -in for the foreseeable future. All the pressures seen during the usage in August looked appropriate and the well appears to have maintained its mechanical integrity throughout the disposal operations. The general pattern of stable or slowly rising pressure trends continued this month for the Baker & Dillon wells on this list with the only other pressure anomaly related to the seasonal trend in pressures apparent in Ba -15RD. The well kill operations performed on the Dillon platform in August show up very clearly on the plots. Other than the noted issues, there doesn't appear to be any wells that show indications of any well integrity problems. Larry 10/14/2011 Plot PressurSRate vs Time - Well G -22 • 200 180 • _. - -- - ...--- -_ -... 180 ""95/8" 13 3/8" 160 - - -- — — 160 26" •Tubing •Vol G -22 . 140 140 - - - - - -- _ - -- _ - - -_ 120 120 v v i100 - - -__.. __ --- - - -_.._ ._.._.. .... -.. -.. _. __. 10' E m 80 - -.___.._.— ____._..- - -- _.._. 80 60 60 40 40 20 — 20 O O M - - 0 co co m O O O 0 O 0 O Date . 13 3/8" 20" 26" "° Tubing Vol G -22 TIO Report 10/01/11 79 6 9 0 0 09/30/11 79 6 9 0 0 Data Sheet 09/29/11 79 6 9 0 0 09/28/11 79 7 9 0 0 09/27/11 79 7 9 0 0 G -22 09/26/11 79 7 9 0 0 09/25/11 79 7 9 0 0 09/24/11 78 7 8 0 0 INJECTION 09/23/11 78 7 7 0 0 09/22/11 78 7 7 0 0 09/21/11 78 7 7 0 o Permit # 1750160 09/20/11 78 7 7 0 0 09/19/11 78 7 7 0 0 09/18/11 78 7 7 0 o Admin Approval # AIO 5.006 09/17/11 78 7 7 0 0 09/16/11 78 7 7 0 0 09/15/11 78 7 7 0 o API # 50- 733 - 20272 -00 09/14/11 78 7 7 0 0 09/13/11 78 7 7 0 0 09/12/11 78 7 7 0 0 04/01/2011 to 10/01/2011 09/11/11 76 7 6 0 0 09/10/11 76 7 6 0 0 09/09/11 76 7 6 0 0 09/08/11 76 7 7 0 0 09/07/11 76 7 6 0 0 09/06/11 76 7 7 0 0 09/05/11 76 7 7 0 0 09/04/11 76 6 6 0 0 09/03/11 76 6 6 0 0 09/02/11 76 6 6 0 0 09/01/11 76 6 6 0 08/31/11 74 7 6 0 08/30/11 74 7 6 0 08/29/11 74 7 6 0 08/28/11 74 7 6 0 08/27/11 74 7 7 0 10/14/2011 8:47 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 10 01.xis G -22 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Thursday, October 13, 2011 9:14 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A; Hallett, Trudi R. Subject: 2011 September's Waivered Injection Well Report Attachments: Master Well List TIO Report 2011 10 01.xls Hi Tom & Jim, Here is September's monthly report for all the active monitored injection wells. S_ 0 t Co I did move G- 29RD,0-22Z& G -5RD out of this report and over to the LTSI report due to the inability to get a temp survey deep enough for a successful MIT. These wells have been shut -in and will remain so for now. These monitored wells, including the newly added wells, are responding as expected to ups and downs in injection volumes without any apparent pressure or rate anomalies observed. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry 3 * r ' 3 i i 22 • 11/8/2011 Regg, James B (DOA) From: Lambert, Steve A [salambert@chevron.com] Sent: Monday, August 17, 2009 9:55 AM To: Regg, James B (DOA) Subject: Benefit of G-22 Injection Attachments: 20090812-dauc-G221njectorShutinSimulationv2.docx Jim attached is an evaluation of the benefit of maintaining water injection into well G-22. The analysis uses the full field simulation to compare oil recovery with well G-22 turned on and with the well shut-in. It appears that an additional 260,000 barrels of oil is recovered by maintaining injection in well G-22 to 2020. If you have additional questions or need more information please let me know. SCANNED? OCT 0 8 20 ,Lnevrlon TRADING BAY UNIT Doc. No.: TECHNICAL NOTE Revision Date: Simulation of Injection well permanent shut-in Revision: SUMMARY A simulation study on the impact of shutting in injection well G-22 on the Grayling platform within the Trading Bay Unit oil field has been conducted. The aim of the simulation study is to assess the impact of keeping G-22 shut-in on oil rate and ultimate recovery for the TBU field. G-22 is currently shut-in due to the production platform shut -down and associated reduced waterflood demand. In preparation for an MIT survey in September 2009, a gauge ring was run in G-22 which encountered an obstruction thus preventing subsequent temperature logging. This simulation study was initiated as a means of assigning value to the G-22. Results show G-22 contributes approximately 50-100 bbls oil per day to the TBU total production. This was calculated for the case in which no further development activity is undertaken for the TBU other than maintenance of the current production well count. Incrementally G-22 adds approximately 260,000 stb out to January 2020. Due to the relatively sparse injection and production well spacing in the TBU field it is considered probable that this represents lost rather than deferred oil production. Chris Dauth Reservoir Engineer Mid Continent Alaska Cook Inlet Oil Asset Development Team Dist List: Page t of 5 • Chevron TRADING BAY UNIT Doc, No.: rLi_ TECHNICAL NOTE Revision Date: Simulation of G-22 Injection well permanent shut-in Revision: 1. INTRODUCTION An obstruction in Trading Bay Unit (TBU) injection well G-22 at 7,540ft was detected in June 2009 which would preclude the possibility for further MIT surveys beyond this depth. A simulation run was designed to assess the value of G-22 to assist with decision making on further action to take with G-22. This TECHNOTE summarises results of this simulation run. 2. G-22 INJECTION HISTORY G-22 is located in the central western flank of the TBU field. Prior to injection shut-in (associated with the 2009 Mt Redoubt production platform shut-in) G-22 injected at a rate of 3000-8000 bbls water per day (Figure 1). 14000 12000 10000 v 2 3 v 8000 m c 0 v 6000 v m 3 4000 2000 0 90 9ti 9ti 0�A 9h orb g19$ co p0 O'1 p1. Q'3 (P Oh Q6 13A 04' p9 bac has �a11 �a" �a� �a� _0111 �a� �a� �a� �a� �a� 11211�1 Figure 1. G-22 injection and tubing head pressure history. G-22 Injection Data water injection rate the (psig) 4000 3500 3000 m 2,500 a v 5 2000 fl v m t 1500 a 1000 500 0 Injection profile logging in July 2007 was conducted on G-22. Results of this survey indicate the following injection profile: G-4 1% G-5 1.7% HB -1 2.6% HB -2 87.4% HB -3 7.3% Dist List: Page 2 of 5 cnevron TRADING BAY UNIT Doc. No. TECHNICAL NOTE Revision DateI 1 0,0 : Simulation of G-22 Injection well permanent shut-in Revision: 3. BASIS OF SIMULATION STUDY The current 2009 version of the TBU Exodus full field simulation model was used to calculate a full -field production forecast to January 2020. Two forecast have been completed: i) Run including all production and injection wells ii) Run with G-22 injector remaining shut-in the the remainder of field life Differences between the simulation forecasts provide a means to assign a production value to the G-22 injector. The main relevant assumptions associated with the simulation are given below: • End of field life is January 2020 (arbitrarily selected) • Well injection decline in the field is 5% per annum — this is to account for integrity (surface and sub -surface) related injection reduction across the field. This is in line with historical values. • Production well count is maintained at the current level. • Forecast future injection in injectors is based upon an average injection rate over the preceding 12 month period (G-22 returns to injection Jan 2009 at 5,600 bwipd). • Injection allocations are maintained as per the last production logging survey. 4. RESULTS Simulation results indicate G-22 contributes 260,000 stb oil associated with keeping G-22 injecting to January 2020 (Figure 2). The associated oil rate associated with G-22 is in the order of 50-100 stb/day (Figure 3). Dist List: Page 3 of 5 • Chevron TRADING BAY UNIT Doc. No.: TECHNICAL NOTE Revision Date: Simulation of G-22 Injection well permanent shut-in Revision: 0.1 0.05 U) 0 2 2 -0.05 C -0.1 E -0.15 E d -0.2 -0.25 -0.3 -0.35 -0.4 S,61\ Q9 S,61\ NI) ,a",NL P" Kb SIP , S211\ N6 S211\ N6 TBU incremental oil Exodus Simulation - impact of G-22 injector shut-in ,2 a1� V_11\ SIP Figure 2. Simulated incremental cumulative oil associated with G-22 0 -10 -20 -a -30 -40 U) -50 -60 — -70 0 S -80 u -90 d -100 -110 -120 -130 -140 -150 TBU incremental oil rate Exodus Simulation - impact of G-22 injector shut-in Figure 3. Simulated incremental oil rate associated with G-22 injector Dist List: Page 4 of 5 TRADING BAY UNIT I Doc. No.: TECHNICAL NOTE Revision Date: Simulation of G-22 Injection well permanent shut-in Revision: 5. CONCLUSIONS/ RECOMMENDATIONS G-22 has a clear and measureable value to the TBU waterflood performance through incremental simulation studies. A 50-100 bopd well in the TBU is not an insignificant contribution to the total field rate. The area being swept by G-22 is not considered to be swept by other injection wells thus it is probable the majority of the reduction in oil rate represents lost rather than deferred oil production. Dist List: Page 5 of 5 Chevron W I fth, a Certified Mail 7001 0320 0005 5887 3476 July 27, 2009 Steve Lambert Sr. Advising Petroleum Engineer MidContinent/Alaska Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 W 7th Avenue Suite # 100 Anchorage, Alaska 99501-3539 G-22 MIT Dear Mr. Regg: PI -b 1750e0 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 :JC�aVk , RECEIVED JUL 2 9 2009 Alaska Oil & Gas Cons. Commission Anchorage In preparation for the MIT temperature survey due September 14, 2009 a gauge ring was run in well G-22 on June 28th. The 2" gauge ring would not go below 7,540' and a subsequent run with an impression block stopped at the same depth and could not go deeper. The impression block did not give any indication what was causing the restriction. This well has experienced similar problems at this depth since the well was reperforated in May 2008. Well G-22 was originally drilled as a west flank Hemlock producer in 1975. The well was shut-in due to high water cut production and a stuck ball valve in 1987 after producing 2.3 MM barrels of oil. In 1989 the well was worked over and converted to a dual "G" zone and Hemlock injector. In 1998 the well was worked over to repair known tubing leaks and was completed as a single string "G" and Hemlock injector. In May 2005 the well experienced tubing to casing communication and was temporarily shut-in. A variance was received in September 2005 and the well was returned to injection. In July 2007 an injection profile was run in the well which indicated the well had casing integrity and 95% of the fluid was being injected into the Hemlock. Temperature surveys run in 2005 and 2007 confirmed that all fluid was being injected within the zones of interest. (A copy of the temperature surveys is included as part of this report.) In May 2008, selected intervals in the "G" zone were reperforated in attempt to improve the injection profile. Following the reperf of the G-2 interval an attempt was made to reperf the G-1 interval but it was not possible to get the perf gun past 7,575'. It was decided to return the well to injection. Injectivity did not change following the reperf and no additional pressure was seen on the exterior casing strings. Approximately 11 days after the reperf, injection pressures and rates were increased in the well in order to provide additional injection support for offset producers D-1 and D-47. Injection rates and pressures remained fairly constant until late December 2008. The loss of the ESP in well D-47 in December 2008 reduced the requirement for injection support and the injection rate in G-22 was reduced by 50%. (See attached injection curve.) Current injectivity is at or near that seen prior to the reperf in 2008. The well's pressure and rate performance indicate that the well has maintained mechanical integrity. This is MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com Mr. Jim Regg AOGCC G-22 MIT Page 2 of 5 confirmed by the rates and pressures observed at the time of the 2005 and 2007 compliance temperature surveys and the similarity to the most recent rates and injection pressures. As shown in the attached schematic, the tubing obstruction is approximately 2,300' above the packer. This restriction makes it impossible to utilize a temperature survey to verify the casing integrity down to the packer. While a temperature survey cannot be used to confirm integrity, injection rates and pressures are monitored daily and can be used to verify casing integrity. The well is currently shut-in due to the platform production shut -down and the reduced waterflood demand. When production is restored and the waterflood is returned to full capacity, Chevron would like permission to return well G-22 to injection as long as the rates and pressures remain within historic trends. We realize this is an unusual request; however we find ourselves in an unusual situation. In the current economic climate and state of the field life, a repair of this well cannot be justified. The well has been proven to supply critical pressure support to several offset ESP producers. If the well is allowed to remain on injection, a monthly TIO plot will be prepared and submitted to the state and an annual summary of well performance can be prepared and submitted in lieu of the biannual temperature survey. Any significant increase in injectivity without a corresponding increase in pressure or a significant decrease in pressure without a corresponding decrease in injectivity will signify a loss of integrity and cause the well to be shut-in. We look forward to your feedback on this proposal to return well G-22 to injection. Sincerely, �, 0" -- Steven A. Lambert Sr. Advising Petroleum Engineer Cc: MIT Book Well File MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com Mr. Jim Regg AOGCC G-22 MIT Page 3 of 5 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 d 5500 6000 CL 0 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 1 11 111 11 111 11 111 11 X111 � 11 MEN= ..3.1 1111 MW WE in am 11111111111W'W I in 11111101 . go .1 .1 . 1 :1 : •1 • 11 1 1 1 1 �1 1 - 1 MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com Mr. Jim Regg AOGCC G-22 MIT Page 4 of 5 G-22 Wellbore Schematic 1 NO. Depth JEWELRY DETAIL ID Item 40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt CASING AND TUBING DETAIL RM13D1WHVr=4a6 TmmSr&4-V2'6j000W Btm Amt x 4-1/2" EUE top j� NID NID TVD SIZE WT GRADE CONN ID TOP BTM. BTM 9897' 3.958" Baker Anchor Tubing Seal Assy. (P/N451-40-9999) 26" 1" wall 24.0 Surf. 356' 356 11/19/89 Open for injection G-2 10115' 10154' 39' 2 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) 4 G1 20" 94 Butt 19.124 Surf. 629' 629' 9903' 4.820" Baker 5.22' Millout Ext. (P/N 995--09-9999) 5 G2 4 13-3/8" 61 & 68 H-40 Butt 12.415 Surf. 5548' 4977 3.813" Baker"X" Nipple (P/N 995--08-9999) Ci3 5 9978' 9-5/8" 47 N-80 Butt 8.681 Surf 7016' 6231' Baker Ball Seat Sub (P/N 469-21-999) G4 6 10,968' 4.0" 9-5/8" 47 P-110 Butt 8.681 7016 10,087' 8915' G6 7 10,980' 2.635" 3-1/2" Otis "XN" Nipple, w/ 2.75" PXN plug 9-5/8" 47 S-95 Butt 8.681 10,087' 11,335' 9984' 8 10,981.55' 2.99" WI -REG 10629' Tubing: 6/4 11/16/89 Open for Injection B-2 10643' 10734' 4-1/2" 12.6 L-80 Imp. Butt 3.958 40.6' 9978' 8746' 20/8/4 11/16/89 Open for Injection B-2 10742' 10752' AB Mod Tbg Restriction B-3 10762' 10815 @ 7,540' 1. 1 NO. Depth JEWELRY DETAIL ID Item 40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt �:— 2 Top Btm Amt x 4-1/2" EUE top j� 1 9897' 3.958" Baker Anchor Tubing Seal Assy. (P/N451-40-9999) 3 11/19/89 Open for injection G-2 10115' 10154' 39' 2 9898' 4.75" Baker Model 3H P Packer. (P/N 409--06-9999) 4 G1 3 9903' 4.820" Baker 5.22' Millout Ext. (P/N 995--09-9999) 5 G2 4 9945' 3.813" Baker"X" Nipple (P/N 995--08-9999) Ci3 5 9978' 3.958" Baker Ball Seat Sub (P/N 469-21-999) G4 6 10,968' 4.0" Otis "BWH" Perm Pkr (10,961' DIL) G6 7 10,980' 2.635" 3-1/2" Otis "XN" Nipple, w/ 2.75" PXN plug 8 10,981.55' 2.99" WI -REG 7 8 111 132 B2 B3 B4 6 B6 B6 IatDNELELLi/=9B 1D=1'1,338 ErD=I J NA1t W EANU=34910W Mid Continent/Alaska Chevron North America Exploration and Production www.chevron.com PERFORATION DATA Zone Top Btm Amt SPF Date Present Condition G-1 10061' 10095' 34' 4 11/19/89 Open for injection G-2 10115' 10154' 39' 4 11/19/89 Open for Injection G-3 10178' 10218' 40' 4 11/19/89 Open for Injection G-4 10230' 10300' 70' 4 11/19/89 Open for Injection G-5 10370' 10430' 60' 4 11/19/89 Open for Injection G-5 10590' 10592' 2' 4 6/24/75 Sqzfor Isolation B-1 10595' 10629' 34' 6/4 11/16/89 Open for Injection B-2 10643' 10734' 91' 20/8/4 11/16/89 Open for Injection B-2 10742' 10752' 10' 4 11/16/89 Open for Injection B-3 10762' 10815 53' 16/4 11/16/89 Open for Injection B-4 10827' 10952' 125' 16/12/8 11/16/89 Open for Injection B-5 10984' 11022' 38' 4 7/4/75 Isolated B-5 11081' 11082' 1' 4 6/22/75 Sqzfor Isolation B-6 11115' 11145' 30' 4 7/3/75 Isolated Mid Continent/Alaska Chevron North America Exploration and Production www.chevron.com Mr. Jim Regg AOGCC G-22 MIT Page 5 of 5 11 111 i � 111 1 "I T. V'I , .-d -d 1111 injection due ■ �1 I� 1:. 1.�,� l�� I� . loss of r :111 111, II III ' ill Orli I ' 1M � 1000 5/08/08- 5/19/08 -Increased Reperf injection to support Rate 500 2000 0 0 04/28/07 08/06/07 11/14/07 02/22/08 06/01/0�iM99/09/08 12/18/08 03/28/09 07/06/09 10/14/09 MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com Chevrt~n ~.;.;~«' DATE Tune 9, 2008 ~nciisco Castro Chevron North erica Exploration and production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com To: AOGCC Mahnken, Christine R 3s3 w. nth Ave. ste#1~q~~~V6~E~ JUN ~ ~ 200 Anchorage, AK 99501 ~1~5~ J~ ~.~' WELL LOG TYPE SCALE LOG DATE INTERVAL LOGGED RUN # B-LINE CD NOTES -LAS, PDS, DLIS COMPLETION TB STA-25RD RECORD 5" 4-Mar-08 6660-7092 1 1 1 PDS COMPLETION TB ST A-01 RD RECORD 5" 5-Mar-08 5697-6140 1 1 PDS COMPLETION TBU K-18RD RECORD 5" 21-Feb-08 10800-12400 1 1 PDS COMPLETION TBU K-26 RD RECORD 5" 24-Feb-08 10303-10323 1 1 PDS PERFORATING TBU G-22 RECORD 5" 3-Ma -08 10122-10229 PS-2 1 i -DLIS-PDS PERFORATING TBU M-17 RECORD 5" 16-Feb-08 7298-7381 PS-11 1 1 PDS PERFORATING TBU M-17 RECORD 5" 14-Feb-08 7296-7391 PS-9 1 1 PDS POSISET PLUG SETTING TBU M-17 RECORD 5" 11-Feb-08 6889-7430 PS-8 1 1 PDS PRESSURE TEMPERATURE TBU M-17 LOG 5" 15-Feb-08 5636-7398 PS-10 1 1 PDS DEPTH TBU M-17 DETERMINATION 5" 3-Feb-08 5782-7374.5 PS-7 1 1 PDS PERFORATING TBU M-17 RECORD 5" 19-Feb-OS 5832-5856 PS-12 1 1 PDS POSISET PLUG SETTING TBU M-01 RECORD 5" 7-Jan-08 4792-5151 PS-2 1 PDS PERFORATING TBU M-01 RECORD 5" 18-Jan-08 4532-4580 PS-3 1 PDS HAPPY CEMENT BOND PDS, LAS, VALLEY B-12 LOG - SCMT 5" 18-Mar-08 3559-10315 1 1 1 DLIS COMPLETION PDS, DLIS, LRU C-01 RD RECORD 5" 14-Ma -08 4679-4759 1 1 FMA I ' 1 ~ I I ( I I SRU 32A-15 SHOOT RECORD 5" 10-Mar-08 5554-5582 1 1 PDS /1 <1~25~ ----_ Please acknowledge receipt by signing and returning one copy of this transmittal ar fAX to 907 263 7828. Received 8 ~~ Date: .,~~~~ STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM 'ION K~t.-~IV~I.~ MAY ~ ~ [008 REPORT OF SUNDRY WELL OPERATI(AIlI~a Oil & Gas COr~s. Commission Anrhnrarsa 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension^ Project not done / Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory^ T5-1.6 l~SO~~ ' 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^~ 6. API Number: 50-733-20272-00 - 7. KB Elevation (ft): 9. Well Name and Number: 40.6' RKB G-22 _ 8. Property Designation: 10. Field/Pool(s): Grayling Platform/ADL 17594 - Trading Bay Unit/Hemlock & G Zone 11. Present Well Condition Summary: Total Depth measured 11,335 _ feet Plugs (measured) 10,980' true vertical g 989 , feet Junk (measured) 10,968' Effective Depth measured 10,968 feet true vertical 9,663 feet Casing Length Size MD TVD Burst Collapse Structural 285' 26" 356' 356' 2,692 psi Conductor 588' 20" 629' 629' 1,530 psi 520 psi Surface 5,507' 13-3/8" 5,548' 4,977' 3,090 psi 1,540 psi Intermediate Production 11,294' 9-5/8" 11, 6,870 psi 4,750 psi 9,984' 3 3 5 ' ~~ ,, ~~ ~~~~yy~~~~ww,~ ~ tltt Liner ~~~T+p~Dlii~i~.~ JUN ~' ~` 200 Perforation depth: Measured depth: 10,061' - 10952' True Vertical depth: 8,890' - 9,649' Tubing: (size, grade, and measured depth) 4-1/2" ~, L-80 9,978' Packers and SSSV (type and measured depth) BOT Model "3HP" and Otis BWH 9,898' and 10,980' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A Subsequent to operation: N/A 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^ Service Q Daily Report of Well Operations N/A 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q ' WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-089 Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date 5/12/2008 ~~ ~ ~ ~ ~ ~ ~~~~xR~ sae ~. ,tu~~ ~,- ~ tuup -~ Form 10-404 Revised 04/206 R ub~Or~~Or~~2~•~ vt\ STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL. OPERATIONS RECEIVED MAY 1 5 2008 Alaska Oil & Gas Cons.. Commi; 1.Operations Abandon Repair Well Plug Perforations Stimulate Other C Ofa Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ^~ • Re-enter Suspended Well^ 2. Operator Union Oil Company of California Name: 4. Well Class Before Wo ~ Development ~~• Exploratory^ ~ 5. Permit to Drill Number. 175-016 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic Service 6. API Number: • 0-733-20272-00 7. KB Elevation (ft): 9. Well Name and. Number: 40.6' RKB Trading Bay Unit G-22 8. Property Designation: 10. Field/Pool(s): Grayling Platform/ADL 17594 McArthur River/Hemlock & G Zone 11. Present Well Condition Summary: Total Depth measured 11,335 - feet Plugs (measured) 10 980' true vertical g ggg feet Junk (measured) 10,968' Effective Depth measured 10,857 feet true vertical 9,566 feet Casing Length Size MD TVD Burst Collapse Structural 285' 26" 356' 356' 2,692 psi Conductor 588' 20" 629' 629' 1,530 psi 520 psi Surface 5,507 13-3/8" 5,548' 4,977 3,090 psi 1,540 psi Intermediate Production 11,294' 9-5/8" 11,335' 9,984' 6,870 psi 4,750 psi Liner SCI~NNED MAY 2 2 2008 Perforation depth: Measured depth: See attach SChem atlC True vertical depth: See Attach Schematic Tubing: (size, grade, and measured depth) 4-1/2" L-80 9,978' Packers and SSSV (type and measured depth) BOT Model "3HP" and Otis BWH 9,898' and 1.0,980' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A S BFL MAY 2 2 2008 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 5023 2650 psi 2500 psi Subsequent to operation: 0 0 5269 2700 psi 2500 psi 14. Attachments: 15. Well Class after work: ~j (~• ~ ~ Copies of Logs and Surveys Run Exploratory^ Development • Service ~" , ('~ ' Daily Report of Well Operations X 16, Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date 5/13/2008 Form 10-404 Revised 04/2006 /'-'mar l~ Submit Origi I /~/C~s Trading Bay Unit V N O CA ~® ~ Well # G-22 RKB to TBG Hngr = 40.8' Tree: Single 4-1/2"5,000# Actual Completion (11/98) CASING AND TUBING DETAIL MD MD TVD SIZE WT GRADE CONN ID TOP BTM. BTM 26" 1" wall 24.0 Surf. 356' 356' 20" 94 Butt 19.124 Surf. 629' b29' 13-3/8" 61 & 68 H-40 Butt 12.415 Surf. 5548' 4977 9-5/8" 47 N-80 Butt 8.681 Surf 7016' 623P 9-5/8" 47 P-110 Butt 8.681 7016 10,087. 8915'. 9-5/8" 47 5-95 Butt 8.681 10,087 11,335' 9984' Tubing: 4-1/2" 12.6. L-80 Imp. Butt 3.958 40.6' 9978' 8746' AB Mod 1 2 3 4 G-1 5 G-2 G-3 G-4 G-5 B-1 B-2 Sand Fill on B-2 PXN plug B-3 B-4 6 I '~ I 6-5 B-s y Top of Junk ~~ X11.254' RT to MSL ELEV = 99' TD =11,335' ETD =10,980' MAX HOLE ANGLE = 34.59 ~ 4200' SCHEMATICS G22 Schein I198.doc NQ Deut6 JEWELRY DETAIL I12 ~ .40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 41/2" Butt x 4-1/2" EUE top 1 9897 3.958" Baker Anchor Tubing Seal Assy, (P/N451-40-9999) 2 9898' 4.75" Baker Mode13H P Packer. (P/N 409--06-9999) 3 9903' 4.820" Baker 5.22' Millout Ext. (P/N 995-09-9999) 4 9945' 3.813" Baker "X" Nipple (P/N 995-08-9999) 5 9978' 3.958° Baker Ball Seat Sub (P/N 469-21-999) 6 10,968' 4.0" Otis `BWH" Perm Pkr (10,961' DIL) 7 10,980' 2.635" 3-1/2" Otis "XN" Nipple, w/ 2.75" PXN plug 8 10,981.55' 2.99" WLREG PERFORATION DATA Zone Top Btm Amt SPF . Date Present Condition G-1 10061' 10095' 34' 4 11/19/89- Open for Injection G-2 10122' 10137' (DIL) G-2 10115' 10154' 39' 4 11/19/89 . .Open for Injection G-3 10178' 10218' 40' 4 11/19/89 Open for Injection G-3 10190' 10220' (DIL) 30' 4 5/4/08 Open for Injection G-4 10230' 10300' 70' 4 11/19189 Open for Injection G-5 10370' 10430' 60' 4 11/19/89 Open for Injection G-5 10590' 10592' 2' 4 6/24/75 Sqz for Isolation B-1 10595' 10629' 34' 6/4 11/16/89 Open for Injection ',B-2 10643' 10734' 91' 20/8/4 11/16/89 Open for Injection B-2 10742' 10752' 10' 4 11/16/89 Open for Injection B-3 10762' 10815 53' 16/4 11/16/89 Open for Injection B-4 10827 10952' 125' 16/12/8 1.1/16/8 9 Open for Injection B-5 10984' 11022' 38' 4 7/4/75 Isolated ~B-5 1108.1' 11082' 1' 4 6/22/75. Sqz for Isolation SIB-6 11115' 11145' 30' 4 7/3/75 Isolated. G-5 10,375' 10430' S5' 6 9/10/98. Open for Injection G-4 10230' 10280' S0' 6 9/11/98 Open for Injection G-3 10190' 10220' 30' 6 9/11/98 / Open for Injection G-2 10118' 10.133' 15' 6 9/11/98 Open for Injection ~,G-1 10065' 10092' 2T 6 9/11/98 - Open for Injection REVISED: 5/12/08 DRAWN BY: BCA Chevron Chevron. -Alaska Daily Operations. Summary Well Name Field Name.. API/UWI Lease/Serial Orig KB Elev (ftK6) Water Depth (ft) G-22 MCARTHUR 507332027200 ADL0017594 99.0. 10,980.00 Jobs AfE No. OC Eng UWDAK-R8022 Daily Operations 4/21/2008 00:00 -4122/2008 00:00 Operations Summary Ran 3.69" GR to 160'. Ran 3.5" star bit and tag fill at 10,854'. Ran 3-3/8"x20' dummy gun to 1000'. Pick tap. wt too high. Pull tools. 5/1/2008 00:00 - 5/2/2008 00:00 Operations Summary Run 2 7/8" spent dummy gun and tag fill at 10857 RKB 5/3/2008 00:00 - 5/4/2008 00:00 Operations Summary Rig up, Pressure. test and begin Reperf operations 5/4/2008 00:00 -5/5/2008 00:00 Operations Summary / ~ Perforate G2 (10,115' -10,130'_ pIL) and G3 (10,190' - 10,220' DIL) zones, Multible attempts to pert G-1 zone 5/5/2008 00:00 - 5/6/2008 00:00 Operations Summary Attempt to pass obstruction at 7575 no go. Regg, James B (DOA) ~' l From: Regg, James B (DOA) ! ' ~~r~ /,e, ~ ~~ d(N; Sent: Wednesday, December 26, 2007 5:23 PM To: 'Greenstein, Larry P' Cc: Maunder, Thomas E (DOA) Subject: RE: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Larry -Each of the listed admin approvals did not establish a forma! anniversary date for determining when to perform compliance temperature surveys. There has been some confusion that has resulted. Based on what I have read below and our conversation earlier today, 1 believe using the effective date (signature dotal of the administrative approvals is consistent with your request for nearly all wells accomplishes what you are after (efficiency). The wells you reference below are (with a due date for the next temp survey}: Granite Pt State (Anna} 19 - AIO 6.008 {3/29/2005); next temp survey due 3/29/2009 Granite Pt State (Anna} 21 - AIO 6.009 (3/29/2005); next temp survey due 3129/2009 TBU G-11 - AIO 5.009 (12/15!05}; next temp survey due 12/15/2009 ;you suggested 912009} TBU G-22 - AIO 5.006 (9/14(2005); next temp survey due 9114!2009 TBU G-23RD - AIO 5.004 (6/30/2005}; next temp survey due 6/30/2009 (you suggested 312009) TBU G-27 - AIO 5.003 (3/29/2005}; next temp survey due 3/29/2009 TBU G-29RD - AiO 5.007 (9123/2005}; next temp survey due 9!23/2009 TBU G-40 - AIO 5.002 (312912005}; next temp survey due 3!29/2009 TBU K-11 - AIO 5.011 (2/6/06); next temp survey due 2/6/2010 TBU K-24RD2 - AEO 5.010 (216/06}; next temp survey due 216/2010 There is nothing preventing Chevron from testing earlier (as you have proposed for 2 of these wells). This does not affect any admin approvals that have anniversary dates specifically listed in the conditions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage; AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, December 26, 2007 10:45 AM To: Regg, James B (DOA) Subject: Well with Questions on Determining the Anniversary Dates for Compliance Temp Surveys Thanks for the conversation on this anniversary date topic Jim. It gets real confusing forme to keep the different basis for the anniversary dates separate for each well. The wells in question are: An-19 - AA signed 3129105 -last compliance temp survey 10!3/06. ~JVould like to slide 10108 temp survey to 3,/fl9 to get on AA anniversary date cycle. An-21 - AA signed 3!29;'05 -East compliance temp survey 1014100. Would ike to slide 10108 temp survey to 3109 for the AA date reason. K-11 - AA signed 2(6;06 -last compliance temp survey 12111107 (ust sent to you}. Would like to slide 12109 temp survey to 2110 for the AA date reason. 12/26/2007 - 1 1 -J _ -.D° _ ~.~ . K-24RD2 - AA signed 213103 - last c lance temp survey 12121;07 (will send t~ soon). Would like to slide 12109 temp survey to 2110 far the AA date reason. The Grayling wells have some other things going on. We have wells with AA anniversary dates in every quarter. !sure would like to get the number of logging visits down to just twice a year instead of four times a year. Maybe slide G-23RD forward from June to March and G-11 forward from December to September. This way only two wells get off the AA anniversary date cycle and we'll have three wells due for temp surveys each visit. G-11 - AA signed 12f15105 -last compliance temp survey 3125107. Would like to slide to 3109 temp sunray to 09109 for efficiency. G-22 - AA signed 9114.'05 -last compliance temp survey 4126/07. Would like to slide 4f09 temp survey to 9/09 far the AA date reasan. G-23RD - AA signed 6130105 -last compliance temp survey 4!19107. Would like to slide 4109 temp survey to 3109 far efficiency. G-27 - AA signed 3/29105 -last campliance temp survey 9121/06. Would like to slide 9108 temp survey to 3/09 far the AA date reason. G-29RD - AA signed 9123/05 -last compliance temp survey 6/24/07. Would like to slide 3/09 temp survey to 9109 for AA date reason. G-40 - AA signed 3!29f05 -last compliance temp survey 9,'21x'06. Would like to slide 9108 `amp survey to 3109 for AA date reason. I hope there aren't any more hiding out there. Surely next year I'll find one or two, but for now this list looks like all of them. Thanks again for your consideration Jim. Call me if you want to discuss some more. tarry 263-7361 12/26/2007 `j~~%~~~~ r -r. (~~(c~ 2-Year Temperature Survey Timing Requirements Granite Point Field and Trading Bay Unit Administrative Approvals for these wells did not include specific anniversary dates for determining when to perform compliance temperature surveys (alternate mechanical Background Info: integrity determinations in lieu of MITs). Clarification was requested by Chevron (L, Greenstein; 907-263-7661) on 12/26/2007. The following table summarizes admin approval info, anniversary date options, and the Commission's decision. Well PTD AA Anniversary Date AA Date Last Surve GP State An-19 168-006 6.008 3/29/2005 10/3/2006 GP State An-21 176-049 6.009 3/29!2005 10!4/2006 TBU G-11 168-043 5.009 12/15/2005 6/25/2007 TBU G-22 175-016 5.006 9/14/2005 4/26/2007 TBU G-23RD 179-014 5.004 6/30/2005 4/19/2007 TBU G-27 178-070 5.003 3/29/2005 9/21/2006 TBU G-29RD 192-052 5.007 9/23/2005 6/24/2007 TBU G-40 190-003 5.002 3/29/2005 9/20/2006 TBU K-11 168-083 5.011 2/6/2006 12/11/2007 TBU K-24RD2 201-141 5.010 2/6/2006 12/21/2007 GP State An Granite Point Field, Anna Platform TBU G Trading Bay Unit, Grayling Platform TBU K Trading Bay Unit, King Salmon Platform AA Administrative Approval (AIO 5 and AIO 6, Rule 9) Options Next Temp Surve Due, Based on AA Date1 AA Date2 Last Surve 3/29/2007 3/29/2009 10/3/2008 3!2912007 3/29/2009 10/4/2008 12/15/2007 12/15/2009 6/25/2009 9/14/2007 9/14/2009 4/26/2009 6/30/2007 6/30/2009 4/19/2009 3/29/2007 3/29/2009 9/21/2008 9/23/2007 9/23/2009 6/24/2009 3/29/2007 3/29/2009 9/20/2008 2/6/2008 2!6/2010 12!11/2009 2/6/2008 2/6/2010 12/21 /2009 last u date: 12/26/2007 Next Survey Due (Chevron Proposed) Next Survey Due (AOGCC) Which Option? 3/29/2009 3/29/2009 AA Date 3/29/2009 3/29/2009 AA Date 9/30/2009 12/15/2009 AA Date 9/30/2009 9/14/2009 AA Date 3/30/2009 6/30/2009 AA Date 3/30/2009 3!29!2009. AA Date 9/30/2009 9/23/2009 AA Date 3/30/2009 3/29/2009 AA Date 2/2$/2010 2/612010 AA Date 2/28/2010 2/6/2010 AA Date • • 2007 July's Waivered Injection we.port .Regg, James B (DOA) . Page 1 of2 From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Thursday, August 09, 2007 11 :29 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Lambert, Steve A Subject: RE: 2007 July's Waivered Injection Well Report \(l11 "tit'll 07 to 'l6~V\ ~ \ (}--J ~",Çj~ Jim, Both wells have had some recent wireline work that might explain the pressure changes you noted. Steve Lambert provided the following summary: G-22- The casing pressure increased on July 13. This is the day we ran the injection survey and we opened the annulus to flow in an attempt to locate any tubing leaks. Since that time the tubing and casing have been tracking. It appears that gas in the annulus was blown off the well and now both strings are tracking. (We are still waiting on the log results.) G-29RD. This well was surveyed on July 14 and 15. Once again the annulus was opened to flow during the test. 2 days later on 7/17 the casing pressure dropped to zero and has remained low. (I believe the pressure probably dropped at the time of the survey and was not recorded properly until 7/17.). The change in casing pressure is a result of having blown off the pressure on the annulus and the annulus has not repressured to date. The pressure gauge on the casing was changed on August 6 and the pressure is currently reading zero. We are awaiting the results of the survey to determine if the source of the tubing 1 casing communication can be determined. The one curiosity, is why didn't the annulus pressure in G 29RD pressure back up with the tbglcsg communication that necessitated the admin approval in the first place?? We even changed out the gauge to make sure the readings were accurate. We are very interested in what the recent injection surveys will show us about both these wells. Hope this helps. SCANNED SEP 0 7 2007 Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 08, 2007 10:08 AM To: Greenstein, Larry P; Maunder, Thomas E (DOA) Cc: Martin, J. Hal; Lambert, Steve A; KRAMER, TED E Subject: RE: 2007 July's Waivered Injection Well Report Larry - When you get a chance, a couple things to look at... G-29RD: Why the sudden drop in IA pressure? Seems uncharacteristic for this well with TxlA communication; IA has always tracked tubing pressure. G-22: Quick review of history indicates that there has normally been a 300-500 psi differential between T and IA; since 7/13/07 pressures have been equal; is communication getting worse? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, August 08,20079:17 AM 8/29/2007 2007 ~ulY's Waivered Injection Wel.port To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A; KRAMER, TED E Subject: 2007 July's Waivered Injection Well Report . Page 2 of2 Hi Tom & Jim, Here is July's monthly report for all the active monitored injection wells. The King (deaereator) and Steel head (well) waterfloods are still down. As you can see, the A-8RD2 well has maintained some pressure isolation between the tubing and casing pressures. Possibly a slow equalization is occurring (trend shows -4#/day) and we would like to watch this for another month or so to confirm. There was a pressure spike on An-32RD in the middle of July. The well was already shut-in, so it seems odd to show this pressure. Talked with the operators and nobody had an explanation. Doesn't appear to be typos. With all the ups and downs of Anna injection lately, possibly the well got opened and then shut back in without any injection volumes measured. Just don't have an answer for this spike. The well settled right back down to normal pressures right after this 'event'. Lots of ups and downs, as usual, but nothing out of the expected changes in rates 1 pressures was recorded this last month. Bottom line, I don't see any indication of any of these wells losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2007 07 31.xls» 8/2912007 vs 3000 2500 2000 1500 000 " 500 o G-22 Compliance Temperature Survey . . Subject: G-22 Compliance Temperature Survey From: "Lambert, Steve A" <salambert@chevron.com> Date: Tue, 08 May 2007 18:15:18 -0500 To: Thomas Maunder <tom _ maunder@admin.state.ak.us>,jim_regg@admin.state.ak.us Jim, Tom \\ç-O\~ ~\~!r~\.\" \~ o",~\\~dti~~ G-22 Admin Approval Temperature Survey Well G-22 (PTD 175-016) was granted Administrative Approval (AID 5.006) on September 14,2005. As required under the approval, a follow-up temperature survey was on run on 4-26-07. The survey (see attached) confirms that all injected fluids are being contained within the zones of injection. The survey does show a cool interval at approximately 200'. The cooling at this depth has been seen in other wells and is believed to be residual cooling from the injection period. A longer shut-in period prior to running the survey would likely eliminate this cooling affect. All external casing strings in this well show no indication of pressure, confirming the fact that no fluid is exiting the casing at a shallow depth. Please contact me if you have any questions concerning the survey_ «G-22 Temp Survey 04-26-07 vs 8-24-05.zip» C t tD . ti· G-22 Temp Survey 04-26-07 vs on en - escnp on: 8-24-05.zip G-22 Temp Survey 04-26-07 vs 8-24-05.zip Content-Type: application/x-zip-compressed Content-Encoding: base64 -1"" Jü~ n 5 20G? S~N~j¡,i /.J ,'. ". ........,...... ..."......J.....". ,. ".,. 1 of! 6/25/2007 11: 17 AM 10000 o o 500 1000 1500 2500 3500 4500 2000 3000 500 K -~ ...... ~i ""'- "" "\ " r / I" " II , V ~ - i .m C:hJ ¡%..in j....................... ~ " 1\ ~ ". \ I i <\: .... c;; ~ "\ <::::: b ~ !~ ~ ['. ............ ...... .. ............. ~ . t:::::> <: < ~ n s:lmj ~ ~ ~ ~ ~'" ; :- m'" m" ....... 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 1500 8000 8500 9000 9500 10500 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 Perfs RKB 13-3/8" -4-26-07 Pressure -9-5/8" -26" -8-24-05 -4~26-07 Report date: 6/25/2001 G~22 Compliance Temperature Survey . 8-22 Admin Approval Temperature Survey Jim, Tom Well 8-22 (PTD 175-016) was granted Administrative Approval (AlO 5.006) on September 14,2005. As required under the approval, a follow-up temperature survey was on run on 4-26-07. The survey (see attached) confirms that all injected fluids are being contained within the zones of injection. The survey does show a cool interval at approximately 200'. The cooling at this depth has been seen in other wells and is believed to be residual cooling from the injection period. A longer shut-in period prior to running the survey would likely eliminate this cooling affect. All external casing strings in this well show no indication of pressure, confirming the fact that no fluid is exiting the casing at a shallow depth. Please contact me if you have any questions concerning the survey. «8-22 Temp Survey 04-26-07 vs 8-24-05.zip» Temp Survey 04-26-07 vs 8-24-0S.zip Content-Type: Content-Encoding: .. G-22 Temp Survey 04-26-07 Content-DeSCrIptIOn: 8 24 05 . vs - - .ZIp applicationlx -zip-compressed base64 S"CANNEO MAY 1 6 2007 1 of 1 5/11/2007 4: 14 PM 0 500 1000 1500 2000 2500 3000 3500 4000 - 4500 ....., Q) ~ 5000 - 5500 6000 5500 1000 1500 8000 8500 9000 9500 10000 10500 Pressure Perfs RKB -20" - 3-3/8" - 4-26-07 -8-24-05 000 500 2000 2500 :moo 3500 4000 4500 5000 5500 6000 6500 1000 1500 8000 8500 9000 9500 10000 10500 11 000 1500 55 60 5 90 95 Pressure Perfs RKB -13-3/8" -8-24-05 30 135 140 . . SARAH PALIN, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: McArthur River Field, HemlockjG Oil Pool, G-22 Sundry Number: 307 -089 l b \ 1 b --0 ~({~ANNE[) MAR 1 6 2007 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ¿day of March, 2007 Enc!. () v:s.3! /'1-~TATE OF ALASKA œ~ 2~1~ tI RECEIVED ALA. Oil AND GAS CONSERVATION ~OMrJIJ§ION {r~{IÇ MAR 0 20 7 APPLICATION FOR SUNDRY APPROVALS . 9 0 20 AAC 25.280 ,âlA~¡'A nil R. 1::".. ('n.... 1", 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver ~ hora Other ~ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension ',- proqife Modification Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: v~~~!?(' Union Oil Company of California Development ~. Exploratory 0 71:;_nn4 ~ n ) /~ /1 3. Address: Stratigraphic 0 Service A ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 . {a'''? 733-20272-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 0 [] , Spacing Exception Required? Yes No G-22 9. Property Designation: ¡fb'- 17t;!1ý' .~,10. KB Elevation (ft): 11. Field/Pool(s): Gravlinq Platform/Cook Inlet Trading Bay Unit / Hemlock & G-zone - Jb·J.I.J· 40.6' RKB tI Hngr 12. ~ PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,335' 9,989' - 10,968' 9,663' 10,968' Casing Length Size MD TVD Burst Collapse Structural 285' 26 " 356' 356' 2,692 psi Conductor 588' 20 " 629' ,629' 1,530 psi 520 psi Surface 5,507' 13 3/8" 5,548' 4,977' 3,090 psi 1,540 psi Intermediate Production 11,294' 95/8" 11,335' 9,984' 6,870 psi 4,750 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,061' to 11,145' 8890' to 9820' 4-%" L-80 9,978' Packers and SSSV Type: BOT Model "3HP" & Otis "BWH" Packers and SSSV MD (ft): 9,898' & 10,980' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service [] . 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 3/15/2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 - WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Drilling Manager Signature '2.::- IS- ~ Phone 263-7657 Date 3/8/2007 - C/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: :3:/)7 -DRC} Plug Integrity 0 BOP Test, 0 Mechanical Integrity Test 0 Location Clearance 0 Other: \..t),,~ '........, It::ð ~\~\-\"'~~ ~~~-\\~~<t, ~\'C)s-.ao<.a R8DMS 8Ft MAR 1. 5 2007 Subsequent Form Required: \..\ () '-\ ~ "~~COMMISSIONER APPROVED BY 3-/tf--6 ¡- Approved by: THE COMMISSION Date: T '-""" mB ~ Form 10-403 Revised 06/2006 0 \~ ß¡f Ø? Submit in Duplicate __ r'l -{, ~C> ~ /' ~ "ø 3 1 7 . . / Grayling G-22 Injector Profile Modification with Polymer Well Status: Currently on injection @ 10,000 bpd with 3250 psi tbg pressure. Objective: Perform an injection profile modification with J571 PowerClean polymer, leftover from Coil Clean out on G-15RD. Volume unknown but projected to be ±200 bbls. ,- Polymer will be cleaned through a centrifuge and will have a reduced apparent viscosity of 10cp. Procedure: · MIRU pumping surface iron to G-22 tubing. Pressure test same. · Pump two (2) tbg volumes (304 bbls) ofFIW at max rate. MASP=3500 psi. · Pump 1/3 of the total volume of J571 polymer at max rate. MASP=3500 psi. · Pump two (2) tbg volumes (304 bbls)ofFIW at max rate. MASP=3500 psi. If any discrepancies in rate and pressures, call Steve Lambert @ 263-7658 before proceeding any further. · Pump 2nd 1/3 of the total volume of J571 polymer at max rate. MASP=3500 psi. · Pump two (2) tbg volumes (304 bbls)ofFIW at max rate. MASP=3500 psi. Note any discrepancies in rate and pressures, call Steve Lambert @ 263-7658 ifthere is. · Pump last of the total volume of J571 polymer at max rate. MASP=3500 psi. · Pump two (2) tbg volumes (304 bbls)ofFIW at max rate. MASP=3500 psi. · . '* --.---- - ~ "1II"£:.'-.1\,] . errading Bay Unit Well # G-22 Actual Completion (11/98) ~ - ... ~ ....- - - ....... CASING AND TUBING DETAIL MD MD TVD RKB to TBG Hngr = 40.6' SIZE WT GRADE CONN ID TOP BTM. BTM Tree: Single 4-1/2" 5,000# 26" l"wall 24.0 Surf. 356' 356' 20" 94 Butt 19.124 Surf. 629' 629' 13-3/8" 61 &68 H-40 Butt 12.415 Surf. 5548' 4977 9-5/8" 47 N-80 Butt 8.681 Surf 7016' 6231' 9-5/8" 47 P-IIO Butt 8,681 7016 10,087' 8915' 9-5/8" 47 S-95 Butt 8.681 10,087' 11,335' 9984' Tubing: 4-1/2" 12.6 L-80 Imp. Butt 3.958 40.6' 9978' 8746' AB Mod JEWELRY DETAIL NO. Depth ID Item 40.60' 3.958" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt x 4-1/2" EUE top I 9897' 3.958" Baker Anchor Tubing Seal Assy. (pIN451-40-9999) 2 9898' 4.75" Baker Modet 3H P Packer. (PIN 409--06-9999) 2 3 9903' 4.820" Baker 5.22' Millout Ex!. (pIN 995-09-9999) 4 9945' 3.813" Baker "X" Nipple (pIN 995-08-9999) G-1 5 9978' 3.958" Baker Ball Seat Sub (pIN 469-21-999) 5 G-2 6 10,968' 4.0" Otis "BWH" Perm Pkr (10,961' DlL) G-3 7 10,980' 2.635" 3-1/2" Otis "XN" Nipple, wi 2.75" PXN plug G-4 8 10,981.55' 2.99" WLREG G-5 Sand Fill on PXN plug B-1 B-2 B-2 B-3 B-4 PERFORATION DATA Zone Top Btm Amt SPF Date Present Condition G-l 10061 ' 10095' 34' 4 11/19/890pen for injection G-2 10115' 10154' 39' 4 11/19/890pen for Injection G-3 10 178' 10218' 40' 4 11/19/890pen for Injection G-4 10230' 10300' 70' 4 11/19/890pen for Injection G-5 10370' 10430' 60' 4 11/19/890pen for Injection G-5 10590' 10592' 2' 4 6/24/7 5 Sqz for Isolation B-1 10595' 10629' 34' 6/4 11/16/890pen for Injection B-2 10643' 10734' 91' 20/8/4 11/16/890pen for Injection B-2 10742' 10752' 10' 4 11/16/890pen for Injection B-3 10762' 10815 53' 16/4 11/16/890pen for Injection B-4 10827' 10952' 125' 16/12/8 11/16/890pen for Injection B-5 10984' 11 022' 38' 4 7/4/75 Isolated B-5 11081' 11082' l' 4 6/22/7 5 Sqz for Isolation B-6 11115' 11145' 30' 4 7/3/75 Isolated G-5 10,375' 10430' 55' 6 9/10/98 Open for Injection G-4 10230' 10280' 50' 6 9/11/98 Open for Injection G-3 10 190' 10220' 30' 6 9/11/98 Open for Injection G-2 10118' 10133' 15' 6 9/11/98 Open for Injection G-l 10065' 10092' 27' 6 9/11/98 Open for Injection 6 7 RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.5~ ~ 4200' G22 Schem 1198,doc REVISED: 11/16/98 DRAWN BY: DNM • FRANK H. MURKOWSKl, GOVERNOR 333 W. 7TM AVENUE, SUITE 700 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 5.006 Mr. Steve Lambert Reser~°oir Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99~ 19-6247 • ~~~~' JAN ~ ~ 2008 RE: Trading Bay Unit G-22 [aka Grayling 22] (PTD 17~-016) Request for Administrative Approval AIO ~ Dear Mr. Lambert: Per Rule 9 of Area Injection Order ("AIO") 005, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. This well was originally reported to have experienced tubing x inner annulus ("T x IA") communication in May 200 and was shut-in. 2. On May 25, 200 Unocal applied by sundry to return the well to injection so that diagnostic logging could be performed in support of an administrative approval. 3. Following review of available information, Unocal's application was approved on June 9 subject to recording and submitting the daily injection rate and well pres- sure information and performing a subsequent temperature survey. 4. Actual injection did not begin until early July. While injecting, Unocal has been recording daily injection rate and well pressures and has provided this information to the Commission. In support of this application, Unocal has submitted a base- line and subsequent temperature log. ~. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The rate/pressure information has not indicated any fur- ther pressure integrity loss. 6. At this time, Unocal is not proposing to repair the well to restore full integrity. 7. An aquifer exemption is in effect for all aquifers lying directly below ~1cArthur River Field (Trading Bay Unit) [40 CFR 147.102(b)(2}(ii).] Based on analysis of the submitted information, the Commission concludes that TBU G- 22 exhibits two competent barriers to release of well pressure. Accordingly, the Com- Mr. Steve Lambert September 14, 200 Page 2 of 2 mission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Trading Bay Unit G-22 [aka Grayling 22] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I!OJ (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing!IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. dated September 14, 200. v~~~ ; ~ , '< v Cathy P. oerster Commi sinner Gti\ ~~~ ~~\, ¡,'fI' .iß"\, ~, I íþ ~. , ! "\ I i I , U! ~ II I' ,'.... ¡ \ ¡ I I I 'I I \" I, " f \ \ J L6 ) ¡¡1m rr ffi, /,n~I~\., 11 t/4f\ ((ù n~i7 t fA \. '[!I!Þ !¡J\:I ,fr¡ "':i¡'\ fil\ \0 iJ i: \J S .~ cQ) U \~ i!.ï\1 ) AI~ASIiA OIL AND GAS CONSERVATION COMMISSION / .¡ I I J FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Lambert Reservoir Engineer UNOCAL P.O. Box 196247 Anchorage, Alaska 99519 o (/~ \ 1S' v' SCANNED JUN It\ 2005 Re: McArthur River 0-22 Sundry Number: 305-135 Dear Mr. Lambert: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Super' unless rehearing has been requested. / S i ere DATED this.!"l day of June, 2005 Enc!. ) Unocal Alaska Resourcl ) Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 May 25, 2005 R lEe t;¡!!,~,¡f,~~'&' t:::: ,,~i ~¡, {" t ,t,~'\',( JUN fJ J zoos ail 8e G~~," C . IrØ"ì '10nL~. Anf;lìOf8~r[;î Steve Lambert Reservoir Engineer Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 RETURN TO INJECTOR GRAYLING PLATFORM WELL NO. 22 MCARTHUR RIVER FIELD Dear Tom: Unocal is proposing to return well G-22 to injection. Enclosed is form 10-403. Well G-22 was returned to injection on April 22. The well experienced pressure on the tubing casing annulus and was shut-in on May 12. The well is a critical component of the efforts to maintain productivity and improve recovery from the Tyonek "G" zone and Hemlock reservoirs. Following is the proposed procedure for bringing this well back on injection. 1) Obtain permission to inject. 2) Baseline temperature survey 3) Inject until the well has stabilized (approximately 1 month). 4) Follow-up temperature survey. 5) Obtain variance to inject. 6) Monitor well daily and repeat temperature surveys every two years. Please let me know if you require additional information. slncerelY,0v ~~J~~ - Steve Lambert Enclosure O:\OOE\OOEFields\TBU\Grayling\Wells\G-22Inj\Projects\G-22 Retum to Injection Letter May 05.doc Abandon U Suspend U Alter casing D Repair well D Change approved program 0 Pull Tubing D 2. Operator Name: Union Oil Company of California 1. Type of Request: 3. Address: 7. KB Elevation (ft): 103'KB above MLW 8. Property Designation: ADL 17594 11. Total Depth MD (ft): 11335 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10061-10095,10115-10154, 10178-10218, 10230-10300, 10370-10430. 10595-10629, 10643-10734. 10742-10752, 10762-10815,10827-10952 Packers and SSSV Type: ~'-c·· "E'a\}VE"~~ 1::., ':: ffl ~ ,':::,,' -' JUN 0 1 Z005 (~ CAtJ-. '.Þ'or ) STATE OF ALASKA W-) b /9 :s ALA~KA OIL AND GAS CONSERVATION COMMISSION /- APPLICATION FOR SUNDRY APPROVAL ,A!a~dŒ Oil & G~s Coms. Cmr¡missioil 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: P.O. Box 196247 Anchorage, Alaska 99519 Development Stratigraphic D D Perforate U Waiver U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 75-16'V o 6. API Number: / 50-733-20272-00 . Other U Service 9. Well Name and Number: G-22 10. Field/Pools(s): McArthur River Field Tyonek G/Hemlock PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9990 11 254 9912 none Length Size MD TVD Burst Collapse 629 20" 94# H-40 629 629 1530 psi 520 psi 5548 13 3/8" 61-68# K-55 5548 4977 3090 psi 1540 psi 11335 9 5/8" 47# N-80, 11335 9984 6870 psi 4750 psi P-110, S-95 Perforation Depth TVD (ft): 8891-8920, 8936-8969, 8989- 9022, 9032-9091, 9150-9201, 9338-9367,9379-9456,9463- 9472, 9480-9526, 9536-9645 Tubing Size: Tubing Grade: 12.6# L-80 Tubing MD (ft): 9978 41/2 Date: Packers and SSSV MD (ft): Single Packer 10968' 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: 6/6/2004 Oil D Gas D WAG D GINJ D Abandoned WDSPL D D Dual Packer 9993', Single Packer 10,500' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Lambert 263-7658 Printed N~Ste~. Lambert Title Reservoir Engineer Signature - (}.-r- Phone 263-7658 Date t\1\ "25 '2. coS ,"-.. )~) ~~ D.-\. I COMMISSION USE ONLY '__J D Service o D o Plugged WINJ 25-May-05 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3Ð5-/s.~ Plug Integrity D Other: \J-...) (( \ \ \,~c:..S-...;) ~\\c BOP Test D Mechanical Integrity Test D Location Clearance D k ~ ~ ~~\\ð~c:Jð~I' 't~ ìL~ V'l\.O~-\-~ ,'-{, ~~~~ CbÙ~'i ~DÖt'- \ó ~ t ) S -as- o RIG I N l\lVED BY RBDMS BFt .J U N 1 0 ZU05 Date: ;!~L COMMISSIONER THE COMMISSION RE: G-22 and G-29RD ) ) Subject: RE: G-22 and G-29RD From: "Lambert, Steve A" <salambert@unocaLcom> Date: Tue, 07 lun 2005 08:40: 11 +0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Surveys are scheduled for next week. You are right the wells have been shut in long enough to establish a good base line. -----Original Message----- From: Thomas Maunder [ma,:Ll to: tom maunde.r@a,dm:Ln. sta,te. a.k. us] Sent: Monday, June 06, ......i..Õ..Ö'S.......4..';..2..7-þÏVC...............................·...·...................'.....................................,....,......................... To: Steve Lambert Subject: G-22 and G-29RD Steve, I am finalizing the sundries you sent over. Have you already gotten the temperature surveys?? With the wells SI for a while, the downhole temperatures should have changed (likely warmed up) to give you a good contrast when the wells are returned to service. Thanks, Tom Maunder, PE AOGCC 1 of 1 6/7/2005 9:41 AM Re: G-22 return to Injection ) ) Subject: Re: G-22 return to Injection Fr.om: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 25 May 2005 11 :25:05 -0800 To: "Lambert, Steve A" <salambert@unocal.com> CC: "Greenstein, Larry P" <greensteinlp@unocal.com>, "Cole, David A" <dcole@unocal.com> Steve, et al: I did a quick look at the sundry. This sundry form is not "the most current" as available on our web site. I think I sent you and Larry a note recently regarding using the correct form. I know this may be "being bureaucratic", but the word I have from the top over here is that it is possible we will return applications that are not on the correct form. There are also some issues contentwise: According to our records, G-22 has been a water injection (1 winj) or service well since May 4, 1990. That makes your checking development in boxes 4 and 13 incorrect. Service is the correct Class. I hope you are able to catch the hard copy to make the appropriate corrections. Call or message with any questions. Tom Maunder, PE AOGCC Lambert, Steve A wrote: Tom following is our request to return well G-22 to injection. The originals will be sent by mail. «G-22 Return to Injection Letter May 05.doc» «G-22 Return to injection.xls» 1 of 1 6/6/2005 4:21 PM G-22 Pressure Observations 2500 5000 - - 4500 2000 r-- 4000 - HRS_ON ,-. -TBGPRESS -CSGPRESS295ffl - - 3500 ----CSGPRESS3133ffl \, CSGPRESS5 20 1500 - ~ CSGPRESS6 26 - - 3000 C -DAILY_VOLUME Q. 3: CD I !!!. ... CD :::::I rn - - 2500 10 rn 0::: CD ... c Q. 0 :¡:¡ CJ 1000 CD 2000 'ë - - 1500 ~-..... 500 1000 - - 500 o -- 02/07/05 02/17/05 02/27/05 03/09/05 03/19/05 03/29/05 , .-.L...-<c '-~"',c...,. ~ ~ .-...=,-.<~ , 04/08/05 04/18/05 04/28/05 05/08/05 -", -- . .~ -. ,oM 0 OS/28/05 05/18/05 Date Printed on 6/6/2005 at 4:21 PM Prism Chart Prism Chart Prism Chart Prism Chart - -~.- 04/08/05 03/04/04 09/20/04 08/17/03 Date J-- ~ -HRS_ON -TBGPRESS -CSGPRESS -CSGPRESS2 9 5/8 -CSGPRESS3 133/8 CSGPRESS5 20 - CSGPRESS6 26 SURF_PRESS -DAILY_VOLUME 01/29/03 Printed on 6/6/2005 at 4:22 PM 1000 - -.~ - - .-'H- ~< . ..:.','-'J,'\. ..jll ~::, fiTI' In .. ..·...:-I'\~¡P,..:.,I-..,',..\ ~~ -"" ,'.: .".' ,. , , . {o~ ;" ': '. .'.' '. ¡, ¡\~ .~(r ",." 11 o 'r~.orn·-" -----. ,.":'7.::':,~___.""" ~ 12/25/01 07/13/02 ..........,...---.-- ~.~, -~~ ,,( ~~II ~ ~ 4--rr 1 -~.~-~- - J 'Iv" G-22 Pressure Observations 2000 3000~ i ~ . ".-. 4000 I; ~ ::::J ~ 5000 ~ a. 6000 7000 ,,-. 8000 - 9000 - 10000 RE: G-22 (175-016) Injection test ) ) Subjeçt~ RE: G-22 (175-016) Injection test From: "Lambert, Steve A" <salambert@unocal.com> Date: Fri, 20 May 2005 01 :46:07 +0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Greenstein, Larry P" <greensteinlp@unocal.com>, "Dolan, Jeff J" <dolanjj@unocal.com> This well passed the standard MIT in October 2002. As shown in the attached plot, it was injecting with no communication between annulus and tubing through September 2004. The well was shut-in at that time. The well was placed back in service in April 2005. It was during this period that we noticed the increase in casing pressure and shut the well in on May 12. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, May 18, 2005 3:53 PM To: Lambert, Steve A Cc: Greenstein, Larry P; Dolan, Jeff J; Cole, David A Subject: Re: G-22 (175-016) Injection test Steve, I need a little more information on this one. What is the history of G-22. I don't see it on Larry/Jeffs monthly report and I don't have any earlier emails on the well. Thanks in advance, Tom Maunder, PE AOGCC Lambert, Steve A wrote: «G-22 Pressure Observations 200505 17.xls» We have recently attempted injection into well G-22. The well experienced casing pressure and was shut-in (see attachment). We feel this well is a valuable injector and would like to return the well to full time injection status. As we understand the procedure, we need to submit a sundry to allow an injection test with appropriate temperature surveys to confirm fluid is not moving outside the zone of interest. If the surveys confirm that the water is beinig contained within the zone of interest, a request for administrative approval to return the well to full time injection status would be submitted. Please let us know if this is the proper procedure for reestablishing injection into this well. C t t D . t· G-22 Pressure Observations 2005 05 on en - escnp Ion: 18.xls G-22 Pressure Observations 2005 05 IS.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 1 of 1 6/6/20054:22 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair THRU: Tom Maunder ~,(,~ P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: October 1, 2002 SUBJECT: Mechanical Integrity Tests Unocal Trading Bay Unit McArthur River Field Grayling Platform NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Notes: QA pressure 70. psi. ·we,Io-~s I Type Inj. I ~ I T,V:D' I 8833 I'Tubing I 3250 ! 3250' I" 3250."l 3250 l ihteNall 4 P.T.D:I'1681090.,TypetestI P. I'Test~s'il 2450 I CaSing,[ 190..0 .I 2450"1' 24'25 I ~425 I P/F.I Notes: OA pressure 310 ,vve, I,G.19 ' ITypel.n.j.I S' I T.V.D. I' 91~45 I T'ubingl 3200 1 320'0 I' 3200' [';~0(~ I i~terval'l"4 Notes: OA pressure 125 - 210 during pressure test. Notes: OA pressure 180 psi. - 300 during pressure test. PiT'D'I 1790140' ITypetestl P IT~stpsil 2300 I Casingl' 560 I 230°'1 2300 I 2300 I p/F ,,0tes= OA preSsUre 86 psi. ' ' ' . Type INJ. Fluid Codes F = FRESH WATER INJ. G - GAS INJ. S= SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVadance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to Kenai Alaska 09-30-02 to be available to travel to the Grayling Platform @ 0630 hrs. 10-01-02. Testing went well w/Water Flood Operator David L. Meyers conducting tests in a safe & efficient manner. No failures were witnessed. All OA pressures were observed & recorded during tests. With no permafrost concerns, all tests utilized filtered Inlet water for test fluids. M.I.T.'s performed: _5 Attachments: Number of Failures: O Total Time during tests: 4. h.m., MIT report form 5/12/00 L.G. MIT Grayling Pit. 10-01-02jc.xls 10/9/2002 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 IJNOCAL Tim Billingsley Drilling Engineer 8/21/2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Tom Maunder Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G-22 Mr. Maunder: Enclosed is the final report on annulus disposal of A-29RD oil base mud (OBM)liquid waste into the G-22 annulus as required by the Sundry Application Approval #301-304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G-22 annulus while drilling at A-29RD. The following is the total volumes disposed in G-22 annulus by drilling well source. Well G-15RD OBM, bbls Seawater Flush, bbls Total Bbls 1269 2160 3429 G-28RD 203 700 903 G-26RD 823 2155 2978 A-15RD 1374 5067 6441 G-12RD3 ' 366 1050 1416 A-29RD 856 1494 2350 17517 Total This concludes all presently scheduled disposals into the G-22 annulus. If there are any questions, please contact myself at 263-7659. Sincerely, ,,,~ Tim Billingsle'y ~ Drilling Engineer AOGCC G-22A-29RD waste annular disposal final report Created on 8/21/2002 10:13 AM Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G-22 Drilling Wastes From M°nopod A-29RD Maximum Allowable Injection Pressure 2000 psi TVD 13 318" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry'sFlushe= 6/29/20021 2.0 1600 10.2 . 205 0 205 0 6/29/20022 2.0 1400 10.2 146 351 0 6/29/2002 3 1 2.0 1800 10.2 60 357 411 357 7/15/2002 2 2.0 1550 20 411 377 7/15/2002 4 2.0 1850 8.7 125 536 377 7/15/2002 3 2.0 1800 357 536 734 8/5/2002 4 2 1400 8.3 20 536 754 8/5/2002 5 2 1750 8.5 170 706 754 8/5/2002 5 2.5 1850 8.3 350 706 1104 8/10/2002 6 2 1500 8.3 20 706 1124 8/10/2002 6 2 1750 8.5 150 856 1124 8/10/2002 7 2.5 1850 8.3 370 856 1494 *Injection pressure is the highest injection pressure observed while injecting Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Jim Harrison Drilling Manager 7/3/2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Tom Maunder Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G-22 Mr. Maunder: Enclosed is the final report on annulus disposal of G-12RD3 oil base mud (OBM)liquid waste into the G-22 annulus as required by the Sundry Application Approval #301-304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G-22 annulus while drilling at G-12RD3. The following is the total volumes disposed in G-22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls G-15RD 1269 2160 3429 G-28RD 203 700 903 G-26RD 823 2155 2978 A-15RD 1374 5067 6441 G-12RD3 Total 366 1050 1416 15167 Unocal began disposing of drilling wastes.from the A-29RD into the G-22 annulus.on' June 29, 2002. If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. Sincerely, . Jim Harrison' U/ Drilling Manager AOGCC G-22 G-12RD waste annular dispoSal f'mal report R1 Tim Billingsley Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G-22 Drilling Wastes From Grayling G-12RD3 Maximum Allowable Injection Pressure 2000 psi TVD 13 318" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry's Flushes 6/1012002 1 1 3 1800 9.1 170 350 170 350 6/15/2002 2 2 2 1800 8.3 11 350 181 700 6/17/2002 3 3 2 1750 8.4 185 350 366 1050 -*Injection pressure is the highest injection pressure observed while injecting Baker and Grayling Issues Subject: Baker and Grayling Issues Date: Wed, 15 May 2002 14:15:38 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Tim Billingslea <billita@unocal.com>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak. us>, Daniel T Seamount JR <dan_seamount@admin.state.ak. us> Tim, I'll cover 2 issues with this note. Thanks for sending over the prior approved sundry for Baker 14. The scope of the workover is still the same and as you note, the pressures should have declined a bit. The schematic and procedure notes answered my question regarding the SSSV. You design will allow it to still function. By copy of this email, you have approval to proceed as planned. Please have Evan send in the BOP test report when done. On Grayling disposal. The Commissioners have asked me to pass on the following. Unocal has recently sent 2 letters to the Commission with regard to operations on Grayling and disposing of resulting wastes into the G-22 annulus. In the first letter, the entire scope of the planned operations including workovers and sidetracks was listed. The purpose of the letter was to provide notice to the Commission that Unocal planned to dispose of wastes generated on Grayling. After talking with you and Dave Johnston, the second letter was sent which correctly noted that workover wastes were not eligible for annular disposal and that you only planned to dispose of drilling wastes into the G-22 annulus. This is correct. The G-22 annulus is presently permitted for annular disposal with a waiver to allow waste from Monopod to be hauled to Grayling and disposed into G-22. Since the annular disposal authorization is still valid, no special authorization is needed for disposal of drilling waste generated from wells on Grayling..Should other Grayling wells not mentioned in the letter be added to the schedule, please provide us notice. Good luck with the operations. Tom Maunder, PE AOGCC Tom Maunder <tom maunder.~,admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 6/7/02 8:28 AM Dan Wiliiamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Gas Co~'~s. Commission Anchorage May 8,2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Mr. Tom Maunder Proposed Annulus Disposal of Drilling Waste from Grayling Platform Wells to Grayling G-22 Dear Mr. Maunder: The purpose of this letter is to clarify Unocal's intention to inject approved drilling wastes as defined in 20 AAC 25.080 (h) from the upcoming drilling activity on the Grayling platform well G-12RD, in the G-22 annulus. At no time will wastes from work over operations on the G- 7WO, G-29WO, and the G-34WO wells be injected into the G-22 annulus for disposal. The Grayling G-22 well was approved for annular injection of drilling waste from the Monopod platform on November 6, 2001, Approval No. 301-304. If the Commission has no objectionS to the disposal of drilling wastes from the Grayling platform wells listed above into the G-22 well, please have an authorized representative sign and return this letter. ., If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. Sincerely, Dan Williarfison Drilling Manager Approved by order of the Commissioner Date Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) May 8, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Mr. Tom Maunder Proposed Annulus Disposal of Drilling Waste from Grayling Platform Wells to Grayling G-22 Dear Mr. Maunder: The purpose of this letter is to clarify Unocal's intention to inject approved drilling wastes as defined in 20 AAC 25.080 (h) from the upcoming drilling activity on the Grayling platform well G-12RD, in the G-22 annulus. At no time will wastes from work over operations on the G- 7WO, G-29WO, and the G-34WO wells be injected into the G-22 annulus for disposal. The Grayling G-22 well was approved for annular injection of drilling waste from the Monopod platform on November 6, 2001, Approval No. 301-304. If the Commission has no objections to the disposal of drilling wastes from the Grayling platform wells listed above into the G-22 well, please have an authorized representative sign and return this letter. .. If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. Sincerely, Dan Willia~son Drilling Manager Approved by order of the Commissioner Date Unocal Corporation ~, P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALi Dan Williamson Drilling Manager 5/8/2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Tom Maunder Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G-22 Mr. Maunder: Enclosed is the final report on annulus disposal A~R~ oil base mud (OBM)liquid waste into the G-22 annulus as required by the Sundry-A-ppplication Approval #301-304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G-22 annulus while drilling at A-15RD. The following is the total volumes disposed in G-22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls G-15RD 1269 2160 3429 G-28RD 203 700 903 G-26RD 823 2155 2978 A-15RD 1374 5067 -----~, 6441 Total ~ 13751 If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. ~~/~/~lia-msbn Drilling Manager AOGCC G-22 Monopod waste annular disposal final report Tim Billingsley Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G-22 Drilling Wastes From Monopod A-15RD Maximum Allowable Injection Pressure 2000 psi TVD'13 318" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry'sFlushes 12/9/2001 Inj-test 1 3 1600 FIW 0 338 0 338 12/9/2001 1 2 3 1600 9.9 450 338 450 676 12/10/20012 3 3 1750 10 198 338 648 1014 12/10/20013 X 3.5 1650 10 150 0 798 1014 12/11/2001Flush 4 3.5 1750 FIW 0 450 798 1464 2/14/2002 Flush 5 3.5 1650 FIW 0 338 798 1802 2/14/2002 4 6 4 1750 9 80 338 878 2140 2/27/2002 Flush 7 2.5 1100 FIW 0 40 878 2180 2/28/2002 Flush 8 3 1100 FIW 0 20 878 2200 3/2/2002 Flush 9 3 1200 FIW 0 20 878 2220 3/2/2002 5 X 3 1750 10.0 130 338 1008 2558 3/3/2002 6 X 3 1750 10 100 338 1108 2896 3/5/2002 7 10 1.75 1750 10 50 360 1158 3256 3/19/2002 8 11 4 1750 9 76 360 1234 3616 3/24/2002 9 12 1750 70 351 1304 3967 4/3/2002 flush 13 FIW 0 20 1304 3987 4/3/2002 10 14 4 1900 9.1 20 360 1324 4347 4/3/2002 11 15 4 1750 9.1 20 360 1344 4707 4/3/2002 12 16 3.5 1800 9.1 30 360 1374 5067 Total bbls injected .. ~ 6441 *Injection pressure is highest reading while injecting Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOr. ALI Dan Williamson Drilling Manager April 8, 2002 RECF \/ b APR 2002 0il & c4as cor~s, c;ommlssion Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commissioner Camille Taylor Re: Drilling Waste Disposal of Oil-based Mud Commissioner Taylor: Unocal is currently disposing oilrbased drilling waste from well A-15RD into the annulus of the G-22 well on the Grayling platform as approved under Sundry Approval No. 301-304, dated November 6, 2001. Some of the oil-based drilling waste is extremely viscous and may not be pumped into the annulus without exceeding pressure limitations imposed under the annular disposal requlations. Under 20 AAC 25.080(h)(1), water may be added when needed to facilitate pumping of drilling mud or cuttings. However, the addition of water to oil- based mud will result in an emulsion that will exacerbate viscosity and compound disposal problems. Unocal respectfully requests a determination by the commission that the addition of small quantities of diesel for the limited purpose of facilitating the pumping of oil-based muds and cuttings is an acceptable drilling waste under 20 AAC 25.080(h)(3). Based on Unocal's reading of 20 AAC 25.080(h)(1)-(3), we believe the commission may determine that diesel used to augment the disposal of oil-based muds and cuttings is a drilling waste associated with the act of drilling a well, in the same manner that water was included under 20 AAC 25.080(h)(1 ), and therefore, an acceptable. practice for annular disposal. If your or your staff have any questions or care to discuss this request further, please contact me at 263-7677 or Tim Billingsley at'263~7659. ~cerely, A Drilling Manager . ~HY-U{-2UU2 'I'UE 1U:44 8H Unocal Corporal:ion P,O, 8ox 196247 Anchorage, AK 99501 Telephone (g07) 263-7660 UNO . L F, LI] Dan Williamson Drilllt~g Man~,get April 4, 2002 Alaska Oil and Gas Conservation Commission 333 West 7~h Avenue Anchorage, Alaska 99501 Attn; Re: Commissioner Julia Heusser Proposed Annulus Disposal of Drilling Waste from Grayling Platform Wells to Grayling G~22 Commissioner Heusser: ..................... Unocal intends to dispose of drilling wastas-~.{~3 t. be-ua~oming drilling Gd'ivitie~ .on the Grayling platform wells: G-12RD, G-gRD,~G-30RD, and(~4W~)~n the G-22 annulus. The Grayling G-22 well was approved for annular injection of~[FllT['~g waste from the Monopod platform on November, O, 2001, Approval No. 301-304. To date a total of 12,160 bbls was disposed in G-22. Unocal does not intend to inject greater than 35,000 bbls of total waste through the annular space of the well. Pending no objections, the disposal of wastes from the Grayling platform wells into tile G.~,22 well should commence about May 6, 2002. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager ? ZOO Post-it" Fax Note 7671 Eh~ene #- ' I e,-/-& 7-s - _ IPages - Pl~onc # Fax # Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL( 10/25/01 RECEIVED OCT 2 5 Alaska Oil & Gas Cons. Commissior~ Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Proposed Annulus Disposal of Drilling Waste from Monopod A-15RD and A-29RD to Grayling G-22 Commissioner Heusser: On 8/1/01, Unocal requested permission to dispose of drilling waste from the Monopod platform at King Salmon annulli. However, the sheen observations starting on 9/12/01 at King Salmon caused the shut down of annulus disposal at the King Salmon platform and the upcoming Monopod drilling waste will not be disposed of at the King Salmon platform. Unocal now requests permission from the AOGCC to dispose of liquid-only waste from upcoming drilling on the Monopod platform in the G-22 annulus on the Grayling platform as per the attached Sundry Application (Form 10-403). The G-22 annulus has previously been used for liquid drilling waste disposal in 1998 and 2000. A total of 7310 bbls was disposed in G-22 while drilling 3 wells. Solid drilling waste will not be transported to Grayling for a grind and inject operation, The solids from A-15RD and A-29RD will be transported and stored at the Bruce platform. After air quality permit issues are resolved, the cuttings will be ground and injected at the Bruce injection well. The recent problems with annulus disposal at King Salmon platform should not occur at Grayling G-22. The 13-3/8" shoe is much deeper at G-22 (5548' MD/4977' TVD for G-22 vs. 2591' MD/2302' TVD for K-19). The disposal pressures at G-22 will also be' much higher at 1200-1400 psi compared to only 250 psi at K-19. The past history of 7310 bbls of oily waste disposed in G-22 was without incident. The oil-based mud drilling phase at A-15RD should commence about December 1, 2001 so your timely consideration for approval of this Sundry is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Sincerely, Drilling Manager AOGCC letter Monopod Waste to Grayling. doc ORIGINAL Tim Billingsley STATE OF ALASKA, ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Annular Injection 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: RT 99' above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface Grayling Leg 3, Conductor No.1 8. Well number 1413' FEI, 1789' FSL, Sec 29, T9N, R13W, S.M. Grayling G-22 At top of productive interval 9. Permit number 2091' FNL, 3361' FEL, Sec 32, T9N, R13W S.M. at 8881' TVD 75-16 At effective depth 10. APl number 2553' FNL, 3761' FEL, Sec 32, T9N, R13W, S.M. at 9908' TVD 50-133-20272-00 At total depth 11. Field/Pool 2579' FNL, 3791' FEL, Sec 32, T9N, R13W S.M. at 9984' TVD McArthur River Field 12. Present well condition summary Total depth: measured 11335' feet Plugs (measu red) true vertical 9984' feet Effective depth: measured 10,980 feet PXN Plug in nipple true vertical 9,670' feet Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" D riven 360' 360' Conductor 629' 20' 1125 ou.ft. 629' 629' Surface 5548' 13-3/8" 5802 cu.ft. 5548' 4977' Intermediate Production 11335' 9-5/8" 1840 cu.ft. 1133~=~J J"'""~% r,-., % ,j.=- r9¢84, Liner IVI::: LJ Perforation depth: measured (See attachment) true vertical OCT 2 5 ZO01 Tubing (size, grade, and measured depth) Single 4-1/2" 12.6 Ib/ft L-80 Butt at 9.978' Alaska 0il & Gas Cons, Commission Anchorage Packers and SSSV (type and measured depth) Baker 3H Packer set at 9,898' Otis "BWH" Packer set at 10,980' 18. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: "14. Estimated date for commencing operation 15. Status of well classification as: 12/1/01 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby~%.that ~ ~~~ t~,e fo~g.oiJ~g is true and correct to the best of my knowledge. Signed:~ . _ Title: Drilling Manager Date./. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test ___ Location clearance Mechanical Integrity Test____ Subsequent form required ORIGINAL SIGNED BY' Approved by order of the Commissioner D Taylor Seamount, Commissioner Date J J/O~./(~ / Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Grayling G-22 Annulus Injection Details Re: Information Requested under Section 20 AAC25.080 , o , e 5, . Annulus for disposal: Grayling G-22 13-3/8" x 9-5/8" Casing Annulus The 13-3/8" casing was set in 1975 at 5,548' MD/4977' TVD. The depth to the base of freshwater aquifers and permafrost. At 3,000 feet TVD, the formation waters start to exceed 6000 ppm chlorides. This is well above the 4,977' TVD of the 13 3/8" casing which is cemented to surface. There is a freshwater exemption for the Trading Bay platforms. There is no permafrost present in Cook Inlet. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to surface. The 13-3/8" shoe is set at 4977' TVD. This corresponds to the approximate depth of Middle Tyonek formation. The waste is expected to be confined within this strata as this is a primary gas trap in the McArthur River Field with no evidence of surface breaching. List of all publicly recorded wells within one-quarter mile radius and all publicly recorded water wells within one mile of the well that will be receiving the waste. The attached Property Plat shows the adjacent wells to Grayling G-22. The G-22 wellbore is an excellent annulus disposal candidate because it has a shallow kick-off point and is directionally drilled to the southwest, away from most of the other Grayling wells. The tick marks on the well paths are in 2000' increments of TVD. The wells that are within 1¼ mile of G-22's shoe depth of 4977' TVD on the plan view map are at considerably deeper depths. Types and maximum volume of waste to be disposed of and the estimated density. Only liquid waste from Monopod drilling will be transported to the Grayling platform. The solid drill cuttings will be transported and stored at the Bruce platform where they will be ground and injected in the Bruce disposal well. The liquid waste sent to the Grayling platform will consist of appx 9.0 ppg oil base mud mixed with high concentrations of fresh wash water. (approximately 90/10 ratio of water/OBM). The density of the waste mud/fresh water will be approximately 8.8 ppg. The seawater will be injected ahead and behind the waste slurry injections. The estimated volume to be disposed of is 3000 bbls OBM/Water and 6000 bbls seawater. Description of any waste sought to be determined as drilling waste under (h)(3) Section 20 AA C 25.080(3) Other substances that the commission determines upon application are wastes associated with the act of drilling a well permitted under 20AAC 25.005. None at this time. X:\TIMB\Grayling\G-22 ann disp\G-22 ann disp 403 Attachment.doc 7e Estimate of the maximum anticipated surface pressure at the outer casing shoe during disposal operations. The estimated pressure for injection was derived from the two LOT's performed prior to initial annulus injection in.July 1998. The first leak off occurred at 1510 psi and the second LOT indicated a leak off at 1525 psi. In actual practice during the injection of wastes while drilling Grayling G-15RD, leak off occurred between 1200 and 1400 psi. The two leak off tests indicate a fracture gradient at the 13-3/8" shoe of approximately .745 psi/ft ge Details that show that the shoe of the outer casing is set below the base of the permafrost, if present, and any freshwater aquifer is adequately cemented to provide zonal isolation, the information relied upon and submitted must include A) cementing records and B) a cement quality log or formation integrity records The lowest most point of fresh water aquifers as detailed in No. 2 above is 3000' TVD. The 13-3/8" casing is set at 4,977' TVD which is below the lowest known freshwater aquifer. A) Cementing records: The 13-3/8" surface casing was cemented in two stages via a DV tool at 2733'. After cementing the first stage the DV collar was opened and 260 sx of excess cement was circulated from the well. The second stage entailed pumping 1470 sx (2822 cu.ft.) from the DV to the surface. As the annular volume was 2831 cu ft with 50% excess in open hole it is assumed that cement reached surface although there was no mention in the daily reports to substantiate or contradict that. (The Permit to Drill and the Drilling Program called for cement to surface.) The 9-5/8" casing was set at 11,135'. The Drilling Program called for cementing the 9- 5/8" casing to 1500' above the top of the "G" Zone. The CBL/VDL log run (6-22-75) after the cement job indicates the top of cement at approximately 9100'. B) CBL or formation integrity records: Them was no cement bond log run on the 13-3/8" surface casing. Two LOT's were performed prior to initial annulus injection in July 1998. The first leak off occurred at 1510 psi and the second LOT indicated a leak off at 1525 psi. In actual practice during the injection of wastes while drilling Grayling G-15RD, leak off occurred between 1200 and 1400 psi. The two leak off tests indicate a fracture gradient at the 13-3/8" shoe of approximately .745 psi/ft e Details that show that the inner and outer casing strings have sufficient strength in collapse and burst to withstand the anticipated pressure of disposal operations. Casing Details indicate that the inner and outer casing strings have sufficient strength to withstand the anticipated pressure of disposal operations. 13-3/8" Casing 61 and 68 lb/ft, K-55 Burst: 3090 psi/3450 psi Collapse: 1540 psi/1950 psi 9-5/8" Casing X:\TIMB\Grayling\G-22 ann disp\G-22 ann disp 403 Attachment.doc 47 lb/ft, N-80/P-110/S-95 Burst: Minimum 6870 psi Collapse: Minimum 4750 psi 10. 11. 12. 13. The downhole pressure obtained during a formation integrity test conducted below the outer casing shoe. The downhole pressure was derived from the two LOT's performed prior to initial annulus injection in July 1998. The first leak off occurred at 1510 psi and the second LOT indicated a leak off at 1525 psi. The two leak off tests indicate a fracture gradient at the 13-3/8" shoe of approximately .745 psi/ft or 3700 psi. Identification of the hydrocarbon zones, if any above the depth to which the inner casing is cemented. Hydrocarbon bearing formations above the top of cement at approximately 9100' MD to the 13-3/8" casing shoe at 4977' TVD are gas producing sands of the Lower and Middle Tyonek. Given that all gas sands present below the 13 3/8" casing shoe are below the lowest known gas, and that all records indicate that the 13 3/8" casing has good cement bond, all injected volumes should enter either water-bearing sands or the water-leg of gas beating sands. Given the minute amount of expected waste disposal volume compared to the volume of the sands being disposed into, reservoir effects would be insignificant. Therefore, there is no significant risk to gas reserves as a result of the proposed disposal project. Duration of Disposal, not to exceed 90 days: The A-15RD well is anticipated to take 70 days to drill beginning approximately November 10. The first hole section will be drilled with water based mud so no oily liquid waste will be brought to Grayling G~22 for disposal until the second hole section starts to be drilled on approximately December 1, 2001. The A-15RD drilling will finish on approximately Jan 20, 2002. The second redrill at Monopod will be A-29RD pending reservoir results from A-15RD. Drilling with oil-based mud could commence on Jan 20, 2002 and end on March 20, 2002. If both Monopod wells are drilled, the 90 day limit will probably be exceeded for liquid disposal into G-22. Unocal requests permission to exceed the 90 day limit. Summary of Previous Disposal The G-22 9-5/8" x 13-3/8" annulus has previously been used for disposing of liquid drilling waste. From 6/30/98 to 9/1/98, 3429 bbls of liquid waste generated while drilling G-15RD were disposed in G-22. From 6/18/00 to 7/22/00, 903 bbls of liquid waste generated while drilling G-28RD were disposed in G-22. From 7/22/00 to 8/29/00, 2978 bbls of liquid waste generated while drilling G-26RD were disposed in G-22. X:\TIMB\Grayling\G-22 ann disp\G-22 ann disp 403 Attachment.doc The above three redrills total disposed volume into G-22 was 7310 bbls. 14. 15 16 The well where the drilling waste to be disposed of was or will be generated The liquid waste will come from the drilling of Monopod A-15RD and A-29RD. Only liquid waste will be coming from Monopod for disposal into G-22's annulus. The cuttings will be stored, ground and injected at the Bruce platform. If the operator proposes not to comply with a limitation established in (d) of this section, an explanation of why compliance would be imprudent. d (4) Through the annular space of a well not located on the same platform as the drilling operation generating the drilling waste. There are no available annuli on Monopod suitable for disposal due to the presence of hydrocarbons beneath the surface casing shoes. Unocal proposes to bring oily liquid waste generated from the drilling of Monopod A- 15RD and A-29RD to the Grayling G-22 for disposal. The solid cuttings will be placed in drums and shipped to Bruce platform for storage and eventual grind and injection once air quality permits are approved in 2002. It would be even more costly to transport and store liquid waste on the Bruce platform awaiting air quality permit approval. It would be much more economical to bring the liquid waste to the Grayling platform and dispose of it under this proposed annulus disposal operation while drilling the A-15RD well in December 2001-January 2002 and the A-29RD well in Jan 2002 to March 2002. Any additional data required by the commission to confirm containment of drilling waste: The attached spider plat mentioned in item No. 4 above demonstrates that G-22's surface casing point is far away from other wellbores on the Grayling. The depth and location of the G-22 surface casing shoe is a good indication that there will not be a conduit for communication to surface. X:\TIMB\Grayling\G-22 ann disp\G-22 ann disp 403 Attachment.doc UNOCAL ) RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5 000# Sand Fill on PXN plug =-- G-1 --- G-2 --- G-3 --= G-4 ~ G-5 --- B-1 --= B-2 =- B-2 -= B-3 --- B-4 B-6 Top of Junk @ 11,254' RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.5;i @ 4200' SIZE 26" 20" 13-3/8" 9-5/8" %5/8" 9-5/8" Tubing: 4-1/2" WI' Trading Bay Unit Well # G-22 Actual Completion (11/98) CASING ANI) TUBING I)ETAIL MI) GRADE CONN ID TOt' Nil) TVI) B'FM. BTM 1" wall 94 61 & 68 47 47 47 12.6 H-40 N-80 P-Il0 S-95 L-80 24.0 Surf. 356' 356' Butt 19.124 Surf. 629' 629' Butt 12.415 Surf. 5548' 4977 Butt 8.681 Surf 7016' 6231' Butt 8.681 7016 10,087' 8915' Butt 8.681 10,087' 11,335' 9984' Imp. Butt 3.958 40.6' AB Mod 9978' 8746' N~(). Depth 40.60' 9897' 9898' 9903' 9945' 9978' 10,968' 10,980' 10,981.55' JEWELRY I)ETAH., ID 3.958" 3.958" 4.75" 4.820" 3.813" 3.958" 4.0" 2.635" 2.99" Item Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt x 4-1/2" EUE top Baker Anchor Tubing Seal Assy. (P/N451-40-9999) Baker Model 3H P Packer. (P/N 409--06-9999) Baker 5.22' Millout Ext. (P/N 995--09-9999) Baker "X" Nipple (P/N 995--08-9999) Baker Ball Seat Sub (P/N 469-21-999) Otis "BWH" Perm Pkr (10,961' D1L) 3-1/2" Otis "XN" Nipple, w/2.75" PXN plug WLREG Zone G-1 G~2 G-3 G-4 G-5 G-5 B-I B-2 B-2 B-3 B-4 B-5 B-5 B-6 G-5 G-4 G-3 G-2 G-1 Top 10061' 10115' 10178' 10230' 10370' 10590' 10595' 10643' 10742' 10762' 10827' 10984' 11081' 11115' 10,375' 10230' 10190' 10118' 10065' PERIi'ORATION DATA Btm Amt SPF 10095' 34' 4 10154' 39' 4 10218' 40' 4 10300' 70' 4 10430' 60' 4 10592' 2' 4 10629' 34' 6/4 10734' 91' 20/8/4 10752' 10' 4 10815 53' 16/4 10952' 125' 16/12/8 11022' 38' 4 11082' 1' 4 11145' 30' 4 10430' 55' 6 10280' 50' 6 10220' 30' 6 10133' 15' 6 10092' 27' 6 Date Present Condition 11/19/89Open for injection 11/19/89Open for Injection 11/19/89Open for Injection 11/19/89Open for Injection 11/19/89Open for Injection 6/24/75 Sqz for Isolation 11/16/89Open for Injection 11/16/89Open for Injection 11/16/89Open for Injection 11/16/89Open for Injection 11/16/89Open for Injection 7/4/75 Isolated 6/22/75 Sqz for Isolation 7/3/75 Isolated 9/10/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection G-22 11-98.doc REVISED: 11/16/98 DRAWN BY: DNM Grayling Platform Surface Casing Cement Summary Well Casing Size Shoe MD Shoe TVD Cement Comments Volume (inches) (feet) (feet) (sacks) G-1 13.375 2,160 2,118 3,100 Returns at surface G-2RD 13.375 2,011 2,010 2,500 100 Sacks top job. G-3RD 13.375 2,209 2,176 2,500 G-4RD 16.000 621 621 1,200 G-5 16.000 591 591 1,395 Cement to surface. G-6 16.000 631 631 1,450 Good cement returns to surface. G-7 17.750 560 560 650 Good returns to surface G-8RD 16.000 590 556 1,250 Slight Returns G-9 16.000 623 621 1,300 Good returns to surface G-10 16.000 643 643 250 Top of cement @ 411' G- 11 16.000 694 694 1,300 G- 12 17.750 602 602 775 G- 13 17.750 602 602 750 G-14 17.750 600 600 700 Good cement returns. G-14ARD 17.750 520 520 700 Good returns to surface G-15 17.785 600 600 700 G-16 17.750 901 888 750 G- 17 17.750 560 560 675 IG-18 DPN 17.750 600 600 800 G- 19 17.750 520 520 700 Cement returns at surface G-20 : 20.000 1,200 -1,200 - 798 G-21 20.000 822 822 799 Cement returns at surface. Tested to 500 psi. G-22 20.000 629 629 661 Good returns. G-23 20.000 796 796 541 Good Cement returns. Tested to 500 psi. G-24 20.000 829 829 850 Cement returns at surface. Tested to 500 psi. G-25 20.000 816 816 780 Good Cement returns. Grayling Surf CSG CMT summary.xls 1/2 10/24/2001-- 11:20 AM Well Casing Size Shoe MD Shoe TVDi Cement Comments Volume (inches) (feet) (feet) (sacks) G-26 20.000 741 741 500 ~ G-27 20.000 821 821 600 Cement returns at surface G-28 20.000 828 828 660 G-29 20.000 911 911 1814 ft3 Good cement returns to surface. G-30 17.750 520 520 750 G-31 17.750 520 520 790 Cement returns at surface G-32 17.750 497 497 850 Lost returns after 650 sxs pumped. CSG tested to 400 psi. G-33 20.000 605 605 6,150 65 sack top job. No returns while cementing. CSG test to 700 G-34RD 20.000 616 616 1,000 Lost circ. 100 sack top job. G-36 DPN 20.000 599 599 800 Cement returns to suface after 690 ft3 pumped. G-40 16.000 1,929 1,929 1,898 Performed two top jobs: 500 sacks and 1,000 sacks. Grayling Surf CSG CMT summary.xls 2/2 10/24/2001--11:20 AM Grayling Platform Well G-22 Proposed Annulus Disposal 000 / SCALE IN / GRAY ~G'-i OR G- ~ Mile/Radius ~( G-22 13-3/8'' qasing Shoe ~ (4977' ~VD) I~ ~ ~ ~ L:~DraftingXProp PlotsX~BU-G~22-~NN-DISP~SAL. Dwg D G-3 -=8O Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCALe August 30, 2000 Mr. Dan Seamount AOGCC 3001 Porcupine Drive Anchorage, AK. 99501 '~'L.SVli i~ i COMM !_Ez~.ENG ~R ENG NRO SR GEOL ~ "'-~: GEOL GEOL ASST STAT TEC~ ~ .... Dear Mr. Seamount, Re: Summary of OBM Liquid Waste Iniected into Grayling G-22 Unocal has completed the injection of Oil Base Mud (OBM) liquid waste in Grayling G-22. As required by the Permit to Inject, we have provided a daily summary of the fluids disposed of in the G-22 casing annulus during the drilling of G-26RD and G. 2$RD. The total waste injected during the drilling of the two wells was as follows: Well Name OBM Waste Seawater Grayling G-28RD 203 Bbls 700 Bbls Grayling G-26RD 823 Bbls 2155 Bbls Total 1026 Bbls Total 2855 Bbls Should you have any questions or concerns please contact myself or the Drilling Engineer assigned to the project; Neil Magee at 263-7671. Yours faith~lly, D.R. Williamson Drilling Manager Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary for Drilling of G-26RD Day Date Hole Size Depth Footage Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) '(ft) (ft) (BBLS) (BBLS) (DRUMS) (DRUMS) (BBLS) (BBLS) (BBLS) 1 7/22/00 Abandon - - 13.0 13.0 72.0 2 7/23/00 Abandon - - 25.0 38.0 72.0 3 7/24/00 Abandon .... 38.0 72.0 4 7/25/00 Abandon .... 38.0 72.0 5 7/26/00 Abandon .... 38.0 72.0 6 7/27/00 Abandon - - - 12.0 50.0 106.0 7 7/28/00 Abandon - 7.0 57.0 133.0 106.00 350.00 7a 7/28/00 a 8.50 10,263 - - 57.0 27.0 8 7/29/00 8.50 10,294 31 1.05 1.05 - 57.0 41.0 9 7/30/00 8.50 10,362 68 2.31 3.37 - 57.0 56.0 10 7/31/00 8.50 10,760 398 13.53 16.90 37.0 94.0 56.0 11 8/1/00 8.50 10,878 118 4.01 20.91 20.0 114.0 56.0 12 8/2/00 8.50 11,137 259 8.81 29.72 20.0 134.0 62.0 13 8/3/00 8.50 11,366 229 7.79 37.50 35.0 169.0 62.0 14 8/4/00 8.50 11,425 59 2.01 39.51 12.0 181.0 62.0 15' 8/5/00 8.50 11,587 162 5.51 45.02 35.0 216.0 62.0 WellTD 16 8/6/00 Liner 11,587 - - 45.02 10.0 226.0 62.0 17 8/7/00 Liner 11,587 - - 45.02 21.0 247.0 170.0 170.00 375.00 18 8/8/00 .i Comp. 11,587 - _ 45.02 10.0 257.0 - 19 8/9/00 Comp. 11,587 - - 45.02 38.0 295.0 20 8/10/00 Comp. 11,587 42.0 337.0 42.0 135.00 360.00 21 8/11/00 Demob 11,587 - 337.0 110.0 160.00 360.00 22 8/12/00 Demob 11,587 - 337.0 110.0 23 8/13/00 Demob 11,587 13.0 350.0 157.0 24 8/14/00 Demob 11,587 19.0 369.0 157.0 25 8/15/00 Demob 11,587 - 369.0 - 160.00 360.00 26 8/16/00 Demob 11,587 - 369.0 36.0 . OBM Injection Summary G-22 for G-26RD.xls 1/2 8/30/00--9:29 AM Day Date Hole Size Depth Footage Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings VolUme Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (DRUMS) (DRUMS) (BBLS) (BBLS) (BBLS) 27 8/17/00 Demob 11,587 5.0 374.0 41.0 28 8/25/00 Demob 11,587 374.0 108.0 29 8/29/00 Demob 11,587 374.0 21.0 91.50 350.00 Total: 374.0 823 2,155 Drums full of OBM absorbents: 8.0 Note: Bruce/Dispose costs was estimated at $207/Drum. Flush injection is FIW Summary Total DRUMS of Cuttings from G-26RD Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus (B 374 2,978 OBM Injection Summary G-22 for G-26RD.xls 2/2 8/30/00--9:29 AM Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary for Drilling of G-28RD Day Date Hole Size Depth Footag~ Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 1 6/18/00 6.00 11,712 12 0.41 0.41 24.0 24.0 0 2 6/19/00 6.00 11,869 169 5.75 6.15 4.0 28.0 62.0 3 6/20/00 6.00 11,923 54 1.84 7.99 9.0 37.0 62.0 4 6/21/00 6.00 12,155 232 7.89 15.88 38.0 75.0 68.0 5 6/22/00 6.00 12,380 225 7.65 23.53 11.0 86.0 68.0 6 6/23/00 6.00 12,597 217 7.38 30.91 18.0 104.0 112.0 7 6/24/00 6.00 12,787 190 6.46 37.37 17.0 121.0 112.0 8 6/25/00 6.00 12,986 199 6.77 44.13 17.0 138.0 41.0 71.48 350.00 9 6/26/00 6.00 13,168 182 6.19 50.32 15.0 153.0 41.0 10 6/27/00 6.00 13,237 69 2.35 52.67 11.0 i64.0 41.0 11 6/28/00 6.00 13,357 120 4.08 56.75 14.0 178.0 46.0 12 6/29/00 6.00 13,455 98 3.33 60.08 12.0 190.0 46.0 13 6/30/00 6.00 13,580 125 4.25 64.33 15.0 205.0 64.0 14 7/1/00 6.00 13,660 80 2.72 67.05 7.0 212.0 64.0 15 7/2/00 6.00 13,819 159 5.41 72.45 14.0 226.0 64.0 16 7/3/00 6.00 13,950 131 4.45 76.91 13.0 239.0 64.0 17 7/4/00 6.00 14,160 210 7.14 84.05 18.0 257.0 77.0 18 7/5/00 6.00 14,203 43 1.46 85.51 5.0 262.0 92.0 19 7/6/00 6.00 14,310 107 3.64 89.15 12.0 274.0 92.0 20 7/7/00 6.00 14,491 181 6.15 95.30 16.0 290.0 93.0 21 7/8/00 6.00 14,660 169 5.75 101.05 14.0 304.0 75.0 Reclaim 18 bbls 22 7/9/00 6.00 14,746 86 2.92 103.97 14.0 318.0 75.0 23 7/10/00 6.00 14,914 168 5.71 109.68 10.0 328.0 75.0 24 7/11/00 6.00 15,065 151 5.13 114.82 16.0 344.0 75.0 25 7/12/00 6.00 15,251 186 6.32 121.14 18.0 362.0 86.0 26 7/13/00 Log 15,251 - - 121.14 12.0 374.0 86.0 27 7/14/00 Log 15,251 - - 121.14 14.0 388.0 86.0 OBM Injection Summary G-22 for G-28RD.xls 1/2 8/22/00--3:12 PM Day Date Hole Size Depth Footage Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 28 7/15/00 6.00 15,416 - - 121.14 17.0 405.0 86.0 Well TD 29 7/16/00 6.00 15,416 - - 121.14 9.0 414.0 86.0 30 7/17/00 Liner 15,416 - - 121.14 414.0 86.0 31 7/18/00 Liner 15,416 - - 121.14' 414.0 86.0 32 7/19/00 Liner 15,416 - - 121.14 12.0 426.0 86.0 33 7/20/00 Comp. 15,416 - - 121.14 426.0 86.0 34 7/21/00 Comp. 15,416 - - 121.14 426.0 - 132.00 350.00 35 7/22/00 Comp. 15,416 - _ 121.14 426.0 _ Total: 426.0 203 700 Drums full of OBM absorbents: 10.0 Note: Bruce/Dispose costs was estimated at $207/Drum. Flush injection is FIW. Summary ITotal DRUMS of Cuttings from G-28RD Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus 903 OBM Injection Summary G-22 for G-28RD.xls 2/2 8/22/00--3:12 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson Chairman THRU: Blair Wondzell P.I. Supervisor FROM: John Cris~~,~.~ Petroleum ~spector DATE: 05/22/2000 SUBJECT: NON- CONFIDENTIAL Blowout Preventer Test Grayling Platform Unocal's Grayling Platform TBUS G-22 PTD 75-16 Sundry #300-090 McArthur River Field Operator Rep.: Dou~ Niehaus Contractor Rep.: Donnie Fowler Op. phone: 776-6630 Rig phone: 776-6630 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 5000 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location yes Hazard: yes Standing Order: yes Annular: 3500 Choke: 5000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 passed Lower Kelly 1 passed Ball Type 1 passed Inside BOP I passed BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8" P Pipe Rams 1 3 1/2"x6" P Lower Pipe Rams 1 5" P Blind Rams 1 13 5/8" P Choke Ln. Valves 1 4" P HCR Valves 1 4" P Kill Line Valves 2 3" P Check Valve none CHOKE MANIFOLD: Quantity P/F No. Valves 12 P Man. Chokes 1 P Hyd, Chokes 2 P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector tested ok H2S Gas Detector tested ok ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3050 P After Closure 1300 200 psi Attained 32 sec. Full Pressure 3 min. 6 sec. Blind Covers (All Stations): yes N2 Bottles (avg): 5 btls. @ 2050 Test's Details I traveled to Unocals Grayling Platform to witness the initial BOP test on well G-22 in the McArthur River Field. This was initial BOP test before fishing parted tubing under Sundry Approval #300-090. N/U of BOP stack took longer than expected. I arrived approximately 24 hours early for BOP test. Total Test Time: 5 hours Number of Failures: .,cc: none Attatchments: none BOP Grayling PLT. 5-22-00jc.xls F'W: G-22 WFL Time & Event Subject: FW: G-22 WFL Time & Event Date: Mon, 24 Apr 2000 09:22:16 -0700 From: "Ruff, Christopher A" <ruffc~unocal.com> To: "Wondzell, Blair E -Vendor" <Blair_Wondzell~admin.state.ak.us> CC: "Tyler, Steve L.-Contract" <tylersl~Orion. Unocal.com> ! 7~-- o [6 Hopefully this is the information you were looking for. If you have any questions about the procedure, Steve Tyler is the best person to get you accurate answers. Thanks Chris Ruff ..... Original Message ..... From: Tyler, Steve L. -Contract Sent: Thursday, April 13, 2000 11:09 AM To: Ruff, Christopher A Subject: G-22 WFL Time & Event <<G-22 WFL Time & Events for AOGCC.xls>> Steve Tyler Unocal Alaska Con tra c t (907) 263-7649 (907) 263-7884 (907) 696-1837 tylerslSunocal, com Of fi ce Fax Home <<G-22 dwg. doc>> ~G-22 WFL Time & Events for AOGCC.xls Name: G-22 WFL Time & Events for AOGCC.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 ~i~]: G--~'2Tdwg.d~=;~~ ................... ' ...................... Type: Microsoft Word Document (application/msword)] ]..~.~.?,~!ng: base64 of 1 11/1/00 10:58 AM Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL Dan Williamson Drilling Manager April 3, 2000 Mr. Robert Christensen Chairmain AOGCC 3001 Porcupine Drive Anchorage, AK. 99501 Dear Mr. Christensen, Re' Notice of Intent to Inject Waste Liquid in Grayling G-22 ORIGINAL Unocal is in the planning stages of designing a horizontal sidetrack from well Grayling G-28 in early May 2000. The sidetrack will consist of approximately 2000' of 8-1/2" hole drilled with water based mud and 3800' of 6" hole drilled with oil based mud. This will be much the same as the sidetrack we performed on G-15 in July 1998. As in the case during the drilling of G-15, we would like to request your approval to dispose of OBM liquid waste in the G-22 9-5/8" x 13-3/8" casing annulus. We have provided a summary of the Grayling Platform surface cement jobs and the summary of the fluids disposed of to date in the G-22 casing annulus. The attachment titled Information Requested Under Section 20AAC 25.080 provides information relevant to this request for annular disposal of drilling waste. If no further issues are raised we will plan on re-instating injection of OBM liquid waste once OBM drilling operations commence on the Grayling Platform. Should you have any questions or concerns please contact myself or the Drilling Engineer assigned to the project; Neil Magee at 263-7671. Yours faithfu~f, ,, D.R. Williamson Drilling Manager RECEIVED Alaska 0il & Gas Cons. Commission Anch0rag~ 1. Type of Request: OIL STATE OF ALASKA ( ALASKA AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon: Suspend: Operation shutdown: Re-enter suspended well: 2. Name of Operator Alter casir;~l: Repair well: Plugging: Time extension: Change approved program: Pull tubing: Varia'--~ce: Perforate: Union Oil Company of Califonia (UNOCAL) 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of well: Development: Exploratory: Stratigraphic: Service: X 4. Location of well at surface Grayling Leg 3, Conductor No.1 1413' FEI, 1789' FSL, Sec 29, T9N, R13W, S.M. At top of productive interval 2091' FNL, 3361' FEL, Sec 32, T9N, R13W S.M. at 8881' TVD At effective depth 2553' FNL, 3761' FEL, Sec 32, T9N, R13W, S.M. at 9908' TVD At total depth 2579' FNL, 3791' FEL, Sec 32, T9N, R13W S.M. at 9984' TVD 12. Present well condition summary Stimulate: Other: Annular Injection 6. Datum elevation (DF or KB) RT 99' above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number TBUS G-22 9. Permit number 75-16 10. APl number 50-133-20272-00 11. Field/Pool McArthur River Field Total depth: measured 11335' feet Plugs (measured) true vertical 9984' feet Effective depth: measured 10,980 feet PXN Plug in nipple true vertical 9,670' feet ORIGINAL Casing Length Size Cemented Structural 360' 26" Driven Conductor 629' 20' 1125 cu.ft. Surface 5548' 13-3/8" 5802 cu.ft. Intermediate Production 11335' 9-5/8" 1840 cu.ft. Liner Perforation depth: measured (See attachment) true vertical Measured depth 360' 629' 5548' 11335' TrUe vertical depth 360' 629' 4977' 9984' RECEIVED Tubing (size, grade, and measured depth) Single 4-1/2" 12.6 Ib/ft L-80 Butt at 9.978' Packers and SSSV (type and measured depth) Baker 3H Packer set at 9,898' Otis "BWH" Packer set at 10,980' 13. Attachments Description summary of proposal: X Detailed operations program: APR 05 2000 Alaska 0il & Gas Cons. Commission sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 5/1/2000 16. If proposal well verbally approved: Oil: Gas: Name of approver Date approved Service: Water Injector 17. I hereby certify that thee f,,of~e_going is true and correct to the best of my knowledge. ~ Title: Drilling Manager Suspended: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.,. BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~5 IApproval No. Approved by order of the Commissioner ORIGINAL SIGNED, BY Robert N. Christenson Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Grayling G-22 Perforation Record (Revised 3-16-00) Date Interval (MD) Interval (TVD) Status Formation 6-22-75 11081-11082' 9957-9965' Squeezed HB-5 6-23-75 10708-10710' 9429-9431' Squeezed HB-2 6-24-75 10590-10592' 9327-9329' Squeezed HB-1 7-3-75 11115-11145' 9787-9814' Isolated w/packer HB-6 7-4-75 10984-11022' 9671-9705' Isolated w/packer HB-5 7-7-75 10911-10936' 9607-9629' Injection HB-4 7-14-75 10685-10700' 9409-9422' Injection HB-2 7-15-75 10670-10700' 9396-9422' Injection HB-2 7-16-75 10832-10862' 9537-9564' Injection HB-4 7-17-75 10768-10788' 9480-9498' Injection HB-3 7-18-75 10602-10622' 9337-9355' Injection HR-1 12-18-75 10832-10862' 9537-9564' Injection HB-4 12-18-75 10768-10788' 9480-9498' Injection HB-3 4-2-76 10670-10700' 9396-9422' Injection HB-2 4-2-76 10602-10622' 9337-9355' Injection HB- 1 6-29-78 10602-10622 9337-9355' Injection HB-1 6-29-78 10670-10700' 9396-9422' Injection HR-2 6-30-78 10768-10788' 9490-9498' Injection HB-3 7-1-78 10832-10862' 9537-9564' Injection HB-4 7-1-78 10886-10904' 9584-9600' Injection HB-4 11-16-89 10595-10629' 9339-9367' Injection HB-1 11-16-89 10643-10734' 9379-9456' Injection HB-2 11-16-89 10742-10752' 9463-9472' Injection HB-2 11-16-89 10762-10815' 9480-9526' Injection I-lB-3 11-16-89 10827-10952' 9536-9645' Injection HB-4 11-19-89 10061-10095' 8891-8920' Injection "G" Zone 11-19-89 10115-10154' 8936-8969' Injection "G" Zone 11-19-89 10178-10218' 8989-9022' Injection "G" Zone 11-19-89 10230-10300' 9032-9091' Injection "G" Zone 11-19-89 10370-10430' 9150-9201' Injection "G" Zone 9-11-98 10065-10092' 8885-8908' Injection G- 1 9-11-98 10118-10133' 8930-8943' Injection G-2 9-11-98 10190-10220' 8990-9015' Injection G-3 9-11-98 10230-10280' 9023-9065' Injection G-4 9-11-98 10375-10430' 9144-9190' Injection G-5 RECEIVED Alaska Oil 8, Gas Cons. Commission Anchorage Grayling G-22 Annulus Injection Details Re: Information Requested Under Section 20 AAC25.080 Annulus for disposal: Grayling G-22 13-3/8" x 9-5/8" Casing Annulus The 13-3/8" casing was set at 5,548'. Casing was cemented in two stages via a DV tool at 2733'. After cementing the first stage the DV collar was opened and 260 sx of excess cement was circulated from the well. The second stage entailed pumping 1470 sx (2822 cu.ft.) from the DV to the surface. As the annular volume was 2831 cuft with 50% excess in open hole it is assumed that cement reached surface although there was no mention in the daily reports to substantiate or contradict that. (The Permit to Drill and the Drilling Program called for cement to surface.) The 9-5/8" casing was set at 11,135'. The Drilling Program called for cementing the 9- 5/8" casing to 1500' above the top of the "G" Zone. The CBL/VDL log run (6-22-75) after the cement job indicates the top of cement at approximately 9100'. . The depth to the base of freshwater aquifers. At 3,000 feet TVD the formation waters start to exceed 6000 ppm chlorides. This is well above the 4,977' TVD of the 13 3/8" casing which is cemented to surface. 0 . A Stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to surface. The 13-3/8" shoe is set at 4977' TVD. This corresponds to the approximate depth of Middle Tyonek formation. The waste is expected to be confined within this strata as this is a primary gas trap in the McArthur River Field with no evidence of surface breaching. List of all publicly wells within one-quarter mile radius. The attached Property Plat defines the adjacent wells to Grayling G-22. J Types and maximum volume of waste to be disposed of and the estimated density. The waste will consist of 9.0 ppg oil base mud mixed with high concentrations of fresh wash water. (approximately 90/10 ratio of water/OBM). The density of the waste mud/fresh water will be approximately 8.8 ppg. The seawater will be injected ahead and behind the waste slurry injections. The estimated volume to be disposed of is 1000 bbls OBM/Water and 3000 bbls seawater. . Description of any waste sought to be determined as drilling waste Section 20 AAC 25.080. 0 8~ e (3) Other substances that the commission determines upon application are wastes associated with the act of drilling a well permitted under 20AAC 25.005. Estimate of the maximum anticipated surface pressure at the outer casing shoe during disposal operations. The estimated pressure for injection was derived from the two LOT's performed prior to initial annulus injection in July 1998. The first leak off occurred at 1510 psi and the second LOT indicated a leak off at 1525 psi. In actual practice during the injection of wastes while drilling Grayling G-15RD, leak off occurred between 1200 and 1400 psi. The two leak off tests indicate a fracture gradient at the 13-3/8" shoe of approximately .745 psi/ft Details that show that the shoe of the outer casing is set below the base of the permafrost, if present and any freshwater aquifer is adequately cemented to provide zonal isolation. The lowest most point of fresh water aquifers as detailed in Number 8 above is 3000' TVD. The 13-3/8" casing is set at 4,977' TVD which is below the lowest lmown freshwater aquifer. The cementing records detailed under No. 1 above indicate that the 13-3/8" was cemented to surface. Details that show that the inner and outer casing strings have sufficient strength in collapse and burst to withstand the anticipated pressure of disposal operations. Casing Details indicate that the inner and outer casing strings have sufficient strength to withstand the anticipated pressure of disposal operations. 13-3/8" Casing 61 and 68 lb/ft, K-55 Burst: 3090 psi/3450 psi Collapse: 1540 psi/1950 psi RECEIVED 9-5/8" Casing 47 lb/ft, N-80/P-110/S-95 Burst: Minimum 6870 psi Collapse: Minimum 4750 psi t),{:R 0,5 2.000 Ala~a Oil & Gas Cons. Commission Anchorage 10. The downhole pressure obtained during a formation integrity test conducted below the outer casing shoe. The downhole pressure was derived from the two LOT's performed prior to initial annulus injection in July 1998. The first leak off occurred at 1510 psi and the second LOT indicated a leak off at 1525 psi. The two leak off tests indicate a fracture gradient at the 13-3/8" shoe of approximately .745 psi/ft or 3700 psi. 11. Identification of the hydrocarbon zones, if any above the depth to which the inner casing is cemented. There are no hydrocarbon bearing formations above the top of cement at approximately 9100' MD to the 13-3/8" casing shoe at 4977' TVD. The Lower and Middle Tyonek Sands in this structural position are wet and low on structure. 12. 13. 14. The 13 3/8" casing has good cement bond, all injected volumes should enter either water- bearing sands or the water-leg of Lower and Middle Tyonek Sands. There is no significant risk to gas reserves as a result of the proposed disposal project. Duration of Disposal: The well is anticipated to take 54 days to drill. During that time we anticipate that we will be disposing of approximately 1000 bbls of OBM waste mixed with fresh water and 2000 bbls of seawater into the 9-5/8" x 13-3/8" annulus. Summary of Previous Disposal This has been provided as Attachment "Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings" The well where the drilling waste to be disposed of was or will be generated The waste will come from the drilling of G-28RD. RECEIVED AJaska Oi~ & Gas Cons~ Commissior~ Anchr~rag~ UNOCAL RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# Trading Bay Unit {' Veil # G-22 Actual Completion (11/98) CASING AND TUBING DETAIL ~ MD MD TVD SIZE WT GRADE CONN ID TOP BTM. BTM 26" l" wall 24.0 Surf. 356' 356' Sand Fill on PXN ,plug 20" 13-3/8" 9-5/8" 9-5/8" 9-5/8" Tubing: 4-I/2" 2 G-1 -=- G-2 -~ G-3 --- G-4 -= G-5 94 BuR 19.124 Surf. 629' 629' 61&68 H-40 BuR 12.415 Surf. 5548' 4977 47 N-80 BuR 8.681 Surf 7016' 6~31' 47 P-110 BuR 8.681 7016 10,087' 8915' 47 S-95 BuR 8.681 10,087' 11,335' 9984' 12.6 L-80 Imp. BuR 3.958 40.6' 9978' ' 8746' AB Mod -~ B-1 =- --- B-2 _=- B.3 --= ~.4 ~;~;. ,; Top of Junk RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34,$~1 @ 4200' jEWELRY DETAIL ,Depth ~P_ ..l.~em 40.60' 3.958" 9897' 3.958" 9898' 4.75" 9903' 4.820" 9945' 3.813" 9978' 3.958" 10,968' 4.0" 10,980' 2.635" 10,981.55' 2.9,9" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt x 4-1/2" EUE top Baker Anchor Tubing Seal Assy. (P/N451-40-9999) Baker Model 3H P Paclmr. (P/N 409--06-9999) Baker 5.22' Mil]om Ext. (P/N 995--09-9999) Baker "X" Nipple (P/N 995--08-9999) Baker Ball Seat Sub (P/N 469-21-999) Otis "BWH" Penn Pkr (10,961' DIL) 3-1/2" Offs "XN" Nipple, w/2.75" PXN plug WLREG Zone Top Btm G-1 10061' 10095' G-2 10115' 10154' G-3 10178' 10218' G-4 10230' 10300' G-5 10370' 10430' G-5 ' '10590"10592' B-1 10595' 10629' B-2 10643' 10734' B-2 10742' 10752' B-3 10762' 10815 B-4 10827' 10952' B-5 10984' 11022' B-5 11081' 11082' B-6 11115' 11145' G-5 10,375' 10430' G-4 10230' 10280' G-3 10'190' 10220' G-2 10118' 10133' G-1 10065' 10092' PERFORATION DATA Amt SPF 34' 4 39' 4 40' 4 70' '4 60' 4 2' 4 34' 6/4 91' 20/8/4 10' 4 53' 16/4 125' 16/12/8 38' 4 1' 4 30' 4 55' 6 50' 6 30' 6 15' 6 27' 6 Date Present Condition 11/19/89Open for injection 11/19/89Open for Injection 11/19/89Open for Injection 11/19/89Open for Injection 11/19/89Open for Injection 6/24/75 Sqz for Isolation 11/16/89Open for Injection 11/16/89Open for Injection 11/16/89Open for Injection 11/16/89Open for Injection 11/16/89Open for Injection 7/4/75 Isolated '6/22/75 'Sqz for Isolation 7/3/75 Isolated 9/10/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection RECEIVED G-22 11-98.doc . Alaska 0il & Gas Coas. Commission Anchoraflo REVISED: 11/16/98 DRAWN BY: DNM K- G-l? K-10RD'""-- K-1 ADL-18777~ Unocal Forcenergy G-15 G-29RD G-13 G-27 30 G-19 -to GRAY~! AD L-17594-1,A Unocal Forcenergy D-40RD D-28 UNOr. A. Le Trading Bay Unit Grayling Platform Well G-22 PROPERTY PLAT K-17 (OH) ADL-18730-1 Unocal Marathon ADL-18730-2,AI Unocal Forcenergy G-6 LHEkD G-14ARD G-8 IK-5 D-15 .6 Trading Bay Unit Boundary, DOLLY ADL-17602 Unocal Forc~nergy ~"rgN - R13% D-26 TBN -, R13' ADL.l~8729.1 )-29RD G-I~ Unocal ~ )-~ Marathon ~ L-18729-2,A~~-,-~, Unocal ~ Forcenerg,y ~-~o ,$ I )-25RD SCALE v. DOUBT ,~T. ! Grayling Platform Surface Casing Cement Summary Well Casing Size Shoe MD Shoe TVD Cement Comments Volume (inches) ~ (feet) (feet) (sacks) G-1 .13.375 2,160 2,118 3,100 Returns atsurface G-2RD 13.375 2,011 2,010 2,500 100 Sacks top job.. iG-3RD 13.375 2,209 2,176 2,500 G-4RD '16.000 621 621 1,200 G-5 16.000 591 591 1,395 Cementto surface. G-6 16.000 631 631 1,450 Good cement returns to surface. G-7 17.750 560 560 650 Good returns to surface G-8RD 16.000 590 556 1,250 Slight Returns G-9 16.000 623 621 .1,300 Good returns to surface G-10 16.000 643 643 250 Top of cement @ 411' G-11 16.000 694 694 1,300 G-12 17.750 602 602 775 G- 13 17.750 602 602 750 G-14 17.750 600 600- 700 Good cement returns. G-14ARD 17.750 520 520. 700 Good returns to surface G-15 17.785 600 600 700 G- 16 17.750 901 888 750 G-17 i7.750 560 560 675 G-18 DPN 17.750 600 600 800 G-19 17.750 520 520 700 Cement returns at surface G-20 20.000 1,200 1,200 798 G-21 20.000 822 822 799 Cement returns at surface. Tested to 500 psi. G-22 20.000 629 629 661 Good returns. G-23 20.000 796 796 541 Good Cement returns. Tested to 500 psL G-24 20.000 829 829 850 Cement returns at surface. Tested to 500 psi. G-25 20.000 81.6 816 780 Good Cement returns. Surf CSG CMT summary.xls 1/2 2/28/00--2:45 PM I · Well ~,Casmg Size Shoe MD Shoe TVD Cement Comments Volume (inches) (feet) (feet) (sacks) . G-26 20.000 741 741 500 G-27 20;000 821 821 600 Cement' returns at surface G-28 20.000 828 828 660 G-29 20.000 91'1 911 1814 ft3 !Good cement returnsto surface. G-30 17.750 520 520 750 ~ G-31 17.750 520 520 790 Cement returns at surface G-32 17.750 497 497 850 Lost returns after 650 sxs pumped. CSG tested to 400 psi. G-33 20.000 605 605 6,150 65 sack top job. No returns while cemenffng. CSG test to 700 G-34RD 20.000 616 616 1,000 Lost circ. 100 sack top job. G-36 DPN 20.000 599 599 800 Cement returns to suface after 690 ft3 pumped. G-40 16.000 1,929 1,929 1,898 Performed two top jobs: 500 sacks and 1,000 sacks. RECEIVED Oil & Gas Co~s. Surf CSG CMT sumrnary.xls. 2/2 2/28/00--2:45 PM Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary Day Date Hole Size Depth Footag~ Calculated Cum Calc Actual Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Drums Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) Filled (BBLS) (BBLS) (BBLS) (BBLS) (BBLS), Test 6/30/98 NA 113.50 1 7/13/98 8.50 10,860 - 21.0 27.5 27.5 2 7/14/98 8.50 10,860 - - 27.5 3 7/15/98 8.50 10,872 12 0.84 0.84 - 27.5 4 7/16/98 8.50 11,125 253 17.76 18.60 18.0 23.6 51.1 27.0 5 7/17/98 8.50 11,372 247 17.34 35.94 37.0 48.5 99.5 36.0 6 7/18/98 8.50 11,587 215 15.09 51.04 28.0 36.7 136.2 36.0 7 7/19/98 8.50 11,986 399 28.01 79.05 52.0 68.1 204.3 43.0, 8 7/20/98 8.50 12,110 124 8.70 87.75 24.0 31.4 235.7 43.0 9 7/21/98 8.50 12,370 260 18.25 106.00 60.0 78.6 314.3 43.0 10 7/22/98 7" LNR 12,370 - - 106.00 - 314.3 43.0 11 7/23/98 7" LNR 12,370 - - 106.00 - 314.3 43.0 12 7/24/98 7" LNR 12,370 - - 106.00 24.0 31.4 345.7 50.0 13 7/25/98 6.00 12,370 - - 106.00 3.0 3.9 349.6 70.0 91.00 350.00 14 7/26/98 6.00 12,375 5 0.35 106.35 33.0 43.2 392.9 70.0 15 7/27/98 6.00 12,508 133 9.34 115.69 54.0 70.7 463.6 70.0 16 7/28/98 6.00 12,508 - - 115.69 24.0 31.4 495.0 17 7/29/98 6.00 12,539 31 2.18 117.87 - 495.0 18 7/30/98 6.00 12,539 - -. 117.87 12.0 15.7 510.7 19 7/31/98 6.00 12,594 55 3.86 121.73 22.0 ~ 28.8 539.5 57.7 20 8/1/98 6.00 12,708 114 8.00 129.73 10.0 13.1 552.6 - 21 8/2/98 6.00 12,915 207 14.53 144.26 36.0 47.1 599.8 14.4 22 8/3/98 6.00 13,195 280 19.66 163.92 33.0 43.2 643.0 30.4 23 8/4/98 6.00 13,325 130 9.13 . 173.04 13.0 17.0 660.0 38.4 24 8/5/98 6.00 13,491 166 11.65 184.70 16.0 21.0 681.0 46.4 25 8/6/98 6.00 13,600 109 7.65 192.35 36.0 47.1 728.1 49.9 26 8/7/98 6.00 13,781 181 12.71 205.05 36.0 47.1 775.2 49.9 27 8/8/98 6.00 13,875 94 6.60 211.65 - 775.2 49.9 28 8/9/98 6.00 13,950 75 5.27 216.92 2.0 2.6 777.9 49.9 29 8/10/98 6.00 14,039 89 6.25 223.17 36.0 47.1 825.0 49.9 30 8/11/98 6.00 14,254 215 15.09 238.26 - 825.0 49.9 31 8/12/98 6.00 14,326 72 5.05 243.31 21.0 27.5 852.5 49.9 32 8/13/98 6.00 14,400 74 5.19 248.51 16.0 21.0 873.5 49.9 33 8/14/98 6.00 14,525 125 8.78 257.28 12.0 15.7 889.2 1.5 OBM Summary.xls 1/2 2/28/00-~2:50 PM Day Date Hole Size Depth Footag~ Calculated Cum Calc Actual Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Drums Cuttings Cuttings . Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) Filled (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 34 8/15/98 6.00 14,723 198 13.90 271.18 27.0 35.4 924.5 1.5 35 8/16/98 6.00 14,822 99 6.95 278.13 12.0 15.7 940.2 1.5 36 8/17/98 6.00 14,962 140 9.83 287.96 11.0 14.4 954.6 1.5 37 8/18/98 6.00 15,038 76 5.34 293.30 14.0 18.3 973.0 1.5 38 8/19/98 6.00 15,114 76 5.34 - 298.63 34.0 44.5 1,017.5 12.2 39 8/20198 Log 15,114 - - 298.63 - 1,017.5 12.2 40 8/21/98 Log 15,114 - - 298.63 - 1,017.5 12.2 41 8/22/98 Liner 15,114 - - 298.63 - 1,017.5 12.2 42 8/23/98 Liner 15,114 - - 298.63 - 1,017.5 12.2 43 8/24/98 Liner 15,114 - - 298.63 - 1,017.5 i2.2 44 8/25198 Comp. 15,114 - - 298.63 - 1,017.5 46.Q 167.00 350.00 45 8/26/98 Comp. 15,114 - - 298.63 - 1,017.5 571.00 365.00 46 8/27/98 Comp. 15,114 - - 298.63 10.0 13.1 1,030.6 47 8/28/98 Demobe 15,114 - - 298.63 - 1,030.6 48 8/29/98 Demobe 15,114 - - 298.63 - 1,030.6 49 8/30/98 Demobe 15,114 - - 298.63 - 1,030.6 303.00 365.00 50 8/31/98 Demobe 15,114 - - 298.63 26.0 34.0 1,064.6 137.00 730.00 51 9/1/98 Demobe 15,114 - - 298.63 - 1,064.6 Total: 813 1,065 1,269 2,160 Drums full of OBM absorbents: 31.0 Note included in total. Note: Bruce/Dispose costs was estimated at $200/Drum. Flush injection is FIW with 3% KCI. Summary Total BBLS of Cuttings from G-15RD 1,065 Drums full of Cuttings from G-15RD 813 Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus (BBLS) 3,429 !8-1/2" Hole Volume Factor = (Cum Cuttings/Cum Calc VOl) 3.26 6" Hole Volume Factor = (Cum Cuttings/Cum Calc Vol) 3.73 Hole Volume Factor for entire Well = 3.57 Waste Injected/Cum Cuttings = 1.19 : OBM Summary.xls 2/2 2/28/00--2:50 PM UNOCAL DATE: 7/1/98 FOREMAN Hauck FIELD:. Mt. Arthur Rlve~ PLATFORM: Gray~ng WELL: G-22 ISIZE: - 13.375 IN WEIGHT: 61.0 lBS' GRADE: H-40 BU. RST: 1,730 PSI I~ PRESS; 1,700 PSI TEST PRESS: 1,700 psi IcsG DEPTH (MI)): 5,548 FT C~G DEPTH (TVD): 4,977 FT' Ti) (MEASURED): NA FT TO (1'VD); ~ FT FLUID TYPE: ~V: 8.50 PPG INCREMENTS: 0~0 BBLS PUMP IN RATE: ? BPId LEAKOFF(GRAPH): 1,510 LOT OR F~/: LOT FRAG GRAD: 0.745 PSUFT EMW: 14.33 PPG IK5 - MSL 99.00 FT K~ -MUD LINE 189.75 FT I GOR FG.: 0.77 PSI/FI COR EMW: 14.74 PPG Lk O~ T~ G22~ds TBU 'g~/r x 133/8' Leak..off Test 5548' MDI,4977' TVD Note: .0997 BBLS/STRK RECEIVED Alaska 0ii & Gas Cons. C, omm~ Anchorage UNOCAL DATE: 711/98 FOREI,~d~I Haud( FIELD: McAdt~ River PLATFORM: Grayling WELL: G-22 ISIZE: 13.375 IN WEIGHT: 61.0 LBS GRADE: H-40 BURST: 1,750 PSI . MAX. PRESS: 1,900 PSi TEST PRESS: 1,900 PSi CSG DEPTH (MD): 5,548 FT CSG DEPTH (TVD): 4,977 FT TD (MEASURED}: NA FT T= (TVD): NA FT FLUID TYPE= Brine? MW:. 8.50 PPG INCREMENTS: 0.50 BBLS PUMP IN RATE: 0.50 BPM LEAKOFF(GRAPH}: 1,525 PS! LOT OR FIT?: LOT 'FRAC GRAD:. 0.748 PSUFr EMW: 14.39 PPG IKB - MSL KB - MUD UNE 189.7'5 FT 0.77 PSI/FT I'COR FG-' COR EMW: 14.50 PPG ., o. TBU G-22 LOT ;r2 ,. 9-5/8' X 13-3/B" Leal(off'Test 55,18' MD/4977' "VD Note: .0997 BBLS/STRK RECEIVED Alaska Oil & ~as Co~s. Com~ · ............ Illlll /- t t I- OI ~g~ t2~ 1~,~ 240.~ ~ 34O,0 Dan Williamson Drilling Manager Unocal Corporation~ P.O. Box 196247 ti Anchorage, Alaska 99519 907-263-7671 UNOr. JLd February 28, 2000 Mr. Robert Christensen Chairmain AOGCC 3001 Porcupine Drive Anchorage, AK. 99501 RES ENG FILE Dear Mr. Christensen, Re: Notice of Intent to In~ect Waste Liquid in Gray Unocal is in the planning stages of designing a horiz~sidetrack from either Grayling G-28 or G-29 in late April 2000. The sidetrack will consist of approximately 2000' of 8-1/2" hole drilled with water based mud and 3800' of 6" hole drilled with oil based mud. This will be much the same as the sidetrack we performed on G-15 in July 1998. As in the case during the drilling of G-15, we would like to request your approval to dispose of OBM liquid waste in the G-22 9-5/8" x 13-3/8" annulus. We have provided a summary of the Grayling Platform surface cement jobs and the summary of the fluids disposed of to date in the G-22 casing annulus. We estimate that approximately 1000 bbls of OBM waste and 2000 bbls of seawater will be injected into the G-22 annulus whilst drilling G-28/29. If no further issues are raised we will plan on re-instating injection of OBM liquid waste once OBM drilling operations commence on the Grayling Platform. Should you have any questions or concerns please contact myself or the Drilling Engineer assigned to the project; Neil Magee at 263-7671. Yours faithfully, Drilling Manager UNOCAL RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# 1 4 Sand Fill on PXN plug SIZE 26" 20" 13-3/8" 9-5/8" 9-5/8" 9-5/8" Tubing: 4-1/2" 13-3/8" x 9-5/8" injection annulus at 4,977' == G-1 --- G-2 --- G-3 --- G-4 --= G-5 --- B-1 -~ B-2 --- B-2 --- B-3 -= B-4 B-6 Top of Junk @ 11,254' RT to MSL ELEV = 99' TD = 11,335' ETD = 10,980' MAX HOLE ANGLE = 34.5~ @ 4200' G-22 11-98.doc WT Trading Bay Unit Well # G-22 Actual Completion (11/98) CASING AND TUBING DETAIL MD MD TVD GRADE CONN ID TOP BTM. BTM 1" wall 94 61 &68 47 47 47 12.6 H-40 N-80 P-Il0 S-95 L-80 24.0 Surf. 356' 356' Butt 19.124 Surf. 629' 629' Butt 12.415 Surf. 5548' 4977 Butt 8.681 Surf 7016' 6231' Butt 8.681 7016 10,087' 8915' Butt 8.681 10,087' 11,335' 9984' Imp. Butt 3.958 40.6' 9978' 8746' AB Mod NO. Depth 40.60' 9897' 9898' 9903' 9945' 9978' 10,968' 10,980' 10,981.55' JEWELRY DETAIL ID Item 3.958" 3.958" 4.75" 4.820" 3.813" 3.958" 4.0" 2.635" 2.99" Cameron DCB 4-1/2" Tubing hanger. 4-1/2" Butt x 4-1/2" EUE top Baker Anchor Tubing Seal Assy. (P/N451-40-9999) Baker Model 3H P Packer. (P/N 409~-06-9999) Baker 5.22' Millout Ext. (P/N 995--09-9999) Baker "X" Nipple (P/N 995--08-9999) Baker Ball Seat Sub (P/N 469-21-999) Otis "BWH" Perm Pkr (10,961' DIL) 3-1/2" Otis "XN" Nipple, w/2.75" PXN plug WLREG Zone G-1 G-2 G-3 G-4 G-5 G-5 B-1 B-2 B-2 B-3 B-4 B-5 B-5 B-6 G-5 G-4 G-3 G-2 G-1 Top 10061' 10115' 10178' 10230' 10370' 10590' 10595' 10643' 10742' 10762' 10827' 10984' 11081' 11115' 10,375' 10230' 10190' 10118' 10065' PERFORATION DATA Btm Amt SPF 10095' 34' 4 10154' 39' 4 10218' 40' 4 10300' 70' 4 10430' 60' 4 10592' 2' 4 10629' 34' 6/4 10734' 91' 20/8/4 10752' 10' 4 10815 53' 16/4 10952' 125' 16/12/8 11022' 38' 4 11082' 1' 4 11145' 30' 4 10430' 55' 6 10280' 50' 6 10220' 30' 6 10133' 15' 6 10092' 27' 6 Date Present Condition 11/19/890pen for injection 11/19/890pen for Injection 11/19/890pen for Injection 11/19/890pen for Injection 11/19/890pen for Injection 6/24/75 Sqz for Isolation 11/16/890pen for Injection 11/16/890pen for Injection 11/16/890pen for Injection 11/16/890pen for Injection 11/16/890pen for Injection 7/4/75 Isolated 6/22/75 Sqz for Isolation 7/3/75 Isolated 9/10/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection 9/11/98 Open for Injection REVISED: 11/16/98 DRAWN BY: DNM Day Date Hole Size Depth Footage Calculated Cum Calc Actual Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Drums Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) Filled (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 34 8/15/98 6.00 14,723 198 13.90 271.18 27.0 35.4 924.5 1.5 35 8/16/98 6.00 14,822 99 6.95 278.13 12.0 15.7 940.2 1.5 36 8/17/98 6.00 14,962 140 9.83 287.96 11.0 14.4 954.6 1.5 37 8/18/98 6.00 15,038 76 5.34 293.30 14.0 18.3 973.0 1.5 38 8/19/98 6.00 15,114 76 5.34 298.63 34.0 44.5 1,017.5 12.2 39 8/20/98 Log 15,114 - - 298.63 - 1,017.5 12.2 40 8/21/98 Log 15,114 - - 298.63 - 1,017.5 12.2 41 8/22/98 Liner 15,114 - - 298.63 - 1,017.5 12.2 42 8/23/98 Liner 15,114 - - 298.63 - 1,017.5 12.2 43 8/24/98 Liner 15,114 - - 298.63 - 1,017.5 12.2 44 8/25/98 Comp. 15,114 - - 298.63 - 1,017.5 46.0 167.00 350.00 45 8/26/98 Comp. 15,114 - - 298.63 - 1,017.5 571.00 365.00 46 8/27/98 Comp. 15,114 - - 298.63 10.0 13.1 1,030.6 47 8/28/98 Demobe 15,114 - - 298.63 - 1,030.6 48 8/29/98 Demobe 15,114 - - 298.63 - 1,030.6 49 8/30/98 Demobe 15,114 - - 298.63 - 1,030.6 303.00 365.00 50 8/31/98 Demobe 15,114 - - 298.63 26.0 34.0 1,064.6 137.00 730.00 51 9/1/98 Demobe 15,114 - - 298.63 - 1,064.6 Total: 813 1,065 1,269 2,160 Drums full of OBM absorbents: 31.0 Note included in total. Note: Bruce/Dispose costs was estimated at $200/Drum. Flush injection is FIW with 3% KCI. Summary Total BBLS of Cuttings from G-15RD 1,065 Drums full of Cuttings from G-15RD 813 Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus (BBLS) 3,429 8-1/2" Hole Volume Factor = (Cum Cuttings/Cum Calc Vol) 3.26 6" Hole Volume Factor = (Cum Cuttings/Cum Calc Vol) 3.73 Hole VOlume Factor for entire Well = 3.57 Waste Injected/Cum Cuttings = 1.19 OBM Summary.xls 2/2 2/28/00--2:50 PM Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary Day Date Hole Size Depth Footage!Calculated Cum Calc Actual Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Drums Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) Filled (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) Test 6/30/98 NA 113.50 1 7/13/98 8.50 10,860 21.0 27.5 27.5 2 7/14/98 8.50 10,860 - 27.5 3 7/15/98 8.50 10,872 12 0.84 0.84 - 27.5 4 7/16/98 8.50 11,125 253 17.76 18.60 18.0 23.6 51.1 27.0 5 7/17/98 8.50 11,372 247 17.34 35.94 37.0 48.5 99.5 36.0 6 7/18/98 8.50 11,587 215 15.09 51.04 28.0 36.7 136.2 36.0 7 7/19/98 8.50 11,986 399 28.01 79.05 52.0 68.1 204.3 43.0 8 7/20/98 8.50 12,110 124 8.70 87.75 24.0 31.4 235.7 43.0 9 7/21/98 8.50 12,370 260 18.25 106.00 60.0 78.6 314.3 43.0 10 7/22/98 7" LNR 12,370 - - 106.00 - 314.3 43.0 11 7/23/98 7" LNR 12,370 - - 106.00 - 314.3 43.0 12 7/24/98 7" LNR 12,370 - - 106.00 24.0 31.4 345.7 50.0 13 7/25/98 6.00 12,370 - 106.00 3.0 3.9 349.6 70.0 91.00 350.00 14 7/26/98 6.00 12,375 5 0.35 106.35 33.0 43.2 392.9 70.0 15 7/27/98 6.00 12,508 133 9.34 115.69 54.0 70.7 463.6 70.0 16 7/28/98 6.00 12,508 - 115.69 24.0 31.4 495.0 17 7/29/98 6.00 12,539 31 2.18 117.87 495.0 18 7/30/98 6.00 12,539 - - 117.87 12.0 15.7 510.7 19 7/31/98 6.00 12,594 55 3.86 121.73 22.0 28.8 539.5 57.7 20 8/1/98 6.00 12,708 114 8.00 129.73 10.0 13.1 552.6 21 8/2/98 6.00 12,915 207 14.53 144.26 36.0 47.1 599.8 14.4 22 8/3/98 6.00 13,195 280 19.66 163.92 33.0 43.2 643.0 30.4 23 8/4/98 6.00 13,325 130 9.13 173.04 13.0 17.0 660.0 38.4 24 8/5/98 6.00 13,491 166 11.65 184.70 16.0 21.0 681.0 46.4 25 8/6/98 6.00 13,600 109 7.65 192.35 36.0 47.1 728.1 49.9 26 8/7/98 6.00 13,781 181 12.71 205.05 36.0 47.1 775.2 49.9 27 8/8/98 6.00 13,875 94 6.60 211.65 - 775.2 49.9 28 8/9/98 6.00 13,950 75 5.27 216.92 2.0 2.6 777.9 49.9 29 8/10/98 6.00 14,039 89 6.25 223.17 36.0 47.1 825.0 49.9 30 8/11/98 6.00 14,254 215 15.09 238.26 825.0 49.9 31 8/12/98 6.00 14,326 72 5.05 243.31 21.0 27.5 852.5 49.9 32 8/13/98 6.00 14,400 74 5.19 248.51 16.0 21.0 873.5 49.9 33 8/14/98 6.00 14,525 125 8.78 257.28 12.0 15.7 889.2 1.5 OBM Summary.xls 1/2 2/28/00--2:50 PM Grayling Platform Surface Casing Cement Summary Well Casing Size Shoe MD Shoe TVD Cement Comments Volume (inches) (feet) (feet) (sacks) G-1 13.375 2,160 2,118 3,100 Returns at surface G-2RD 13.375 2,011 2,010 2,500 100 Sacks top job. G-3RD 13.375 2,209 2,176 2,500 G-4RD 16.000 621 621 1,200 G-5 16.000 591 591 1,395 Cement to surface. G-6 16.000 631 631 1,450 Good cement returns to surface. G-7 17.750 560 560 650 Good returns to surface G-SRD 16.000 590 556 1,250 Slight Returns G-9 16.000 623 621 1,300 Good returns to surface G-10 16.000 643 643 250 Top of cement @ 411' G-ii 16.000 694 694 1,300 G-12 17.750 602 602 775 G-13 17.750 602 602 750 G-14 17.750 600 600 700 Good cement returns. G-14ARD 17.750 520 520 700 Good returns to surface G-15 17.785 600 600 700 G-16 17.750 901 888 750 G-17 17.750 560 560 675 G-18 DPN 17.750 600 600 800 G-19 17.750 520 520 700 Cement returns at surface G-20 20.000 1,200 1,200 798 G-21 20.000 822 822 799 Cement returns at surface. Tested to 500 psi. G-22 20.000 629 629 661 Good returns. G-23 20.000 796 796 541 Good Cement returns. Tested to 500 psi. G-24 20.000 829 829 850 Cement returns at surface. Tested to 500 psi. ~G-25 20.000 816 816 780 Good Cement returns. Surf CSG CMT surnmary.xls 1/2 2/28/00--2:45 PM Well Casing Size Shoe MD Shoe TVD Cement Comments Volume (inches) (feet) (feet) (sacks) G-26 20.000 741 741 500 G-27 20.000 821 821 600 Cement returns at surface G-28 20.000 828 828 660 G-29 20.000 911 911 1814 ft3 Good cement returns to surface. G-30 17.750 520 520 750 G-31 17.750 520 520 790 Cement returns at surface G-32 17.750 497 497 850 Lost returns after 650 sxs pumped. CSG tested to 400 psi. G-33 20.000 605 605 6,150 65 sack top job. No returns while cementing. CSG test to 700 1 G-34RD 20.000 616 616 1,000 Lostcirc. 100 sack top job. G-36 DPN 20.000 599 599 800 Cement returns to suface after 690 ft3 pumped. G-40 16.000 1,929 1,929 1,898 Performed two top jobs: 500 sacks and 1,000 sacks. Surf CSG CMT summary.xls 2/2 2/28/00--2:45 PM TBU G-22 ., 9-5/8" x 13-3/8" Leak-off Test DATE: 7/1/98 Strokes I Volume Pump Time FOREMAN Hauck Pumped Pressure FIELD: McArthur River (BBLS) (ps~ (min) PLATFORM: Grayling 0 0 - WELL: G-22 1.00 290 2.0 2.00 330 4.0 , ,,, , , , SIZE: 13.375 IN 3.00 390 6.0 WEIGHT: 61.0 LBS' '4.00 450 8.0 GRADE: . H-40 5.00 500 10.0 BURST: 1,730 PSI 8.00 580 12.0 MAx. PRESS: 1,700 PSI 7.00 880 14.0 TEST PRESS: 1,700 PSI 8.00 720 16.0 9.00 780 18.0 CSG DEPTH (MD): 5,548 FT 10.00 840 20.0 CSG DEPTH ('i'VD): 4,977 FT 11.00 910 22.0 TD (MEASURED): NA FT 12.00 990 24.0 TD (TVD): NA FT 13.00 1050 26.0 FLUID TYPE: Brine? 14.00 I I00 28.0 MW: 8.50 PPG 15.00 1150 30.0 ,., INCREMENTS: 0.50 BBLS 18.00 1220 32.0 PUMP IN RATE: ? BPM 17.00 1300 34.0 LEAKOFF(GRAPH): 1,510 PSI 18.00 14i0 '36.0 LOT OR FIT?: LOT 1 ?.00 1470 38.0 FRAC GRAD: 0.745 PSI/FT 20.00 1510 40.0 EMW: 14.33 PPG 21.00 15i0 42.0 22.00 1520 44.0 IKB- MSL 99.00 FT 23.00 1580 46.0 KB MUD LINE 189.75 FT 24.00 1620 48.0 25.00 1650 50.0 ICOR FG.: 0.77 PSI/FT 28.00 1690 52.0 COR EMW: 14.74 PPG 27.00 1690 54.0 28.00 1700 56.0 29.00 1700 58.0 30.00 1700 60.0 1550 90.0 1350 420.0 , Note: .0997 BBLS/STRK Lk Off Tst G22.xls Pressure vs Volume 5.00 10.00 15.00 20.00 25.00 30.00 Volume (BBLs) Pressure vs Time 1800 1600 1400 1200 1000 8oo 4OO 200, O: 80.0 120.0 180.0 240.0 300.0 360.0 420.0 Time (Minutes) 7/919812:39 PM UNOCAL DATE: 7/1/98 FOREMAN Hauck FIELDi McArthur River PLATFORM: Grayling WELL: G-22 SIZE: 13.375 IN WEIGHT: 61.0 LBS GRADE: H-40 BURST: 1,730 PSI MAX. PRESS: 1,900 PSI iTEST PRESS: 1,900 PSI CSG DEPTH (MD): 5,548 FT CSG DEPTH (TVD): 4,977 FT TD (MEASURED): NA FT TD (TVD): NA FT FLUID TYPE: Brine? MW: 8.50 PPG INCREMENTS: 0.50 BBL$ PUMP IN RATE: 0.50 BPM LEAKOFF(GRAPH): 1,525 PSI LOT OR FIT?: LOT FRAC GRAD: 0.748 PSI/FT EMW: 14.39 PPG IKB - MSL KB MUD LINE 99.00 FT 189.75 FT 0.77 PSI/FT ICOR FG.: COR EMW: 14.80 PPG Lk Off Tst ~2 G22.xls TBU G-22 LOT ~2 9-518" x 13-318" Leak-off Test 5548' MD/4977' 'i'VD Note: .0997 BBLS/STRK 5.00 10.00 15.00 20.00 25.00 30.00 Volume (I~BI.~) Pressure vs Time 2.00O 1800 1600 1400 1200 800, 0 $0.0 120.0 180.0 240,0 300.0 360.0 420.0 Time (Minute~) 7/9/9812:39 PM U.NOC L ) RKB to TBG Hngr = 46.6' Tree connection: Dual 3" 5,000# o~-r Obstruction in Itbg,:0, 10.490 7 8 9 26" 20" i3-Y8" %5;8" 'Fubin~: l.S 3-I 2" ~4.s 3-1,2" -- 2~99q Obstruction in ~tbg~a 10,055 (TASING AND TI.'BIN(; I)ETAII.. Mil [' I{,\ I}1,2 f ( )N ~q 11} ()P Trading Bay IL:nit Well # G-22 Completed 5/6/90 x I 1) I'V D !; I'M, BTM G-1 G-2 G-3 G-4 1" wail 24.0 '~4 Butt 19.124 (,I & 08 H-40 Butt 12.415 4 ? N-80 Butt 8.681 47 P-110 Butt 8.681 4: 5-95 Butt 8.68 I ') 2 N-80 Butt 2.992 ~ 2 N-80 Butt 2.992 Surf. Sm-f. Surf '016 0.087' 360' 029' 5548' '016' 20.087' 1.335' 6231' 8915' 9984' 0.583' 9330' · 0.037' 8831' ,IEVqI(I,RY !}!':'I'.~.i 1, N(). t)epth 1D llem 46.60' -- B-1 _-= B-2 _Z B-2 == B-3 --- B-4 10 Fill ~. 10,480'] A 9951 2.75 B 9994' 2.90 C 10,030' 2.635 D 10,036.67' 2.99 btm 10,037.35' I 9960' 2.75 2 9994' 2.90 3 10,031' 2.75 4 10,478' 2.75 5 10,510' 2.95 6 DP MD 10,507' 4.00 7 DP MD 10,512' 4.00 8 10,550' 2.75 9 10582' 2.95 btm 10,583' 10 DP MD 10,968' 4.0 II DP MD 10,973' 2.99 12 DP MD 10,980' 2.635 13 DP MD 10,981.55' 2.99 btm 10.982.30 Cmneron DCB Dual 3-1 2" Tubing hanger. SHORT STRING 3-I/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RDH" Dual Packer, SS set 3-1/2" Otis "XN" Nipple, 2.75 WLEG LONG STRING 3-1/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RHD" Dual Packer 3-1/2" Otis "XA" Sliding Sleeve 3-1/2" Otis "XA" Sliding Sleeve Otis Strai~t Slot Locator w/8.96' of seals & mule shoe Otis "BWH' Perm P'kr ( 10,500' DIL) Otis Seal Bore Ext. 3-1/2" Otis "X" Nipple WLEG Otis "BWH" Perm Pkr (10,961' DIL) Crossover 3-1/2" Otis "XN" Nipple, 2.75 WLEG wi PXN plug --- B-5 Top of Junk (!~ 11,254' RT to MSL ELEV = 99' TD=11,335' ETD=Il,254' MAX HOLE ANGLE = 34.51 ~ 4200' Si.,IC'KLI.NE T..kGS SS 'Fagged fill w/2.343" GR LS "Fagged Obstruction in tbg w/2.125" LIB Tagged Obstruction in tbg w/2.25" Swedge STI 5.1U LA'FIONS 3 stage diverter acid job 138 bbls of7-1/2% HCL 200 bbls of 6 1/2% X 1-1/2% mud acid 12,'9/97 "~ 10.480' 12/10/97 ~ 10,055' 12/10/97 (~ 10,490' 1 1/21/89 G-Zone Zone G-1 G-2 G-3 G-5 B-1 B-2 B-2 B-3 B-5 PERI;'OR:VI'ION I)AI"A Accum. Date Top Btm Amt SPF Last Opr. ~,06~ ~,095' '3.' 4 i1/19)89. 19,115' 19,154' 39' 4 11/19)89 13,178' 0,218; ~i3;' 4 'il)19)'89 '19,230' 13,300' 70' 4 11/19i89 10,370' 19,430' 60. 4 11/19/89 13,590' 10,592 2' 4 6/24)75 19,595' ~,~29' 34' ~s & 4 ~1/~89 19,~43' 19,734' 9~ ~o, 8 & 4 ~1/16/89 10,742 10,752' 19' 4 11/16/89 10,76Z 19,8 15' 53' 16 & 4 11/16/89 13,82T 13,952' 125' 16,12 & 8 il/18/89 19,984' 1~022' 38' 4 7/4/75 11081 11082' I 4 6/22/75 1~ ~5' 1l 145' 30' 4 7/3/75 Present Condition Ope~ f/Injectio n Open f/Injection Open f/Injection , Open f/Injection Open f/Injection Cmt sq~d f/Isolation. Open f/Injectio n Open f/Injection Open f/Injection Open f/Injectio n Open f/Injection Isolated Cmt sclz~(l f/Isolation. Isolated G-22 dwg.rtf REVISED: 12/12/97 DRAWN BY: SLT 2000. 6:42PM ~UNOCAL CORP,~ ~h~q~\/z~'rld~N ~¢ CtlSSlCNO~,0583 P, 13.~.~, REPORT% F SUNDRY WELL OPE . JNS Stimulate', Plugging: Perforate: Alter casing: -- Regair welt X Qther: "'-'-'-----'" 5. Type of'"~ell~ 6."'~atum elevation (OF or KB) RT 99' to MSL 7. Unit or Property name 1. OoeratJons performed: Operation shuffiowiq: Pull tubing: 2, Name of Operator Union Oil Comps.ny of Oallf0~i.a' (,UNOCAl.) 3. Addrees Tradlng Bay Unit 8, Well number 9, Permit numl~erlaCproval number 75-161 3~6-069 10, APl number $0~133-20272-00 Plugs (measured) Junk(measured) 11. Field/Pool Mc. Arthur River Field P O Box 196247 Anchorage Alaska ...... _.____,.~,,'-.,,'."~a~,' '--~.'-- . _ ~ Location ~f wetl at .~urface Grayling Leg 3 C~nduc~er No,1 1413'FEL 1789' F'$L, Sec 29, TgN, RI3W, SM At top of productive interval 2091°, FNL, 3361' FEL, Sec 32, TgN. R13W,$M at 8881' TVD At effective depth 2553' FN~ 37~1' FEL, Sec 32. TgN, R13W, SM at 9908' TVD At t~tal depth 2579' FNL, 3791' FEL., Sec 32, TgN, R13W, SM at 9984' TVD 2, Preeent welJ ¢ond[tlcn summary Torsi depth: measured 11338' feet tree veffic=al 9984' feet · Effe~ve depth: measured 11,254' feet hue verticat 9908~ feet DeveJopmem: StraUgraphi¢: Service: 10,980' (Sand f~ll on PXN plug sat In OTIS BWH packer at lO968') Casing Length Size Cemented MeasUred dep~ True vertical depth Structur~) 360' 26" Ddven 360' 360' Conductor ~2g' 20" 112~ cu,tL $29' 629' 8u~ 5~48' 13-3/8" 5802 ~,~ ~B' 4977' Inm~edlam 99~' Production 11335' 9-5/8" 1 ~0 cu.[ 1 ~ 235' Liner, Pe~ta~en de0~: measured See e~c~ment ~Ue vestal Tubing (size, grmde, and measured depth) Packers and SSSV (tyge and measured depth) Single 4.1/'2" 12,8 Ibtft L-80 Butt at 9,978' Offs "BWH" packer set at 10,980' 13, SUmulaUen or cement squeeze summary Intervals t~eate¢l [meaeure~) , Trea~ent des~p~on Including VD[Ureas used and final pressure "Sk~ 0~[ & Gas Cons commission Ale' ' ~~w D~I[ ~ 12/17/1997 10,~00 BPD 3050 PrJ~3t tO well ~eratien ~,600 ~tPO llOO psi (Maintained)~ Se:vice: Subsequent to operation ~ ! 5. A~schments: CoCos of Logs and Surveys run: ..-- Dairy Report of Well O~era~ons: X OIt: Gas: Suspended: ~ ~at the olng is ~e and corte~ ta ~e best of my ~nowledge: Tubing Pressure 3280 psi Zl ,~0 psi W~ter injector Form t 0,.404 Rev 08/15t88 Tltle: Odllbg~Manager SUBMIT IN DUPLICATE [3 · Jan, 6, 2000 6:42PM UNOCAL CORP, N0,0583 P, Grayling G-22 Summary of Operations Well work was required on G-122 water injector to repair tubing to casing comrt~unication and to fu~er investigate if there was a hole in the tubing above the uppermost packer. The existing dual completion was recovered which indicated leaks in the XA sleeves above the uppermost packer. Following fishing runs to recover the · uppermost dual hydr,a~li.c se..t_packer ~d the rniddIe pernaanent, p_acker. The well was ,_ cleaned out to 10,973 IA. RT'I'~-'w~s utilizeCt tO'lest the"caS~g integrity abc~'v~'~'e Pt~ed[ ~-~n~"dep'~ ct' ~e single injection packer, A pressure tests was made at 9937' to 2500 _. % ~ [ p~w~e,h iadi.?ated cas~$ integ~-~ty,,-38 ,,ps! bleed,,..off !n 30 ~utc_s, .. ,, Following this the well wa~ re-completed as a 4-I/2" single injector with the/njectiort packer set at 9898', Subsequently a MIT was conducted (MIT form attached) on 1.9 April 1998 which indicated rnechan/¢al integrity and the weIl was placed back on .injection, ~. -_= _ UNOCAL CORP, i . iiiiml., [" w~ll t2,6 '/ell# (;'No, 0583 P, 15 ,iai Completion (4198) BTM. STM 1~utt tg.t24 5uH'. 529' 629' H&0 ~n 12.415 S~, 5~4~' 49~ N-~0 ~un ~.~ t S~ 701 ~' ~2~ I' P-t ~ 0 gu~ 8,5S t T016 t Q,087' I~ ~ 5' Dg~ 3~ ~.~al t 0,037' [ 1,335' gga~' L.-~Q ':m~. Bu~ ].95l~, 40.6' 9978' ~746' NO, .......... O,,p~ .... [_~D 9903' Zone; Top ' Btm Amt :'):!{ -~'" i ..... ~:~ ........ ' ~ .......... "~ ~e_.,,~, ~ ..... :,, ~ ~"--~" =- RT tO MSt, ELEV TO = ~,~3S' ETD · 10,980' HOLE ANGLE - 34,~ ~ 4200' O-22 new completion dwg,rrf REVISED: 4/13/95 DRA. W'N' BY: DNM OPERATOR: WELL NAME G-22 COMMENTS: G-12 COMMENTS: G-16 COMMENTS: COMMENTS: COMMENTS: STATE OF ALASKA ALASKA OIL AND-GAS CONSERVATION COMMISSION Mechanical :Integrity Test UNOCAL [FIELD i UNIT t PAD: McArthur river/Trading Bay/Grayling DATE: Wa~r[. P ! T~PE ANN. FLUID PACKER TVD MD 8,746 CASING SIZE I WT 1 GRADE KCL 9,897 9 5/8, 47#, N-80 I I REQ TBG TEST I SIZ-~LPRESS 4 ~'/..2 2~a7 Prete~l pressures obsen/ed for lhidy minutes wior to pressureing up annulus. PRETEST TBG CSG PRESS START. TIME TBG CSG PRESS 2,2OO 2,3OO 15 MIN TIME TBG CSG PRESS' 2,2O0 2.3O0 3O MIN TIME TBG CSG PRESS 200 2,3O0 [ Water .... j P I KCL 12,072 9 5~8, 47#, N-80 3 2191 Pretest pressures obsez~ed for thirty minutes prior ~o pressureing up annulus. 3,200 J 3,200 J 3,200 j 3,200 .5oo l z soi ,2aolz2 ol Water KCL t 1842 9 5/0, 47#, N.-80 1 . 2291 Pretest pressures observed for lhidy minutes prior to pressureing up annulus. 3050 J 305O 1150 2350 START TIME 930 945 305013050 1500 rain J 4/19/98 ! I l I I TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS tNJ. S = SALT WATER iNJ. N = NOT ~UEG'T]NG TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST iR = iNTERNAL RAD. TRACER SURVEY A --TEMPERATURE .ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. ago 9,3 0.48 000 o~00 WELL TEST: Inilial X 4 - Year Werkover ~-~ Olher OPERATOR REP SIGNATURE: Johnny T. Santiago j[~jdste,xl~ , AOGCC REP SIGNATURE: Louis R. Gnma/dj (Rev 9t 17/96) · ~an, 6, 2000 6'43PM UNOCAL CORP, III .. _ --" _. ~ ...... - i__ i~1 .!,!!.~.,,~.~ ........ III Log Date .. :La- tC-~.t~a7 N 0,0583 P, 17 WFL Interpretation Summary A TDT-WFL Survey was run on 18-Dec-1997 to check the Mechanical Integrity of the tubulars under injecting conditions. The WFL survey was logged in the long string. The tool was run in the up-flow configuration with the annulus open and returning approximately 700 bpd to the surface, The up-flow survey was then repeated with the annulus closed. The toot was then changed to the down-flow configuration and a down- flow survey was completed. In conjunction with the WFL survey spinner/temperature surveys were run in both tubing strings under injecting conditions and in the long string under shut-in conditions, Summary of Findings: The Dual. Packer at 9994 is leaking; ~:'The 9'-~'~;8" casing has a teak between 4750 and 4800 feet, The 9 5,/8" may have an addi!ional leak between 5500 and 8000 f~ee ....... . ,., i ....... i ii ....... Mi The Long Tubing String has a leak between 1800 and 2000 feet. The Long Tubing String Sltdtng Sleeve at 10031 feet is leaking, WFL Discussion: With the tubing to 9 5/8" annulus open during injection the well was returning -700 bpd to the surface, This flow originates'from e,' leak past the Dual. Packer at 9994 feet. With the tubing to 9 5/8" annulus closed up,~flow continues at a reduced rate, This flow travels up the tubing x 9 5/8" annulus until between 4750 and 4800 ft where it exits the 9 5/8" casing and flows down the 9 5/8" x 13 3/8' annulus, An additional small leak out of the 9 5/8" may be indicated by the drop in Up Flow rote between 6000' and 5500'. Down-flow in the tubing x 9 5/8" casing annulus is seen starting between 1800 and 2000 feet. This flow continues down and appears to exit the 9 5/8°. casing in the same interval as the up flow mentioned above (,-4800 fi). This combined flow then travels down the 9 5/8" x 13 3/8"/OH annulus to the reservoir at or below 9500 feet, The spinner surveys run in both strings show an unexplained drop in injection rate below -, 1000' which may best be explained by a ID reduction above this point (scale?). The Long String survey shows an additional slight drop just below 1500' which could accouter for the start of the WFL Down Flow indication mentioned above. The Long String spinner response at 10,030 feet indicates this sliding sleeve is leaking, Attached are plots and tabular listings of the WFL Interpretation and field recordings, ./ °Jan, 6, 2000 6'43PM 0 1~0~0 0 1~ (SPO) (BPO) W~FL Results ,,Jan. 6. 2000 'L~ 6'44PM UNOCAL CORP, MD Chart G-22 Temperature ~urvey No,0583 P , 19 60 0 60 70 80 90 Temperature t00 110 120 180 140 1000 2000 3000 4OOO 15000 6000 7000 8000 gO00 10000 11000 12000 dolanjj Page 1 1 t6/00 /1 Unocal Corporation 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL 2000 "~ -- ~// ' ~ / / 'j ~om Maunder ~(~ ~~ ~ /~~~~r~ ~~n' · ~- , ~~ ~,as~a3001 Porcupine Drive~ ~ un ana uas ~onse~ation Commission~ ~~ Re: Results of WFL's from 1998 Grayling wor~over rrogram -- We ran a series of Water Flow Logs in 1998 to identify holes in the casing of a series of wells which had experienced tubing/casing communication. Our goal was to prove no holes in the casing and request a variance, which would have saved us over $8MM in repairs. Unfortunately, all the WFL's suggested holes in the casing. Even though only one of the temperature surveys showed a hole in the casing (which didn't correlate with a hole suggested by the WFL), we were so confident that the WFL's were correct we decided to bit the bullet and work the wells over and repair the casing holes. When we went to do the work there was good news and bad news. The good news was there was only one hole in any of the casings (the one the temp survey clearly showed - G-36DPN) and we were able to save over $3MM in repair costs. The bad news was we still spent over $4MM in workover costs which may have been unnecessary if we were able to obtain variances on them. I have attached three examples: G-36DPN G-22 G-16 WFL showed multiple leaks between 3000 and 5000 MD. Temp survey showed leak between 10,200 and 10,300 MD. Pressure testing confirmed leak identified by Temp survey and proved leak identified by WFL to be nonexistent. WFL showed multiple leaks between 4750 and 6000 MD. Temp survey showed possible leak between 8,900 and 9,400 MD. Pressure testing proved no leaks exist. WFL showed leak between 6300 and 6500 ft. Temp survey had minor temp variations over the length of the log but was interpreted as noise. Pressure testing proved no leaks exist. IfI can be of further assistance please don't hesitate to call me at 263-7830 or Steve Tyler at 263-7649. Sincerely, Reasons for no WFL's on Baker. doc Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management Unocal Alaska Resourc{r'~ P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOr. Dale Haines Drilling Manager Thursday, July 09, 1998 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: UNOCAL is submitting the requested information as per your phone conversation on June 18, 1998. Since UNOCAL could not establish injection into G-15's annulus, we were forced to find an alternative annulus to inject the Oil-Based Mud (OBM) from G-15 Redrill. When we received your verbal approval on June 18, we attempted to inject filtered inlet water down the 9-5/8" by 13-3/8" annuli in the following Grayling wells: G-40 and G-22. We were not successful injecting fluid into G-40's annulus; however, we were able to establish injectivity into G-22's annulus by performing two successful Leak-Off Tests. (See attached LOT's.) As per your request, we have also provided a summary of the Grayling Platform's surface casing cement jobs. (See attached summary.) Since we have established the integrity of G-22's 13-3/8" casing shoe, UNOCAL plans to dispose of G-15 Redrill's OBM and OBM liquid waste down G-22's 9- 5/8" by 13-3/8" annulus. If you have any questions or concerns, please contact myself or Drilling Engineer Mitch Damm @ 263-7679. Thank you for your time and cooperation. RECEIVED' JUL 1 0 '~99i~ Naska 011 & 0a~ Cons, Sincerely, Dale A. Haines Drilling Manager UNOCAL IDATE: 7/1/98 FOREMAN Hauck FIELD: McArthur River PLATFORM: Grayling WELL: G-22 ISIZE: 13.375 IN WEIGHT: 61.0 LBS GRADE: H-40 BURST: 1,730 PSi MAX. PRESS: 1,700 PSI TEST PRESS: 1,700 PSI CSG DEPTH (MD): 5,548 FT CSG DEPTH (TVD): 4,977 FT TD (MEASURED): NA FT TD (TVD): NA FT FLUID TYPE: Brine? MW: 8.50 PPG INCREMENTS: 0.50 BBLS PUMP IN RATE: ? BPM LEAKOFF(GRAPH): 1,510 PSI LOT OR FIT?: LOT FRAC GRAD: 0.745 PSIIFT EMW: 14.33 PPG IKB- MSL 99.00 FT KB MUD LINE 189.75 FT I COR FG.: 0.77 PSI/FT COR EMW: 14.74 PPG TBU G-22 9-5~8" x 13-3/8" Leak-off Test 5548' MD/4977' TVD Note: .0997 BBLS/STRK Pressure 5.00 1o.0o 15.00 20.00 25.00 30.00 Volume (BBLs) Pressure vs Time 18oo 600 60.0 12o.o 18o.o 240.0 300.0 360.0 420.0 Time (Minutes) 1600 1400 1200 1000 800 400 200 0 Lk Off Tst G22.xls 7/9/9812:39 PM UNOCAL ) IDATE: 7/1/98 FOREMAN Hauck FIELD: McArthur River PLATFORM: Grayling WELL: G-22 ISlZE: 13.375 IN WEIGHT: 61.0 LBS GRADE: H-40 BURST: 1,730 PSI MAX. PRESS: 1,900 PSI TEST PRESS: 1,900 PSI CSG DEPTH (MD): 5,548 FT CSG DEPTH (TVD): 4,977 FT TD (MEASURED): NA FT TD (TVD): NA FT FLUID TYPE: Brine? MW: 8.50 PPG INCREMENTS: 0.50 BBLS PUMP IN RATE: 0.50 BPM LEAKOFF(GRAPH): 1,525 PSI LOT OR FIT?: LOT FRAC GRAD: 0.748 PSI/FT EMW: 14.39 PPG IKB- MSL 99.00 FT KB MUD LINE 189.75 FT I COR FG.: 0.77 PSI/FT COR EMW: 14.80 PPG TBU G-22 LOT #2 9-5/8" x 13-3/8" Leak-off Test 5548' MDI4977' TVD Pumped Note: .0997 BBLS/STRK Pressure vs Volumeo:{-)O 5.00 10,00 15.00 20.00 25.00 Volume (BBLs) 30.00 Pressure vs Time 20OO t -- 1800 1600 1400 1200 1000 8OO 6OO 4OO 2OO 0 60.0 120.0 180.0 240.0 300.0 360.0 420.0 Time (Minutes) 7/9/9812:39 PM Lk Off Tst #2 G22,xls Grayling Platform Surface Casing Cement Summary ~10~l~} Well Casing Size Shoe MD Shoe TVD Cement Comments Volume (inches) (feet) (feet) (sacks) G-1 13.375 2,160 2,118 3,100 Returns at surface G-2RD 13.375 2,011 2,010 2,500 100 Sacks top job. G-3RD 13.375 2,209 2,176 2,500 G-4RD 16.000 621 621 1,200 G-5 16.000 591 591 1,395 Cement to surface. G-6 16.000 631 631 1,450 Good cement returns to surface. G-7 17.750 560 560 650 Good returns to surface G-8RD 16.000 590 556 1,250 Slight Returns G-9 16.000 623 621 1,300 Good returns to surface G-10 16.000 643 643 250 Top of cement ~ 411' G-11 16.000 694 694 1,300 G-12 17.750 602 602 775 G-13 17.750 602 602 750 G-14 17.750 600 600 700 Good cement returns. G-14ARD 17.750 520 520 700 Good returns to surface G-15 17.785 600 600 700 G-16 17.750 901 888 750 G-17 17.750 560 560 675 !G- 18 DPlX 17.750 600 600 800 G-19 17.750 520 520 700 Cement returns at surface G-20 20.000 1,200 1,200 798 G-21 20.000 822 822 799 Cement returns at surface. Tested to 500 psi. G-22 20.000 629 629 661 Good returns. G-23 20.000 796 796 541 Good Cement returns. Tested to 500 psi. G-24 20.000 829 829 850 Cement returns at surface. Tested to 500 psi. Surf CS G CMT summary.xls 1/2 7/9/98-- 12:38 PM Well Casing Size Shoe MD Shoe TVD Cement Comments Volume (inches) (feet) (feet) (sacks) G-25 20.000 816 816 780 Good Cement returns. G-26 20.000 741 741 500 G-27 20.000 821 821 600 Cement returns at surface G-28 20.000 828 828 660 G-29 20.000 911 911 1814 ft3 Good cement returns to surface. G-30 17.750 520 520 750 G-31 17.750 520 520 790 Cement returns at surface G-32 17.750 497 497 850 Lost returns after 650 sxs pumped. CSG tested to 400 psi. G-33 20.000 605 605 6,150 65 sack top job. No returns while cementing. CSG test to 700 t G-34RD 20.000 616 616 1,000 Lost circ. 100 sack top job. G-36 DPN 20.000 599 599 800 Cement returns to suface after 690 ft3 pumped. G-40 16.000 1,929 1,929 1,898 Performed two top jobs: 500 sacks and 1,000 sacks. Surf CSG CMT summary.xls 2/2 7/9/98--12:38 PM JUN-29-98 MON 13:41 UNOON~ ~qS~T G~$ GRP FRX NO, 9072637874 P. 01/01 Unocal Corporation 909 West 9"' Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL June 29, 1998 Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Wendy, Re: Status of Unocal's Cook Inlet Injector Work This letter is to provide you with an update of the work conducted sincc our March 27, 1998 letter which you signed granting time extensions for various wells. Testing or work was completed on the fo]lowine wells and the results of this work is listed: 8Z- o'~ Z_ Anna 46-42 ' SI MIT approved on 4/17/98. ':l~,' a 4-z King 4RD : SI MIT approved on 4/17/98, workover scheduled. · -4q.a'ao4 King 15RD 8't~- ~,-,-Dolly D- 16RD 6~-I~ Dolly D-22 ~~:Grayling 22 ~/. o4~1 Grayling 36DPN ~/'°:"t Monopod A-12RD2 9z'~2-~1 Monopod A-29 ?4- ?~ Baker 9 King 22RD SI MIT approved on 4/17/98. : SI MIT approved on 4/17/98. SI MIT approved on 4/17/98. : Workover completed on 4/19/98. : Workover completed on 4/28/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6/03/98, Variance granted Jug test proved communication, workover scheduled. planning acid treatment to clean tubing for lesting, on 6/09/98, Jug test proved casing integrity. Anna 27-42 :Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. Anna 19-42 :Coil Tubing cleanout completed on 6/27/98, further testing scheduled to prove easing integrity, Granite Point 33-14RD: Wireline fishing continuing to remove wire and wireline fish from well. Grayling 5 : Redrill in progress. Testing. or work w~ attempted on the following shubin wells and a time extension until September 30, 1998 requested to complete further work and testing. - 615 -o t, Anna 19-42' Coil Tubing clean out completed on 6/27/98, furfl~er testing scheduled to Prove casing integrity. ":F/.olg Anna 27-42: Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. · -4"}- 0-4 Grayling 28: Coil Tubing cleanout planned to follow currently active rig program. ~- o5 Grayling 40: Workover schedule in current rig schedule. -42~-o4z. King 4RD · SI IV[IT granted on ~/17/9g, workover soheduled. "4fi- t~%4 King 15RD · SI MIT granted on 4/17/98. Jug test proved communication, workover scheduled. As you can see we are making excellent progress. Unocal respectfully requests a time-extension until September 30, 1998 to complete the work on the above listed Anna wells. The Grayling and King work will be executed per our current drilling schedule. Please call me if you have any questions or clarification on these issues. Cook Inlet Waterflood Management Please acknowledge the approval of the time axtension and your receipt of this letter by faxingback a si~ned of this letter to Christopher Ruff at 263-7874 (fax), ~[~ ~ [ ~ ~~ Wendy2vlahan Dat; ' d [J N 2 9 AOGCC RKB to TBG Hngr = 46.6' Tree connection: Dual 3" 5,000# in --tbg @ 10,055 7 12 ~13 G-1 G-2 G-3 G-4 B-1 B-2 B-2 B-3 B-4 10 -= B-5 == B-6 Top of Junk @ 11.254' RT to MSL ELEV = 99' TD = 11,335' ETD = 11,254' MAX HOLE ANGLE = 34.5'1 (~ 4200' SIZE WT CASING AND TUBING DETAIL MD GRADE CONN ID TOP Trading Bay Unit Well ti G-22 Completed 5/6/90 MD TVD BTM. BTM 26" 20" 13-3/8" 9-5/8" 9-5/8" 9-5/8" Tubing: LS 3-1/2" SS 3-1/2" 1" wall 24.0 Smae. 94 Butt 19.124 Surf. 61 & 68 H-40 Butt 12.415 Sm'f. 47 N-80 Butt 8.681 Surf 47 P-110 Butt 8.681 7016 47 S-95 Butt 8.681 10,087' 9.2 N-80 Butt 2.992 0' 9.2 N-80 Butt 2.992 0' 360' 629' 5548' 7016' 10,087' 11,335' 10,583' 10,037' 6231' 8915' 9984' 9330' 8831' G-22 dwg.doc __ Fill @ 10,480' JEWELRY DETAIL NO. Depth ID Item 46.60' A 995l 2.75 B 9994' 2.90 C 10,030' 2.635 D 10,036.67' 2.99 bun 10,037.35' 1 9960' 2.75 2 9994' 2.90 3 10,031' 2.75 4 10,478' 2.75 5 10,510' 2.95 6 DP MD 10,507' 4.00 7 DP MD 10,512' 4.00 8 10,550' 2.75 9 10,582' 2.95 btm 10,583' 10 DP MD 10,968' 4.0 11 DP MI) 10,973' 2.99 12 DPMD 10,980' 2.635 113 DP MD 10,981.55' 2.99 btm 10982.30 Cameron DCB Dual 3-1/2" Tubing hanger. SHORT STRING 3-1/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RDH" Dual Packer, SS set 3-1/2" Otis "XN" Nipple, 2.75 WLEG LONG STRING 3-1/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RI-ID" Dual Packer 3-1/2" Otis "XA" Sliding Sleeve 3-1/2" Otis "XA" Sliding Sleeve Otis Straight Slot Locator w/8.96' of seals 8,: mule shoe Otis "BWH" Perm Plo' (10,500' D1L) Otis Seal Bore Ext. 3-1/2" Otis "X" Nipple WLEG Otis "BWH" Penn Pkr (10,961' DIL) Crossover 3-1/2" Otis "XN" Nipple, 2.75 WLEG w/PXN plug SLICKLINE TAGS SS Tagged fill w/2.343" GR 12/9/97 ~ 10,480' LS Tagged Obstruction in tbg w/2.125" LIB 12/10/97 ~ 10,055' Tagged Obstruction in tbg w/2.25" Swedge 12/10/97 ~ 10,490' WIRELINE WORK WFL ran on 12/18/97 indicated a +500 BPD csg leak between 4750' & 4800' originating from a pkr leak. STIMULATIONS 3 stage diverter acid job: 138 bbls of 7-I/2% HCL, 200 bbls of 6 1/2% X 1-1/2% mud 11/21/89 G-Zone acid Zone G-2 G-4 c-5 Top Btm PERFORATION DATA Date Amt Last Opr. 34' 11t19/89 39' '11t1~/89 40' 11"9/89 70' 11/19/89 60' '11t1~/89 Present Condition REVISED: 2/3/98 DRAWN BY: SLT Trading Bay Unit Well # G-22 Completed 5/6/90 Wireline Problems: Tubing Size: Minimum I.D. Status: Perforations: LS Fill tagged on 8/1/97 ~ 10,956' (11' above isolation pkr ~ 10,968'), covering part of HB-4 and effectively isolating HB-5 & 6. Metal obstruction tagged ~ 10,055 on 12/9/97. Metal obstruction tagged ~ 10,490' on 12/9/97. Can not go past SS Fill tagged ~ 10,480' w/2.343" GR on 12/10/97 LS 3-1/2", 9.3#, N-80, Buttress SS 3-1/2", 9.3#, N-80, Buttress Plastic Coated Plastic Coated Isolation Assy. 2.635" ~ "XN" nipple 10,980' LS 2.75" ~ "XA" Sliding Sleeves & "X" Profile Nipple ' 9961', 10,031', 10,478' & 10,550' SS 2.75" ~ "XA" Sliding Sleeve & 2.635" ~ "XN" Profile Nipple: 9951' & 10,030' SS "G" sand Shut-In LS Hemlock Shut-In "G" Zone & Hemlock Discussion WFL ran on 12/18/97 indicated communication with tbg / csg annulus originating from a leaking dual pkr. The WFL indicated a +500 BPD casing leak between 4750' & 4800'. · Well head DID NOT pass Pressure Integrity Test. · Long and Short string are in communication, between top and middle packers. G-22 dwg.doc REVISED: 2/3/98 DRAWN BY: SLT G-22 Start in hole @ 12117197 '19:45 LS Rate: 5,1'16 BPD 2000 psi SS Rate: 3,570 BPD 2000 psi Detector Stop Order Depth Spacing 1 500 5 2 3OO0 5 3 6000 - 4 8000 5 5 9000 5 6 9500 5 7 10040 5 8 9500 2 9 9980 2 10 8000 2 11 6000 2 12 5500 2 13 3000 2 14 500 2 15 1500 - 16 2000 - 17 2500 - 18 3000 - 19 5500 - 20 5000 - 21 4500 22 4750 23 4800 - 24 500 - 25 1200 - 26 4500 - 27 5000 - 28 6000 - 29 8000 - 30 9000 2 31 9500 2 32 7000 2 33 6500 2 34 6000 2 35 5500 2 36 5000 2 37 3000 2 38 800 39 1200 - 40 2000 2 41 1600 2 42 1800 - Measured FPM 8.1 8.8 9.8 10.1 9.8 9.6 0.0 4.4 4.6 4.3 3.8 3.1 3.7 0.0 0.0 0.0 0.0 0.0 3.4 3.2 0.0 0.0 3.1 ? 7.4 6.2 0.0 7,3 10.5 11.6 10.1 11.6 9.6 7.7 7.4 5.2 0.0 0.0 6.0 0.0 0.0 Tool Mode Up Flow Up Flow Up Flow U ~ Flow U ~ Flow U ~ Flow U ~ Flow U 3 Flow U ~ Flow U 3 Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Down Flow Remarks Csg Flowing @ 2000 BPD Csg Flowing @ 2000 BPD Csg Flowing @ 2000 BPD Csg Flowing @ 2000 BPD Csg Flowing @ 2000 BPD Csg Flowing @ 2000 BPD Csg Flowing @ 2000 BPD Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Csg Shut-In Page 1 STATE OF ALASKA ~" · ' .... ALASKA OiL AND GAS CONSERVATION C'OMMISSlON REPORT OF SUNDRY WELL OPERATIONS '1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: RT 99' to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, Alaska Service: X Trading Bay Unit 4. Location of well at surface Grayling Leg 3 Conductor No.1 8. Well number 1413'FEL, 1789' FSL, Sec 29, T9N, R13W, SM TBUS G-22 At top of productive interval 9. Permit number/approval number 2091', FNL, 3361' FEL, Sec 32, T9N, R13W,SM at 8881' TVD 75-16 / 398-069 At effective depth 10. APl number 2553' FNL, 3761' FEL, Sec 32, T9N, R13W, SM at 9908' TVD 50-133-20272-00 At total depth 11. Field/Pool 2579' FNL, 3791' FEL, Sec 32, T9N, R13W, SM at 9984' TVD McArthur River Field 12. Present well condition summary Total depth: measured 11335' feet Plugs (measured) true vertical 9984' feet \ Effective depth: measured 11,254' feet Junk (measured) 10,980' (Sand fill on PXN plug set in OTIS BWH true vertical 9908' feet packer at 10968') Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" Driven 360' 360' Conductor 629' 20" 1125 cu.ft. 629' 629' Surface 5548' 13-3/8" 5802 cu.ft. 5548' 4977' Intermediate Production 11335' 9-5/8" 1840 cu.ft. 11335' 9984' Liner Perforation depth: measured See attachment true vertical Tubing (size, grade, and measured depth) Single 4-1/2"12.6 Ib/ft L-80 Butt at 9,978' Il Packers and SSSV (type and measured depth) Baker Hughes "3H' packer set at 9,898' Otis "BWH" packer set at 10,980'2 1998 13. Stimulation or cement squeeze summary~I Oil & Gas C0~s. Commis~l Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/17/1997 10,500 BPD 3050 psi 3280 psi Subsequent to operation 4/20/1998 6,600 BPD 1100 psi (Maintained) 2150 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: /~ ~j(~, d/~ 'Title: Drilling Manager Date: .~....-- . Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Grayling G-22 Summary of Operations Well work was required on G-122 water injector to repair tubing to casing communication and to further investigate if'there was a hole in the tubing above the uppermost packer. The existing dual completion was recovered which indicated leaks in the XA sleeves above the uppermost packer. Following fishing runs to recover the uppermost dual hydraulic set packer and the middle permanent packer. The well was cleaned out to 10,973'. A RTTS was utilized to test the casing integrity above the planned setting depth of the single injection packer. A pressure tests was made at 9937' to 2500 psi which indicated casing integrity -38 psi bleed off in 30 minutes. Following this the well was re-completed as a 4-1/2" single injector with the injection packer set at 9898'. Subsequently a MIT was conducted (MIT form attached) on 19 April 1998 which indicated mechanical integrity and the well was placed back on injection. Oil & ~s Co~s. Commis~i~ UKOCAL RKB to TBG Hngr = 40.6' Tree: Single 4-1/2" 5,000# 5 Sand Fill on PXN plug 7 RT to MSL ELEV = 99' TD = 11,335' ETD = ~0,980' MAX HOLE ANGLE = 34.51 @ 4200' _-= G-1 _E G-2 --- G-3 -= G-4 _~ G-5 -- B-1 --- B-2 -- B-2 --- B-3 --- B-4 _-= B-5 _~ B-6 Top of Junk @ 11,254' SIZE 26" 20" 13-3/8" 9-5/8" 9-5/8" 9-5/8" Tubing: 4-1/2" WT i ' rrading Bay Unit Well # G-22 Actual Completion (4/98) CASING AND TUBING DETAIL MD MD TVD GRADE CONN ID TOP BTM. BTM 1" wall 94 61 & 68 47 47 47 12.6 24.0 Surf. 356' 356' BuR 19.124 Surf. 629' 629' H-40 BuR 12.415 Surf. 5548' 4977 N-80 BuR 8.681 Surf 7016' 6231' P-110 BuR 8.681 7016 10,087' 8915' S-95 BuR 8.681 10,087' 11,335' 9984' L-80 Imp. Butt 3.958 40.6' 9978' 8746' JEWELRY DETAIL NO. Depth ID Item 40.60' 1 9897' 2 9898' 4.75" 3 9903' 4 9945' 3.813" 5 9978' 6 10,968' 4.0 7 10,980' 2.635 8 10,981.55' 2.99 Cameron DCB 4-1/2" Tubing hanger. Baker Anchor Tubing Seal Assy. Baker Model 3H Pema Packer. Baker 5.22' Millout Ext. Baker "X" Nipple Baker Ball Seat Sub Otis "BWH" Penn Pkr (10,961' DIL) 3-1/2" Otis "XN" Nipple, w/2.75" PXN plug WLREG PERFORATION DATA G-22 new completion dwg.rtf REVISED: 4/13/98 DRAWN BY: DNM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: UNOCAL FIELD / UNIT / PAD: McArthur fiver/Trading Bay/Grayling DATE: 4/19/98 FEUID I i [ G-22 I Waterl P I KCL 9,897 ............ - ........ I .... 11500rain ....... '2,:~0~< 9 5/8, 47#, N-80 1 4 1/2 I 2187 ~ :-START 2,200 15 MIN TiME TBG: CSG PRESS 2,200 2,300 2,300 30 MIN TIME TBG CSG pRESs 2,200 2,300 START i F TiME 93O COMMENTS: Pretest pressures observed for thirty minutes prior to pressureing up annulus. G-12 COMMENTS: Water l P I KCL 1Z072 9 5/8, 47#, N-80 3 1/2 2191 Pretest pressures observed for thirty minutes prior to pressureing up annulus. 3,200 3,200 2,250 3,200 3,200 I 1,500 2,250 2,250 945 3050 3050 G-16 COMMENTS: COMMENTS: COMMENTS: Water l P I KCL 11842 9 5/8, 47#, N-80 3 1/2 2291 Pretest pressures observed for thirty minutes prior to pressureing up annulus. 1150 2350 2350 2350 955 I I 15OOoI I I I II 15OOoI I I I TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL PAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 9.3 0.48 0.00 0.00 WELL TEST: Initial X 4 - Year Workover Other Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c- Inspector OPERATOR REP SIGNATURE: Johnny T. Santiago ju9jdsfe.xls , AOGCC REP SIGNATURE: Louis R. Grimaldi (Rev 9/17/96) ~AR-27-98 FRI 13:B2 UNOO~hL aSSET GAS GRP FaX NO, 90721,'r7874 P, O1/O1 Unocal Corporation 909 West 9'a Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL :March 27, 1998 Wendy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Stares of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our January 23, 1998 letter which Blair signed granting time extensions for various wells. Testing or ~vork was co...mp!eted on the follom.'ng wells and the results of this work is listed: Anna 29-42: Well head inspection completed (no leaks), Variance granted on 3/3/98. Baker 4: MIT passed on 2/15/98 by Leu Grimaldi Brace 31-42: Coil Tubing operation completed to repair leaking cement plug. Pressure test completed. GP 33-14RD: SI MIT successfully completed on 2/11/98. GP 22-13RD2: Variance granted on 3/17/98, MIT completed on 12/15/97.. Grayling 16: Workover completed on 3/26/98. MIT Passed. Monoped A-eRD2: MIT passed on 1/28/98 by Leu Grimaldi Testing: or work was attempted on thc follo~ng.shut-in wells and a time extension until. June 30. 1998 is reques!~.O to comolete further work.and testing, Anna 19-42: Scale cleanout of tubing completed, further testing scheduled to prove casing integrity, Anna 27-42 '. Scale cleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 46-42 '. Temp Survey ran on 2/17/98, survey should prove no flow and allow SI status. Baker 9: MiT attempted on 2/15/98, farther wireline testing scheduled to prove casing integrity. Monopod A-12RD2: SI MIT attempted, Temp Survey scheduled to prove no flow, Monopod A-29 : SI MIT scheduled to prove no flow/casing integrity King 4RD : WFL indicates possible casing leak, well shutin, further testing and workover scheduled. King ISRD: WFL indicates possible casing leak, well shutin, further testing scheduled. King 22RD: WFL indicates possible casing leak, well shutin, further testing scheduled. Grayling 5 : WorkoverfRedrill scheduled in current drilling schedule. - Grayling 22 : Workover/Redrill scheduled in current drilling schedule. Grayling 28 : Workover/Redrill scheduled in current drilling schedule. Grayling 36DPN : Workover/Redrill scheduled in current drilling schedule. Grayling 40 : Workm'erfRedrill scheduled in current drilling schedule. Unocal respectfully requests a time-extension until June 30, 1998 to complete the work on the above listed Anna, Baker and ,Monopod wells. The Grayling and King work will be executed per our current drilling schedule..Please call me if,ou have any questions or clar/fication on these issues. R i C E i V E D ~ .~AR 2'7 Senior Reservoir Engineer Cook Inlet Waterflood Mana~ 0ii & Gas t;~m,;. CommIssIon Anchorage Please acknowledge the approval of the time extension and >'our receipt of this letter by faxing back a signed copy of this letter to Cltristopher Ruff at 263 ~7874 (fax), '[Vendy~han ....... Dat{~ I - AOGCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: RT 99' above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface Grayling Leg 3, Conductor No.1 8. Well number 1413' FEI, 1789' FSL, Sec 29, T9N, R13W, S.M. TBUS G-22 At top of productive interval 9. Permit number 2091' FNL, 3361' FEL, Sec 32, T9N, R13W S.M. at 8881' TVD 75-16 At effective depth 10. APl number 2553' FNL, 3761' FEL, Sec 32, T9N, R13W, S.M. at 9908' TVD 50-133-20272-00 At total depth 11. Field/Pool 2579' FNL, 3791' FEL, Sec 32, T9N, R13W S.M. at 9984' TVD McArthur River Field 12. Present well condition summary Total depth: measured 11335' feet Plugs (measured) true vertical 9984' feet Effective depth: measured 11,254 feet Junk (measured) true vertical 9908 feet Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" Driven 360' 360' Conductor 629' 20' 1125 cu.ft. 629' 629' Surface 5548' 13-3/8" 5802 cu.ft. 5548' 4977' Intermediate Production 11335' 9-5/8" 1840 cu.ft. 11335' 9984' Liner Perforation depth: measured (See attachment) true vertical ORt6~NAL Tubing (size, grade, and measured depth) Dual 3-1/2" 9.2 Ib/ft N-80 Butt. tubing strings.(LS at 10583' MD, SS at 10037' MD) Packers and SSSV (type and measured depth) Otis RDH at 9994' MD, Otis BWH at 10507' MD, Otis BWH at 10968' MD 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 4/1/1998 16. If proposal well verbally approved: Oil: 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. Signed: '") ~ ~t o.~.,.~. Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity Test Location clearance ., .-,) Mechanical Integrity Test Subsequent form required 10- ¢2('~ '~ Original Signed By Approved by order of the Commissioner 0avid W. JohnstonCommissioner Date Form 10-403 Rev 06/15/88 Re Copy turne4(~ SUBMIT IN TRIPLICATE Grayling G-22 Perforation Record Date Interval (MD) Interval (TVD) Status Formation 6-22-75 11081-11082' 9957-9965' Squeezed HB-5 6-23-75 10708-10710' 9429-9431' Squeezed HB-2 6-24-75 10590-10592' 9327-9329' Squeezed HB-1 7-3-75 11115-11145' 9787-9814' Isolated w/packer HB-6 7-4-75 10984-11022' 9671-9705' Isolated w/packer HB-5 7-7-75 10911-10936' 9607-9629' Injection HB-4 7-14-75 10685-10700' 9409-9422' Injection HB-2 7-15-75 10670-10700' 9396-9422' Injection HB-2 7-16-75 10832-10862' 9537-9564' Injection HB-4 7-17-75 10768-10788' 9480-9498' Injection HB-3 7-18-75 10602-10622' 9337-9355' Injection HB-1 12-18-75 10832-10862' 9537-9564' Injection HB-4 12-18-75 10768-10788' 9480-9498' Injection HB-3 4-2-76 10670-10700' 9396-9422' Injection HB-2 4-2-76 10602-10622' 9337-9355' Injection HB-1 6-29-78 10602-10622 9337-9355' Injection HB-1 6-29-78 10670-10700' 9396-9422' Injection HB-2 6-30-78 10768-10788' 9490-9498' Injection HB-3 7-1-78 10832-10862' 9537-9564' Injection HB-4 7-1-78 10886-10904' 9584-9600' Injection HB-4 11-16-89 10595-10629' 9339-9367' Injection HB-1 11-16-89 10643-10734' 9379-9456' Injection HB-2 11-16-89 10742-10752' 9463-9472' Injection HB-2 11-16-89 10762-10815' 9480-9526' Injection HB-3 11-16-89 10827-10952' 9536-9645' Injection HB-4 11-19-89 10061-10095' 8891-8920' Injection "G" Zone 11-19-89 10115-10154' 8936-8969' Injection "G" Zone 11-19-89 10178-10218' 8989-9022' Injection "G" Zone 11-19-89 10230-10300' 9032-9091' Injection "G" Zone 11-19-89 10370-10430' 9150-9201' Injection "G" Zone Grayling G-22 Summary of Work Program Grayling G-22 Injector workover was originally proposed to repair tubing to casing communication and restore access to existing Hemlock and "G" perforation intervals. In light of the new information regarding the anticipated leak in the production casing, the attached revised program describes the well work xvhich will now be carried out. In short the workover xvould entail the fbllowing steps: · Remove all the existing tubing in the well and uppermost packer and middle packer. · Conduct a leak investigation with a RTTS packer and USIT log to determine the nature of the leak at 4,750 as identified by the WFL log results of 17 December 1997. · Restore the well to a serviceable condition. · Carry out a modified MIT test to demonstrate the tubing/packer integrity. The fluid used to workover and re-complete the water injector will be 3% KCL/FIW with an approximate weight of 8.5 ppg. The well was shut in on 13 January 1998 and no pressure has built up on either the long or short string. Unocal Alaska Business Unit Grayling Platform Well Grayling G-22 Injector AFE Prepared by: Neil Magee Date:3/4/98 Revision 0 UNOCALi:?~ No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) I Rig up on well 12.0 12 0.5 2 Check for tubing pressure and set BPV. 2.0 14 0.6 3 ,N/U and test 13-5/8" 5K BOP's 8.0 22 0.9 4 P/U landing joints and screw into hangar top. 4.0 26 1.1 5 Attempt to pull tubing/packer assembly loose from packer 9,994' 2.0 28 1.2 6 If unable to pull free, perform chemical cut in tubing as deep as possible. 6.0 34 1.4 7 Pull dual string loose and displace well with 3%KCL/FIW. 4.0 38 1.6 8 POOH laying down packer and tubing 22.0 60 2.5 9 P/U 5"" DP and RIH with overshot to recover tubing stub. 18.0 78 3.3 10 Fish tubing stub and POOH laying down tubing 8.0 86 3.6 11 Make up and RIH with packer milling assy to 10,507' 8.0 94 3.9 12 Mill over packer 22"+/- Ciculate hole clean. 4.0 98 4.1 13 POOH with packer milling assembly and packer. 8.0 106 4.4 14 RIH with bit and scraper. Clean out well to lower isolation packer atl 0,968' 7.0 113 4.7 15 Circulate hole clean and pump hi-vis pill. 3.0 116 4.8 16 POOH with scraper assembly. 7.0 123 5.1 17 Rig tip Schlumberger and run USIT log from 10,000' to surface 8.0 131 5.5 18 Make tlp and RIH with packer assembly to locate potential casing leaks 8.0 139 5.8 19 Conduct leal( investigation from 10,000' to surface. 12.0 151 6.3 20 POOH and lay down packer assembly 6.0 157 6.5 21 Repair potential casing leak as required.(potential patch/liner installation) 48.0 205 8.5 22 Run 4-!/2" completion tubing with anchor seal assy. 16.0 221 9.2 23 Displace well to inhibited packer fluid. 4.0 225 9.4 24 Run BPV and N/D BOP's 6.0 231 9.6 25 N/U tree and test to 5000 psi 6.0 237 9.9 26 'Release well to Production and prepare to skid rig. 8.0 245 10.2 Swr AFEG-22.xls Page 1 of 1 3~6~98 UNOCAL - RKB to TBG Hngr = 46.6' Tree connection: Dual 3" 5,000# Obstruction in tbg (~!! 10,055 A o C,, · D ~ -:-- G-1 [ Obstruction in [-= G-2 tbg (id-}, 10,490 ~ 7 i == G-3 / ii G-4 4 /- 5 ::: i: : 8 ' · 9 -= 5-1 == B-2 -= B-2 -1-- '"= B-3 :'--- B-4 3 ---- 5-5 _:E B-6 · ~ ~opofdunk ,,,,,--' '-,,,,. RT to MSL ELEV = 99' TD=11,335' ETD=Il,254' MAX HOLE ANGLE = 34.51 @ 4200' ',IZE 26" 2O" 13-3/8" 9-5/8" 9-5/8" 9-5/8" 'Fubin~: I,S 3-1/2- S.q 3- I/2" 11,254' __Fill ~), 10,480' ( iA S I N G A N I) "l' I.,: B 1 N G D E T A I L (; R.\I)I,i ( '( )NN ID 'lOP Trading Bay Unit Well # G-22 Completed 5/6/90 MD 'l'X,'l) BTM, |I'I"M I" wall 24.0 Surf. 94 Butt 19.124 Surf. 61 & 68 H-40 Butt 12.415 Surf. 47 N-80 Butt 8.681 Stiff 47 P-110 Butt 8.681 7016 47 S-95 Butt 8.681 10,087' o.2 N-80 13utt 2.992 0' 9.2 N-80 Butt 2.992 0' 360' 629' 5548' 7016' 6231' 10,087' 8915' 1,335' 9984' 0,583' 9330' I 0.037' 8831' .IE'O,"I';I,ItY DI':'I"..~.I 1, Depth II) Item 46.60' A 9951 2.75 B 9994' 2.90 C 10,030' 2.635 D 10,036.67' 2.99 btm 10,037.35' I 9960' 2.75 2 9994' 2.90 3 I0,031' 2.75 4 10,478' 2.75 5 10,510' 2.95 6 DP MD 10,507' 4.00 7 DP MD 10,512' 4.00 8 10,550' 2.75 9 10,582' 2.95 btm 10,583' 10 DP MD 10,968' 4.0 11 DP MD 10,973' 2.99 12 DP MD 10,980' 2.635 I 13 DP MD 10,981.55' 2.99 i btm 10.982.30 Cameron DCB Dual 3-1/2" Tubing hanger. SHORT STRING 3-1/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RDH" Dual Packer, SS set 3-1/2" Otis "XN" Nipple, 2.75 WLEG LONG STRING 3-1/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RHD" Dual Packer 3-1/2" Otis "XA" Sliding Sleeve 3-1/2" Otis "XA" Sliding Sleeve Otis Straight Slot Locator w/8.96' of seals & mule shoe Otis "BWH" Penn Pkr (10,500' DIL) Otis Seal Bore Ext. 3-1/2" Otis "X" Nipple WLEG Otis "BWH" Penn Pkr (10,961' DIL) Crossover 3-I/2" Otis "XN" Nipple, 2.75 WLEG w/PXN plug SLICKLINE 'I"AGS SS 'Fagged fill w/2.343" GR LS 'Fagged Obstruction in tbg w/2.125" LIB Tagged Obstruction in tbg w/2.25" Swedge STI M t.i i..,ATIONS 3 stage diverter acid job 138 bbls of 7-1/2% HCL 200 bbls of 6 1/2% X 1-1/2% mud acid 12/9/97 . ~ 10,480' 12/10/97 ~ '10,055' 12/10/97 ~ 10,490' I 1/21/89 G-Zone PE'RFORATION i)AT'A Accum. Zone Top Btm Amt SPF G-1 10.061 10,095' 34' 4 G-2 10,115' 10/64' 39' 4 G-3 10.178' 10.218' 40' 4 G4 13,230' 10,300' 70' 4 G-5 10.370' 10,430' 60' 4 10,590' 10,592' 2' 4 B -1 10,595' 10,629' 34' 16 & 4 B-2 10,643' 10,734' 91 20.8 & 4 B-2 10.742' 10,752' 10' 4 B-3 10,762' 10,8 16' 53' 16 & 4 B-4 10.827' 10.952' 125' 16,12 & 8 B-5 10,984' 11,022' 38' 4 11.081' 11,082' 1' 4 B-6 11.115' 11.145' 30' 4 ,. Date Last Opr. 11/19/89 11/19189 11/19/89 11/19/89 11/19/89 6/24/75 11/16/89 11/16/89 11/16/89 11/16/89 11/16/89 7/4/75 6/22/75 7/3/75 Present Condition Open f/Injection Open f/Injection Open f/Injection Open f/Injection Open f/Injection Cmt sqz'd f/Isolation. Open f/Injection Open f/Injectio n Open f/Injection Open f/Injection Open f/Injection Isolated Cmt sqZd f/Isolation. Isolated G-22 dwg.rtf REVISED: 12/12/97 DRAWN BY: SLT U NoCAL ) . RKB to TBG Hngr = 46.6' Tree: Single 3" 5,000# 5 1112t~ --- G-1 --- G-2 -= G-3 --- G-4 _--- G-5 -- B-1 --- B-2 -- B-2 ~ B-3 -= B-4 10 _--- B-5 -- B-6 Top of Junk ~ 11,254' ....-- -..... RT to MSL ELEV = 99' TD = 11,335' ETD = 11,254' MAX HOLE ANGLE = 34.51 @ 4200' 13-3/8" 9-5/8" 9-5/8' 9-5/8" 'i'ubinl~: 3-1/2" 1" wall 04 61 &68 ,17 47 ,47 9.2 N(). __ 1 2 3 4 5 7 8 9 10 II 12 13 Trading Bay U'nit Well # G-22 Proposed Completion (4/90) CASIN(;ANI)'' ~' '" I LBIN(, i)ETAll, N'I I') ~. I !') 1 "V D (; I~,.\I)E ('(.).N N I D I'OP B'I'M, II'I"M 24,0 Stiff. 360' Butt 19.124 Surf. 629' H--tO Butt 12.415 Surf. 5548' N-80 Butt 8.681 Surf 7016' 6231' P- 110 Butt 8.681 7016 10,087' 8915' S-95 Butt 8.681 10,087' I 1,335' 9984' N-80 Butt 2.992 0' 10,583' 9330' Depth 46.60' 9960' 2.75 9994' 2.90 10,031' 2.75 10,478' 2.75 10,510' 2.95 DP MD 10,507' 4,00 DP MD 10,512' 4.00 10,550' 2.75 10,582' 2.95 btm 10,583' DP MD 10,968' 4.0 DP MD 10,973' 2.99 DP MD 10,980' 2.635 DP MD 10,981.55' 2.99 btm I 0,982.30 J Ii;WE I.,RY i) ETA 11., II) Item Cameron DCB Dual 3-1/2' Tubing hanger. 3-1/2" Otis "XA" Sliding Sleeve 9-5/8" Otis "RHD" Dual Packer 3-1/2" Otis "XA' Sliding Sleeve 3-1/2" Otis "XA" Sliding Sleeve Otis Straight Slot Locator w/8.96' of seals & mule shoe Otis "BWH" Perm Pkr (10,500' DIL) Otis Seal Bore Ext. 3- I/2" Otis "X" Nipple WLEG Otis "BWH" Perm Pkr (10,961' DIL) Crossover 3-1/2" Otis "XN" Nipple, 2.75 w/PXN plug WLEG Zone Top Btm G-1 lO,O6~ lO,O95' C--2 10.115' 10,'rM.' G-3 10.178' 10.2B' C,-4 10,230' 10,300' G..5 10,370' 10,430' 10,590' 10,592' B-1 10.595' 10,629' B-2 10,643' 13,734' B-2 10.742' 10.752' B-3 10,762' 10.815' B-4 10,827' 10,952' B-5 10,984' 11,02_2 11,081' tt08Z B-6 11,115' 11,145' PIi;III;'()RA'I'ION I)A'I"A ,. Accum. Bate Amt SPF Last Opr. Present Condition 34' 4 11/19~8g' 0Pen' f/injec't i~.n ,'. , ' ' '.'i" '" i'i"i'.i 39, 4 11/19/89 open f/Injection · 40' 4 11/19/89. Open fi.Injection 70' 4 11/19/89 Open.f/Injection 60' 4 11/19/89 . open f/InjeCtio n ..... 2' 4 6/24/75 Cmt squid f('lsolatio n: i .,.' ' 34, 16 & 4 11/16/89 . Open f/Injectio n · 91' 20, 8 & 4 11/16/89 Open f! Injection 10' 4 11/i6)89 Open f/. Injection ...... 53' 16 & 4 11/16/89 Open f/Injectio n 125' 16,12 &8 11/16/89. . . open f/InJect.io, n .... 38' 4 7/4/75 Isolated ~ 4 6/22/75. 30' 4 7/3175 Isolated ...... G-22, new completion dwg.rtf REVISED: 12/12/97 DRAWN BY: SLT 5" KILL UNE WITH TWO ,..i"5,k/ VALVES I '].,' KILL LINE FROM MUD &: CEMENT UNIT 8ELL NIPPLE ANNULAR PIPE RAMS BLINO. RAMS I '~ ~OWLINE PIPE RAMS l,.l-5/a" ,.sM FLANGE DOUBLE GATE 5M ___]4." CHOKE LINE WITH ONE REMOTE &::I k,C~NUAL 4."5M VALVE _~~ ;i,,' '(l,.' 1 cO~ECT~ 'rD C~OK~ ~FOLa 15-5/8" 5M FLANGE t SINGLE GATE 5M ~ 15-5/8" ,SM FLANGE I I I RISER 10" 5M x 13-5/8" ADAPTER CAMERON 5M SPOOL 15-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) ..... -oRAWN: OAC ARP'O: SCALE: NONE DATE: MIXINO PIT 4o BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM /..// Ii TRIP 4-5 TANK BBLS i' 18,5 BELLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS DEOASSER! 67 BBLS I DESILTER 24-0 BBLS SHAt<ER SHAK ER RESERVE 475 ......... '___tCENTRIFUGE PIT BBLS NOTE: THE S"Y'SSI"EM WILL BE EQUIPPED WITH A DRILLINg PIT LEVEL INDICATOR AUDIO & VISUAL WARNINg DEVICES. WITH EQUIPMENT LIST l) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VlSUXL & ^UD~O) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS B) DESILTER CENTRIFUGE lO) MIXING PIT UNOCAL GRAYLING MUD PIT SCHEMATIC DRAWN ElY: DAC APP'D: 6213 SCALE: NONE DATE: 1 TO GAS BUSTER /\ TO DERRICK VENT l'O WELL CLaN TANK /\ AUTOMATIC CHOKE FROM CHOKE LINE 3-1/8" AUTOMATIC CHOKE UNION VALVES UPSTREAM OF CHOKES ARE 10,000 PSI GATE TYPE VALVES 00WNSTREAM OF CHOKES ARE ,5,000 PS[ CATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC AP P'O: G SCALE: NONE OARS: Unocal Corporation Agricultural Products 909 West 94 Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) March 9, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Grayling G-22 10-403 Application for Approval to Repair Well and Extend Variance Dear Blair: As promised in previous correspondences, we are submitting a 10-403 Application for Approval of the G-22 workover project and variance which will allow us to inject into the well without repairing the casing leak. Due to the limited life of the field, the plan is to put a new completion in the well which will isolate the injection interval from the annulus above the packer. The well will be tested by raising the injection pressure to normal operating conditions while monitoring the casing pressure on the well. A large differential pressure between the tubing and casing will demonstrate tubing/packer integrity. Following the workover the daily pressures will be reported to you on a monthly basis. If casing pressure is recognized during the daily monitoring, the well will be immediately shut-in and a plan will be developed to deal with the problem. Please approve the application and return an approved copy of the 10-403 for our records. If you have any questions please call me at 263-7830. hristopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management FEB-03-98 TUE 15;59 UNOORL P, SSET GRS GRP FRX NO, 9072 ?7874 f Unocal P, O1/18 Fax transmittal 909 W. 9th Avenue Anchorage, AK 99501 Fax 907-263-7874 907-263-7665 (confirmation) To; Fax Number: [' 77~--~_¢ ¢z Pages: Cover plus [/? __[ Comments: FEB-03-98 15'~9 UNO¢flL ~SSET GflS GRP F~× NO, 907~'~7874 Unocal Corporation Agricultural Products 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) January 29, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 P, 02/18 Re: Grayling G-5, G-16, G-22, CrJ6DPN and G-40 9-518 casing leaks. Dear Blair: Water-flow logs were run on G-5, G-16, G-22, G-36DPN and G-40. Thc results from these logs indicate possible leaks in thc 9-5/8" casing strings. Thc wells have been shut-h~. Copies of the WFL interpretations with updated wellborc diagrams arc attached for your flies. Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated copy of this letter to document notification for our records. Blair Wondzel[ Petroleum Engineer AOGCC Date FEB-03-98 TUE 15:59 UNOCAL UNOCAL RKB to TRG Head · 41.$' ~e nection: e3ao' to oeo' 12,418' 12,?1~ I G~2 (3-4 G-5 HB-1 HB-2 HB-3 ETD · 13,482' TO" 13,683" KB ELEV - MAX ANGLE ' 4E.48 (~ 11,0G?' G-16.DOC aSSET GaS GRP FaX NO, 9077~7874 P. 03/18 Trading Bay Unit Well # G-16 Re-Completed 5/8/87 CAS~rG AND TUBLNO DETAIL SIZE WT GRADE CONN ID TOP BTM. CMT 7.3/4' .312 wall Weld Surl: 601' NOTE: 12' I)L~. between DP & DIL 12.24' Diff. between tbg & DP 24.24' Diff. between DIL & tbg 13.3t8': 6] K-55 Sc~I Lock 12.515 Surf. 5~60' 2350 ax 9-$/8" 47 P-110 Butt 8,681 10,680' 12,416 1000 ax 9-$/8' 47 N.80 Butt 8.681 8503' 10,680' 9-5/8" 43.5 N.80 Butt 8.755 62~6' 8503' ~.$/g" 40 N-80 Burl 8,835 4009' 6296' 9.~/s" 4a.s N-aO nun 8.Tss 24' 40or " 9-5/8" 47 N-10 BuR 8.611 S~ 54' ~ 2~ P-Il0 B~ 6,194 I I,~5' 13,663' ~' 2P H-g0 Bu~ 6,1~ 5~. 11,345' T' DV Coll~ 61 ~' 6174' Tubing: 3-1/2" 93 N.80 S.L. 2.~2 0' 12,0~' 2-7/I" 6.4 N-S0 S.L. 2 441 12 20; 12,773' - i i i i ' ii ii ' I I II II ['~' Integrity Note: . I W~te~..~ (~4BPM, 205O psi down tho P. S/8 X13-3/S"o. nnulua, aT.e,~,pLo~rmon4/23/S? I ~v~led ~j~ion to 6060'. Cma sqz'~ do~ ~e ~ul~ wt g00 sx of clue O . No~d PBU ~ ~ulus t on 5/t/87, bled o~ built back-uu to 800 esi ~abll,h~d no inic~ion rate 0 ' , ,,, , ' _, '~7: ....... , ,~2 00~s]~5/~87, , , ~LRY DET~L ' -' N~ ~epth ID Item 41,5 I 12,042' 2,75 2 i 2,072' 2, 4O6 3 12,073 3.25 4 12,076' 3.25 5 12,086' 2,441 6 12,087' 2.760 7 12,088' 2.992 8 12.20g' 2.441 9 12,237' 2.44 I 10 12,77'J' 2.406 I 1 12,7'/4' 3.25 12 12,778' 3.25 13 12,816' 2.313 14 12,845' btm 12,B46' ,, , , , , FI$tl Cma Relaine~ Iu~ced 1~' Cmt Retainer 3-I/2" CIW Stabden Tubi~ Hanger Otis "XA" Sld~ Siva Lo.mr S~ ~, w/1.6' offals, B~ M~el "DB" P~ ~. ~32 Seal Bore E~. ~s~, 80~ Bore E~. B~ X 2-7/8' Seal L~k P~ Crms~, 2-7/r ~ L~k B~ X ~.1/2' 3e~ Lock pm 4j~ of~-l~", 9.2~, N-gO, ~, SnaI Lock ~$ C~w~, 3-1~" Se~ L~ Box X 2-71r ~ Lock Pin Tel~c.Meda ~ow M~el 8~2 $eg Bore E~ ~EO STIMULATIONS Acldlze w/4000 gals of 12-3 mud acid & lO0 gait Df E-OS eolvent. Fraotum 811muleted w/13,$00# of sand Inlo perf., Acldlze w/4000 gala of 15% HCL & 10,000 gals of t2-3 mud acid. Acldlze w/18000 gale of ?.~% HCL Acldlze w/35,700 gala of 12-3 mud SLICKLIN~ WORK 6/18/74 (~ 13,462' 3/30171 (~ 13,412 4/2/78 (~ 13,412 7/20/74 4/6/78 HB-4 4/2~/r/ "o" Zono $/3/87 "O" Zone Tagged XO w/2.72" OR 8/3tg7 Tagged obslmDflon wi 2 23" OR 8/3/g7 2.25" LIB shewed deep gouges on ~lde & amaller In middle 12,07g' WLM (12,086' MD) ]2,220' WLM 12,220' WLM PER~ORATION DATA Accum Ullt Zone ToL Btm Amt SPP Pert Date G4 "' 12j ' t2,146' ' 26' 12 ..... G-2 12,164' 12,210' 46' 12 4/26~7 O-3 12,275' 12,318' 40' 12 4~25/87 G.4 12,335' 12,450' 11 ~' '12 412~/87 G-; t2,88G' 12,726' 40' 12 4/28187 HB=I 12,84B' '12~BtO' 46' 16 4126/07 HB-2 '12,904' '12,98~' 81' HB-2 13,008' 13,088' 8~' eH4/74 HB-~ ~3,108' '13,'142' 34' HB-4 13,172' ~3,270' 08' 20 4/211/87 Preaent Condition Open 11 lnJedion' .... Open fl Injection Open fl Injection Open fl Injection Open fl Injection Open f! Injection Open fl Injection Cmt Sqz'd Cma Sqz"d Cma Sqz'd Open f/InJection REVISED: 8/5/97 DRAWN BY: SLT FEB-03-98 TUE 16:00 UN00flL ASSET GAS GRP i!,,,'~ I1 I I,~IIIL/~I FAX NO, 9072~q7874 P, 04/18 r. UI A GEOQUEI~T 500 W. International Airport Rd. Anchorage, Alaska 29518 FAX COVER SHEET DATE: TO: FROM: RE: CC: February 3, 1998 TIME: 10:48 AM Hal Martin/Chris Ruff PHONE: 907-263-'7 6"/5 UNOCAl. FAX: Rob North PHONE: (907) 563-1597 GeoQuest ICS FAX; (907) ,562-6521 G-16 WFL Results Number of pages including cover sheet: 2 Message Hal & Chris, Attached to this cover letter Is a log presentation of the WFL results for 61-1 Below is a brief discussion: With the tubing to 7" annulus open during Injection the well was returning 1000 bbls to the surface, This flow Is originating at the sliding sleeve at a depth of 12042 feet as no flow was Indicated jUSt above the packer at 12073 feet. With the annulus closed a reduced flow rate of about 100 bpd is indicated moving up from below 12110 feet, Thls flow appears to be leaking past the packer at 12073 into the tubing x 7" annulus where It oontinues up to a point between 6500 and 6300 feet where It exits the 7" casing, No further up flow was seen above this point with the annulus closed. Down-flow measurements Indicate a hole In the tubing between 3500 and 4000 feet where flow Is measured In the tubing x 7" annulus, This flow appears to continue down to -6400 feet where It merges with the up.flow, exits the 7" casing and flows down the 7" x 9 5/8" annulus. This down-flow continues down past 12100 feet, Interested in your comments, Regards, Rob.. ': -"' ......."'! .~' !i'.;..,. · ,. ,.,,,.,,, '~,,/;...,,,~ ... FEB-03-98 TUE 18:00 UNOORL RSSET ORS GRP FRX NO, 907~'~7874 P, 05/18 { .... ,,,u,,,~,-~.,. rn^ nv. ~v{ ,~v~ r, u,' I o o 0 0 ~ Up Annul, O~h U~ ,l~v,d. ~.d Do~ Tub. x 7In ~ ~l 7~ I I ,~ I ~ , ~o~ '[ '; '- - ~ ...... ;~ , ~ , ~ , ~ I ' ~o~ ~j~tl.,..~.~tt~ ~/;!~ ~ ~ ? ~ ..... ' ...... 70~ [' , , '~ .......... ~ I ~ , &~M~~~',~ ~~ ~ ~ ~ _ ~ ........... FEB-03-98 TUE 16:01 UNOCC~L ,'qSSET Gb, S GRP UNOCAL RKB to TBG Hngr = 42' Tree connection: Dual 3" 5,000# ~cl SIZE 13-3/8" 9-~/8" L$ 3-1/2" SS 3-1/2" WT FaX NO, 9072¢:'~'7874 , P. 06/18 Trading Bay Unit Well # G-36DPN Completed 12/5/87 CASING AND TUBING DETAIL GRADE CONN 1D , 11 KB ELEV = TD' 13,479' ETD" 13,364' MAX HOLE ANGLE .: 48.36° G-36.DOC 54.5 K-J5 Butt } 2.6 ! 5 43.5 & 47 N-80 & S-95 8rd LT&C 8.835 29 N-g0 8rd LT&C 6. i 114 9.3 9.3 NO. ,,, Depth 42' A 10,215' B 10,249' C 10,266' D 10,279' E I0,280' btm 10,281' 1 10,i78' 2 10,249' 3 10,318' 4 12,467' 5 12,500' TOP BTM. 12,501' 7 12,505' gusp~cltb§paxtcd ] g 12,$12' @ 11,329' I 9 12,520' IB ran on 8/1/97 10 12,553' l Il 12,585' btm 12.586' ~ Suspect tbg parted @ ~2,~o7' IS ran on 6/10/95 N-80 S.L & DSS-IrI'C 2.992 N-80 $.L 2.992 Surf. 5307' Surf 10,874' 10,354' 13,479' O' 12,586' o' 10,281' JEWELRY DETAIL Item Camoron DCB Dual 3-1/2" Tubing hang~s, StlORT STRING ..... I II Ill 2.75 3-I/2" Otis "XA" sii~n$ Sleeve 9-518" Otis "RHD" Dual Packer 2,635 3-1f2" otb "KN" Nipple, 2.75 Olia Ball Catcher sub WLEO LONG STRING II III I I 2.75 3-1/2" Otis "XA"Sliding'"Sl=,:vc 9-5/8' Otis "RI'iD" Dual Packer 2.75 3-1/2" Otis "XA" Sliding 3.73 3.1/2" Olis "XA" $liding Sleeve otis Straighl Slot Locator w/4' spaoer, $' of seals & mule shoe 4.00 otis "WB Perm Pkr 4.00 otis Seal Bore Ext. Otis Mill out Eat. Crossover, 4-.1/2" X 3-1/2" 2.75 3,1/2" Otis "X" Nipple WLEO FISH Retrievable Bridge Plug gLICKLINE TAGS SS "XN" w/'TX" plug leaked LS Tagged Fill Tagged obstruction (parted tbg) Tagged obstruction (parted tbg) WI_RELINE WORK WFL ran on 1/ STIMULATIONS Acidized w/5% HCL & 12-3 Mud acid I]/12/73 ~ 13,364' 7/31/97 (~ 10,266' I 1/19/88 @ 13,270' 6/10/95 @ 12,507' $/1/97 @ 11,350' 8/18/87 West Foreland "O" Zolle .-- ' ....... , : PERFORATION DATA Zo~e Top Btm Ami 8PF Last Opr, ~ Condition' (~"1., . 11,0~C~I'' 11,!10. ~/ 1i WlWe7 C)F~.n f/Inj~,-~on m _.G-2 t1,124 ll,lOff S? 12 .." 'WlO87 e.3 11,212' 11,265' .. '. ~ 12 .8/tW87 ~n~tJni~,-~on . ~ 04. 11,2~z ,1~,30~ , 1o~ 12 Wl~te7 ,_.q.o.o.o.o.o.o.o.q~~~ n.S 11,497 11 ,S~ ~ 12 8/14/87 Oran --eNO ! 1,848' 11,e77 2'9' 12 t 8f'i4/07 Open g InJe,,,-Uon WF-~I L~] 2,664' 12.7~Z · ,98, 12 a/a/BT' WF.2 12,793' 12,920' "127' 12I a/5'~7 ' WF-3 .__!2,967' 13,00~ 129' 12 e/5~7 Opanf/ nla~lon WF.-4 13,.1.q~7 13220' 70' {$- ...... ~/fi/~7 ~-5 13,27~' .. 13,330' .... ....~'_. .......... 4 8/3/~ 7 REVISED: 8/4/97 DRAWN BY: SLT EB-.03_-98 TUE t6,01 , ,, UNOORL RE;SET GRS GRP P, 07/18 GEOQUEST 500 W, International Airport Rd. Anchorage, Alaska 99518 FAX COVER SHEET DATE: TO: FROM: RE: Februa~ 2, 1998 TIME: 2:29 PM Hal Martin/Chris Ruff PHONE: 907-263-'7675 UNOCAL FAX: 90'7-253-?8'74 Rob North I=HON£: (907) 563-1597 GeoQuest ICS FAX: (g07) 562-6521 G-#36DPN WFL Results Number of pages including cover sheet: 2 Message Hal & Chris, Attached to this cover letter ls a log presentation of the WFL results for G- 36DPN. Below is a brief discussion: With the tubing to 9 5/8" annulus open durtng Injection the well was returning 940 l:)bls to the surface, A rate of 256 bpd is shown to be leaking past the dual packer at 10249 feet, This rate increases at the station at 1020,5 feet Indicating a significant leak tn the short string sliding sleeve at 10215 feet. An additional small leak was indicated in the long string sliding sleeve at 10178 allhough this Increase le near the resolution of the WFL measurements. With the tubing to 9 5/8" annulus =losed no flow was seen leaking up past the dual packer at 10249 however at rate of about 200 bpd appears to originate at the LS eliding sleeve al 10178, This up-flow continues up the tubing x 9 5/8" annulu~ until between 5000 to 3000 feet whore It exits the 9 5/8" casing. An additional up-flow was measured at 10500 ff which may bo flowing up the 7" x g 5/8" annulus. Down-flow possibly in the tubing x 9 5/8" annulus is seen at 500 and 2000 feet. This flow appears to exit the 9 5/8" casing between 1000 and 2500 feet and continues down outside the 9 5/8" casing past the lowest WFL elation at 10550 feet.. I plan on delivering color copies tomorrow afternoon, Regards, Rob... FEB-03-98 TUE 1 UI,IOCPmL aSSET GrtS GRP ('-'q lumraerger FAX I,lO, 907~7874 I'MA IXU, I~U{' 50U~ P, 08/18 r', ur' , , UNOCAL, TBU G-36DPN, TRADING BAY UNIT, WPL, 25-Jan.gB, (gBLll 1) 0 0 0 0 ' : ,,, W.,Sk.,~ :~:~:~;I ...... I ,, ,1 , lJ~;~',, : i , ,,,,, ~ , , ~1 '~ ~'.~ .... ~ . .~]i,.~'i~ i~l'~,'~ i"'~' , "~l-"~ ....... IJ [J~'' ' ; ' ~ ' ' I ,,~. [ 1~,..,. , ..ILl_ . ~,,[ I , , , , ,', ' ,~' J --~' i;~ i --'-=: - :' ~. -_~I:A ,~, ~ 'i ' '; ': '1~~'' ',;;~l~i ' I~[,'~!'~1 ~ ' / .~"~1 ~, ~ ; ~',,, ' ' i ' - ~oo~ ~' ,'r,:, ~l~ ' r 1to~ L ~' I I11 , ' FEB-03-98 TUE 16:02 UNOCALe RKB to TBG Hngr = 48.83' Tree connection: Dual 3" $,000# 10 Rilnnd ii,hi ipeh 171I'47~t' II'Il 13 11 -- g584' UNOCAL aSSET GaS GRP 9119' FaX NO, 9072~,~7874 P, 09/18 Trading Bay Unit Well # G-5 Re-Completed 9/16/87 CA~U~G ARD TUBI~G DE,AIL , SIZE %%"I' GRADE CONN ID TOP BTM. CMT 16' 75 1-55 Butt 13.3/8" 54.5 K-55 Butt 9.5/8" 47 P-110 Seal Lock 9-5/8" 47 N-g0 Seal Lock 9-5/8" 43.5 N-80 Seal Lock 9-5/8" 40 N-80 Seal Lock 9-518" 47 N-80 Seal Lock T' 29 N-80 8rd LT&C 9-5/8" DV Collar .................................................... 5" ScAb 18 N-g0 Butt l'ublng: L,S 3-1/2" 9.3 N-80 S.L. 83 3-h'2" 9.3 N-80 $,L. Ta~led Metal Ob,t~u¢lion --6c2~/9~ @ 9175' WI,M w/2.Y3B ~9/97(~ 9175' WLM w/1.9~GR Surf. 591'[ 1330~ 12.615 Suit'. 5307' 2400 Ix 11,681 8519' 9657' 3000 ~n 8.681 6925' 8519' " 8.755 51 B7 6925' " 8,835 79' 5187 11.6111 Su~. 79' " 6.184 9544' 10,302' 200 an 4376' 4378' 9719' 9803' 2.992 O' 12,586' 2,992 0' 10,251' ......... JEWELRY DgTAIL 0-2 O-$ g715' H3.75" mill on i 19/2/87 . . =-' _= KB ELEV" 110.$' TO" 10,312' ETDI 9,$65' MAX HOLE ANGLE = 20.13' (~ 2800' MID PERF ANGLE = $.5° : ~ ,. , Depth 48.1Y A 905i1 9119' C 9140' D 9162' btm 9164' I "9~8T 2 9119' 3 9550' 4 9584' 5 9587' 6 9591' 7 9600' 8 961 I' 9 9632' bm1 9633' l0 9715 i I 9619' 12 9804 ! 3 980Y btm 9808' i III[L ii 2.75 2.75 4.00 4.00 2.75 4.00 4.276 4.00 4.75 X4,00 Cameron 10" X 51vL Du~l 3-1/2" 3S Tubinl h~nger. s~pRT s ,Xm~ 3-1/2" Otis "XA" Sliding Sleeve 9-$/8" B~:ar Dual P~:kcr g~ Hydro-Trip Sub 3.1/2" Otia "XN" Nipple, 2,75 LONG STRING ii i Ill 3.1/2" Otis "IA' $1idina 31cevc 9.5/8~ Bdter Dual Packer 3.1/2" Oti, "XA" Sliding Sleeve Loc~or SeAl A~sy. g~ket 7" FB-1 Pk~ Baker Seal ante Ext., 9' long. Croasuver, to 3-1/2" Otis "X" Ptot'iln Nipple WLECt Baker 'FB-I" pl~, Aize 85-40 5" 18#, N-80 Anchor Latch 8CAI Aasy. Baker "FA-I" pkr, aiza 85-47 G-5,DOC FISH 2 Junked Retainer 9/16/71 @ I0,244' Junked Retainer 8/I 2/72 ~ 10,240' Wire line tools, 16.5' length 6/6/95 ~ 9274' 8LICKLINE TAGS L8 Tagged obstruction, metal protruding ~ side oftbg, wi 2,5" lB 6/26/95 ~ 9175' WLM Tagged obstruction w/1.9" GR 8/9/97 (~ 9181' WLM WIRELINE WORK WFL ran on t/22/98 indicate a csg leak ~ or near DV collar i~ 4376'. Indicatiom of multiple tlog le~8 in one or both sting from 2400' to STIMULATIONS Acidized w/2.t/2% HCL & 12-10 Mud acid 11/18/71 B-l, 13-2, B,3 ,. ,,, PERFoRATIo~ i~ATA " Zone Top I~n SPF ,, ,Lam OW.Pte~emCendlaon .... O-1. 9,20E: 9~2417 32'. 4 9/11/87 OP~.n.fll,r,~__Jon G.2 6,253 9,268' t.~, 4 12/30F8'1' Olin f/In~ec0.0n ... ~ 9,3~ 9,~ 1~ 4 1~Sl G~ 9,~:9,~ ~ 4 1~81 O~nUl~n G~ g,4~ 9,~ ~ .... 4. 1~81 ~nU~on ~2 9,~ 9,~ 7E 6 .1~1~81 ~d ~3 ~.~ g,a/u ~ 4 I~BI ~d .. ~4 9,871.' g.~. _ ~ 4 t~8! ~n U I~on · 4 9,9~ 9,~ 2Z 4 ~1~87 ~nfll~on REVISED: 8/11/97 DRAWN BY: SLT FEB-03-98 TUE 16:03 I LI~ ~- v~J I 1%.~1 ! UNOORL. RSSET GRS GRP FaX NO, 90726?7874 P, 10/18 r, u! _ T 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER SHEET DATE: TO: FROM: RE: co: January 30, 1998 TIME: 12:18 PM Hal Martin/Chris Ruff PHONE= 90'7-263-7675 UNOCAL ~AX; 907-263-7874 Rob North PHONE: (907) 563-1597 GeoQuest ICS FAX,. (907) 562-6521 G-$ WFL Results Number of pages including cover sheet: 2 Message Hal & Chris, Attached Io this cover letter is a log presentation of the WFL results for Below is a brief discussion: With lt~e tubing to 9 5/8" annulus open during injection the well was returning 1043 bbls to the surface. Thls flow appears to be coming in small part from the L$ sliding sleeve at 9082 and mainly from the SS slldlng sleeve at 9051. No flow Is seen coming up past the packer at 9119 feel,. With the tubing to 9 5/8" annulus closed no up-flow was seen tn the well, Instead down-flow begins between 2400 and 2.500 feet Indicating at least one of the tubing strings is leaking in this interval, Increases in the down-flow rate between 2400 and 2650 Indicate the possibility of multiple leaks, This flow continues down the tubing x 9 5/8" annulus to around 4000 ft wIlere changes in velocity Indicate it possibly exits into the 9 5/§" x 13 3/8" annulus and continues down. Between 6500 and 7000 feet the down-flow stops indicating lhe flow has exited into the formation, I hope to have the G-40 and G-36DPN interpretations out shortly. Regards, Rob,.. FEB-03-98 TUE 16'03 ~' ~,D- ~_-~0 I IUI'i ! {3, U~3 UNOOAL ASSET GAS GRP FAX NO, 90726?8?4 P, 11/18 t¥ lumberger kfl~ NU, ]~UI~ ':JO~l P. [}2 ,. UNOCAL, TBU G-5, TRADING BAY UNIT, WFL, 21-J~,n-98, {98011) Up Afoul. Ol;en Up A.~. C~e~ 0~ fu~t ~ 0.0 ~.0 o,0 1~.~ ~,~ Wel 6k*~ ,, .... I ......... ~o~ '~ ,, ~{~. ';., L~'.. ? ~ ~ ~, , . ];,~:'? ,~ , : , ,,~ ~, ',~: ~ '1: ',, ~ '1, I ~ , ~)~" : ,r ,',~, ~ ' , ~., ' , I , , ;~ I ~_ rl~!'~ll'~,,' ~ .-~ . ~ ...... ] .... FI..',~ :," ,, ~ ~ 8000 : 3 ',",'? "',' I : ' L ~,, J.; ~_ -., FEB-03-98 TUE 16:04 UNOOAL UNOCAL ) aSSET GaS GRP FAX NO, 907~g'~7874 RKB to TBG Hngr = 48.6' Tree connection: Dual 3" $,000# 26" 20" 9-~/8" 9-518" 9-5/8" Tubing; l,,~ $~ J-liT' WT CASING AND TUBING DET . GR.,kDg CONN ID TOP I" w&ll 24,0 Surf. 94 Bun 19.124 Surf. 61 & 68 H40 Burl 12 415 Surf. 47 N.80 BuR 8.681 Surf 47 P- 110 Burl 8.6g I 7016 47 3-95 Butt 8.651 10,087' 9 2 N.80 Run 2.992 O' 9.2 N.80 Butt 2.992 O' P. 12/18 Trading Bay Unit Well # G-22 Completed 516190 T~rO BTM 360' 6~' 5548' 7016' 10,087' 11,335' 10,$83' 10,037' 6231' 8915' 9984' 9330' Obstruction in ] tbg @ 1o,095 G-1 G-2 G-3 G-4 Fill @ 1o,48ov JEWELRY DETAIL ID 46 60' A 9951 2,75 B 9994' 290 C 10.030' 2.635 D 10,036.67' 2,99 b[rn 10,037,35' 1 9960' 2.73 2 9994' 2.90 3 10,03 I' 2. 4 10,478' 2.75 5 10,Si0' 2.99 6 DP ~ 10,~7' 4.~ 7 DP~ ~0,512' 4.00 9 ~0,592' 2.95 btm I0.583' 10 DP~ 10,~' 4.0 11 DP ~ 10,~73' 2,~9 12 DP ~ ~ 0,980' 2 13 DP ~ 10,ggt.~Y Z99 b~ 10,9~2.30 Cameron DCB Dual 3.1t2' Tubing hanger. SHORT 8TRilq'O _ lull II 3-1/2" Otis "~A" $lidLt~ 81ewe t 9-51S" ~ia "~F' ~i P~k~, SS act 3-1~" ~is '~' Nipple, 2.75 g~EO LONG STRIIh'C 3-1/2" Otis "XA" ShdJx~ Sleeve -- 9-5/8" Otis "l~lD" Dual Packer 3-1/2" aria "XA" Sliding Sleeve 3-112" Otis "XA" Rlidin8 Sleeve Otb Straight Slot Locater w/g.96' ofscals & mule shoe Otia "BWH" Perm Pla' (10,500' DII.) Otis Seal Bore E~. 3-1/2" Otis "X" Nipple WLEG Otla "nvar' P~'m P~r (I 0.951' DR,) Crossover 3-1/2" Otis "XN" NIpple, 2,75 wi PX~ pluI WLEO RT to MSL ELEV TD ~' 11,336' ETD" MAX HOLE ANGLE = 34,$I ~ 4200' G-22 dwgdoc -= 8-5 _-= ~-6 0 t t,2S4' SLICKLINE TAGS SS Tagged fill w/2.343" GR 12/9/97 @ 10,480' LS Tagged Obstruction in tbg w/2.125"L~ 12/10/97 ~ 10,055' Tagged Obstruction in tbg w/2.25" Swedge 12/10/97 @ 10,490' WIRELINE WORK WFL ran on 12/18/97 indicated a :1:500 BPD csg leak between 4750' & 4800' originating from a plo' leak. STIMULATIONS 3 stage diverter acid job: 138 bbla of7-1/2% HCL, 200 bbls of 6 1/2% X 1-I/2% mud 11/21/89 G.Zon~ acid ......... ['"'~:~:::]:::...::~::~ ::::::::::::::::::::::::: PERFORATION DATA ..................................... '/ ............................ r'~ ................. i .......... '-" ............... v ...................................................... : .... ~m j __NUt i~ !LastOpr. IP~esentCondltlon I , 13154 ............... , ........... · ~ :::::]:~:.~ lo. ~)21~ 40 · 4 1t' t .................. .---. ~-==.----1 .... i ..................................... 11430 i g7 ii 1H}/~9 j~nfl '~{i~'fi ...................... r ....................................................................... ~ .................. "r ~ ........ ................ ~,~ ! ..z. ...... ! ~2~ crns~c,/~o'~ii'~;~ ........... :. v,~ , ............. "T' .......... 11734 i 91 20,8&4 1/~/89 ~fll~ecl on ' ~ ...... '~j~ ...... r"'. ........ ........ i'" '~='::~: i : ...~....nf/Iniect on '. ~ .,o~' ................. t ............................... --4-~-' .......... ..... I ....... :::::::::::::::::::::::::::::::: ...... ~ .... -7~-"i'~;'aa .......................... .... ~ ......... ~.. .... ~ ......... .~.~' REVISED 2/3/98 DRAWN BY: SLT FEB-O~7,,98' ~T~E~ !,~S 0~ ,o · UNT,~L ASSET ~G,~$ GRP P, 13/18 GEOQUEST 500 W. International Airport Rd, Anchorage, Alaska 99518 FAX COVER SHEET OATE.. January 14, 1998 TO; Hal Martin UNOCAL FROM: RE: cc; Rob North GeoQuest ICS G.22 WFL Results TIME: 6:16 AM PHONE: 907-263-7675 FAX; 907-263-7874 PHONE, (907) 563-1697 FAX: (907) 562.-6521 Number of pages including cover sheet: 3 Message Hal, Attached to this cover letter la a Icg presentation of the WFL ,results for (3,22. ·. Below is a brief discussion: ,. :., The WFL Up Flow rates were calculated for the tubing x 9 5/8" annular area, .., This flow appeam to originate from a leak In the packer at 9994~ and. continues, up until it exits the 9 5/8" casing between 4800' and 47§0'. An additional'small. · leak out of the 9 5/8" m~y be Indicated by' the drop In Up Flow rate b'etween .. 6000' and 5500% The WFL Down Flow rates were calculated for the 9 5/8" x 13 3/8" annular area from surface to the bottom of the 13 3/8" at 5548% Below Ihls point the area was assumed to be the full g 5/8" x 12.25" OH annulus, Increase or decreases in this annular area would have a corresponding effect on the calculated flow rates, The data Indlcates Down Flow starting between 1800' and 2000' and continuing down beyond the last station at 9500'. The possibility exists that the indicated Down Flow may be In the tubing x 9 5/8" annulus Irom 2000' to 4750' at whtch point it converges wilh the Up Flow and exits the 9 5/8" through the same point and continues down outside the 9 5/8', The tubing sptnner surveys both show an unexplained drop In Injection rate below -1000' which may best be explained by a ID reduction above this point (scale?), The Long String survey shows an ~dditional sllght drop just below 1500' which could account for Ihs start of the WFL Down Flow Indication mentioned above. It should be noted that the spinner Injection rate measured In the Short FEB-03-98 TUE 16:05 UNOORL RSSET G~S GRP t"'" ti I ~llll,~l ~1 FAX NO, 907~-~7874 P, 14/18 String (-6000 8PD) is greater than that of the Long String (-5000 BPD) which Is in opposition to the surface reported Injection rates (S,.~ = ,3570 BPD, LS = 5118 BPD). The spinner data appeam to be verified by the temperature data which shows cooler temperatures In the Short String which would be expected at a higher injection rate. Hope this gives you some more food for thought. I am Interested In any addillonal Information or ideas you may have. Give me a call when you've had a chance to look It over, Regards. Rob... FEB-OS-98 TUE 16:0~ UNO.~I. ~SSET G~S GRP F~X NO, 9072~?q74 P, 15/18 ' 'll~bgro~gr I"HA i'ig. IVI, JI~( :~uo ~, FEB-03-98 TUE 16:06 UNOO~L ' 'UNOCAL ) (' RKB to TBG Hngr = 40.8' Tree connection: Dual 3" 5,000# B-I 8-1 $ I T 6 ~ r::.:..: . ' :::, .....i. ':.,,,,:m: ......... RT to MLLW ELEV- 103' TD - II,267' ETD=' t1,143' -= WF-3 -= WF.~ -= ~ w~.? MAX HOLE ANGLE - 27.2' ~ 8900' GdO,DOC aSSET GaS GRP FaX NO, 9072~.,~'~874 P, 16/18 Trading Bay Unit Well # G-40 Completed 4/26/90 CASING AND TUBING DETAIL --" MD MD 3'VD BT1M SIZE ~vI' GRADE CONN ID TOP BTM. 16" 78 K-58 Butt 1 S.124 Surf. 1926' 13-3/8" 9-ail" 9-5/8" Tubing: LS 3-1/2" SS .1-1/2" 68 47 47 ,17 47 47 S-gO & l(-55 Butt 12.415 Surf. 812,q' K-88 Butt 8.6{ 1 Surf 47' N-60 Butt 8.681 47' 9?68' $-)5 Bult I.aI t 9768' 10,929' N-SO Butt S.681 10,929 11,146' $-98' Butt 8.681 11,146' 11,232' 9.2 N-80 9.2 N-80 Butt 2.992 0' ! 0,463' Butt 2.992 0' 9827' 9220' t0J(]0' ]0,S00' 10,606' 9290' 2,72" LIB ran on 8/6/97 shows lb8 to bc oblongcd 2,72" X 2.68" ~ $,012' NO, Deptl~ 40.80' B C D I I _ i 2 4 6 7 __ .,, SLICICLIN'E TAGS III JEWELRY DETAIL ltetp 97~o, 2.?s 9'796' 2.90 9fl13' 2.6JS 9828' 2.~ btm 9827' II I Il 9762 2.75 979~' 2.90 10.348' 1or.118, DF ~ 10~7l' 4.00 DP~ 10~83~ 4.00 b~ 10~90' lo,n2s 2.78 10,SOZ' 2.9s btm 10~82' Cameron DCB Dual 3-1/2" Tubing hanger. SltORT STR~G 3-I/2" Otb "XA" Sliding Sleeve 9-5/~" OUs "RDH" Dual Picbr, SS I~ Bill Catcher Sub III I l_l I__ LONG t s it, it' tam 3-1/2" OUt ,,XA;, S~idln{ Sleeve 9-S/8" eel *'~' ~uaJ PIC~F 3-1~" O~ "~" Slldfnl Sleeve erie ~mlShl Sl~ ~ator w/a.{' Ofli "B~' Perm P~ (10,S00' DIL) O~ Seal Bore gzL 3-1/2" Oflm "X" Nipple WLEG SS Tag "XN" w/2.72' GR 8/5/97 (~ 9813' LS Tagged obstruction w/2.72" GR & 2.72" LIB 8/6/97 ~ 5,012' Tag fill w/2.25" LIB 8/7/97 ~ 11,086' WIRELINE WORK LS · Spinner ran on 1/22~8 Indicates tbg leaks (~ 9812' & 10,125' · WFL ran on 1/23/98 indicates csg leak between 3250' & 3350'. · WFL Indicated multiple SS tbg leaks, sidg slve ($ 9760', tbg Jt between sidg sire & pkr and between 1200' to 3400'. STIMULATIONS 2 slag acid Job wi divot, er, S0 bbb ofHCL & 75 bb[s of 6-19% X l.la" mud acid 2 ateI acid Job, 40 bbb of IICL & 135 bbb of 6-1/2% X 1-1/2" mud acid 3/29/90 West Forland 3/29/90 HB.I & 2 -- ,,, PERFORATION DATA Accum. Dat~" ' Zone ,T.op Btm Ama $PF LastOpr, Present Condition .... 9,cap, 9,el}2, z' .... 4 "'3/2010o Cma Sqz .......... .... fl-t 9,692' 1,626,' ..... ~4, '9' ,3~26!90 ' ,~pefl fl injection S,934' .. 0,I35' ,,,, 2' ' 4 3/19/90 Cmt 9qz .... 10,111' 10,113' ' 2' 4 3H8/00 'em, 3qz ..... B-4 10)128' 1,0,208' 60', 6 ',' ,312B/90 0pin fl Inject:a_n_. _ 10,218' 10,22Q' 2' 4 ,3118100 Cmt Sqz ,, -- 10,455' 10,457' 2' 4 3/17110 Cmt 8qz "WF-2 10,1S25'. 10,SSS' 46' il' ' ' ~/29/90 Open fl InJectl0,' :' _ We4 lO,le0',, ", 10,770;, 00' 0 3/25/90 Open f! InJectlo~~ . wF -6 1 o,esm' 1o,66~: 56' e ~!Is/io ._ WF -6 10.,91S' -1-'~,172'-"-'-- 6T e :3/2'-~9~ Open fl Injection WF -? 10,003' _ __. 11,~0' 4T 8 3/26100 Open ri InJ!.ctlon - _ .... !1,..0'12', ..... 11,0Ui,. 2' ~ ' ', ' $/17/00 cma e.= ' ,, ~ ..r :,~, ", .... . ..... ' ' .... ' .... ~:' REVISED: 2/2/98 DRAWN BY: SLT ,:~-r~ , . . ,~;: ~,L.~ .... FEB-OS-98 TUE 16:07 J~,N-30-98 FRI 1:/:03 · UNOO~flL flSSET GfiS GRP ',,mberger F~qX NO. 90726??874 F,qX NO. 190%:309 P,l?/18 P, OI ~ GEOQUEST 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER SHEET DATE: January 30, 1998 TIME: 3:44 PM TOt Hal Martin/Chris Ruff PHONE: 90?,.-263-?6'7.5 UNOCAL FAX: 907-263 FROM; Rob North PHONE; (907) 563-1597 GeoQuest ICS FAX: (907) 562-8821 G-40 WFL Results CCi Number of pages Including cover sheet: 2 Message Hal & Chris, Attached to this cover letter is a log presentation of the WFL results for G-40 Below Is a brief discussion; ' With the tubing to 9 5/8" annulus open during Injection the well was returning 1040 bble to the surface. This flow appears to originate from the sliding sleeves at 9702 and 9760 In the long anU short strings. No flow is seen coming up past the packer al 9789 feet. With the tubing to 9 5/8" annulus closed up-flow continues at a reduced rate. This flow travels up the tubing x g 6/8" annulus urttll between 3350 and 3250 ft where It exits the 9 5/8" casing, An additional up-flow la measured across the lower packer at 10378. Down-flow In the tubing x 9 5/8" casing Is seen starting between 900 and 1200 feet. This flow continues down and appears to exit the 9 5/8" casing Ir~ the same Interve, I as the up flow mentioned above (~3300 ft). This combined flow then travels down the 9 5/8" x 13 3/8"/OH annulus to the reservoir al or below 10000 lest. Working on G-3§DPN now. Regards, Rob... FEB-03-98 TUE 16:07 ..JRN-30-g8 FRI 17=03 UNOCAL ASSET GAS GRP FAX NO, 9072~'-~7874 P. 18/18 uNOCAL, TBU G..40, TRADING BAY UNIT, V/FL, ~.3-Jan-g8, (gt~Oll) ~ o o '- -7 .... C--F --- ~.~',,'lll ,,~',,~ ~,~" ':.'1~ 1 I r', ',,,,, , , , - '-'- ~, ~__~ , ~',~' , ~l~l:i~, t · E- ' ~' , - ~ ~ ; ..... :. , a~]~E,', /1{~ , ,,,,,,~,, ' ~i~l;l~ir,' I' . I:l~ ~. . ,~,,' ;'," ~_~ '_ . ~1~'=' I~l~l , '.,~ , ,, ~. I~ , · ,.~,1" ~1~ . ~ ' 'r,'i';,"~t ~:, ~1~ , .',.~ ~ . ~~~~"~ ~ =. ,,,,,. ~ , - ;~" ~.~_ ~ .. JA~1-27-98 TUE 18:40 0,.1./27/95 15:$0 UNOOAL ASSET GAS GRP r" ~7~623906 FAX NO, 9072637874 D~ Anchorage {~' P, 02/05 ~ool GEOQUE.~T 500 W. International Airport Rd. ^nchomge, Alaska 99518 FAX COVER SHE ET OATS: January 14, 1998 TO: f-taf'M~in UNOCAL FROMI RE: CC: Rob North GeoQuest ICS Q-22 WFL Results TIME: PHONE: FAX: PHONE** FAX; 6:16 AM 90'7-263-7675 (907) 5ea-1597 (907) 562-652.1 Number of pages including cover sheet: 3 Message Hal, ,, Attachecl to this cover letter is a Icg presentation of the,WFL ,results.for G~22; ' ,, Below is a brief discussion: , ,.... ,. ,.. The WFL Up Flow rates were calculated for the tubing x, 9 5~8*.annular area., ...~ .. This flow appears to originate from a leak in the packer at 9994~, and.,oonlir~ues~, up until It exits the 9 5/8" casing between 4800' and 4760', An* additional, small. leak out of the 9 5/8' may be Indicated by the drop in Up Flow rate.between. · 6000' and 5500'. The WFL Down ,Flow rates were calculated for the 9 5/8' x 13 3/8' annular area from surface to the bottom of the 13 3/8' at 5548'. Below this point the area was assumed to be the full 9 5/8" x 12.25' OH annulus. Increase or decreases in this annular area would have a correspondlng effect on the calculated flow rates, The data Indicates Down Flow starting between 1800' and 2000' and continuing down beyond the last station at 9500'. The possibility exists that the indicated Down Flow may be in the tubing x 9 5/8" annulus from 2000' to 4750' at which point it converges with the Up Flow and exits the 9 5/8' through the same point and ~ontinues down outside the 9 5/8". The tublng spinner surveys both show an unexplained drop in injection rate below -1000' which may best be explained by a ID reduction above this point (scale?). The Long String survey shows an additional slight drop Just below 1500' which could account for the start of the WFL Down Flow Indication mentioned above. It should be noted that the spinner injection rate measured ill the Shod JA'N-27-98 TUE 18:41 ~1/27/9~ UNOOAL P, SSET GAS GRP t?' 37B6fi3906 F~X NO, 907~7874 P, 03/05 ~]oo2 String (-.6000 BPD) is greater than that of the Long Stdng (~5000 BPD) which is in opposition to the surface reported Injection rates (SS = 3570 BPD, LS = 6116 BPD). The spinner data appears to be verified by the temperature data which shows cooler temperatures in the Short String which would be expected at a higher iniection rate. Hope this gives you some more food for thought. I am interested in any additional information or ideas you may have. Give me a call when you've had a chance to rook it over. Regards, Rob,.. J[aN-27-g8 TUE 18:41 UNOCAL ~SSET G~S GRP 075623906 FAX NO, 907~?-~t7874 DS A~chora~e t P, 04/05 r~oo3 I UNODAL, TBU G-22, TI:lADING BAY UNIT, WFI_, 17-DE0-97, (9801t) t ~'tg'"-,,.1 __,._.,_~_. i-,,~,tjl::,,~J] - .~"'""""' '° '""~'"" - ~"'- / ,,,., |° ''~' , '!Iii . i . el- , ,,~ I. - - T--r--- ! / //' ;if ' "'" i i I II ~ il,] JgN-27-98 TUE 18:42 UNOOAL ASSET GAS GRPFAX NO, 9072.~7874 uNOCAL ) ( P, 05/05 Trading Bay Unit Well # G-22 Completed' 5/6/90 24.0 Smf 13.3/r 9-5Y8" Tubing: LS 3-1/2" $[, ran on 8/I/~7 o.1 G-2 G-3 G-4 C--5 iB-l' B-2 8-3 8-4 10 ~4 61&68 47 47 9.2 9.2 Buu 19.124 Su~ 629' H-40 Butt 12.415 N-SO Butt 8.681 Surf 7016' P-110 guu 1.681 7016 lo, or/' 8915' S -95 Bu~t N'.80 Btm 2.S~2 o' ~0j83' ~J30' N.80 Bu~ 2.~2 o' 10,037' 883 I' MO. JEWELRY DETAIL O~p,th rD 'Item · )51 2,7:~ ~J94' {0,~J0' 2.635 10,036,6T 10,~7.35' ~' ~' 10,03 !' Z75 10,4~' ~75 l 0,50T 4.~ 10,512' 4.ffi 10,550' 235 10,582' Z95 10,58~' 2.~ I0,~0' 10~81.55' 2.~ Cam~n ~ Dud 3-1/2" Tubing SHORT S'I'R~G ].-I/T O~'XA" $1i,:lkl :1.1/2" Otb'Xl, r' l'~pplc 2.?5 LOHG S'Z'RI~G 3-1/2," Otiz 'XA" I]lidin~ ~.$18' Otis 'I~ID' Du~ P~.kor 5-1/2' ~ '"x.~" Stldia$ 3-1/2" ~ 'X~" $1id~ Offs S~'aJShl $1otL~ ~/8.~' o£s~als & mu{e Otb Smd Bore F.~ 3-1/2" O~ "X' Nipple vvl~O o6s 'BWI. r' Pe~ ~ ( { o,961 ' DIL) 5- I/l' Oiis "Xlq" Nil~le, Z75 wt p.-v~ plull U/LEG SLICKLINE TAGS SS 2.72" GR 2.75" PX plug suspected dropped out of parted tbg LS Tagged btm w/2.$0" OR Tagged btm wY 2.72" GR STIMUI~TIONS 3 stage diverter Kid job 138 bbls of 7-1/2% HCL 200 bbLs of 6 !/2% X 1-1/2% mud acid 811/97 to 9968' 8/1/97 @ 9983' 6t9/95 ~ 10,943' 8/1/97 @ 10,956' 11/21/89 G-Zone Fill ~ 10,247' 12 ~13 iB-5 .... 'r~ of ~nk ~ i 1,2s,i RT to MSL ELEV" 90' TD,= 11,33~' ETD ~ 11,2S4' ~X HOLE ANGLE = 34.~1* ~ 4200' G-22.DOC PERFORATION DATA ~,:,~,~ ~ ..-.~" REVISED: 8/d./97 DRAWN BY: SLT O(i STATE OF ALASKA ALASKA L AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: X Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X KB 103' above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 ,¢~v,~,Service:~ Trading Bay Unit 4. Location of well at surface'=" '" -- 8. Well number 1413' FEL, 1789' FSL, Sec. 29, T9N, R13W, SM G-22 S & L At top of productive interval 9. Permit number 2098' FNL, 3370' FEL, Sec. 32, T9N, R13W, SM 75-16 At effective depth 10. APl number 2555' FNL 3759' FEL, Sec. 32, T9N, R13W, SM 50-733-20272-00 At total depth 11. Field/Pool 2582' FNL, 3784' FEL, Sec. 32, T9N, R13W, SM MaArthur River / Hemlock & G zone 12. Present well condition summary Total depth: measured 11,335 feet Plugs(measured)RECEIVED true vertical 9,990 feet Effective depth: measured 11,254 feet Junk (measured) ~t/~t~l 2 ~ 1998 true vertical 9, 912 feet Casing Length Size Cemented UeasureJ~ 0il & Gas - _ --~ue~,emca/depth Structural 360' 26" Driven 360' Anchorage 360' Conductor 629' 20" 1,125 cuft 629' 629' Surface 5,548' 13 3/8" 5,802 cuff 5,548' 4,977' Intermediate Production 11,335' 9 5/8" 1,840 cuff 11,335' 9,990' Liner Perforation depth: measured true vertical See Attachment 0RII INAL Tubing (size, grade, and measured depth) LS: 3-1/2", 9.28, N-89 (Internally Coated w/TK-99) SS: 3-1/2", 9.2~, N-89 (Internally coated w/TK-99) Packers and SSSV (type and measured depth) Otis RDH Dual Pkr I~ 9,993' ; Otis BWH Pkr ~ 10,500' ; Otis BWH Pkr ~ 10,968' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: · 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby certify t/h,~i~l:h~reg.~jp.,,~ is~~orrect to the best of my knowledge. Signed: ,,??//~,/~~~ .............. ,..~"'f~"~'~' Date: Title: .. ('~2 f' ,,/' U" ~' ' "" ~ .... FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessjJApproval No_.....~,,,;-,j").., /.,~ ,..-~ ~ Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /~,i~'~" ~t" O.~[ t~' ¢JP.~O4'CI~J, -- ~,pprovea Copy /t]oturned Original Sigm:o ~ Oavid W. ,Johnston ,, Approved by order of the Commissioner Commissioner Date Well G-22 Failed its MIT on 8/2/97 and casing leaks were detected by a recent WFL. The well will I~shut-in until it can be repaired during the '98199 Grayling Workover Program'. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-22 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-22 PERFORATIONS ZONE TOP MD BOTTOM TOP BOTTOM MD TVD TVD G 10,061 10,095 8,891 8,920 G 10,115 10,154 8,936 8,969 G 10,178 10,218 8,989 9,022 G 10,230 10,300 9,032 9,091 G 10,370 10,430 9,150 9,201 H B- 1 10,595 10,629 9,338 9,367 HB-2 10,643 10,734 9,379 9,456 HB-2 10,742 10,752 9,463 9,472 HB-3 10,762 10,815 9,480 9,526 H B-4 10,827 10,952 9,536 9,645 Page 1 JAN-14-98 klED 09:19 UNOOAL ASSET GAS GRP FAX NO, 9072637874 P, 02/02 UNO J L 909 W. 9"' Ave. Anchorage, Alaska Blair Wondzell State of Alaska Alaska Oil and Gas Conservatio~ 'Commission 77-'o Re: McArthur River Field Injectors G-22, K-4RD, K-15RD, K-22RD, K-7RD & K-11 Dear Blair: As per our phone conversation on 1/13/1998. The WFL ran on Grayling Platform G-22 showed a breach in the 9-5/8" csg between 4750' and 4800'. The WFL indicated water flowing down the 13-3/8" X 9-5/8" annulus from the breach in the 9-5/8" csg out thru the 13-3/8" shoe,.The well is curren[ly shut-in and will remain so until'it can be repaired. I will be forwarding G-22's WFL logs and summary to you when we receive them in their final version from Schlumberger. King Salmon K-4RD failed it's MIT on 2/26/97. The well was shut-in on 3/04/97. Slickline attempts on 4/5/97 failed to obt'{~'~ a MIT. We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. King Salmon K-15RD, passed it's MIT on 2/26/97. On 11/25/97 th_e c_Asgj~ressured _u.p_t_o..2~.0..0.. psi (tbg 3000 psi) indicating communication between the tbg and csg. The we-~F,~A~-~fiut-in on .... l_.~/0p_/_9..7~.We plan to run a temperature survey this month and a WFL next month to confirm weltbore integrity. 1/25/97 King Salmon K-22RD, passed it's MIT on 2/26/97. On ' the c. sg._pressured u@ t_~__o !.8~_0... psi. The well was shut-in on (tbg 3000 psi) indicating communication between the tbg and csg. - ....... -i-2~03/971' We plan to run a temperature survey this month and a WFL next month to confirm wellbore integrity. King Salmon K-7RD, passed it's MIT on 2/26/97. The well was shut-in on 12/03/97 pending facility upgrades to the water flood system's ability to handle the Iow injection rates caused by K- 4RD, K-15RD & K-22RD being shut-in. King Salmon K-11, passed it's MIT on 2/26/97. The well was shut-in on 12/03/97 pending facility upgrades to the water flood system's ability to handle the low injection rates caused by K-4RD, K- 15RD & K-22RD being shut-in, If you require anything else regarding.what we discussed, please let me know. Sincerely, . ~.. Steve Tyler Engineering Technician CC: Chris Ruff JAN 1 .'-!. t998 C!t & Gas C~ns. STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: KB 103' above MLLW feet "3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service:-X- Trading Bay Unit '4. Location of well at surface 8. Well number 1413' FEL, 1789' FSL, Sec. 29, T9N, R13W, SM G-22 S & L At top of productive interval 9. Permit number 2098' FNL, 3370' FEL, Sec. 32, TgN, R13W, SM 75-16 At effective depth 10. APl number 2555' FNL 3759' FEL, Sec. 32, T9N, R13W, SM 50-733-20272-00 At total depth 11. Field/Pool 2582' FNL, 3784' FEL, Sec. 32, TgN, R13W, SM MaArthur River/Hemlock& G zone "12. Present well condition summary Total depth: measured 11,335 feet Plugs (measured) true vertical 9,990 feet ORIGINAL Effective depth: measured 11,254 feet Junk (measured) true vertical 9,912 feet Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" D riven 360' 360' Conductor 629' 20" 1,125 cuft 629' 629' Surface 5,548' 13 3~8" 5,802 cuff 5,548' 4,977' Intermediate LinerPr°ducti°n 11,335' 9 5/8" 1,840 cuff 11,335' . ..J~ E¢~ V ~ D" ' .., , Perforation depth: measured See Attachment true vertical ~UG ~ ]997' Tubing (size, grade, and measured depth) LS: 3-1/2", 9.28, N-89 (Internally Coated w/TK-99) ~--" --~!;!~'. & ,Gas .Coils, ss: 3-1/2", 9.28, N-89 (Internally Coated w/TK-99) "~i'~4'~ ~l~.~_a~( Packers and SSSV (type and measured depth) Otis RDH Dual Pkr @ 9,993' ; Otis BWH Pkr @ 10,500' ; Otis BWH.Pkr @-i~;9-~~'"" ~>~ ....... " 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: Oct-97 16. If proposal well verbally approved: Oil: 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. Signed~ ~~~...,FoRTitle:cOMMISSION ~ ~:::~P---"~'USE ONL, - ~--.~%. "' ~-~¢.J",,,..~ .¢~ Conditions of approval: Notify Commission ,o representative may witneSSplug integrity BOP Test Location clearance IAppr°va' N°' ~'1 '-1"' / ~ ~ Mechanical I'ntegrity Test ' ' ubsequent form required 10- ~4 ' Approved by order of the Commissioner 0avid W. Johnston, [ ;.~"(~'~~er Date /~) Well G-22 Failed its MIT on 8/2/97. Unocal requests a continuation of injection while the well is being evaluated for either a workover to replace the existing completion or a WFL to insure csg integrity. .~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-22 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-22 PERFORATIONS TOP BOTTOM TOP BOTTOM ZONE MD MD TVD TVD 0,061 10,095 8,891 8,920 0,115 10,154 8,936 8,969 0,178 10,218 8,989 9,022 0,230 10,300 9,032 9,091 0,370 10,430 9,150 9,201 H B-1 10,595 10,629 9,338 9,367 H B-2 10,643 10,734 9,379 9,456 H B-2 10,742 10,752 9,463 9,472 HB-3 10,762 10,815 9,480 9,526 H B-4 10,827 10,952 9,536 9,646 Page 1 G-22 (Long and Short String Total) 3200 ......... i i i ~ m ~m ~ m~i i i i ~ 2400-.' ............................. ; ................................................................... ~ ....................................................... -- 2000 ' .5 <22) .n~ 'ih. n~ fl4 08:31:52 1997 G-22 (Long ond Short String Total) - lll~ter Inj press (psis) ~600 ........................................................... ~ ....................................................... i ............................. !. ............................................................... ' ............... 3200 ............................................. ~ ........................... "' =~" "~='"-'~'"= .................. -~ .... ~"-~'~-~ ~" ~' ....... "'L~ ........ ~"' 2800 .............................................................. ~ .............................. _ - A i 0 A 4 0 ~ ..... 89- t -90 ;. 91 i A d 0 A J 0 92 ~ 93 ~ 94 A d 0 ~a A d 0 A ,I 0 A d 0 A d 0 · ! 9~ i o~----F---g7 ... f ti'Nd ~N~_"~4 d%4 dM'T z <iD APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extenmon __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator Union Oil Co_ of Cal~f_ (ITNOCAT.5 3. Address PCB 190247, Anch, AY,., 99519-0247 4. Location of well at surface 1413' FEL, 1789' FSL, Sec. 29, T9N, At top of productive interval 8881 ' '[A/D 2098' i~L, 3370' FEL, Sec. 32, T9N, At effective depth 2555' FNL, 3759' FEL, Sec. 32, T9N, At total depth 2582' FNL, 3784' FEL, Sec. 32, T9N, 5. Type of W'ell: Development Exploratory Stratigraphic Service R13W, SM R13W, SM R13W, SM R13W, SM &Datum elevation(DForKB) KB 103' above MLLW Z UnitorPropertyname Trading Bay Unit 8. Wellnumber G-22S&L 9. Permit number 75-16 10. APl number 50-- 733-20272 11. Field/Pool McArthur River/Hemlock feet &G 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 360 Conductor 629 Surface 5,548 Intermediate Production 11,335 Liner Perforation depth: measured 11,335 9,990 11,254 9,912 Size 26" 20" 13 3/8" feet Plugs (measured) feet /'~'~ feet Junk (measured) feet Cemented Measureddepth ~ueverticaldepth Driven 360' 360' 1,125 cu. ft. 629' 629' 5,802 cu. ft. 5,548' 4,977' 9 5/8" 1,840 cu. ft. See Attached f~AR 1 9 1991 true vertical Tubing (size, grade, and measured depth) '1'.. S' 3 1/2", 9.2#, S.S' 3 1/2", 9.2#, Packers and SSSV (type and measured depth) Otis RDH Dual Pkr. Otis BWH 13. Attachments Description summary of proposal __ Abska OiI& Gas 6ons. 6ommissio~ Anchorage N-80 (Internal Coated w/TK-99) N-80 (Internal Coated w/TK-99) @ 9,993', Otis BWH Pkr. @ 10,500', Pkr. fa 10.~' Detailed operations program .-X. BOP sketch __ Upon14' EstimatedApprovaldate for commencing operation ! 16. If proposal was verbally approved I Oil __ Name of approver Date approved Service 15. Status of well classification as: Gas __ Water 17. I hereby certi_fy that the foregoing is true and correct to the best of my knowledge. Signed (~c~--.-k ~. (~'-"-~'--- Title (~e_,%.."~,r~..,,~, & r~_~- FOR COMMISSI(~N USE OhLY Conditions of apl~r-oval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Suspended __ Injection Date IAppr°val N°'?'/...5~,,~' Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Form 10-403 Rev 06/15/88 Commissioner SUBMIT IN TRIPLICATE ATTACHMENT TO APPLICATION FOR SUNDRY ARROVAL, WELL G-22 PERFORATIONS TOP BOTTOM TOP BOTTOM ZONE MD .MD TV_._~D TVD G 10,061 10,095 8,891 8,920 G 10,115 10,154 8,936 8,969 G 10,178 10,218 8,989 9,022 G 10,230 10,300 9,032 9,091 G 10,370 10,430 9,150 9,201 HB-1 10,595 10,629 9,338 9,367 HB-2 10,643 10,734 9,379 9,456 HB-2 10,742 10,752 9,463 9,472 HB-3 10,762 10,815 9,480 9,526 HB-4 10,827 10,952 9,536 9,645 RECEIVED Alaska 0ii & 6as Cons. Anchorage March 14, 1991 RE: Grayling, Well G-22 Short and Long Injection Profile 1. RU electric line unit. 2. Pressure test lubricator to 2500 psi for five minutes. 3. Run in the long string with the WFL tool made up in the "DOWN FLOW MODE". The long string injection will be shut in while the short string injection is left on. 4. Log a base gamma ray Icg from total depth to 9200' on two inch film. 5. Go back down the well to below the tubing tail and turn on the long string injection. Wait two hours for the injection rate to stabilize. . Take Water Flow measurements at the following MINITRON depths: 10,590, 10,615, 10,630, 10,700, 10,730, 10,750, 10,775, 10,800, 10,815, 10,850, 10,875, 10,900, 10,925, and 10,950. The neutron generator (MINITRON) should be turned on for a burst time of "2" seconds and "6" cycles should be recorded at each depth. When the water velocity slows down to less than 15 FPM, change the neutron burst to "10" seconds and record "5" cycles of recorded data. 7. When finished with step 6, turn off the long string injection and Icg an after gamma ray pass from T.D. to 10,550 on two inch film. RE( EIVE'L) 8. This completes the long string injection survey. 9. Now the "G" sands injection profile will be done with the WFL tool still in the long string of tubing. The short string water injection must be on. Alaska Oil & Gas Cons. Anchorage: 10. The long string water injection must be off. 11. The water velocity in the short string is very slow, so use a burst time of "10" seconds and "5" cycles of recorded data. 12. Take Water Flow measurements at the following MINITRON depths: 10,045; 10,075; 10,100; 10,125; 10,150; 10,165; 10,190; 10,220; 10,250; 10,300; 10,400; 10,450 and 10,550. 13. When finished with step 12, Icg an after gamma ray pass from 10,500 to 101030. 14. Switch the TDT-P tool from the Water Flow mode to the Gravel Pack mode and record a "FILL LOG" from 10,050 to 10,550 at 900 FPH. This Icg will indicate if there is any fill above the packer set at 10,500. 15. Come out of the hole and rig down. Memorandum UNOCAL TO: BLAIR WONDZELL FROM' KIRK KILOH Transmitting one (1) Blueline and Sepia copy of Cement Bond/Evaluation Logs of each of the following wells: G-22 6-22-75/ ryo~-T / ... G-40 F¢ 'F 3-16-90, 3-24-90 '5 -- t ~-~ o /~ 7 K- 15RD ~:~%u9-6-79;' 10-8-89 D-45 5-28-89 v...~¢T' 5-2.,~,.-~ ~ 7' ~ RECEIVED DEC 1 8 1990 Alaska 011 & Gas Cons. Commission An~orage FORM 1-0C03 (REV, 8-85) PRINTED IN U.S.A. STATE OF ALASKA ( 0 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing z_ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: · L Development __ Union Oil Company of California (UNO~AL) Exploratory__ 3. Address ! Stratigraphic __ P.O. Box 190247, Anch, Ak., 99519-02~7 Service--x 4. Leg #3, Conductor #1 Location of ,well at surface Jl~ 1413 WEL & 1789" NSL At top of productive interval 3370' WEL & 2098' SNL At effective dep. th 25 55' SNL F/NE Corner, Att0t~l~t~ SNL F/NE Corner, F/ SE Corner, Sec. 29, T9N, R13W, S. Top "G" Zone-10060' MD, F/NE Corner, Sec. 32, T9N, R13W, S.~ ETD = 11,254' MD, 3759' WEL & Sec. 32, T9N, R13W, S.M. TD = 11,335' MD, 3784' WEL & Sec. 32, T9N, R13W, S.M. Other __ 6. Datum elevation (DF or KS) 103' RKB above MLI~t 7. Unit or Property name Trading Bay Unit 8. Well number M. G-22 9. Permit _num. I~e,r/.,appr.,oy~l number 10. APl number733_20272 50-- 11. Field/~rthur River Field 12. Present well condition summary Total depth: measured true vertical Effec!ive depth: measured true vertical 11335 ' 9990' feet Plugs(measured) feet 11254' feet Junk(measured) 9912 ' feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 360' 629' 5548' 11335' true vertical Tubing (size, grade, and measured depth) Size Cemented Measureddepth ~ueverticaldepth 26" Driven 360' 360' 20" 1125 cu ft 629' 629' 13-3/8" 5802 cu ft 5548' 4977' 9-5/8" 1840 cu ft 11335' 9990' Uppermost: 10061' MD Lowermost: 11145' MD Uppermost: 8882' TVD Lowermost: 9814' TVD 3-1/2", 9.3#, N-80 MMS Threads L.S. @ 10584' S.S. @ 10033' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Otis "RDH" Dual Packer @ 9990' Otis "BWH" permanent pac~.~~; 14. Intervals treated (measu red) N/A Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ MAY ! 8 1990 OIt& Sas ,Cram.. Commie!on Representative Daily Average Production or Injection Data ......... ~ OiI-Bbl Gas-Md Wat~r-Bbl Casing Pressure Tubing Pressure Shut-in SS (Water injection) 1693 BWPD 1500 psi 3250 psi LS (Water injection) 2059 BWPD 1500 psi 3250 psi 16. Status of well classification as: Oil __ Gas __ Suspended __ 17. I hereby cert~that the foregoing is t/.v,e and c~orrect to the ~/~"~'~ Signed ~ Ga~ S. Bush Service Water Injection best of my knowledge. Title Regional Drilling Manager Date ~'/(:5/9 ~) Form 10-404 Rev 06/15/88 SUBMITIN DUPLICATE ~AL DRILLING RECORD ALASKA REGION PAGE NO. LEASE..TRADING BAY UNIT WELL NO. FIELD McARTHUR RIVER FIELD DATE DETAILS OF OPERATION, DESCRIPTIONS, AND RESULTS 04/28/90 COMMSNCED OpeRATIONS ON G-~ AT ~200 HRS ON 4/28/90. Install BOPE. Install flowline and degasser return line. Test BOPE. Pull BPV's and install landing joints. Long string had built to 450 psi. Rig up on short string taking returns from the annulus to production pipe line. Monitor annulus and short string-static. Rig to pull dual packer loose. 04/29/90 04/30/90 Pull dual packer loose with 15K overpull. Check for flow-static. Pulled long string seal assembly out of permanent packer. Well started flowing. Displaced long string and annulus with 68 pcf brine. Reversed kill weight brine into short string. Well static. Pull hanger to rig floor and break out landing joints. Well flowing slightly. Circulate well on choke and increase weight to 69 pcf. Well static. Pull out of hole with dual tubing string. Packer dragging in places. Finish pulling out with dual tubing string. Found short string safety shearout sub parted. Laid down dual packer, sleeves, shear out sub, and long string seals. Sent equipment to beach to be redressed. Changed lower pipe rams to 3-1/2" singles. Test BOPE to Unocal specificiations. Held safety meeting with crews. Made up test stabin seal assembly. Ran in on long string and tagged permanent packer at 10,515' TM. Stabbed into packer and pressured tubing to 500 psi with no returns on annulus. Pulled tubing to 10,470' TM and hung string off on slips. Installed tubing safety valve. Closed and locked lower pipe rams. Prep to skid Rig #55 to Leg #4. Re~ease.d rig at 2400 hours. 05/03/90 COPIMENCE OPERATIONS AT 0000 HOURS. Perform general maintenance while waiting on dual packer. Pumped dry job down kill string hanging at 10470'. Pulled and stood back kill string tubing. Changed out 7 couplings on trip out. Rigged up and started running dual 3-1/2" completion. o5/o4/9o Completed running dual 3-1/2" tubing string. Spaced out hangers. Picked hangers two feet off seat. Test long string seals by injecting 10 BBL FIW at 1500 psi with no returns to surface. Changed 9-5/8" x dual 3-1/2" annulus over to packer fluid. Attempted to test long string to 3000 psi, but bull nose blew out at 2700 psi. Set dual packer and tested short string to 3000 psi. Landed hangers in DCB spool. Pulled landing joints and installed BPV's. Ran in tiedown pins and packed hangers. Nippled down BOPE. Installed tree. Performed mechanical integrity test. Release rig at 2400 hours. 20" [ @ 629'/] @ 5548' Z JUNK @ 10247' 9-5/8" / @ 11335' A D ~ 11 12 JUNK 13 E C 3-1/2', ~.2~, ~-BO, IHPROV£D BDTTR~S$ WXTM TKC ~ SP~CIX. L CLF. AJ~CE CODPL/HGS AND T~-99 /~E-RKAL COAT/KG 2J~OLAT2D~ PACKER ?) cr:zs R:~:]C'rRY GO/D: ~ITB ~ AT 13) C~lS BWB P~P~L~-DRIL~ PACKER AT PF. RPORATIO~ RECORD 6/22/?~ 11082'-llOE2' 6/23/75 10708'-~0710' SgU::ZCD 6/24/?5 ~0590'-10592' S00:CZCD ?I03/75 11115'-11145' Ub-~ ZSOLkT~D ~/D4/75 ~0984'-11~22~ MB-~ ZSO~Tr.D 7/0?/?5 ~091~'-1 0936' H~-4 PRODU~/~ 9/11/75 10911'-1 0936' H~-4 PRODU~ID~ 10886'-10911' ~-& PRODD~IO~ V/~4/75 10685'-10700~ Hb-2 PRODD~I~ TI15/?~ 2D6?D'-lD?OO~ g~-2 PRODD~2DN ?/16/75 10B32 ' -~ 0862 ' R~-4 PRODU~/~ ~/17/75 1096B'-~OVB8' H~-3 PRDDU~ ON ?/1 B/75 10602 ' -10622' Hb-1 PRODD~ 12/1&/75 IOE32'-lOB62' RD-4 10?6B'-10~88~ BB-~ PRODD~ON 41021?6 10670'-1 0~00' H~-2 ~ODU~2~ 10602'-10622' H~-i PRODD~I~ 6/29/76 10832'-10862' ~-4 PRODD~I~ 10886q'1090~~ ~-4 6/30/?8 lO~68'-lOVBe~ H~'3 PRODD~IO~ 1D6~O'-~0~DD' R~-~ PRODD~ON ?/01/78 10602'-10622' BB-I PRDDD~ION 11/16/89 105~5'-10629~ B~-i Z~J~ZON ~0643'-10734~ B~-2 10~42'-10?52' H~-2 10~E2'-1081~* H~-3 10B2?'-10952' H~-4 11/19/BS 10061'-10095~ G ~ON~ 103?0'-10430' G ~N~ WELL THUS G-22 COMPLETION ( 05-06-90 ) UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN' DAC SCALE. NONE DATE' 5-9-90 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV L I Gl NA 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown m Re-enter suspended well __ Plugging m Time extension __ Stimulate __ Pull tubing _X. Variance __ Perforate __ Other 2. Name of Qperat_or Union ual ~ompany of California (UNOCAL 3'¢.dSr.eS~ox 190247, Anch, Ak., 99519-0247 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 1413' FEL, 1789' FSL, Sec. 29, T9N, R13W, S.M. 6. Datum elevation (DF or KB) 103' RKB above MLLW 7. Unit o.r .Prope_~y na .m.e. ~ · &'raa~ng ~ay un~ 8. Well number G-22 At top of productive interval 2098 FNL, 3370' FEL, Sec. 32, T9N, R13W, S.M. At effective depth 2555' FNL, 3759' FEL, Sec. 32, T9N, R13W, S.M. At total depth 2582' FNL, 3784' FEL, Sec. 32, T9N, R13W, S.M. at 8881' TVD at 9908' TVD at 9912' TVD feet 12. Present well condition summary Total depth: meas'ured true vertical 11335' feet 9990' feet Plugs (measured) Effective depth: measured true vertical 11254' feet 9912' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth 360' 629' 5548' 11335' Tubing (size, grade, and measured depth) 9. Permitnumber 75-16 10. APInumber 50-- 733-20272 11. Field/Pool ' McArthur River Field Size Cemented Measured depth True vertical depth 26" Driven 360 ' 360 ' 20" 1125 cu ft 629' 629' 13-3/8" 5802 cu ft 5548' 4977' measured Uppermost: Lowermost: truevertical Uppermost: Lowermost: LS: SS: 1840 cu ft 1oo61, APR 2 6 11145' 8 8 8 2' ~J~a$~a~ 8il & Gas ~ns. Commission 9814' 3-1/2", 9.2~, ~-80 (i~e=~al coa~ed ~/T~-99) 3-1/2", 9.2~, ~-80 (i~e=~al coa~ed ~/T~-99) Packers and SSSV (type and measured depth) 9-5/8" 13. Attachments Description summary of proposal .x_ 10500' BOP sketch Otis "RDH" Dual Packer @ 9990' Otis "BWH" permanent packer ~ Detailedoperationsprogram__ 15. Status of well classification as: Suspended __ Water Injection Date IApprova' No. 14. Estimated date for commencing operation April 27, 1990 16. If proposal was verbally approved Oil Name of approver Date a. pprove( Service 17. I hereby cert~that the foregoing is true and correct to the best of my knowledge. SignedI~k,~~ ~ ~~~,. Title Re~;; ,'r'i.-pT~]14'~,~ '(~. ~ ' FOR COMMISSION USE ONLY Conditions of appr'Cval: I~fY Commission so representative may witness Plug integrity BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10-, .... ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Form 10-403 Rev 06/15~88 SUBMIT IN TRIPLICATE WELL PROCEDURE TBUS G-22 REPAIR PARTED SAFETY JOINT IN SHORT STRING 1. MOVE RIG #54 OVER TBUS G-22, ~LEG #3, CONDUCTOR #1. 2. KILL WELL. 3. INSTALL BPV, REMOVE TREE, INSTALL AND TEST BOPE. 4. PULL AND STAND BACK DUAL 3-1/2" INJECTION STRING. 5. REMOVE PARTED SAFETY JOINT IN SHORT STRING AT 9984'. 6. REDRESS DUAL PACKER. 7. RERUN DUAL 3-1/2" INJECTION STRING AS PER PREVIOUS DESIGN. 8. PRESSURE TEST PACKER AND TUBING. 9. REMOVE BOPE, INSTALL AND TEST INJECTION TREE. 10. PERFORM MECHANICAL INTEGRITY TEST AS PER AOGCC REGULATIONS. 11. PLACE WELL ON INJECTION. NOTE: ANTICIPATED SBHP IS 4025 PSI AT 9450' TVD. WORKOVER FLUID IS FILTERED INLET WATER WITH NACL AS REQUIRED FOR WELL CONTROL. A~aska 0il & Gas Cons, Commission Arichorag~ ., A 20" @ 629'/1 @ 5548' Z JUNK @ 'x D 11335' E CASING AND ABAI~DON.~IENT DETAIL A) NELLY BU-~HIKG AT 0.00' B) C~-MERON DUAL SPLIT TUBING HANGER AT 20', 94~, H-40 CASING AT 629' D) 13-3/8', 61~ & 68*, E-55 CASING AT 9-5/8', 47{. ~-80, S-95, & P-ll0 CASING AT 1133~' TUBING DETAIL 3-1/2', 9.25, N-80, IMPROVED BUTTRESS W!TR TKO HMS SPECIAL CLEARANCE COUPLINGS AND T~-98 INTERNAL COATING LONG STRING 1) 3-1/2' OTIS 'IA' SLIDING SLEEVE AT 9957.58' 3-1/2' OTIS 'IA' SLIDING SLEEVE AT 10028.44' 3-1/2' OTIS 'XA' SLIDING SL£EVE AT 10~76.51' 3-1/2' OTIS '~' NIPPLE AT 10551.07' 5) OTIS REENTRY GUIDE WITH BOTTO~ AT 10583.61' 11) OTIS RDH DUAL HYDRAULIC PACKER TOP OF PKR (LONG STRING) AT 8990.41' BOTTOM OF PKR (LONG STRING) AT 9999.0~' 12) OTIS HWH PER~IA-DRILL PACKER AT 10500' STAB-THRU SEAL ASSY FROM 10510..97' TO 10521.20' SHORT STRING 8) 3-1/2' OTIS 'XA' SLIDING SLEEVE AT 9952.21' 9) 3-1/~' OTIS 'IN' NIPPLE AT 10026.62' 10) 3-1/2' OTIS COLLET CATCHER SUB AT 10033,29' 11) OTIS RDH DUAL HYDRAULIC PACKER 40K SAFET~ SHEAR SUB AT 9984.21t TOP OF PKR (SHORT STRING) AT 9990.44' BOT~O~ OF PKR (LONG STRING) AT 9997.16' ISOLATION PA~KER 6) 3-1/~' OTIS 'X~' NIPPLE AT 10~79.94'DP~ 7) OTI~ REENTRY GUIDE WITH BOTTO~ AT 10982.30'DP~ 13) OTIS. BW~ PER'A-DRILL PACKER AT ~0966'DP~ PERFORATION RECORD 6/22/75 llUBI'-ll0BI' SQUEEZED 6/23/75 1070B'-lO?lO' SODEEZED 6/24/75 10590'-10592' SQUEEZED 7/U3/75 11115~.11145, HS-6 ISOLATED 7/04/75 10984~-110~, HB-5 ISOLATED 7/07/75 10911'-10938' H~-4 PRODUCTION 7/11/75 10911'-10836' R~-~ PRODUCTION 10866'-10911' HB-4 PRODUCTION 7/14/75 10685'-10700' HB-2 PRODUCTION 7115/75 10670'-10700' HB-2 PRODUCTION ~/16/75 10832'-10862' H9-4 PRODDCTION 7/17/75 10766~-10788, HB-3 PRODUCTION 71181?5 10602'-10622' HB-1 PRODUCT/ON 12/18/75 10832'-10662' HS-4 PRODUCTION 10768'-10788' HB-3 PRODUCTION 4/02/76 10670'-10700' HB-2 PRODUCTION 10602'-10622' HB-1 PRODUCTION 6/29/78 10832'-10862' HB-& PRODUCTION 10886'-10904' H~-4 PRODUCTION 6/30/78 10768'-10768' HP-3 PRODUCTION 10670'-10700' HB-2 PRODUCTION 7/01/78 1~60~'-10622' HB-1 PRODUCTION 11/16/89 10595'-10629' RS-1 INJECTION 10643'-10734' HB-2 INJECTION 10742'-10752' HH-2 ~NJECTION 10762'-10815' HB-3 INJECTION 10827'-10952' HB-4 INJECTION 11/19/89 10061'-10095' G ZONE INJECTION 1Dl15~'10154~ G ZONE INJeCTION 10176''10218~ G ZONE INJECTION ~0230''1~300~ G ZONE INJECTION 10370''10430~ G ZON~ INJECTION WELL TBUS G-22 COMPLETION ( 11-26-89 ) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE: NONE DATE: 3-8-90 BELL NIPPLE · i FLOWLINE 12" 3000 PS! ANNULAR 5" KILL LINE WITH TWO 3" 5M VALVES I ;I; KILL LINE FROM MUD PMP & CEMENT UNIT I PiPE RAMS BLIND RAMS i 13-5/8" 3M FLANGE ADAPTER 3M x 5M 15-5/8" 5M FLANGE DOUBLE GATE 5M I 15-5/8" 5M FLANGE 4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE (I) d; ' I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) I PIPE RAMS 13-5/8" 5M FLANGE SINGLE GATE 5M 15-5/8" 5M FLANGE ,! 1,m 1 RISER I I I 10" 5M x 15-5/8" 5M ADAPTER CAMERON 5M SPOOL 13-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) APR 2 6 :lgpn Naska Oil,& (~as Cons, Commission All ~.hnrn~rr~ DRAWN' DAC APP'D' GSB SC~E: NONE DATE: 11/26/89 Unocal North Am~ Oil & Gas Division \ Unoc.~l Corporation P.O. ~o× 190247 Anchorage. Alaska 99519-02~7 Teieonor~e ~90~ 276-7800 AlabS~a Reg,on April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: .-. I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Regional Drilling Manager GSB/lew GRAYLING DISTANCE &.DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL FSL FEL LEG ~3: LAT = 60o50' 22.569" LONG =151°36' 46.519" 2,502,352.30 212,272.70 18O4 1409 1 2 3 4 5 6 7 8 9 lO ll 12 2,502,346.65 212,269.32 2,502,350.14 212,266.48 2,502,354.64 212,266.55 2,502,358.05 212,269.49 2,502,358.77 212,273.94' 2,502,356.46 212,277.80 2,502,352.20 ' 212,279.28 2,502,347.99 21 2,277.68 2,502,345.80 212,273.75 2,502,350.83 212,270.89 2,502,354.60 212,272.33 2,502,351.47 212,274.88 G-22 1789 1413 G-21 1802 1415 G-26 1806 1415 G-25 1810 1412 G-24 1810 1408 G-20 1808 1404 1804 1402 G- 36 1800 1'4 04 G-34 & RD 1798 1408 G-23 & RD 1803 1411 G-33 1806 1409 G-27 & 28 1803 1407 LEG #4: LAT = 60o50' 22.832" LONG =151°36' 48. 042" 2,502,380.80 212,197.90 1831 1486 13 2,502,374.34 212,196.66 G-14A 1825 14 2,502,376.65 212,192.79 G-1 9 1827 15 2,502,380.90 212,191.32 G-13 1831 16 2,502,385.11 212,192.92 G-15 i835 17 2,502,387.30 212,196.85 G-5 1838 18 2,502,386.45 212,201.28 1837 19 2,502,382.96 212,204.12 G-3 1833 20 2,502,378.46 212,204.05 G-2 1829 21 2,502,375.05 212,201.11 G-11 1 825 22 2,502,378.50 212,198.27 G-lO 1829 23 2,502,381.63 212,195.72 G-17 & RD 1832 24 2,502,382.27 212,199.71 G-7 1832 LEG #l: 2,502 .LAT = 60o50' 23.575" LONG =151°36' 4Z. 505" ' ,455.60 212,226.40 (Reserved for Compressors) 1906 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 LEG #2' LAT = 60050' 23.313" LONG =151°36' 45. 982" 2,502,427. l0 212,301.20 1880 1383 37 38 39 40 41 42 43 44 45 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 2.502,427.00 2,502,422.80 212,297.82 212,294.98 212,295.05 212,297.99 212,302.44 212,306.31 21~ 307.78 212,306.18 2-,-502,420.60 ...........2'12,302.25" 2,502,425.63 212,299.39 2,502,429.40 212,300.83 2,502,426.27 212,303.38 G-12, RD & 2 1874 G-31 1878 G-4 1882 G-1 1886 G-9 1886- G-18 1884 G-14 1880 G-30 GZ8 & RD ........ 1874 G-6 1879 G-32 1882 G-16 1879 1386 1389 1389 1386 1382 1378 1376 1876 .......1378 ...... 1382 1385 1 383 1381 STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AL 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing Stimulate __ Plugging __ Perforate __ Repair well __ Other 2. Name of Operator I 5. Type of Well: I Development __ TTnien Oil Cemp=_ny of C=_!iforni=_ "3~'n~T ~ Exploratory__ 3. Address ' - ...... ' I Stratigraphic __ P.O. Box 190247, Anch, AA,, 99519-0247I Service.~_~ 6. Datum elevation (DF or KB) I ('3"4 · I:)TFI:~ -,~'~'~r"' MT.T.T~ 7.-0r~it or-P-r~-pe~ ~Jr~e ...... Trading Bay Unit 4. Location of well at sudace 1413' FEL, 1789' FSL, Sec. 29, T9N, R13W, S.M. At top of productive interval 2098 FNL, 3370' FEL, Sec. 32, T9N, R13W, S.M. at 8881' TVD At effective depth 2555' FNL, 3759' FEL, Sec. 32, T9N, R13W, S.M. at 9908' TVD At total depth 2582' FNL, 3784' FEL, Sec. 32, T9N, R13W, S.M. at 9912' TVD 8. Well number G-22 9. Permit number/approval number 75-16 / 9-67] 10. APl number 50--733-20272 11. Field/Pool McArthur River Field feet 12. Present well condition summary Total depth: measured true vertical 11335' feet Plugs(measured) 9990 ' feet Effec!ive depth: measured 11254 ' true vertical 9912 · feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth Size Cemented Measureddepth 360' 26" Driven 360' 629' 20" 1125 cu ft 629' 5548' 13-3/8" 5802 cuft 5548' 11335' 9-5/8" 1840 cuft 11335' Tubing (size, grade, and measured depth) measured Uppermost: 10061' Lowermost: 11145' truevertical Uppermost: 8882' Lowermost: 9814' LS: 3-1/2", SS: 3-1/2", 9.2#, N-80 (internal 9.2#, N-80 (internal ~ueveAicaldepth 360' 629· 4977· 9990' coated w/TK-99) coated w/TK-99) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. Otis "RDH" Ot is "BWH" Intervalstreated (measured) See attached Treatment description including volumes used and final pressure Dual Packer @ 9990' permanent packer ~ 10500' "stimulation" summary. ~.', i,~. r,,'r::, ~ c, ~ !:~;':.! ~.'.'? Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Shut-in SS: LS: Shut-in Injecting 6087 BWPD 0 psi 2700 psi 15. Attachments Copies of Logs and Surveys run._.... Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas ~ Suspended Servic~ater Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed,~~//~2..~.,.~. ,~"~g.-¥.J (~T~itle Environmental Engineer Form 10-4~)4 ~'ev 06/15/88 Date 3 / '16/90 SUBMIT IN DUPLICATE ACID STIMULATION SUMMARY TBUS G-22 WORKOVER NOVEMBER 21, 1989 ACID STIMULATED "G" ZONE BY PUMPING THREE STAGES AS FOLLOWS: 1st stage: 2nd stage: 3rd stage: 52.3 BBL, 7-1/2% HCL 66.6 BBL, 6-1/2% HCL/ 1-1/2% MF 15 BBL, 7-1/2 % HCL 133.3 BBL, FIW w/surfactant 47.6 BBL, FIW w/diverter 23.8 BBL, 7 1/2% HCL 66.6 BBL, 6 1/2% HCL/ 1-1/2% HF 15 BBL, 7 1/2% HCL 133.3 BBL, FIW w/surfactant 47.6 BBL, FIW w/diverter 23.8 BBL, 7 1/2% HCL 66.6 BBL, 6 1/2% HCL/ 1 1;2% HF 15 BBL, 7 1/2% HCL 75 BBL, FIW w/surfactant 375 BBL, FIW PAGE NO. 1 of 2 LEASE TRADING BAY FIELD MCARTHUR RIVER WELL NO. TBUS G-22 LOCATION: CONDUCTOR ~1, LEG RM ~3, 1798'N & 1413'W OF S.E. CORNER, SECTION 29, T9N, R13W, S.M. PERMIT NO. 75-16 SERIAL NO. ADL 17594 TD 11,335' TVD 9990' DEVIATION (BHL) 4370'S & 2370' W OF SURF. LOC COMPANY ENGINEER CHUDANOV, GRAHAM, HARNESS SPUD DATE 11-03-89 COMP. DATE 11-26-89 CONTRACTOR POOL ARCTIC AK RIG NO. 54 TYPE UNIT NATIONAL 1320 DRILL PIPE DESCRIPTION 5",* 19.5~, E&S ELEVATIONS: WATER DEPTH 125' RT TO OCEAN FLOOR 228' RT TO MLLW 103' CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 26" 1" Wall 360' Driven 20" 94~ Buttress H-40 629' Cmt'd w/1125 cuft 13-3/8" 61~ & 68~ Buttress K-55 5548' Cmt'd w/5802 cuft Buttress N-80,P-110,USS-95 11335' Cmt'd w/1840 cuft 9-5/8" 47~ PERFORATING RECORD DATE INTERVAL E.T.D. REAsoN PRESENT CONDITION 06-22-75 11081'-11082' 11253' Sqz. No Breakdown 06-23-75 10708'-10710' 11253' Sqz. 06-24-75 10590'-10592' 11253' Sqz. 07-03-75 11115'-11145' 11253' Production 07-04-75 10984'-11022' 11253' Production Sqzd. w/100 sxs Sqzd. w/100 sxs Isolate w/pkr 11/19/89 HB-6 Isolate w/pkr 11/19/89 HB-5 07-07-75 10911'-10936' 11253' Production Open HB-4 07-11-75 10911'-10936' 11253' Production Open HB-4 07-14-75 10685'-10700' 11253' Production Open HB-2 07-15-75 10670'-10700' 11253' Production Open HB-2 07-16-75 10832'-10862' 11253' Production Open HB-4 07-17-75 10768'-10788' 11253' Production Open HB-3 07-18-75 10602'-10622' 11253' Production Open HB-1 12-18-75 10832'-10862' 11253' Production Open HB-4 INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAY. C.P. T.P. CHOKE MCF GOR REMARKS Water Injection Well WELL HEAD ASSEMBLY TYPE: Cameron CASING HEAD: Cameron type WF 20" 2Mx20" SOW w/2 ea. LP outlets CASING SPOOL: Cameron type WF 20" 2Mx12" 3M (X btm prep) w/2 ea. 2" 5M flanqe outlets T~u~ .... ~D: Camerun uype DCB 12" 3Mxl0'' u,-~ w/2 ea. 2" 5M scudded outlets TUBING HANGER: Cameron dual 3-1/2" w/EUE up and USS Improved MMS down TUBING HEAD TOP: 10" 5M MASTER VALVES: Cameron dual solid block saltwater tree w/2 ea. 3-1/8" master valves and 2 ea. 3" bore winq valves CHRISTMAS TREE TOP CONN: 3-1/2" EUE 8RD PAGE NO. 2 of 2 LEASE TRADING BAY WELL NO. TBUS G-22 FIELD MCARTHUR RIVER LOCATION: CONDUCTOR ~1, LEG RM ~3, 1798'N & 1413'W OF S.E. CORNER, SECTION 29, T9N,' R13W, S.M. PERMIT NO. 75-16 SERIAL NO. ADL 17594 TD 11,335' TVD 9990' DEVIATION (BHL) 4370'S & 2370' W OF SURF. LOC COMPANY ENGINEER CHUDANOV, GRAHAM, HARNESS SPUD DATE 11-03-89 COMP. DATE CONTRACTOR POOL ARCTIC AK RIG NO. TYPE UNIT NATIONAL 1320 11-26-89 54 DRILL PIPE DESCRIPTION 5", 19.5~, E&S ELEVATIONS: WATER DEPTH 125' RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED 228' 103 ' 23.3' 46.6' DATE INTERVAL E.T.D. PERFORATING RECORD (CONTINUED) REASON PRESENT CONDITION 12-18-75 10768'-10788' 11253' Production 04-02-76 10670'-10700' 11253' Production 04-02-76 10602'-10622' 11253' Production 06-29-78 10602'-10622' 11253' Production 06-29-78 10670'-10700' 11253' Production 06-30-78 10768'-10788' 11253' Production 07-01-78 10832'-10862' 11253' Production 07-01-78 10886'-10904' 11253' Production 11-16-89 10595'-10629' 11254' Injection 10643"-10734' 11254' Injection 10742'-10752' 11254' Injection 10762'-10815' 11254' Injection 10827'-10952' 11254' Injection 11-19-89 10061'-10095' 11254' Injection 10115'-10154' 11254' Injection 10178'-10218' 11254' Injection 10230'-10300' 11254' Injection 10370'-10430' 11254' Injection Open HB-3 Open HB-2 Open HB-1 Open HB-1 Open HB-2 Open HB-3 Open HB-4 Open HB-4 Open HB-1 Open HB-2 Open HB-2 O~en HB-3 Open HB-4 Open G Zone Open G Zone Open G Zone Open G Zone Open G Zone LEASE GRAYLING UNOCAL DRILLING RECORE ALASKA REGION WELL NO. G-22 WO PAGE NO. 1 of FIELD MCARTHUR RIVER DATE 11/03/89 11/04/89 11/05/89 11/06/89 11/07/89 E.T.D. 11253' 11253' 11253' 11253' 11253' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS COMMENCED OPERATIONS ON TBUS G-22 AT 0000 HOURS, 11/03/89. Completed rig up over G-22, Conductor #1, Leg #3. Pumped one tubing volume at 5-1/4 BPM with no surface pressure. Well would not stand full. Mixed sized salt pill. Attempt to pump pill down tubing-bridged at flapper valve at 236'. Bled pressure off tubing and well backflowed enough to return salt pill to surface. Rigged up and reverse circulated 1200 bbl FIW. Returns contained ~ 300 bbl 'crude oil. All returns to production. Rigged up wireline and pulled tubing slip stop and prong from stuck flapper valve at 214'. Attempt to pUmp through tubing stop. Pumped down tubing taking returns from annulus to production to clean up oil left in annulus. Checked well for flow-on slight vacuum. Installed back pressure valve. Found 200 psi on 13-3/8" x 9-5/8" annulus-bled off same. Removed 4-1/2" single production tree. Nippled up and tested BOPE to Unocal specifications. Installed new flex kill line to meet AOGCC regulations. Continued testing BOPE. Pumped down tubing taking returns up annulus while backing out hold down pins. Attempt to unseat tubing hanger from DCB spool and landing joint pulled out of hanger at 30K overpull. Waited 1-1/2 hours on a spear. Made up spear and latched tubing. Worked hook load to 220 K and pipe started moving. Pipe had drag for ± 10' and then hook load dropped to 160 K. Pulled out laying down 4-1/2" tubing to 6993' TM. Gas was breaking out of annulus. Crossed over to 5" drill pipe and ran in to 10514' DPM. Circulated gas out of well bore. Continued circulating gas out of wellbore. Pulled out racking back drill pipe and laying down 4-1/2" tubing. Found GLM split at 9438'. Tubing plugged below split mandrel. Attempt to clear tubing with 5200 psi without success. Continued to pull out laying down tubing (drilled 3/16" hole below connection to check for pressure prior to breaking connection). Attempted to clear tubing with Haliburton at 7000 psi without success. Made up sinker bar on 40' of braided line and rabbited each joint before breaking the connection. Found tubing plugged with scale 3 joints above the seal assembly. Removed 4-1/2" r~s~ ~m stack and.~placed with 5" rams. Testea BOPE to Unocal specifications. Made up burnover assembly with PRT. Ran in to 10445' DPM. Circulated one hole volume from 10445' DPM. Tagged up at 10454' DPM-11' above packer. Seemed to be cleaning fill with PET bull nose. Trip to remove bull nose-afraid of twisting it off. Ran in and tagged packer at 10454' DPM. Milled over packer and chased to 10470' DPM. Trip for spear to recover packer. Ran in and engaged packer at 10489' DPM. LEASE GRAYLING UNOCAL DRILLING RECOPJ ALASKA REGION PAGE NO. 2 of WELL NO. G-22 WO FIELD MCARTHURRIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 11/08/89 11/09/89 11/11/89 11/12/89 11253' 11253' 10253' 10253' 10253' Started off bottom but did not have any drag to indicate the packer was on the spear. Ran back to bottom and set down with 20K at 10495' DPM. Pulled up and had 25-30 K of drag. Pulled out and recovered packer body. Ran in and tagged fill at 10483' DPM. Cleaned out scale to 10900' DPM. Circulated well clean and recovered 14 drums of scale. Washed down to 10929' DPM and engage fish. Jarred at 50K over for 1 hour and fish came free. Pulled out and recovered complete perforating gun and 3/4" X 6' prong that had been dropped in hole. Made up mill shoe and ran in hole. Continued running in with shoe to 8380' DPM. Down 3-1/2" hours to repair Wakashaw #1. Continued in hole to 10914' DPM and washed down to packer at 10944' DPM. Milled to 10951' DPM and packer released. Chased packer to 10957' DPM and circulated bottoms up on the choke. Blew down all circulating lines. Made up spear assembly and ran into 3660' DPM. Cut 65' off drilling line. Continued in and tagged up at 11065' DPM. Engaged packer and trip to check recovery-no recovery. Redressed spear and ran in hole. Continued in with spear and attempted to work into fish at 11065' DPM-no good. Trip for overshot to catch OD of packer body. Found grapple gone from spear. Made up overshot and ran into 11066' DPM. Attempt to engage fish with spiral grapple-slipped off with 30K overpull. Blow down lines and trip to check tools. Found grapple missing from overshot. Ran in with mill shoe to 7437' DPM and circulated while repairing Wakesha #1. Continued in to 11066' DPM and milled on packer and junk to 11068' DPM. Trip for overshot. Continued trip for overshot. Made up overshot with 6-1/2" spiral grapple and ran in to 11066' DPM. Attempt to engage fish-slipped off with 100K overpull. Blow down rig and trip to check tools. Found grapple missing from overshot. Pull wear bushing and test BOPE to Unocal specifications. Made up mill shoe and ran in to 11067' DPM. Milled on junk around packer. Continued milling on junk to 11068' DPM and penetration ~~d. Trip ~n check shoe-cutting ~ructure worn off face of shoe with severe ID wear. Ran in with new shoe and tag up at 11068' DPM. Milled for 1-1/2 hours with no penetration. Trip to check shoe-face worn smooth. Ran in with overshot with 6-3/8" basket grapple and engaged fish at 11068' DPM. Jarred fish free with 90K overpull after 30 minutes. Pulled 3 stands wet and sheared pump-out sub. LEASE GRAYLING UNOCAL DRILLINGRECOK, ALASKA REGION '~--~ PAGE NO. 3 of WELL NO. G-22 WO FIELD MCARTHUR RIVER DATE 11/13/89 11/14/89 11/15/89 11/16/89 E.T.D. 11254' 11254' 11254' 11254' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued pulling out with fish. Recovered packer body and tail assembly (entire fish). Found wireline tools sticking about 1.75' above packer top. Made up mill shoe and ran into 11101' DPM. Milled over packer to 11105' DPM. Packer started moving downhole. Circulated bottoms up with some gas to surface. Chased packer to 11,254' DPM and circulated well clean. Trip for bit and casing scraper. Ran in with bit and scraper to 11,234' DPM (20' above junk). Circulated well clean. Blow down rig lines. Trip for RTTS packer. Continued trip for RTTS packer. Ran in and set packer at 10964' DPM. Test for isolation between HB-4 and HB-5. Pressured to 2500 psi and had slow bleed to 1000 psi with no returns to surface. Repressured with same results. Pulled packer loose and pulled up to 10549' DPM. Reset packer and tested casing to 3000 psi. Replaced wing valve and all lock down pins on DCB spool. Trip for bit and scraper. Ran in to 11234' DPM. Displaced well and active system to pipeline with clean FIW. Clean active system. Continued cleaning active system. Displaced one more hole volume overboard. Fill active system with clean FIW. Picked up Vann 5", 4 HPF, 90 deg, 32 gram charge perforating gun assembly. Ran in hole leaving the top 3100' of drill pipe dry to obtain a 750 psi drawdown at the top perforation. Rigged up Schlumberger and ran gamma ray correlation log. Adjusted gun depth and set RTTS packer. Made confirmation pass with correlation log. Rigged down wireline. Tested surface equipment to 5000 psi. Opened Omni valve at 0319 hours. Had good blow on bubble hose. Fired guns at 0327 hours. Perforated HB-1, 10595'-10629' DIL; HB-2, 10643'-10734' DIL, 10742'-10752' DIL; HB-3, 10762'-10815' DIL; HB-4, 10827'-10952' DIL; with 4 HPF, 90° phasing, 32 gram charges. Well went on slight vacuum and then came back with a strong blow throughout flow period. Ran impulse test flow period from 0327 hrs to 0427 hrs. Shut in at Omni valve for 2 hr shutin period. Cycle Omni valve to reversing position and reversed one drill pipe volume. Cycled Omni valve open and pulled packer loose. Well t~'~q fluid a~ ~ ~PM. Reset packer and mixea and pumped sized-salt LCM pill. Pulled packer loose and pulled out of hole with perforating assembly-all shots fired. Made up bit and scraper and ran in to 11254' DPM. LEASE GRAYLING UNOCAL DRILLING RECO~ ALASKA REGION '~"~ PAGE NO. 4 of WELL NO. G-22 WO FIELD MCARTHUR RIVER DATE 11/17/89 11/18/89 11/19/89 11/20/89 E.T.D. 11253' 11253' 11253' 11253' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Circulated well clean. Pulled out with bit and scraper. Made up Otis 9-5/8" x 4" Bore "BWH" perma-drill packer with tail and "XN" nipple. Ran in with packer assembly to 10968' DPM (10961' DIL). Tested packer from backside to 500 psi. Sheared off packer and circulated bottoms up. Trip for test seal assembly. Ran in and stabbed into packer. Tested packer from bottom side to 2000 psi-ok. Rigged up wireline and set "PX" plug in packer tail at 10973'. Prepare to run prong. Finished setting prong in "PX" plug body. Rigged down wireline. Made up 9-5/8" x 4" Otis "BWH" packer with seal bore extension on 5" drill pipe. Ran in and set packer at 10500' DIL (10507' DPM). Tested backside to 1500 psi-ok. Sheared off packer and circulated bottoms up. Pulled out of hole. Tested BOPE to Unocal specifications. Made up Otis "JP" packer plug on drill pipe. Ran in and set plug in packer at 10500' DIL. Equalized in 6 ft3 sand plug. Pulled 6 stands and waited for sand to settle. Ran in and tagged 5' of sand on packer. Picked up 30' and changed over to clean FIW. Trip for perforating assembly. Picked up Vann 5", 8 NPF, 25 gram charge perforating gun assembly. Ran in hole on 5" drill pipe. Rigged up Schlumberger and ran Gamma Ray Correlation log. Adjusted gun depth and set packer. Reran correlation log. Tested surface equipment to 3500 psi. Fired guns at 1626 hours. Perforated "G" zone 750 psi underbalanced as follows: 10061'-10095' DIL, 10115'-10154' DIL, 10178'-10218' DIL, 10230'-10300' DIL, and 10370'-10430' DIL. Ran 1 hour flow test and then a 2 hour buildup. Total fluid rise during test was 2011'. Cycled Omni valve to reversing position and reversed out 26 barrels of Oil/Water emulsion at 32% cut. Reversed a total of 200 barrels and cycled Omni valve to test position. Unseated packer and reversed well clean to production. Finished reversing a total of 250 barrels of FIW to production after packer was pulled loose. Checked well for flow or fluid loss-taking 1/4 BPM. Pulled out and laid down perforating assembly. All guns fired. Made up bit and scraper and ran in on 5" ~rill pipe. ~ .... ~ ~il~ at ~o, DPM (sand plug). Picked up to 10485' DPM and attempted to break circulation-drill string plugged. Started out of hole wet and second stand pulled dry. Broke circulation at 10275' DPM and washed down to 10485' DPM. Circulated well clean and tripped for RTTS packer. Set packer at 10320' and injected into "G-5" at 2 BPM with 3900 psi. Reset packer at 10225' and injected into "G-4" and "G-5" at 1 BPM at 3100 psi. Reset packer at 10165' and injected into "G-3" thru "G-5" at 1-1/2 BPM at 3050 psi. Reset packer at 10105' and injected into "G-2" thru "G-5" at 2-1/2" BPM with 3200 psi. LEASE GRAYLING UNOCAL DRILLING RECOPd · ALASKA REGION PAGE NO. 5 of WELL NO. G-22 WO FIELD MCARTHUR RIVER DATE 11/21/89 11/22/89 11/23/89 E.T.D. 11253' 11253' 11253' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Reset packer at 10015' and injected into "G-i" thru "G-5" at 2-1/2" BPM with 3200 psi. All benches were isolated from each other. Blew down rig lines. Rigged up Dowell-Schlumberger to pump acid job on "G" zone. Covered and heated acid tanks to stop 7.5% HCL from freezing. Mixed acid for 6 1/2 hours. Pressure tested surface lines to 5000 psi. Started to pump acid job at 0855 hours. Pumped three stages as follows: 1st stage: 52.3 BBL, 7-1/2% HCL 66.6 BBL, 6-1/2% HCL/ 1-1/2% HF 15 BBL, 7-1/2 % HCL 133.3 BBL, FIW w/surfactant 47.6 BBL, FIW w/diverter 2nd stage: 23.8 BBL, 7 1/2% HCL 66.6 BBL, 6 1/2% HCL/ 1-1/2% HF 15 BBL, 7 1/2% HCL 133.3 BBL, FIW w/surfactant 47.6 BBL, FIW w/diverter 3rd stage: 23.8 BBL, 7 1/2% HCL 66.6 BBL, 6 1/2% HCL/ 1 1/2% HF 15 BBL, 7 1/2% HCL 75 BBL, FIW w/surfactant 375 BBL, FIW Dowell pump broke down during final displacement. Finish job with rig pump. Job complete at 1815 hours. Average rate during job was 2 to 2.5 BPM at 3500 to 3600 psi. Waiting to trip drill pipe due to high winds. Continued waiting on weather to 0530 hours. Pulled out and laid down acidizing assembly. Made up Otis "JP" plug retrieving tool and ran in to 10445' DPM. Held safety meeting with people on tour. Circulated sand off top and latched "JP" plug. Pulled plug loose and circulated well. Pulled out of hole laying down drill pipe. Continued laying down 5" drillpipe and tools. Changed top pipe rams to 3-1/2" dual. Pressure tested dual rams. Rigged up tubing running equipment. Ran in picking up 3-1/2" long string and found cross-over on Otis seal assembly to be larger than the ID of the packer. Sent cross-over to beach to be machined down to 3.875" OD. Continued running in with long string to dual packer. Made up short string tail assembly on dual packer. Ran in with dual 3-1/2" injection ~ing. Water ~ .... ~n heat e×~b~¥~ers on ~nashaws developeu a leak-repaired same. Continued running dual injection string. LEASE GRAYLING UNOCAL DRILLING RECOPd ALASKA REGION PAGE NO. 6 of WELL NO. G-22 WO FIELD MCARTHUR RIVER DATE 11/24/89 11/25/89 11/26/89 E.T.D. 11253' 11253' 11253' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued running dual injection string. Tagged permanent packer at 10509.61' TM (9.61' deep to DIL). Spaced out with 1' extra on LS and 2' extra on SS to get more weight stacked on dual packer. Changed annulus over to FIW with 2500 ppm Nalco 3900 packer fluid. Tested long string seals to 500 psi. Dropped ball on short string and set otis RDH dual packer with 1500 psi. Sheared ball out with 2000 psi. Pressured short string to 3000 psi to test dual packer. Slacked off 2' and landed hanger. Locked down and packed off hanger. Continued packing off hanger. Test mechanical integrity of 9-5/8" casing by pressuring up annulus against dual packer at 8822 TVD to 3000 psi and holding for 30 minUtes. Witness of test waived by AOGCC. Layed down landing joint and installed back pressure valves. Removed and broke down stack. Installed 3-1/2" dual solid body tree. Removed back pressure valves and installed two way check valves. Tested hanger and tree to 5000 psi. Installed injection chokes. Closed all tree valves and turned well over to production. Rigged down choke manifold for move to Rig #55. Rigged down brake water pump, trip tank pump, rig floor equipment, and tools for move to Rig #55. Continued moving equipment to Rig #55. Installing steps and landings on rig #55. Heat treat new choke line. Cleared rig floor to x-ray welds on choke line. Worked on flow ditch from Rig #55. Prepare to hook up choke manifold. Release Rig ~54 from G-22 at 240Q hours on 11-26-89. TUBING DETAIL - SHORT STRING TBUS G-22WO NOVEMBER 1989 JTS PUP PUP 329 'PUP PUP DESCRIPTION COLLET CATCHER SUB 3-1/2",9.2#,N-80,BUTT OTIS "XN" NIPPLE 3-1/2",9.2#,N-80,BUTT DUAL PKR 3-1/2",9.2#,N-80,BUTT 40K SAFETY SHEAR SUB 3-1/2",9.2%,N-80,BUTT OTIS "XA" SLEEVE 3-1/2",9.2#,N-80,BUTT 3-1/2",9.2#,N-80,BUTT 3-1/2",9.2#,N-80,BUTT DUAL SPLIT TBG HANGER LANDED BELOW ZERO LENGTH BOTTOM TOP 2.21 10035.50 10033.29 4.98 10033.29 10028.31 1.49 10028.31 10026.82 29.66 10026.82 9997.16 6.72 9997.16 9990.44 5.05 9990.44 9985.39 1.18 9985.39 9984.21 28.22 9984.21 9955.99 3.78 9955.99 9952.21 9896.35 9952.21 55.86 2.00' 55.86 53.86 15.00 53.86 38.86 1.00 38.86 37.86 37.86 37.86 0.00 1') TUBING CONNECTION IS USS IMP BUTT W/ TKC MMS COUPLINGS. 2) TUBING IS INTERNALLY COATED W/ TUBOSCOPE TK-99 COATING, 3) TAGGED PERM PKR AT 10509,61' TM (9.61' LOW). PERM PKR SET AT 105'07' DPM (.10500' DIL) 4) RAN' 2,7 FT EXTRA TO STACK WEIGHT ON TOP OF PACKER. TOP OF DCB = 40,60 5) HANGER: TOP IS 3-1/2" EUE 8RD. BOTTOM IS 3-1/2" USS IMP BUTT TKC MMS 6) PICKUP WT BEFORE SETTING PKR = 225K, SLACKOFF = 125K TUBING DETAIL - LONG STRING TBUS G-22WO NOVEMBER 1989 JTS 15 PUP 329 PUP DESCRIPTION REENTRY GUIDE SHOE 3-1/2" 9 2# N-80 BUTT OTIS X LANDING NIPPLE 3-1/2" 9 2# N-80 BUTT · · · · OTIS SEAL ASSY 3-1/2" 9 2% N-80 BUTT LENGTH 0.81 30.62 1.31 29.87 10.23 28.68 OTIS XA SLIDING SLEEVE 3.78 3-1/2",9.2#,N-80,BUTT 446.28 OTIS XA SLIDING SLEEVE . 3.79 3-1/2",9.2#,N-80,BUTT 29.40 DUAL PKR 8.63 3-1/2",9.2#,N-80,BUTT 29.05 OTIS XA SLIDING SLEEVE 3.78 3-1/2",9.2%,N-80,BUTT 5.10 3-1/2",9.2#,N-80,BUTT 9896.91 3-1/2",9.2#,N-80,BUTT 15.00 DUAL. SPLIT TBG HANGER' 1.00 LANDED BELOW ZERO 39.59 BOTTOM TOP 10583.81 10583.00 10583.00 10552.38 10552.38 10551.07 10551.07 10521.20 10521.20 10510.97 10510.97 10482.29 10482.29 10478.51 10478.51 10032.23 10032.63 10028.44. 10028.44 9999.04 9999.04 9990.41 9990.41 9961.36 9961.36 9957.58 9957.58 9952.48 9952.48 55.57 55.57 40,57 40.57 39.57 39.60 0.00 1) TUBING CONNECTION IS USS IMP BUTT W/ TKC MMS cOUPLINGS.. 2) TUBING IS INTERNALLY COATED W/ TUBOSCOPE TK-99 COATING. 3) TAGGED PERM PKR AT 10509.61' TM (9.61' LOW). PERM PKR SET AT 10507' DPM (10500' DIL) 4) RAN 1.0 FT EXTRA TO STACK WEIGHT ON TOP OF PACKER. TOP OF DCB = 40.60 5) HANGER: TOP IS 3-1/2" EUE 8RD. BOTTOM IS 3-1/2" USS IMP BUTT TKC MMS PRODUCTION PACKER DETAIL TBUS G-22WO NOVEMBER 1989 DESCRIPTION OTIS "BWH" PERMA-DRILL OTIS RDH DUAL HYD PKR LONG STRING SHORT STRING LENGTH 13.12' 8.63' 6.72' BOTTOM 10519.80'DPM 9997.16'TM 9999.04'TM TOP 10507.00'DPM 9990.44'TM 9990.41'TM ISOLATION PACKER DETAIL TBUS G-22WO NOVEMBER 1989 DESCRIPTION REENTRY GUIDE SHOE OTIS "XN" NIPPLE 3-1/2", 9.2#, N-80 OTIS ADAPTER BxP OTIS SWAGE PxP OTIS "BWH" PERMA-DRILL LENGTH 0.75' 1.61' 6.08' 0.50' 0.27' 5.09' 'BOTTOM. TOp 10982.30'DPM 10981.55'DPM 10981.55'DPM 10979.94'DPM 10979.94'DPM 10973.86'DPM 10973.86'DPM 10973.36'DPM 10973.36'DPM 10973.09'DPM 10973.09'DPM 10968.00'DPM 20" @ 629'J @ 5548' Z A JUNK /l @ 11335' E 13 l C B Bi ¢~L3~ON DUAJ. SPLZT T~B]NG H~KGER AT ~00, 94o, H-4G CASING AT 620' Z3-318', 63m & 6&e, ~-SS CASXKG AT 5548' T~BZNG DL'TAZ~ JlJJlmummamll 3-Z/~', 9.24, N-S0, 3flPROVED BUTTRESS KZ?R 'TIKC K SPKIAL CLF. ARANCE CC)~P~Z#GS A~CD TK-99 XIFTEP~AL COATIIf~ ~ rS'R~#G · mtn · WELL TBUS (;;-22 COMPLETION ( 11-26-89 ) UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-8-90 ~ 25, 1989 LEO3 ,C'G- X-I~D 2" C~¢ 9 10 11 12 14 ~6 ~17 18 --IV VI . 2. 3. 4. . 7. 9. 11. Trading aa~ Unit 9-5/8" 47 ppf N-80 3-1/2" 9.2 ~ Tubcsa:t~ ~.~ ~ Buttress 431/1013/01,/89 ~ 28, ~ (907) 283-7531 I.D. O.D. K.B. 40.60; ~ TUbJ.t~ ~ 2.99" 1.0' ~ JO.tl~ 2.95" 3.94" 15.0s ~ree i%Jzz~-e~ ~ 2.95" 3.94" 9896.91' (329) ,7~ of Tubirg PU~ Joint 2.95" 3.94" 5.10' Ot/s 'ICA' SlJ~U~ ShOe Doc= 2.75" 4.28" 3.78' (pm 121 x~ 123) (1) Joint: 40,000 1~ Shear Valve (:P/N 12 i~H 9129) one (1) o'o.t,~ (P/N ~21 ~a 23) Fi~'tean (~) ~oints of Tubing ~ 'X~' SlJ~Ln~ Side (P/N 121 X~ 123) ona (1) 2.95" 3.94" 29~05' 2.90" 8.44" 8.63' 2.95" 3.94" 29.40' 2.75" 4.28" 3.79' 2.95" 3.94" 446.28' 2.75"" 4.28" 3.78' 2.95" 3.94" a. Straic~Yc Slot Locate' (P/N 2~2 S 40000-.) b. Nolded Seal Assm~y (P/N 212 14SN 40000-A) c. Seal~ (P/N 222 X 40000-A) cl. Molded ~ ~¥ (P/N 212 ~ 40000-A) (P/N 222 X 4(X)00-A) 28.68' 10.23' 2.95" 4.97" (1.31') 2.95" 4.04" (1.1') 2.95" 3.97" (2.01') 2.95" 4.04" (1.1') 2.95" 3.97" (2,01') 40.60' 41.60' 56.60' 9,953 · 51' 9,958.61' 9,962.39' 9,991.44' 10,000.07' 10,029.47' 10,033.26' 10,479.54' 10,483.32' 10,512.00' 19 20 21 22 HD: 431/1013/01,/89 November 28, 1989 23 2/, 25 26 27 28 29 3O 15. Orla (1). 3'OJZfC 2.95" 3.94" 16. Ot/S 'X' Selective ~ 2.75" 3.80" (P/q~' 11 X 27560-A) 29.87' 10,522.23' 1.31' 10,552.10' 17. ~ (1) JOJ/~t 2.95" 3.94" 30.62' 10,553.41' 18. Ot/S ~11e Shoe Re-ERtr~ 2.95" 3.865" .81' 10,584.03' ~0,584.84' 31 32 11 --'12 --13 14 19. K.B. 2o. ca~-cr, ~'ubir~ av~g~ 2.~" 21. Cr~ (1) ,.ToL]I~ 2.95" 3.94" 22. ~ (1) Jo/rd: 2.95" 3.94" 23. ']hL"ee la2zxlL.*e~ ~h'Je 2.95" 3.94" (329) Joints of Tubir~' 24. Otis 'X~' Slid/rig side ~ 2.75" 4.28" (~ =[ ~ =3) 25. ~ (1) 3o~ 2.95" 3,94" 26. ~ ~ ~ ~ 3o~ 3.0" 4,25" 4~ ~ ~ V~ (~ ~ m 3~) 27. ~ ~ 2.95" 3.94" 28. ~ ~ ~ ~~ 2,90" 8.44" (P~ ~ ~ 9~9) 29. ~ 3o~ 2,95" 3.~" 30.' ~ ~~ ~ 2.635" 4.25' (~ ~ ~ 31. ~ 3o~ 2.95" 3.~" 32. ~ ~ ~11~ ~1 2.95" 4.28" (~ ~ ~ 3~) 40.60' -0- 1.0' 40.60' 15.0' 41.60' 2.0' 56.60' 9896.35' 58.60' 3.78' 9,954.95; 28.22' 9,958.73' 1.18' 9,986.95" 5.05' 9,988.13' 6.72' 9,993.18' 29.69' 9,999.93' 1.49' 10; 036.09' 4.98' 10,031.11' 2.21' .10,036.09' ~Q,038.30' II 43Z,/3.03.3/01/89 28, 1989 II. Ob/s Su~Ige PXP 4.0" 5.0" (;,~ 212 x '7o46) III. Ot.'Ls ~.~ BXP 2.99" 5.2" (P/N 2Z2, C '/3.42) ZV. :Pap Join~ 2.99" 3.94" V. Otis ')iN' No"Go ~ 2.635" 4.25" (P/N 11 ~(N 27500-A) 2.99" 6.5" ~DP C~ P~&~ 5.10' 10,507.00'* 7.70s 10,512.10' 10.519.80' 5.09' 10,968.00' * · 27' !0,973.09' .5s 10,973.36' "6.08' 10,973.86' 1.61' 10,979.94' · 75' 10,981.55' 10.982.30' Lease: GRAYLING Field Contractor Ri9 Hud Il NAT N-1100 TI Days iT1 Rot Well 12289 TBUS POOL ARCTIC J54 Pumps J2NAT N-1100 24 [3. ,'o. , ~ize ~pe [Serial ,~e,, 32 nos Ou~ ~ee~ :C~ Rr ~/~r iO0ORP~ Pres. Liner'SPM ~PS ,L P, [,B~ ,e,ark, ,1''00' 8'SISEC {41232 0/0/ 0/011234~ 0 0. O :0 0{ 0.' 0494. 0 O 0741 RUN i'~'i [M44N 0. 0 :0 0 0. 0 0 0 11 11/13/89 2X 8.5 SEC 41232 O/ O/ O/ 011234'. 0 O. 0 ~0 0 0 0 533. 0 0.,..23. O. JO I0 . 8.5 szc t,.,J, 0/ 0/'8/ 0] O 0 { 0 533. 0 0 0{7[4]1 SCR RUN {3X 8.5SEC [4!232 { 0/ 0/ 0/ 0 10502 0 0. 0 :0 0{ 0. 513. 0 0 0 ' M44N t 0.{ 0 20 0 0 O 0 { .I C.O. ,R, ~ {RI 18 11/20/89! 2X 8.5SEC 41232 O/O/O/ 0 11234 0 O. 0 00 0 O,513. 0 0 0,7 41:C.0. TRIP , M44N o. 0 0 o, 0 0 RI 18 11/20/89 ! ~' ',o. ,o~ ' . o.I 20 ~oo oo.1 oi, o . oi '~ 0 Al' ASKA OIL AND GAS CONSERVATION COMMI'SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Pluggi0g __ Time extension ~ Stimulate ~ Change approved program Pull tubing ~ Variance ~ Perforate ~ Other __ 2. Name of Operator I 5. Type of Wail: 6, Datum elevation (DF or KB) Development __ t~ 0'11 C_~¥ of C~'l"it=orP'~s (~') ,] Exploratory__ Address I Stratigraphic __ P.O. Bo~ 190247, Anc_h~ Ak.~ 99519 0247 I ServicerS._ 4. Location of well at sudace 1798' N & 1413' W of SE Corner Sect. 29, TgN, R]3~ SM At top of productive interval 10,602' MD, 9338' TM), 4112' S, 2142' W from surface location At effective depth 11,253' MD, 9911' TM), 4343' S, 2346' W from surface location At total depth 11,335' MD, 9984'., TM), 4371' S, 2371' W from mn~ace location 12. Present well condition summary Total depth: meas'ured true vertical 11,335' feet Plugs (measured) 9,984' feet Effective depth: . measured 11,253' feet Junk (measured) true vertical 9,911' feet Unit or Property name Traa~ Bay Ur~t Well number G-22 9. Permit number 7"k.lR 10. APl number 50-- 11. Field/Pool McArthur River Field Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" D~i~ 360' 360' Conductor 629' 20" 661 sxs 629' 629' Sudace 5,548' 13-3/8" 3,060 sxs 5,548' 4,977' Intermediate Production 11,335' 9-5/8" 1,600 sxs 11,335' 9,984' Liner Perforation depth: measured Uppermost Perf: 10,602' REcEiVED h=w~rmost Perf: 11,145'. true vertical Uppermost Perf: 9,338' Lowermost Perf: 9,814' AUG 0 '7 1989 Tubing (size. grade, and measured depth) 4-1/2", 12.6#, N-80 @ 10,533' Alaska 0il .& Gas Cons. C0mmissl0~ ,} '..Anchorage: Packers and SSSV (type and measured depth) Otis Ball Valve @ 286', Baker '~-1" pkr @ 10,465', Baker Description summary of proposal x Detailed operations program __ BOP sketch 2[_ 13. Attachments feet 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approvedI Service ]' rlj ect ~ on 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title ]~rcJ. rorm~ta~ Engineer -/Rog' D. F~b~rts · ' FOR COMMISSION USE ONLY Conditions of ap~3roval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- 15. Status of well classification as: Oil ~ Gas ~ Suspended Approved by order of the Commission Fo m OS/15/SS Original Signed By David W. Johnston Commissioner Date 7/26/89 Approval No. Approved Copy Returned Date SUBMIT IN TRIPLICATE WELL PROCEDURE TBUS G-22 7-29-89 v" 1. MOVE RIG $54 OVER TBUS G-22, LEG $3, CONDUCTOR 2. KILL WELL. 3. INSTALL BPV's, REMOVE TREE, INSTALL & TEST BOPE. !,.. 4. PULL AND LAY DOWN SINGLE 4 1/2" PRODUCTION STRING. 5. BURN OVER AND RECOVER THREE BAKER PERMANENT PACKERS. 6. RUN BIT AND SCRAPER TO 11253' ETD. ~ ' 7. PRESSURE TEST THE 9-5/8" CASING WITH RTTS PACKER. 8. SET A CEMENT RETAINER AT 11100' AND CEMENT SQUEEZE HEMLOCK BENCH 6; PERFORATIONS FROM 11115'-11145'. 9. SET A CEMENT RETAINER AT 10950' AND CEMENT SQUEEZE HEMLOCK BENCH 5; PERFORATIONS FROM 10984'-11022'. V" 10. CLEAN OUT CEMENT AND CEMENT RETAINERS TO 11253' ETD.j 11. PERFORM DRAWDOWN TEST AND PRESSURE TEST ON SQUEEZED PERFORATIONS IN BENCHES 5 AND 6. 12. CHANGE OVER TO CLEAN COMPLETION FLUID.v' ~.~o~.~ G ~-~.~.-~,.. 13.~ REPERFORATE THE HEMLOCK UNDERBALANCED WITH 7" OD TUBING CONVEYED GUNS AS FOLLOWS: ., G ZONE G-1 G-2 G-3 G-4 G-5 HEMLOCK HB-1 HB-2 HB-2 HB-3 HB-4 10061'-10095' DIL (34') 8 SPF 10115'-10154' DIL (39') 8 SPF 10178'-10218' DIL (40') 8 SPF 10230'-10300' DIL (70') 8 SPF 10370 '-10430' DIL (60') 8 SPF lcl595'-10629' DIL (34') 4 SPF 10643'-10734' DIL (91') 4 SPF 10742'-10752' DIL (10') 4 SPF 10762'-10815' DIL (53') 4 SPF 10827'-10952' DIL (125') 4 SPF 14. RUN BIT AND SCRAPER TO 11253' ETD. 15. RIH WITH A RTTS PACKER AND SET AT. lO056' DIL AND PERFORM INJECTIVITY TEST INTO THE G ZONE AS DIRECTED. .. 16. STIMULATE THE'"G" ZONE AS DIRECTED. 17. RUN A DUAL 3-1/2" COMPLETION ASSEMBLY."' 18. REMOVE BOPE AND INSTALL DUAL TREE.. 19. RETURN WELL TO PRODUCTION DEPARTMENT. NOTE: SBHP ANTICIPATED TO BE 4025 PSI AT 9450' TVD. WORKOVER FLUID WILL BE FILTERED INLET WATER WITH NACL AS REQUIRED FOR WELL CONTROL. A MECHANICAL INTEGRITY TEST WILL BE RUN ON THE WELL PRIOR TO BEGINNING INJECTION. AOGCC WILL BE GIVEN 24 HOUR NOTICE PRIOR TO THE TEST. '~" KL, Urn' Wn'H (~)' ~" S~ V~¥~.S 1. ~'1~'~ '~,~i KILL LINE r-"ROM, MUD PtJ,? A, C-ZL{ENT 'UN~' ,, NIPPLE= 12" 3DDO PSI ANNULkR · ._ ! , , , BLIND RAMS: PIPE RAMS 1 PiPE RAMS ,, , , ,, ,= , f' FLDWMNE 15-5/B" 3M FLANI;E ADAPTER 5M x 51,I 15-5/B" 5M FLAN~F.. DDUBLE GATE 5M I 13-5//B" 5M FLANGE ,,I 4" CHDKE LINE WITH DNE ,t, 1 MANUAL 4" 5M VALVe_ CDNN-Z~TED TD CHDK~ (S~ MANIFDLD DRAWINg') · '1 ! 5u. STACK DRILLING OP,:"RA ONS UNION OIL COMPANY OF C..A~FO,=','NIA t'db= UNOCAL") 15-5/B" 5tvt rm_ANG.-- S1NG~='' GATE 5M 13-5/B" 5M FLANGE iD" 5M x 13-5/B" 5M ~.i~D. APTE_R C.,..JJ,,,,DN 5M DC~ SPOOL I I "11 ' I.II PRESENT 20',94+,H-40 at 629' 13 3/6',61+ & 68+,K-55 Casing at 5546' 4 1/2',12.6+,N.--60 Tubing Perm. Packer st 10,465' Perm. Packer at 10,940' Perm. Packer at 11,090' . · 9 5~8',47+,N-80.S-95 & P-110 Casing st 11,335' WELL T.B.U.S. G-2 2 WELL'TBUS CASING & CEMENT DETAIL tl;~:';.iF;';!;:!~: I I :~'.'(/'.:i~;!,:::::.". VOLUMES SHOWN ARE i~?':!i~[}:{'}. ; ' ~:-~?~i?? (CMT, VOL./HOLE VOL,) '.: :!i"."; f:i';ii:.'i ' , t;:..!-:~ F:.:.:~: ' I ~.'.:::' .' ~:'.:~." / .,...,°' ~;..;." ,,' .'; '.'..;_. · ',,', q , o~.";~ ..,'.,.,'. ~'~..':.:. .:.,:?., . ..v.'..'. .:'.'~.':'. . . · ~:,.'-.'?..~ ..;:,.'.".".'_'., ?.~".~::::,':.'J~, 26 ~t ? ~,: :,:.....'...._ ;:'.;.; .:., .'.;., .... ~. · ;.:-.'~' .:~:~ii.; . '.".~.'.: i !.".'.'.~, ~ r:-;.-.! .:.'~',:~ ;...'.,.;., ,:;.;.,;I , , .,;:~,.:; ..,,.,:::, ~ ~ .-,.; .-,,_..t ..o..,.,,.......~ , ~.;;:...-..;;: = ; .'.~.'4~.; r....~:, i i:.:...~ .'.'..;...,' i . i .:.::v;,;..,......~, ~ . · , ..:.,:',, .;..:.'::, . .....?.:~1,5::.::.:~ ~ . .,,"'o -'.4 ,° · ~1 ,;4'.: r'-?.-';; I I r .:'.'::.~ ).":"" ~ ' 23 Hole -,-~';'~'?b:.':;.'.;. '.'~;:.:.:t;."..'::."~ · ~':;:"': I:::'::: ' ; ':"'"' I;;: :"':' 'r':".:: '":""=~, ";'"".":"::'"';' 20 94~'. H-4O at 629 ..:::.:;.:, I'":!;i';~1_.... I~',.':"?i 3/5/'/5 S61sxs (112Slt3/442f~ l:;,!i';!![ l~?'!:ii Good RTNS Noted o =";':'/I ~'.;':. . ~ ..~.l: '; %' I b '".' 17 1!2 HO · .'..,., .:,.-.'.. · . 0 ','::f'::l'~ ['p:.':.":. DV Collar at 2753 ~ ...:..;z~ ,- ,:.;:..: . · , ?".'2.' , '.'.'=:: ';/.:::t .. ~::?.": ~[}.'!'"[':';'~520'i' TOP PLUG ' "~l ";""' '''?' ' ,, · '[;;-'"' I ' h T m n ,..,:, · .. r.'-..'~:: ..... ' T eo, OD Ce e t 5377 ,.5.,...'.' ~ ,.--.,,.'. ~I':;..., ;v'!i!:f~:; '..~ · .;:~' i'..' ;, .. :'..r.'::~..'' ,:.".:;?:it,': '::I '".'%: !s'!""! ....-....., ......, .:...'?: :.,::.:j ~.',.~:': ~ · ,'.'.':'..'i..'..' :~ '.:':.: .~:..'.:.. 1 ~. '..J ;....'., , ...'.~; ~ '"'"' :" t'l ""':' .:~'.';. '.t'...I ';;..:~ ?.-..:!....... ,).. ;,~':;~u -~:"'-'"~13 3~B', 61&6B~', K-55 BT&C at ~548 KO at 5600 ~' ".vf..='.~ j~..-:'..".;~ · ::.":' ..':'.; ' · ..~.'"' .~';." f::.':::'-:;: V-',?.'-~ ~,/~..:'.";,Y' ~:!~~ BTM CMT PLUG AT 6000 ,.: :'-.:~j 'b'?. I .':.:-.?.~ ~:~.~ ,' · ,'..,.-.,~ · ~:(:'::-h , r ;;;.'"'.l ;'; 'H '~ I · '; '""' ';;-';'i ' ~'."--.--. b.".:] . . ,. ;..: -. e... '.1 t . · · . , ~.: :-.':.:t t.'::':'.1 , ~ F I s h -~ t 7196 ,, ! · ,. -::;;~1 ,.::.:.".:,; ', ~ . ..'.-.':; ',,;.:'i I~ , ,~ · ~ .~',-~ J:.-:.', , -, 2 114 Hole , "-. ;-;;. i.;::';i ~ ;.."..'~' I::::.,?, ,' · i;'-:'.': !;:.':. ':J ~ ;':-.'.:.-:; l'.:.".:~;: ~ ' ""°~ I '~""" I~ ""' '" I.;' '""~ %-.- .,-,[ r'~: :J . _ 'l:.':'.;I [ ;.'.::;,' ' --~ ' '1'"'" '.. 9 518 at 112,3 ,~.:~ TKO.,, 6/20/75 1600sxs L-_~_- ..... -_ _~, ~--_-- -_-_____~ 11336' (est. 1840tt3/3639ft3) Theo, ToD Cement st 5,377' · CBL ToD at -_10000' NOTE: ALL CEMENT TOPS ARE THEORETICAL Poor CMT Bond Noted _ :=-,,-' GRAYLING PLATFORr?I =':; ....... , CASING ._ I .~..;.~., .~.~ ~.-,~,~.~..v .--,~ ";''.---w'~ ,. · .-~ :,. :~.~ :'.'.. '". ~i,...:~. :...' · : :~.:. .. · ,. · . .' :~::.:~, · .;'"!lb;i:. ~. ,....,..: .. ... :: .; ·. · '.,, ~..,::, ~, · '.. :: ~;.'~ :.'.:. · :';: ;: } i:":;. ;' · ;,:.' ..~:;~.: · .'il :'..'.'!.~'~ ;: · ..,',, .., '~,, · , .., ', ; "::..:. · , .... ,: :-I.! .'.i . · '.".:. , · .; ; ~ :.(: · .... · ...... ' .:;4.:.. ·: ;.'.:. :[:L-i . ".;:.i .... :.ff . · .!.' .":: ~'I": ::'ii,.;. .....','... :::, ". .., ,~.~ ~:~:'i. :': Union Oil and Gas/I;':"'"sion: Western Region Union Oil Company u~ California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unll n 3une 28 ~ 1984 Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission ~001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE INTENTIONS Attached for your approval are Sundry Notice Intentions for D-21 & G-22, Trading Bay Unit. The G-22 Sundry for abandonment replaces all other's previously submitted. Please return the.approved Sundry's to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPEC IAL IST LOC/ti Attachments RECEIVED JUL 0 1 u~ · {~as Cons. Co~la|ssloll Anchorage STATE OF ALASKA _ ALASK ' ILANDGAS CONSERVATION ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 75-16 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o~33-20272 4. Location of Well Leg 3, Cond, #i, i789'N & i413'W of SE Cot. Sec. 29, TGN, Ri3W, SM. 5. Elevation in feet (indicate KB, DF, etc.) Rt 99' MSL 12. I 6 . Lease Designation and Serial No. ' ADL 17594 9. Unit or Lease Name Trading Bay Unit .. 10. Well Number G-22 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon 'J~ Stimulation [] Abandonment [] Repair Well [] Change Plans [] · Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). G-22 Abandonment of Lower Portion 9 5/8" casing string. Prior to G-22 redrill operations the lower portion of the existing 9 5/8" casing string will be abandoned as follows. 1.) Rig up over 9-22. Rig down tree. Rig up and test BORE to ± 3000 psi. 2.) Pull existing 4 1/2" completion assembly. 3.) Squeeze cement to abandon existing perfs. 4.) Shoot squeeze holes $ + 5900'. Set retainer $ + 5850' and squeeze for isolation. Dumpin~ cement on top of retai~r to + 5750'. 5.) Wash-over and pull existing 9 5/8" casing down to + 5650'. 6.) Lay densified plug ± 5750-5400' and perform 8radenh-ead squeeze down on casing stub. 7.) Continue with 9-22 redrill operations. " RECEIVEE J u L 0 ]985 Alaska 0il & Gas Cons. C0m Anchorage 14. I hereby certifySJ~a9 the forego.' 's rue and correct to the best of my knowledge. Signed La~.~u~ Title ENVIRONMENTAL ~PEC'IALIST The space below for Commission use Date Conditions of Approval, if any: ~ltlllllAt $1GIE! Approved by ApproVed Copy hturrj~ij By Order of COMMISSIONER the Commission Date 7 --/__'_~.J~__ ..... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate A(~' STATE OF ALASKA ~I ALASK ''L AND GAS CONSERVATION C ''''MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UN[ON 0TL COMPANY OF CALTFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well Leg 3, Cond, #1, 1789'N & 1413'W of SE Cot. See. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) Rt 99' MSL 12, 7. Permit No. 75-16 8. APl Number 5o-133-20272 9. Unit or Lease Name Trading Bay Unit 10. Well Number I;-22 11. Field and Pool \ I 6. Lease D~!gnation and Serial No. NcArthur River Field ADL ~\17594 Check Appropriate Box To Indic~a~te Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' ~,/SUBSEQUENT REPORT OF: (Submit in Triplicate) I Perforate [] Alter Casing [] ~, Stimulate [] Abandon [] Repair Well [] Change Plans [] Pull Tubing [] Other [] (Note: Report multiple completions on Form 10-407 with a submitted Form 07 (Submit in Duplicate) Perf( [] Altering Casing [] Abandonment Repair [] Other ;ach completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent dls//and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). / ..,,.' ,. / ,,, G-22 Abandonment Lower Portion 9 5/8" ca,sing . ... , Prior to G-22 redri11 operations the lo'er .on of the existing 9 5/8" casing string will be abandoned as follows. 1.) Squeeze to abandon existing perf's/ 2.) Shoot squeeze holes a + 5900'. Set ;r a + 5850' and squeeze for isolation. Leave 'Ee, ment on top of ,aine~-'to + 5750'. 3.) After existing 9 5/8" casing is removed + 5650'; a cement plug will be laid f/+ 5750 ..,.(inside 9 5/8'" ) t/+ 5400'. Cement will be squeeze'~. ///I/ ' ~'~'~.,~~~~~~~ 14. I hereby qertify~the~re~~ correct to the best of my knowledge. Alas~ 0" & Ga, .Anchorage Si~ned Lawrence 0. Cutt~O Title ENV[RONMENTAL SPECIALIST Date The space below for Commission use Conditions of Approval, if any: By Order of Approved by.. COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate % ~' .." · ,..?.:~?; .~...o · _.C"'-"~Z' O t. · . · ', i,{ ~. ,. ,,~ &..~; :' - · -., ....~'~'../ , . LS;'~ ',. "' - '7~;-. %"" - · '2".'-i:f..'.'" ' . · · :.~:i_'/... ...... ... · · .. . ~.,~ · ~0_0. ..... . ................ ..7_.0._.~. ...... .. . :.. · ........... . ' .. - · -~-~;, ·-' . ·. . · ,-/oO. ' ....... ':' .--- 7:57.. .. ,~oo ............. .. ~.- ~ · ~. -. :-~-. .... ';",' '". ' ii; :',r:-':', - o.' -' '.: . ...' . unl ,n October 22, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska Union Oil and Gas,,['':' 'ision: Western Region Union Oil Compa( )f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 -i-'i I~1""~: ~-r:~a"-i .... [ .... i'-'-Y ~'-I--' '. .... [.~ ~ ~.E~i..-[ .... ~?' ~:~.,,~---~ .... ..... ~.--~-.t .... I 3 G~OL I ..... I ....... ,.~v"2.~.. ..... l~,'~c ..... .... ,, ............. kltE~ 99504 Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the Well Histories for the following wells: Trading Bay Unit State G-15 (WO) Trading Bay Unit State G-13 (WO) Trading Bay Unit State G-2 (WO) Trading Bay Unit State G-21 (WO) Trading Bay Unit State G-23 '(WO) Trading Bay Unit State.......~ Trading .Bay Unit St G~_~7.~_~ Trading Bay Unit State K-21 Kenai Untit #21-6 (WO) Kenai Unit #33-30 (WO) Kenai Unit #43-7 (WO) Very truly yours, 5..~'.~..:;.',,' lc'. C.,..~:. (':..~..::',,~'~; C,--- Jim R. Callender ,,.'2.,L..- . District Drlg. Supt. sk Encl. (22) · cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. - TBU only Skelly Oil Co. - TBU only Phillips Oil Co. - TBU only Standard Oil Co. USGS - Rodney Smith Dear Mr. Marshall: Union Oil and Gas~ .... sion: Western Region / Union Oil Company",,, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 AUgust 12, 1975 unlen Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska Enclosed for your files are the following reports: 99504 TBUS G-22 (12-32) TBUS G-2 TBUS D-27 (31-6) TBUS D-Z0 (22X-6) TBUS D-2A (13-5) TBUS K-21 (21-28) Kenai Unit #33-30 Monthly Report (Form P-4) Completion Report (Form P-7) Monthly Report (Form P-4) Formation Test #1 & #2 Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Completion Report Monthly Report (Form P-4) Completion Report Kenai Unit #43-7 2 ENG - 1 ~EOL r-~ . I - ........ . ..... ~_ PILE, t, ,, Completion reports for TBUS D-27 and TBUS D-20 will be forwarded to you within the next week. Very truly yours, David A. Johnson Drilling Engineer sk Encl. cc: Marathon Oil Co. Atlantic Richfield Co. Standard Oil Co. Phillips Petroleum Amoco Production Skelly Oil Co. Mr. Rodney Smith-USGS. STATE O( ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICAT~ MONTHLY REPORT O'F DRILLING AND WOR'KOVER OPERATIONS o,,~ . [~ G,s ~-] otH. Salt Wtr Injector WSLI, ~LL · · ~. NAME OF O~It. ATOR UNION OIL COMPANY OF CAL~ORNIA ~. ~ba~s OF o~a 909 West 9th Avenue, Anchorage, Alaska 99501 4. ~CA~ON OF W~ Conducto~ ~1, Le~ Rm. ~3, 1798~N & 1413'W of the SE corner. Section 29: TgN, R13W, S. M. AP1 NUMERICAL CODE 50-133-20272 LEASE DESIGNATION A.~D SERIAL NO. ADL-17594 IF INDIA~. ALOTlki O1{ TRIBE NAME 8. L,~IT FARM OR LEASE NAME Trading Bay Unit 9 WE.L,L ~'O State 0-22 (12-32) McArthur River-Hemlock Il s~c. r.. ~.. ~. r~ ~o~ , o~ ~080'S &~870 W of sur: loc. or 2330'S & 950'E of NW cot: S~ction 32: TgN. R13W. SM~' 75-16 '13. REPORT TOTAL DEPTH AT END OF MONT'H, CHANGES IN HOLE SIZE, CASING AND UI/;IviF.,N'I'ING JOBS INCLL'DING D~T-H SET AND VOLUlhTES USED, PEI~.FORATIONS, TESTS AND RESULTS FISHING JOB~ Jl/igK I.N HOLE AND SIDE-TRACKED HOLE A~D A~Y OTHF.~ SIGNIFICANT CH. ANGES L'~ HOL~ COI~rDITIONS RU & ran Baker perm. pkr. on 4 1/2" tbg. & set @ 10,450'DPM. Pooh. RU & ran 4 1/2" tbs. w/ accessories. Stabbed into Baker perm. pkr. @ 10,467'TM. Tested pkr. to 1000 psi-ok. Displ. mud w/ wtr. Displ.. wtr. w/ diesel to top pkr. @ 10,450'. Installed BPV's. Removed BOPE. I'nsialled x-mas tree & tested to 5000 psi. Diff. perf.' Hemlock Bench #6 from 11,115'-11,145' .w/ 3 3/$" csg. gun @ 4 hpf. Prod. tested Bench #6 perfs. @ 600 BWPD & trace of oil. Ran build-up survey. BHP Bench #6-3343 psi after 12 hrs. still increasing. Set "N" plug in "N" nipple @ 11,104' to isolate Bench #6. Perf. Hemlock Bench #5. from 10,984'-11,022' w/ 3 3/8" Hyperjet II csg. gun @ 4 hpf. Prod. tested Bench #5 perfs. @ +1000 BPD rate w/ +_90~5 wtr. cut. Ran build-up survey. BHP Bench #5-3646 psi after 18 hrs. Set plug in "X" nipple @ 10,954' to isolate Bench #5. Pulled dwn. well on gas lift for 500 psi neg. diff. RIH w/ 3 3/8" Hyperjet II csg. gun & diff. perf. Hemlock Bench #4 from 10,9 11u 10,936' @ 4 hpf. 'RD Schl. Released rig crews @ 6:00 pm, 7/7/75 while production testing & evaluating TBUS G-22. Pro. duction tested Bench #4 perfs. @ 96 bbls w/ 40% cut. RU Schl. RIH w/ 3 3/8" Hyperjet II csg. gun & diff. perf. Hemlock Bench '#4 from 10 911'-1.0,936' '@ 4 hpf. Prod tested Bench #4 @ 96 bbls/day w/40% cut RIH w/ 3 3/8" Hyperjet II csg. gun & diff. perf. Bench #4 from 10,886'-10,911' @ 4 hpf. Prod. tested Bench #4 perfs, from 10,886'-10,93'6' for 12 hrs. @ an average rate of 98 bbls/day w/ 30% cut. Ran BHP build,up Bench #4 press-2723 psi after 48 hrs. RU Schl. RIH w/ 3 3/8" Hyperjet II csg. gun. Perf. Bench #2 from 10,670'-10,700'. Prod. tested for 13 hrs. @ an average rate of 2880 BPD w/0.7% cut. Ran press, build-up survey (14 hrs.) BHP on Benches #2 & #4 - 2720 psi. RU Schl. & ran 3 3/8" Hyperjet II csg. gun. Perf. ~ upper interval of Bench #4 from 10,8'32'-10,86.2' .@ 4 hpf & Bench #3 from 10,768'-10,788'. ' Flowed well.to clean upl perfs. Rate-4000 BPD w/ 0.8% cut. Ran 3 3/8" Hyperjet.II csg. gun & diff. perf. Hemlock Bench #1 from 10,602'-10,622' w/ "4 hpf. Produced well @ 4320 BPD w/ 0.1.% cut. Ran & set ball valve in ball valve nipple. Put well on production test. RELEASED RIG @ 12:00 MIDNITE, ?/18/75. FINAL REPORT ,,, hereby c~rI~[~{~at the.~ore~otn~ .~ ~e ~ ~ ~.~.//~~C~~/~~ Dist. Drlg. Sup.}~_. n~. 8/10/75 imlll ii i i NOTE ~ROl)ort on this form is rscluired for ,eec~ colsndor month~ regardless of the stotus of operotion~, o~d must be flied in duplicate with the oil end gas conservation committee by the 15th of the sueceedin9 moth. unle~ Otherwise directed. . Form P--.7 ... ,,~' . .... SUBMIT IN DUY~ STATE OF ALASKA ',See other st ructions on reverse side~ OK AN~ OAS CONSeRVAtION I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* 1,. TYPE OF WELL: OiLWELL ~ ~ASW,LL ~ D,, ~ Other b. TYPE OF COMPLE~ON: W~LL OrBS ~ nAe~ n~SVR. Other 2. NAIqE OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, Alaksa 99501 ,i. Z. OC~TZON OF w~LL (Report location clearly and in accordance with any $tate requirements)* At~.~c, Conductor ~1, Leg. ~3, 1798'N & 1413'W of SE corner. s, tio zg: T,N. At top prod. interval reported below 4093'S & ~5 of surface loc. or 2295'S & 1697'E of NW corner. Section 32: TgN, R1BW. S .M At total dep~ 4355'S & 2356'W of surface loc. or 2557'S & 1466'E of 5. AP1 NUMF.~CAL CODE 50-133-202~ -- 18. UNIT,FAlllVI OR L,g~SE NAME Trading Bay Unit 9. WELL NO. state G-ZZ (lZ-3Z) 10. F~ AND POOL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 32: T9N, RllW,S 12. P~%IVIIT NO. NW corner. Section 32: T9N, R13W, S. M. ~.-.vA~oNs D I 75-- 16 · 13' DA'TE SPLTD'DED 114' DA'TE ~:D"RF-~CI-IF-~D'[15' DATE CO'IVIP STJSP CIR AI~D"3/4/75 6/18/75 [ 7/18/75 ii,.. RT 99' above( 'F' I{KB' RT' GR' ~C) '17' ELEY' CASlNGHEADMsL ', 18. TOTAL DEPTH, IViD & TVD[19. PLUG, BA,CK MD & TVD . I~ 1V~t,TLT~PLE COM~PL., 21. INTERVALS DRILLED BY .[ I-~OW MA~Y*' ROTARY TOOLS ' CABLE TOOLS 11 .3'~5' , 11,253'+ TMD 0-11,335' ' 99.. PR6DUCING INTERVAL(S), O.F TI-IlS CO~PLETIO~---TOP, BOTTOM, NA1VIE (MrD AND TVD)' 23. WA~S DIREC-'TIONA.L SURVEY il/fADE Hemlock: 10,602'-.10,936'MD (9343'-9635'TVD) . Yes 24. TYPE F_J_,ECTRIC AND OTH. I~ LOGS RUN DIL-SP~ CNL-FDC.-GR & CBL CASING RECORD (Report all strifes set in well) CA, SING SIZE WEIGHT, HOLE SIZE 20" CFAL~. N'TING RECOB,D I AIVIOIJNT PULLED 26. LINFJ{ R~CO,I%D 27. TUBING R~OOI~D 28. PERFORATIONS OPEN ~ PRODU~o~m (In~rv~ ~ze and number) . ' ' 11,145'-11,115'~3 3/8" 'csg, gun ~ 4 hpf ~o. ~CID, SHOT, F~CTU~,C~:NTS~U~ZE,~C. 10,985'-11,022'~isolated by p~r. w/plug 10,886'-10,936') 10,940' Iu ~09 Iu '~?'"~-'"'-"t-""-10'832'-10'862'~3 3/8" csg. gun $ 4 hpf ~n_q9n,-!n. .q92'[, !on'sx_ C]a~ "~,, cit.. PRODUCTION 'DATE FIRST PI%ODUCTION I' PP, ODUCT1ON METHOD (Flowing, gas lilt, pumping--size and type of pump) 7/8/75 [ Gas lift DSTE OF TEST, [HOURS TF_~TED '[CItOlfE SIZE [~OD'N FOR OI~EL. ! I . l~S'r 7/1R/7~ , I 12 'i I ~ I' 2002 ~OW~ ~B~NG ~S~G P~SU~ [CAL~~ OI~BBL. ~ss.. I ' ' [~-sou~ ~ 4 ' Gas lift 180[ 1020 ] -' > [4004 [ 979 WELL .STATUS (Producing or ~'~'~{, Producin~ S2. 'LIST 0~' ATTACHMENTS , . "' 33. I hereb~ certify that the-foregoing and attached information is complete and correct as determined from alFavailable records . *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc production from more than one inlerval zone (multiple completion), so state in item 20, and in item 22 show the prc-Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, show- ing the additional data pertinent to such interval. Itmn26:. "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the Io~ation of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. i{U1VIMAI{Y Oie I{'ORI~YAT|ON T{{'-~T$ 1NCLUI~IN(; INTERVAL T~TED. PH~UR~ DATA ~'~Ov~I~ OF OIL'. OAS. 35. G~GIC MARK~ WA~ AND MUD , *~28. Perforations Open to Producfion: 10,685~-10,788~ { . 10,602~_10,622~ 3 3/8" csg. gun ~ 4 hpf. - . ,~-. --'- - . .- . ---* ~ ~ . ~ ..... ~ ..... ~ ~' ~ ~';5' ...~ .'. ~ .... , "-': "' -- -i ". .. . ,- (' ..'~ -"- .... '- :"- - -1 i~ ' '- ~ .... '" - - -- ' ' ' ' ~ ' ' -' . ~ - : ' - - --- '. . ,, , ............... ~ -, .... : ....... , -. SH.:/:ET PAGE ~,., ~e,,, Trading Bay Unit Sta.'.eViELL NO. G-22 ":'I r-: !,D. __Mr.~&r_t kur_ gLv_e r ._ _F.'2e kd i.OCATION_gond_u_cjor #1, Leg_R_m. #3, ._ 1798'N '' ' Section 29: T9N. RI'3~__S_, M. -.-,--, - · v · ADL-17594 P,~,~MIi' NO. 75-16 __S._RL~L NO. SPUD DAT2: 3/4/75 COMP. COiqTi{ACTOR_~P_~rlcmr_ D i_~tlin~__C_o. RIG FrO. 54 ..... ~yp.,' '~' UNIT_N_ational 1320 DRILL P1PE DESCRIPTION 5~"-pr~ad.e [, G & $-135. .......... H o_v~ - W_a_t e. ~.. ELF, VATIONS: WATER DEFriI 125.00 R.T. TO OCEAN FLOOR 235~'60 -R.T. TO MLLW 110.60 _. T.D.____I. 1 ~335' 'f.V.D.--- 9990' 11. T..T4~ DRILL DEC~ 19,30 *~.Ex -XTIO:.,' B 'q L 4925 10' ' ~_.,., II: ' ( .... ) -- '---' - R.T. TO Pn~DUCT!O2.4 '~t¢, 42 COMPANY ENGINEER Hess-Wes_ter~l'SLatson APPIIOVED: .~_///~oo/(~.( _~[.~t.,~ ~f'.~,.,x.~ _ ,_._ · ' ' '-m: C,u.,~,-IG ~.~ TUBING RECORD SIZE : ¥[E.IG.'riT I 20" ] 94# 13 3/8 ~61,~, 68J_. B~ttr_e_sas_~ 9 5 / 8"., 47~,. I Buttress · ~ I i 1 t GRAD}] H-40 K-§5 N-_80 ,P-I!0 U.q$-9 r-L DEPTH [ RE~.!ARKS 629' Refer to Report #2, 315/75 f_or_ daily d_e__ta3l_. 5,548'! Refor__to_l:Lapo~t #]3; 3/16/_75 for d~i]v detail, 11:335'1 Refer to Report_#76, 6/2.0/75 for dail(: cletai]~ PERFORATING RECORD 5/22/75 i 11,081-11,082 } 11,253'FC lBlo~qz.%Dlock Sqz. ~k~~Benches ~ ~6, )/23/75 J ~+30B-10 710J 11_25q'FC JWSO J Wg~qz; (lflfl ' [- : I ' - I I Hemlock ~-~c~--~2T 5/24/75 ] 10,590-10,592 [ 11,253'FG [Isolation [ Hemlock Bench ~1 - Isolation sqz. ']3/75 [ .11-115-~!.,}4~[ 11,~53'FC [Production [Hem]ock Bench '/4/75 [ 10,984-11,022 [ 11,253~FG ]Production [ Hemtock Bench ~5 - P~oducfion (4 '/7/75 f 10,936-10,911 i 11,253'FC -[Production [ Hemlock Bench ~.4 ProductiOn (4 h~f~. . ~/11/75 j 10,911-10,936 I 11,253'EC ]Production [ Hemlock Bench ~4 - Produc6on (4 hpf) '/11/75 ~i0,886-10,911 [ 11,253'FC ~Production '[ Hemlock Bench ~4- Production (4 hpf). ~]14/'15 1~,685-10,700 i ~,~b3'FG IProduction ~ Hemlock Bench ~2 - Production-top 15' misfired_~ '/)5/75 ~,670-10,700_~~EC ]Production ! Hemlock ~nch '/16/75'. j10.832-10,862 [ 11,253'FG JProduction [ Hemlock Bench ~4 -.Production (4 hpf). 18/75 [10,602-10,622 ~ 11 253'FC Production [ Hemlock Bench gl - Productinn (4 huf) I I DATE [ I:I'TERVAL 7_/1S!75{ TYPE: Cameron INITIAL PRODUCTIO.*'I NET OIL i CUT ]' GRg. V.', C.P. ~ T.P. I i 4012I~! a4,z?-]o2o! ~_an I I I I. I I i I I i ?._;c.?' .. 954 X~K_L L_ F,_E AD_A.S ;3_?.'~,I B. LY ! - 238 !' CASING HEAD: Cameron WF 20" 2M X 20" slip on w/ two 2 LP oulets. . CASING HANGER:--Slip & seal assy. CA 12 X 9 5/8"OD incl. Cameron type WF 20" 21%-{ WP X 12" X 3M WP X btm. prep. w/ two 2" X 5.\I %VP CASING SPOOL: flanK.ed outlets w/ I 1/2" VR fl~d, incl, · TUBING HEAD:_ Cameron DC-B 12"-X 31%4 wP x 10"-x 5M WP.w/ 2 5M WP stud outlet ihcl. TUBING IIANGER: Cameron 4 1/2" xv/ 4 1/2" DSS-HT Atlas Bradford thread top & btm-. TUBING IIEAD TOP' 10" X 5M WP Cameron btm. flange 5M w/ 7"OD seal-picker, sgl. string solid block log type MASTER VALVI;:S:___~/- 4 1/fl" bome~ CIt R !STMAS TIIEE TOP C()NN.:__4._i/_2'_:_EUE-Sr~zL~ -- A Division of HALLIBURTON Company 2400 West Loop South, P. 0 Box 22005 Houston, Texas 77027 A/C 713 622-5555 WELL DATA SUMMARY P--D M PANY UNION OIL OF CALIFORNIA ADDRESS. 909 W. 0th Anchorages Alaska 99501 REPORT FnR MR. Callender WELL NAME & ND. G 22 CONTRACTOR Parker Drilling_ ADDRESS "~'-'~-FDRT FOR MR, FIELD McAt thur River -~TATE iCOUNTY I DESCRIPTION OF LOCATION Alaska ' ' ; Grayling Platform IMnD WAR EH OU-~ E PoD. no. 238pc WELL DATA DATE SPUDDED eSS. SIZE 3-5-75 20" FROM TO 0 - 629 ' ~DTAL DEPTH 11~335' P-SO. SIZE FROM TD O.D. 13 3/8" 0 - 5548' DATE TD REACHED 6-19-75 TOTAL DaYS 72 ~.s~. SiZE FROM TO 9 5/8" a.D. 0 - 11335' DSG. SIZE FROM TO O.D. HOLE SIZE 26" HOLE SIZE 17 ~ HOLE SIZE 13 i HOLE. SIZE FROM 3~ 0 --- 629 FROM TO 629 ' -- 5548 ' FROM TO 5548' -- 11335' FRO~ TO Bi'rs: NUMBER AND SIZE 2..u.__ -.._.'.z_ '.o_:.~ ___r( ~_ ': ~ .... i_.'_z_.~_.L .......... ~4UD UP DEPTHS 629' - 11335' XC Po_lymer TYPE MUD IMCO XC POLYMER~ Sea Water OOMMENTS .,~ 1 It Drilled out of 20" (629') with XC Polymer to 5548' with l~ with no problems. Drilled out' with XC Polymer with 12¼" hole to 11336'. Hole in very poor condition. Stuck pipe coming out of the hole for bit at 11336'. Drill pipe parted. Redrill kicked off 5-22-75. Drilled to 11335' with no hole problems. TD & run Csg (9 5/8") 9-21-75. _.- . _ . . .. _R a nd y_F~ e t c 13_e r/p z IMCO REPRESENTATIVE ff CO SERVECES A D~v:slon cf HALLIBURTON 2400 W(-,.,t lc)Dp Sou~h, P 0 J~rJu',lofl, T~g', 11027 A/C /13 RECOR'3 OF DRILLING ~'L~i) TESTS CASING HOLE S:ZE 20" @ 629 26" IMCOREPRESENIAIIVE Adams, Watson ~.._Fle. tcher 13 3.~-.f 5550--1-~r C~. IMCO XC POLYMER @ TYPE MUD O~ PT~4 -, 981 1906 8 2014 2125 2674 3274 4O8O 4242 4800 4992 55S0 5550 5548 5548 5760 6000 i6382 6382 20 J6893 '~ 7 9 10 70 71 70 70 72 72 71 71 71 70 72 74+ 75 76 75 75 77 72 72 70 70 70 71 73+ 72 71 72 50 ,, 17 '73 42 j l0 40 44 38 44 45 47 3.3 43 13 44 14 38 10 14 10 20 18 16 28 17 NO. BITS 4 8 4 .. 16j 8. 241 8 14i 8 ........ 151 0 15ll 11.84 1.0 cOMPANy .... U~T[ON OIL OF WELL NAME & NO. G 2~ --NOms'IX'JWELLJ STAT~ t COUNTY J j j . 'J J J J J J jWEtL J_ S/T FIELD COUNTY STAT~' ~'-'~' McArthur River Alaska .. CONTRACTOR Sec. ITl . ~Parker DrillingJ'J. SALT ('l'4t O ~il)[ CALCIUM WATER MIET~,. *w~ II, LUll[ I,i,m :ON SAND SOLIDS OIL ( ON tENT .,,,.., ,. ..... . ..... , [6~-6 -i2o 2 1 ~ ~'-. ~. ~' 24 ~000 120 1 15 .26/5.8 24 )000 160 2.5 7 j ~000 160 2.5 8' , 24 )000 120 1 8 .44/2.2 J I000 160 1/2 6 1 .44/2.2 I )000 180 1/2 6 o42/1.8 j 24 )000 160 I 11 i 25 ~000 180 1/4 7 25 lO00 150 1/2 8 .4/3 )000 180 1/2 8 .34/~ j 24 ~000 240 i' 9 .4/~ 5I ~000 240 1 7 .42/~:3 , F JO00 240 1 9 I.46/.j2:1 iL 1!23' JO00 160 1 6 [ .49/1 6 I ; 28 t000 240 1 6 i .5/,1.4 i 26 i000 140 2 10 .56/11.3 30 iO00 80 3/4 ~ i ., '30 1000 80 2 8 .45/2.6 30 i000 80 1 14 , .54/~1 5 ~ 30 ooo iO00, 160' 13 .41/~ 8 J 27 'ooo ~oo ~. ~ ~/~ ~ so i000 200 1 8 :39/;3:3 ~000 80 Tr 8' 28/ ~000 80 1/2 6 ~000 80 3/4 8 J27 ~000 80 1/2 8 , .66/~056 I i 27 !000: Nil 3/4 9 , .64~.44 i 24 ~000i 60 3/4 11 .4.8~1.55~i 24 1000J 80 3/4 10 I .54~.45 i 24 ,oooI 80 ij ,O00j 120 10 .46/2.6 ~ 24 0001120 1/4 11 [ .45/f.6 i24. NO. DaY: J13 114 13 13 SERI [ ES A D,v~,lor~ oi HALLIBUR1()t',I ( 2400 We~t Loop South. P .q I:',, 2/605 Hou~lun, Texu~ 11021 A/(. /13 /,~)' CASING RECORD OF DRILLING ~'¢LIJD TESTS HOLF SIZE NO, BITS NO. DAYS IMCO REPRESENTATIVE TYPE MUD !DATI~ J ...s. ! Gl , 23 DE PTN 7073 7434 7434 7559 7758 7758 7841 7841 7940 8024 8024 8175 8240 8240 8403 8596 8596 8962 8962 9364 9592 9.689 I°~-0?I wi r..]. 7 7 7 7 7 7 7 7 7 7 7 7 7 7 Jcu It 3 3' 3 3+ 1 l+ 1+ 3 3 1+ 73+ 74 73 72+ 73 72 72 71 72 ?1 71' 71 71 71 71 71 71 71 71 52 42 44 44 43 4O 43 43 42 43 43 42 43 43 42 40 39 16 11 14 13 ll 14 15 10 14 13 12 12 11 13 12 11 13' 13 12 10 11 11 11 12 11 11 11 11 11 10 5 ALKALINIT~ 2 2 2 2 2 2 2 2 2 22 2 18 2 20 2 23 2 21 J 2 20 6 '9o0 2 22 6 1590 2 20 9 1~ 2 20. 516,I 90 2 20 ~ 1~ 9.5 2 .... J .... i , . ,,,,, j:... l! ,. ill. i,. , I .... i. r . '.1' . '. .... ,.. ,.. , ! ,I I1,~ , ,,I,., ~ '~ , . ~; ....I ..... , ,~ · , · ! . ~ ! , ,',ll,'l !.1! .JiLl ~,ll'l I'J'"', Jt,','., ((, ,1., I)l i,)J)l 11'.4' . III'.HJliIi,I JlllllJ JJJ(' tl'.l' &pJ ',fbi's' COMPANY Page 2 UNION OTL OF CALIFORNIA WELL NAME & NO, G 22 W~LL NO, FI[LD COUNTY McA~thur River CON fRACTOR Sec. Parker Drilling' !,OIlDS VOl 8O 8O 8O 8O 8O 8O 8O 80 80 80 · 80 80 120 '80 80 80 80 80 80 11 12 11 -~/3 :443.6 4~/2 i4~/2 4~/2 °38/4 .4~/2 o 4~/2 . ~/3 .4~/1 .4~1/1 .4~/2 .3~',/4 , .~/3 .3~/3 .4~. .4~/~ .44/2 .4~/~ .4~/2 ~/2 42/2 STATE Alaska M£THYtENI: ~LUE Ib'Jbbl 24 27 25 ~5 27 27 27 ~5 25 25 25 26 ~6' 25 27 2~ 2.7~ A D,v,',mr, of HAIIIBIJRIf)ti r,,. p,my 2400 W.,,I Houston. Texos 77027 A/C 113 672 5555 IMCO REPRESENTATIVE TYPE MUD 4/ 1 D[ PTH 10313 10414 10424 10438 10560 10748 L0900 L!073 11211 1,336 8 ~1336 [1.1336 9 ~[133 6 [1336 [1336 10 L1336 L1336 12 [1336 [1336 13 565O 5650 5650 14 71 71 7 + 7 .+ 7 + 715+ 7 + 7 + 715 7 75 76 75 75 75 75 71 72 74 72+ 73 + 7g 74 72 71+ 72 38 40 38 48 50 50 55 43 45 11 14 12 18 17 17 17 14 RECORD OF DRILLING t%IiUD TESTS CASING HOLE 31ZE NO, BITS NO. DAYS A~I(ALINII~' 1617 5 8275 18 121 23 2O , 23 119 9.0 8.~ ]6 ].~J 9.0 I 8.81 ~~ . 16 ~j 9.5 / 8.8. z J. ~ .~ .... ~ ,, . I, ~ ,~ ., .... i , ,, '... ,,' , . ' ,. i ', ..... '. ,, ~ i .... v,, . I,.'.. ,.'.1 ~,~ ~.~. ,, ,,, ,,. ,.~l,mI ~,,~,~ I!. ~,., ~1 COMPANY Page 3 UNION OIL OF CALIFORNIA WELL NAME & NO. G 22 APl WELL NO. F'IfLD ou.f I 1s,, _E_Lii~L-_.E_I-I ! I I I 1 C(,)U N IY STATE McAr~hur River t ()N1RACtL)~ I Sec Paz'ker Drilling j '" ..... ' T'~'''~ ......WATER ,4 ~/~. 8 ~ 42[/2' ~ 44~2.~ 44~2 42/2 5 38~3 42~2 ~ 4272 .42~2,7 4/~ 56~.4 55f1~3 54~1 4 00 O0 O0 Alaska : i' l _1 METHYLI:NE IILUE mP/r,'~l 58/. o 687. 7/L2 ,5;L7' 5 .5471.3 .51fl. 5 1 3 25 26 25 27 27 33 33 34 34 36 36 36+ 37 37 37 36 37 36 43 45, 48 47 45 24 27 27 25+ 27 24" 24' ( ( IMCO REPRESENTATIVE TYPE MUD :' 75 4/15 16 5/22 23 25 26' 27 28 29 30 i6I 1 ., 2 7236 On or out o 5553 5553 5600 5614 5664 5672 5721 5935 6153 6153 6401 6521 6756 6901 7101 7164 7420 7549 7852 7960 8045 fi:riCO SER,V[CES D,wS,On Of HAI. LISURII'JN rexes 17021 A/(. / I .~ t,;,7 ',555 CASING RECORD OF DRILLING MLID TESTS HOLE 51] E NO. BITS NO. DAYS 73 75 8684 No c 8701 8803 71 71 71 71 71 71 71 71 71 70 71 73 irc n 73 73 43 45 47 4~ud 46 47 51. 18" 15 13 15 16 12 12 15 11 12 ck 13 1,2 ALKALINITY 19 21 25 22 25 21 ~4 9 0 9 0 2 1.0 rille!d t~o ! sho,~, 1 ;1/64 36 !1/64 :;1/64 26, il/64 28 ~1/'64 ~/'64 1/64 28 1/64 1/64 !1/64 28 1/64 1/64 L0.5 23 ~1'/64 L0.5 1/64 L0.5 23 1/64 ~0.5 !/32 10.0 25 '.11i 2~ 9.5 22 I ' i , ' ,, i ' ' .... I ' I I I , I I~ : ' ' ;lr i I jI Il ' ,] ', ,~ : il ' : Ill~ ;~/1111 [ 'l lis lIT: I I I Illl ,, COMPANY UNION OIT. OF CAI.IFORNIA Page 4 WELL NAME & NO. G 22 APl WELL NO. FIELD I I I l_ I I I'-YI COUNTY STATE McArthur River CONTRACTOR Parker Drilling Alaska BLUE drill p~pe whl~.le t 15-22-!75. G-2~ on[ o48~3'9 4Wz 45~ 5~ 39/3 2 34~3 2 39~3.4 3~/3;2 4~1.8 .4~/2.2 4~/2.3 4~/. 3 8 .~/1.~ .4 /3.o rippi 24 27 27 27 12 12 12 19.5 26 24 22 22 22 24 24 IMCO REPRESENTATIVE TYPE/',iUD $/ 6/ 10 11 12 13 14 NOTIC£: . . 8875 8942 Ream 9008 9112 9205 9240 9379 9539 Ream 9550 9585 9660 9719 9740 9771 9800 9977 [0004 L0105 10147 10222 10324 [0384 10427 10485 10553 !10648 ?44 7 74 7 75 75 75+ 75+ 75 75+ 7 + 73.~ 74 74 7 72+ 72 73 '73 72 72 72 72+ 72+ 62 58 16 8 19 7 18 16 15 16 2' 15 REcoR'Ii:, i)1 DRILLING AA, UI) TESTS CASING HOLE .c:ZE NO. BITS NO. DAYS ALKALINITY ~":i'i':'}'''NY ', . Page' '5 UNION OIT. OF CAL:i"TORIq'IA WELL NAME & NO. '*""---': ....... G 22 WEL~ J '."ELL .... FIELD COUNTY ST,~,.~ .E CONTRACTOR R I Parker Drilling 27 24 32 34 27 23 27 28 27 25 7 27 36 10 38 34 12 41 2819 33 30 ~0 33 24 9. 9. 10 22.5 10 10 9 22 :tO 12 11 23 8~ 10 22 9 9222 9. 22.4 8. 11 ~ 9,, 1~ 8 22 2 9.5~ 10o6 24 '9.51 9.8 23.4 8{ 8{ 8( 8~ 8~ 8( 000 500 ~4000I ' i ' I l 80 80 80 80 80 80 80 80 20 80 80 80 80 1/2 1/2 3/4 1/2 1/2 1/2 o3g/. 4 4o/2.~ 4~/2.1j 5!/1o 7 2 7 4 8 3,2 ' Z~ 21 23 24 24 26 26+ 26 24 24+ 24+ 24+ 24+ 24+ 24+ 24 24 27 24+ 24 25 25 24 25 24+ 25' '25 A D~w:,.or~ of HALLIBIJP. t¢)N ",.. ;,'my ?.100 West loop South. P Houslon. Texas 7~027 A/C / IMCO REPRESENTATIVE TYPE MUD DAT~ D[ PTH ,, 7,5 6/15 10700 ~0796 0863 17 ~1088 F~o8 ~o~ 18 11~1~ 19 1~335 NO r15[: .... ' ' . · . :.. ~ , ~ .... . ,.. ..t.,.... ~,;~.... ,.,.. ,'., .... . , ~ CASING · .. RECORD OF '".".'.. DRILLING ,r/1,1JD TESTS HOL[ SI 7_E I 9,0.0! ]' 19.8 NO. BITS NO. DAYS ALKALINITY 45 ~0 22° Oi 36I1 5 t'1 'COMPANY " UNION OIL OF CALIFORNIA WELL NAMIi & NO. Page 6 G 22 WELL NO. FIELD COUNTY McArthur River co~ ] ,~;,: l ~ STATE CONTRACTOR Parker Drilling 11 11 11 10 3/4 1/2 1/2 3/4 1/4 3/4 1/2 801 - 80 1/2 801 ]./2 80 8o 1/2 8ol 100 3/4 Alaska '['-'L~, .... R i ~..,~.,,, ~/s.o 4~/9.. 9. 4/] 3.4 4/13.4 41/2'2 41~/4o 55 4/~4.3 22 24 26 2.~: 24 24, 26 26 . ,,, CODE ) OIL COMPANY /~,/)l'~)/.] ~.l'/~ (~ LEASE/WELL I'i0.,-7-.,~)1).~ ('~-~..,-~.,. FLD./TOWN ,?,/'J ,,O /c" -.,m",~,/,,E'7' TOOL ' ' ¢ ' ' ' P-U-~-.IJ-ER :: ~-~---~' "~,./-'-/~-..c'-~'.~.z"'-~'.-"/-'~'-~/-,,D.,.R.,_.~.A~:~!._~-_c.I_I=~.~_' DR G~'._~,/~'/'vJ ,~ ' DR. ~'~.-. }.,~ /,-~ ~' SEC/T'SHIP/ ._.-. ~ '; ~ ................... ._.~,..--:.-......:~:: .... ::~_'-.:~' ..: '.:.-'._~..,: -.~.-~ , ....- , . .... ~:-~.~.,,,:...~.~._~:--~:~. :~.,- ............. ~ ............. . MODEL : I · MAKE .., HAKE & MODEL i · ~'~ , RUN SIZEMAKE 'JETS.32ND BIT NO. ""~' ' SER. NO. DEPTH OUT RECORD NO., / sMEEr / NO.~-/.- SPUD DATE,, ''~' /''/' 7.,~'"' UNDER --.SURF' -- INTER T.D.., TOOL, d~ / ~o · //..//..~..~, O.D. , . DRILL COLLARS: NO. '~O,D ..... I.O 25 LENGTH ~0 DRILL COLLARS: NO.~ : 0 O----. I.D ~~ NO, I MUD DULL COND. f~ ~ . I / ? '/L. /~ rc ,~ /?)'z ? 12'-/7 Po '70 OF BIT CONDITION DEGREE OF TOOTH DULLNESS NEW TI TI T1 14 "A TS T6 17 TS ... HOW' TO REPORT BIT WEAR IN EIGHTHSi TOOTH DULLNESS {general exarn;notion) TI . . . tooth helgh! 1/8 gone T2 . o . toad~ height 1/4 gone · T3 . , . tooth height 3/8 gone T4 .... tooth helght 1/2 T5 ... tooth he;ght 5/8 gone T6 . . . ~oo:h he;ght 314 gone 17 . . . too:h height 7/8 gone T8 . . . tooth height all gone NOTE: If cny one row has a majority of teeth broken, add fhe letters "BT" BEARING CONDITION {/~ec~: the worst cone) BI . . . bearing life used: 1/B B2... bearing life reed: 1/4 83 . . . bearing fife ·used: 3/8' (medium) beor;ng l;[e used: ~/8 B6 . . . ~ecr;ng life ~ed: B7 . . . bear;nB fife reed: 7/8 B8... beefing life oll '' ~oc~ed or lost) BIT GAGE . !... ;n gage O ...out of gage ~NOTE: If out of gage, follow the "O" ~tK t~e ~mount out of DoSe in frac- S;cns of cn Example ~1 . . . T2.B4.1 (Teel~ 1/4 . ~ · ~earT~g medium, bit in gage) Example ~'2 . . . T6BT-B6.0 1/2 (Teelh 3/4 gone. BroLen teeth, beer;nfl ohd bit out of gage 1/2 , Lc, I o I L E:NGTI,~ . REMAR)~$ ( FAILURE. t,4UO. ETC.) · . .) p CODE OF BIT CONDITION DEGREE OF TOOTH DULLNESS HEW' . T! 12 T3 T4 :...' TS T6 TI TI ..: HOW TO REPORT BIT WEAR IN EIGHTHS TOOTH DULLN[$$ too~h he;ght 1/8 tooth height 1/4 gone T4 teeth hr;gM !/2 gone T6 loath he;ghl 3/4 gone ' T7 tooth height 7/8 gone T8 tooth hc;ght all gone NOTE~ I~ en~ one ~ow ha~ a ~EA~ING CONDITION / ~..~o ~. o RIG NO ..... ,~' // BIT RECORD ~" "T" s~,. ,o. out ~.. - / ,~ ~ ~ -~ ,"r~ .... I )~l 0 ~~ ,7 .... ~ ,./ I .- .. .~__ .~ - _ . :.. ,~ ..... ACCUM WT, V£RT, PUMP NO I NO 2 ~U° DULl. CO*e. RE'MARKS tou"s .ou,s 'ooo La. OZv. PnCSS. --[~W ZT~"{E~'rG~. ' [~"r .... ~i~-'"~"-["~ (rAJLU,C. ,ua. CRC.) =~.. ~: ................................................................................ ,~ c,.~ ~ .......................... '] Il 'i ..~ o · ".//~ //~,'~ 7~ /;~ ,.,...~'' ~'~,~*~'/4 .,.... /,. ~,r ~C'/ .~ ~"~' ->'~..~..~/~.Z --~ .~: ......... , , '~/;~Io~q 7'~ ,/~ '~/ ,r,~o ./~.~ ,, ~.-,u' &...., z .... ...... .,..~.._, ,/~ ~/, ~, , ....... '~ ..,~ __~ ....................... ~ ~ · /o 1}9 1~ z~o , l.~O~ ~, ~ ~ _ ~, " 7~ 4~ ~ 5 o ~.,~'~.~'4 ..... ' I~/ . ox ~ ~ ~ ~ ,'~* ~ ~.~.~ '~.'~ :' ", .Z(_./* --- ~ _,,~ x ~/~ ...... /-' z _) ~.S F~ . ,., -" , ............. /%/ I_r ~ ~ .~/3 t,~ .g,u ~ ,..?/~0 -/6 4(t /, ~,/ .,.4~,.," ~ ~.~ ........... ~. /~.._z//~. , , 1 ~l~ ~ , ~ ' ~. g. /~. BI . . .beodng I;fe u~ed: I/1~ 63 , . . beorlng I;fe 'used~ 3/8' B4 . . . bee,lng I;fe useds !12 (medium) B5 . . . beg,lng I;fe u~edt 518 B6 . . . bearing llfe u~ed: 3/4 B7 . . . bearing llfe V~ed~ (l~c~,d or BIJ GAG~ (NOTE~ If out of ~age, follow IRe "0'" with Ihe amount gui Gf gage Iff true. ~e. b~or;ng mod;urn, bit In [,omple ~2 .... T6E?.B6.B ~/2 o~d bh out of gogc 1/2 19~) ". .. UNION 0IL CaiPt ,tY OF CALIFOP IA ICCORD PAGE lb,2 LF. E TRADING BAY UNIT STATE I' _LL [!0, G- 2 FIELD ARrHUR RIVER FIELD DATE 1 3/4/75 2 3/5/75 3 31517= 4 3/7/75 5 3/8/75 6 3/9/75 ETD 645'TD 645'TD 579 'ETD (FC) 1926'TD 2108'TD 2674'TD DETAILS OF OPEP~TIONS, DESCRIPTIONS g RESULTS (Footage 645') Commenced operations on TBUS G-22 0' 12:01 am, 3/4/75. Skidded rig over Conductor #1, Leg Rm. #3. Installed'· 26': riser & CO fill & cmt. in conductor from 299'-360'. Spudded well @ 12:00 Noon, 3/4/75. Drilled 17 1/2" hole to 645'. Surveys: 412' 1/4° 513' 1/4° 645' 1/2° (Footage 0') RIH w/ 23" hole opener. Opened 17 1/2" hole to 23" to 636'. Circ. hole clean. Made wiper trip. 'Pooh. RU & ran 20" 94#H-40 csg. to 629' w/ stab-inFC @579'. Landed 20" csg. on CIW flo-thru hgt. Ran 5" DP & stabbed into FC @ 579'. Circ. hole clean. Pumped 200 cu, ft, caustic wtr. Mixed & pumped 461 sx. (895 cu. ft.) Class "G" cmt. w/ 2 1/2% prehydrated gel & 2% CaC12 followed by 200 sx. (230 cu. ft.) Class "G" cmt. w/ 3% CaC12 . Good cmt. returns to surface, Pulled out of stab-in collar. Float held-ok. Pooh w/ 5" DP. Removed 26" riser, Skidded rig to TBUS G-23 for perforating of ' Hemlock Bench #5. v-'u~,~ ~Ju; ~..,uuuu ~- ,rum TBUS G-23 to TBL, 3 u~-_~., installed ~iW 20" 2M-MSP weld-on csg. hed. spool, installed 20" riser & 20" hydril. PU 17 1/2" bit & BHA. CO 20" conductor csg. to FC @ 579'. Tested 20" csg. &BOPE to 500 psi-ok. Drilled FC & 20' of firm cmt. Retested 20" csg. to 500 psi-ok. Drilled cmt. &FS @ 629'. Drilled 17 1/2" hole to KOP @ 981'. Circ. well clean. (Footage 945') Ran 17 1/2" bit on Dyna-drill to KOP @ 981'. Oriented Dyna-drill' Dyna-drilled & surveyed to 1247' (7 3/4°- S16W). Hole angle & direction - ok. Pooh. Ran 17 1/2" angle building assy. Drilled & surveyed to 1926'. (28-°- S32W). Hole turned 16° righe while building angle. Pooh. '(Footage 182') Ran 17 1/2" bi.t on Dyna-drill run #2. Oriented Dyna- 'drill @ 1926'. Dvna-drilled & surveyed, to 20701. (31°- S26W). 6° ]eft turn & 3° angle build. Pooh. Changed @its. (Footage 5.66') Ran 17 1/2" bit on Dyna-drill run #3. Oriented & Dyna-drilled to 2170'. (29°- S21W). Total 11° left turn. Hole angle & direction - ok. Pooh w/ Dyna-drill' Ran 17 1/2" bit on follow-up O assy. & drilled from 2170' to 2552' (33 - S16W). Hole angle & direction- ok. Got 8° left turn (S31W) & 3° right turn back (S16W) on follow-up run. Pooh w/ follow-up assy. Ran 17 1/2" bit on locked · 13HA. Drilled from 2552' to 2573'. Lost 500 psi pump press. Pooh. DP box had split & pin screwed through box 4 stds. below rotary. Changed out damaged DP. TIH toTD @2573'. Drilled to 2674:. DP torqued & backed off 22 jts. below rotary @720. Poohw/ DP. Picked up OS to catch 6 1/8" DP box looking up. UNIO[ OIL COFBA ,N OF CALIFORNIA {ECORD PAGE I'.b, 3 LEASE TRADING BAY UNIT STATE t'~L [10, G-22 FlED RIVER FIELD DATE - 7 3/10/75 8 3/11/75 9 3/12/75 10 3/13/75 11 3/14/75 12 3/15/75 13 3/16/75 ElD 3274'TD 4080'TD 4242'TD 5015"I"D 5548'TD 5548'TD 5548'TD DETAILS OF OPERATIONS, DESCRIPTIO.~IS & RESULTS · (Footage 600') Ran OS & latched top of fish @ 720'. Pooh. Rec. total fish. TIH. Broke out & redoped all tool jts. on drill string. Drilled from 2674' to 3226'. DP torqued & drive bushing jumped out of master bushing in rotary. DP backed off @ 482'. RaffOS & latched top of fish @482'. Pooh. Rec. total fish. TIH. Broke & redoped al].tooljts. Drilled from 3226' to 3228'. DP torqued & drive bushing jumped out of master bushing in rotary. DP backed off @ 887'. Ran OS & latched top of fish @ 887'. Pooh. Rec. total fish. Welded out lip on drive bushing pins & master bushing sockets for temp. repair. TIH. Drilled to 3274'. (Footage 806') Drilled 17 1/2" hole from 3274' to 3521'. Hole angle dropping slightly & turning left. Pooh for bit change. TIH w/ 17 1/2" . bit & locked BHA. Drilled from 3521' to 4080'. Hole direction turning slightly left. (Footage 162') Pooh. PU Dyna-drill on 17 1/2" bit. TIH. Oriented Dyna-drill for right turn. Dyna-drilled from 4080' to 4242'. Turned hole right from S12W to S20W. Pooh w/ Dyna-drill. Ran follow-up assy. (Footage 773') TIH w/ 17 1/2" foiio~v-up assy. Reamed Dyna-driii run. drillef from 4242' to 4993'. Got 6° right turn on follow-up run to S26W. Pooh. TIH w/ 17 1/2" locked BHA. Drilled 17 1/2" hole from 4993' to 1015'. (Footage 533') Drilled 17 1/2" hole to 5548'. Circ. hole clean. Dropped survey & Pooh. Hole cond. good. (Footage 0') RU Schlumberger & ran DIL-SP Log. Checked driller's' TD of 5548' @ 5549'WLM. Logged to surface. Ran CNL-FDC-GR Log from 5549' to surface. RD Schlumberger. Ran 17 1/2" bit to TD @ 5548'. Circ. & cond. hole to run-13 3/8" csg. Pooh. Hole cond. good. (Footage 0') RU & ran 136 jts. of 13 3/8" 61# & 68#K-55 Buttress Csg. set @TD 5548'. (FC @ 5465' - DV tool @273~"-)'. Circ. hole clear_. Pumped 200 cu. ft. caustic wtr. & 200 cu. ft. filtered lnlet,,vtr. Cmt:d btm. stagew/ 1450 sx. (2780 cu. ft.) Class "G" cmt. w/ 1%CFR-2, 2% CaC12 in 2-1/2% prehydrated gel mixing wtr. followed by 200 sx. (230 cu. ft.) Class "G" w/ 1%CFR-2 & 3%CaC12. Bumped plug w/ 2500 psi-float equipment held ok. Dropped opening bomb & opened ports in DV tool @2733' w/ 800 psi. Circ. out 260 sx. excess cmt. from above DV tool. Circ. well through DV tool ports @2733' while waiting on cmt. to be unloaded for top stage cmt. job. Released rig from TBUS G-22 @ 12:00 Midnite, 3/16/75. Skidded rig to TBUS G-23 for perforating @ 12:01 am, 3/17/75. UNIOI1 OIL COMP/ ,IY OF CALIFORNIA RECOi FAGE i",D, '~ LEASE TRADING BAY UNIT STATE I',~_LL II0, G-22 FIELD McARTHUR RIVER FIELD DATE ETD 3/17/75 14 9/18/75 16 3/20/75 17 3/21/75 18 3/22/75 19 3/23/75 20 3/24/75 5548"rD 7039'TD 7442'TD 7758'TD 7841'TD 8047'TD DETAILS OF OPERATIONS, DESCRIPTIOt.iS & RESULTS Unloaded cmt. for top stage of 13 3/8" csg. through DV tool @ 2733'. Pumped 200 cu. ft. causticwtr. Mixed &pumped ]_470 sx. (2822 cu. ft.) Class "G" cmt. w/ 1% CFR-2, 2% CaCi~ in 2 1/2% prehydrated gel mixing wtr. Followed lite xCate slurry w/ 200 sx. (230 cu. ft.) Class "G': w/ 1% CFR-2 & 3% CaC12. Displ. cmt, & clbsed ports in DV tool @ 2733: w/ 2500 psi-ok. No rig activity on TBUS G-22. Rig over TBUS G-23 for a 24 hr. period to perf. Hemlock Bench #5 from 11,700' to 11,730'. (Footage 225') Recommenced operations on TBUS G-22 @ 12' 01 am, 3/18/75. Removed 20" BOPE. Hung off 13 3/8" csg. Installed C!W 13 3/8" csg. hd. spool & tested to 3000 psi. Installed 12" 3M BOPE & tested to UOCO specs. RAn 12 1/4" bit. Drilled out stage cmt. collar 2733' & tested 13 3/8" csg. to 2500 psi - ok. Drilled out FC @ 5498' plus 20' cmt. Retested 13 3/8" csg. to 2500 psi-ok. Drilled cm.'.. & FS @5548'. Drilled to 5593'. Tested 13 3/8" csg. seat &tm. to .650 psi/f-_. equiv, to 94#/cu. ft. mud. Pooh w/ drill out assy. RU Sperry Sun & Go-Int'l. WL units. Ran Gyro-Survey from btm. of 13 3/8" csg. @ 55~'~'~ to surface. RD Go-Int'l. PU 12 1/4" tandem square drilling assy. TIH. Drilled to 5773', rt. ~,,, .... o 4') ~ ..... ~ 61 Drilled 12 1/4" drlg. assy. Lost 500 psi pump press. Pooh. Found washout in DP tuSe between slip area & box @ +_ 1500'. Pooh. Changed bits. 12 1/4" tandem square assy. Drilled from ,6101'-6387'. Pooh lc:- bit I '.~ change. (wtr. cooling line above electrical panels started lea:<-,_g on panels & caused shut-dwn, of 2 hrs.) (Footage 652') Completed bit trip @ 6387'. Drilled 12 1/4" hole w~ tandem square assy. to 7039'. Bit trip @6834'. (Footage 403') Drilled 12 1/4" hole w/ tandem square assy. fre:r.. 703? - 7135'. Hole turning left continuously @arate of 1/2°/100'. Reran 12 '"4' tandem assy, & drilled from 7135'-7359'. Hole turned 2° right -'.e S27W. Pooh. Laid dwn, square assy. TIH w/ 12 1/4;: cony. stab. ass'.', to follow up on right turn . Drilled 12 1/4'"'" ladle.from 7359'-7442'. (Footage 316') Drilled 12 1/4" hole from 7442'-7469'. Lost pump press. Pooh for washout. Found washout in DP tube 1' above pin @ 980'. TIH. Drilled 12 1/4" hole from 7469'-7580'. Ran survey. Hole turned 5° right to S32W. Pooh. Changed bits. Reran cony. stab. assr. w/ building hook-up. Drilled from 7580'-7758'. Ran survey. Hole direction had turned back 4° left to S28W. Pooh. (Footage 83') Picked up Dyna-drill &Sperry Sun Steering Too!. TIH. Oriented Dyna-drill @7758', Dyna-drilledfrom 7758' to 7841' Ran survey. Hole had turned right 7° on Dyna-drill run, Pooh w/ Sperry Sun Steering Tool. .~,, ) (Footage 206') Pooh w/ Dyna--drill @ 7841' (survey @ 781.0' S3~" . Ran 12 1/4" follow-up assy. Reamed Dyna-drill run. Drilled from 7841'-7995'. Ran survey @nWL. Hole had turned 7° right on follow- up toS42W. Drilled to 8047' &Pooh. - - UIqOl'1 OIL CQVPh'.h' OF. CALIFOP .IIA , IECOt LEASE TRADING. BAY UNIT STATE FIELD M'cARrHUR _RIVER FIELD BATE 21 3/25/75 22 3/26/75 23 3/27/75 24~ 3/28/75 __2~ 3/29/7~.~ 26 3/30/75 27 3/31/75 28 4/]./75 29 4/2/75 30 4/3/75 ETD 8250'TD 8615'TD 8963'TD 9370'TD 9596'TD- 9801'TD 10,110'TD ] 0,314'TD 10,428'TD 10,562'TD DETAILS OF OPERATIONS, DESCRIPTIOtlS & RESULTS (Footage 203') Pooh ~v/ folloxv-up assy. RIH w/ cony. packed stab. assy. w/ type 5-1-5 Insert Bit. Drilled 12 1/4" hole from 8047'-8177'. RU & ran WL survey. Hole angle had dr.opped 2° to 27°. Pooh. RIH w/ angle building assy. & type 5-1-5 Insert bit. Drilled 12 1/4" hole from 8177'-8250' . ' (Footage 365') Drilled & surveyed 12 1/4" hole w/ angle building assy. & type 5--1-5 bit from 8250'-8615' w/WL survey @8401'. Hole angle built 1 1/2° to 28 1/2° & turned right 2° to S49W. (Footage 348') Drilled 12 1/4" hole from 8615'-8772' w/ Insert type 5-1-5 bit. Hole direction turned right to S52W. Pooh. (inspected DP w/ hand guage while Pooh for suspected OD reduction) Found 8 its. necked dwn. in tube area above pin. Had suspected DP damage from back offs in 17 1/2" hole due to drive bushing junping out of master bushing. Remainer of DP inspected on beach. Picked up 12 1/4" tandem conv. stab. assy. TIH w/ Insert type 5-1-5 bit. Drilled & surveyed to 8963'. (Footage 407') Drilled & surveyed 12 1/4" hole to 9370'. Hole direction holding S52W & angle increasing +1°/100'. (Footage 226') Drilled & surveyed 12 1/4" hole to 950!'. Pooh. Changed bits & added 12 1/4" stab. to lock BHA. (repaired rotary table). TIH w/ 12 1/4" Insert type 5-1-5 bit. Found bridge @ 9338' while TIH. Reamed bridge & CO to TD @ 9501'. Drilled 12 1/4" hole to 9596'. (Footage 205') Drilled & surveyed 12 1/4" hole from 9501'-9801'. Lost 300 psi pump press. Pooh. Looking for washout. Hole tight from 7688'-7650'. Found washout in X-over sub between near bi~ & tandem stab. Laid dwn. cony. BHA. Picked up 12 1/4" tandeTM square BHA. TIH w/ 12 1/4" Insert type 5-1-5 bit. (Footage 309') TIH w/ 12 1/4" tandem square assr. Reamed square assy. to btm. @ 9801' Drilled 12 1/4:' hole to 10,1!0'. (Footage 204') Drilled 12 1/4" holew/ tandem squa'-,_'e assy. to 10,200'. Lost 700 psi pump press. Dropped survey &Pooh looking for washout. Found box on #2 steel DC cracked & washed out @ last engaged thread. Shifted stabilizer in BHA to give Might build on angle. TIH w/ tandem square building assy. on 12 1/4" Insert type 5-1-7 bit. Drilled 12 1/4" hole from 10,200'-10,314'. (Footage 114') Drilled 12 1/4" hole from 10,314' to 10,428' w/ tandem square building assy. Dropped.survey. Pooh for bit change. Pulled intokeyseat @8899'. Worked pipe. Low clutch failed while working pipe. Dwn. 3 hrs. for rig repairs. Worked pipe dwn. thru tight spot @ 8899'. (Footage 134') Pooh to btm. of 13 3/8" csg. Shut-dwn. & repaired wtr. leak on brake drum jacket. Completed. Pooh. Changed out pads on square stabs.. No survey (film would not develop). TIt{ w/ mill tooth bit. Reamed section from 7700'-8900'. Completed TIH toTD @ ].0,428'. Drilled 12 ]./4" hole to 10,562'. Dropped st, rvey & Pooh. LEASE UNIOI1 OIL OF CALIFOPC. IA IECORD TRADING BAY UNIT STATE It, LL [10, G-22 FIELD PAGE N0, 6 McARTHUR RIVER FIELD DATE 31 4/4/75 32 4/5/75 33 4/6/75 34 4/7/75 35 4/8/75 ...... 9/75 60. '-~i 37 4/10/75 38 4/11/75 ETD 10,748'TD 10,926'TD 11,075'TD 11,336'TD 11,336'TD 11,336'TD 11,336'TD DETAI-LS OF OPEPATIONS, DESCRIPTIONS g RESULTS (Footage 186') Pooh for bit change. · square assy. & insert bit type '5-1-7. 10,562' to 10,748'. Hole cond. good. RIH w/ taJ'dem -- Drilled 12 1/4" hole from (Footage 178') Drilled 12 1/4" hole from 10,748' to 10,926'. Surveyed &: Pooh for bit change. Had tight spots @ 10,456', 7636', 7495' & 7-404' ,. (Insert bit 95% used & 1" out of guage). (FooLage 149?) RIH xv/ tandem square assy. & insert bit type 5-1-7 to8390". Washed to 8410. Washed &reamed from 10,325' to 10,335'. Washed & reamed from 10,380' to 10,926'. Drilled 12 1/4" hole from 10,926~' to 11,075'. (Footage 261') Drilled 12 1/4" hole from 11,075' to 11,336' w/ tandem square assy. Circ. & cond. for survey. Dropped survey. (Footage 0:) Pooh for bit change @ 11,336'. Pulled, worked & reamed BHA thru tight section 10,780'-10,605'. Pooh to 9972'. Unable to get above 9972'. Back reamed & worked BHA from 99712' to 9914'. (Footage O:) Reamed BHA out of hole from q9i41-9880~ (34; in i~ hrs.) Hole free below 9880' Dwn. reamed from 9880' to bridge @ 10,122'. Reamed out bridge & CO hole to 10,174'. (294' in 3 hrs.) BHA length 179'. Pooh. Hole free to 9880'. Unable to pull above 9880'. Reamed out of hole from 9880'-9858'. (Footage 0') Reamed out of hole from 9858' to 9853'. TIW lower Kelly Cock parted in body while working DP @ 9853'. Dropped 9858' of tools in hole. Top of tools should be 1478' below rotars:. PU Il"OD guide on 10 5/8" OS dressed w/ 6 3/8" grapple. TIH to 2870'. Unable to locate top of fish (No more DP on location). Ordered out all remaining DP - 75 jts. Grade "G". RU stop on sand line unit. TIH to locate top of fish.w/ stop while trying to locate more DP & determine amount requir.ed. Hung up IVL in 13 3/8" csg. RU T-bar &parted 9/16" WL. Left approx. 2500'I','L in hole. Ran rope spear & tagged up on WL @ 1987'. Pushed to 2049: Pooh. Rec. approx. 1500' of WL. Reran rope spear. (Footage 0') Reran rope spear w/ 12 1/4" WL stop. Tagged up on wire @2225'. Pushed wire & tools dwn. hole to 4147'. Set dwn. solid @ 4147'. Wrapped WL on spear & Pooh. Rec. approx. 850' of WL (left 150' of wire & tools in hole). Reran rope spear w/ 12 1/4" WL stop. Tagged up on wire @4622' Unable to push below 4622:. Pooh. Rec. 120' of WL-no tools. Ran 12 1/4" OD guide on 4 11"16" OD dressed w/ 2" grapple. Stopped on top of fish @ 4656'. Engaged fish. Pooh. Rec. all ofWL & tools on WL. '(sinker bars & stop ring). Picked up 11" OD guide & 10 5/8" OS dressed w/ 6 1/4" grapple on 6 1/4" jars. TIH. Engaged top of fish #1 (TIW valve on DP) @4657'. Tripped, jarred &worked fish free. Pulled 31' & hung up @4626'. Worked fish #1 from 4657'-4626'. Unable to jar fish above 4626'. UNI011 0IL C0t PA ' ' OF CALIFOR .IIA ¥ LLL I{ECORD PAGE Ih, L~,~ TRt.~.rlNG BAY UNIT STATE .! FIELD cAR'rmJR RF ER FIELD DATE 39 4/12/75 40 4/13/75 41 4/14/75 42 4/15/75 ETD 11,336'TD 11,336'TD 11,336'TD 11,336'TD DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS (Footage 0') Circ. & cond. mud while jarring on fish #1 @4657:. (Oil Jars bleeding off from drag prior to pull @ 4626'). Released OS. Pooh. Laid dwn. 6 1/4" Bowen Oil Jars.' PU 7 3/4" Oil Jars. TiH. Engaged fish #1 @ 4657'.. Worked & jarred fish #1. Jars bleedi~g off-unable to jar at top of free travel @ 4626'. Unable to wedge fish. RU dialog & ran free pt. Unable to obtain good readings due to torque running out btm. of fish. Pulled strained on fish @ 4626'. Still unable to hole torque for free pt. reading. Stretch readings indicated fish recoverable to + 6800'. Released OS & Pooh, Laid dwn. Bowen Oil Jars. PU 7 3/4" Daily Oil tool mechanical jars & accelerator jars. TIH & engaged top of fish #1 @ 4666'. Worked & jarred on fish. Able to trap torque into fish. RU dialog & TIH. (Footage 0') Dialog checked fish #1 recoverable to +7500'. Backed off DP in fish #1 @ 7236'. (took 2 hrs. + to effect torque to break & back off PD after shot fired) RD Dialog. Pooh w/ fish #1. Rec. 82 jts. S-135 DP. (total footage 2566' plus 4' of saver sub & parted TIW valve on top of fish (total of 2570'). Top o-f fish #1 @ 7236'DPM. Picked up 12 1/4" bit & reaming assy. TIH. Tagged obstruction @ w/ 12 1/4" bit. (rechecked top of fish ~ 5632'-12' high to original iag-up Could be along Side. Hole is enlarged to +18" in this section based on previous wells). TIH w/ 11" guide & 10 5/8" OS dressed w/ 6 1/8" grapple. Unable to locate top of fish ~2. Worked from 5613'-5645'. Get indication ~ 5636' & 5640'-would hold u~0M weight but pump o~f cautious of washing out along side fish. Pooh w/ OS. (Footage 0') Pooh w/ OS. No indication of OS having been along side fish #2. Reran OS on bent single & limber hook-up. Washed & ' reamed from btm. of 13 3/8" csg. @ 5548' to obstruction in hole ~ 6193'. Unable to work or ream below 6193'-no torque on fishin~g assy. Pooh w/ OS. Mill control in grapple showed having run on me~a! w/ no markings on outside lip guide. Indicated top of fish #2 had been inside OS. Redressed OS w/ 6 1/8" mill control & grapple. Ti.:--~. · Cleaned out coal bridge @ 5870' & TIH to top of' fish #2 @ 6193'. Attempted to work over top of fish. Fish moving dwn. hole. Ci:ased fish#2 to 6918' . Attempted to aress' off top of fish #2 & catch lis'.-':-., w/ OS w/o success. (Footage 0') Pooh w/ OS. Mill control worn dwn. & had been en top of'fish #2 @6918'. No indication of fish in grapple. Ran OS w/ 5" grapple & mill extension w/ 5" hollow mill. Tagged up on top ef fish @6918'. Milled 1 foot & either fell off along side fish or fish started moving dwn. hole. Reamed dxYr~, to 7196'. Milled or rotated o'..~, fish @ 7196'. Worked dwn. to 7215'. Unable to work below 7215'. Pooh w..- OS & hollow mill. OS showed to have been along side of fish by external marks. Slight wear in btm. of hollow mill indicated to have been over fish at one time. Picked up 12 1/4"OD rotary guide shoe on 6 1/4" hollow mill extension & OS. UNIai 0ILOF CALIF0, IIA I' ELL REC01 P^GE t'b, ___ LEASE TRADING BAY UNIT STATE I'~LL Il0, 6;-22 FIELD McARTHUR RIVER FIELD DATE 43 4/16/75 44 4/17/75 ETD 11,336'TD 11,336'TD ]], 336'TD DETAILS OF OPEP, ATIONS, DESCRIPTIOIIS g RESULTS (Footage 0') TtH xv/ 12 1/4"OD rotary guide shoe on 6 1/4" hollow mill extension & OS w/bent jr. DP below DC. Had no indication of fish #2 until 7152:. Got torque & wt. indications @ 7152' but unable to pick-up top of fish. Unable to work fishing tools be.low 7196' or locate top of fish. Pooh. Had indications on rotary shoe of being along. side of fish. TIH w/ 4 1/2" IF cripple screw-in sub on bent jr. DP. TIH to 7226'. Wa'shed dwn. to 7258' looking for top of fish #1 @ 7236'. Unable to tie into top of fish #1 or work below 7258' Pooh. No indication of contact w/ fish #1. PU side~,all hool on 6 1/4" holle mill on 15° knuckle jr. (Footage 0') TIH w/ 12 1/4" sidewall hook on 15° knuckle jt. Worked dwn. to 7152'-unable to locate fish #2. Worked dwn. to 7196'-unable to ~ork below 7196'. Unable to PU fish in SW hook. RIH w/ 5" OD OEDP to 6000' to lay cmt. plug in open hole. Pumped 500 cu. ft. Inlet wtr. Mixed & pumped 1100 cu. ft. cmt. w/ 1% CFR-2 & 2 1/2% pre- hydrated gel. Displ. cmt. to 5500'. Poohw/ DP. CIP @2:30 pm, 4/17/75. [ '~ ^ ,-,, ,t- .-. ~ _ rt l "~ '~ a T t'"i f-' 'r) T u -..! l ') I /All m ~ · CO firm crnt. to 5650:. Pooh. Rill ~v/ 5" OEDP to 5646-". Pumped 100 cu. ft. Inlet wtr. Mixed & pumped 400 sx. Class "G" cmt. w/ 1% CFR-2 & 15% sd., deiasified to a 125#/cu. ft. slurry. Pulled up to 5200' & reversed out. Closed pipe rams & braden head squeeze 45 cu. ft. cmt. plug w/ 1300 psi. Held press. 4 hrs. CIP @ 12:00Noon, 4/18/75. Poohw/ DP. Released rig to TBUS G-21 @ 12:00 Midnite, 4/18/75. UNIQ"I OIL Cg'?/ ,IY CF .CALIFORI.IIA I.,ecLL-iIECOI PAGE LEASE TRADING BAY UNIT STATE I' [LL [-10, G-22 FIELD McARTHUR RIVER FIELD DATE 46 5/21/75 47 5/22/75 48 5/23/75 49 5/24/75 ~o 5/25/75 31 5/26/75 52 5/27/75 53 ~'/ ~, 28/75 54 5/29/75 55 5130/75 5/31/75 ETD 11,336'TD 5200'ETD Cmt. plug 11,336'TD 5538'ETD Cmt. 11,336'TD 5600:KOP 5669:TD 5600'KOP 5935'TD 5600'KOP 6401'TD 5600'KOP 6885'TD 5600'KOP 7420'TD 5600'KOP 7960'TD 5600'KOP 8422'TD 5600'KOP 8684'TD 5600'KOP DETAILS OF OPERATIONS, DESCRIPTIOt-IS & RESULTS (Footage 0') Recommenced operations on TBUS G-22 @12'01 am, 5/21/75. Skidded rig from TBUS G-21 to TBUS G-22. Installed BOPE & tested to UOCO specs.-ok. Made up BI-IP~ & RIH. (Footage 0') Drilled out firm cmt. in 13 3/8" csg. from 5201' to 5538' w/ filtered Inlet wtr. Circ. hole clean & cleaned mud tank. Displ. hole w/ inhibited Inlet wtr. & let well set for 2 hrs. to kill bacteria in wellbore. (Footage 0') Mixed X-C Polymer drlg. fluid. Displ. hole w~ drlg. fluid. Drilled out cmt. frorr, 5538'-5600'. Pooh. RIH w/ DD & Sperry Sun Steering tool to 5600'. Attempted to orient DD for maximum right hand turn. Steering tool failed. Changed out' Sperry Sun Steering tools. Oriented DD for right hand turn. DD failed. Pooh w/ DD. RIH w/ turbo-drill & steering tool. (Footage 69') Oriented turbo-drill @ 5600'KOP. -T-urb0. driile~.'.fro.m 5600'-5616'. Steering tool failed. Puuled out steering to°l. Rearn-bd turbo-drill run from 5600'-5616'. Ran new steering tool. Oriented turbo-drill @ 5616' for maximum.right hand turn. T~rho-dr~ll~d r.. _ _ Pooh.. _,rom 56~6'-q669'. _ (Footage 266') RIH w/ 12 1/4" follow-up assy. Reamed turbo-drill run from 5600'-5669'. Drilled & surveyed 12 1/4" hole from 5669'- 5721'. Pooh for BHA change. TIH w/ 12 1/4" tandem square assy. Drilled 12 1/4" hole from 5721'-5935'. Pooh. (Footage 466') RIH w/ 12 1/4" tandem square building assy. Drilled 12 1/4" hole from 5935'-6358'. Pooh for BHA change. RIH w/ 12 1/4" tandem square locked assy. Drilled 12 1/4" hole from 6358'-6401'. (Footage 484') Drilled 12 1/4" directional hole w/ tandem square assy. from 6401'-6885' w/ bit trips @ 6597: & 6872'. (Footage 535') Drilled 12 1/4" hole w/ tandem square assy. from 6885'-7420' w/ bit trip @ 7164'. (Footage 540') Made bit trip @7420'. Drilled 12 1/4" holew/ tandem square assy. from 7420'-7960' w~ bit trip @7723'. (Footage 462') Drilled 12 1/4" hole v,:/ tandem square assy. from 7960'-8422' w/ bit trip @ 8282'. (Footage 262') Drilled 12 1/4" hole w/ tandem square assy. from 8422'-8684' w/ bit trip @8591'. H°le turning slightly left. Pooh for Dyna-drill. RIH w/ Dyna-drill to 8684'. '~..., PA, GE !"bo lO IJNIOII 0IL CCI?ANY CF CALIFORNIA I{ECORD · ~E TRADING BAY uNrr STATE ~'~_LL t'10. G-22 FIELD McARTHUR RIVER FIELD .DATE .6/1/75 38 6/2/75 59 6/3/75 ~0 6/4/75 6/5/75 6/6/75 6/7/75 ~4 6/8/75 )5 6/9/75 ;6 6/10/75 8684'TD 5600'KOP 8758'TD 5600'KOP 8943'TD 5600'KOP 8985'TD 5600'KOP 9224'TD 5600'KOP 9379'TD 5600'KOP 9541'TD 5600'KOP 9688'TD 5600'KOP 9775'TD 5600'KOP 9980'TD 5600'KOP DETAILS OF OPERATIONS, DESCRIPTIOI-IS g RESULTS (Footage 0') RIH xv/ Sperry Sun Steering tool on DA WL. shorted out three times. Pulled up into 13 3/8" csg. shoe. RD DA. WL (Footage' 74') RU Schlumberger. RIH w/ Sperry Sun Steering too!. Oriented Dyna-drill @ 8684'. Dyna-drilled from 8684'-8758'. Pooh w/ Sperry Sun. Hole turned 11° right w/ no angle change on Dyna-drill run. (Footage 185') Pooh w/ Dyna-drill. RIH w/ 12 1/4" follow up assy. Reamed Dyna-drill run from 8684'-8258'. Drilled 12 1/4" hole from 8758'-8806'. Ran survey on WL. Both survey instruments failed, Rereamed Dyna-drill run while waiting on survey instruments. Ran WL survey. Hole dropping angle. Pooh. RIH w/ 12 1/4" building assy, -Drilled 12 1/4" hole from 8806'-8943'. Dropped survey. (Footage 42') Completed BHA change. RIH w/ 12 1/4" tandem scuare - assy. to 8684'. Reamed Dyna-drill run from 8684' to 8943' Drilled ]2 1/4" ho]~ from_-g943' to 8985'-, ' (Footage 239') Drilled 12 1/4" hole w/ tandem square assy. from 8985' to 9111'. Dropped survey. Pooh. RIH w/ 12 1/4" stab. assy. to allow for right hand turn. Drilled 12 1/4"hole from 9111'-9224'. (Footage 155') Drilled 12 1/4" directional hole w/ 12 1/4" mil! tooth bit on 12 1/4" cony. tandem NB stab. BHA from 9224' to 9379' w/ bit trips. @ 9246' & 9379'. (Footage 162') Drilled 12 1/4" directional hole w/ 12 1/4" mill tooth bit on 12 1/4'! cony. tandem NB stab. BHA from 9379~ to 9541'. Hole turned 6° right to S48W. Ran Inset bit (type 5-1-7) on 12 1 4" tandem square BHA. Reamed from 9350' to TD @9541'. (Footage 147') Drilled 12 1/4" directional hole from 9541' to 9572'. Took 3 hrs. to drill last 6' Pooh w/ Insert bit. Ran 12 1/4" m::!l tooth bit on tandem square BHA. Drilled 12 1/4" hole to 9688'. (Footage 87') Directionally drilled 12 1/4" hole w/ milled tooth bit on tandem square BHA from 9688'-9719'. Dropped survey &Pooh. Sperry Sun check inst. failed. BU inst. (new) showed hole had turned 8° left to S40W. Ran 12 1/4" insert bity (type 5-1-7) on cony, tandem NB BHA toTD @9719'. Drilled to 9749' while circ. & cond. mud. RU & ran check survey..Bo.th inst. confirmed hole directie-n as S40W. Drilled to 9775'. (Footage 205') Drilled 12 1/4" directional hole w/ insert bit (type 5-1-7) on cony, tandem NB BHA from 9775'-9980'. Bit torquing excessively, Dropped survey & Pooh. Hole cond. good. Insert bit (Reed FP-52) had 1 locked cone & bearing gone on 2nd cone. Total run-261' in 28 hrs. Changed BttA to break angle build & Tilt w/ Smith 2JS insert bit (type 5-1-5)-. SI-',t-L ILI PAGE i"b, 11 UNIO['I OIL CO ' PANY OF CALIFOP tIA ¥;ELL i ECORD LEASE TRADING BAY UNIT STATE 1-10, G-22 FIELD x. ^RT} uR RIVER FIELD DATE 67 6/11/75 68 6/12/75 69 6/13/75 70 6/14/75 ?1 6/15/75 .72 6/16/75 73 6/17/75 74 6/18/75 6/19/75 '6 6/20/75 '7 6/21/75 ETD 10,174'TD 5600'KOP 10,395'TD 5600'KOP 10,491'TD 5600'KOP 10,662'TD 5600'KOP 10,863'TD 5600'KOP 10,969'TD 5600'KOP 11,203'TD 5600'KOP 11,335'TD 5600'KOP 11,335!TD 5600'KOP 11,335'TD ll,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar DETAILS OF OPERATIONS, DESCRIPTIOilS g RESULTS (Footage 194') Completed TIH w/ Smith 2 JS (type 5-1-5) Insert bit. Drilled from 9980'-10,110'. Ran survey & made short trip. Hole cond. good. Drilled 10,110'-10,174'. (Footage 221') Drilled 12 1/4" directional hole from 10,174' to 10,220'. Made short trip. Hole cond. good. Drilled 12 1/4" hole from 10,110' to 10,395'. (Footage 96')Directionally drilled 12 1/4" hole w/ conv. tandem N.B. BHA & Insert bit type (5-1-5)from 10,395[ to 10,491' w/ bit trip @ 10,415'. (Footage 171')'Directionally drilled 12 1/4" hole w~ cony. tandem N..B. BHA &Insertbit (5-1-5) from 10,491' to 10,662'. :Made short trips every 12 hrs. Hole cond. good. (Footage 201') Directionally drilled 12 1/4" hole w/ cony. tandem N.B. BHA & Insert bit (5-1-5) from 10,662' to 10,863' 5iade short wiper trip every-12 hrs. Hole in good cond. Pooh @ 10,863' w~ Insert bit. (Footage 106') Completed bit trip @ 10,863'. Hole cond. ok. Drilled 12 1/4" hole from 10,863' to 10,966'. Made short trip. Hoel cond. ok. Drilled from 10,966' to 10,969'. (Footage 234') Directionally drilled 12 1/4" hole from 10,969' to 11,203' w/ Insert bit type (5-1-5). Short trip @11,095'. Hole cond.ok.. (Footage 132') Continued drilling 12 1/4" hole to TD @ 11,335' w/ short trip @ 11,264'. Dropped survey &Pooh to log.- RU Schlumberger &ran DIL Log. Schlumberger checked driller's TD of 11,335' @ 11,330'WLM. (Footage 0') Completed running DIL. TIH w/ BHC-Sonic-GR Log. Unable to get below coal section @5740'. RD Schlumber.2er. Ran 12 1/4': bit for CO run. ttole cond. good. Unable to find ledge @5740'. RU Schlumberger. Reran BHC-Sonic-GR Log. Unable to get below 5775'. RD Schlumberger. Ran 12 1/4" bit to cond. hole to run 9 5/8'" csg. TIH. Hole cond. good. Circ. btms. up. (Footage 0') Pooh w/ bit & scraper. RU & ran 273 jts. of 9 5/8" csg. to TD @ 11,335'. Float collar (a 11,253'. Cmt'd csg. w/ 1600 sx. Class "G" cmt. w/ additives.- Bumped plug w~ 2500 psi. Float equipment held ok. Hung off 9 5/8" csg. .. (Footage 0').InStalled tbg. head &BOPE. Tested to UOCO specs.-ok. Ran 8 1/2" bit''& 9 5/8" csg. scrapea' to ETD. Float collar (d11,253'. Pooh. RU Schlumberger & ran CNL-FDC-GR Log from 11,253' to 5548'. -; St-IE[-T D PAGE No, 12- UNIOI'I 0IL CCI'PArC OF CALIFOPdIA I ECORD LEASE TRADING BAY UNIT STATE t'~IELL NO, G-22 FIELD McARTHUR RIVER FIELD DATE 78 6/22/75 79 6/23/75 6/24/75 Bi 6/25/75 6/26/75 6/27/75 6/28/75 6/29/75 ETD 11,335'TD ll,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD 11,253 'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD 11,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD 1], 253 'ETD Float Collar 11,335'TD 11,253'ETI~ Float Collar DETAILS OF OPERATIONS, DESCRIPTIOHS g RESULTS (Footage 0') Ran Sperry Sun Gyro Survey froTM ETD to surface. Ran Variable Density-CBL Log from ETD to 8000'. Bond results-poor to ~Perf. from 11,081'-11,082' w/ 4hpffor block sqz. #1 between Benches #5 & #6. (Footage 0') Schlumberger ran junk. basket & guage, ring to 11,150'· Ran 9 5/8" Baker cmt. ret. & set @10,990' (DIL meas.). Ran stinger on DP & stabbed into ret .-unable to break dwn. perfs, from 11, 081'-11, 082" w/ 3000 psi. Poohxv/ DP. RU Schlumberger & perf. Hemlock Bench #2 from 10,708'-10,710' for WSO sqz. ~_,f~ (Footage 0') Ran Baker cmt. ret. & set on WL @ 10,660'. Ran stab. in stinger on DP & set into ret. @ 10,660'. Sqz'd. off Bench #2 perfs. from 10,708'-10,710' for WSO w/ 100 sx. Lo-filtrate Class "G"-cmt. Fm broke dwn w/ ~ ' · . 2900ps~~z. press. 4400 ps:. Bledto 4250 psi & held ok. Pooh. Ran BO shoe & pkr. picker. Milled over ret. @ 10,660' & Pooh. Rec. ret. less slips-left in ho!e. RU Schlumber- ger. Perf. top of Hemlock Bench #1 from 10,590'-10,592' for zone isolation sqz. Ran guage ring & junk basket to 10,600:-ok. (Footage 0') Ran Baker cmt. ret. on WL & set @ 10,530,. Ran DP & stabbed into ret. tp~. perfs, from 1~ 590'-10, 592' for zone isolation at top of Hemlock. Unable to PU w/ 5500 psi. Pooh. Ret. stinger on DP damaged by junk. Milled over ret. @ 10,530' & Pooh. Rec. top part of ret. Left slips in hole. Ran junk basket & guage ring-unable to get below 10,575'. Ran 8 1/2" bit & pushed junk to 10,665' (cmt. plug). (Footage 0') Reran cmt..ret. & set @ 10,526'. Broke dwn. perfs. top of Hemlock Bench #1 from 10,590'-10,592' w/ 4500 psi. PI 7 cfm @ 4700 psi. S_,~_qz'd. perfs, w/ 100 sx. Lo-filtrate Class "G" cmt. to a final press, of 4800 psi. Hel~-~2l-B-~J'0'-~i- W-/'Pumps 6i'~-. '-PU & rev. out on top ret. Pooh w/ stinger. TIH w/ BO shoe & pkr. picker. Milled over ret. @ 10,526' & worked free. . ' . . '-= . No PL: (Footage 0') Completed Pooh w/ Dkr oicm~r rec. OS (short catch) & TIH. Worked over ret. @ 10,530'-~PNi. Pooh. Rec. top of ret. Left btm. slips & packing element in hole. Rata 8 1/2" bit &junk basket. Tagged junk @ 10,53-0'. (Footage 0') Drilled on junk & cmt. from 10,530'-10,614'. (Sqz. perfs, from 10,590'-10,592') TIH to cmt. plug @ 10,662'. Drilled firm cmt. from 10,662'-10,745'. (Sqz. perfs, from 10,708'-10,710'). Drilled out cmt. ret. @ 10,990' &CO well to ETD @ 11.253' Pooh. Rec. large amounts of junk & rubber in junk basket. Ran bit & scraper to ETD @ 11,253'. -Hole appeared clean. (Footage 0') Pooh. Laid dwn. 5" DP'& tools. RU Schl. torunprod. pkrs. TIH w/ junk basket & guage ring. Unable to get below 11,033' due to rubber in hole. Pooh. Rec. large pieces of rubber. Made several attempts on junk basket run. Unable to get clean run. Fabricated 7 1/1.6" OD poor-boy junk catcher. UNIO!1 OIL C(I;PA ' OF CALIFORNIA I, [LL I-',ECORD LEASE TRADING BAY UNIT STATE 1',ILL II@, G-zz FlED McARTHUR RIVER FIELD DATE 6/30/75 7/1/75 7/2/75 713175 ;0 7/4/75 ,1 7/5/75 · Z 7/6/75 7/7 "75 ,4 7/8/75 ~5 7/9/75 11,335'TD 11,253'ETD Float Collar 11,335'TD 11,253'ETD Float Collar 11,335'TD 11,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD 11,253'ETD Float Collar 1.1,335'TD 11,253'ETD Float Collar ll, 335'TD ll., 253'ETD Float Collar 11,335'TD l 1,253'ETD Float Collar DETAILS OF OPEP~-,TIONS, DESCRIPTIO~IS g RESULTS [Footage 0') Completed picking up 4 1/2" tbg. RIH w~ poor boy JB Lo 11,233'. Rev. out. Rec. loose rubber &junk. SetJ'B dwn. on il@at collar @ 11,253'. Pooh-no rec. RU Schl. RIH w/ 8 1/2" guage ~ing &JB to 11,227'. Pooh. Rec. loose rubber &junk. Ran & set erm. pkr. #1 @ 11,090' w/ 4 1/2" tbg. tail @ 11,106' Ran & set perm. kr. #2@10,940' w/ 4 1/2" tbg. tail @10,977'. Made up Baker 9 5/8" ( 6" perm. pkr. RIH ~v/ pkr. on WL. Unable to get below 3374'. [Footage 0') Poohw/ Baker 9 5/8" X 6" perm. pkr. Reran JB. RU ran Baker 9 5/8" X 6" perm. pkr. on 4 1/2" tbg. & set @10,450'DPM, . ~ooh. RU &ran 4 1/2" tbg. W/ accessories. Stabbed into Baker perm. )kr. @ 10,467' tbg. meas. Testedpkr. to 1000 psi-ok. Spaced ~ut tbg. Displ. mud w/ Wtr. iFootage 0') Displ. wtr. w/-diesel to top pkr. @ 10,450'. Removed 3OPE. Installed x-mas tree & tested to 5000 psi. Conneceted well o prod. facilities. '.Footage 0') Pulled well on gas lift xv/ 500 psi neg. diff. Perf. emlock Bench #6 from 11,115'-11,145' w/ a 3 3/8" Hyperjet II gun- hpf. Prod. tested Bench #6 perfs. @ 600 BWPD & trace of oil. SI .... ~,ell & ran WL press', build-up surveY. iF@@rage 0') BHP-Bench #6-3343 psi after 12 hrs. SI & still increasing. ;et "N" plug in "N" nipple @ 11,104' to isolate Bench #6. Pulled dwn. cell on gas lift for 500 psi neg. diff. Perf. Hemlock Bench #5 from .0,984'-11,022' w/ a 3 3/8" Hyperjet II gun-4 hpf. (Footage 0') Prod. tested Bench #5 perf. 0+1000 BPD ratew/ %90% wtr. cut. SI well & ran WL press, build-up survey. (Footage 0') BHP-Bench #5-3646 psi after 18 hrs. SI & static. Set plug in "X" nipple @ 10,954' to isolate Bench #5. Pulled dwn. well gas lift for 500 psi neg. diff. (Footage 0') RIH w/ 3 3/8" Hyperiet II csg. gun & diff. net:. "iemlock Bench #4 from 10,936'-10,911' 04 hpf. RD Schl. Prod. tested Bench #4 @ 1080 BPD w/ 80% cut. Released rig crews @6:00pm, 7/7/75 while production testing & evaluating TBUS G-22. RU North Star. RIH w/ press, survey instruments to ]0,720' S! well for 24 hr. build-up survey @ 9:00 pm, 7/7/75. (Footage 0') Completed running 24 hr. press, build-up survey, · ,4-3518 Pooh w/ survey instruments RD North Star. BHP for Bench ~ psi after 24 hrs. Returned well to gas lift for production testing. (Footage 0') Production tested Hemlock Bench #4 perfs, from 10,911'-10,936' for 24 hfs.while;evaluating well. Rate of 960 BPDw/ 80% cut. ,blll:t'l U PA e' UNIO[ I OIL CCFPA ' OF CALIFOP tIA I' [LL RECOt D LF_A E TRADING BAY UNIT STATE FIELD McARTHUR RIVER FIELD DATE 96 7/10/75 97 7/11/75 98 7/12/75 99 7/13/75 00 7/14/75 01 7/15/75 102 7/16/75 103 7/17/75 ETD 11,335'TD 11,253'ETD Float Collar 11,335'TD 11,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD 11,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar 11,335:TD 11,253'ETD Float Collar 11,335'TD ll,253'ETD Float Collar DETAILS OF OPERATIONS, DESCRIPTIOI/S g RESULTS (Footage 0') Tested Hemlock Bench #4 @950bbls/day w/ 80% cut. RU North Star. Pulled 4-1/2" plug from "X" nipple @ 10,954' (3 runs). (Footage 0') RIH w/.press, survey instruments attached to bL.'r., of "X" plug. Set "X" plug in "X" nipple @ 10,854'. Prod. tested Hemlock Bench #4 perfs. @ 96 bbls w/ 40% cut. ("X" plug set previsouly had been leaking). RU Schl. RIH w/ 3 3/8" Hyperjet II csg. gun & diff. perf. Hemlock Bench #4from 10,911'-10,936' @4hpf. Prod. tested Hemlock Bench #4 @ 96 bbls/day w/ 40% cut. RIH w/ 3 3/8" Hyperjet II csg. gun & diff. perf. Hemlock Bench #4 from 1-0,886'-10,911' @ '4 k~zf. (Footage 0') Prod. tested Hemlock Bench #4perfs. from 10,885' 10,9_:5" for 12 hrs. @ an average rate of 98 bbls/day w/ 30% cut. RIH w press. survey tools. SI well @ 12:00 am, 7/.12/75 .for 24 hr- press, bu:_!d-up survey. (Footage 0') Completed running 24 hr. press, build-up @ 12' 0O am, 7/13/75..Pooh w/ press, bomb making stops to check fluid gra:~ient. Hemlock Bench #4 press-2266 psi after 24 hrs. & still building. Reran (Footage 0') Completed running 48 hr. SI BHP build-up @ 12:09 noon, 7/14/75. Poohw/ survey instruments. Bench #4press.-2723 ~si after 48 hrs. & still building. RU Sch!. RIH w/ 30' 3 3/8" HyFeriet II csg. gun. Perf. Hemlock Bench #2 from 10,685'-10,700'. (tep 15' of gun misfired. ) (Footage 0') Completed perf. Hemlock Bench #2 w/ 3 3/8" Hyperjet I! csg. gun. Total perf. interval 10,670'-10,700'. Put well on gas lift. Prod. tested for 13 hrs. @ an average rate of 2880 BPD w '3.7% cut. RU WL unit. RIH w/ press, survey instruments. SI we]~ ~s 8' 00 pm, 7/15/75 for press, build-up survey. (Footage 0') Completed 14 hr. SI press, build-up survey &Fc-'-h w/ survey in'struments. BHP on Hemlock Benches .~',~2 & #4 - 2720 '-s; & building. RI? Schl. &ran 3 3./8" Hyperiet II csg. gun. Perf. =:=uer interval of Hemlock Bench #4 from 10,832'-10,862' @4 hpf. Pe:h w~ perf. gun. Gun hung up @8950'. Pulled gun free & restuck g'an @ 8850'. Unable to pull free. (Footage 0') Unable to work perf. gun stuck 08850' free. Pu:!ed out of rope socket. Pooh w/ elect. WL. RD Schl. RU braided '.'iL unit. RIH w/ 2 5/16" grapple & hyd. oiliars. Engaged fish ¢$S50 jarred free. RIH to 10,500'. -Tbg. clear. Pooh. No rec. R!.:-! w/ shifting tool. Tbg. clear of debris. RU Schl. RIH w/ 3 7/8" F. yper- jet II csg. gun. Perf. Hemlock Bench #3 from 10,768'-10,788'. Flowed well to clear up perfs. Rate- 4000 BPD w/ 0.8%cut. bl"iEE PAGE 15 UNIO~ OIL CCi','P/~,IY OF CALIFORt,IIA i'~ELL I~ECORD LEASE TRADING BAY UNIT STATE ~'~t~LL l~O, G-22 FIELD McARTHUR RIVER FIELD ELATE 104 7/18/75 ETD 11,335'TD 11,253'ETD Float Collar DETAILS OF OPEP&TIONS, DESCRIPTIOt-IS g RESULTS (Footage 0') Production tested Hemlock Benches #4, #3 & #2 0 4000'B?D w/ 0.8% cut. 'Poohw/.perf. gun. Ran 3 3/8" HyperjetII csg. gun & diff. perf. Hemlock Bench #1 from 10,602'-10,'622' w/ 4hpf. Produced well @ 4320 BPD w/ 1.0% cut. Ran & set ball valve in ball valve nipple. Put well on production test. Ave. Prod. Test: GROSS NET CUT FM.GAS GOR GLR GRAVITY TBG. CSG. 4032 4012 0.5% 954 238 1.107 34.7° 180 1020 FINAL REPORT UNIO[' OIL CO PNCf OF CALIFOP IA I LCORD P^GE NO, , ],6 LEASE TRADING BAY UNIT STATE I,,gl NO, a-zz FIELD McARTHUR RIVER FIELD DATE ETD JTS. 13 14 Jts, JTS. 67 67 136 Jts. JTS. 1 1 28 74 169 1 277 Jts. DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS 20" 94# H-40 BUTTRESS CSG. DETAIL: DESCRIPTION LENGTH BOTTOM 20" Shoe' 20" H-40 Buttress.Csg, 20" Stab-in Float Collar 20" H-40 Buttress Csg. 24 3/4" Cameron CIW Hgr. Landed below RT TOP 2.10 628.9.2 626.82 43.20 626.82 583.62 4.55 583.62 579.07 533.65 579.07 45.42 2.82 45.42 42.60 42.60 42.60 -0- 13 3/8" 61# & 68# K-55 BUTTRESS CSG. DETAIL: DESCRIPTION LENGTH BOTTOM 1 9O /V YU 1 59 2729 47 2 5O 2692 86 5548.02 5546.12 5466.22 5464.63 2735.16 2732.86 39.80 39.80 13 3/8" Shoe (Dowell) · ~ ~/o" oo~ K-55 But+.ress Csg. 13 3/8" Dowell Float Collar 13 3/8" 68# K-55 Buttress Csg. 13 3/8" Dowell DV Collar 13 3/8" 61# K-55 Buttress Csg. Landed below 0' on Cameron Warp around slips. 9 5/8" N-80, P-110 & USS-95 BUTTRESS CSG. DETAIL: DESCRIPTION LENGTH BOTTOM TOP 5546.12 5466.22 5464.63 2735.16 2732.66 39.80 9 5/8" Dowell Shoe 9 5/8" 47# USS-95 BUttress Csg. 9 5/8" Dowell Float Collar 9 5/8" 47# USS-95 Buttress Csg. 9 5/8" 47# P-il0 Buttress Csg. 9 5/8" 47# N-80 Buttress Csg. 9-5/8" 47# N-80 Buttress Csg. Cut off Landed below RT -0- TOP 19.54 56.73 37.19 37.19 37.19 -0- 1.73 11,336.73 11,335.00 79.76 11,335.00 11,255.24 1.62 11,255.24 11,253.62 1166.93 11,253.62 10,086.69 3070.21 10,086.69 1,016.48 6959.75 7,016.48 56.73 UNION OIL C(I'"£ANY OF CALIFORNIA 'ELL RECOI PAGE NO, :17 LE~E TRADING BAY UNIT STATE WELL NO, 0-22 FIELD McARTHUR RIVER FIELD DATE JTS. 12 11 11 12 10 11 12 11 11 11 11 19 34 34 53 DETAILS OF OPERATIONS,, DESCRIPTIOr-IS g RESULTS TUBING DETAIL 4 1/2" 12.~0# N-80 Tbg. DESCRIPTION LENGTH 4 7/8"-X 4" Mule Shoe 4 1/2" 12.60# N-80 Pup Jt. Otis 4 1/2" X Nipple 4.60"X 3.812" 4 1/2" 12.60# N-80 Pup Jr. Baker seal assy. 6" X 4" Baker Locator Sub 6 1/2" X 4" 4 1/2" 12.60# N-80 Pup Jr. 4 1/2" Otis XA Sleeve 3.812 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #17 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #16 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #15 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #14 4 1/2" 12.60# N-80.Tbg. 4 1/2" Camco MMG GLV #13 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #12 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #11 4 1/2" 12.'60# N-80 Tbg. 4 1/2" Camco MMG GLV #10 4 1/2" 12.60# N-80 Tbg 4 1/2" Camco MMG GLV #9 4 1/2" 12.60# N-80 Tbg 4 1/2" Camco MMG GLV #8 4 1/2" 12 60# N-80 Tbg 4 1/2" Camco .MMG. GLV ~.t~' 4 1/2" 12 60# N-80 Tbg 4 1/2" Camco M~XlG GLV #6 4 1/2" 12 60# N-80 Tbg 4 1/2" Camco MMG GLV #5 4 1/2" 12 60# N-80 Tbg 4 1/2" Camco MMG GLV #4 4 1/2" 12 60# N-80 Tbg 4 1./2" Camco MMG GLV #3 4 1/2" 12 60# N-80 Tbg 4 1/2" Camco MMG GLV #2 4 1/2" 12.60# N-80 Tbg. 4 1/2" Camco MMG GLV #1 1.70 25.00 1.66 20.10 20 53 92 24 20 4 55 30 33 8 55 242.90 9.80 361.79 9.O8 326.89 9,08 329.62 8.55 360.61 8.55 301.22 9.O8 328.65 9.O8 363.11 9.O8 331.97 9.O8 334.42. 9.O8 330.74 9.08' · 328.47 9.08 5 5.71 9.08 1026.76 9.08 1024.49 9.O8 1608.48 9.08 TOP , 10,532.68 10,507.68 10,506.02 10,485.92 10,465.39 10,464.47 10,440.27 10,435.72 10,405.39 10,396.84 10,153.94 10,144.86 9,783.07 9,773.99 9,447.10 9,438.02 9,108.40 9,099.85 8,739.24 8,730.69 8,429.47 8,420.39 8,091.74 8,082 66 7,719 55 7,710 47 7,378 50 7,369 42 7,035 00 7,025 92 6,695 18 6,686 10 6,357 63 6,348 55 5,772 84 5,763 76 4,737.00 4,727.92 3,703.43 3,694.35 2,085.87 2,076.79 BOTTOM 10,534.38 10,532.68 10,507 68 10,506 02 10,485 92 10,465 39 10,464 47 10,440 27 10,435 72 10,405 39 10,396.84 10,153.94 10,144.86 9,783.07 9.773.99 9,447.10 9,438.02 9,108.40 9,099.85 8,739.24 8,730.69 8,429.47 8,420.39 8,091.74 8,082.6'6 7,719.55 7,710.47 7,378.50 7,369.42 7,035.00 7,025.92 6,695.18 6,686.10 6,357.63 6,348.55 5,.772.84 5,763.76 4,737.00 4,727.92 .3,703.43 3,694.35 2,085.87 UNIal OIL COfeA C OF CALIFOP IA I' LL RECORD PAGE No, ]_8 -. TRADING BAY UNIT STATE I'~ELL N0, G-22 FIELD McARTHUR RIVER FIELD DATE ETD 6O 340 Jts. DETAILS OF OPEPATIONS, DESCRIPTIOI,IS g RESULLTS TUBING DETAIL 4 1/2" 12.60# N-80 Tbg. 4 1/2" 12.60# N-80 Tbg. · 4 1./2" Otis Ball Valve 4 1/2" 12.60# N-80 Tbg. 4 1/2" 12.60# N-80 Pup Jr. 4 1/2" 12.60# N-80 Pup Jr, 4 1/2" X over Atlas-Bradford X Butts. Cameron 4 1/2" Tbg. Hgt. w/ 4 1/2" DSS-HT Atlas- Bradford threads top & btm. RT to csg. hd. 1787.91 3.10 235.87 6.10 6.11 .2O 1.00 36.50 Total its. of 4 1/2" 12.60# N-80 Tbg. 288.88 285.78 49.91 43.81 37.70 37.50 36.50 --0-- 8" OD X 4" ID Bell Nipple 4 1/2" Otis N Nipple 3.725"ID 4 1/2" 12.60# N-80 Pup Jr. Baker 9 5/8" X 4.75" Model "D" Perm. pkr. .86 1.30 10'. 12 4,00 11,105 ~ 42 11,104.12 11,094.00 11,090.00 8" OD X 4" ID Bell Nipple 4 1/2" 12.60# N-80 Pup Jr. 4 1/2" Otis X Nipple 3,812"ID 4 1/2" 12.60# N-80 Pup Jr. Baker 9 5/8" X 4.75 Model "D" perm. pkr. .88 20.05 1.63 10.11 4.00 10,975.79 10,955.74 10,954.11 10,944.00 10,940.00 2,076.79 288.88 285.78 49.91 43.81 37.70 37.50 36,50 11,106.23 11,105.42 11,104.!2 11,094.C0 10,976.67 10,975;7a 10,955.74 10,954.1! I0,944.C~ ........ -- I I I 1~ RT to csg. head 36.50' 1. Tbg. hgr.-Cameron 4 1/2" w/ 4 1/2" DSS-HT Atlas Bradford threads top & btm. @ 36.50. 2. "X" over-Atlas Bradford X Butts. @ 37.50'. 3. Ball valve-Otis 4 1/2" MMG @ @ 1076.79 4. Gas lift valve-Camco 4 1/2" MMG @ 3694.35', 5. Gas lift valve-Camco 4 1/2" MMG @ 4727.94'. 6. Gas lift valve-Camco 4 1/2" MMG @ 5763.76'. 7. Gas lift valve-Camco 4 1/2" MMG @ 6686.10'. 8. Gas lift valve-Camco 4 1/2 MMG @ 6686.10'. 9. Gas lift valve-Camco 4 1/2" MMG @ 7025.92'. 10. Gas lift valve-Camco 4 1/2" MMG @ 7369.42'. · II Ga~ "~' '~ ' '~" 1.U-L viilv , c-,,..,,~mco 4 i/6" MMG @ 77i0 47'. 12. Gas lift valve-Camco 4 1/2" MMG @ 8082 66' 13. Gas lift valve-Camco 4 1/2" MMG @ 8420 39' 14. Gas lift valve-Camco 4 1/2" MMG @ 8730 69' 15. Gas lift valve-Camco 4 1/2" MMG @ 9099 85' 16. Gas lift valve-Camco 4 1/2" MMG @ 9438 02' 17. Gas lift valve-Camco 4 1/2" MMG @ 9773 99' 18. Gas lift valve-Camco 4 1/2" MMG @ 10,144.86'. 19. Gas lift valve-Camco 4 1/2" MMG @ 10,396.84'. 20. "XA" sleeve-Otis 4 1/2"OD X 3.821"ID @ 10,435.72'. 22 24 u/25 29 21. Locator sub-Baker 6 1/2" OD X 4"ID @ 10,464.47'. 22. Pkr-perm. Baker Model F-1 9 5/8" X 6" @ 10,465.39'. 23. Seal assy.-Baker 6" X 4" @ 10,465.39'. 24. "X" Nipple-Otis 4 1/2" 4.40"OD X 3.812"ID @ 10,506.02:. 25. Mule shoe 4 7/8"OD X 4"ID @ 10,532.68'. 26. Pkr.-perm. Baker 4.75' Model "D" @ 10,940.00'. 27. "X" Nipple-Otis 4 1/2"OD X 3.812"ID @ 10,954.11'. 28. Nipple-Bell 8"OD X 4"ID @ 10,975.79'. 29. Pkr.-perm. Baker .k~odel D-- 9 5/8" X 4.75" @ 11,090.00'. 30. Nipple "N" Otis 4 1/2" OD X L~~><~l 31. Nipple-Bell 8"OD X 4"ID @ 26 [~127 11,105.42'. ' 28 Note: All Camco gas lift valves are [ [ 4 1/2" ID X 3.812"OD. 31 · i i - R£V..[ DATE ! ! '. I I" . - - - -111 i i ii't i WELL SCHEMATIC TRADING BAY UNIT STATE WELL G-22 ORIGINAL COMPLETION DATE 3/4/75/COMPLETED 7/18/75. · _ . _ -':OI'~M 247 (~'l[.W ~ ~,61 O~,~,q,~--._------ CKD. A~'P'D. SCALE DATE ........ $H£[15 I tl 91 CONTROL LiNE NATIONAL BUTTRESS UNION OIL ANCHORAGE .-ir__ '~'.v--~.._.(.',.~.&.~L _. _.. ..... ._.:?_~ wo~,~ ~o~--~-- ~,~~a'~'~' XI~O~ "U~Oil:tl-~, Xl'~'C. P. O. BOX 1212 -- HOUSTON, TEXAS 77001 DATE PAGE BILL OF MATERIAL NUMBER ' 7-31 -69 2 932698 ' UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA QUOTE #9-4474 ERON CASING ORDERED PROGRAM - 4-1/2 "OD UNIT PRICI:' 629.64 8.48 28.69 . O0 NATIONAL BUTTRESS W/l/8" PART NUMBER 677162 1 7482. 40 7484 40 18775 8721 1 NPT CONTROL LINE D£SCRIPT ION LOOSE XF~S TREE- HATERIAL HANGER, TBG ASSEMBLY "DC-FBB" W/7" OD EXT. SEAL NECK, 10" 50OO.,~WP X 4-t/2" OD NATIONAL BUTTRESS BTH X 4-1/2" EUE TOP W/"H" BPV THD AND 1/8" LP CONTROL LINE PREP VALVE,STRAIGHT NEEDLE 1/2"NPT MXF GAUGE, ASHCROFT PRSSR, 4-1/2 "FACE O-5OOO~ RANGE ST/STL CASE, #IO2OXT GUN PLASTIC PACKING, INCL. WRENCH TOTAL LOOSE XHAS TREE HATERIAL TOTAL LIST PRICES ' LESS CASH.DISCOUNT 2 PER CENT 5TH-AND 20TH PROX. TOTAL NET PRICE FOB HOUSTON, PLANT TEXAS NOTE-PRICES SHOWN VALID FOR 30 DAYS ON TH! S ONLY. QUOTAT I ON AMOUNT 62.9.64 8..4J~- 28.6.c .OC 666.81 6597.i2 6465.1[ 0 RIG ~ N..A.L: DIRECTIONAL SURVEY REPORT TANGENTIAL COMPUTATIONS- FOR UNION OIL COMPANY OF C~'LIFORNIA TYPE OF SURVEY: SURVEY DEPTH: FROM Surface LEAaE: Grayling TBU State G~roscoptc Directional Multishot FIELD:. McATthur River ~.TO 11,200 WE~ NO. G-22 Redrill ~laska COUNTY/PARISH Kenai Peninsula Borough STATE DATE OF SURVEY. June 22, 1975, ~.OS ~o. SU3-..16999. ~nchorage~ Alaska VE~TI'cAL SERTIO~,~ CO;',;PUTED'-:~.LC.'?,!G CLOSURE · . ". $-:-22 GRAyLit..G."PLATFOR>: .. :.. · ... ... ~.",g,, RT'~UR RIVER ' . ..... ~"-'. ....... TT ~t~ ', ....... ~ '~'~'~'~" ~ ~ ., . . . . ,.. . "SPERRY-SUN ~.~ELL SURVEY -. ..... ~ .......... COP[PANT 'LS U-' 3-1&999 RECORO.OF SURVEY " ., · ~E TH ., .......... TRUE ...................... . VEfiTICAL SU~SEA ' ~2EPT~. nEPTH O, 0,0.0 3: .'- " ' :99' -~.9.00 50, ~, · =o""~--7-'-'i ......... ..... ' .............. ' ....... IUfi. '".' ' i5C', ~9,99 59,97 . . Ir%~L'IrJ',~TION .......... D"IRECTiaN ..... DOSiL'E$ ............... :"~'"': ....... .."-=" "':"'."-: ...... :""'RECTAN~O~:AR ................................... '$EVEA~TY "gE~:[:~L COORDINATES ORIGIN AT ~HE 'SURFACE .0,00 N 0,00 h 0 27' -N 1~,91 E 0.00. .-'0,3~ ¢,3a,- N '. 0.09 E ~ ..... ~ ........................ ;'-S ........ 1.5~'~ ....... ~'.3'~ ..................... -0,i=''''. ....................... g'"~?'"'Ho .......................... 0.08 '[ ..... 250, "" 2%9,99 150.99 0 .. · 'O .......... 5 0 ~ 0 " 606, ................. ~ .......... ~.,~.~ · . ' '. ~U'* ' 700.., '" 8"'"'55.'76 k,'" .......... 0 .' . $ :LO,~8 ~ S -0.05 'E S ' 0,05 . '" ........................ : ....... :-'""~ ...... ~:3" :' ~ ' U I U' S ,0,09 . ... '6' S 8,8~ W ". ,,' ' ,: 15 0.72 O,~° S" ' 0'.I0 W · ' ' ....... : ........ ' ...... . ......................... ' ............. ~' ' ............... . .................. "''". ............ ' ................ '""': ................ ','"' ..... ':': ................. ~"i ................. ' ...... T. ' · . :~9 0 ..1.0' S. ~'3,55 !4. 0.1~: ,. O,&6 ...... 0,~ $ 0.20 ~' =,:r .............. : ................................. ~, _.' ,, .. 0:,'57'" ,, 0 I1 S""-'~'8','9I !:-; ............... 0";: -3 ......................... I'.'22 ........................ " ....... 2-"~ ........ .~ ..................... :"'-: ....... 99 e. 1.! S 27,8~ ~.,;. 0.,07 1,37. ' .I',3~ S O,q'q. H . " . .... ' ....................... 0 ....... !5' ..................... : ........ 1'.'5~. ;"5':~ 8'.':': .......... : ........ : ...... :'0";'~' t,!':':"'. ..... 99' ' '0 ....... !'C ............................ S ......... 0,99 l~i . . ."' ................................. ~ ................ .. ,.. 99' ." 0 lO. S'.10..'3~. E' O,O~ 1,&.~ · i,a~..'.$ · · 0.~.2 .~' . .. . . : ' ' ....... r'7 ................ -~'"" 'J:~ ............................ "' ............. 7'~"9'";'~9 .............. &5'~"j~'9'' '-: "-:T""i2 ........... . ........... '""'S ......... 9"~'3I ~, ,.~.~ · 1.76 i.~.f-.~" S ' .,.0.~ w S '2~,70 ;~, ..n,27' I,~..,_ '1,57. :S O.t~7 u... S ~7,~7. ~.~ ,~.n, 21 1.~,.. . 1,9'/' '3 0.55 ~'J . : S 5~3,~5 ~:!" 0,16 · .2",~.-< ,-..0;,-, S 0.77 ¢~ , -. %? ;-~: , ., ~-.. ~ .... .., ~. . .... -- ';:,5" >~ · :~ '2 ..5~ '[~i ........ ~ ~'"~ '2'-' ~v ............. ~.' ..... ~. ' ............. ~ · SPERRY-SU~,j MILL SURVEY CC~'.PANY i~GO. 1,'595.0.0 . 1.5=.00. 1~2.05 .........................z ..= u ..,' ......... n ................... '"5.,. ay" ~l .......... .1: ~':$g. R. ECC~D OF SURV[Y ............. 2.57 .. , 'SEVEF~TY VErTiCAL 12 i5 S..27.75. W 1.85 1~' 0 S 30,69 k. 1.87 55,5G ?"W' ' =5. ,, 52 S 7"--,. ~ 5 S ......... ' ......... 1 I3. =. 3 .............. -;'"~,';r-"'-~"='"'~ 27.30 . 55,15' .'~ 16~ 5.:- · . I,'7' '"',,. .-.1 , ~. %56~.":~L;,,. 19 5~ $ 55. ~'~6 ',!.., ;'g' "q. 7:92 .~,'_""7, ;~.5 .~ 90 i'~. ................ i~ ~:'O'F-.- ........ I'772.70.- ......... I673'70. ............... 2;F-5'0 ...... ~-": ..... .......... .""$'""37'.75 '[.~ ................ 5 ;'0"0.': ..................... 1~9','82 ....... ..'. ........ i"'~'f;'~"~ .... ...... ,~ ........................ :. . AO0.oi - . ..... ' " ' ':.~ 2~1. i~CO. 18~5.i~ 1759,~ 5! iS' .$ ~9.1~ ~; ~...,. 5~ 2~I.~~' S'.'" 1~B,~9 . . ...... .' ...: ............. : ......... . ..... :. :..... ..... :L...._,_:'......" .."'-' ......................... ~'"'~"' .............. ~r.'~'s .......... ~'~'2...,~ . ... ~=~..o~ .,-,~,2s s zs'~";2'7":~J':: .......... ~.,., u 0 .. [9. '" '~3 ...... 2'..' -': ............ . ............ S '"~','50'"'"t;~'": .......... 3' ;'0': .......... :: ............. ~ ' ~ ·· " e~ 3~.2 5,3 · =~7..~ S' . . ~56 35 ". 2n30 [5 193[.~5 2~ 9 S '27. . _ . 2.200, 2117..92 2~1~.'92 2S E. 8 S 20.~7 ~ 3;56 3&9.~2 3:~2.~}7 3 20~.10 '.!:500 220~ ~6 '213~ ~ 50 ~. S. 21,25 W I,~3 · 2~00. 2299.73 ' 2190.73 ~1 30 S' 2i.~9 ~ .1.~5 4,B9 --'""~'"7 ..... 25U'0';' ........ 2375; 60 ............ 227~, &'~ 33 ........ 0 .................. V"'S" 2'!; l~'""[.; ..... ; ............. %-'5i .................... .. . . - , ' .. =; ~'~ 3~ ~0 " '~ .2~ W ~0 ~6 ~'"":'-'7; ........., ~'7~''~, vu.: ........... '~'~a'~ .... .... e ...... ~'~ .......... ~'a'~' ~ ..... e~a"":" ................... . . .~'~'"'n~":u~. ...................................................... .' ' ............. ~' ~[e ~5" k ~. .... ~'"~ ......... ' '~F~ 2&~~ ~5 252~.~'= .52 26 S 21.~2 k: O. .... . ,.!600. .~. .... · ... ~ ' ". . . . . .....' .. .. ..... . .... .....'... ..... . . . . .. . .. ..... . :.. . . . .... .. . . . . . .... . . . . .. : .- . .... . . . . . .: . . . .............................. '7;" ~ .~ ......................... ~ ~ ' ~ .... ,' ~ ......... ' ......................... .~..~3. 2, ~.,.5'~ ........ 2'6'II'.52 ................. 5.I ...... gZ ..................... '"'S 2[';'13"'~ "O.b~ ............................ 7'5'5",2Z-' .............. '~7S";'55""S' 33G",2'3 W =n~C'. 27~r~,~1 25~7,~ '31 2 S 21.28 W .n.r~ - =~GC,. 2.~.~... '~5 27S5,;i~.. '30 .~6... S 21.27 ,,~ d.~5 -~55.27 ~ ~'~" :575. ........ ~ ........................ ~ ..................................................................................................... '"~ ......"."~'7 ............... . ......... ' .......... : ......... :': .............. ."".'"'" ...... ~'-'": .... .'"'/::'; .......................... :'-'~: ........ : ................. ":" :'"-': ........... 7 ...... ~ ........ '": ...... ~.:-:"-:":' · ~,;;~.,~UREG VER'rZCA'._ ' .... 2~.FTH DEPTH : ~800. 5~93.4.0' , . . .. ..... . ~ ' __I m ' mm lT.m JUNE'' 22' 'I97~ '.$'pRVEY DAzE .... · Vr_RTI.CAL SECTION CO;,'iPUTF_D ' ~3N O~ AL G Cl_ ,.,URE SPERRY-SUN ~ELL SURVEY'COF4PANY "'~"' .. ..................... ~ -..~.. RE¢ORO Of SURVEY .... .~' . . -- I'~.~'CL-I'~.~-T']:O~.~ ..... 'D:! 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OR i-6'IN A L DIRECTIONAL SURVEY REPORT RADIUS OF CURVATURE COMPUTATIONS FOR '11 I I UNION OIL COMPANY OF CA'LIFC~NIA ! ii i i ['1 I I I i I I .. TYPE OF SURVEY: , Gyroscopic .DtrectionaI Multish°% SURVEY DEPTH: FROM Surface ' ~. TO 11,200 .~. ~EAaE: Grayling TBU State WE~ NO. G-22 Redrtll FIELD:. , McArthur River COUNTY/PARISH Kenai Peninsula Borough ' STATE Alaska -- 9ATZ O~ SURVEY. June 22, 1975 '-~os NO. SU3-16999 OFFICE: Anchorage, Klaska '.'~II~'~'O~i...~ZL."COi',iP~'Y'o'i: C~LZFCRNZf~.: ...~.'......'" .':...... m qllll' '' : 'm q ' ' ' q ' mi ' ' ' ' ' ' ' '' m mill' '' ' : ' ' qllm ':' ' m :q''' ':':~ :~:' ' :":'~' qll'lllq: qOl'~':~ ~q~ 0 ~ m.. .sl~ ~ vl~ ~ ' '~ U ~'~' q ' ~ ~ ''1975.' '"',' ." G-~'.~'" ,.S;~A YL1'N$ "'PLA TFORP9 '.....i;.:..:/:.~.:~!:?.?.:`:...~.i!!!?!.~.:.`:.:.`?:!:...~..!....y..:.c~¢iPUTAT~.N ' OATF. 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'" · '~,CARTHUR RIVER.-' .': ..... ..:'.-.....:.'~....::.' .~ :'.. '"' :.'.:.. dUNE.- · .....~:...Z~75 .. .- ..-:';';' '.' d'~B .NU~,BER SU-~"~69~' .. '' ALASKA "-"~"'-'-:'." ..... '- · '..i`...~.?.::~:.::::~:`..::.:~::..~..:~:~::~....~.:.`.!`:~`..`.~.:>.~.~:..:~.:::. ..... ".'"'.;.~-:..-:'.......:'.'....'.:..".::...:~. ...... ..'...-, .....-f~....:-".:.-v...-':'-..... K~LLY 'BUSH][~,=G ELEV,. ':' 99.00. FT .. , . . .. ...' .'......... . ..."'.... . :. "".' . . .:'... ..... SUB-SEA · ' ,, '22~0 '2~OO 26'36' 2.700 2036.~ .OEPTH .. · ..... - 2Z2~,.~...'¢:2025,~ 2297,50 2633'58. ' 2~'~,58' 2718.57 ~6.19.37' .. · , 2975,.~7' Cou,s~ '.'-.':,' · I'NCLINAT~ON DE6. ~r~ .. 26 -50 3~ 38. 3O · 35 0 35 30 32. 55 C,E~REE. S $ 27,=-0 W '..,-' 92 EAST/WEST SECTION 2i2,2<9 516.65 676,55 728.11 ?7.a,..~&. .50 36 8'21,37 ~ ;'....' 0'~3' '" ' 752'o~5 S 30 2 $ 19... 0 W "1,27 '"""'799,~3 S 3'66,38 W · . ""."'876°03 '33~0 ' 30~2,.82 2~&3.82.. 29 3~. '$ ~9.~5 W 5;17 B~.5.~ S' . 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'.'.:'.:..."': ...:':'..{;.'~-".'".?"'.'.'I::O~'P'UTATIO~ DATE: ' ' .... :'.'"SURi~E:L ~YRoS.coPZC ~iULTI:~.HOT SUA'[ '~" ..'..'.I"lCARTHuR .Ri'VER. .. '" "~ .':. ': .... .' '...'".~JUN£': .. , lg75 " UO'S NUt~BER SU-:5-16999 . . ALASKA '"' '"' "' "" "'~".. ""'"'"":'""'"' ...... "'..'.' "" ..'"".:.'.':":' ':" '." ' . ." KI~,LLY. . ~USFIlN,~ ELE¥.. = 99.00 FT. '~:* . ', -'. " Z~O POINT-INCLi'~;O~,ETE~ A..T 'KBE__ I I I I~ . . ~ I I I ~ U . :l'r~ ~'' ~I I iT I .... I i i iI II , i I II .... I .:' '../-- , OTAL ...... , ...... . .. ... .... ~IE.ASURED ' V~,qTTCAL VERTICAL R£CT/~.N~g-'LAR CO0.RDI'i~ATES' ~.~D".Tvo .' VERTI~A'~ -' "" .... " '"' DEPTH DEPTH " OEPTH NCRTH/'SOUTH EAST/~E'ST' ~IFFERE~,~CE cORRECTiON.' '"'" ':' . ...... '.":"" '.":'..":'..". ...... I0'B'9~ ."~.'"~'.... 9'*g'e.'O0.. ' e~O'O',O0.'.::.:.' .'" .:~'e'a~:..'75.s ....'.. '2~e.3~ ..~ .... i~e7,9I.'.' ' '". '.'i~..'~": ...... "" ": ."" · ..' 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OF CA'LIFORNIA TYPE OF SURVEY: Gyroscopic D'irectionaI Multishot SURVEY DEPTH: FROM Surface · EA-~E: Grayling TBU State FT. TO FIELD: McArthur River 11,200 FT. WELL NO. G-22 Redrill COUNTY/PARiSH,,Kenat Peninsula Borough . STATE Alaska DATE OF SURVEY June 22, 1'975 JOB NO. SU3-16999 OFFICE: Anchorage, ~laska .- ............................ . ......... SPE. RRY-$Uk; WELL SdRVEY'[Nj CO~!pANY ' PAGE I '' .. . ANCHORAGE.~, ALASKA L!NIOr,~' ~ZL.., CO;,;PANY OF CALiFOrNIA DATE OF SURVEY SRAYLti"'G G-22 CoF'PUTATION DATE . SUF.~iEL GYROS.COFIC FiULTISHOT SURVEY -~'i'C~RTHUR"'RIVEN ..................................... dULY '25~ 1975 dOB NUi'.~EER 8[J3-1699~ ALASKA ' KELLY BUSHING ELEV. = 99.00 FT. TPUE e,~... _ . _ . ,..,,.,,~. S,';" A COUR~F COURS~ BOG"L~S TOTAL F!EASUR C VERTICAL VERTICAL 'INCI. I,~ATION' DI~ECTZO[4 SEVERITY RECTA~ GULAR COORCINATE VERTICAL ~'E'PT'~ ................... DEPTH .......... DEPTH ............. DEB-' ~.~ I'N DEGREES DEG/[O0 NORT['~/~n''~ , H EA ST/~EST. '" SECTION lO0 99,$9 O. 2nO 1~9,99 100, ¢~ 200, "' ~Q'O ,. ..................... ~.. 5~9 ~ 5oo, 700' 6~9,9S 600, 8~0 7~9, 56 700, ' ..~..~.9 ............ e~.?,..~~ soo. l~O0 999,97 .................. 900, Ilco I09~,65 lO~O, 12n..~_.. ~ 1199,~9 llOO. · ~'rTj'.:'-'Z ~ ~'~]' ~ .'. . ~..,Q 1595,92 1296, 1500 1~93.17 17S~ 1800 1776,~7 1677, ' --"~'.', ............ , 1~ ................................ . .... ', '. , . . , . , '" 2000': '"'" 19~+9,02. '" 2100 ................. 2'2C,.'6 .............. 23~' ,j 2210.2~ alil, 2~": :'~ 2~96~ , ~+. 2197. . , . 2 :: .:' '..:. ~':..' ,' . Z," ..... ' ~ % .... .. ,,. oo 0 .......... o .............. S .o.,. o. 99 0 11 S', '2,35 99 0 50 8 2%, 66 ~a' . o 9-. .....s e~.~f 98 0 'I1 S 8,7~ 9~ 0 2~ S 9~ O' !2 S lq,76 9~ 0 · i2 .S 97 1 7 S 0,~9 85 ~ 9 S 1%, 61 W 29 7 50 S 2%.58 ~'~ 97 ...... j'~'=[-d ......... ~ .......... S 17 I~ 81 S 25,67 W ~7 ............... ~'~ ............ 53 ........... 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DEP T N 5100 2868,68 2789, ........... o~' ~ ~""5 ..... : .......... 2 97'5 ~'~ ~-: .......... ~ ~ 76. . 3600 ~B26,2% '~227, ~?vG ... · ". ............... 58gGi"; ....................... ,50G,~?~ ........ ~ ...................... ' ~0~,~" $9~0 5585,78 ~&6.' ~OOO ~670,26 .~571, ~'r ....... ~". ............... ~''"~ ......... ~ ...................... ~,,',~" 75 ~8'15 ~CO 3917, , ~ ' -~ ......... i ....... : ......................................... ~ ..... .'.'.. ~O'O ~000,30 390"1'. :.,., . . , 4900 ~2~.~ ~525 '~:.' ...... ..Suoo~<':'"' ........................ ~51.1,.o' ................... ~'~ ...... : ......... ~ .... 51~0 "4598,25 5200 ~6~4'.71 ~585 . . ~8f..7, O~ ~75~: 50 ;29,5~. 4$~O, 5116,35' 501'7, 5290,73 5191. '~= ' 22 527* ~--" c~ b~,~i~. ...~¢~ ~ .. . . . SPER...P,__y..-SU!,,: .......................................... WELL SURVEYING COpPANY '",;'.::'RA6E'. 2. ..... '' A~:CHCRAGE,,, ALASKA .COF~PUTATZON DATE uuLY 2"9, .... i975 COURSE 'COU,SE oo~-L~e" "INCLINATIO~ D'!KECiiOH SE~E~tTY .......... ~"~-" MIN .......... DE~R~ES'" ""DEG/~O0 ..... N'ORTH'~SOUTH' DATE.OF 'URVEY.gUNE sU~.~EL, eX~Sg_~p:~ MULTISHOT SUR~_ ' KELLY BUSHING ELEV, .:' 99,00 FT, ...: ..... . ' ' '" '""~"' " .. .'.:' !i ;".;". .... ' ....... :?"~'~'""'" ' .... · ..::....~?.....::~:~:.,.:.!.:...... EAST/~E'~'T .'~SECTION" 65 30 20 S ,1. 6 ...... --""2'9' 96 '.29' 36 S "J3 '" ' 28 O' S 13 O0 .............. 2~., 28 25 'S 13 ~'1 29 20 S 13 ~7... '" .................. 78 "~1" 26 · '75 5~ ~7 S 2_6 30' . ""'"'""5 ,7~ W 0,68 795,47.$ 275,3~ W "':":':"'":835, . ~ 2 ~.c. ........ 0 ~ ........................ ~ ...... . '~ ".:..::.::~i,i:i::::~'.~'sO. .... , ~ . ~,.. s~" S .. ~7, ~ ,82 "~'. .................... u,~' 30 ..................... ~85,24 S 52~,25 W 1020, ':":~ ~ 066, ....'.,,- ¢ ;99 W ..... . .... ~'"'::'~'9~ ~077,77'S . . 3e6,~5 W ,.~' ~ ..~' :-. ........ -it'~&','~.i'--S ;.:.'..'::-~-~;:95 .~ :,,~' ~,~o..: :zz?7.oo s,..' "'"..3.6'~,~'~'.~..':.....~;'.::'~:~;'.iazz. ,62 :,j o. se' ""zee~.z~ s ...... :...'..":.'.~sz', ~7 '~'"'::.?;.:...::~:::'.:;:.:~::"!.~..~.~'. . 5 u ~.zz $~sT.sa s 4~z.4e ~ , 9 W 2,87 1389.82 S' 4~,2~ W '"."1~29 , a"~ "-~ ....................... ."O', 'e S' "'"'"']: ..... ~ ~'~'0"; ~ ? "'s .... m~"~-gTi~'". U:; :'"~.:.::::~:~:¢::~ 8'~ ~ 83 '32.'~6 S 19 '32 12 .S ~5 ......... :i ....... 53 ............... :S 2~ 31 5 '.$ 5~ 30,* 5 S a 5 ............ :'~'~"": ........ i6 .............. s . · . .,... .. . ~ 2.9' ~ S 66 ~0 29 $ 08 38 22 S 3i 30 30 S 5~ .............. SO ..... 15 ......... s ~'~ 29 ~6' S ::': 2 29 30 S 73 29 ~ S ,~ .-. ;'~ % S 25 25 '25 25 25 25 2~ 2~ 25 ..es w .................. ,.,..g~59 15~8.~o s 506.25 w"'"",'...:i:::::::;':¢~5~, ,63"W '0,37 ................. X586~'3'0 S 529,0~ W .16~7. ,56 ~ 0,8~ 1633,~6 S 551,59 ~ .". 1699. ,28 W 0,97 1679,~0 S 575,~2 W "' ~.~5.0.., . '-: .......... :'-5¢'~', S w' '.'""::;:.¢!?"!:.'z8 o o, ,?~ ~f ......... o,65 isz~,a~ s ....... ] ...... 6.~6,66....W "'"':'~??'".~899, ,80 ~ 0,~0 ............. i660,~ S &57,9~ W X950, , 5 W :S,~8 .'~906,25 S 67'9,29 W 2060, ,70 W 0,22 Z952,21 S' 700,59 W '?"~051, , ¢~ · ~ ..................... ,~ ;~ z,s~ ..... zsg?,~ s ........ ]7~'~';'?g'"~';'":::.'%'::e'ioz,. . ,75 !..i ~,~9 20~8,80 2 7q.?,19 W '"'.".:::'..'"8~51, ,95 W l,ll ....... 2082,02 S ......... ~.7~,.79 ~ :": .... 2200, , 5 W ~.0~ a~a3,05 s 800,~5 .-.% 31. ?,'2 22~9.06 .... ".. 0,28 216~.1~ S 826,05 W 2297.38 6.3! .228~;,67 S 851.~8 W 23~5,28 SP~.~RY-$U!..: WELL SURVE¥ii'..IG COF'PAi'GY · .. .. ANCHC. RASE, ALASKA JNiON "iL' CCNPAN¥ OF CALIFORNI.~ ~CARTHLR 'RIVER .................................................. ~LASKA .. COr',PUTATiON DATE ._ JULY 29~ ~975 .................................. PAGE D.. T~UE ~EASbF'~'~ VERTICAL )Ep'fH .................. DEPTH ..... DATE OF SURVEY uu~_ 21, 1975 SUF%,,.'EL GYROSCOPIC ,"1OLTI,,KOT SURVEY dO~. ,'~;J~DEN 5~5-~5 .... KELLY ~u~HI ~ ELEV, = 99,00 FT, $U8- SEA CObR~'E cOURSe_ DOG-L~6" TO T AL VERTICAL '"INCLZNATZOhi ~IP¢¢TIO?,; SEyE~Z-TY P. ECTA!'.;GULAR COOPBZNATE$ ......... VERTICAL DEPTH ............DEG' F!i~.~'" CE$~EES DEG/ZO0 ~,!ORTH/SOUTH EAST/blEST SECTIO::,i · 6~,,~._. 5 ......... .... 5,66 5~5~,65 2~ 52 S ~,59 W 0,~5 ... 63n. C 56~0,.~'=8 ................. . 55~1,58 ................ 5'~';"'"22 S.~l,6~_ !~ ..... 1,50 6~'00 5726.~6 5627,36 31. 8~ S 52, 6 W ~,~ 6500 5811.70 5712.70 31 21: S ~2,2~ W 0.18 ........... ~i"oO .......... 5's~.s."sz .......... 5797.~1 ................... ~2 ........ 0 ...... s'=2.,'s.~ "' ~' 670C 5981,76 5882,7J ~1 ~I ~ ~2,~ ~,! 0e52 .................. ':.u. .................. 6067. .............. ' ' "" ............................................ 81 H 0.55 6909 6152.2% ................ ~055.~ ~i 50 S 32. 7~0 £2~'?,78 61~6,76 30 ''~ "S 32,60 W 1,28 22~,5,72 S 2287.8,5 $ 2.~75. G3 8 2~1S.97 S 2~6~.~.~& S 2506,~ S .. .... !0L[.2.,05 %.; ................ ~702,~9 2552.~ -,~'1 S X070e*~ W. " 2755,06 2595,98 S 1098 ~'2 " 876,71 W .......... '239~,21 (" 902,5~ N 2~6.2_,55 929,65 W '2~9~',~ 957. ~.1 W 25~5,8~ "985.53 ;, .......... 2598.2& 1015,86 ~.~ 2650.82 '"" "-' ~0 S 11£'. 66 W 285 95 71~0, 6~;~q'._ .1~ 622~,I'~,. 30 0 S 32,m2 "~ 0,56 ¢~6~A,._ :,.. . . ....................................... ~..~ ................ ~ ' · ................................... · ............. ,, ' ........................ ....... 7200 6~I0,~,~ 511 85 ...... ~9 ~5 ............. ~"S'"32 83 W" 0,~5 .......... .~680',~6 $ 1152,67 W 2906,60 7~0~ &~7,6~ S598,63 29 51 S 31,97 W' O,~ 2722,22 S 1179,29 W 2956,17 7~CC 658N',37 6~85,37 29 50 S 32,20 N , J,12 27Gq.,~8 S- 1265,72..H .................. 3005.82 .... .. 7500 &'~7l';"O'O ................... &57~.0'0 ........ ~ ....... 3'0 ......... -~; ........... S""'~a.'O'W .................... 7o.28 ....... 280~'9 S ......... 125'2,27 N ~055.65 76:,0-' !,757,~0 6658,60 ~ 55 S ~2,~6 "~ 0.29 28~9,00 S ~258,9~. W.. ~105,5~ 7700 68~.0~. 67~~.,05 ~O 25 S 32.~8 V;. O.~O, 2891,~9 S 1285.92. ~:4 ~155,6G ......... ;~'*'~' .................... "'~ ..... 02 '"68~1,02 51 ......... ~ .................... S-'SZ,"&2"(~ .............. '~ 60 .... 29~,~,~5 S .... 151~,~0"W ................. 2206,59 ( 7 .... ~,O 69~0, ........ ., u, - 7900 70!5,~6 ' 6916,66 Sl 9 S ~a, ~ W 8e~ 297~,07 S 1~1,00 ,¢~ ~258,09 ' 8000 7101.1~ 7002,3,~ 51 -~"-T'"81dO ............. :."-7I'~6,'39 .... . .......... 70~7.3~ .................... 5~ ..... 6'0" '' '520G 7271,~ 7172,5& " ~.' .32 '" .. ~5 '31 25 ..8~..~.0 ................ 75.56,~5 7257.~ S~O0 7~2.5~ .......... 7~3.5~ .................. ~ ......... 39 ~::5;" O.... 7528, ~2 v.'~i ~. g r. ...... ~ i...f.~. ...... , , i,~,~ 1. ........ · -'.U,J 7970 ~ 3- ~;~..'~ '"t ~' ' ~ 0 ~'3 . ~G.. ~.~ ~ .. . ~ c,, .~:.,' L' la ~+ ....... 76d~,$5 ............. 27 23 7693,7~ .27. 16 77~'''..,~:.8~ 27 '2~ 796r,,~8 ~7 1~ .... S 52,15 $ -31,80 S 5I,&9 ... $ 31.57 S 3i,18 S $ 52,52 S 5 ~+, 7 S 5c~, 1368.63 '~ 3509,86 ., . 13 S6.5,, ..,; ..................... ~2.0 i ...................................................................... ~F~REY-SI:i',: WELL SURVE~Ir, iG CO~'~PAi~.iY ..... · · PAGE ,. ANCHORAGE,~ ALASKA '~i'rOl'? ,OZL eOF, mANY OF CALIFORNIA DATE OF SURVEY ~U~'~E 2[, ~AYL.~;'..~ G-22 CONPUTATION DATE SUp~JEL 6YROSCOFZC ;',u~ SEO'T SURVEY :'~RT¢~U',q A IVEA .... JULY Ag~. ~975 .................................. doe NU~.:~BER SU3-26~99 ..... .ASKA "' KELLY 8USHIN6 ELE~~, : ~9.00 FT. TpUE SUB-SEA COURSE 'coURSE DOG-L~6" TOTAL · :AS' ""-" . -- .- ur~,...[: VERTICAL VERTICAL 'iNCLIi'tATZOH' DIReCT.ION SEVEaI.TY RECTAf,;~:.ULAR COOR~I,'4ATES VERTICAL ~ ' ~,1 r~ ~ '1"' [.J . ' ......... ~"PTH""' DE~TH DEPTr: BEG ..... ~:~,.T N DEGP, F'ES DE'G/~nO ,.~,,-,-,/SOUTH EA ST/-~;F_.S T SECTZON ......... 96'~'~ ............. ~£~.~5 .............. 8'225.~5 ...........~$ ........ ~0 .............. S~'55.20' W-] ............ 0,62 ~1 29 20 S 55.~8 ~ 0.68 ~00 8~11.91 8312.. ~600 8~8.7~ 8~9~.7~ ~0 "~:' S 35.'~ W ,. . ................. ,,, , ....... 97 g ~.5~.~ 8~S5.~: ................... 3i' '2'~ S ~6.~0.~ · ' ~7 8570. 3552.79 S 17Z[.17 ~ 3~39..55 f ~53~.76 S ..... 1758.36'"'W ............... ~98&.77 5631.~1 S 1766.~2 W ~671.63 S !755.51 ~,i ~08~.07 ~712,9~ S 'i825,~5 ~ ........ ~755.08. $ 1856.50 W 4186.5~ ~SO9 8.75~.51 8655.51 lO90C "'88~'8.'87 ................. 875~. ..................... [i9 ......... 55~n 5~ $ 1920.75 ~ ..... ~292.25 10100 892~,2e 882~,29 '~2 "~ .'S ~8,27 W 0,~2 ~882,82 $ 1955.7~ W 1020~i 9006,97 8907,97 ~ 50 S 38e5~ W 1,29 ~925.72 S 1987',7~ t~ ~$98.,97 ...... i"b'~ ......... 9090,'S'5 ................ 899'1~,~ .................. logo0 91'7~..0~. 9075,05. ~5 1~ $ ~9,8~ 'W 0,70 ~011.~2 $. 20~6.75'" W ~507,0~ ;1.0700 '9~aB.~! 9~0,31 30' lO S ~1,31 W 1.06 10850 9516,06 . 9~17,06 29 .~O · $ ~O,8l W 0,71 ....... ~"90~ .............. 9'&6~'.'5i ................. 950'~15~ ............. ~6 ........ 50 .................. S 6i',2[ ~ ........... 1,0i ~5 8a 7 S ~1,15 ~ llOOO 9691,55 9592,~ . 1~.i00 9779,~7 ~680,97 27 ~. $ ~2,~ ~ 0,57 ":""1'. ia"; ;o ........... .... ...... .......... .................. , s e,lm " o,.. .... . ~052.70 $ ' '2091,q6,~ ~092.71 S ~51.25 S ~2e8,75 ~205.5~ S ' ' ~276.&1S ~519.09 S 8559,~2 ................... , .. .......... 2515,72 %.~ ~892.80 ~.- ........ !_H.,~..I_~.g_i'.?.:['_~_L..._g.!.S_p...LA...i.C..E_?!I.E.,r!JT...=......... ~ i 9.~i ~ mi .~ ilo~ ...... FEET AT SOUTH., 2~ ~£G, 1~ NiN. W£$T AT ',"'iD : ~1200 ,, THr:', C¢,LCU!.ATIO,',; PROCEDURES ARE BASED Of",; THE USE OF THREE DI?i~:N$IC,"iAL RADIUS OF CUFVA,TURE i':,,[~THOD, · , :, .: j..',:.'.'. . DATE OF SURVEY.UUN'E 21_e .1975" 'SU..R_!,!EL. GY_~.O'SCOPIC MULT:I:SHOT SUR.V.E_Y ...... dOB NlJr'iBE~ SU3-16999 ......'. · KELLY BUSHZNG ELEV, = 99.00 Fl', .. 'KELL;F'"-E~ISHING ELEV.. =' .' 99'.00 "F~;' .........' NIO~:; 3iL CC?q~.,'g~Y OF CAL!FOE?,!IA RAYLI:.'.'G G-22 L~SKA LASi,',A ANCHC. RAGEt ALASKA Co,FPUTATION DATE duLY '29~'-[975 ...... Z-I~!'T'i~'RPO[A'TED""-~rA'[[i~-'S'""J~'oR'"'"Ei/'E?,i 3.000 FEET OF ,rqEASURED DEPTH TRUE SU~-S[A TOTAL EPTH !~EPTH DEPTH NORTH/.$OUTH EA S.T/~'~!EST CZFFERENCE cORREcTION . '" ~000 99~,:-7' 900,97 5.~1_ S ~,58 VJ '0,02 0,08 .~8~0.56'S --~-~z"O',"c~'s ......... ~OnO ... ~9q, 9. O~ 1650.02 ' 2~5,17 S '1-29.72 N ' 501'97 ' "50 ~- 9~" ' ' ' ~!i['. '" ' ' ' ... 50 rj 0 .' ~ 5 ~ ~ .. 23 . ~ ~ ~ ~. ~ 3 . '. ". ' ~ 72 ~. ~ "~ ' ' "' ' ' ' ' '"" ''''''~' ': '. ;''~'':''''''.' ':;'"::"~":~:;;::~:~:"":'~:~?' '`:`~' ':' ' ' ' ........ -&~'~ ........ '5'3'7'6',':~'~ ............... 5279. c2 .......... ; ....... ~'~"6~'.Z~ 'S 82~.08 W 6~.77 ~33.00 ' "....:.'.????:..'.:?::."... ". '. 1098,~2 W 762121 1~0,~ .: . ':~-'~"d"d~ .................. ~?'97.0 ;'~z ................. 7~71', ~ z ~ ~2.,'.2~' ~.. ............. ~0~. ~". ....................... iS"d'~ ~' ........ '"""~" ..' .... .."'~'~"'"~""'"~'~:~'~"~':":':::~':"'"'~""".'.:.?:" ~,.~:,~..~.:?,:~;?:.~?..,.~.... .... ...... . .. .~','.: ?-:'~".... '. .10000 883~,87 ' ~73~.~7 1920,75 W 1161,12' 11~00 9691.55 B5~2.55 225~,52 ~ 1508.~ ' 1~7.32 ...... _ ............. ':" 2e. ..~.:...~....,....... 'THE C;~LCULATION pRocEDURES' ARE BASgD ~N. THE'USE OF THREE GIgENSIONAL RADIUS OF CURVATURE ~E'THOD, .. . '......... ............. . .... ..' . ."; .~" ... .. ..~ .~ . ,'~L... ..'' .,. ..................................................................................................................................... :, ...,....,. :. INTEEPOLAT ....... :.- YR,3-~- ................. MEASL;~.~_-. ,.,..:; VERTICAL VERTIC :DEPTH DEPTH OF:PT . . j '0,00 -9'9,0 9°~. gg,00 "-~ .................. i'~;"~- ................ i.s e ""0'"'o ................. i o o. c, ~ 2T"~ 299, O0 200,0 .......... ~ :-.~ ....... 'Z '~ ..... ~ ~ ..... ~ ..... ~,. .................... ~.:.~ 0, " , '"' 5~5 599,00 500,0 '"': 6~9 G99,00 "' '600,0 ~'"" ....... :~'~, ~ .................. .'~ fe ;'~"~; ..................... y'o'o. ~.~ " 8~9 ~99,00 800.0 9~ 979,00 900,0 ..., ...'.." ~ o e9 '. $ o 9'9~'~F~ .... ~--'"~ 0 o o. o ".":" 11~ 1199,00 1100.0 1~C~I 1299.00' 1200.0 . , iSr~ 1~9~,00 1~0C. rJ .- ~ ..5 00' ................. 1600,0 ~ .......... :" i 7 i '~': ................. ~ '' .... I~2~ !799,00 1700. $.URVEYID'G,~ COr:;PA.~.:I.Y_ .................... ANCHORAG~ ALASKA ,COFIPUTATION DATE · dULlY 2~,' 1975 EF; VALUES ~'OF.., EV'~t',," 100 FEET CF SUB-'SEA DEPTH . · .. - · ~ A .................................... T 0 T/: L ::::::::::::::::::::: ....... AL RECTANGULAR COORIDINATES MD-TVD VERTICAL ..::::': .......... '... H NORTH/SGUTH EAST/WEST DiFFERET4CE C(~RRECTiOt.; ' :'?.??:."'. ' ............. ':'" .'TT-.· ''-'~ ......................... , ................... ,' .' ,' ....................................................... . .... . .".'...'.. ?::.'..'::?.::<i:~;'~!i'::;:i'.,:!;~i:f:...'.:.'..... o. o o o. o o o. o o .'o o, "'" "' :"'," "::".:.'! :'.'i::: ':?::.'" "0.;.15 S 0,00 E. '0.00 .0 i:: .................... 0.~ S .............. o-..aS' :~ ........................... i~', o'0 ..................................... 6.oo' ::....,:............ '. 1,75 ,~ O, ,,,,, , . 5 ~ '~ 0,01 · 0,00 "' '??:''''::'''''' :' '..' 2,D5 S 0,50 W 0,0 o ':0, 0,0 .... PAGE . ~ ....:?.-:...... DATE OF SURVEY JUNE 21~'..197§ · $URV~EL GYRO. SCOP~C MULTISHOT SURVEY · ,JOB NUF. BER"'"$U'3;[6999 ..:. ........ KELLY BU.~HIN$ ELEV, =-'99,00 FT, " '" .... .... .:. :.:'::,'.. '. :...::.~.:.' ::!:'..;<~!!..:.'~ , · . .. . .. .... ..... "'..."......::.'.i~i~::.:'i ::.~....:':.' .. (. '0,14 S '~,22 W' '0,70 O,SG' $ 12,72.W ........................ 2~.0~ .......................... :'. ......... 1.,_~5 ~ ~,15' 2,11 S 30,89 ~'~ 7,01 2,B6 S ~3,?0 W 'S ........ : ......... 6'0.60 b;': ................... 16.76 ........................... ~,95. .. .5.79 . O0 '168. . · .. · . UhIOi',~ .O'.','L, COPiPAN¥ 'OF CALIFO'~*'n..~IA 6R,A.¥L! ,,~.~ 6.-22 '[';!'~'~ F, T 6- (,'i"{ -'R '~: '~' E 'R- ..... ALASKA 8_PI~.B. RYr. SU~i WELL SURVEYING COMPA.N_Y._ ........ A~-,CHORAGEo ALASKA COF'~PUTATTON DATE d'u~Y 29", 1975 ...... '. '",i'; .'.'"' '... DATE O~ SURVEY dUNE 21~ i975 SUR.I,,,F.L. 6.Y.~O. SCO.._P ]:__C_.r:!.U_L_T_I sH_O..T___S_UP,.V E¥ .dOB 'KELLY BUSHING ELEV, '~=~=!"199',00 FT, · . 'ZNTERPOLATED VALUES FOR .EVEN 100 FEET OF 8LI.~'-~EA DEPTH T~t'SE ........ S't~ r:;:'S ~.'IA -- F:E.~, S U F',6 i:: VEF, TIC'AL VERTICAL EEPTH DEPTH DEPTH TOTAL RECTAN6ULAR COORD. ZNATES NORTH/SOUTH EAST/~4EST .o oo ~1.7..~1 s' .!~.~ ~ oo .................. 5~,"Ol ~ .1~0~6~'~'" O0 578,22 8 17~.1~ W " l~q,~ · 1899.00 1800, 20 ~5~;. 199~,00 1900, ....... . .... 2. i","':;,~ .............. :~09.~', a'O ................... ~o0"o', 22,.::. ~: 219~,00 2100. 2q'::~ '..'22~, O0 2200. .............. ,'. ........................................................... 2~,~I 25e9,00 2.~OO, 26~{i 2q99, O0 2~00, 27~5 ~1' 2599,00 2500, ............................................ ~ .......... :2955 2,79~, O0 2700, ~1..~ 28e~.o0 .................. ...... .32~ .. 29¢~,00 33~2 '." 3.099,00 '30 '· 3~55 5199,00 .- ................. ~-'~"~:""- ............. =~='o '0'0 ............. 32 ..... ~ o O .................. :~.~.~.., ~ ? s .. O0 ~.9.8,01.8 Od '. 561,72 S O0 G2~,7~ S Od .................... ~8'5',[[0"'8 ........ 2'~8,25 O0 7~,7G $ . 2G2.71 00..,.00 802,~$ 8 276,77 oo.oo ....... ."-.".~: ..... ::858.~.s ..... ,2~!..z0 00,00 "~13,50 8 305,56 00,'00 965,~ S 318,36 00','~0 ................. ~'b16.5~ S $~o.98 5~$3 3399,00 5~00,00 1069,70 S ~.~,1~ ~.! 28~,01. 579~' 3~99.00 5~00,00 112'5,~1 S ~57,76 W 299,59 .............. 7"'~g'i~ ............. :'""'~5~s'.'oo ................... ~5o.''"~.oo ................ · .. ............... 11~=.- oZ s ........ sTz.,as"~ ............. ~16.56 . . . ,.- . .. ~O~ 3699,00 3~OO.OO 12~7,19 S 386,01 W 3'55.'17. 2,~.1 N 1 2,82 ... . . 18, 7', ~ ~ W .1. ~ ~ ...... 2.78 .,...._.. .............. :.~...,, ~....5 ~ ........... '_L....: ...... :_':._.~.-_.....~.:~_" .:::--"'L::::::'.i:<'/i~'..'!i!;~!~: :':.. "~,~ 179,5::1. ~7,96 '. ."..':"'.'::'.'.." ' , ., . ~,., ~. e ~. ? o 17. ~. ~. .' ::"<<:'.':....... ~ ................... 2.~.2, 9~ ............................. ..'._;t.6.2~. · "" .".':.: .'" ' ''''.:'' W '.22.8', 50 ' 15, 6 ..... "' ......... :':""~'"':'"':*': ~ ,,~ .... "'....: ..:¢.:':'."4.: :.:'x'!.::~:~ .'.:.::.".i::.'~t.;{ l:: 2~'5.57 'W 256,9~ 13, ~,6 ' :": '""'"':":':':??:!~ ., .... · ,,~ ...................... 27 o", o 2...= .................................... i' ~';'~"? .: .,... (' 13,98 ..................... 15,,s~ 17,i7 .18~&0 .................................. :. ............................................................. __:_=i.s.P-.~..P,.E;.Y-$UFI WELL SURVEYING ¢O.~:!PANY · . . ~NIO.~,i CIL CO~:iPANY OF CALIFOP, Ni.~ GRAYLi'I'~ G-~.2 ALASKA · ..................................................... . ...... PAGE 8 ANCHORA'~E, ALASKA DATD OF SURVEY dUNE 2$~ [975 CoP, Pb TATI ON DA..TE .', ................................ _S. UE',.~EL G TpoS~C~!'C..f~)U~.~..iSH~.T...SURVEY dULY· 29~ i975 dOB NU;~BER 8U3-16999 KELLY 8~SH[N~ E&EU~ = 99,00 FT~ " INTERP.OLATEO VALUES F~R .EVE~' lO0 FEET OF"SEE-SEA DEPTH · · .............................. CROE ................. SUB;sEA .............. TOTAL ~'iEASUR~ VERTICAL VERTICAL RECTANGULAR COORDINATES F,D-TV'~ DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST ~"jIF'FEREi',JCE .. ~6~S6 '...~.199,00 ~iO0,O0' ~555,9~..8 ......... '51~,52 ~ ":'i ....... . ..... ~'-ri~ ........ :"".'""~:"~'~, oD ~eoo, o'O':'l ..... "~"-:'--i'6~'2, ....... :'-" ........ 02 '8 5~1,37 ~ ~570' .~39~-,..nO ~300,00 16'66,0~. $ 567,~5 t{ ...................... .. ' ............................... ~ .... - ..... n ..... : .................. . 68 521~ ~699,00 '~6'00,00, 182~,$? S 6~0,19 b~ 5~I~ q799.00 ,700.00 1675.57 S 66~,89 W VERTICA CORR~CTI 21, 21. L o.~! ........................................... (' 76 2~ ~71.70 ~6,'.5~ .. ~86.,96 15.a7.' . . ............... . ................. · ...... ..................................................... 501,~5 1.~.,~7 517,5~ 15.75 5~3,a5 - 5~S~ ' ~9'99.00 ~900,00 ~981 56'C0 5099,00 5000.00 20~2 59?9. ~299,00 5200,00 212G ..... 6o;;~ 53~9.00 5500,00 217'3 .~ .... 6a'l 55~9.00 5500.0U 22a7 .~'0 $ 71~,.57 ~ 565.59 ,51 S 7~2,06 !4 58!,06 ,~5 S 802,89 ,ZC $ '"8~1,01 ~] ....... 638,62. ,20 8 889.8~ W 652;85 (_ · . .$_P__E_R.R_Y_,~U.~'~'._..WELL.. GURV£Y ING C,O£,IP. AN_'Y · A~CHORAGE t ALASKA , P. AGE .9 UNION OiL COMPANY OF CALIFOPNIA GRpYLI~..G G-22 '.'.."']i"?.. MCARTHUg RIVER ALASKA ., . . ' '.'. "" "'.' .'TNTERF 0 L ..:, MEAS',JREL~, ., DEPTd C ..O_O.P U._T_A T_~....O.N.D.A.. ~ULY 29~ 1975 ~3~7 ' .6~n~''' 67~0 TED VALUES FOR EVEN 100 TRUE. SUB" SEA VERTICAL VERTICAL OEPT.H DEPTH 5699,00 5e 57'::9,.00 '5.7 5~99,.30 5~ ,00 60 , O0 6'1 6099 6299 6399 659~ 0 620 0 6.50 0 .'.6LJ' 0 650 0 66C 0 670 0 660 0---7O0 0 710 0 7,2O 0-- O, 740 TOTAL 0.00 0,00 0.. O0 O,O0 O. 0'0 ,;,Ob O,O0 0,00 C,O0 0,00 O,CO' 0..q'O C', O0 RECTANGULAR NORTH/SOUTH 2~21,15 S FEET OF SUB-SEA DEPTH . · OATF_. OF SURVEY dUNE el., 1~J75 SU.P:.~EL_.GY~O.S.Cc.._F_ZC.._~!._U.L TZSH.OT SU_~._V. EY dO~ NUr.'.BE~ SU3-16999 .. KELLY 5USHI,Nr~ ELEV, = 99,00 FT, · . COORDINATES ~D-TVO .VERTICAL · · , 9e0,'76 W 66~,~0 i~,0~ 953,27 ....W 68.6.,~2 ........................... 98G,26 ~ 703,58 Z7,~6 2'q. 7~5.,q'5 ~ 1019,57 W 721.,25 25..2~."75 .. S .....~ 052,60 ...W ......... .7.~B, 59 '17,67 27,.13 755,~2' . ..... "17,5'2 771.96 , '. 16,03 802,57 15,23 617,~6 15,26 ~53,35 15,'~9 '":..'":'.",.'2576.6~ S 1086,05 "'::' .:2626,20 S ~117,80 ''."."..'"':'":.267~,56 S 1148,97 .. ........ s79.TS-- 2771.~8 S. 1E10,19 2820,~5 S . 12~0.87 6899,0 6999,0 7299,0 7299,0 --7599,0 .......... 2918,7~ S. · s. ' 02'0','89"S 5072,~0 S 312~,97 S · .:.....'ti7:'~e2'"S .......... i~65,56 ~ ...............950,~ '3227.2~ $ 1~96,30 W ~66,55 . j'.,.,' ,',.. ·: , "-ia71',TS'-w ............. 8'~8,'7~" ............................ 15,~a' 1305,3~ W "66~,8~ 16,01 '15.35,66 bi 681,52 ' . 16,72 ......... 1~67,93'""~ ............. ~98,~8 ........................ 2~00,65 W 915,80 17,52 9s, s,ta ..................... ~7,~6 16,Z6 · . . . . .... ,, .( (, ONIGN CIL COMPANY OF ALASKA CALIFORNIA SPERRY-$U!:,,i ','JELL SURVEYING COMPANY .................................. ...... ~ .......... :-- PAGE 1.0 ....... ANCIioRAGE, ALASKA DATE OF SURVEY .dUNE 21, 1975 COMPUTATION DATE ...... SU~WEL GYROSCOPIC :~OLT.ISHOT SURVEY ~U'LY-2~"~' [975 ....... ~o~. NUP, BEa KELLY BUSHING ELEV, = ~,00' FT~ ..................................................................... .INTERPO .................................................. T~OE ................... S .D",E' S' '~" A u,~-'_ i] VERTICAL VE DEPTH . DEPTH LATED VALUES FOR EVEN 100 FEET O'F SUB-SEA DEPTH UB-S[A TOTAL RTICAL RECTANGULAR COORDINATES MO-TVD 5EPTH .NORTFI/S~UTH EAST/~EST O!FFERENCE .. 8550 75~,06 750 86~4. 7~9~,00 760 ................ 06F!'~ .................. 779'9,0'0 ............ 770 ~9~ 7~S~,00 709 90~i 799~.00 793 :"-~'".i'"."'"'gz~'~ ........... : ...... gO'~.oO ................ :6'oo 9A57 6~,00 ~1.0 9570 8299,00 820 .......... 9,~ :,;'~ ............... .~ ;"0"o '.'a~'o OI O, O, C, O, O, G, D, O. O, O, 0,0 . . ~7P..6 8599,00 850 .................... ~'.s's'~ ...... T-:'7'~.o'b ............... 9~52 ~7.99,00 870 ~OOT~ ~99,00 ......... 1.0isU": ......... :'"~99.9.~:;.'D.o .................. 1.0~'!0. 909'9'~00 900 ~0~9 '9199.00 9~0 ............. ~5~.~'~.":'.-'"",:'"'929~,'0.0 ................... "'920 lOGGY' '9399,00.:. ' 930 . , O0 ' ~27~.,27 S 1525,81 O0 '" 5~22,56 $ 1.553,92 O0 ................ 5565,'~'~5'"S 1582,~2 O0 5408,~9 $ 1~11,~7 O0 ~50.68' S 16~0,~6 c'o .......... T~: ...... 2%92',~a s ............ 16&9,ss O0 .5~$6.~ S 1699,B0 OD 5580,'~9' $ 17~0,$6 oo ................ '"~6'~5',~0'S .... : .... O0 ~671,76 S 1795,'~0 O0 $720,05 $ 1850,6~ ~o '~ ",.L.T'~TST'6'9 55 's ............ ,'ias7 ~ ? OO . , ~820,5~ S Z905,56 O0 ".5870,$5 S 19~,1~ VERTICAL CGRRECTIOH 995,~1 ..... 1007,97 1020,5~ 1052,99 1556,~1 1~,65 .' . 12,56 l~ · ....... z~,~ ........................................................................ · '.' . ~5.08. .'. 1056,18 i~,!9 1101,50. i5,11 1117.81 .... !'6',50 . . . ............... 1155.2~ 17,~1 .... "."' ,. !15~.Si I~,57 .... 1172.18 18,36 5921.".5~"$ ............... 196~.'~1 'W .......... i191,'~0 .... 5973.30 S 2025,65 W 181!,32 ~02~,B8 S 2067,21W 1230,84 ...'.....~'072,~5 S 2107.97 W, . 12~9.17 '??'":'.'"~118.01S 21~7,18 W 126§.9~ · ,. ~'...''. .... ., ....................................................................................a'"t'l 0 ~.~ 19,91 19,52 ,18.,~3 16.76' ,~Ior,~i CiL CO?-'!PANY OF iRAYLIr'G G-~22 , i(~AIRTHijR" R i VER C,.C~LIFORNIA -.' ,LASKA SP_.E.R..R_Y..-.S.Uf'J .WE.LL SiJRVEYZI~.!G C'O. MPA.~¥ .............................. .P_AGE 3,1 ANCHORASE~ ALASKA " '"" . ..".:'::.'":? ..... '"' · 'O~T~' o. s~v~Y ~u~-.-' CO..:"~PUTATIO~'J DATE SUF~;,.~EL GYROSCOPIC ,"-IULTISHOT SURVEY au~¥ a~, 3,975 '- dOB' '~Ju~,~:~E:R'SU3';'~.'~999 ...... KELLY BUSHING ELEV, =. 99,00 FT. · .ZNTETERPOLATED 'VAL'UES 'FOR EVE¢~ ~00 FEET'OF SUBLSEA DEPTH .' .... TOTAL ................................................................................. : .. RECTANGULAR COORDZNATES ~D-TVD VERTZCAL NORTH/SOUTH T~'E 'SU~-'SEA !EASURE~ ' YERTZCAL VERTZCAL ~EPTH DEPTH DEPTH ,, · , . ''lO.?~!~O '9~9~,0O' 9~00.00 EAST/WEST DIFFERENCE ¢ORRECTZON .............................................. .'"~ ........ .'; ............. ~ .......... . ............. .7 ...... :' .~ "!....?~ i:::..~.'..".i:.'..?::!i;;i'.~i;i~.:?'~: .. :. ' ................. .1~..5 s' ~.5.~ ~ ~8~.~0 ~'.~ '""'":~.'!,.:?~ ~?'~:'.~.." 1089 ~ c = ., N 12 o, 86 1 ~, ~ 5 : . .:......,..:~?.:;~:~.~?:;~,~?::...::..~..... ~ ........ .,59.-.,n0 9500,00 ...... : ....... ~E03,~9 S ..... 222~,68.' 9 ' :' ........ ~'l'O~'i~ .............. ~'G99','0'0 ......................... 56'00.0'0- ~2~.'02 S 22~7.1~ W' .1~09.~ 1~.58 .,~. ~11~.i 9799.00 9700,00 ' ~63,55 S 2~9~',92 N 1~2~,~G .1~,0~' ": ....... :'"'; .......... ; ................................ · ............................................. ~ ~ .'. '"' '..:'.'; :...'.: .. T' ................... .'". ............................. ". ................ ' :..' .................. . .... . ...... ~'"..' '.'.. ".-~:"'~" ............. .':'?~'~'7~;.~.~:?~:~:~¢:~:~.~?~:~:~:~:~.?::?~-7~7~`~ ~ C~L.C.L~o~,~ ~c, cz=zuu,.,zs u'sz' ~'.:C~.~ZA~".Z~..~T~'~OL~TZO~ SETZ'=E~~''~ ~''' "";":~"'" ' """":'""'"'"" ,,.':?;.?.;;;;;~?~;<~?': ~:~}~;'"":'.~": ..' "" ...... T~ ~[A~EST ~O"F~::;~ ~'~U iF~O~i.'~=~O~US OF cuF<vATu,z).POZ~,,,TS ""':.':".'..:"'..":... ':.' ~::~:~:~..~;~..~;~?~?~/~ ~?'":"':.'".'.... .'. . .. ti:' ,I ti i I ii" --[---i--I i- !' · I- I .; I D RECTIO AL SURVEY REPORT ThN GENTIAL CO~UTATI~S- - FOR UNION OIL COMPANY OF CA'LIFORNIA TYPE OF SURVEY: SURVEY DEPTH: FROM Surface LEASE:. Grayling TBU State O~,Toscopic Directional Multishot FT. TO 11~200 - . FT. WELL NO. G-22 Redrill FIELD: McA'r thur River COUNTY/PARISH Kenai PeninsuIa Borough, STATz_A*laska' DATE OF SURVEY June 22, 1975' ~oe NO., SU3-16999 OFFICE: Anchorage, Alaska WELL NO,"G"22 GRAYLrNG PLATFORM ,JUNE'22';"'1975 .............................. "SURVEY'"'"D'A'TE ................. ~"'"'"':: .......................... I~CARTHUR'RIVER FIELD VERTICAL SECTION COMPUTED ALONG CLOSURE ........................ .......... S T'A T E A L ,a, $ K A ~......,... .................. .. ........... . ............ : .......... : ........ "~'""'~. ........................... ............ '"~"":" .,..'i "'."i':!ii.il..'.','.']]!]'!i[~':[~ii!'.i]"..'~.'".'"ii'i:;i!'i[,.~.'i'i'';I ].' ..'...'.,.'.['i'.."'.'~iii,'.i!?i: :i.'...'l '....:]!'?]'..'...{i.i?!'/.';'.''': ".'":.".i".'i. '... 'i[.!i]?.ii::.'i".':.,.'.'.':i!" '.":i".!!f.';] ']:'.']?[!:.'iY.'.' '.i']'~i.j, iiii[i:~"i.'ii?i'.i!i?!.?[?~.. ::"" ' ?".:.:....:.; <..:.;.~:::~.'..::.~'~'~'~'"~'?~"'?'" ~"'"?'"".~.:.~,;:,;~. ,:::.;, ~, ~..::.~: ~:.. :..~:~..:. ......... .,...~.:::;~,L'.C,~'?'"'"~.,.<:2:;.> ,..:;.' .... ;;..'.;':.':. SPERRY-SUN WELL SURVEYING COMPANY ;T'.'L:;'.'.L~" ""' ......... .'~.,;'.:'32.:;'~;:.'' ~.~.~....~.~:~7.;~;:.~!..~!~:..:..~..~.~`i~L~2~!ZZL;:i.?::~L~:~:.~..:.~..-..'.ii'.":'L.~L',:.:,'.'.'.:,T~::'I:I`:. ,..L..'.L"~.~"i~':i..C;//. ::,. LL"'i ,,,::L' '. '."./' '::/'/ .... .' L: ..... : T::".. < ............ T: L: l' T:.:'/'T'.iLLL%:: RECORD OF SURVFy SEVER I T Y .......... v'Ei.~.:¥"i"i~/~'~' ...................... ';':":;:"~'~;";':':~':'"'~,"OORDi"N~":r'ES'`':''''''~`'':~,;'~;''~:~'~'~:~''::~::'~;'::'';'''''~'~','`~' ........... " DEPTH DEPTH DEPTH DEG MIN DEG ~I'N DEG/ZO0 SECTION "" :: >:";'"~:; .'~"Y'~':"?'L"~..'""3'" "' "::' ;' ~.~.~.~:~;~..~:;~..~.:~.~;.:..~.~.~.~:~.~t~;.~..~.~::~.~?;~.;~t..:~;~:.~Z~c~;:~:~.~.~.~:~...~2~;~;.~.~:~.v~;:`t~;''~..~.~,~ v".' :.'C.: .~.:~i~...~(?.qC.;:~..T.~?.;,.;%...~.:~:.~.~..~.~;:~``~Y~.~.~,`..~.~.~...~..~`~X..~..;;:~..;.~..? .~ '":'¥"~;F':"":t'q?'~'}t?~'":'~'~:::?'~;'~'"::].?~'':;:;''r /,'"" ~." '.', '" ' """>' ' :', "'~'::';:'~ '" '"] "::.?'"'.'"",.:" ']' .'.'"' ":" '.:?'..:',.'*.'?.';'::V; ':':C '. '"'. ' 0 `.~.~.~.`::.~..~.....~:..`~,...~`.`~;~:~`~`~`;~:~..~`~:.~:~.;.~::~.~.`~`...:.~;.~,`~:~.`9...?~6...`~:~.F.`~..~...~.:..~`~,~;.....~`.:`..~..R.i.G`IN. A'T'""'TH'E"'"'?SUR¢"X~'~:'''':':/~'''''' ''''~: ............................. ~". 0'~" ~J ....................'" ~"~'~ ~"'~ ' 100. 99.99 0.99 0 11 S 2.35 E 0.00 0,27 0,31 S 0.01 E "~ '" :.~..~' .'"'",'..":2 06 "~.'.' ............ '.'.'.~ 99,9 6 '.'.':"?'."..100 ,'98 .. · ....... ~"?'"~:.-,,~ '0'. ' 50 .: .: ": ...... S' 2 ~. 66 W ..". ........... 0'. 67 .... .'"'";'""': ........ .~...~.'.'?~.~.'::...1'. ~. 7 ~ '.' ' .'."~.':.':."":..":.'~.'~:;~.~'..'.?'~'1'", '6'~ :"'"S .."'."??%::.:~'~'~'~;~.:~".T~:"Q:";':59"... W..' ..'.~.'.': ..: ',.....'......'. :',..~..~ ,.,..:. . ~ ..~:.,:.,..:~:.:~,..::~,...,~,,,',~,~.'........ ..>.:.,..,.,,....,.:.~.-.~.:?':/.~:..,..:~..L..:.v..'...,.,. .'"' ..... :,':., ',...h.'~,:.:A.2:.~.,.~,::;,~:.~>,~,:,'~.:,,,...~... /".:.,',:.,.'..,,.. ........... :..' ... : ........... .. ,.~.,.;.~...'.~.~.~.~; ....... ~..,.; ............ .:...:.']>...,/,,;.,.<:...~:.,L':~.,~<...',.:,,~.:~;.:.~;.~'.}~, .' , ...,...:.~...~ ~:~.~`~:~``:.~f~k~;/~):~f~`~:~;C~:~`;~:~;~;~/~:~;~'~2::~7~J?~?~:~:~:~;~`~;~:~:~f~:~ , 299,98 200,98 0 9 S 24,31 E 0,74 1,88 1,88 S 0,~.1.8 W . .......... :5'99 ¥96'.: ......... :.'./."'300'. 98" "":".'.:""..'.':.'?~.'.'..',':,.'.'O'.. 11 .: '. S' '. "' 8 '. 7q..' W: ......... ~"~ ......... 0 ,.1' 0."". ..... .' ~"~'"'..:..:,,:".:': T""'2';' 1'6 ........ :.'..."':'~:'.::.'.::';".?'.'2,'19"' S¥?~?':?;":.~?!;:'::70' ~ 55':".'t¢:'-':''','' 800. 799..98 700.98. ' 0 12. $ 2.:35 W 0'.05 ;5.93 '.3,87 S 1.09 lO0 '.": ..... ." 12o -' .............. 130 . .- O. 999.96 900,96 i 7 $ .0,49 [ 0.8~. "6.37 6.39 S 1.57 W 0..' ..... .'1099.69. '..1000'.~9 ........ ~ ......... .-..~, .,9..'........'. ...... ."...S...I~,~I W ....... 3.08 ...... .'13.~0 ' '.'"':"'.~$'.~9 S "'. .............. ~'"""'3.~0 W '( .... , ......... ,. . ,.,.. ....... ,.,,.+ ......... · ,...,... ........ ,.,,,,. :..,........;,,;~,.,~,,,~,..,:..,........'.... ,,.,.,.'.' ,', ..... ',....,.~: .,... ~....' ,' ...... ~,.,~ ......... ...... J, · ................. ~ .......... : , ',. ........ :~ .... -.. '...:...,.....,., : - .. .. .... ,,,, ......... ?,-,,,d.~.-...L./..,:,.. t ............. ~-.-.,,, · O, '1198.76. 1099.76 7 50. S 2~.58 ~ 3.61 2'7.00 25,78 S 9,07 W O. ..... ~297.02... '1198.02 ' ..10~...~5. '..-..,.,'$'22..60 W' ' '2.90 .- ~5,51 .... ..~2·~5 S . .'. ......... 16.2.1'W 0"" .... 139~'~'65 .... '"'"12'95.65..... ...................... i'2 .... 2~ ............ ' ....... S""23'57 W ....... ' ...... 1'77 ' .... ........... ~7.05 ~'2,76"$ ....................... '""24',~6 ...... ~ ........ 5OO ~00 7OO 8[;O 9OO 0'00 · , · .. . , . 1~.91 5:3 .... 65.10 S ......... .55,59 'W .... 1'587",'2'2 '11U,85 S q9,03'W ........ 1681.0:5 lq.U,TG S 66,50 W 1771,5~ 1856,70 1940.7~ .1392,53 .... .... 1:4 2'1 'S 25,67 W 1,92 9'1,81 14'88.22 ........... 16 53' S'27.56 W 2,58 120.65 1582~03 20 16 S 30,29 ~ 3,49 .155.46 1672,54 25 10 S 30.7d W' 4.90 197,95 1757,70 ~1 ~7 S ~5,51 W 6,57 ~50,16 la41,7~ '..,~'2' 49 S 27,36 W $.~6 30~,3~ ' ""'""177·'29'$ ..... ' .... ' '88 .'2'6 W' " 221,00 S 117,21 W 2&9,1L~ S 142,11 W' 10 2O 3 0 , 0. 0, 2026.96 2].].6.68 2203.06 1929.96 28 5 S 20,2~ W 5,9~ 350,95 20].7.~ 26 ~2 S 1~.78 ~.. 3,12 397.~ 2104,~8 ~0 i~ S 1-3.10 t 1.5b ~4.6,05 31.5,51S 158,39 559,95 S 169.~3 WELL NO. G-22 GRAYLING FL'ATFORH ' 'dUNE' 22, 1975 ............ SURVEY OATE McARTHUR'RIVER FIELD VERTICAL SECTION COMPUTED ALONG CLOSURE · '"' ' · : .... - , ,'.' . ' .... "-. ..','..'., ..~<<':.. '.':~'~','..'..~ .~:.'"....i.< ::~;:,i~.'~...,/',,!;'."~':..v....',,,:.L. % ',.........'.. " SPERRY-SLIN WELL SURVEYING coMPANY SU$-16999 '" .... "' ' ................... '""? ':'~"'":'~ ........ ' ............... '"" ......."' .... ' ' ' .................. , ' "]' .' '". "' . ' '." 'i i." '"" ' " ....... ' .......... " .......... '""" ....... 7. ........ ' .................. :" ": "'.? ! ......... 7" ~ ......... "· <"~' ........ ' ......... . .. RECO~D" SUR ........................................ . ................... . .......... . .......... ,.....~.,,.. ........ :.:...~..<....~.... ..... ,:~...,...-.,:... ....... " ' .......... ' .......... ' .......... · ........... : .... ~ '"' .............. '""~"': .............. OF VEY 270 ..?,<.i'::L'.,,:."L:-' 2. ~ .. 0 290 .510 ~20 · ~., .:,.. %:, ....h.....;,..~ .;....,. ~;......... ..... ~!.~$'i:,'~'~..~ii '.'..i' ' .i ...'~ ~.0 '..~....,;:.~w~ ...~.....< ...i.i~..,..;... .... . .... .'<.............. TRUE.......... ~I'" mmmm ............ ' ............... :.."'I['dCLINA'[ ION DIRECTION 'DOG-LEG....... ' ' m"'m:Im .... m ~mm'Imm :m m m'm ~Im I~I~ Im ' .:m~l ...... :RE. CTANG,ULARv'. .......... ~'~EARURE[) VERTICAL" "sUB'SEA SEVERITY ........ VEF, TiC'A'L .............. ' ........... ' ...... COORDINATE'S''''~'''':~'' ............................... ~"~'"'"'"'" ............... " ............... OE~.P.T.H .......... , .................. ~,.E,....P..,~'..!.!~ ............................... D~...P...T.,,!.' ............... .D,,~G.........H.!...N.....,' .................. D.Efi..,..,.M.'.,!...N ............ ?..E..?,/.,10,.0 ......... ~.EC !~.I..O...N ........ ' ......... ' .......................... 2500. 2572.29 227~.29 ~2 ~5 S 12.29 W 1.q6 5~8.92 512.76 S 205.57 W /.i.:',,::....':'...2'60 O, "' ..v2~55-... 85 .......... <..'2~56.83 ..-......,....-..53. 21 ..... ,.. .... S ' 1~.,.56 · W.......: ',~'.:.'.','..0.., 91. '.:.< ..'.:,,. 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WELL NO."R';'22' GRAYLING PLATFOR ............................................................ i ........................ : .......... ":" ....... JumE'"'22';' 1975 ................................. ""S'URVE'¥"'"'DATE ................... ' ~"'""'~"'~'~ ........ ...... M£ARTHUR'RIVER FIELD VERTICAL SECTION COMPUTED ALONG' CLOSURE ~:.,.. ~....: . .' ................................... '.:':,~:'L'....'..' ~...,:...':..;<.......:.]..:.,i':,:~:>:' ...~...;:: .~.:'?...i.:~,d.L,.'.~.~...:~:.'~.,.~,io..;..,::i"..',.. ;'~ ..i....::...' ,.;.;:.:.i..iiL... :.. '..".': .... i '..~ ........ ': ,, '.,. L. ~', '~. ".. ~ :J:J,L ,;· i_ ,·>. ........... ;.,:,,,.L:,.,:l~,<{ .·. :' ::<:..,? ,L,t~:,z¥.,Jd=,,L..·L·::;.>·J,::,<· ,C,/· ~ .... :,,,/,/X,ii~;~f:;:J i.Z:>%;;<i:i',]i~·;':-:~;:<::;,".'.j·~il;!i~?;:;i.:,¥:;i¢;· SPERRY-SUN WELL SURVEYING COMPANY SU~-16999 ,. : ::: ?'.""::: 'oF 's 'r Vr .............. ' .......... ' .... 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"?...!T~:RPO'LATED..TI~U~' VL.'.RTICAL'".DKPTH$~, 'CO'""~'DZI~,IATE$ AND C,C'''~s FGR GIVEN.~EPTHS ........ ~. ,... ~ ........... ~ ~x ........ ~..~U ¥~ ~ . ~'~4~ ' '' ~,~ e~'~ V~c.~RT i CAL TOTAL COo~DI NAT[S C .... ~;t' J..i;.. .................... z. ,~ ~.. ~ .~ ~ J ! ~..*~ ................ ~ ........ , .................... . ................................................. · ...................... ............................................................................................... ............ 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['l.. ~ 1 ........... 9'99, 900 0 1!~9, 1!00 0 12;9, 1200 1499, 1400 6 15~9. 1.500 10 1699., 1600 16 1799, 1700 26 1Bgg, 1800 39 19~9, 1900 56 2099~ 2000 2199. 2100 86 2299e 2200 103 2499, 12~,$00 14! · . 2599, 2500 160 0 0 0 1 2 3 z~ 6 I0 1.3 17 15 15 17 19 19 19 . . 19I .......... ,~ , ~ ,{ ~ 0 2¢}3I l ........ 15 "'2 '*, ~l ~ 11,$1 26.07 45.03 67,0~ 93,29 124.69 163,~5 209.24 262,88 315,67 0,00 8,17 15,~5 '36,24 51,27 72.48 100e02 ... 128,24 16~,37 180,35 C 616,31 ,5 I ' '226.90 · . 758.6! S 25~,57' W 852*23l' $..... 285,:03 ............90:!~l~79'l ills ....... 3 olO', ' '110t2~153"'S 1327, 1"7l 'il' [~'' .................................. 3~.4 ~3~9,I ~.~'[ll~'l ~n 2C5 .......... 114 ........... ' ~.. ; * . ~ ' ' . . ?' ' ;] ...... I ........ ' ..............i ......................... ~'I [ll'l (~:'l{ l~¢~l ~¢~ ~ ......... I ................................... ........................ l[~jll~:'l'f ....................... -- .... :l}--l"ll ...... ~l'llllllll'~lJll ...... [-.5 ........ IS.l 12142e79$ 379,00 W I . : ......................................... ~ 1 ~ 9 ....................... }iT ~ '~ {.,, '..~T~? ...... ~- ~ ~ ........................ 2 ! .......................... .... 4630' I .... ~.199* ~IO0 ~ 3 9 .......... 1.9 AND.. O..lh:,'.',. DA1A...FOR EVERY EVEN 100 F£F.T. OF ,~'B "" .... SEA.. ~,~ , H e ........................... :. ~,~.. ~ ~ ~,, ~.-...:~ .,~.~ .. .............. ,:..~ .... '--,.,,~ .... ,~.~D V,-~ ICAL D=TVD VE~T ~CAL ~, '~" ~ ~ ~ t .......................... ..................... ~ ~,-.....~.. ~'"'~ ............ DEPTH... S.~A ._.D !FFERENC~ CORRECTION ~:,~,:,.~ .... ._. : ........... y:,-... :,.,-... .............................. ,.. ".-.':~.~. ....... ..': ............................................................................. .. . ...................................................... ...................... .5,10..,.5 .......... ~'5'99), ........... ~500 .... ........................... 52.22 ............ 4699. ../)600 .... ................ 5.338 .. ~799., .4700 ................... 5 ~ 5,4 ................... ,Z~8 99.., ..... 4800 ................... 55..71 .... 4.~99. 4900 ............ ,.....568.& .. .5099. 50.00 ...................... ~80.2 ................... 5!99. ...51..oo ............... ~.916 ............... §2~9, .....5200 ................... 60.:~0 ... ~399, .. 5~00 ............... 61~4 549~, 5~00 ................. 6259 ....... 55'99, 5500 63"/4 5699, 560'0 6491 5799. 5700 ":."'_'i':.:..L. .... . .... i':":...::'.:.:_ ....~Y2 6 .......... '5999 · 5900 ............. 6B~4" ........ : ......... -:..:,.:.~09 _9 · 6000 .......... ...506 523 539 55.5 572 511.7 60S 6.!*/' 631 659 675 692 7~0 727 '/45 .. ......... 6960 6199,"..: ...... .'::..:~..tO0.. 76! 707~ ......... 6299, 6200'"'" 777 ]..'.i i '"'. '. "_. 719 2 ...................... ".6.399, ......6300 793 ' ' 73'07 .......... '6499, . 6'400 808 ..: ......................... 7.~22 .................... 6.5~9, 6500 .. 82S ................ 75.~8 ....................... 5.6.9~..~ ........ 6~00 ......... 8.39. ............. 765~ ........ 6799~. 6700 8~ ....... 7.770 ...... 6899. 6~00 . 87[ ' ..7.~85...'..' . . 6999, ........ 6900.. 8.8.6 ...... .............. g002 ........ 70~9, 700.0 902 7100 919 . . 7.200 936 7300 954 7~00. 970 7500 985 7~00 998 7700 ..1.009 ............ 81~8.. 7!.99, ..................... 8235 ...... 7.299, ..................... 83.53 7999, ............ ,. 8469', ...7~99, ................ ~5.~ ...... 7599, .................... 8697 7699. .. . ...... ~ ...... 0.809 . .'..."'....77~9, .., .............. 8..921 ....... 7899. ...... 780'.0 .... !02.2.. .... . . ,. ~ ....-.... .. ~ __ -- ~.-~' .., . ~ ,.-~ ~ ·., r~r ..... : .~ :.,' ..., ....... ~.....~.';_.~:_.,.,... , ....... ........ . , .......... ,.. 17 16 17 .. .16 16 1.7 ~5 16 ., . ... . 14 16 17 18 17 ..... 18" 16 .. 15 16 16 · . 15 16 17 17 18 .... [5. 1[ TOTAL.. COOnD~'' .- ..... .... i7&g.,21 S · . 1821,56 $ . . !873,96 S !9~$~59 S .... 1979,$5 S 2030.02 $ 2077.76 $ 212'3,99 $ 22~,45 S 2260,~8 S 2~09,80 $ 2~60,55 $ 2~6~,5'5 S 2514,99"S.' 256~'68 $ 26[2.75 $ 2660.32 S ..... 2708.29'5 2756.47 $ 2805e03 $ .... . ..... 2853,~ 5 2901.8[ $ 2949.99 S 2999,~1'$ ....... 30~9.62 $ 3101,41 . . 3~53~30 S 3203,79 S 3252.21 $ 3295,31 S 3368'96 S .... 589,9~ W 618~.03..W ................. .... 6~, 76 W 67~,7~ W .. 702~12 W 729,17 W 758,00 W 789,~3 W 820.51 W "851'85 'w .................. 883.62'w .......... 91~.~8 W ...... .. 9~,81W ... 977.57'W 10t2.02 W 10~5.89 W 1079.,6.5 W' i113.10'."~'" · ................ 1146.32 W 1179.17 W 12i'i,22 W ...... 1'2~2.67 W 127~.73 W 17' 'W ................ 1339,78 W 1372,27 W 1437,73 W · 1670.39 W 1501,~'~.W .. 1533,22 W !563.33 W ,. 1594,60 W ~627.08 W .. 166~.33 W ,.. ........... £ ti.. · .. ~.. ~;~ ........ 9374 ........ . ............. ,~r ,,~ ~..A ,~;~. 96OO ... .9.Y~.? ' " .............. ~g5 2 ~ .... 10'071 .................... 10190 ......... 10~.~,0 ~, ! 0~3 i ................... I o...~.f~ ~,... 0.~ 7 ................ ................. ..i .. ................ .i :..o · .. ..................... '799¢'e 7SOO F. ~, ..~', 80.~ '..7, 8 u,v.~ 1 '"'" 8%9':; · 8105 I062 ~'g<;~, 8~00 !037 ~ ~*,.. 8499, 8auu IiCi 8599~ 8~0o .8600 ... 879.~~, 8700 88~9. 8800 1172 8999. 8900 1 I91 gog'go go00 1211 9199, 9100 1252 9299, 9200 12~ 9~ 9300 1268 9~9'~ 9400 9599. 9500 1~0'0 9699e 9600 .9799.' 9700 ..... 9899. gSO0 1341 13 13 12 16 18 19 lg 20 21 18 17 15 14 12' 34~7 G'~ 3~4.~ 3523~81 ~690,05 3738°34 ~786,77 388~,g7 ~934,61 $9'82.25 ~02'8',0'! 4153,50 ',$ '23'8.2.~17 W 4190,94 5 2421,08 W' 42'26" 10 $ 245"¢,29' W ..C. !' t200 'k £ 800~-,-? \ \ \ 3{;00 ~ \ 4400~ . 4~5 2005~C~0 ~.' 6400% VERTICAL .. ~.~ Tit.¢~4 SCALE !"=luOu"' UNION OIL COMPA~Y'OF CALIFORNIA TBU WELL G-22 RADIUS OF CURVATURE METHOD i '~ SHOWN I" · A,,__ . D~P'I.'H$. .~. ARE TVD. ti 7200 -~ · 8000 ~--- \ 8400 ,\ 9200 i~ 960"0-: ~ · .\ "T VD.. = · TMD = 11,255" // / · '"' /-' 8800 .. .. / ...,~' 9200 '.,. ~'~' 9(;o0 HORIZONTAL VIEW SCALE I"= 500' UNION ,.;IL COMPANY OF'CALIFORNIA TBU WELL G-22 RADIUS OF CURVATURE' METHOD i' ~,z'oo. I ' . ' ? SGOO~... ~ · O' ' ~/ ~/ · 7 /~4oo · . . ~ 7200 ' / / ~ O0 TMD II,2. 55' UNION OIL CO, OF CALIFOR.~.iIA JULY 8~ 1975 TRADING BAY !J~'!IT WELL G-22. "~,AGNFTIC SINGLE SHOT SURVEY AVERAGING METHOD K~ ELEV, 99 FT. DECLINATION 24 ·DEGREES EAST '' CO~:DLJTED FOR. ADDCO BY F, M., LINDSEY $ ASSOC, ,. RECORD OF SURVEY ALL CALCLJLATIONS PERFO.RMED BY. I B M ELECTRONIC COMPUTER TRUE ?.EAS, DRIFT VERTICAL F) .FP TH ANGLE DEPTH SUB DRIFT SFA DIREC'!' DFG, TOTAL COORDINATES C L 0 S U 'R E S DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT SECTION DISTANCE. 981 0 0 981,00 882,00 S 0 W 1024 0 45 1023,99 '924.g9 S 9 W 1126 4 15 1125,90 .1026,90 S 18 W · 1187 6 BO 1186,63 .i1087,63 S 21W 1217. 7' 45 1216,40 1117,60 $ 16 W 1312 10 45 1FlO,16 1211,16 $ 20 W 1469 13 30 la57.79 1358.79 S 23 W !650 18 90 1637.55 1538,55 S 25 W 1866 28 0 1836,01 1737,01 S 32 W 1943 30 0 !903,35 1804,35 S 30 W 2005 32 0 1956,50 1857.50 S 27 W 2068 31 0 2C10,21 191],21 S 26 W 2130 29 0 2063,91 196~,91 S 21W 22~ 29 FO 2!5~.65 2055.65 S 13 W 2358 31 0 2261,76 2162,76 g 16 W 2482 33 0 2366,92 2267,92 S 16 W 2738 33 0 258!,62 2482.62 $ 11 9! 2955 31 30 2765,14 2666,14 S ~ W 3204 30 0 2979.14 2880,14 S 17 W 3451 28 BO 3194,64 3095,64 S 14 W ~574 2~ 15 BB02,86 9703,86 S 13 W 3760 30 0 3465,35 3366,35 S 1~ W 4006 32 45 3675.38 3576,38 $ 12 W 0.00 S 0,00 W 0,28 S 0,02 W 4,60 S 1,06 W ' 9,99 S 2,96 W 13.52 S 4,14 W 28,04 S 8,86 W 57,55 S 20,49 W 104,64 S 41e45 W 179,57 S 82,1.4 W 211,57 S 101,36 W 239.63 S 116,60 W 269,09 S 131,29 W 297,52 5 143,65 W 346,11 S 158.51 W 406,59 S 174.15 W 469,76 S 192,26 W 605.33 S 224,81W 718,60 S 248.8~ W 841,57 $ 281.83 W 957,87 S 314.09 W !014,71 S 327,73 W 1102,92 S 348,10 W 1227,96 $ 375.82 W 0o00 S 0 0 0 W 0.28 S 4 BO 0 W 4,72 S 12 57 59 W 10,42 S 16 32 32 W 14,14 S 17 ~ 25 W 29.41S 17 32 47 W 61,09 S 19 35 52 W 112.55 S 21 36 43 W 197.47 S 24 34 49 W 234,60 S 25 35 59 W 266,49 S 25 56 49 W 299,4! S 26 0 28 W 330,38 $ 25 46 21W 380.68 S 24 36 22 W ~42.32 S 2~ 11 I0 W 507,58 S 22 15 29 W 645,73 S 20 22 27 W 760,48 S 19 6 12 W 887,51S 18 30 55 W !008.05 S !8 9 16 W 1066,32 S 17 53 58 W 1156.55 S 17 ~0 59 W 1284.18 S 17 1 0 W 0,000 1,744 3,442 3,716 4,647 3,228 1,868 2,690 4,573 2,886 4,075 1.791 5,161 3,787 1,717 1,613 1,064 0,848 1,018 0,849 0,437 0,941 1,1~8 0,00 0,25 4,51 10.12 13.77 28,69 60,04' 111,28 196,51 233. 3 265,75. ' 298,60 ~29,B9 378,86 438.99 502,69 6~6,22 746,21 869,0~ 985,78 1041,76 1128,23 1250.23 RECORD OF SURVEY · ALL CALCULATIONS PEEFORHED BY I B M ELECTRONIC COMPUTER TRUE IH, EAse DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 41[.8 34 15 3768.77 3669.77 S 17 .... 4180 35 0 3819.79 3720.79 S 20 4316. 34 45 3931,37 3832.37 5 25 4628 32 30 4191,16 4092.16 S 26 4815 31 0 4350,18 42~1.18 S 26 5132 30 45 4622,25 4523,25 S 29 5473 50 45 4915,31 4816,31 5'27 5600 30 30 5024,60 4925,60 $ 27 566.5 30 0 5080,75 4981,75 S 33 5883 29 0 5270,49 5171,49. $ 34 6101 28 3.0 5461,61 5362,61 S 36.W 6288 30 0 5624,77 5525,77 S 31 6521 31 45 5824,75 5725,75 S 34 673.8 31 45 6009,28 5910,28 S.33 7084. 30 0 6306,24 6P07,24 S 35 ...7~50 30 0 6536,61 64~7.61 S 33 .. 7653 30 15 6798,68 6699,68 S 34 ..789~.. 30.. 15 7003,41 6904,41 S ~4 .8212.~1 45. 7279,42 7180,42 S 32 8511 ~0 0 7536,05 7437,05 S 31 ...~774 26 0 ..... 7768,26 7669,26 S 41 ...8868 2v 45 7852,11 .7753.11 S 48 9040..2~ 45 8004,33 7905,3~ S 39 9!66 28 0 8115,71 8016,71 S 42 9299 28 0 8233,14 81~4,14 S 46 9~6'1 27 0 8376,84. 8277,84 S 48 963! 30 30 8528,51 8429,51 S 40 9901 32 30 8756,16 2657,16 S 40 100~0 32 30 8864,96 8765,96 5 41 TOTAL COORDINATES 1287,81 S 1321,22 $ 1~93,06 S 1549,00 S 1637,44 S 1781,74 S 1935,68 S 1993,~2 $ 2021,68 S 2111.20 S 2197.09 S 2273,29 S 2374,1~ S 391,30 W 402,47 W 432,23 W 506,61 ~ 549,75 W 624,86 W 706.72 W 752,~6 W 811,71 W 871,85 W 922.28 W 986,53 W 2469.35 S 1049.55 2616,55 S 1148,84 2726,81S 1223,21 2853.62 S 1307,15 2952,60 S 1~73.91 ~091.69 S 1464,24 ~222,52 S 1544,41 ~322,41S 1616,98 3352,72 S 1646,76 ~410,81 S 1701,89 ~455,60 S 1740,15 ~500,52 S 1783,53 3551,5~ S 18~8,23 3611,39 S 1896,04 3718,26 S 1985,71 3770,97 S 2030,72 CLOSURES D I STANCE ANGLE O M S 1345,94 $ l~ 5~ 4 W 1~81,16 $ 16 56 31W 1458,58 S 17'14 16 W 1629,74 S 18 6 39 W 17'27,27 S 18 33 31 W 1888.13 S 19 19 33 ~ 2060.66 S 20 3 25 ~ ' 2124,89 $ 20. 16 5 ~ 21.57.18 S 20 2~ 54 ~ 2261,87 S 21 I 5'0 ~ 2363,76 S 21 38 39 ~ 2453.25 S 22 4 57 ~ 2570,94 S 22 33 52 W 2683.14 S 23 1 37 ~ 2857.65 S 23 42 17 ~ 2988.60 S 2~ 9 37 ~ 3138,76 S 24 36 39 W 3256,61S 24 57 1~ W 3420.90 S 25 20 32 ~ 3573.~9 S 25 ~6 22 ~ 3695,00 S 25 57 6 W 3735.~! S 26 9 32 W 3811.83 S 26 31 4 W 3869.02 S 26 43 43 ~ 3928.69 S 26 59 56 ~ 3999.06 S 27 21 56 ~ 4078.86 S 27 42 0 ~ 4215.27 S 28 6 ~4 w 4282.99 S 28 18 11 w SEVER I TY DEG/.iOOFT 2,803 2,110 0,743. 0,802 0,492 0,300 0,197 4.712 0,5'11 0.497 1.532 1.000 0,242 0.586 0.376 0,185 0,000 0.565 0.610 2.341 3.844 2,434 1.131 1.412 0.840 3.003 0.749 0,417 DISTANJ 1309.74': 1344.23 ' 1421,29 1593.47 1691.61 1854.10 .~, 2028.~2 ii. 209.2.91 2125.66 2232.8~ "' 2428.55 2548.02 .~, 2839. 2971.90 ": 3123..72 32~2,86 3408.51 3561.90 368~.75 3725.93 : 3803.87 3861,84 ~922,48 i... ~99~,10 . .. I074,91 4212,40 4280,59 RECORD OF SURVEY ALL .CALCULATIONS PERFORMED BY I B "'~, ELECTRONIC COMPUTER TRUE UEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 10337 34 0 9121,70 9022,70 S 42 W 10783 30 30 9498,g0 9399,90 S 43 W 11255 27 0 9912,71 9R13,71 S 48.'W 3897.03 S 2142.26 W 4072.50 S 2303.05 W 4231.63 S 2464.97 W BOTTO~,~ HOLE CLOSURE 4897,22 FEET AT S 30 13 16 W C L 0 S U R E S DISTANCE ANGLE D M $ 4447,04 S 28 47 53 ~ 4678,60 S ~9 29 19 w 4897,22 S 30 13 16 w DOG LEG SEVERITY DEG/IOOFT 0.520 0,794 0.899 SECTION DISTANCE 4445.67 4678.22 4897.22 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GXVEN DEPTHS CODE.. NAHE TRUE MEASURED VERTICAL DEPTH DEPTH TOTAL COORDINATES C L O S UR'E D I STANCE ANGLE D M S SUB' SEA H..EASURED DEPTH AND OTHER DATA :'OR. EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE NEASUR'ED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTXON TOTAL COORDINATES .... 999 ...... 1099 1199 1301 '1403 1506 1610 1717 1826 1938 2055 2170 2285 2402 252O 2639 2759 2877 2994 31.11 3227 3341 3456 3570 3684 .. 3799 3917 .... 4034 ........ 4155 4?77 4!~7 .......... 651.7 · 4637 4755 4872 · . 99q, 900. 0 1099. 1000. 0 1199. 1100. 0 1299, 1200. 2 1399. 1300. 4 1499. 1400, 7 1599. 1500. 11 1699, 1600. 1~ 1799, 1700. 27 1899. 1800. 39 1999, 1900. 56 2099, 2000, 71 2199, 2100, 86 2299. 2200. 103 2399, 2300, 121 2499. 2400. 140 2599. 2500, 160 2699. 2600, 178 2799. 2700. 195 2899, 2800, 212 2999, 2900. 228 3099. 300'0, 242 3199, 3100, 257 3299. 3200, 271 3399. 3300. 285 3499. 3400, 300 3599. 3500. 318 3699. 3600. 335 3799. 3700. 356 3899. 3800. 378 3999. 3900. 398 4099, 4000. 418 4199. 4100. 438 4299. 4200. 456 4399. 4300. 473 0 0 0 2 3 4 7 9 12 17 15 15 17 18 19 20 18 17 17 16 14 15 14 14 15 18 17 21 22 20 20 20 18 17 0,11 $ 3,46 $ 11'45 S .. 26,31 S 45..80 68,34 S 94.54 127,84 S 165.59 S 209.50 262.94 S 316.'31 S 371.15 S 428.96 S 490.01 S 553,16 S 616.06 S 677.77 738,05 $ 795,52 S 852,29 S 906.25 960.16 S 1012,68 $ 1066.90 $ 1122.95 S 1182.49 S 12~3,09 S 1307.60 S 1372.22 S 1~+33,65 S 1493.68 S 155~, 36 S 1608.98 S 1663.33 S 0.00 W 0.78 W 3.45 W 8.30 W 15.86 W 25.29 W · 36.96 W 54,05 W 74.55 W 100,12 W 128,22 W 149.39 W 164.98 W 180.56 W 197.12 W 212,28 W 227,09 W 240,21W 254,10 W 269.49 W 284.81 W 299.77 W 314.64 W 327,24 W 339.78 W 352,54 W 365.7~ W 379.73 W 397.92 W 423.60'W 451,60 W 480,23 W 508.74 'W 535,86 W 563.23 W AS'URED DEPTH AND.OTHER DATA .FOR' .EvERy· EvEN 100. FEET OF ,SUB SEA DEPTH. ..... ~EA"$URED DEPTH .. ~ · ... 4988 ......... 5 '105 5221 ..... 5.338 5570 5686 5801 . 59.16 6030 ..6144 6258 .. 62~91 6608 6726 68/+3 ... 60'59 7L76 7191 7307 7/+22 7538 7653 7769 7885 8002 8118 8235 8351 8468 8582 .. 8696 8808 8921 TRUE VERTICAL. DEPTH SUB MD-TvD ,SEA D!FFERENCE VERT.I.CAL CORRECT ION 4499. 4/+00. 489 16 4599, 4500. 506 17 4699. 4600. 522 16 4799. 4700. 539 17 4899. 6800. 555 16 4999. 4900. 571 16 5099. 5000. 587 16 5199. 5100. 602 15 5299. 5200' 617 15 5399. 5300. 631 14 5/+99. 5400e 645 14 5599. 5500e 659 14 5699. 5600. 675 16 5799. 5700. 692 17 5899. 580'0- 709 17 5999. 5900. 727 18 6099. 6000. 764 17 6199, 6100. 760 16 6299. 6200, .777 17 6399. 6300. 792 1'5 6499, 6400, 808 16 6599. 6500. 823 15 6699, 6600. 839 16 6799. 6700. 854 I5 6899. 6800. 870 16 6999, 6900. 886 16 7099. 7000. 903 17 7199, 7100. 919 16 7299. 7200, 936 17 7399. 7300e 952 16 7499. 7400. 969 17 7599. 7500, 983 1/+ 7699. 7600, 997 7799. 7700. 1009 12 7899. 7800. 1022 13 TOTAL. · . COORDINATES 1716.37 1769./+0 1822..05 1874.58 1927.11 1979.82 2030.29 207.7,47 212~,01 2168,95 2214.55 2261.25 2310.72 2361.1/+ 2513,82 2563,39 2612.96 2660.9/+ 2708.81 2757.00 2805,39 2853,77 2902'.12 29150e~7 3000,77 3051,16 3101,67 3152.65 3203.63 3249,60 3292.61 3333.52 3370.61 S S $ $ $ $ $ $ S S S S 5 S $ S S $ S S S S S $ S' S $ $ S S $ S S 59o'.m3 61'8,44 646.30 674.23 702.16 729,21 758,16 789,39 820.68 852.15 883.41 914.32 9/+6.13 978.25 1011.89 1079.55 1112,98 1146,42 1178.79 1211.07 12/+3,19 1275,22 1307.25 1339,86 1372.47 1405,19 lq37,92 1470.35 1501,59 1532.83 1564.08 1595.33 1627.90 1663.7~ W W W W W " W W W W W W W 'W .w W W W W W W W w W W W w W w W w W W W w w _~..H.E_A_S. UJ:L~.D..D. EP. TH.. AND.,.OTHER...D~TA...FOR EVERY_EVEN "i.~'~)"..."F'EET O-~..$UB...':.SEA DEPTH. .................................................. ....... ~ ............... :'2: ...... .:...,:-':..,:...'.'.:"". .... ...:'. YR:u~'......,':':" '.. ",:'.".'~':.": .... '":'":: '":.:. ":",. ',' .... : ..................................................................................... "H£A~_U_R_[.D. ................. ' .V.ERT..!CA...L SUB....'._ ND'.TVD VERTI'CAL .................................. ' .............................................................. !. · PE._P.TH ....... DEPTH SEA ._.O:IFF..ERENCE ........ CORRECTION . .'.'. TOT'AL . COORDI. N'AT£.,S.. "..' .... ....' ....... ...................... ...9...260 .......... 8.!99,_. 8100, .... !06.1. 1.3 _917.3_ .... : ......................... 8299.,. ..... 8200.... 107/+. ............. 13 .. ........................ 9~86 ............................. 839...9..,.. ...... 8.300, ...... !_08.7 ................ t3 ................ 9.600 .......... 8/+99, 8/+00, 1!.01' .............. ....9:Z_17_ 85.99. 8500,, 1118 ,.~ ........................... 9..8~_~...": ........ ""8899. ~6oo. 1~3~ . ... ........ .._:_ ................ 99..~2 .. . 8799, · 8700, 1153 ................. !~07.1 .. .......................... 10190 ..... ...................... lo~o ....... 10~28 ............ !o5~7 ................. 1.0665 8899* 8800, 1172 899'9, 8900, 1191 .. 9099, 9000. 1'211 ... 9199, 9100. 1229 9299. 9200, 1248 9399* 9300, 1266 18 '1'9 19 20 18 19 18 3408,77 $ 1699.96" ~"'. ..... ' .................... 'I'" 34~8,88-S ....... ~7'3'4~-~1"'~ ...... .,' ........... .,.;...i....i'.'::'i .... ......::.~...`~...........::...::..~..::.::::.....~..:.~:.:.:.t..~:i::::..:...~!:..:~t~ 348V.%'6"$ "1770,91'""~ 3523,90 S 1808,60 W 3560,28 $ '1846,68 W ............. 3599,74 $ 1884,79' W 3644,~8 $ 1923,8'0 W " 3691,42 $ 1963*19 ~ '- 3739,01 $ '2003,4~'~ .... 3787,68 $ 2045,51W .... 3836,78 5 2088.95 3885,88 $ 2132,~0 3932,99 5 .2175.21 3979-51 S 2217.83 ./~~P_Q. LA..T...E..D...V.'ALuES":::'"~O.R'.:.."~vEN'":'~'O'~o.'' FE.ET".'OF. MEASURED'. DEPTH, "' TRUE ::::::::.~':~.:S~E~'~:..'..:'.~,,:.~ ',. V~.R.~ z.'c'4~' '.".'., :,..SOB:'....."'. ,.'"...'". ..... ". .............. · .DEPTH. .. ..DEPTH ..... .SEA .... TOTAL ¢00RD ]NATEs ................... 2000.' ........... 1952, .~ ..... !8.5_3, ............237...,..:~7 $ .......... 115,37 W ..................... · .... 30'00 2803. 27'04'....... "" ':'"m--J:"~ """'': 7 ~ 0 ' ~p'S 254,.84 W ".::T".:F'::~:T'..L':.: .......... z+O00 ............ . ............... .-..... ..... ~,~n ........... ' ....... :1224,.91 S..................... ~ ~ ~ ' "1 ~ W =-'==~' ....:.~.L.:....=........ ' ........... ""~ .................. "': ....... ' "' '" · ................... ' .... .. 500.0 ................. 45o.8, .... 4./+09, _.~ ::.:~_-:-._60oQ .......... 5~73... .... .52?4. ...... ". ....7.000 ..... 6.2, 34,. ...... A15.5. ........ . ......... 8000 7097. 6998, ........................ 9000 7968, 7869, ..................... ~0oo0 .~3~. .874,o. 7'2 ~.~,5 'S 593,59 W 2157,30 $ 2580.~1 S ·. 3000.12 S 3758.71 S 843,99 W 1124.74 W 1404,77 W 1689,07 W 2020.26 W 400- 2800 3600 :~ 4000 VERTICAL SECTION SCALE I"=1000' UNION OIL COMPANY OF CALIFORNIA TBU WELL G~22 AVERAGING METHOD ALL DEPTHS SHOWN1 ARE TVD. 9600 '~- \ '~. TVD = 9,913' TMD--11,255' HORIZONTAL VIEW SCALE I"= 500" UNION OIL COMPANY OF CALIFORNIA TBU WELL G- 2:2 'AVERAGING 'METHOD .. , . .. 'I .. :. · .. ,. ... 9200 .. 6400 7ZOO · 7600 8000 ,,/ii200/~°° ,/./"~2400 3600 4000 44OO ALL DEPTHS SHOWN ARE TVD. . Form ! 0-403 REV. 1-10-73 Subml t "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate S'I'ATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not use tl31s form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for sucll proposals.) WELL t_..J OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIF. [ ADDRESS OF OPERATOR 909 West Ninth Ave., Anchorage, Alaska 99501. 4, LOCATION OF WELL At surface Conductor #1, Leg Rm. #3, 1798'N & 1413'W of the SE corner.. Section 29: TgN, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 99' above MSL. .. 14, Check Appropriate Box To Indicate Nature of Notice, Re 50~133-20272 LEASE DESIGNATION AND SERIAL NO. OR TRIBE I~AME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-22 (12:32) 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 4080'S & 2870'W of the surf. loc' 2330'S & 950'E of the NW corner. 12. PERMIT NO. Section 321 T9N,R13W,: · 75-16 )oft, or Other Data' NOTICE OF INTENTION TO= TEST WATER SHUT-OFF L-~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) '*See Below PULL OR ALTER CASING MULTIPLE COMPLETE ABANDO'N* CHANGE PLANS SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DE.~CRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. *The original wellbore of TBUS G-22 was drilled to '11,336'. Excessive drag and deterioratinl hole conditions due to an organic degradation of the mud system caused the drill string to part at the lower Kelly Cock (determined to be a fatigue crack) resulting in 729E' of drill string being dropped to TD @ 11,336'. Fishing attempts were unsuccessful and the well was subsequently plugged back to 5600'. The redrill wellbore encountered the top of the Hemlock approximately 180' higher than anticipated which 'will yequire that the well be completed as .a Hemlock Producer rather than a water injection well. After setting 9-'5/8" csg. @ 11,'335', 4-1/2" production string was run to allow selective testing of the Hemlock benches w/ isolation pkrs. set above Hemlock Bench #6 @ 11,070' and above' Hemlock Bench #5 @ 10,940' and a production, pkr. set above Hemlock Bench.#l @ 10,450'. Hemlodk Benches 5 & 6 were perf. and tested water productive. Hemlock Benches 2 & 4 were perf. & tested oil productive. . ? (Cont. on Page 2) '~",- .. · 16. I hereby certify that the.fo~,~olng Is true and correct .ZJi~3_.R', c _.ca~a~ ' "-. ' ' DATE,. 7/].7/75 . , . (This space for State office use) · ~?'"" , Approved Copy .., Reamed ~e Imtructiom On Rever~e Side Form 10-403 REV. 1-10-73 Submit "1 ntontlons" 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 o'r to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL m-'l GAs F--i WELL L-J WELL I----J OTHER 2. NAME Or OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface o, 13- ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 6, LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF ~ PULL OR ALTER CAS,NG FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) . SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well . Completion or Recompletion Report and Log form.) DESCRI!aJE PROPOSED OR ~'.OMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed worl<. State G-22 (12-32) - Continued Plan of Procedure 1 0 Leave well cqmpleted w/ 4-1/2" gas lift assy. Hemlock Bench #6 is isolated by an I'N" plug set in the tbg. tail below the pkr. @ 11,070'. Hemlock Bench #5 is isolated by an "X" plug set in the tbg. tail below the pkr. @ 10,990'. Complete well in Hemlock Benches 1 thru 4 with production Perforations as follows: Sand Hemlock Bench #1 Hemlock 'Bench #2 Hemlock BenCh #3' Hemlock Bench #4 Hemlock Bench #5 HemlocJ( Bench #6 Interval 10,602 10,670 10,768 10,832 10,886 10,984 11,115 10,622 10,700 10,788 10,862 10,936 11,022 11,145 ~Isolated by plugs Dear Mr. Marshall: Union Oil and Gas I~" '~ion: Western Region ! Union Oil Companyk. California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union July 10, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive ' Anchorage, Alaska 99503 - ....... f' G~OL ~ FILE= RE: TBUS G-22 (12-32) TBUS K-21 (21-28) TBUS D-27 (31-6) ~--"~ KU #43-7 Enclosed for your files are two (2) copies each of the. Monthly Report of Drilling & Workover Operations (Form P-4) for the above captioned wells. Also enclosed is the Sundry Notice & Reports on Wells (Form 10-403) for KU #21-6 WO. sk Very truly yours, District Drlg. Supt. cc: Marathon Oil Co. Atlantic Ri'chfield Co. Amoco Production (TBU only) Phillips Petroleum Co. (TBU only) Skelly 0il Co. (TBU only) Standard Oil Co. USGS - Rodney Smith ~ ~°' P~ STATE OF ALASKA I~EV. B- 1-70 OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE .. AP1 NLD~IERICAL CODE 50-133-20272 LEASE DESIGI~tATION AND SERIAL NO. ADL-17594 ? IF INDIA~T. ALOTTEE OR TRIBE IqAME O,'-,,L,. ~] G,,,,,.,. [~ o,n-., Salt Wtr . Inj. 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIF.O]~IIA 3. ADDRESS OF OPER~TOI~ 909 West 9th Avenue, Anchorage, Alaska 90501 4. LOCATION OF Conductor #1, Leg Rm. #3, 1798'N & 1413'W of the SE corner. Section 29: T9N, R13W, S. M. L~,'IT FARM OR LEASE NAME Trading Bay Unit 9 WELL NO State G-22 (12-32) 10 FI.EJ.,D AND POOL. OR WILDCAT McArthur River-Hemlock n s-.c, T.. R,. ~. (BO'n'OM ~o~ o~ 4080~S & 2870~W of surf. loc. or 2330~S & 950~E of NW corn~ '~ect!~ 3~: .T9N. R!3W,.S.M. 75-16 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN BOLE SIZE. CASING AJ~TD CEMF2~TTING JOBS INCLUDING DEP~ SET ~ VOL~ US~. P~O~TIONS. ~TS g~ ~SUL~ FI~ING JO~ J~K ~ HO~ AND SIDE-~C~D BOLE ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS Dyna-drilled 12 1/4" h01e from 8684'-8758'. Pooh w/ DD. Drilled, tripped & surveyed 12 1/4" directional hole from 8758'-11,335'TD. RU Schl. & ran DIL Log from 11,335'TD to 5548'. RIH w/ BHC-Sonic-GR Log. Unable to get below 5740'. Made CO trip w/ 12 1/4" bit.. Reran BHC-Sonic-GR Log. Unable to get below 5775'. RD Schl. RIH w/ 12 1/4" bit to 11,335'.' Circ. &cond. mud. Pooh. RU &ran 273its. of 9 5/8" csg. toTD @11,335'. FC @ 11,253'. Cmt'd. csg. w/ 1600 sx. Class "G" cmt. w/ additives. Bumped plug w/ 2500 psi. Float equipment held ok. Hung off 9 5/8" csg. Installed tbg. head & BOPE. Tested to UOCO specs.-ok. Ran 8 1/2" bit'& 9 5/.8" csg. scraper to ETD. FC @ 11,253'. Pooh.. RU Schl. & ran CNL-FDC-GR Log from 11~253' to 5548'. Ran Sperry Sun Gyro Survey from ETD to surface. Ran Variable Density CBL Log from ETD to 8000'. Bond results-poor to fair. Perf. from 11,081'-11,082' w/ 4 hpf for blk. sqz. ~l between Benches #5 & #6. Ran 9 5/8" cmt. ret. &'set @ 10,990'. RIH w/ ret. stab-in tool on DP & stabbed into ret. Unable to break dwn. perfs, from 11,081'-11,082' w/ 3000 psi. Perf. from 10,708'-10,710'. Ran & set cmt. ret. @10,660'. Stabbed into ret. w/ DP &sqz'd. perfs, from 10,708'-10,710' w/ 100 sx. Class "G" cmt. to a final press, of 4400 psi. Ran BO shoe & pkr. picker. Milled over ret. @ 10,660' & retrieved. Perf. from 10,590'- 10,592' for zone isolation sqz. Ran & set cmt. ret. @ 10,526".. Stabbed into ret. w/ DP & sqz. perfs, from 10,590'-10,592' w/ 100 sx. Class "G" cmt. to a.final press, of 4800 psi. Ran BO shoe & pkr. picker. Milled over ret. @ 10,526'. Pooh-no rec. RIH w/ OS. Worked over ret. @ 10,526'. Pooh. 'Rec. top portion of ret. RIH w/ 8 1/2" bit. CO sqz..work & wellbore to ll,253'ETD (FC). Pooh.. Laid dwn. 5" DP. R.U Schl. RIH w/ JB & gauge ring. Unable to get below 11,.033' after several attempts. RIH w/ 7 1/16" junk catcher on 4 1/2" tbg. to 11,233'. Rev. out. Rec. loose rubber & junk from cmt. ret. Pooh w/junk catcher. RU Schl. Ran gauge' ring .& JB'to 11,227'. Ran & set 9 5/8" X 4 3/4" perm. pkr. @ 11,090' & 10,940'. RIH w/ 9 5/8" X 6" perm. pkr. Unable to get below 3374'. Pooh w/pkr. Now: Pq6~ W/ pkr, , . . sm~-~'~.-r, -z'__ ' _ ~a~.~ Dist. Drl~. Smt,.,,~. . ~*~. 7/10/75 ' ~OrE--Re~ort on this f~ is required ~, ~ch calendar ~th~ regardle,l ~ the status of opemti°~, and must ~ filed in dupli~te with the oil and gas eonservatbn eommiflee b~ the 15~ of the suee~4ing mon~, ~le~ otherwise direc~d. /' .Union Oil and Gas~i,,islon: Western. Region Union Oil Company~ ,.,alifornia ' ' P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-768I Dear Mr. Marshall: J.une 4, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alasl~a '99503 .. RE: TBUS G-23 (23-33) TBUS G-21 (21-33) TBUS G-22' (1,2-32) TBUS D-24 (33-5) Listed below are the enclosed reports required for each of the above captioned wells. TBUS G-23 (23-33) TBUS G-21 (21-:33) TBUS G-22 (12v32) TBUS D-24A (33-5) Form 'P-4 Monthly Report Form 10-403 Sundry Notice ' Form' P-4 Monthly Report Form 10-403 Sundry Notice Form P-4 Monthly Report Form P-7 Completion Report Well History Directional SurVey sk Encl. cc: Marathon Atlantic Richfield Amoco Production PhillipS. Petroleum' Skelly Oil Standard Oil Rodney Smith - USGS V truly ' uts,' . Drilling Engineer ' ~ No. ~-~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMrI'i'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS o,,. ~ °*" F-'] o~.. SaltWtr Inj WELL W~-LL ' * SUBMIT IN DUPLICATE AP1 NU'MERICAL CODE 50-133-20272 LEASE DES:GNA~ON AND S~IAL NO. ADL-17594 IF INDIA]~J'. AL~)T'r'EE 0]~ TRIBE NAME 8. T,,,~IT FA/qleI OR LEASE NAME Trading Bay Unit 9 tw~ .NO State G-22 (12-32) 5. NAME OF OPERATOR UNION OIL COMPANY OF CALIF. 3. ADDRESS OF OPERATOR 909 West 9th 'Avenue, Anchorage, Alaska 99501 4. -OCA~ON O~, Conductor #1, Leg Rm. #3, 1798'N & 1413'W of the SE corner. Section 29: TgN, R13W, S. M. 10. ~.~*p:lJ~ AND POOL. OR WILDCAT McArthur River-Hemlock I1. SEC., T., 1~., M.. (BO'I'TOM HOL~ o~-~-~ 4080~S & 2870~W of t~e surf. loc. or 2330~S & 950~E of NW c~rr. cr. Sc=. 32: T9N, P.!~W, S.~ 1~. P~IT ..75-16 . ! - REPORT TOTAL DEPTH AT END OF MONTH, CHANGE~ IN HOLE SIZE, CASING AND CEIVIENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PERFORATIONS. TESTS AND RESULTS'FISHING JOBS JI/NK IN HOLE AND SIDE-TRACKED HOLE AND A/q'Y OT'HI~R SIGNIFICANT CHANGES IN HOL~ CONDITIONS. Recommenced operations on TBUS G-22 @ 12:01 am~ 5/21/75. Skidded rig from TBUS G-21 to TBUS G-22. Installed BOPE & tested to UCCC specs.-ok. Made up BHA & RIH. Drilled out firm. cmt. in 13 3/8" csg, from 5201' to 5538' w/filtered Inlet wtr', Circ. hole clean & cleaned mud tank. Displ. 'hole w/ inhibited Inlet wtr, & let well set for 2 hrs. Mixed X-C Polymer. dr!g. fluid & displ, hole." Drilled out cmt. from 5538'-5600'. Pooh. RIH w/ DD & Sperry Sun Steering tool to 5600'. Attempted to orient DD twice w/o success. Pooh w/ DD.. RIH w/ turbo-drill & 'steering tool & oriented @ 5600'KOP. Turbo drilled from 5600'-5616'. Steering tool failed. Pooh w/ steering tool. Reamed turbo-drill run from 5600'- 5616'. Ran new steering tool. Oriented turbo-drill @ 5616'. Turbo-drilled from 5616'-5669'. Pooh. RIH w/ 12 1/4" follow-up assy. Reamed turbo-drill run from 5600'-5669'. Drilled & surveyed 12 1/4" hole from 5669'-5721'. Pooh for BHA change. RIH w/ 12 1/4" tandem square assy. Drilled, tripped & surveyed 12 1/4" directional hole from 5721'-8684'. Pooh for DD. RIH w/ DD to 8684'. RIH w/ Sperry Sun Steering tool on DA WL unit. WL shorted out three times. Pulled up into 13 3/8" csg. shoe. RD DA. Moved in & rigged Schlumberger. RIH w/ Sperry Sun Steering tool. Oriented DD @ 8684'. Dyna-drlg. @ 8684' DIV:SlCN C F GIL AND OAS ANCHORAGE iii , NOTE --Rt')crt on this form is ~uired for .lOCh oOlendor moflth$ regardless of [he ltotun of operotJons, and must be flied 'Il duplicate with tho oil and gas conllrvatbn committee by tht 15th of the succeeding month, unless otherwise directed. ~ ~°' ~'~ STATE OF ALASKA OIL AND GAS CONSERVATION CoMMrI'rEE SUBMIT Ilq DUPLICATE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS o...,..z, i'"-J O*,..,_L ["--J o,..-n Salt Wtr. In] ector, NAME OF OPERATOR UNION OIL COMPANY OF CALIF. A~D~SS or oPn~TOa 909 West 9th Avenue~ Anchorage. Ala,~ka. ~CA~ON OF W~ Conductor #1, Leg Rm. #3, 1798'N & 1413'W of the SE corner. Section 29: T9N, R13W, S. M. APl NI/MERICAL CODE 50-133-20272 6 LEASE DESIGI~ATION AND SEI~TAL NO. , ADL-17594 ? IF TNDIA~, ALOTLE~. Ok TRIBE NAMIg 8. L.~IT F.~ OR LEASE NA~ME Trading Bay Unit 9 %vE~L NO State G-22 (12-32) I0 Ft~D A.ND POOL. OR %VILDCAT McArthur River-Hemlock u sec. T., R. M. (_BqmM HOLE oamcrnrmi080'S & 2870'W of the su loc. or 2330'S & 950'E of the NW corner. Sec. 32: TgN. R]3W $.M. 12, PEP. MIT NO 75-16 ,,, "'13. P. EPOI~T TOTAL DE~TH AT END OF MONTH, CHANGES IN HOL~E SIZE, CASING AND C]/m/[ENTING JOBS INCLUDING DEPTH SET AND VOLU1WES USED, PER.FORATIONS. TESTS A.ND RESULTS FISHIT'ZG JOB~ JUNK LST HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS Drilled,. tripped & surveyed 12 1/4" hole from 10,110' to TD @ 11,336', Pooh for bit change. TI_T~._l..0..w,.~.r.__K..e..!ly. C0c.k.iR~r,.ted..i!! body. while working DP thru tight spot @ 9853'. Dropped 9858' of tools in hole. PU OS & RIH to 2870'-unable to locate top of fish. Pooh. RU stop on sand line unit. TIH to locate top of fish w/ stop, Hung up WL in 13 3/8" csg. RU T-bar & parted 9/16" WL. Left approx. 2500' WL in hole. Ran rope spear & rec. WL fish. CO 2566' of DP fish. DP parted in at least two pieces. Attempts to CO fish below 6918'+ unsuccessful. RIH w/ 5" OD OEDP to 6000' to lay cmt. plug in open hole. Pumped 500 cu. ft. Inlet wtr. Mixed & pumped 1100 cu. ft. cmt. w/ 1% CFR-2 & 2 1/2% pre-hydrated gel. Displ. cmt. to 5500. Pooh w/ DP. CIP @ 2:30 pm, 4/17/74. WOC. RIH w/ 12 1/4" bit, Tagged top of cmt. @ 5387'. CO firm. cmt. to 5650'. Pooh. RIH w/ 5" OD OEDP to 5646'. Pumped 100 cu. ft, Inlet wtr. Mixed & pumped 400 sx. Class "G" cmt, w/ 1% CFR-2 & 15% sd., densified to a 125#/cu,ft. slurry. Pulled up to 5200' & rev. out, Closed pipe rams & braden head' squeeze 45 cu. ft. cmt. plug with 1300 psi. Held press. 4 hrs. CIP @ 12:00 Noon, 4/18/75. Pooh w/ DP. R~.l...eased.rig to TBUS G-21 @ 12:00 Midnite, 4/18/75. Note: Will move back over TBUS G-22 after WO's on TBUS G-21 & TBUS G-23 to sidetrack fish and redrill. Refer to Form 10-403 submitted 4/23/75. 14. I hereb~ out'if3, that the/f~re~f ~ ~e and tract , ~rE --Report on mis fo~ is requi~d ~, ,~ch calendar ~thT regardless ~ the status of ope~tio~, and must ~ filed ~n dupli~te with the oil and gas eoneervatbn commiflee by the ISm of the suoe~ding m.~, ~le~ Otherwise directed. t,,[ (,' /i" e Union Oil and Gas ~-..{sion: Western Region Union Oil Companf ..,, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 Ufll fl April 23, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99502 RE: TBUS G-ZZ (12-32) GRAYLING PLATFORM ~ ill - '" Dear Mr. Marshall: Enclosed for your approval are three (3) copies of the recruited Sundry Notices & Reports on Wells for TBUS G-22, Grayling Platform. Very truly yours, ~"~ Sim R. Callender District Drlg. Supt. sk CC: Mar athon Oil Co. Atlantic Richfield Co. Standard Oil Co. Phillips Petroleum Co. Amoco Production Co. Skelly Oil Co. Rodney Smith - USGS AMCfl(,)RAGq F~rm 1~403 REV. 1-10-73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVAT!ON COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' o,L r-I GAs r-J WELLL-.J WELL OTHER Salt'. Wt~. Injector. 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIF. 3. ADDRESS OF OPERATOR 909 West 9th Ave, Anch. ora~e, Alaska 9'9501 4. LOCATION OF WELL At surface Conductor #1, Leg Rm. #3, 1798~N & 1413~W of the SE corner. Section 29: TPN, R13W, S. M. 1~. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 99' above MSL. 14. Check .Appropriate'Box To Indicate ,Nature of Notice,, Re 5. APl NUMERICAL CODE 50-133-20272 6. LEASE DESIGNATION AND SERIAL NO. ADL-17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-22 (12-32) 10. FIELD AND POOL, OR WILDCAT M cArthur' River.-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 4080'S &.2870'W of the surf. loc. or 2330'S & 950'E of the NW corner. 12. PERMIT NO. Section 32: TPN,R13W,SI~. 75-16 3ort, or Other Data NOTICE OF' INTENTION TO-' TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL ' CHANGE PLANS (Other) Sidetrack fish & redrill SUBSEQUENT 'REPORT OF.- WATER SHUT-OFF REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZlNG ' ABANDONMENT;' ' (Other) (NOTE..' Report results.of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of . starting any proposed work. .' . . , , 0 , Abandon existing Well bore bY' setting 11'00 cu. ft. primary crnt. plug in well from 6000' to btm. 13 3/8' csg. @.5548'. Dress off primary cmt, plug to +5650'. Set secondary .400'cu. ft, KOp cmt, plug (dens!fled cmt. w/ 15% sd.) from 565'0' to + 5400' & braden head squeeze to +1500 psi (equiv. to ,76 psi/ft., or ll0#/cff', £t, hyd. hd,).. Set RBP in 13 3/8" csg. to +..200'. Release rig t° perform WO operations for +14 days. Resume operations on TBUS G'22. Dress off cmt. plug to KOP of +5600' .' Directionally redrill well to the originally.proposed BHL & complete as Hemlock Injector. ,Tim ,R. Ca,~lender , ,=,~ TITLE Dist.. Drl'g. Supt. DATE .4/2~/7~ , (This space for State offi. ce'jise) .~.. :.-,. ........ . ..~ .... .~. ,,.,,...~.....~.'~,,. · APPROVED BY' CONOITIONS OF APPROVAL, IF ANY': See Instructions On ReVerse Side ~,-,,, No. ~,..-, STATE OF ALASKA ~"V. ~- 1-70 OIL AND GAS CONSERVATION CONU~I'I'i'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 1. o,,.,,,.,. I~ ~*".,,.,. [-] o~, W~. Inj ec~or Well ~. N~ OF OPhiR UNION OIL COMPANY OF CALIFORNIA 3.ADDR~S OF OPhiR 909 West 9th Ave, Anchorage, Alaska 99501 4. LOCATION OF W~-T-T- SUBMIT IN' DU'~LICATE AFl NU~ERICAL CODE 50-133-20272 LEASE DESIGBIATION AND SE'RIAL NO. ADL-17594 IF TNDIA~, ALOTT'EE O{~ TRIBE NAME 8. L.~IT F.~'/{VI OR LEASE N.~ME Trading Bay Unit 9 %vEL,L NO State G-22 (12-32) 10 FLF-,.D A_ND POOL, OR WILDCAT Conductor #1, Leg Rm. #3, 1798'N & 1413'W of the SE corner. Section 29: TgN, R13W, S. M. __ McArthur River-Hemlock 11 SEC. T., R.. M. (B~_m'rOM HOlE oamcTnr~ 4080'S & 2870'W of the surf. loc. or 2330'S & 950'E of tk NW corner. Sec. 32; T9N. R13V 1~. PEPdVIIT NO S. M, 75-16 REPORT TOTAL DEPTH AT END OF MONTH. C~IANGES IN HOLE SIZE, CASING AND CEMF. NTING JOBS INCLUDING DEPTH SET ~ VOLUIVI'ES USED, PERFOP.-ATIONS, TESTS A.h-D P. ESULTS FISHING JOB~ JU'~K IN HOLE AND SIDE-TI~.ACKED HOLE AND A~Y OTI-IE~ SIGNIFICANT C~[A.~G~S IN HOLE CONDITIONS Commenced rig-up operations on TBUS G-22 @ 12:01 am, 3/4/75. Skidded rig over Conductor #1, Leg Rm. #3. Installed 26" riser & CO fill & cmt. in conductor from 299'-360'. Spudded well 0 12:00 Noon, 3/4/75. Drilled 17 1/2" hole to 645'. Pooh· RIH w/ 23" hole opener. Opened 17 1/2" hole to 23" to 636'. Circ. hole clean. Pooh· RU & ran 20" 94# H-40 csg. to 629 w/ stab-in FC @ 579'. Landed 20" csg. on CIW ilo-thru hgt. Ran 5" DP,& stabbed into FC @ 579'. Circ. hole clean. Pumped 2'00 cu. ft. caustic wtr. Mixed & pumped 461 sx. (895 cu. ft.) Class "G" cmt. w/ 2 1/2% pr,hydrated gel & 2% CaC12 followed by 200 sx. (230 cu. ft.) Class "G" cmt. w/ 3% CaCI_. Good cmt. returns to surface. Pulled out of stab-in collar @ 579'. FloatZhel~'"'0~"~ ...... -P'~)'°h" W'/'5"'"'""'D'P-~. --~e~noved 26" riser. Installed 20" hydril & 20" riser . PU 17 1/2" bit & BHA. CO 20" conductor csg. to FC @ 579'. Tested 20" csg. & BOPE to 500 psi-ok· Drilled FC & 20' of firm cmt. Ret,steal 20" csg. to 500 psi-ok· Drilled cmt. & FS @ 629'. Drilled 17 1/2" directionalhole from 629' to 5548' w/ Dyna-dri11 runs from 981' to 1247' and from 1926' to 2170'. DP torqued causing drive bushings to jump out of master bushing and backing off DP three times while drilling at 2674' 3226' and 3228' Rec total fish all three times , · · · Repaired drive bushings and master bushings· Ran DIL-SP and CNL-FDC-GR Logs from 5548'TD to surface· RIH w/ 17 1/2" bit. Circ. &cond. mud for csg. RU and ran 136 its. of 61# & 68#.K-55 Buttress Csg. to 5548'TD (FC @ 5465', DV tool @ 2733') Circ. hole clean. Cmt'd btm. stage w/ 1450 sx. (2780 cu. ft...) Class "G" cmt. w/ 1% CFR-2 & 2% CaC12 in 2.5% pr,hydrated gel mixing wtr. followed by 200 sx. (230 cu. ft,) Class G cmt. w/ lo CFR-2 & 3o CaC12. Preceeded cmt, w/ 200 cu, ft. caustic wtr. & 200 cu. ft. Inlet wtr. qp..ene..d D~....~..o..9_1__~_..2.733' & circ, out 260 sx., excess cmt. above DV tool. Cmt'd top stage w/ 1470 sx. (2822 cu. ft.) Class "G" cmt. w/ 1% CFR-2 & 2% CaC12 in 2.5% prehydrated gel mixing wtr. followed by 200 sx. (230 cu. ft.) Class No. 8-1-70 ( STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'I'I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS l, W~LL 2. NAME OF OPEI%ATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WEX~ OTHER SUBMIT 1~ DUPLICATE AP1 Nt.~IERICAL CODE 6 LF..ASE DESIGNA'I'ION A.%'D SEI~IAL NO, IF INDIA]~', ALOi l~.~. OR TRIBE NAME 8. L~.'IT F.~ OR LEASE NAME 9 %v=~J., NO I0 FLeD A_ND POOL, OR WILDCAT I1 SEC , T.. R., M, (BO'FI'OM HOLE oamcTn~ ~2. P~IIT NO "13. REPORT TOTAL D]IPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING A/~D C~TING JOBS INCLI;DING D~ SET A~ VOL~ US~, P~O~TIONS, ~TS ~ ~SULTS FI~ING JO~ J~K ~ HOL~ AND SIDE-~CK~ HOLE ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS "G" cmt. w/ 1% CFR-2 & 3% CaC12. Preceeded cmt. w/ 200 cu. ft. caustic wtr. Closed DV ports & tested to 2500 psi-ok. Removed 20" BOPE. Hung off 13 3/8" csg. Installed CIW 13 3/8" csg. hd. spool & tested to 3000 psi. Installed 12" 3M BOPE & tested to UOCO specs. Ran 12 1/4" bit. Drilled out stage cmt. collar @ 2?33' & tested 13 3/8" csg. to 2500 psi - ok. Drilled out FC @ 5498' plus 20' of cmt. Retested 13 3/8" csg. to 2500 psi-ok. Drilled cmt. & FS @ 5548'. Drilled, tripped & surveyed 12 1/4" hole from 5548' to 10,110' w/Dyna-drill run from 7758' to 7841'. Now: Drlg. @10,110'. *Note: Released rig from TBUS G-22 for a 24 hr. period (12:00 Midnite, 3/16/75 to 12:00 Midnite, 3/17/75) to TBUS G-23. No rig activity on TBUS G-22 on 3/17/75. / Form / REV. 1-10~73 / / ., ,.. Submit "1 ntentions" In Triplicate & "Subsequent Reports,' In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. OiL I--1 GAS I--1 WELLL.--I WELLL~I OTHER Water Injection Well. 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #1, Leg Rm. #3, 1798'N & 1413'W of the SE corner. Section 29: TgN, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 99' above MSL 14. 5, APl NUMERICAL CODE 50-133-20272 6. LEASE DESIGNATION AND SERIAL NO. ADT,-]7594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-22 (12-32~ 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) 4080'S& 2870'W of the surface loc. or'2330'S & 950'E of the NW corner. 12. PERMIT NO. Section 32: T9N, R13W, S 75-16 Check Appropriate Box To Indicate Nature Of Notice, Report, or Other Data NoTIcE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR'AClDIZlNG ABANDONMENT* (Other) .... (NOTE: Report rebuts of multiple completion on Well Completion or RecomPletion Report and Log form.) (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, an(J give pertinent dates, Including estimated date of starting any proposed work. Corrected Surface Location: Conductor #1, Leg Room #3, 1798'N & 1413'W of the SE corner, Section 29: T9N, R13W, S. M. BHL - 4080'S & 2870'W of the surface location or 2330'S & 950'E of the N~ corner. Section 32: T9N, R13W, S. M. The proposed surface location for TBUS G-22 has been changed to enable WL operations to continUe on TBUS G-23. Change In Casing Design: Size of Hole Size of Casin$. ...Weight Per Foot Grade Setting Depth. 26" 26" 1/2'" W.T. Drive Pipe Pre-driven to 369' 24" 20" 94# *H-40 +600' 17 1/2" 13 3/8" 61# & 68 # *K-55 +5500' . ,. 12 1/4" '9 '5/8" 47# *N-80, P-110 +11,600' & USS-95 Note: Details on the cementing prbgram are outlined in Note #1 through Note #4 in the Drilling Orders for TBUS G-22 forwarded to the Division of 'Oil & Gas 2/25/75. *Buttress Csg. 16. I hereby certify that the fo_regoJJ~l:lS tr,',e and correct r~.~ ~~~b'"~~ .. TIT, LE 'r').~fi.l.: ~wl~: ~11~: SIGNS U. a. a ennson for J. ~. Caiien~r DATE (This space for State office use) CONDiTIONS OF~R~PROVAL, I F ANY-' See Instructions On Reverse Side DATE Approved Copy Returned form UNION OIL COMPANY OF CALIFORNIA Alaska I) i. stri ct;,- Drilling Orderr~. WELL NAME: TRADING BAY UNIT STATE G-22 (12-32) DATE: 2/25/75 PROSPECT: Grayling Platform, Cook Inlet~ Alaska AFE NO.. 351402 LOCATION: ELEVATION: DRILLING: Conductor //4, Leg Rm. #3: 1810'N & 1412'W of the SE corner. Section 29: TgN, R1BW. SM. 'BHL - 4080'S & 2870'W of the surface location or 2330'S & 950'E of the NW corner Section 32:.TSN,'~13W, S, M. ' .. · MSL: RT 99' above MSL. TOTAL DEPTH 11.600'+ Bit Size Depth 17 1/2" bit , 600' 24" fixed blade hole opener 0 to 600'MD +5018'TVD 17 1/2" 600'MD tO _%'5500'MD - +5018' TVD +10,200'TVD 12 1/4" ~5500'TMD to ~11,600'TMD Deviation Max. Angle to Depth See directional prog: to to to to CASINO:, LINER: Size _ Description ---= Setting Depth . ~ .Cement 26" 1/2" W.T. Drive Pipe Pre-driven to 369' See Note #1. 20" 94# H-40 Buttress Csg. +600'MD See Note #2. +5018'TVD ' 13 3/8" 61#-68# K-55 Butt. Csg. ~5500'TMD See Note #3. ' TV'D : 10,200' . , . 9 5/8" 47# N-80, P-110, USS-95 ll,600'TMD see Note #4. " Buttress Csg. *Note:Cat., slurry type & displ, for results of lab tests (Howco). 20" & 13 3'/8" & 9 5/8"' csg. is dependent Upon · . 13 3/8" Casing Design Dept~ F00tage Description Weight · Acc. Wt.. S.F.T. S.F.C. .07,27,00'(2580'T.V. ,D) 2700', , .,,'61# K-55, Buttress 164,700 355,100 2.71 1.06 2700-5500'(5018'TVD) 2800' 68# K-55 Buttress 190,400 190,400 " 5.'61 0.78 Note: Collapse on 13 3/8" 68# would be applicable only if fluid level inside csg. were removed to : th'.. 3518'TVD.,]evel w/_75# mud in cs_~. _annulus, ....... 9 5/8" Casing Design 0-8800'TMD ' 0~ __ 8800' _ 47# N,80 Bu.~tress_ 413..,600. · '545.200 .. 1.99 . 1.127 8800'-10,400'TMD " . 7860'-9230'TVD 1600' 47# P-il0 Buttress 75,200 131,600 11 3 1.127 ' ~ . 10,400'- 11,600'TMD o,~O'=30;2O0'T. VD 1200~._ 47# US,S...-.95~Buttre. ss. 56,400 . 56.'400 22.9 1.39 DIRECTIONAL PRLGPukH: KOP 1000' BUILD ANGLE 2 1'/2°/100' TO 30° 18' @ 2200'MD DIRECTION S34° 53'W of surface R~iAR2<S Kick off @ 1000'w/.+ 22° lead ~ 3000' (S]7°W). · DIRECTIOXALI~ft handle, adco.(Sl~0W) .ADDCO Have min. of 18°~ l~.f~ DEFLECTioN ToOL. Dyne-Drill. bogging Dep~s. 1. 5500'MD Other Electric Services · . 11,600'TMD ..... Type ,, (1) ... ,DIL (2) DIL-SP CNL-FDC-GR CNL-FDC-GR BI{C-GR WET,I, ..' .... TRA 'G BAY UNIT STATE G-22 (12-32) DRIL!ff:?I :."'n: Dl~t,.'i.butor IMCO S.er~,ices ' *Note: Test 13 3/8" csg. seat #/cu. ft. Static HTP Depth "' ~ ~"~ ~-L~'~ Water Loss @:200OF- 500 psi **Use M,A,D. Hydraulics Concept. · 650 psi/ft· Remarks** See .attached .drillin,~, optim ~ program., · 1. 0-600' 72# NC 1. 'Type ~Lienosulfonate Polymer (X-C) Run Inlet wtr. gel mud..Maintain CEC @ +26-~b#/bbl. D'esand &~ h'esilt mud c0ntinuousl) l~un ~0 ~creen.~ or) SwecQ .l~.~iltar. , 2. 600'-5500' 72#-74# 14-20 cc. 2. · ! I .l i , . i L · I I , Il Il I mi , __ i i _ [ ' ,Run. shear-thin low-solids mud system. Maintain minimum K values at ~.0+ & attempt tc keep N values @ 0.3+. Add eel & fresh wtr. as required to maintain desired filter cake co.rnpressibilit¥. Ke,ep co, nstant check .for carbonate' contamination. Report mf-~m-of. Contrbl excessive ~el strengthS' .w/ ',VC-10 If hole conditions warrent, be prepared to add Run mud as in step' #2, Report CEC daily. R Report same, Report shear S~ress #/100 it,'2 i~ ~ out & 3-6-100-200-300-6,00' RPM readings. Re6ord flow line temps & temp. of' sampl'e whet. Rheology is checked. .. COMP~=TION: Tub!ug and Packer AND' S~VXCES: TBD Wellhead equipment - Cameron Ironworks. Cementing service - Howco' 3. ~ Flo.at__.e.q.uipm. 3nt :~'DoweH ........... 4. , Electr!,.c logging - S.chlumberger. :_ : mm 6. 7. 8. Bits - Union Oil Comps,ny warehouse stock. Casing crews & service - AYR Stabilizers &, BHA -Dri,lco.-LOR-Servco-(*Use surplus stock). , =R~_.EMARKS: ~o ~mo~in, g on or under ri$ f].oor. Submit one copy AAODC Tcur Repprt and qnion___~'s____. Daily Mud Record ~ ' · _ ,. ., , da.~.y.. Test BOP's, to Union"s_ soecificat, icn on in.$,tal!at.!on ~nd e~ch ).:onda.,.v . thereafter, lqOPfs are tO ..be~ ope~r~,ted Ldai_ly, preferab!~ on alter~tting Pit drills & safety valve drills are to be conducted daily and times reported on T)DR Form.' All mu, .., ~ , ,__ ...__ ~ _ , ,.. Tonot0ring e,q,,uipmen,,.t.!s to be_ch, eck?,d.daU¥,,f0r res,p, o3~,se and calibration, yore: mc~ up Grade "S-135" 5" DP when drag reaches 250M# or .,8000' of depth. Visually, inspec,'t ail. D,P,,,~p r,un,,.fn,,,,hole, Form 10-403 REV. 1-10~73 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 proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL r'"] GAS D OTHER WELLl I WELL Water Injection Well. 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsufface Conductor #4, Leg Rm. #3: 1810'N & 1412'W of ,) 5. APl NUMERICAL CODE 50-133-207.72 6. LEASE DESIGNATION AND SERIAL NO. ADL-17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit '9. WELL NO. State G-22 (12-32) 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock, 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) .... / the SE corner. Section 29: T9N, R13W, S. M. 13' ELEVATIONS (Show whether DF, RT, GR, etc.) RT 99' above MSL. 14. Check Appropriate Box To Indicate Nature of Notice, Re: 4080'S & 2870'W of the surface loc. or 2330'S & 950'E of the NV 12. PERMIT NO. corner. Section 32:T9 75-16. R13W, S. M. )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF R FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER'SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Corrected Surface Location: Conductor #4, Leg Rm. #3: 1810'N & 1412'W of the SE corner. Section 29: T9N, R13W, S. M. BHL '- 40'80'S & 2870'W of the'surface location or 2330'S.. & 950'E-of the NW corner. Section 32: T9N, R1BW, S. M. Change In. Casing Design! Size 'of Hole Size of ,Casing Weight Per Foot Grade Setting .Depth 26" 26" 1/2" W.T. Drive Pipe Pre-driven to 369' 24" 20" 94# * H-40 +600' , ~ 17 1/2" 13 3/8". 61# & 68# * K-55 +5500' 12 1/4". 9 5/8" 47# ~N-80, P-Il0 ~11,600' & USS-95 Note: Details on the cementing program are outlined in Note #1 through Note #4 on the enclosed Drilling Orders .for TBUS G-22. *Buttress Csg. ... // -Jim ~. (Jallender (Thls~ace for State office use) District Drlg. Supt. DATE. 2/25/75 ,, ...Wi,~ION OF OIL AND GAS ANCHORAGE See Instructions On Reverse Side Approved Copy ,' ~:"~;i' . Memorandum Union Oil Company(' California February 25, 1975 TO: Jim R. Callender District Drilling Supt. FROM: Dave A. Johnson ~ ~ " Drilling Engineer SUBJECT: RECOMMENDED DRILLING PARAMETERS FOR WELL NO. TBUS G-22, GRAYLING PLATFORM ..~ · The following is a recommended list of drilling guidelines for the 17 1/2" hole and 12 1/4" hole for Well No. TBUS G-22, Grayling Platform. Th.ey should be used as guidelines only, subject to change as. field conditions dictate. MUD PROGRAM 17 1/2" Hole The 17 1/2" hole should be..spudded with the "XC" Polymer' system left over from Well TBUS G-23. The recommended guidelines for the mud properties are listed below. The guidelines are for the desired optimum conditions & emphasis. should be. placed' on holding.the mud properties constant. · Mud Wt. Plastic Viscosity Yield Point Gel Strengths Cake ll nll ii KiI Water Loss CEC C1-' Ca+ Solids 70-72#/cu. ft. Maintain in the range of 8-12 cps. Maintain the YP/PV ratio in the range of 2.0-2.5. Maintain initial gels in the 6-12 range. Hold 10 min. gels as flat as possible to initial gel strengths. Be alert for progressive gel strengths. Use lignites to control gel strenths when needed. Maintain a thin tough filter.' cake. Use bentonite as needed to control the filter cake. : APprOach as' close to a 0.3 "n" value on the 300 & 600 RPM as possible. Maintain 300-600 "K" values below a 3.0. Maintain water loss in' the range of 10-20 cc. Use Poly-RX & gel for filtrate control if needed. Maintain the #/bbl of bentonite..equivalent above 20. bio control-use fresh water if possible. Treat for calcium' contamination from sea .water, as required. Maintain a low solids system utilizing so'lids removal rcqu'ipment on board. Dilute and water back if needed. Form 035 (Rev, 7/67) Jim R. Callender TBUS G-22 (21-32) February 25, 1975 12 1/4" Hole The "XC" Polymer mud used in the 17 1/2" hole should be maintained in the 12 1/4" hole. After drilling out cement in the i3 3/8" casing string, the mud should be conditioned to.the 'recommend'ed' properties listed below prior to drilling new hole with. the exception to water loss which .can be lowered to the desired range if it is not' excessively high. Mud Wt. Plastic Viscosity Yield Point Gel Strengths Cake. Water, Loss CEC CI- Ca+ Solids 70~72#/cu..ft. Maintain in the'range of 8-12 cps Maintain the .YP/PV ratio in the range of 2.0'-2.5. Maintain..initiat 'gels in ~he 6-12 range. Hold 10 min. .." ..... gels.as fl."~'{." as possible to initial gel strengths.' Be. alert for prOgressive gel strengths. Use lignites to control gel strengths .when needed. l~laintain 'a thin tough filter cake. Use bentonite as ."... needed to control the filter cake. '..'APproach.as close to a 0.3 "n" value on the 300 & 600 ." RPM as possible. . ~:.M~in.tain 300-600 "K" values below @ 3.0. Maintain water loss in the range of 10-15 cc. Use Poly-RX & gel for filtrate control if needed. Maintain the #/bbl of bentonite equivalent above 24. No control-use fresh water when possible. Treat for calcium contamination from sea water. Maintain. a low solids system utilizing solids removal equipment on board. Dilute & water back if needed. Solids Control 'The' 'solids contror'equipment: RreSentl.¥ On 'board consists .of two conventional shakers, one high speed shaker., one two-cone desander and two eightrcone Sweco Desilting units. The high speed shaker, desander .and Sweco units should be utilized to their maximum capabilities. The two conventional Shakers should be utilized when field conditions dictate diverting partial flow from the hi-speed shaker. The Sweco units should be run without screens at all times. If excessive dilution is required to maintain a low solids system with the present solids control equipment at full operation, the installation of a third Sweco unit should be strongly considered. Jim R. Callender TBUS G-22 (21-32) -3- February 25, 1975 ANNULAR FLOW PROFILE AND. HYDRAULICS 17 1/2" Hole Annular velocities should be maintained between 40-55 ft/min, with 55 ft/min. being the more desirable objective. If the mud is kept at it's recommended properties, good hole cleaning, low annular pressure drops and laminar flow conditions for minimized hole erosion will exist at this velocity range. It is recommended to start the 17 1/2" hole with 2-16/32" nozzles and one blank. · The largest nozzle size combination required for the entire 17 1/2" hole should be 2-18/32" and .one blank. With 2-16/32" nozzles, pump pressure should not reach it's maximum of 2500-2'600 psi until +_2000' w/ 55 ft/min, annular velocity. With 2-18/32" nozzles, annular velocity should be approximately 50 £t/min. by 5'000' w/ 2600 psi. '12 1/4" .Hole Annular velocities should be maintain between 65-75 ft/min, w/ 75 ft/min, being · ... the more desirable objective. With the recommended mud properties, this. velocity range will insure .good hole Cleaning, low annular pressure drops and laminar flow condition~. It is recOmmended to start the 12 1/4" hole with 2-13/32" nozzles and one blank. 'Expected annular velocities will be 75 ft/min, w/ 2500-2600 psi starting, out of the 13 3/8" csg. shoe. This nozzle combination should be used during the entire 12 1/4" hole. With 2-13/31" nozzles, annular velocity should 'be 72 ft/m!n, with 2600 psi when TD is reached. BIT, WE,I, GHT & ,ROT,,ARY Class 1-1-1 type bits are recommended for the entire. 17. 1/2" section. The directional program may dictate to Some degree as to the weight and rotary 'program but should have very little bearing once the well is locked in on course. The best recommendation of weight and rotary for this interval' is the maximum that can safely be achieved. Rotary speeds as high as 150 RPM and 'bit weights up to 70,000# have been used on previous wells in the first 5000' interval with good penetration rates being maintained w/o .equipment damage. Jim R. Catlender TBUS G-Z2 (21-32) -4- February 25, 1975 Class 1-1-1, 1-2-1, 1-3-3, 5-1-5 and 5-1-7 type bits will be required for the 12 1/4" hole. Individual bit selection should be based on information from the DIL-ROP comparison logs from TBUS G-21 and TBUS G-23, the type log plotted on the proposed TBUS G-22 directional plat and the.actual bit performance being obtained on the well. Bit Weight and rotary should be the maximum that can safely be achieved. DAJ/sk . . UNION OIL COMPANY OF CALIF. Alaska District. Drillin,g Orders NOTE #1: ae C · EJ NOTE #2: A. B · C · D , 26" Drive Pipe & Drill-Out (Driven to ,depth of 369'). Install 26" riser as shown in diagram #1. Run 17 1/2" bit & CO 26" drive pipe to 369'. Run 24" mill & dress out 26" drive shoe @ 369' . Drill 17 1/2" vertical hole to +600'MD. Run 17 1/2" OD fixed blade h~le opener in tandem w/ 24" OD fixed blade hole opener. Open 17 1/2" hole to 24" to +_600'MD. The 24" ' hole should be drilled to fit the 20" csg. This will insure a minimum rathole below the 20" csg. shoe. Oond. the hole prior to running csg. Circ. all sd. out of mud and add 2#/bbi. fresh gel. 20" Conductor & Drill-Out. 'Run 20" OD 94# H-40 Buttress Csg. w/ Dowell Float Shoe & stab-in float collar 40' above guide shoe· Hang 'off 20" csg. on 24 3/4" OD CIW hanger on 26" Cameron' landing hub. Cement 20" csg. as follows: 1. Stab into 20" float collar @ +560' w/ 5" DP. 2.. Circ. well clean @ reduced pumping rate. 3. Pump 200 cu. ft. of caustic wtr. mixed w/ i#/cu, ft. caustic soda. 4. a. Mix & pump light wt. class "G" cmt. slurry u'ntil cmt. returns to surface. *Actual cst. slurry mix will depend.upon cmt. lab test results prior to running csg. b. After cmt. returns to surface, mix 200 sx' 'class "G" neat w/ 3% CaC12 in mixing wtr. @ a slurry.wt, of 118#-120#/cu. ft. Displ. cmt. to stab-in collar @ +560'. c. Pull out of stab-in collar & check float equipmeni.. If ok, Pooh w/ DP stab-in tool.' 5. Pick up. 26" riser & wash out cmt. Cut off 20" OD landing jt. as shown in diagram #2 & install 20" SOW csg. head.. Install 20" riser & 20" hydril as shown in diagram #2A & #3. Run 17 1/2" bit &'CO 20" csg. to stab-in float collar @ +_560'. 20" csg. to 500 psi. Drill out ,float collar plus 20' of cmt. Retes't 20" 6sg. to 500 psi.. Drill out w/ 1.7 1/2" bit. TBUS G-22 DRILLING ORDERS -2- February 25, 1975 F · H· NOTE #3: A· B · C· De E · F · He K· Drill 17.1/2" vertical hole to KOP @ 1000'MD. Drill 17 1/2" hole as per directional program from 1000! KOP to +5500'TMD. -. ~irc. &cond. mud @ 5500' prior to running 13 3/8" csg. Add 2#/bbl fresh gel to mud. 13 3/8" Casing & DrillLO_ut~. Run 13 3/8" float Shoe, 13 3/8" float ~ollar +40' above shoe & 13 3/8" plug Catcher +_80' above shoe· Run 13 3/8" X 17' 1/2' centralizers 10! above float shoe, 30' above float shoe & 60' above float shoe. Run 1 centralizer in the middle of every other' jr. to 2500'. Run DV stage cmt. tool @ +_2500' w/ a centralizer 10' ab'ove and 10' below tool· Run 13 3/8". X 17 1/2" centralizers every other jr. to 400'. Run cmt. basket @ 500' & @ 400' w/ centralizers' above & below basket. Cmt. 13 3/8" csg. to two stages as follows: I. Pr,eceed each cmt. stage w/ 100 cu. ft. caustic wtr., 200 cu. ft. SAPP wtr. & 100 cu. ft. Inlet wtr. 2., Cmt. btm. stage with: a. +'1150 sx. of Class "G" light wt. cmt.* b. ~ail-in w/ 400 sx. Class "G" cmt. neat w/ 3%'CaCl~.. 3. Cmt. top stage with: a. +1850 sx. 'of Class "G''~light wt. cmt.* b. ~ail-in w/ 200 sx. Class "G" cmt. neat w/ 4% CaC12. *Actual cmt. slurry mix will depend upon cmt. lab test results prior to running csg. Pick up 20" riser & wash out cmt. Land 13 3/8" csg. on 20" X '13 3/8" CIW TYpe AW Csg. hgt. & cut off 13 3/8" csg. as shown in diagram #4. Remove 20" riser system. Install 'CIW 12" 3M csg. head. spool as per diagram #4. Install 12" 3000 psi BOPE as per diagram #5. Install choke manifold as per diagram #6. Test to UOCO specs. 1. Run 12 1/4" l~it & 7 3/4" drill collars. Do not. run any stabil.'izers to drill out float equipment & cmt. ,.. 2. Test 13 3/8" csg. to 2000 psi. '. 3. Drill DV tool (_d 2500' & 'retest csg. to 2000 psi. (.. TBUS G-22 DRILLING ORDERS February 25, 1975 NOTE #4: B ~ 4. Drill landing collar & 20' of cmt. in Shoe it. & test to. 2000 psi. (if in firm cmt. only). 5. Drill float shoe plug 10' of new hole below shoe. 6. Test cmt. job & csg. seat equivalent to a hydrostatic head of 650 psi/1000'. ' Example: If mud wt~ is 72#/cu. ft. this is equivalent to a 500 psi/1000' mud gradient and would require an additional pressure of 150 psi/1000' 'of vertical depth superimposed in the mud column to test the csg. shoe. If the test is ok, drill enough hgle to bury the packed hole assy. & Pooh to pick up · same. 9 5/8" Casing_. Amount & type of cmt. for 9 5/8" csg. to be. determined at the time of log run @ the csg. point. Land 9'5/8" csg. as per diagram #4. Install 12" 3M BOPE for completion work as in diagram '#5 ~, diagram #6. DAJ/sk 2o" .csp ,~o,,~o/. · ,.,o ,to" .9'./-* it-Fo · · · · · ° .w" / · /. o · · · ~..~;~. '~., .pi ^1.~"'~.. . '~. 3. 43 ~ b$S:n~bt,i .o :I . ·CHECk' VAZ VE I ANSLED FILL UP L//,"~ · . HYD£1L ,· · ., '. .. -I. · . · · i '. i · .i SATE VALVE · 8ATE VALVE REQ~,'REB · · ?IPE ~IJ. IS '~ ' I i · . I · _:,:. ::_~',Tc~.:::~ --4. _~:'l,~,~.~-_-:-)- · · . '"'~'T:" .... '~:t:~''''~'~.'''-- .' · ,iI · . · · .,' · · · · · · · NOTE' .' ' V£I¢ T ~ '¢H0/~£ . . ..(' · BUBBLE · TANK 0t? tI0/,',£ I,!4DE DEGASSER · · o · · · o L.P. VALY£ · I.. P. VALVES IOJUST~£LE · · .o POSITII/E CHOKE I1¥. Febru.y 7, 1975 Tradln9 Bay UAlt G-22 (12-32.)' Unten 0tl Company of California Permit Ho. 75-16 Dt. strlct Lam~ Ftanager 'P.O. Box 6247 Anchorage,. Aluka 99601. Dear StP: £nclosed .t's the approved app11.catton for permtt to dr111 the above referenced ..e11, on or about Februa~j 20, 1976, at a lecatton from the Greyllng Platform, hie11 samples, core chtps, and. a mud log are not required. A dlrecttona.1 survey ts ~equt~. Pollution of any ~a'te, of the .State ts prohibited by_AS 46, Chapter 03, Arttcle 7 an~ the. regula'ttons., p_romulga.ted thereunder (Tttle 18, A.las.ka. _ klmt.ntstratlve Code, Chapter .70) and. by the Federal. Hater Pollution Control Act, as amended..Prlor to cemaeactng operations you may be contacted by a representative of the Dep, tment .of Environmental Conservation. Pursuant to AS 38.40, Leca] H!te .Under State .Leases, the. Alaska Department of Labor ts. beth9 notified .of the tssuance of thts permt't to dr111. Very truly ;yours, O. lC.. Gtl'breth "' .. Cba.t, rman Alaska 0fl and Gas Conservatt.on. 'Conmtttee.. Encl. eSure cc.: Oepa~t of Ft. sh and: Game, llabttat Sectton w/o. eat1. Department of Envtronmen.tal Conservation w/o eric1. Oe~rtment of Labor, Superv!sor, Labor Law Comp11'ance Otvtsten w/o eric1. ' .. ,..., ,, R.EV. ( STATE OF ALASKA OIL AND GAS CONSERVATION :COMMITTEE SUIlMIT IN TRIPI,IC~"~, (Other instruction! o'i' rev,,rs¢, side) ~. APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK IA.TYPE Or WORK DRILL J~ DEEPEN J--I PLUG BACK b, TtP. O, WE,.,. Water injection well ~'" 0 °"I-1 '"~"' 13 """'"'"' FI tgi. I, WELt. ~)TIi ER ZONE Z NAME OF OPERATOR Union Oil Company of California P.O. Box 6247, Anchorage, Alaska oo~rll 4 LOCATION OF WELL , , ~ v Atsurface Conducto~- #3, ~e~ ~3, 1806'N & 141S'W of'SE corner of Sec. 29, TgN, R13W, . . ~,.o~}~o~.~o~ Top Hemlock. Approx. 3750~S. ~ 2630~W of surface location or 1~9~S and 1210~E of NW corner. Sec' 32, TON, ~q3~ 13. DIST~CE IN MILES AND DIRECTION F.tOM NEAREST TOWN OR POST OFFICe S.M ~4 miles NW of K~gai 14. ~OND I~O~TIO~: ~[~tewide s~[~~cific Insurance Co. B-55372 3,500 NO. Or ACRE8 IN LEASE .' 5116, 11,650~TMD & 10,2001~ 15. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. I AI?.o to nearest drig. unit, if any) _ 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR, l~r, 2,000' 21. EI,EVATIONS (Show whether DF, RT. eR, ete. p A.P! ~ 50- 135-20272 i, 6.I,EASE DI~I$I(;NA'I'ION A. ND .~il~itlAL NO. ADL-17594 7] IF INDIAN. AL,I.Z)'I~FEE tlr 'I~IBE NAME 8 UNI'I',I"AI(M OR LEASE NAM/: Traclin~ Bay Unit 9. WELL NO. '' ' G-22 (12-~2) 1o. FIELD AND POOL, Oil WILDCAT McArthur River - Hem. I1, SE(',. T.. Il., ,M., PBO'I'FOM I HOLE Oma-CT(YE, 4080 S & 2870'W of Surface loc. or 2330'S & . 950'E of NW corner. Sec. ' '~'TgN,. R13W. S.M. A-,.o~t $100,000 RT 99' above'MSL PROPOSED CASING AND CEMENTING PROGRAM 17. N(.). ACRES Ab'~tGNEI) TO THiS WELL 160 20. ROTARY OR C.'ABLE TOOLS VD Rotary APPROX. DATE WORK WlI,I. W|'ART* February 20. 1975 L __ SIZE OF HOLE ~SIZE OF CASING· , ,WEIGHT PER FOOT GRAD~ SE-~-r~IG DEPTH QUANTITY OF C~MEN: 26" 2'6" ~" w~l] fh'iccna~ 373' Pre-driven to 373' below 0' elev'.- 24" 20" 94# H-40 ~80' See attached _ ~.t" 13 3/8" kl~ ~, (,R~ K-qq ~.q~nn ~D See attached - _ i2~" 9 5/8" 47~ See Detail 11',9,50 ~[D 8~a attached ' Attachments: lJ Target'- GSG. Program - Plan of Procedure. Cementing Program. 13 3/8" & 9 5/8" CSG. Design. BOPE Diagrams no. 1 through no. 7 I9/5 IN AflOVE SPACE. D~'SCtILIIrlE I~ROPOSIRD I~RAM: If p~l ~ ~ deo~n or plug ~ek, give (am on present p~)duPllve, zon~ and i,ropo~t new prm'hn'tlw. ~one If pro~aal la ~ drill or d~len direct onally,, give I~rtlm~nl dnta Oll 81$b;lllr~lll~ ~wat~ma and mvah'Q~d and [r'ue verth,.I dvptha. Give bio.u[ ~ .... . -, _ _. , /---,' ,;v~-y , _ _ (This space for State office u~') . CONDI~O~8 Or APP~V~, IF ANY: o ~= ~NO See Transmittal Letter ~ v~ o ~o 50-133-20272 'TIT~ District Land Manager Febr,u, ary 7~ 1,975 n*~ February 7,1975 --t Conductor It3, Leg ~13, (~' .~yling Platform. 1806'N & 1415'W of the SE corner. Section 29: TgN, R13W, S. M. TARGET LOCATIONS: · Target "A": Top Hemlock, approximately 3750'S & 2630'W of the surface locatioh or 1990'S & 12]0'E of the Nlq corner. Section 32:T9N0 R13W0 S. M. · Target "B": Bottom ~Iolc, approximately 4080'S & '2870'W of thc surface location or 2330'S & 950'E of the NW corner. Section 3.2: T9N, R13W0 S. M. OBJECTIVE:. Hemlock Oil Pool: At approximately 10,870'TMD, .9550'TVD. Distance out 45?5' @ S35°W. Bottom Hole: 150' below base of Hemlock @ approximately ll,650'TMD, 10,'200'TVD. Distance out . · 5000' @ S359W'. CASING PROGRAM: 26" Driven to 378' 20" Conductor 800'+ (cmt. to surface,) 13' 3/8" Surface 5000'+ (cmt. 'to surface) 9 5/8" Production 'll,-g50' (as required) PLAN OF PROCEDURE: i. Move rig over TBUS G-22, Conductor #3, Leg #3. 2. Install & test BOPE. 3. Drlg. 17 1/2" hole & open to 23" to +_800'.. 4. Run & cmt. 20" csg. 5. Drlg. 17 1/2" hole to +5000'. .. 6. Run & cmt. 13 3/8" csg. to +5000'. 7. Drlg. 12 1/4" hole to ll,650'TMD'. 8. ' Log as directed. 9. Run & cmt. 9 5/8!' csg. to ll,650'TMD. 10. Run CBL & perf', as directed in completion fluid· 11. Complete as a Hemlock water injector. 12. De-mob .& move rig off hole. · . ESTIMATED COMPLETION TIME: Drilling Time .Complciion Time FOrty-Two (42) Days. Twenty, (20) Days. Sixty-Two (62) Days. TOTAL TIME · ,, G}:~,IF, NT_[}3_I.,,C._~.}::I.__,£D.'.J~].?'2!7;_: 'I'1~( : calculatio,,:, provide the optit~ o£ using 12.°~ dry mi>:ed w/ bulk cmt. 20" CASING · · .5o5 x - c0' = · 0.9599 X 440' · --' 1..9947 X 50' = gel 541.9]. cu. ft. bc:lween 20" cng. & 26" csg. 422.36 cu.' ft. belweun 20" esg. b 24" 99.73 cu. fl. leave 50' of cmt. i~l'Z0" czg. 064.00 cu, 21] .]8 cu. ft. 50~o excess on 422.36 cu. TOTAL 1275.'18 cu. ft. Slurry:' 915 cu. ft..Class; "G" ,,vi 12% gel 94i~/~f!.3. tail in w/. 360 cu ft , · · Class "G" neat and 29~ calcium chloride ].l. 8~;'/ft.3 in mix wlr. Displacement 5"DP: 760' X .0995 = 75 cu. ft. to stab-in.. '. Wit. to Mix Cmnent': ' [(915 cu. ft.)"T 2.26 cu. ft./sx.~ X ]2.8 gal/sx. = 5,182.3 gals].23 bbls. . , Car, ae~y of 20" eng. =. (800) (.3552) = 285 bb!s. Displ.ace w/ ri~ pump 6 1/2" X '16" l~ner 284'bbls' 0.1785 BI'S = 1551 strokes, to pump plug ~} 60 SPM = 27 rains. FIRST S'rAC;E 5200' - 13 3/8" 61ti & 68i~ cs.[;. Stage collar 0.. 2600'MD. k.' 2600' X (.6947) = 1006.22 cu. ft. betweerx ]3 3/8" csg. & 17 1/2" hole. 80' X (.8315) = (,6.52 cu. f~ left inside ~hoe jr. 'I'OTAL 2'/75.85 cu ' ft. t" ~5~ ~5 Tl,eoretical fill of 17 ]/2" hole = 3996' ,BIVISI i Oi . Slurry: 2,t0t~' cu. fl. Cla~; '"G'~ w/ 1~e',.'o gel, l~g CFR-2 h)llowe(l v.,/ 370 cu. ~.; . . · ~,~ Gel slurry -' 9'ili/~t.3 Neat ~;lurry --'ll8;~/ft.3 (2,106~ 2.2(.) X 12.8 = 13,627 gals. = X2.1 1)ltl ~ (370~1 15) X 5 = 1 6(19 gal~;. = 38 bbl. []g~, .. , , · C ]"..', IEN'J' CAI,C:t !I,A']'I ON$: Capacity of 63/I 13 3/8" c. sg. = (,.7:,0) (3.521) = 415 Capacity of 68~,"13 3/8" csg. = (2,t70) (.3497) = 370 TOTAl, Displ;zcc.mc. ntx(,/ rig pmnp 6 1/2" X 16" liner. '/85 bbl$~ 0.]785 }.;P..S = 4,398 strokes to pump plug (~} 60 SPM = 73 min.s. · SECOXD f;T/',GE DV @ 2600'. 1800' (.6946) = 1250.28 cu. ft. between 13 3/8" csg. & ].7 1/2" hole. 800' (!.0!9) = 815.20 ch. ft. between 13 3/8" csg. & 20" csg.' 0 50 X (1.250.28)=;'~r 1~' · ,.,.:~. -: cu. ft. 50% excess TOTAL 2690.62 cu. ft. " Slur:cy: 2390 cu. ft. Class "G" w/. 12% gel & 1% CFR-2 followed by 300 cu. ft. Gl.ass "G" neat. Wtr. to mix Cement: (2390' 2.26) X 12.8 = 13,536 gals. = 322 l~bls. (3004--1.15) X 5 = 1,304 gals. = '31 bbls. · Displace' 1.3 3/8" ¢:sg. to DV tool @ 2600'. (2600'"- 61# csg.) (.1521) =' 395 bbl. s. disp].ac(.ment. Displace 1.3 3/8" cs~, w/ rig pump 6 1/2" X 16" liner · 395 bbls~-0.1785 BPS = 2213 strokes 0 60 SPM = 37 rains. [":E'6 5 i9 ~0[}0 '9'12 "rVD 9090' .o, oO . · o . · ,e t · · · /[/0, · · · o o ti ;1'7' l':r'''' ""': ''?/) "/~'""'~""'""~i ';'"" i~' J k, · e PRICES NOT UP TO DATE I I UNION OIL CG OF CAI.IF'ORNIA AI_ASIIA Dl$'l:lilO'r '" ""' "" ~ .... ~. -~ ~, ~ I{~ '~ IIOU~,'I (~t:. i I;:.,'.'; '/', ' ~ ~ fl3 I~ ¢ J ~ ' . .......... , ~ I.. . ~. ~ . · ............... ., D~ , ..~ ,, ,~ ~,., &:~, ....... · ......... ,.. . ~LJ ~ ,..~ J.:.i I , I I ...................... ,.-. ......................... I' -- .......................... L...L.<y.,,-, ......' ' .... · ..._. . ,, , . ,., ~.,x~ ,.~ ,.,...,...~-, I ~"~. (., ,",.~':,1 .......... I ....... I · ~ .......... ,_ . ........... ...~. ~ ..................... ............... ~ ............................................................................. ~.~,.,vT-~.., ~ .t t-.~ ................. , DI~.. "~'IL ~r"l'~) ~.k3 ''' · F'EB ',5 I9F5 ~G' oD. · · · 20 L. ,94'4- l-!-4 0 19.95G" Di'.~IF'F -'---I,:3 61f' DUT T [~ E c. ,- . 'Sd2,?F~£ ' · '-' '"" [""' E i975 L · ~'iIII$t..81.'~,,011 OIL AN'i3 6AS . - " . b '"'~'~,' i .... ' " " ............. "" I'., ~, , .~ /" . I .4. .. ........ ~ ;! . ,,, .... (~,~¢..;.~//' Z /, ,,.:, ,',,,.;¢ ~:, ~-':.. '.'. ~'"'i" I ' : ' """ .... :""" " i i..' 3.,-' ", J ' , .,( I . /.!I~., ,.,.,,,,.,,. ,,,'-.~ '----, r.". r,.-, -, "~:: ;".-, · i'.., ' I;I(2'"' ,I II . /~;',. ii~"~ ,t II :,-,.'-,,,, ' Lit.', --' . ~;,,. ........... ',~ ,,'.'y' [.']i.:.(:.'~ rj ,',"! ,' I ' , . 'DIVI2i.ON ,. t: C 1[ t'!.J') C..'. ~'; .' Al, I,""l.~".~" ~'~/,: t'~1','.,, I I I,,./l',''' i ['".~-~6 5 i9/'5 ,Uo, C, , , · · · · · : · · · lO .Soob // .'< /¢," ' -3oo~ b DP,]., 5~'ud F_.":: b o' i',.J / 5 DEC'";'"',. . / / .( G- 16 , , · ., · U NJ ON--MA ~FA TH 01.1" ,., G-I'~A · o . · UNION OIL COMPANY. ,OF. CAI..IFORNIA '. ALASKA DISTRICT '' · _. ,. W'ELL ..LOCATION' MAP. -, .u'NiON OI'L 'CQ 'OPEI*.A'I"OR UN,ION TRADING BAY STATE UNIT, G-22 (12--52) DAI'[": Nov. 27,'7;~ ',. i::,. ~':~._~._-[:_~__~=r-j . · ~ , ', CHECK LIST FOR NEW'WELL .PERMITS.' ,' , .: ¢Ompa. ny ~ Vi !'49 vi ,Yes 'No.... . :R'e~ar:ks:......... . ". , ,., ' 'fee attached ~K '".'.:, ' ' 1 Is the permit ' . , ,. .' 2 Is Well to b.e',ocated 'i-n a..:defined..pool ............... ~/~aK, . . .~ :., " ' " 3, .Is a registered s.urve at at a le. d , ..... ......... '.' .... '.:. /~z*OP.~J'~'_~' '.' .. . , , , , 4 Is wel 1 'located proper 'distance from property lin. e '.". ....... ~/~ , , 5' Is well .located Proper distance from other wells ..... ' ..... .6, Is sUfficient undedicated 'acreage a'vail.able in this Pool .... '.. ~ to be deviated' ~/~.~K 7 Is Wel 1 " , , , , , . . . i · · · a · · · · I ~ · · · · · · · I · e · . · · ,, th'e 1 ted'party ' 8, Is operator on 'y affec .......... ' ...... 9 Can permit be a' bef . . · . p. proved ore ten-day wait ,.:, . ,'., ...... . v O. Does operator have a bond. in force .,,. ........ . , . 1. Is a conservation order needed . . . '...' .... , . ~ .... , . . ~K. 2. Is administrative approval needed ............. ' ....... . ~ ~K. ,, 3 IS conductor string provided' . ' ' · . . . i. · · · · ii, ~ · · · e~ · e' · · I · · · 1'4. Is enough cement used to circulate on conductor and surface .... 15, Will cement tie in surface and intermediate or"Production, strings 16. Will cement cover all known productive horizons .......... 17, Wil1 surface casing protect fresh water zones ...... 18. Will all casing give adequate safety in collapse, tension.& burst 19. Does BOPE have sufficient pressure rating ..... ' ........ ¢ ~dditional Requirements: Approval Recommended: Geol og.v Engi nee ri n g: 'TRI~ ~I~U! HWK ~(/~d~ OKG HHH ' JAL ~ ' LCS ~ JCM ~/ -- Revised 1/15/75