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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector C44-14RD (PTD #177079) will lapse on AOGCC MIT-IA Date:Tuesday, January 14, 2025 8:11:24 AM From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Monday, January 13, 2025 5:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com> Subject: NOT OPERABLE: Injector C44-14RD (PTD #177079) will lapse on AOGCC MIT-IA Mr. Wallace, Injector C44-14RD (PTD #177079) is due for its 2-year AOGCC MIT-IA this month per AIO 9.010. The well is currently offline and will not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes and will be added to the quarterly LTSI injector TIO reports. Regards, Daniel Taylor Well Integrity O: 907-777-8319 C: 907-947-8051 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: MIT MGS C44-14RD 1-13-2023 Self Test Date:Tuesday, February 21, 2023 4:34:18 PM From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, February 21, 2023 11:47 AM To: Josh Allely - (C) <Josh.Allely@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Barney Phillips <bphillips@hilcorp.com> Subject: RE: [EXTERNAL] RE: MIT MGS C44-14RD 1-13-2023 Self Test AOGCC waived witness and has accepted the inhouse test as meeting the 4 yr test requirement. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Tuesday, February 21, 2023 11:36 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Barney Phillips <bphillips@hilcorp.com> Subject: FW: [EXTERNAL] RE: MIT MGS C44-14RD 1-13-2023 Self Test Mr Regg We are looking for some clarification on the MIT status of MGS C44-14RD. We requested an AOGCC witnessed MIT after conducting an in-house MIT to verify the well was ready and the annulus was liquid packed. My understanding from the operator coordinating the test is that the witnessed test was waived and a follow-up e-mail from the AOGCC would confirm this. We have not received a follow-up e-mail. Please let us know if a witnessed test is required or if our internal test is sufficient. Additionally, if the AOGCC would like to witness the test when the well is in use, we can coordinate that as well. I will note that that the well is going to be used as a batch disposal well and will likely not reach thermal steady state, which could affect the MIT results. Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Josh Allely - (C) Sent: Monday, January 23, 2023 12:45 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Barney Phillips <bphillips@hilcorp.com> Subject: RE: [EXTERNAL] RE: MIT MGS C44-14RD 1-13-2023 Self Test I do not believe we have such an approval. Based on my records, the 2016 MIT was conducted to allow for disposal of some wellwork fluids. No MIT was performed in 2014 and there is no documentation that there was approval for that MIT to be deferred. My guess is that it was viewed that the MIT was necessary if the well was being actively used as an injector and, if not, then it would be subject to the provisions of Guidance Bulletin 10-02B. Injection wells that are shut in long-term (undetermined when injection will restart) need not be tested until they are ready to recommence injection. In lieu of an MIT for the long term shut-in well, the operator must provide to the AOGCC a quarterly graph of tubing, inner annulus and outer annulus pressures. Josh From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Monday, January 23, 2023 12:03 PM To: Josh Allely - (C) <Josh.Allely@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Barney Phillips <bphillips@hilcorp.com> Subject: [EXTERNAL] RE: MIT MGS C44-14RD 1-13-2023 Self Test MGS C44-14 (PTD 1770790) The last MIT in our records was 8/8/2016 (AOGCC witnessed). According to AIO 9.010, an MIT is required every 2 years (anniversary month is May; beginning May 2012). Does Hilcorp have an approval from AOGCC to defer testing of C44-14RD until being placed on injection? If so, please provide for our records. Jim Regg Supervisor, Inspections) AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Barney Phillips <bphillips@hilcorp.com> Sent: Friday, January 20, 2023 1:32 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: MIT MGS C44-14RD 1-13-2023 Self Test Hello, You may be aware of this well through Hilcorp’s Josh Allely as I have been working with him on it. This well (C44-14RD) is a disposal well that is currently shut in until needed for P&A work. In its static state, we performed a successful “self test” on 1/13/2023. The self test form is attached. I have submitted a request for Inspector for Witness on Tuesday 1/24/2023. Please drop a line or call if you have any questions or need further info. Thanks!!! Barney Phillips bphillips@hilcorp.com 907-394-2454 Mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: MGS C44-14RD (PTD 1770790) Disposal Well Date:Tuesday, February 21, 2023 4:38:01 PM From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Tuesday, February 21, 2023 9:43 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: MGS C44-14RD Disposal Well Hi Chris The lines Ops intends to flush are the platform production headers and they are all 100% within the unit prior to severing. Total volume planned is unknown but there will only be trace oil disposed of as these lines have already been de-inventoried. The purpose of the flushing is to remove any residual hydrocarbons from the lines so that any future fluid contact will pass a sheen test. It is unknown how many circulations that will take. Thank you for the feedback. Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, February 15, 2023 8:56 AM To: Josh Allely - (C) <Josh.Allely@hilcorp.com> Subject: [EXTERNAL] RE: MGS C44-14RD Disposal Well Josh, First we would need to determine which lines we are talking about? If gathering/process lines within the unit prior to severing (metered) from the unit/platform then this is Class II. If transport lines (post meter) (controlled by Hilcorp/Harvest) or pigging waste from said transport lines – then Class I. Exception would be downhole fluids that by normal existing diagrams process/flow/mix together with miscellaneous fluids (eg. Sump, deck drains, slops tanks). A mixture of these would be Class II eligible via the RCRA exempt mixing rule. What total volume is planned and how much oil is planned to be disposed of? Thanks and Regards, th CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7 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: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Thursday, February 9, 2023 12:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: FW: MGS C44-14RD Disposal Well Mr Wallace In regards to the planned utilization of MGS C44-14RD for disposal (authorized via AIO 9), I just want to verify that our plan is consistent with approved Class II disposal. The planned operation is to flush all the surface production lines on Platform MGS C with filtered inlet water (FIW) until they are clean and then dispose of the mixed FIW and downhole fluids down MGS C44-14RD. Based on previous conversations, I believe this is consistent with operations intrinsic to oil and gas production and the resulting mixture is eligible for Class II disposal even though the FIW was not circulated down a well. Please let me know if you concur. Thanks Josh Allely Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 From: Josh Allely - (C) Sent: Friday, January 20, 2023 11:40 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: MGS C44-14RD Disposal Well Mr Wallace Hilcorp intends to perform a state witnessed MIT-IA on well MGS C44-14RD (PTD # 177079) and I wanted to give you a heads up as this well has not been utilized since 2016. MGS C44-14RD is a Class 2 disposal well (AIO 9). The platform has some upcoming work that may require disposal of Class 2 fluids and we would like the well ready for disposal when needed. A few items to note for this well: This well is currently operating under an AA (AIO 9.010) for OA repressurization (AA attached). This is a batch disposal well and its use will be intermittent. The AOGCC witnessed MIT-IA will be with the well SI as our future disposal usage is not known at present. Last MIT-IA was performed on 8/8/16 last injection occurred on 8/12/16. An in-house MIT-IA was performed on 1/13/23 to a required test pressure of 1500 psi and passed. Results attached for your reference. Also attached for your reference is a 90 day TIO plot and schematic. Please let me know if you have any questions. 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MGS C44-14RD Disposal Well Date:Tuesday, February 7, 2023 9:35:29 AM Attachments:MIT MGS C44-14RD MIT - 2023-01-13 In-house.xlsx MGS C44-14RD Schematic 2007-03-02.pdf MGS C44-14RD TIO 90 Day.pdf AIO 9-010 MGS C44-14RD 7-19-12.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Friday, January 20, 2023 11:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: MGS C44-14RD Disposal Well Mr Wallace Hilcorp intends to perform a state witnessed MIT-IA on well MGS C44-14RD (PTD # 177079) and I wanted to give you a heads up as this well has not been utilized since 2016. MGS C44-14RD is a Class 2 disposal well (AIO 9). The platform has some upcoming work that may require disposal of Class 2 fluids and we would like the well ready for disposal when needed. A few items to note for this well: This well is currently operating under an AA (AIO 9.010) for OA repressurization (AA attached). This is a batch disposal well and its use will be intermittent. The AOGCC witnessed MIT-IA will be with the well SI as our future disposal usage is not known at present. Last MIT-IA was performed on 8/8/16 last injection occurred on 8/12/16. An in-house MIT-IA was performed on 1/13/23 to a required test pressure of 1500 psi and passed. Results attached for your reference. Also attached for your reference is a 90 day TIO plot and schematic. Please let me know if you have any questions. Thanks Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 Hikorp Aleeka_, LLC MGS C44-14RD SWD Cook Inlet, Alaska Leg 4, Conductor 31 API No.: 50-133-20252-01 Spud: Cond: 24" @ 370' Surf Csg: 13-3/8" 61# J55 BTC. Set @ 2483'. Cmt'd w/ 2350 sx. Intermediate: 9 5/8" N80 BTC Set @ 6,724'. Cmfd w/122 sx Surf- 4976': 40# 4976-6724' : 43.5# TOC +/- 6570' Longstring: 7" N80 BTC. Set @ 11,398'. Cmt'd w/ 990 sx. Surf- 7989' : 26# 7989 - 11398' : 29# PBTD: 9,730' MD (CIBP @ 10,030'w/ 55 sk. TD: 11,400' (9,399' TVD) Current Completion ALL DEPTHS ARE MD JWG 3-2-07 KB: 35' Water Depth: 73' TBG: 3-'/." 9.3# N80 8rd EUE Duoline-20. Set @ 6,655'. Set 8-15-91 19jts 3-'/2' 9.3# End N80 Duoline 3-1/." Inconel 718 X Nipple (2.313"ID) @ 318' 199 jts 3-'/P 9.3# 8rd N80 Duoline 3-'/" Inconel 718 X Nipple (2.313"ID) @ 6547' 1 it 3-1/." 9.3# 8rd N80 Duoline Baker "CH" Anchor assbly @ 6579' 7" Baker Perm Pkr w/MOE @ 6580' Xover 4-1/." x 3-1/." @ 6590' 1 it 3-'/" 9.3# 8rd N80 Duoline 3-1/." Inconel 718 XN Nipple (2.205"ID) @ 6623' 1 it 3-'/." 9.3# 8rd N80 Duoline WLREG @ 6655' OC calc @ +-5280' qz holes in 7" just below 9-5/8" shoe !15 sx cmt in annulus DK -DM: 7,330-50' @ +-8000' N n O O P y O O ❑� 0.' a N V C O U N C9 Q v 0 0 M N O N H O N O M N n n N O N a 0 0 N +1 O N O N O r ALASKA OIL AND GAS CONSERVATION COMMISSION ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 9.010 Mr. Paul Figel Engineering Manager XTO Energy 200 North Loraine, Suite 800 Midland, TX 79701 SEAN PARNELL, GOVERNOR 333 W. 71h AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: Administrative Approval AIO 009.010 MGS C44-14RD (PTD 1770790) Middle Ground Shoal (MGS) Undefined Waste Disposal Pool Dear Mr. Figel: In accordance with Rule 6 and Rule 9 of Area Injection Order (AIO) 09.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS XTO Energy (XTO) administrative approval to continue Class II injection in well MGS C44-14RD with outer annulus (OA) repressurization. A recent review by AOGCC of the well operating conditions revealed wellhead pressure trend plots confirm that MGS C-44-14RD exhibits OA repressurization. The rate of pressure build-up in the OA is manageable with periodic pressure bleeds. The AOGCC finds that XTO does not intend to perform repairs at this time. A passing AOGCC witnessed mechanical integrity test on May 20, 2012 indicates that MGS C44-14RD exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's approval to continue injection in MGS C44-14RD is conditioned upon the following: 1. XTO shall record wellhead pressures and injection rate daily; 2. XTO shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds are to be flagged on the report; 3. XTO shall submit to the AOGCC by July 1 of each year, an annual report evaluating the performance of the disposal operation. The report shall include data sufficient to characterize the disposal operation, including, among other information, the following: injection and annuli pressures (daily average, maximum and minimum); fluid volumes injected (disposal and clean fluid sweeps); injection rates; an assessment of fracture geometry; a description of any A10 09.010 July 19, 2012 Page 2 of 2 anomalous injection results; and a calculated zone of influence for the injection fluids. 4. XTO shall perform a mechanical integrity test of the inner annulus every two years to the maximum anticipated injection pressure; 5. XTO shall limit the well's OA operating pressure to 500 psi; 6. XTO shall immediately notify the AOGCC if it learns of any improper Class II injection. Complying with the notification requirements of any local, state, or federal agency remains XTO's responsibility; 7. XTO shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC annrnaral chall hr rrnn;rnrl to roctart ;n;nrt;nn• and Chair, Commissioner Commissioner Commissioner As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it rosy file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is Filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t)he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to mn is not included in the period; the last day of the period is included unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m, on the next day that does not fall on a weekend or state holiday. 1 Regg, James B (OGC) From:Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent:Monday, January 23, 2023 12:45 PM To:Regg, James B (OGC) Cc:Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); Barney Phillips Subject:RE: [EXTERNAL] RE: MIT MGS C44-14RD 1-13-2023 Self Test I do not believe we have such an approval. Based on my records, the 2016 MIT was conducted to allow for disposal of some wellwork fluids. No MIT was performed in 2014 and there is no documentation that there was approval for that MIT to be deferred. My guess is that it was viewed that the MIT was necessary if the well was being actively used as an injector and, if not, then it would be subject to the provisions of Guidance Bulletin 10-02B. Injection wells that are shut in long term (undetermined when injection will restart) need not be tested until they are ready to recommence injection. In lieu of an MIT for the long term shut in well, the operator must provide to the AOGCC a quarterly graph of tubing, inner annulus and outer annulus pressures. Josh From:Regg, James B (OGC) <jim.regg@alaska.gov> Sent:Monday, January 23, 2023 12:03 PM To:Josh Allely (C) <Josh.Allely@hilcorp.com> Cc:Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Barney Phillips <bphillips@hilcorp.com> Subject:[EXTERNAL] RE: MIT MGS C44 14RD 1 13 2023 Self Test MGS C44 14 (PTD 1770790) The last MIT in our records was 8/8/2016 (AOGCC witnessed). According to AIO 9.010, an MIT is required every 2 years (anniversary month is May; beginning May 2012). Does Hilcorp have an approval from AOGCC to defer testing of C44 14RD until being placed on injection? If so, please provide for our records. Jim Regg Supervisor, Inspections) AOGCC 333 W. 7 th Ave, Suite 100 Anchorage, AK 99501 907 793 1236 From:Barney Phillips <bphillips@hilcorp.com> Sent:Friday, January 20, 2023 1:32 PM To:Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc:Regg, James B (OGC) <jim.regg@alaska.gov> Subject:MIT MGS C44 14RD 1 13 2023 Self Test CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Hello, You may be aware of this well through Hilcorps Josh Allely as I have been working with him on it. This well (C44 14RD) is a disposal well that is currently shut in until needed for P&A work. In its static state, we performed a successful self teston 1/13/2023. The self test form is attached. I have submitted a request for Inspector for Witness on Tuesday 1/24/2023. Please drop a line or call if you have any questions or need further info. Thanks!!! Barney Phillips bphillips@hilcorp.com 907 394 2454 Mobile 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1770790 Type Inj N Tubing 100 100 100 100 100 100 Type Test P Packer TVD 5654 BBL Pump 0.7 IA 213 1601 1599 1596 1595 1594 Interval O Test psi 1500 BBL Return 1.7 OA 345 448 448 450 450 450 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes:Pre Injection MIT prior to resuming disposal operations. Last MIT performed was in 2016. C44-14RD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Int egr ity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Hilcorp Alaska LLC Middle Ground Shoal Field / C platform None Phillips, Gray, Taylor 01/13/23 Form 10-426 (Revised 01/2017)MIT MGS C44-14RD 1-13-23 Last MIT performed was in 2016. Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8300 Fax: 907-777-8580 June 3, 2022 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2021 Annual Disposal Report for Middle Ground Shoal C44-14RD (AIO 09.010) Dear Mr. Wallace: In accordance with Area Injection Order (“AIO”) 09.010 Rule 3, Hilcorp Alaska, LLC (“Hilcorp”) as Operator of the Middle Ground Shoal field hereby submits for your review the report of injection for well MGS C44-14RD (PTD #177-079) for the year 2021. No fluid was injected into MGS C44-14RD in 2021 and the OA pressure remains below the maximum operating pressure of 500 psi. Should you have questions, please contact Sierra Becia at 529-2160 or Josh Allely at 777-8505. Sincerely, Sierra Becia Reservoir Engineer Date Tubing IA OA OOA 12/31/2021 100 205 355 20 12/30/2021 100 205 352 20 12/29/2021 100 200 350 20 12/28/2021 100 200 340 20 12/27/2021 100 200 340 20 12/26/2021 100 200 340 20 12/25/2021 100 200 340 20 12/24/2021 100 200 340 20 12/23/2021 100 200 340 20 12/22/2021 100 200 340 20 12/21/2021 100 200 345 20 12/20/2021 100 200 340 20 12/19/2021 100 200 340 20 12/18/2021 100 200 345 20 12/17/2021 100 200 345 20 12/16/2021 100 200 345 20 12/15/2021 100 200 344 20 12/14/2021 100 200 345 20 12/13/2021 100 200 345 20 12/12/2021 100 200 345 20 12/11/2021 100 200 345 20 12/10/2021 100 200 345 20 12/9/2021 100 200 345 20 12/8/2021 100 200 345 20 12/7/2021 100 200 345 20 12/6/2021 100 205 348 20 12/5/2021 100 205 345 20 12/4/2021 100 205 345 20 Date Range: 01/01/2021 - 12/31/2021 Well: C44-14RD Desc: Shut-In Permit to drill: 1770790 Admin Approval: AIO 9.010 API: 50-733-20252-01-00 12/3/2021 100 205 350 20 12/2/2021 100 205 348 20 12/1/2021 100 210 345 20 11/30/2021 100 210 345 20 11/29/2021 100 210 345 20 11/28/2021 100 210 345 20 11/27/2021 100 210 345 20 11/26/2021 100 210 347 20 11/25/2021 100 210 349 20 11/24/2021 100 210 347 20 11/23/2021 100 210 347 20 11/22/2021 100 210 348 20 11/21/2021 100 210 347 20 11/20/2021 100 210 345 20 11/19/2021 100 210 345 20 11/18/2021 100 210 345 20 11/17/2021 100 210 346 20 11/16/2021 100 210 345 20 11/15/2021 100 210 345 20 11/14/2021 100 210 347 20 11/13/2021 100 210 348 20 11/12/2021 100 210 348 20 11/11/2021 100 210 348 20 11/10/2021 100 205 348 20 11/9/2021 100 210 345 20 11/8/2021 100 210 345 20 11/7/2021 100 210 345 20 11/6/2021 100 210 345 20 11/5/2021 100 210 345 20 11/4/2021 100 210 345 20 11/3/2021 100 210 350 20 11/2/2021 100 210 350 20 11/1/2021 100 210 350 20 10/31/2021 100 210 350 20 10/30/2021 100 210 350 20 10/29/2021 100 210 348 20 10/28/2021 100 210 348 20 10/27/2021 100 210 348 20 10/26/2021 100 210 348 20 10/25/2021 100 210 350 20 10/24/2021 100 210 355 20 10/23/2021 100 210 355 20 10/22/2021 100 210 355 20 10/21/2021 100 210 353 20 10/20/2021 100 210 353 20 10/19/2021 100 210 353 20 10/18/2021 100 210 353 20 10/17/2021 100 210 352 20 10/16/2021 100 210 352 20 10/15/2021 100 210 350 20 10/14/2021 100 210 348 20 10/13/2021 100 210 355 20 10/12/2021 100 210 355 20 10/11/2021 100 210 355 20 10/10/2021 100 210 355 20 10/9/2021 100 205 355 20 10/8/2021 100 205 350 20 10/7/2021 100 205 349 20 10/6/2021 100 205 345 20 10/5/2021 100 210 350 20 10/4/2021 100 210 350 20 10/3/2021 100 210 350 20 10/2/2021 100 210 350 20 10/1/2021 100 210 350 20 9/30/2021 100 210 350 20 9/29/2021 100 210 350 20 9/28/2021 100 210 350 20 9/27/2021 100 210 350 20 9/26/2021 100 210 350 20 9/25/2021 100 210 340 20 9/24/2021 100 210 340 20 9/23/2021 100 210 340 20 9/22/2021 100 210 340 20 9/21/2021 100 210 342 20 9/20/2021 100 210 343 20 9/19/2021 100 210 343 20 9/18/2021 100 210 343 20 9/17/2021 100 210 342 20 9/16/2021 100 210 342 20 9/15/2021 100 210 341 20 9/14/2021 100 205 345 20 9/13/2021 100 205 345 20 9/12/2021 100 205 345 20 9/11/2021 100 205 345 20 9/10/2021 100 205 345 20 9/9/2021 100 210 345 20 9/8/2021 100 210 343 20 9/7/2021 100 210 345 15 9/6/2021 100 210 345 20 9/5/2021 100 210 345 20 9/4/2021 100 210 345 20 9/3/2021 100 210 345 20 9/2/2021 100 210 345 20 9/1/2021 100 210 345 20 8/31/2021 100 210 345 20 8/30/2021 100 210 345 20 8/29/2021 100 210 340 20 8/28/2021 100 205 343 20 8/27/2021 100 205 342 20 8/26/2021 100 205 342 20 8/25/2021 100 205 342 20 8/24/2021 100 205 342 20 8/23/2021 100 205 340 20 8/22/2021 100 205 340 20 8/21/2021 100 205 340 20 8/20/2021 100 205 340 20 8/19/2021 100 205 340 20 8/18/2021 100 205 340 20 8/17/2021 100 205 340 20 8/16/2021 100 205 340 20 8/15/2021 100 205 343 20 8/14/2021 100 210 342 20 8/13/2021 100 210 342 20 8/12/2021 100 210 340 20 8/11/2021 100 205 340 20 8/10/2021 100 210 342 20 8/9/2021 100 210 341 20 8/8/2021 100 210 340 20 8/7/2021 100 210 342 20 8/6/2021 100 210 343 20 8/5/2021 100 210 342 20 8/4/2021 100 210 342 20 8/3/2021 100 210 340 20 8/2/2021 100 210 340 20 8/1/2021 100 210 340 20 7/31/2021 100 210 340 20 7/30/2021 100 210 338 20 7/29/2021 100 210 338 20 7/28/2021 100 210 338 20 7/27/2021 100 200 340 20 7/26/2021 100 200 340 20 7/25/2021 100 200 340 20 7/24/2021 100 200 340 20 7/23/2021 100 200 340 20 7/22/2021 100 200 340 20 7/21/2021 100 200 346 20 7/20/2021 100 200 336 20 7/19/2021 100 200 336 20 7/18/2021 100 200 336 20 7/17/2021 100 200 337 20 7/16/2021 100 200 335 20 7/15/2021 100 200 335 20 7/14/2021 100 200 335 20 7/13/2021 100 200 335 20 7/12/2021 100 200 335 20 7/11/2021 100 200 335 20 7/10/2021 100 202 333 20 7/9/2021 100 200 332 20 7/8/2021 100 201 333 20 7/7/2021 100 202 333 20 7/6/2021 100 202 333 20 7/5/2021 100 202 333 20 7/4/2021 100 202 331 20 7/3/2021 100 202 331 20 7/2/2021 100 202 331 20 7/1/2021 100 205 331 20 6/30/2021 100 205 331 20 6/29/2021 100 205 331 20 6/28/2021 100 205 326 20 6/27/2021 100 205 326 20 6/26/2021 100 205 326 20 6/25/2021 100 205 327 20 6/24/2021 100 200 330 20 6/23/2021 100 200 330 20 6/22/2021 100 200 330 20 6/21/2021 100 200 330 20 6/20/2021 100 200 330 20 6/19/2021 100 200 330 20 6/18/2021 100 200 329 20 6/17/2021 100 200 328 20 6/16/2021 100 200 328 20 6/15/2021 100 200 330 20 6/14/2021 100 200 330 20 6/13/2021 100 200 327 20 6/12/2021 100 200 327 20 6/11/2021 100 200 327 20 6/10/2021 100 200 327 20 6/9/2021 100 200 327 20 6/8/2021 100 200 327 20 6/7/2021 100 200 327 20 6/6/2021 100 200 328 20 6/5/2021 100 200 328 20 6/4/2021 100 200 328 20 6/3/2021 100 200 328 20 6/2/2021 100 200 328 20 6/1/2021 100 200 328 20 5/31/2021 100 200 327 20 5/30/2021 100 200 327 20 5/29/2021 100 200 325 20 5/28/2021 100 200 325 20 5/27/2021 100 200 326 20 5/26/2021 100 200 327 20 5/25/2021 100 200 325 20 5/24/2021 100 200 327 20 5/23/2021 100 200 325 20 5/22/2021 100 200 325 20 5/21/2021 100 200 325 20 5/20/2021 100 200 325 20 5/19/2021 100 200 322 20 5/18/2021 100 200 325 20 5/17/2021 100 200 325 20 5/16/2021 100 200 325 20 5/15/2021 100 200 325 20 5/14/2021 100 200 325 20 5/13/2021 100 200 325 20 5/12/2021 100 200 325 20 5/11/2021 100 205 325 20 5/10/2021 100 205 325 20 5/9/2021 100 205 325 20 5/8/2021 100 205 324 20 5/7/2021 100 205 324 20 5/6/2021 100 205 325 20 5/5/2021 100 205 325 20 5/4/2021 100 200 322 22 5/3/2021 100 200 325 20 5/2/2021 100 200 326 20 5/1/2021 100 200 326 20 4/30/2021 100 200 326 20 4/29/2021 100 200 326 20 4/28/2021 100 200 326 20 4/27/2021 100 200 325 20 4/26/2021 100 200 325 20 4/25/2021 100 200 325 21 4/24/2021 100 200 325 20 4/23/2021 100 200 325 20 4/22/2021 100 200 325 20 4/21/2021 100 200 325 20 4/20/2021 100 200 325 20 4/19/2021 100 205 325 20 4/18/2021 100 205 326 20 4/17/2021 100 205 325 20 4/16/2021 100 205 325 20 4/15/2021 100 205 325 20 4/14/2021 100 205 326 20 4/13/2021 100 210 327 20 4/12/2021 100 210 330 20 4/11/2021 100 210 330 20 4/10/2021 100 210 328 20 4/9/2021 100 205 327 20 4/8/2021 100 200 325 20 4/7/2021 100 200 325 20 4/6/2021 100 210 327 20 4/5/2021 100 210 330 20 4/4/2021 100 210 330 20 4/3/2021 100 210 330 20 4/2/2021 100 210 330 20 4/1/2021 100 215 340 20 3/31/2021 100 215 340 20 3/30/2021 100 215 340 20 3/29/2021 100 215 340 20 3/28/2021 100 215 340 20 3/27/2021 100 215 340 20 3/26/2021 100 215 340 20 3/25/2021 100 215 340 20 3/24/2021 100 215 340 20 3/23/2021 100 215 340 20 3/22/2021 100 215 337 20 3/21/2021 100 215 337 20 3/20/2021 100 215 337 20 3/19/2021 100 215 337 20 3/18/2021 100 215 338 20 3/17/2021 100 210 339 20 3/16/2021 100 210 340 20 3/15/2021 100 210 340 20 3/14/2021 100 210 340 20 3/13/2021 100 210 340 20 3/12/2021 100 210 339 20 3/11/2021 100 210 338 20 3/10/2021 100 210 340 20 3/9/2021 100 210 339 20 3/8/2021 100 210 339 20 3/7/2021 100 210 339 20 3/6/2021 100 210 340 20 3/5/2021 100 210 335 20 3/4/2021 100 205 335 20 3/3/2021 100 205 338 20 3/2/2021 100 205 338 20 3/1/2021 100 205 338 20 2/28/2021 100 205 340 20 2/27/2021 100 210 338 20 2/26/2021 100 210 337 20 2/25/2021 100 215 337 20 2/24/2021 100 215 335 22 2/23/2021 100 215 332 20 2/22/2021 100 215 337 20 2/21/2021 100 215 332 20 2/20/2021 100 215 336 20 2/19/2021 100 215 338 20 2/18/2021 100 215 341 20 2/17/2021 100 210 340 20 2/16/2021 100 210 336 20 2/15/2021 100 210 337 20 2/14/2021 100 210 336 20 2/13/2021 100 210 336 20 2/12/2021 100 210 336 20 2/11/2021 100 210 335 20 2/10/2021 100 203 335 20 2/9/2021 100 203 336 20 2/8/2021 100 203 336 20 2/7/2021 100 203 335 20 2/6/2021 100 203 337 20 2/5/2021 100 204 339 20 2/4/2021 100 204 340 20 2/3/2021 100 203 338 20 2/2/2021 100 210 335 20 2/1/2021 100 210 336 20 1/31/2021 100 210 337 20 1/30/2021 100 210 337 20 1/29/2021 100 210 337 20 1/28/2021 100 210 335 20 1/27/2021 100 210 337 20 1/26/2021 100 215 337 20 1/25/2021 100 215 338 20 1/24/2021 100 215 338 20 1/23/2021 100 215 338 20 1/22/2021 100 215 337 20 1/21/2021 100 220 336 20 1/20/2021 100 218 338 20 1/19/2021 100 218 340 20 1/18/2021 100 218 340 20 1/17/2021 100 218 340 20 1/16/2021 100 218 340 20 1/15/2021 100 215 340 20 1/14/2021 100 215 338 20 1/13/2021 100 219 339 20 1/12/2021 100 204 340 20 1/11/2021 100 219 339 20 1/10/2021 100 215 340 20 1/9/2021 100 219 340 20 1/8/2021 100 219 340 20 1/7/2021 100 218 340 20 1/6/2021 100 204 339 20 1/5/2021 100 210 335 20 1/4/2021 100 210 335 20 1/3/2021 100 210 335 20 1/2/2021 100 210 335 20 1/1/2021 100 210 335 20 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: JimRegg �e lI f DATE: Thursday,September 08,2016 P.I.Supervisor /¢(I� SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C44-14RD FROM: Johnnie Hill MGS C44-14RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, NON-CONFIDENTIAL Comm Well Name MGS C44-14RDAPI Well Number 50-733-20252-01-00 Inspector Name: Johnnie Hill Permit Number: 177-079-0 Inspection Date: 8/8/2016 Insp Num: mitJWH160818183323 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C44-14RD - Type Inj N' TVD 5654 • Tubing 0 0 - o - o . PTD 1770790 - IType Test SPT Test psi 1500 - IA 50 1600 , 1600 • 1600 - Interval OTHER IP/F P OA 80 90 - 90 90 - i Notes: This well was previously an unwitnessed MIT.Well is a 2yr cycle SCANNED JUN 2 32017 Thursday,September 08,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Wednesday, August 10, 2016 4:27 PM To: Wallace, Chris D (DOA) Subject: FW: MGS C44-14RD disposal availability(PTD# 1770790) Attachments: MIT MGS C44-14RD 07-23-16.xls; Path forward on C44-14RD (AIO 9.010 - PTD# 1770790); MIT MGS C44-14RD 08-08-16.xls Hi Chris Left you a voice mail, but wanted to send this note through also. Just got an e-mail from the C platform that they will be ready to use the C44-14RD well maybe as soon as tomorrow— Thursday. We will most likely be ready to dispose of- 200 bbls of 10.5#CaCl2 from wellbore bore tomorrow. In preparation, we've performed a witnessed MIT this last Monday (see attached). As we discussed on the phone,with the integrity confirmed by pressure tests,AOGCC has agreed that this well is ready to begin disposal operations as needed. Thank you LarryJAN 1 3 201 SCO From: Larry Greenstein Sent: Monday, July 25, 2016 7:53 AM To: Chris Wallace @ AOGCC Subject: MGS C44-14RD disposal availability (PTD# 1770790) Good morning, Chris The C platform folks want to have the C44-14RD well available for disposal now that we've planned some WO and coil tubing work out on their platform. This was the well that got off its two year MIT cycle during the XTO days and without any plans to use it,we left it shut- in. Since it may be needed in the near future, per the attached path forward e-mail (although on a different schedule), we've completed a pre-injection MIT and everything looks good with the well's mechanical integrity. Should the well be used,we will be notifying AOGCC for an inspector to witness an active MIT on the well. As you can imagine with a batch disposal well, it's tough to get an active MIT without some thermal effects depending on batch size and injection duration. To that end,this static MIT does provide clear indication of an intact wellbore for disposal purposes. Let me know if there is anything else you need prior to our returning this well to active status. 1 • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, July 25, 2016 7:53 AM To: Wallace, Chris D (DOA) Subject: MGS C44-14RD disposal availability (PTD# 1770790) Attachments: MIT MGS C44-14RD 07-23-16.xls; Path forward on C44-14RD (AIO 9.010 - PTD # 1770790) Good morning, Chris The C platform folks want to have the C44-14RD well available for disposal now that we've planned some WO and coil tubing work out on their platform. This was the well that got off its two year MIT cycle during the XTO days and without any plans to use it, we left it shut- in. Since it may be needed in the near future, per the attached path forward e-mail (although on a different schedule), we've completed a pre-injection MIT and everything looks good with the well's mechanical integrity. Should the well be used, we will be notifying AOGCC for an inspector to witness an active MIT on the well. As you can imagine with a batch disposal well, it's tough to get an active MIT without some thermal effects depending on batch size and injection duration. To that end, this static MIT does provide clear indication of an intact wellbore for disposal purposes. Let me know if there is anything else you need prior to our returning this well to active status. Thank you Larry SCANNED AUG 1 0 2016 • • � d _ - LAsEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7111 AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 ADMINISTRATIVE APPRO ALFAX (907)276-7542 AREA INJECTION ORDER 9.010 Mr. Paul Figel Engineering Manager XTO Energy SCANNED. 200 North Loraine, Suite 800 Midland, TX 79701 RE: Administrative Approval AIO 009.010 MGS C44-14RD (PTD 1770790) Middle Ground Shoal (MGS)Undefined Waste Disposal Pool Dear Mr. Figel: In accordance with Rule 6 and Rule 9 of Area Injection Order (AIO) 09.000, the Alaska Oil and Gas Conservation Commission (AOGCC)hereby GRANTS XTO Energy (XTO) administrative approval to continue Class II injection in well MGS C44-14RD with outer annulus (OA)repressurization. A recent review by AOGCC of the well operating conditions revealed wellhead pressure trend plots confirm that MGS C-44-14RD exhibits OA repressurization. The rate of pressure build-up in the OA is manageable with periodic pressure bleeds. The AOGCC finds that XTO does not intend to perform repairs at this time. A passing AOGCC witnessed mechanical integrity test on May 20, 2012 indicates that MGS C44-14RD exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's approval to continue injection in MGS C44-14RD is conditioned upon the following: 1. XTO shall record wellhead pressures and injection rate daily; 2. XTO shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds are to be flagged on the report; 3. XTO shall submit to the AOGCC by July 1 of each year, an annual report evaluating the performance of the disposal operation. The report shall include data sufficient to characterize the disposal operation, including, among other information, the following: injection and annuli pressures (daily average, maximum and minimum); fluid volumes injected (disposal and clean fluid sweeps); injection rates; an assessment of fracture geometry; a description of any . • • A10 09.010 July 19,2012 Page 2 oft anomalous injection results; and a calculated zone of influence for the injection fluids. 4. XTO shall perform a mechanical integrity test of the inner annulus every two years to the maximum anticipated injection pressure; 5. XTO shall limit the well's OA operating pressure to 500 psi; 6. XTO shall immediately notify the AOGCC if it learns of any improper Class II injection. Complying with the notification requirements of any local, state, or federal agency remains XTO's responsibility; 7. XTO shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. The MIT anniversary date is May 20,2012. '�'°II'Ma ...47-4i DONE at Anchorage, Alaska and dated July 19, 2012. , ,.. idi `�/7:0N-C I / /� ��.L.1 / 46%..►� r 1_ Cathy '. Foerster Daniel T. Seamount,Jr. Jo . N 1 rman Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration.upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails.OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b)."Mlle questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period:the last day of the period is included.unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p in.on the next day that does not fall on a weekend or state holiday. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re 1 DATE: Tuesday, June 26, 2012 P.I. Sup if ' I Z � ' v SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C44 -14RD FROM: Matt Herrera MGS C44 -14RD Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry i/L-- NON CONFIDENTIAL Comm Well Name MGS C44 - 14RD API Well Number 50 733 - 20252 - 01 - 00 Inspector Name: Matt Herrera Permit Number: 177 - 079 - Inspection Date: 5/20/2012 Insp Num: mitMFH120530200514 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C44-I4RD ; Type Inj N -1TVD 5654 • IA 275 1650 - 1650 1650 - PTD 1770790 Type Test SPT Test psi 1500 OA 1000 _ 1200 , 1250 1250 Interval 4YRTST P/F P - Tubing 0 0 0 0. Notes: XTO contacted about elevated OA pressure (18% of MIYP); XTO provided pressure data 6/13/12 showing OA pressure increases slowly after bleed off & stabilizes at approx. 1050 psi. Well is intermittent injector (disposal) & OA pressure does not appear to be linked to injection; well under evaluation for admin approval. JUL 2 v 20 12 - Tuesday, June 26, 2012 Page 1 of 1 • • Page 1 of 2 Regg, James B (DOA) ~~ ~ ~ ~ ~ From: Regg, James B(DOA) ,~ .~'~ I(~1 Sent: Wednesday, July 15, 2009 2:33 PM ~~~ To: 'Ryan_Tunseth@xtoenergy.com' Cc: DOA AOGCC Prudhoe Bay; Aubert, Winton G(DOA); Schwartz, Guy L(DOA) Subject: RE: XTO OBM Disposal Attachments: MGS_C44-14RD_inj_history_2009-0715.pdf with attachment this time... Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 _ .- a ;~;, ~ v}~ r r~~~ ~~E~'~~; .' ., ~ 4. , ..... E'tw' ~ . w~. From: Regg, James B (DOA) Sent: Wednesday, )uly 15, 2009 2:29 PM To: 'Ryan Tunseth@xtoenergy.com' Cc: DOA AOGCC Prudhoe Bay; Aubert, Winton G(DOA); Schwartz, Guy L(DOA) Subject: RE: XTO OBM Disposal Both are Class II wastes and can be injected down MGS C44-14RD (PTD 1770790); you do not need any special approval from the Commission. Because the well has been used for what appears infrequent batch injections (according to our injection records - see attached), I recommend performing an MIT prior to commencinq in'e~ ction. Please provide notice of MIT for Commission witness. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Ryan Tunseth@xtoenergy.com [mailto:Ryan_Tunseth@xtoenergy.com] Sent: Wednesday, July 15, 2009 9:27 AM To: Regg, ]ames B (DOA) Subject: RE: XTO OBM Disposal used ~ Ryan Tunseth XTO Energy HSE&T Coordinator Office (907) 776-2510 Cell (907) 398-1233 7/15/2009 • • Page 2 of 2 "Regg, James B (DOA)" <jim.regg@alaska.gov> To Ryan_Tu nseth @xtoenergy.com 07/15/2009 0921 AM OBM used or unused? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 cc Subject RE: XTO OBM Disposal From: Ryan Tunseth@xtoenergy.com [mailto:Ryan_Tunseth@xtoenergy.com] Sent: Monday, July 13, 2009 8:38 AM To: Regg, James B (DOA) Subject: XTO OBM Disposal Mr. Regg, Have you given any thought to our proposed disposal of 55,000 gal of OBM down C44-14? Again, we would like to slurry 4,000 gal of diesel with this mud to aid the injection. The plan was to finish a scale squeeze on 43-14 with diesel to clean some paraffin in the tubing ...then use that returned diesel to mix with the OBM. Thanks for your time, Ryan Tunseth XTO Energy HSE&T Coordinator Office (907) 776-2510 Cell (907) 398-1233 7/15/2009 • r'~')~~ ~I07~2~6~ (\ ~ Injection History MGS C44-14RD (PTD 177-079) Manth~ Gas `~ ~ ~ ~' ' Water= ~ ~ ~ ~. '= Da ,`s : - ; dv1IT: ° ;" O 1-May-09: 0' 0 0 _ O1-Apr-09; 0 0 . 0' 01-Mar-09 0! _ 0' 0' O 1-Feb-09 0 0` 0 O1-Jan-09i 0' 0 0: O1-Dec-08 0 6363 7 O1-Nov-08. 0 _ 0` 0 O1-Oct-08 _ . _ 0 0, ~ 01-Sep-08' 0 0 0 . ' ! O1-Aug-08 0 0 _ ~ O1-Ju1-08 0' 0'; 0 O1-Jun-08' _ 0 0 0 O1-May-08 0 1725 3 5/17/2008 ` O1-Apr-08 0 19668 11 O1-Mar-08, 0 0 0 O1-Feb-08 0 0 _ 0' O1-Jan-08 0 0 0 O1-Dec-07 0' 0 0 ' O1-Nov-07 0' : 0' ~ _ O1-Oct-07' 0 _ 0 0 ! 01-Sep-07; _ 0 0 0 _ O1-Aug-07 0 0 _ _ 0 _ O1-Ju1-07' 0! 0 _ __. 0 _. _ .~.~__ .~_ O1-Jun-07 - 0 _ 0 0 _ .. O 1-May-07; 0 0 ~ O1-Apr-07i 0 _ . 0 _ _ _ 0 O1-Mar-07 0' 0 _ _ 0' O1-Feb-07 0 0 . 0 __ , O1-Jan-07... 0 0` ~; Oi-Dec-06' 0 0 0 O1-Nov-06' _ 0! 0 0" _ O1-Oct-06, 0` 0 0 _ O1-Sep-06 0; 0 0 O1-Aug-06 0 0 _ 0 O1-Ju1-06' 0 0, 0 O1-Jun-06 0 0' 0 _ O1-May-06' 0 4216 7 O1-Apr-06; 0 2415 5 O1-Mar-06 0 0 _ 0 O1-Feb-06 _ 0 0 0 O1-Jan-06; 0' 0 0, O1-Dec-05 0! 0' _ 0 ~ _ ~., _ O1-Nov-OS! 0 0 0 _ _ O1-Oct-O5 0' 0 . 0 O1-Sep-O5 _ 0 0 4 , , O1-Aug-O5 0 _ 0' ~` O1-Jul-OS' 0 0! 0 _ O1-Jun-O5 0 0 ~ ~ Page 1 of 5 • • Injection History MGS C44-14RD (PTD 177-079) Mo~t1i ~ _ ~ Ga~ ~ ~ater~ ' ~T?ays ~ 1vIIT ~ ~~ O1-May-OS 0 0 0~ ~ O1-Apr-O5 0' 6846 14 O1-Mar-O5 0' 1726 4, . O1-Feb-O5 0 _ 2496 _ w 8 _ _ . _ Oi-Jan-O5~ _ 0 11445; ~~; , O1-Dec-04 0` 14510: . 22• _ . . O1-Nov-04; 0: _ 5456` _ 12 O1-Oct-04 _ 0 7521 9 _ O1-Sep-04' 0 0 0 O1-Aug-04, _ 0 0 0 O 1-Ju1-04 0 0 0 O1-Jun-04. 0 0. 0! O1-May-04! 0 0 0 O1-Apr-04 0 _ 2971 4 " 01-Mar-04' 0' 0 , 0 _ O1-Feb-04 0 _ 0 0 _ Oi-Jan-04 0 747' 2 O1-Dec-03 0' 0 0' ' _ O1-Nov-03! 0 _ _ 1114 _ 3 11/6/2003! _ _ O1-Oct-03' 0, 0 0' O1-Sep-03 0 _ 0 0 01-Aug-03 0 0 _ 0 O1-Ju1-03 0 6678 10 _ _ _ O1-Jun-03', _ 0 2929 6 O1-May-03 0 0 0 01-Apr-03! 0 _ 0 _ 0 01-Mar-03' 0 0 0 _ _ _ ' 01-Feb-03 0 0 0 O1-Jan-03 0 5765 10 O1-Dec-02' 0' 4980 10 . _ 01-Nov-02 . 0 0 0 O1-Oct-02 0; 0! _ 0 ~ _._... _ O1-Sep-02 , 0 0 0 ` Ol-Aug-02i ~ 0 ~ 1553 4 O1-Ju1-02 0' 10848' _ 18~ _ 01-Jun-02 ;_ _ , _ 0, _ 6594 16 O1-May-02' _ 0 8083 14 O1-Apr-02 0 4055 7 01-Mar-02 0! 4055' 7 .. O1-Feb-02 0 8221` 16 O1-Jan-02 0 3967 10 Ol-Dec-O1' 0 0 0 O1-Nov-O1 0 0 0 O1-Oct-OL, _ _ 0 0 0 O1-Sep-O1 0 0' 0 O1-Aug-O1 0, 0 0 O1-Jul-O1 0' 0 0 O1-Jun-O1' 0' 0,; 0 Page 2 of 5 • Injection History MGS C44-14RD (PTD 177-079) Month Gas! Water ° Days MIT O1-May-O1 0 0 0 O1-Apr-O1 0 3703' S O 1-Mar-O 1 0 0' 0 O1-Feb-O1 0, 0` _ 0 `. O1-Jan-O1 0 0, 0 O1-Dec-00! 0, 0! 0' _ O1-Nov-00 _ 0 0! 0 . O1-Oct-OOi _ _ 0 0; : 0 _ O1-Sep-00 0 _ _ 0 0 O 1-Aug-00 0 _ 0 0 O1-Ju1-00 0 0' 0; _ , O1-Jun-00 0' 0, 0 O1-May-00 0 _ 2200' 3' O1-Apr-00 0 0 0 O1-Mar-00 0 0 0 Ol -Feb-00 0 0' 0 01-Jan-00 0 0 0 01-Dec-99 0 0 0 O1-Nov-99 0` 0' 0: O1-Oct-99 0 0' 0 10/20/1999 O1-Sep-99'_ 0; 0 0 O1-Aug-99 0 1036 3 O1-Ju1-99 0 ` 0 ~' __ O1-Jun-99` ' 0 0 ~ O1-May-99 0` 0 0 O1-Apr-99 0 0 0 _ O 1-Mar-99 0 0 . 0 O1-Feb-99 0! 0' 0 _ O1-Jan-99 0 ~ ~ O1-Dec-98 0 0! 0 O1-Nov-98' 0 0', 0 , _ O1-Oct-98. 0 0 0 O1-Sep-98 0 0 ' 0 O1-Aug-98' 0' 0 0 O1-Ju1-98; 0' 0' 0; O1-Jun-981 0 0 0 ' O1-May-98 0 0 _ 0 _ _ ' O1-Apr-98 , 0, 4 0 ; , O1-Mar-98i 0 0 0 O1-Feb-98 0 _ _ 0 0 _ _ _O1-Jan-98 0 0 0 O1-Dec-97` 0' 0' 0' O 1-Nov-97 0 0' 0 _ O1-Oct-97 0 0 0 Ol-Sep-97 0 0 0 O]-Aug-97 0 0 0 O1-Ju1-97 0 0 0 O1-Jun-97 0 0 0 i Page 3 of 5 ~ Injection History MGS C44-14RD (PTD 177-079) ~ M~rith ;'.° _` Cias ; _ 'Water~ ~ , = Days ~ ~ ~ 1vIIT ` O1-May-97 _ 0 0 0 . O1-Apr-97' 0 0 0', 01-Mar-97 0 0' 0; O 1-Feb-97 0' 0' 0 Ol-Jan-97 0 0 0 01-Dec-96' 0 0' 0 O1-Nov-96 0 0 0 O1-Oct-9bj 0 0 0 O1-Sep-96 0 0 0 O1-Aug-96; 0 _ 0 _ 0 O1-Ju1-96 0 0 0 ' O1-Jun-96 _ _ 0; 0' 0 __ _ O1-May-96; 0, 0 0 ' _ _ O1-Apr-96 . _ _ 0 0 _ 0 _ _ O1-Mar-96 0 0 0 _.., O1-Feb-96 _ 0; 0 . 0 . ! O1-3an-96 0 0" o O1-Dec-95` 0' 0' _ 0 _ _ O1-Nov-95 0 0 0' _ _ O1-Oct-95 0', 0' 0 O1-Sep-95 0 0 ~ O1-Aug-95 0' 0' 0 O1-Ju1-95' 0' _ 0 _ 0 O 1-Jun-95 0' 0, 0. O1-May-95 0 0 0 O1-Apr-95 0' 0 0 O1-Mar-95' 0 _ 0 . ~' . O1-Feb-95 0' 0 O O1-Jan-95 _ 0' 0: ~ O 1-Dec-94 0 0' 0 _ O 1-Nov-94 0' 0 0 ~ __ O1-Oct-94. ... 0: _ ~ 0 0 01-Sep-94; 0 0 0 O1-Aug-94, _ 0 0, 0 O1-Ju1-94` 0 0 . 0 _ O1-Jun-94 0 0, 0 _ O1-May-94 _ 0 - - _ 0 0 O1-Apr-94; 0 0, 0 O1-Mar-94' 0 0 0 _ O1-Feb-94i 0 0 0 O1-Jan-94 0! 0 0 O1-Dec-93' 0 0' 0 : O1-Nov-93! 0 0 0 _ O1-Oct-93 0' 0 ~ O1-Sep-93` 0 . 0 0 _ O1-Aug-93 _ 0 816 2 O1-Ju1-93 0 0! 0' _ _ O1-Jun-93' 0: 0 O C~ Page 4 of 5 ~ ~ Injection History MGS C44-14RD (PTD 177-079) Month Gas'' Water Days ; MIT O 1-May-93 0 0' 0 O1-Apr-93 0 809 2 _ . O1-Mar-93 0 _ 0 0 _ O1-Feb-93 0 0 0 _ .. O1-Jan-93 , _ 0 0 0 ' Ol-Dec-92' 0. 0` _ 0'; _ O1-Nov-92; 0:' 0 . 0 _ O1-Oct-92! _ 0 0 0 O1-Sep-92' 0 0 0 O1-Aug-92 0' 0 0 O1-Ju1-92' 0 0 0 O1-Jun-92 0 0 0 O1-May-92` 0 0 0 O 1-Apr-92 0 1322 2' O1-Mar-92 0 0 _ 0 O1-Feb-92 0', 01 0; . O1-Jan-92 _ _ 0' . 0` 0 01-Dec-91' 0 175' 1 O1-Nov-91 ' 0 0 0 _ O1-Oct-91 0 2100' 8 O1-Sep-91 0 867 5 _ O1-Aug-91; 0 753 1 Page 5 of 5 ~ Regg, James 6 (DOA) From: Ryan_Tunseth@xtoenergy.com Sent: Thursday, July 09, 2009 7:43 AM To: Regg, James B (DOA) Subject: RE: XTO OBM Disposal Sorry Jim, 2 ~~ '~~~~ ~~ • Page 1 of 2 To ciarify ...We want to dispose of the mud down C44-14. ~~_~ `" ~ l I previously sent you an email incorrectly requesting the disposal for A44-11 ...again, my mistake. The request is for disposal of 55,000 gal of OBM with 4,OOOgaI diesel down C44-14. Thank you for your time and I apologize for the errors. Thanks, Ryan Tunseth XTO Energy HSE&T Coordinator Office (907) 776-2510 Ce~l (907) 398-1233 "Regg, James B (DOA)" <jim.regg@alaska.gov> 07/08/2009 04:44 PM ~~ ^~ n r; kx W'E i~~,~ . ~ ~~x~~_~ ~ .". < `~1. L ; ,. +.w.,. ~ ..,. i. . ... To Ryan_Tunseth@xtoenergy.com cc Subject RE: XTO OBM Disposal MGS C43-14 (PTD 1881320) is not a Class II disposal well. No injection is authorized in this well. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Ryan Tunseth@xtoenergy.com [mailto:Ryan Tunseth@xtoenergy.com] Sent: Friday, June 26, 2009 7:33 AM To: Regg, James B (DOA) Subject: XTO OBM Disposal 7/9/2009 • . Page 2 of 2 Mr. Regg, XTO has been storing 55,000 gal of Oil Based Mud for about 4 years now. We have decided to no longer store ~ this mud and we have evaluated our options for disposal. Our best option is to inject the mud down our class II disposal well (43-14). This injection is quoted at costing us around $40K ...to have a third party (Emerald) take the OBM it runs us around $165K. Because this mud has been sitting for so long, it is going to require the use of some diesel (4,000 gal) to soften the mix for disposal. We have came up with an option that we would like your approval and/or ciarification on before we move ahead with this work. We are going to do a scale squeeze on 43-14 around the end of July. We plan on finishing the scale squeeze with ~ around 4000 gal of diesel and letting that sit in the tubing for a few days or so to clean the paraffin in the tubing. Could we then use that diesei to soften the OBM and dispose down the Class II (43-14) ? Please call me at my office if you have any questions. Thank you for your time and assistance on this matter. Ryan Tunseth XTO Energy HSE&T Coordinator Office (907) 776-2510 Cell (907) 398-1233 7/9/2009 MEMORANDUM To: Jim Regg ~ .~ ; _ - P.I. Supervisor l~, ~~c~ ~ Z~ ~ "~'~ FROhI: Lou Grimaldi Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 27, 2008 SUBJECT: Mechanical Integrity Tests XTO ENERGY NC C44-14RD MGS C44-14RD Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~ Comm Well Name: MGS C44-14RD Insp Num: mitLG080518101243 Rel Insp Num: API Well Number: 50-733-20252-01-00 Inspector Name: Lou Grimaldi Permit Number: 177-079-0 / Inspection Date: ~/17~zoos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min 60 Min. _ _- C44-14RD ------- Well ~ T)'pg Inj. ' N ' 'I'~TD -5654 IA 45 1610 ]605 i 1605 _ -- T -- -- _---- v7o~9o ~ -YP ~ sPT p ~6~0 - -~-- -i ---- - _ _ - - _- P T T eTest ~ Test st OA Ito 7so 7~a Aso I----~-- -_- - -- ------ ----_--- ------------------- -- - -- - _. Interval 4YRrsT p~F r ! Tubing I tso t7s ns vs Notes: Good test. ~~~~ MA" ~ 2008 Tuesday, May 27, 2003 Pase 1 of 1 i=~- 0~9 TO ENERGY May 20, 2008 Alaska Oil and Gas Conservation Commission Attn: Ms. Cathy P. Foerster 333 West 7`~ Ave., Suite 100 Anchorage, Alaska 99501 RE: True Vertical Depth of Injection Well Packer Dear Ms. Foerster, - XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) ~~1~VNE1~ JUN (~ ~ 2008 In response to your request dated May 2, 2008, XTO Energy, Inc has reviewed its well files to verify the true vertical depth of all injection packers located in injection wells on Platforms A and C in the Cook Inlet. Two of the fifteen injection well packers have measured depths different than the AOGCC provided records which leads to errors in the TVD. The remaining thirteen wells have measured depths that are consistent with XTO's records, however the associated TVD's are slightly different, generally less that 50 feet. The injection packer depth for C44-14RD (177-079) was incorrectly .reported as 10,015' on the form , 10-404 filed 9/6/1991 by the previous operator. The correct depth for'the packer from daily operations reports is 6,584' MD (5,654' TVD). A mechanical integrity test report from 11/6/2003 shows that the well was tested to the proper pressure. According to AOGCC records the injection packer in the C24A-14 (187-126) is set at 10,336' MD (8,308' TVD). However, daily operations reports and the form 10-404 filed 8/3/2000 indicate that the injection packer was set at 10,585' MD (8,493' TVD). During the most recent MIT, performed 5/11/2004, the annulus was tested to 2310 psi, well above the required minimum pressure of 2123 psi. The TVD's of the injection packers in the remaining thirteen wells have been updated on the attached spreadsheet to reflect XTO's deviation survey data. Please let me know if you have any questions or need more information. Sincerel , G~~~~ Jeff Gasch Production Engineer Cc: Paul Figel Scott Griffith • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 02, 2007 4:26 PM To: 'Barney_Phillips@xtoenergy.com' Subject: RE: MGS SVS Testing -Schedule Request If the well is only to be used during drilling, we will catch the MIT when out for a BOPS test. I believe we receive a monthly rpt for all the MGS A and C injectors that show tbg and csg pressures; that monitoring data is sufficient for demonstrating continued mechanical integrity while well is shut in. ,~y~ Jim Regg „ ~ ~ t f~e~~~`"' AOGCC ~~~ ~~~ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: Barney_PhillipsCxtoenergy.com Sent: Friday, November 02, 2007 3:26 To: Regg, James B (DOA) ~~ [mailto:Barney_PhillipsCxtoenergy.com] PM Cc: Scott_Griffith@xtoenergy.com; Tom_Reese@xtoenergy.com Subject: RE: MGS SVS Testing - Schedule Request Hi Jim, In regards to C44-14, it could be some time from now before this well is injected again and when it is injected it is intermittent. Our next expected date of injecting will be at least a year from now when drilling returns to Platform C. We would be happy to test this well while Chuck is here if that is acceptable. Otherwise, we may run in to a situation where the inspector would need to be here to witness the MIT for this well only during drilling operations when we can inject again. Your comments or recommendations on how to proceed with C44-14 would be greatly appreciated. Best regards, Barney Phillips XTO Energy "Regg, James B (DOA) " <jim.reggCalaska. gov> 10/23/2007 08:35 AM ~~~ Nei ~ 2ao7 k~.._..___._.. Barney_PhillipsCxtoenergy.com Scott Griffith~xtoenergy.com, Tom_Reese@xtoenergy.com To CC Subject RE: MGS SVS Testing - Schedule Request 1 • Thank you for the advance notice. An inspector will contact you about witnessing the SVS tests. MITs for wells C24A-23LN and C44-14RD are due November 6, 2007. Our records indicate C44-14RD is shut in so this one could be delayed unless you are planning to restart injection in the near term. Our preference is to witness an MIT after the well is thermally stable following an extended shut in. An inspector will contact you about witnessing MITs as well. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 ~ phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: Barney_PhillipsCxtoenergy.com [mailto:Barney_Phillips@xtoenergy.com] Sent: Tuesday, October 23, 2007 8:12 AM To: Regg, James B (DOA) Cc: Scott_Griffith@xtoenergy.com; Tom_Reese@xtoenergy.com Subject: MGS SVS Testing - Schedule Request Hi Jim, The SVS Testing for MGS Platform A & C will be due soon. I'd like to offer a couple of sets of dates that work well for us and see if you can provide and Inspector at that time. They are as follows: Thursday 11/29 & Friday 11/30 Monday 12/3 & Tuesday 12/4 Please let us know if either set of these dates will work out for you at your earliest convenience. I leave the platform today at 17:00 for days off. If you need to reach me beyond that time, please feel free to contact me on my cell phone at 394-2454. Best regards, Barney Phillips 907-776-5241 2 ( MEMORANDUM f State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner SUBJECT: Mechanical Integrity Test THRU: Jim Regg ~G~ H(ZIJtL-; XTO P.L Supervisor fr Platform C MGS FROM: Chuck Scheve Petroleum Inspector NON. CONFIDENTIAL DATE: November 6, 2003 Packer Depth Pretest Initial 15 Min. 30 Min. Well C24A-23LN Type Inj. S TVD. 8640 Tubing 4100 4000 4000 4000 Interval I P.T.D. 202-087 Type test P Test psi 2160 Casing 50 2500 2500 2500 P/F P Notes: Well C44-14 Type Inj. N TVD. 5654 Tubing 150 200 200 200 Interval 4 P.T.D. 177-079 Type test P Test psi 1414 Casing 100 1740 1740 1740 P/F P Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.VD. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. 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 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to XTOs platfonn C and witnessed the routine 4 year MIT on well C44-14 and the initial MIT on Well C24A- 23LN. The pretest tubing and casing pressures were observed and found to be stable. The pressure tests were then perfonned with both wells demonstrating good mechanical integrity. M.LT.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 2 hours cc: MIT report form 5/12/00 loG. MIT MGS C 11-6-03 CS.xls 11/21/2003 Re: C44-14RD e e Subject: Re: C44-14RD Date: Thu, 27 Feb 200312:46:21 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Tom Reese <reese@sarcomgs.com> \ ~ '\-0'\ ~ Thanks much Tom. Looks like the well is due an MIT this year. Other Tom Tom Reese wrote: > Tom, . . . OC1 2 8 2005 > I went out to both platforms and researched all the records for C44-14RD.SCJ.\NNED > The original MITwas done on 8-14-91. It was done by drilling. It doesn't > look like we ever > did one by the state right after drilling did the first MIT. I found a > letter that was done by Shell > wanting to know if you would like to witness a MIT on C44-14, but as far as. .. ___---....-r-·.. ..'" > I can tell one was never done. > The next MIT was done on 8-4-95. It was done by Lou Grimaldi. The next MIT > was done on 10-20-99. > It was done by Lou. I have nothing that shows we did anything on 10-23-98. > I will fax all the > imformation that I found to you. > Tom Reese > --- Original Message ----- > From: "Tom Maunder" <tom_maunder@admin.state.ak.us> > To: <reese@sarcomgs.com> > Cc: "Doug Marshall" <dmarshall@sarcomgs.com> > Sent: Wednesday, February 26, 2003 4:56 PM > Subject: C44-14RD > > > Tom, > > Would you please check your records with regard to the MITs performed on > > this well. The records I show (prior to 9/16/02) have MITs 10/23/98 and > > 10/20/99. Do you have any others?? > > Tom Maunder » Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 2/27/20033:05 PM November-2002 C23-23 ACT DATE & NOTES INI INJ ANNU 01 -Nov-2~02 02-Nov-2002 03-Nov-2002 · 04-Nov-2002 05-Nov-2002 06-Nov-2002 07-Nov-2002 08 -Nov-2002 09-Nov-2002 10-Nov-2002 I l-Nov-2002 12-No¥-2002 13-Nov-2002 14-Nov-2002 15-Nov-2002 16-No¥-2002 17-Nov-2002 1 g-Nov-2002 19-Nov-2002 20-Nov-2002 2 I-Nov-2002 22-Nov-2002 23-Nov-2002 24-Nov-2002 25-Nov-2002 26-Nov-2002 27-Nov-2002 28-Nov-2002 29-Nov-2002 30-Nov-2002 TOTAL MAXIMUM AVEP-.AGE # DAYS 12/12/2002 1854 3450 1848 3450 1764 3450 1759 3450 1769 3450 1814 3450 1823 3450 1851 3450 1861 345O 1815 3450 1818 3450 1793 3450 1750 3450 1758 3450 I763 3450 1751 3450 1707 3450 1716 3450 I722 3450 1722 3450 [732 3450 1704 3450 1706 3450 1729 3475 [709 3475 1703 3475 1700 3475 1704 3450 1675 3450 1686 3450 52.706 3,475 1,757 3.453 30 WATER INJECTION REPORT PLATFORM C ACT~ ' ] ACT -- ~qJ ~qJ /LNNU[ INJ INJ ANNU 1 0 50 51~ 398 3475 355( 0 50 51~ 399 35~ 355{ 0 50 51~ 389 35~ 35~ o 5o 51~ 0 50 510 0 50 510 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 56~ 0 50 56G 0 50 56~ 0 50 56C 0 50 56( 0 50 51C 0 50 51C 0 50 51C 0 50 51( 0 50 51( 0 50 51( 0 50 51( 0 70 56( 0 70 56( 0 70 56( 0 70 56( 0 52 53~ 0 388 3450 35~ 386 3450 3500 393 3400 3450 396 3550 3500 402 3550 3500 402 3550 3500 396 3500 3500 394 3500 3500 397 3500 3450 398 3500 3450 66 1350 t350 0 1100 110~ 0 1050 1050 0 1050 1050 0 1000 100~ 0 1000 100~ 0 1000 100~ 440 3500 3475 421 3500 3475 418 3500 345£ 421 3500 3475 397 3500 3475 413 3500 3475 411 3500 3475 409 3450 345( 403 3450 345( 404 3450 345{ 9,341 3.550 3,55C 311 2,928 2,922 24 C34-23 ACT INJ INJ ANN1 587 3450 573 3450 496 3400 498 3400 · 502 3400 533 3400 599 3450 634 3450 597 3450 605 3450 662 3450 667 3450 620 3450 670 3450 566 3450 494 3450 555 3450 583 3450 583 3450 604 3450 634 3500 631 3500 697 3450 682 3500 665 3500 683 3450 673 3475 687 3450 714 3450 715 3450 18,409 3,500 614 3,451 30 C23-26 ACT INJ I~J ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INS I~J ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C4&-14RD ., / C24A-14 AC'Y~ ~ ACT ~qJ INJ ANNU INJ l~J ANIVt. 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 5512 0 0 5512 0 0 5512 0 0 5512 0 0 55C 0 0 55C 0 0 55C 0 0 55£ 0 0 55C 0 0 55C 0 0 55( 0 0 55( 0 0 55( 0 0 55( 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 500 0 0 550 0 0 575 0 0 550 0 369 4450 370 4450 373 4450 442 4550 421 4550 407 4525 416 4550 412 4550 412 4550 405 4560 380 4560 389 4550 407 4550 403 4500 395 4500 400 4500 404 4500 402 4450 387 4450 396 4450 399 4450 394 4450 385 4450 401 4500 381 4500 388 4500 369 4500 357 4450 362 4450 387 4450 11,813 4,560 394 4,497 30 C41-23 shut in due to annular communication problem. WATER INJECTION REPORT PLATFORM September-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ INJ ANNU INJ l~J ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INS ANNU INJ INJ ANNU INJ INJ ANN INJ INJ ANNU 01-5¢ )-2002 02-Se ~-2002 03-Se )-2002 04-Se )-2002 OS-Se )-2002 06-S¢ ~-2002 07-Se )-2002 08-Se )-2802 09-Se )-2002 10-Se )-2002 1 l-Se ~-2002 12-S¢ ~-2OO2 13-Se )-2002 14-Se >2002 15-Se :,-2002 I6-Se >2002 17-S¢ >2002 18-S¢ >2002 19-Se >2002 20-S¢ ~-2002 2[-S{ -2002 22-5~ -2002 23-S~ -2002 24-S~ -2002 25-& -2002 26-S~ -2002 27-S~ -2002 28-S~ ,-2002 29-$1 ,-2002 30-S~ ,-2002 TOTAL MAXIMUM AVERAGE # DAYS 1844 3475 30 1859 3475 35 1861 3500 35 1865 3500 30 1863 3500 30 1864 3500 30 1860 3500 25 0 50 510 0 50 500 0 50 510 0 50 510 0 50 5 lO 0 50 510 0 50 51~ 415 3550 350( 417 3550 350C 417 3550 350~ 415 3550 350( 416 3550 350( 414 3550 350( 415 3500 350( 833 3550 125 880 3550 125 917 3550 13( 909 3550 12! 862 3550 12! 790 3550 12! 783 3500 11( 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 730 600 0 730 600 0 730 600 0 730 600 0 730 600 0 730 600 0 730 600 0 0 55( 0 0 55( 0 0 0 0 55( 0 0 55( 0 0 57.~ 0 0 55( 1861 3500 25 1868 3500 25 1841 3500 25 1853 3500 25 1841 3500 25 1836 3500 23 1850 3500 25 1868 3500 25 1870 3500 27 1845 3500 25 1864 3500 25 1693 3500 25 1768 3450 25 1777 3450 25 1767 3450 25 1765 3450 25 1778 3450 2~ 1778 3450 1798 3450 1804 3450 1827 3475 1674 3450 1429 3450 54,271 3,500 35 1,809 3,481 21 30 0 50 51~ 0 50 51~ 0 50 51~ 0 50 5ltl 0 40 555 0 40 555 0 40 56~ 0 50 56C 0 80 56( 0 60 56C 0 50 56~ 0 50 56( 0 50 56( 0 50 56~ 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 55~ 0 50 55{ 0 50 51( 0 80 56( 0 50 53c. 0 412 3500 350( 413 3500 350( 410 3500 350( 412 3500 350( 408 3500 350( 407 3500 350( 408 3500 350( 406 35OO 352~ 405 350O 350( 399 3500 352~ 400 3500 350( 372 3500 350( 388 3450 345( 131 3450 345( 0 1100 11~ 0 1050 105~ 0 1000 1ooo 173 3500 35® 419 3500 34® 413 3500 3460 417 3550 3475 393 3500 3475 328 3550 3475 10,423 3,550 3,525 347 3,265 3,248 27 773 3500 I 1( 755 35~0 11( 766 3500 11( 774 3500 1 Iff 746 35O0 105 787 3450 105 769 3500 107 826 35OO 102 794 3500 110 688 3500 110 666 35OO 110 626 3500 107 678 3450 103 601 3450 103 697 3450 103 760 3450 103 801 3450 103 597 3450 0 605 3450 25 632 3450 25 660 3475 1 621 3500 600 3500 22.196 3,550 130 740 3,494 100 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 730 600 730 600 730 600 730 600 730 575 730 575 735 575 735 575 735 575 735 575 735 575 735 575 735 575 735 575 735 575 735 575 735 575 735 575 735 60( 735 60( 735 730 60( 730 60( 0 735 60~ 0 733 588 0 0 0 55O 0 550 0 550 0 550 0 550 0 550 0 55O 0 550 0 55O 0 550 0 550 0 550 0 550 0 550 0 55O 0 550 0 550 0 550 0 575 0 550 0 550 0 5OO 0 550 0 575 0 550 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4O0 4450 412 4500 417 4500 430 4525 424 4525 432 4525 415 4500 402 4500 391 4500 402 4500 394 45OO 389 4450 396 4450 391 4450 396 4500 398 4500 408 4500 401 4500 368 4500 391 4500 391 4500 393 45O0 394 4500 394 4500 380 4450 360 4450 360 445O 389 4500 416 4550 342 4525 11,876 4,550 396 4,493 30 10/14/2002 C41-23 shut in due to annular communication problem. C24A-23 shut in for field study and evaluation per Doug Marshall. SCANNED MAR 1 0 2003 I WATER INJECTION REPORT PLATFORM C June-2002 C23-2~3 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT i ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES ' ]NJ ]NJ i ANNU ]NJ ]NJ ANNU ]NJ ]NJ ANNU]NJ ]NJ ANNU]NJ ]NJ ANNU ]NJ l~J ANNU]NJ ]NJ ANNU INJ INJ ANNU ]NJ ]N.~ ANNU 01 -Jun-2002 1770 35,00 0 0 615 371 3450 3450 0 0 0 0 0 0 0 ~40 25( 1,080 1,800 55( 0 0 0 19! 3500 0 02-1un-2002 1776 35~0 0 0 615 373 3450 3450 0 0 0 0 0 0 0 440 25!325 1,800 55( 0 0 0 175 3500 0 03-Jun-2002 1760 35,00 0 0 615 369 3450 3450 0 0 0 0 0 0 0 440 25( 220 1,800 55( 0 0 0 203 3500 0 04-Jun-2002 1764 3450 0 0 615 373 3425 3425 0 : 0 0 0 0 0 0 . 440 25( 0 0 55( 0 0 0 203 3500 0 05-Jun-2002 1376 34~0 0 0 61.~ 291 3425 3425 0 0 0 0 0 0 0 440 25( 0 0 55( 0 0 (~155' 3500 0 06-Jun-2002 I198 34~0 0 0 61.~ 242 3350 3400 0 ] 0 0 0 0 0 0 570 40( 0 0 57~ 0 0 0 141 3500 0 07-Jun-2002 970 34~30 0 0 615219 3350 3400 0 0 0 0 0 0 0 570 40( 0 0 55( 0 0 0 118i 3500 0 08-Jun-2002 6!2 3450 0 0 615 398 3400 3450 0 ~ 0 0 0 0 0 0 590 40( 272 1,900 55( 0 0 0 225,. 3500 0 09-Jun-2002 1416 3450 0 0 61( 291 3400 3450 0 : 0 0 0 0 0 0 600 40( 377 1,800 55( 0 0 0 152 3500 10-Jun-2002 1950 34.50 0 0 61(394 3425 3475 229 3500 0 0 0 (~ 0 600 40( 0 0 55( 0 0 0 2031 3500 ' 0 I l-Jun-2002 1876 3450 0 0 61( 386 3450 3500 410 3500 0 0 0 0 610 45( 0 0 55£ 0 0 0 222', 3500 I2-Jun-2002 1849 3500 0 0 6l£387 3450 3500 370 3500 0 0 0 0 620 45( 372 1,800 55( 0 0 0 205! 3500 13-Jun-2002 1846 3500 (~ 0 0 61( 382 3450 3500 430 3500 0 0 0 0 620 45( 686 1,800 55( 0 0 0 194 3500 14-Jun-2002 1858 3500 C 0 0 61(~ 382 3450 3500 484 3500 0 0 0 0 620 45( 432 1,800 55£ 0 0 0 432' 4100 ~5-Jua-2002 1864 35~0 £ 0 0 61( 384 3450 3500 619 3500 0 0 0 0 620 45( 0 0 55£ 0 0 0 403 4500 16~Jun-2002 1865 3500 (~ 0 0 61£384 3450 3500 634 3500 0 0 0 0 620 45( 393 1,800 55C 0 0 0 457 4500 17-Jun-2002 1877 3500 C 0 0 61£383 3450 3500 636 3500 0 0 0 0 620 45( 0 0 55¢ 0 0 0 438 4500 18-Jun-2002 1895 3500 C 0 0 61(~ 384 3450 3500 625 3500 0 0 0 0 620 45( 386 1,850 55(~ 0 0 0 341 4450 19-.~un-2002 1864 3500 C 0 0 61(~ 380 3450 3500 661 3500 0 0 0 0 620 45( 312 2,100 550 0 0 0 352 4450 20-Jun-2002 1885 3500 (3 0 0 615381 3475 3500 693 3500 0 0 0 0 ~60 50( 0 0 550 0 0 0 347 4450 2 l-Jun-2002 1824 3500 0 0 0 615 374 3475 3500 579 3500 0 0 0 0 665 50( 340 1,900 550 0 0 0 317 4500 22-Jua-2002 1848 35~0 0 0 0 615390 3450 3500 470 3500 0 0 0 0 720 50( 0 0 550 0 0 0 301 4400 23-Jun-2002 1874 3500 (2 0 60 615 386 3500 3500 491 3500 0 0 0 0 670 50( 0 0 550 0 0 0 314 4400 24-Jun-2002 1757 34~0 0 0 60 620 370 3400 3450 388 3425 0 0 0 0 675 50( 354 1,900 550 0 0 0 342 4500 25-Jun-2002 1843 3450 0 0 60 620379 3450 350( 485 3500 0 0 0 0 725 50( 0 0 550 0 0 0 346 4500 26-Jun-2002 1867 3500 0 0 60 615371 3450 350( 568 3500 0 0 0 0 680 50( 332 1,900 575 0 0 0 358 4500 27-Jun-2002 1923 3430 0 0 60 615 373 3500 350( 559 3500 0 0 0 0 680 50( 360 2,000 550 0 0 0 336 4500 28-Jun-2002 1922 3430 0 0 60 615365 3500 350( 557 3500 0 0 0 0 680 50~ 0 0 55(2 0 0 0 0 2800 29-Jun-2002 1916 34~0 0 0 60 615362 3500 350( 524 3500 0 0 0 0 680 50( 0 0 50~ 0 0 0i19 2800 30-Jun-2002 1903 34~0 0 0 60 615359 3500 350( 547 3500 0 0 0 0 680 50( 353 2,000 550 0 0 526 4400 TOTAL 51,948 ~ 0 10,883 10,959 0 0 6,594 0 8,016 MAXIMUM 3,5 0 60 620 3,500 3,50( 3,500 0~ 0 0 725 500 2,100 575 0 4,500 AVERAGE 1,732 3,412 0 0 16 614 363 3,446 3,47~ 365 2,448 0~ 0 0 0 0 607 427 220 998 550 0 0 267 3,925 # DAYS 30 0 30 20 0 0 16 0 29 07/11/2002 C41-23 shut in duc to annular communication problem. C24A-23 shut in for field study and evaluation t~r Doug M~rshall. WATER INJECTION REPORT PLATFORM C October-2002 DATE & NOTES 01 -Oct-2002 02-Oct-2002 03-Oct-2002 04-Oct-2002 05-0ct-2002 06-0ct-2002 07-0ct-2002 08-0ct-2002 09-Oct-2002 10-0ct-2002 11-Oct-2002 12-Oct-2002 13-Oct-2002 14-Oct-2002 15.Oct-2002 16-Oct-2002 17.Oct-2002 18.Oct-2002 19-Oct-2002 20-0ct-2002 21-Oct-2002 22-0ct-2002 23-Oct-2002 24-Oct-2002 25.Oct-2002 26-Oct-2002 27-Oct-2002 28-Oct-2002 29-Oct-2002 30-Oct-2002 31 .Oct-2002 TOTAL MAXIMUM AVERAGE # DAYS C23-23 ACT l~J /NJ 1808 3450 1809 3475 1808 3475 1815 3475 1809 3475 1795 3475 1813 3475 1824 3475 1803 3475 1756 3475 1755 3475 1776 3475 1771 3450 1830 3450 1775 3450 1807 3450 1820 3450 1827 3450 1836 3450 1808 3450 1827 3450 1799 3450 1832 3450 C41-23 ACT INJ I]qJ AN'NE 0 50 51( 0 50 56( 0 50 56( 0 50 56~ 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 C24-23 ACT 411 3500 345{ 408 3525 347.' 405 3525 347.' 404 3525 347.' 395 3525 347.~ 404 3525 347.' 405 3525 347.~ 405 3525 347: 400 3525 347.' 398 3525 347.~ 399 3525 347.' 403 3525 347' 400 3500 350( 410 3500 3500 394 3500 3500 401 3500 35® 402 3500 3500 402 3500 3500 406 3500 3500 400 3500 3500 405 3500 3500 400 3500 3500 405 3500 3500 C34-23 ACT /NJ /NJ ANNU 669 3500 8( 637 3500 6( 617 3500 6( 688 3500 6( 650 3500 6( 628 3500 6( 687 3500 6( 631 3500 6( 629 3500 6( 548 3500 6( 546 3500 6( 579 3500 6( 640 3450 654 3450 574 3450 558 3450 565 3450 491 3450 522 3450 556 3450 584 3450 572 3450 546 3450 C23-26 ACT /NJ /NJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT /NJ /NJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C44-14RD ACT /NJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ 0 0 55~ 0 0 55~ 0 0 55~ 1802 3460 1812 3460 1708 3460 1874 3450 1784 3475 1810 3460 1846 3460 1851 3450 55,990 3,475 1,806 3,461 31 0 80 520 0 80 510 0 80 510 0 50 510 0 50 515 0 50 510 0 50 510 0 50 510 0 80 560 0 53 546 0 402 3500 3475 407 3500 3475 389 3500 3475 410 3500 3500 389 3500 3450 390 3500 3475 397 3500 3475 397 3500 3500 12,443 3,525 3,500 401 3,509 3,484 31 551 3500 595 3500 543 3450 628 3475 699 3450 579 3500 615 3475 630 3450 18,611 3,500 80 600 3,476 24 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 55~ 0 0 55~ 0 0 575 0 0 55{~ 0 0 55~ 0 0 50~ 0 0 55~ 0 0 50~ 0 0 575 0 0 548 0 11112/2002 C41-23 shut in due to annular communication problem. C24A-14 ACT /NJ /NJ ANNU 410 4500 192 3500 337 4500 428 4500 413 4500 397 4500 417 4500 402 4500 403 4500 425 4500 413 4500 381 4500 379 4500 405 4500 ~07 4575 387 4575 412 4550 412 4550 419 4550 415 4550 412 4550 410 4550 437 4550 4O9 46~ 418 4600 388 4500 405 4500 373 4500 382 4500 393 4500 394 4450 12,275 4,600 396 4,489 31 SCANNED EAR I 0 2003 WATER INJECTION REPORT PLATFORM C August-2002 C23-23 C41-23 C24-23 C34-23 ACT ACT ACT ACT DATE & NOTES [NJ IN/ ANNU [NJ [NJ ANNI INJ INJ ANNU INJ INJ ANNU 01 -Aug-2002 02-Aug-2002 03-Aug-2002 04-Aug-2002 05-Aug-2002 06-Aug-2002 07-Aug-2002 08-Aug-2002 09-Aug-2002 10-Aug-2002 11-Aug-2002 l 2-Aug-2002 13-Aug-2002 14-Aug-2002 15-Aug-2002 16-Aug-2002 17-Aug-2002 18-Aug-2002 I9-Aug-2002 20-Aug-2002 21-Aug-2002 22-Aug-2002 23-Aug-2002 24-Aug-2002 25-Aug-2002 26-Aug-2002 27-Aug-2002 28-Aug-2002 29-Aug-2002 30-Aug-2002 3 I-Au~-2002 TOTAL MAXIMUM AVERAGE #DAYS 09/16~-002 965 2500 62 1985 3500 22 1919 3500 30 1897 3500 30 1865 3500 32 1850 3500 35 1880 3500 28 1871 350O 28 1867 3500 28 1863 3500 28 1826 3500 28 1852 3500 28 1867 3500 28 1852 3500 28 1870 3500 13 1854 3475 12 1812 3500 15 1808 3475 40 1763 3500 45 1786 3450 40 1810 3450 37 1817 3475 36 181l 3475 36 1764 3475 36 1782 3475 36 1785 3450 1787 3450 1734 3475 1528 3475 1793 3475 1830 3475 55,693 3,500 1,797 3,453 31 0 80 550 0 70 550 0 70 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 60 550 0 80 560 0 60 555 0 80 560 0 70 560 0 50 555 0 50 555 0 50 555 0 50 555 0 50 555 0 50 555 0 5O 555 0 50 555 0 50 555 0 50 555 0 50 555 0 50 505 0 50 510 0 80 56( 0 59 55( 0 198 1250 1250 408 3500 3500 4O5 350O 3525 404 3500 3550 400 3500 3500 298 3500 3550 0 0 0 0 0 0 0 0 0 0 32 3500 95( 303 3500 312~ 326 3500 315( 390 3500 350( 391 3500 350( 390 3500 350( 340 3500 350( 0 0 350( 0 0 350( 198 3500 100( 265 3475 347~ 145 3500 335( 363 3500 335{ 417 3550 350( 417 3550 350( 6,090 3,550 3,55C 196 2,075 2,465 19 481 1950 860 3500 959 3500 927 3500 855 3500 865 3500 0 1150 862 3500 0 1150 840 3500 0 1150 809 3500 0 1150 670 3500 0 1150 592 350O 0 1150 573 3500 0 1150 614 3500 0 1150 660 3500 0 975! 660 3500 0 95( 640 3500 622 3500 870 3450 793 3450 754 3450 804 3400 875 3475 835 3475 593 3475 625 3475 682 3450 864 3450 852 3450 724 3450 770 3550 848 3550 23,378 3,550 754 3,435 31 C23-26 ACT INJ [NJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41~26 ACT tNI l~J ANNU 0 720 55{ 0 720 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 ' 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 725 575 0 730 575 0 730 600 0 730 600 0 725 575 0 C44-14RD ACT INJ INJ ANNU 454 2,050 550 409 2,200 550 0 0 550 390 1,950 550 0 0 550 300 1,800 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 500 0 0 550 0 0 55{ 1,553 2,2OO 57.' 50 258 55( 4 C24A-23 ACT ]NJ INJ ARNI 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C24A-14 ACT INI INJ ANNI 470 4450 503 46OO 485 4600 463 4650 471 4700 449 4700 432 4650 350 4650 407 4650 406 4450 392 4450 410 4450 411 4450 418 4450 420 4500 402 4500 411 4500 413 4500 380 4500 389 4400 384 4400 390 4400 384 4400 391 4400 421 4400 4O7 44OO 372 4500 380 ~500 385 4400 399 4450 12,796 4,700 413 4,498 31 E41-23 shut in due to annular communication problem. E24A-23 shut in for field study and evaluation per Doug Marshall. $C;ANNED )I/IAR i 0 2003 January-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 ~i{~i~i~i~i~i~i{ii{iiii{~i~i{{{~ AC~ AC? AC~ AC~ AC~ AOX ^C~ AC~ !ili~i~iiiiii!il INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU 01oJan-99 1357 3200 3125 978 700 660 386 3500 3500 1841 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 02-Jan-99 1340 3200 3125 967 700 660 383 3500 3500 1811 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 03-Jan-99 300 3200 3125 368 700 660 85 3500 3500 487 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 04-Jan-99 0 3200 3125 0 700 660 0 3500 3500 0 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 05-Jan-99 0 2000 2000 0 575 575 0 1600 1600 0 1275 0 0 0 0 0 0 400 0 0 550 0 1050 80 06-Jan-99 0 2000 2000 0 575 575 0 1600 1600 0 1275 0 0 0 0 0 0 400 0 0 550 0 1025 80 07-Jan-99 1220 3100 30001 677 700 630 347 3500 3500 1533 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 08-Jan-99 1431 3100 3000! 915 700 630 411 3500 3500 1888 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 09-Jan-99 1352 3100 30001 907 700 630 339 3500 3500 1845 3500 0 0 0 0 0 0 400 0 0 550: 0 3500 0 10-Jan-99 1300 3150 3050 896 700 640 407 3500 3500 1799 3500 0 0 0 0 0 0 400 0 0 550: 0 3500 0 Il-Jan-99 1351 3150 30501 511 700 640 386 3500 3500 1825 3500 0 0 0 0 0 0 400 0 0 550 0 1800 0 · '2-Jan-99 1332 3150 30501 744 700 640 438 3500 3500 1826 3500 0 0 0 0 0 0 400 0 0 550 0 1050 0 Jan-99 1327 3200 3100i 755 700 640 426 3500 3500 1824 3500 0 0 0 0 0 0 400 0 0 550~ 0 35OO 0 ..-Jan-99 1325 3200 3100i 751 700 640 80 3500 3500 1832 3500 0 0 0 0 0 0 40¢ 0 0 5501 0 3500 0 15~an-99 1334 3200 3100! 752 700 640 0 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 16~an-99 1334 3200 3100! 754 700 640 45 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 2050 0 17-Jan-99 1337 3200 310C 754 700 640 417 3500 3500 1858 3500 0 0 0 0 0 0 400 0 0 550 0 1750 0 18~an-99 1329 3200 31001 753 700 640 432 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 1750 0 19-Jan-99 1329 3200 3100! 756 700 640 415 3500 3500 1863 3500 0 0 0 0 0 0 400 0 0 550 0 1300 0 20-Jan-99 1339 3200 310C 755 700 640 419 3500 3500 1886 3500 0 0 0 0 0 0 400 0 0 550 408 3500 0 21~an-99 1341 3200 310~ 757 700 640 421 3500 3500 1903 3500 0 0 0 0 0 0 400 0 0 550 156 3500 0 22-Jan-99 1348 3200 315~ 759 700 630 419 3500 3500 1897 3500 0 0 0 0 0 0 400 0 0 550 57 3500 0 23-Jan-99 279 2200 2400! 254 650 590 92 1700 1725 409 1000 0 0 0 0 0 0 400 0 0 550 0 1825 35 24-Jan-99 0 2150 2400i 0 650 590 0 1700 1725 0 1000 0 0 0 0 0 0 40O 0 0 550 0 1500 35 25~an-99 0 2150 205~ 0 650 590 0 1600 1600 0 1000 0 0 0 0 0 0 400 0 0 550 0 1500 85 26-Jan-99 829 3200 205~ 392 700 590 245 3500 1600 1222 3500 0 0 0 0 0 0 400 0 0 550 0 1100 85 27-Jan-99 1345 3200 3110i 732 700 630 405 3500 3500 2125 3500 0 0 0 0 0 0 400 0 0 550 206 3500 0 28-Jan-99 1319 3200 31101 754 700 630 404 3500 3500 2141 3500 0 0 0 0 0 0 400 0 0 550 300 3500 0 29~an-99 1296 3200 311C 758 700 630 403 3500 3500 2121 3500 0 0 0 0 0 0 400 0 0 550 122 3500 0: 30-Jan-99 1281 3200 31101 750 700 630 400 3500 3500 2117 3500 0 0 0 0 0 0 400 0 0 550 25 3500 0i 31-Jan-99 1241 3200 311C 744 700 630 394 3500 3500 2071 3500 0 0 0 0 0 0 400 0 0 550 0 1625 0i TOTAL 31,916 18,893 8,599 45,692 0 0 0 1,274 MAXIMUM 3,200 3,150 700 660 3,500 3,500 3,500 0 0 0 0 400 0 550 3,500 85 ~RAGE 1,030 3,008 2,908 609 687 629 277 3,200 3,140 1,474 3,115 0 0 0 0 0 0 400 0 0 550 41 2,359 23 DAYS 26 26 25 26 0 0 0 7 'o2/10/99 All injecto~ down January 4, 5 & 6 due to waterflood turbine annual m~ntenance. Ail injectors down January 24 & 25 due to waterflood turbine annu~ m~ntenance. ~} ~ ,cC i'V D Anchorage WATER INJECTION REPORT PLATFORM C January-2002 C23-23 ACT INJ INJ ANNU )ATE&NOTES 01 -Jan-2002 02-Jan-2002 03-Jan-2002 04-Jan-2002 05-Jan-2002 06-Jan-2002 07-Jan-2002 08-Jan-2002 09-Jan-2002 10-Jan-2002 1 l-Jan-2002 12-Jan-2002 13-Jan-2002 14-Jan-2002 15-Jan-2002 16-$an-2002 17-Jan-2002 18-Jan-2002 19-Jan-2002 20-Jan-2002 2 l-Jan-2002 22-Jan-2002 23-Jan-2002 24-Jan-2002 25-Jan-2002 26-Jan-2002 27-Jan-2002 28-Jan-2002 29-Jan-2002 30-Jan-2002 31 -Jan-2002 TOTAL MAXIMUM AVERAGE # DAYS 02/11/2002 2025 3450 1977 3450 2010 3450 275 3450 2219 3400 2006 3400 2045 3450 2039 3450 1978 3450 1999 3425 2028 3425 2027 3425 1964 3425 1926 3400 1941 3400 1962 3400 1982 3400 1320 3400 1991 3425 1966 3425 1897 3425 1949 3425 1864 3425 1928 3425 1944 3425 1907 3425 1926 3425 1924 3425 1930 3425 1898 3425 1884 3450 58,771 3,450 1,896 3,426 31 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INS INJ ANNL INJ INJ ANNL 1800 20 1800 20 1800 20 1800 20 570 570 570 570 570 570 570 570 570 57O 570 570 570 570 570 570 570 57~ 570 57~ 570 57C 570 57C 570 57£ 570 57( 570 57( 570 57( 570 57{ 575 575' 580 580 580 580 580 580 580 580 580 580 580 580 580 580 580 580 580 580 1,800 580 732 502 383 3450 345C 330 3450 345~ 0 3450 345£ 0 3450 345C 0 1150 115£ 0 1150 115£ 0 1150 115£ 85 !150 115( 364 1150 115( 359 3300 330( 309 3300 330( 232 3300 330( 231 3300 3300 265 2800 28O0 351 2800 2800 350 3275 3250 352 3275 3250 228 3275 3250 354 3275 3250 350 3300 3275 1578 3100 305( 1558 3100 305( 1597 3100 305( 212 3100 305( 1643 3050 300( 1585 3050 300( 1591 3100 3050 1597 3100 3050 1563 3100 3050 1574 3100 3050 1598 3100 3050 1595 3100 3050 1559 3100 3050 1546 3100 3025 1557 3100 3025 1564 3100 3025 1573 3100 3025 986 3100 3025 1589 3100 3025 1577 3075 3025 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 700 600 0 700 600 0 700 600 0 700 60C 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 6251 0 800 625 0 800 625 0 800 625 0 0 795 625 0 0 795 625 0 790 625 0 790 650 0 0 550 0 0 550 0 0 550 0 0 550 958 1,800 550 0 0 575 0 0 550 0 0 550 0 0 550 380 1,300 550 0 0 550 0 0 550 350 1,300 550 0 0 55~ 360 1,200 55~ 0 0 55C 390 1,550 55£ 0 0 55( 0 0 550 356 1,800 550 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 6013 0 0 600 0 0 600 0 0 60C 0 0 60( 0 0 60( 343 3300 3275 348 3275 3275 341 3275 3275 349 3275 3275 351 3275 3275 347 3275 3275 351 3275 3275 349 3275 3275 349 3275 3275 346 3275 327~ 395 3425 3425 8,412 3,450 3,45£ 271 2,934 2,929: 26 1529 3075 3025 1566 3075 3025 1529 3075 3025 1551 3075 3025 1563 3075 3025 1533 3075 3025 1559 3075 30251 1556 3075 30251 1558 3075 3025 1537 3075 3025 1511 3100 3025 46,634 3,100 3,050 1,504 3,088 3,032 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 790 .650 0 790 650 0 790 65fl 0 790 65~ 0 790 65C 0 790 65£ 0 790 65C 0 790 65( 0 790 65( 0 790 65( 0 850 65( 0 850 65C 0 785 631 0 0 0 550 0 0 550 330 1,500 550 0 0 550 309 1,400 550 0 0 575 0 0 550 210 1,300 550 0 0 560 324 1,300 570 0 0 550 3,967 1,800 575 128 466 553 I0 0 0 60( 0 0 60( 0 0 60( 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 2750 0 2750 0 2750 0 2750 0 2000 0 2000 0 1700 140 1600 306 1600 268 3450 258 3450 252 3450 235 3450 229 3500 234 3500 284 3500 498 4470 456 4470 433 4550 419 4550 410 4550 413 4550 376 4550 368 4550 252 3100 31 4100 449 4100 306 4100 392 4100 370 4100 352 4400 7,731 4,550 249 3,498 24 1-23 shut in due to annular communication problem. ~,-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. 4A-23 shut in for field study and evaluation per Doug Marshall. , , , December-2001 DATE & NOTES 0 l-Dec-2001 02-Dec-2001 03-Dec~2001 04-Dec-2001 05-Dec-200 I 06-Dec-2001 07-Dec-200 I 08-De¢-2001 C23-23 ACT ]NJ INJ ANNU 2070 3425 2054 3425 2057 3425 2053 3425 2032 3425 2067 3425 2051 3425 2055 3425 WATER INJECTION REPORT PLATFORM C C41-23 ACT INJ ]NJ ANN1 0 565 565 0 565 565 0 565 565 0 565 565 0 565 565 0 565 0 565 5651 0 565 5651 C24-23 ACT ]NJ ]NJ ANNU 370 3450 3450 368 3450 3450 369 3450 3450 369 3450 3450 366 3450 3450 373 3450 3450 371 3450 3450 371 3450 3450 ,,, C34-23 ACT ]NJ ]NJ ANNU 1538 3100 3050 1533 3100 3050 1538 3100 3050 1537 3100 3050 1526 3100 3050 1549 3100 305~ 1545 3100 305~ 1550 3100 305~ C23-26 ACT ]NJ ]NJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT ]NJ ]NJ ANNU 760 60( 760 600 760 600 760 600 760 600 750 600 750 600 750 600 09-Dec-2001 10-Dec-2001 1 l-Dec-2001 12-Dec-2001 13-Dec-2001 14-Dec-2001 15-Dec-2001 16-Dec-2001 17-Dec-2001 18-Dec-2001 19-Dec-2001 20-Dec-200 I 21 -Dec-2001 22-Dec-2001 23-Dec-2001 2044 3425 2042 3440 2064 3440 1998 3450 266 3450 2323 3450 2103 3400 2092 3400 2120 3400 2097 3400 2091 3450 2067 3450 2072 3450 2046 3450 2073 3450 565 565' 550 570 550 570 550 570 550 570 550 570 55O 57O 550 570 550 570 550 570 550 57~ 20 2£ 1300 2C 1800 2C 950 2( 367 3450 3450 371 3450 3450 376 3450 3450 369 3450 345£ 62 1300 135£ 403 3500 350( 378 3450 345( 382 3450 345( 388 3450 345( 387 3450 3450 384 3450 3450 381 3450 3450 380 3450 3450 375 3450 3450 382 3450 3450 24-Dec-200 I 25-Dec-2001 26-Dec-2001 27-Dec-200 ! 28-Dec-2001 29-Dec-2001 30-Dec-2001 31 -Dec-2001 TOTAL MAXIMUM AVERAGE #DAYS 2059 3450 2027 3450 2076 3450 2049 3450 2058 3450 2038 3450 1922 3450 1837 3450 62,003 3,450 2,000 3,436 31 500 2( 379 3450 3450 650 2( 370 3450 3450 1800 2( 381 3450 3450 1800 2( 377 3450 3450 1800 20 378 3450 345C 1800 20 374 3450 345£ 1800 20 355 3450 345C 1800 20 362 3450 345C 11,318 1,800 570 3,500 3,500 858 356 365 3,382 3,384 31 01/15/2002 1546 3100 3050 1548 3100 3050 1568 3100 3050 1543 3100 305( 203 1550 1525 1651 3100 305( 1590 3100 305( 1582 3100 3050 1601 3100 3050 1593 3100 3050 1594 3100 3050 1583 3100 3050 1586 3100 3050 1570 3100 3050 1590 3100 305~ 1581 3100 3050 1558 3100 3050 1596 3100 305~ 1573 3100 305{3 1576 3100 305( 1565 3100 305( 1483 3100 305( 1437 3100 305( 47,033 3,100 3,05{3 1,517 3,050 3,001 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 750 600 770 60O 770 600 770 60{3 770 60~ 770 60~ 770 60( 770 60( 770 60( 770 60( 780 60( 785 60( 790 600 785 600 785 600 765 600 780 600 700 600 700 600 700 60~ 700 60{3 700 60~ 700 60~ 790 600 755 60{3 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received f~om Mr. Wondzell on 12/14/99. 224A-23 shut in for field study and evaluation per Doug Marshall. C44-14RD ACT ]NJ ]NJ ANNU 0 0 550 0 0 550 0 0 55{3 0 0 550 0 0 55C 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55{3 0 0 550 0 0 55{3 0 0 550: 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 575 0 0 553 0 C24A-23 C24A- 14 ACT ACT ]NJ ]NJ ANNU ]NJ INJ ANNL 0 0 600 0 0 60~ 0 0 60~ 0 0 6~ 0 0 60~ 0 0 595 0 0 595 0 . 0 595 0 0 595 0 0 60( 0 0 60( 0 0 60( 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 59~' 0 0 595 0 0 595: 0 0 595 0 0 600 0 0 596 0 318 4600 326 4600 323 4600 322 4600 319 4600 319 4450 323 4450 317 4450 266 45O0 370 4600 319 4550 0 3000 0 2600 349 425O 392 45OO 372 4525 359 4525 248 4525 377 4550 351 4600 322 4600 305 4600 297 4600 310 4500 319 4500 324 4500 320 4500 312 4500 309 4500 304 4500 234 4500 9,326 4,600 301 4,415 29 C23-23 WATER INJECTION REPORT PLATFORM C November-2001 C41-23 C24-23 C34-23 C23-26 ACT ACT ACT ACT ACT DATE & NOTES INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU ][NJ INJ ANNU 0 I-Nov-2001 02-Nov-2001 03-Nov-2001 04-Nov-2001 05-Nov-200 1 06-Nov-200 1 07-Nov-2001 08-Nov-2001 09-Nov-2001 10-Nov-2001 1 l-Nov-200 1 12-Nov-2001 13-Nov-2001 14-Nov-2001 1 S-Nov-2001 16-Nov-200 1 17-Nov-2001 18-Nov-200 1 19-Nov-2001 20-Nov-2001 2 l-Nov-2001 22-Nov-2001 23-Nov-2001 24-Nov-2001 25-Nov-2001 26-Nov-2001 27-Nov-200 1 28-Nov-2001 29-Nov-2001 30-Nov-2001 TOTAL MAXIMUM AVERAGE #DAYS 2004 3450 2032 3450 2019 3450 2022 3450 2029 3450 2014 3450 2010 3450 2028 3450 2012 3450 2035 3450 2079 3450 2075 3450 2114 3450 2093 3450 2104 3450 2117 3450 2098 3450 12/12/2001 0 555 555 0 555 555 0 555 555 0 555 555 0 555 555 0 555 555 0 555 555 0 555 555 0 550 56C 0 550 56C 0 550 56£ 0 560 565 0 560 565 0 560 565 0 560 56~ 0 560 56~ 0 560 56~ 371 3450 345( 377 3450 345{ 375 3450 345( 374 3450 3450i 374 3450 3450 374 3450 3450 370 3450 3450 373 3450 3450 365 3450 3450 365 3450 3450 370 3450 3450 366 3450 3450 372 3450 3450 365 345O 3450 366 3450 3450 370 3450 3450 365 3450 3450 1508 3100 3060 1523 3100 3060 1516 3100 3060 1522 3100 3060 1524 3100 3060 1516 3100 3060 1511 3100 3060 1526 3100 3060 1511 3100 3050 1510 3100 3050 1532 3100 3050 1527 3100 3050 1543 3100 3050 1528 3100 3050 1532 3100 3050 1541 3100 3050 1527 3100 3050 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2096 3450 2102 3450 2100 3450 2081 3450 2103 3450 2115 3450 2129 3450 2142 3450 2116 3450 2034 3450 2096 3425 2069 3425 2067 3425 62,135 3,450 2,071 3,448 30 0 560 565! 0 560 565 0 560 565 0 560 565 0 565 565 0 565 565 0 565 565 0 565 565 0 570 570 0 570 570 0 565 565 0 565 565 0 565 - 565 0 0 570 570 0 0 560 562 0 369 3450 3450 367 3450 3450 367 3450 345O 362 3450 3450 366 3450 3450 369 3450 345~ 369 3450 345C 370 3450 345£ 367 3450 345£ 364 3450 345( 373 3450 345£ 368 3450 345£ 369 3450 345( 11,072 3,450 3,45C 369 3,450 3,45~ 30 1533 3100 305~ 1531 3100 305~ 1523 3100 305~ 1515 3100 305~ 1529 3100 306C 1533 3100 306C 1541 3100 306C 1549 3100 306£ 1532 3100 306( 1501 3100 306( 1547 3100 305( 1532 3100 305( 1537 3100 305£ 45,800 3,100 3,06~2 1,527 3,100 3,055 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNI 0 745 59( 0 745 59f 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 745 59{ 0 750 60( 0 750 60{ 0 750 600 0 750 600 0~ 0 750 600 0 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 60(] 0 760 60(1 0 760 60~ 0 760 600 0 752 597 0 0 0 55(] 0 0 550 0 0 550 0 0 550 0 0 55~3 0 0 575 0 0 550 0 0 55~ 0 0 55¢ 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55£ 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 60~ 0 0 600 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 600 0 0 60~ 0 0 60~ 0 0 0 0 60~ 0 0 60( 0 0 60( 0 0 60( 0 0 60( 0 0 60( 0 0 60( 0 0 60{ 0 0 60( 0 0 60( 0 0 60( 0 0 60{ o o 600! 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 575 0 0 553 0 0 0 600 0 0 600 0 337 4500 335 4500 337 4500 343 4500 341 4500 334 4500 320 4500 313 4500 301 4450 307 4450 309 4450 305 4425 306 4425 292 4425 292 4400 301 4400 297 4400 308 4400 310 4400 310 4400 308 4450 310 4475 309 4475 310 4475 309 4475 301 4450 273 4450 339 4600 324 4600 321 4600 9,402 4,600 313 4,469 30 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received fi.om Mr. Wondzell on 12/14/99. 224A-23 shut in for field study and evaluation per Doug Marshall. October-2001 0 l-Oct-2001 02-0ct-2001 03-0ct-2001 04-0ct-2001 05-0ct-2001 06-0ct-2001 07-0ct-2001 08-0ct-2001 09-0ct-2001 10-Oct-200 ! I l-Oct-2001 12-Oct-2001 13-Oct-2001 14-O¢t-2001 ! 5-Oct-2001 16-Oct-2001 17-Oct-2001 18-Oct-2001 19-Oct-2001 20-Oct-2001 21 -Oct-2001 22-Oct-2001 23-Oct-2001 24-Oct-2001 25-Oct-2001 26-Oct-2001 27-Oct-2001 28-Oct-2001 29-Oct-2001 30-Oct-2001 31 -Oct-2001 TOTAL MAXIMUM AVERAGE # DAYS 11113/2001 WATER INJECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT ACT ][NJ ]NJ ANNU INJ INJ ANN~ INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU ][NJ INJ ANNU INJ INJ ANNU INS INJ ANN~ INJ INJ. ANNU 2077 3400 2084 3400 2082 3400 2071 3400 1290 3400 783 3400 2254 3400 2128 3400 2056 3400 1906 3400 0 3400 762 3350 0 3350 2189 3350 2126 3400 2089 3400 1992 3400 1942 3400 1952 3400 1336 3400 2020 3400 2001 3400 2009 3400 2003 3400 2011 3400 2010 3400 1944 3400 2029 3400 1963 3450 1963 3450 2007 3450 55,079 3,450 1,777 3,400 29 0 550 56( 0 550 56( 0 560 56( 0 560 560 0 560 56~ 0 5~0 5~° 0 560 560 0 560 56~ 0 5~0 5~ 0 560 560 0 560 560 0 550 56O 0 550 560 0 550 560 0 570 570 0 57O 570 381 3450 3460 388 3450 3460 384 3450 346(] 380 3450 346~ 236 3450 346O 150 3450 3450 390 3450 3450 381 3450 3450 370 3450 3450 349 3450 3450 0 3450 345~ 150 3450 3450 0 3450 345~ 399 3450 345~ 398 3450 345~ 397 3450 345~ 1521 3150 315£ 1545 3150 315£ 1542 3150 3125 1530 3150 312 955 3150 312: 540 3100 305 1579 3100 305£ 1556 3100 305£ 1521 3100 305£ 1430 3100 305£ 0 3100 305( 517 3000 300( 0 3000 300( 1572 3000 300( 1565 3100 305( 1556 3100 3054 1513 3100 3050 1490 3100 3050 1490 3100 3050 1019 3100 3050 1500 3100 3050 1530 3100 3050 1538 3100 3050 1530 3100 3050 1531 3100 3055 1534 3100 3055 1504 3100 3055: 1568 3100 3055 1508 3100 3060 1496 3100 3060 1518 3100 3060 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 555 555 0 570 570 0 563 565 0 388 3450 3450 378 3450 3450 384 3450 3450 261 3450 3450 383 3450 3450 377 3450 345C 379 3450 3450 373 3450 345C 373 3450 345£ 380 3450 345£ 371 3450 3450 389 3450 345C 374 3450 345£ 372 3450 345£ 375 3450 3450 10,310 3,450 3,46{] 333 3,450 3,452 29 41,198 3,150 3,150 1,329 3,098 3,060 29 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 735 55G 0 735 550 0 735 55C 0 735 55C 0 735 55~ 0 735 550 0 735 550 0 735 550 0 735 550 0 735 55~ 0 735 55£ 0 730 550 0 730 55C 0 730 55£ 0 730 56( 0 730 56~ 0 730 56( 0 730 56( 0 730 56( 0 730 56( 0 730 56( 0 730 56( 0 730 56~ 0 730 56( 0 745 575 0 745 575 0 745 575 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 735 561 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 575 553 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. 224A-23 shut in for field study and evaluation per Doug Marshall. 0 0 598 0 0 598 0 0 60~ 0 0 60~ 0 0 600 0 0 60~ 0 0 60~ 0 0 6OO 0 0 60~ 0 0 60~ 0 0 60~ 0 0 600 0 0 60~ 0 0 60~ 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 60f 0 0 60~ 0 0 60~ 0 0 60( 0 0 60( 0 0 60( 0 0 60f 0 0 60~ , 0 0 598 0 248 4450 145 4450 72 2575 12 433 2575 12£ 240 2575 120 86 4300 lC 442 4300 lC 385 4300 lC 387 4450 lC 342 4450 1£ 0 4450 lC 0 2400 14£ 0 2400 14C 269 2000 23£ 500 4450 439 4450 409 4450 353 4450 340 4450 228 4450 0 4450 446 4450 385 4450 37O 445O 351 4500 340 4500 330 4500 345 4500 330 4500 333 4500 340 4500 8,888 4,500 23( 287 4,054 3( 27 WATER INJECTION REPORT PLATFORM September-2001 C23-23 ' ACT 'DATE&NOTES INJ [NJ ANNU 01 -Sep-200 1 02-Sep-2001 03-Sep-200 ! 04-Sep-200 ! 05-$ep-2001 06-Sep-2001 07-Sep-2001 08-Sep-2001 09-Sep-2001 10-Sep-2001 1 l-Sep-2001 12-Sep-2001 13-Sep-200 ! 14-Sep-2001 15-Sep-2001 16-Sep-2001 17-Sep-2001 18-Sep-2001 19-Sep-2001 20-Sep-200 ! 21-Sep-2001 22-Sep-2001 23-Sep-2001 24-Sep-2001 25-Sep-2001 26-Sep-2001 27-Sep-2001 28-Sep-2001 29-Sep-2001 30-Sep-2001 TOTAL MAXIMUM AVERAGE #DAYS 2179 3400 1627 3400 2262 3400 2199 3400 2223 3400 2228 3400 2247 3400 2253 3400 2260 3400 2264 3400 2264 3400 2264 3400 2251 3400 2284 3400 2256 3400 2251 3400 2252 3400 2181 3400 2146 3400 2171 3400 2163 3400 2184 3400 2189 3400 2177 3400 2191 3400 2187 3400 2196 3400 2 ! 723400 2146 3400 2138 3400 10/15/2001 C41-23 C24-23 ACT INJ INJ ANNU 0 500 53( 374 3400 3450 0 500 53( 292 3400 3450 0 500 54( 377 3400 3450 0 500 54( 366 3400 3450 0 500 54£ 372 3400 3450 0 500 54( 372 3400 3450 0 550 54( 375 3400 3450 0 500 54( 374 3475 3450 0 540 55£ 374 3475 3450 0 540 5IX 371 3450 3450 0 540 55£ 371 3450 3475 0 540 55£ 370 3450 3475 0 550 55£ 370 3450 3425 0 550 55£ 376 3450 3450 0 550 55£ 373 3450 3450 0 550 55£ 373 3450 3475 0 550 55£ 374 3450 3475 0 550 55f 373 3450 3475 0 550 55£ 377 3450 3475 0 550 55( 372 3450 3450 0 550 55{ 371 3450 3450 0 550 55£ 372 3450 3450 0 550 55£ 372 3450 3450 0 550 55£ 372 3450 3450 0 550 55{ 375 3450 3450 0 550 55£ 372 3450 3450 0 550 56( 380 3450 3460 0 550 56( 376 3450 34613 0 550 560 380 3450 3460 0 550 560 376 3450 3460 0 I 11,122 550 560! 3,475 3,475 0 537 546 371 3,440 3,456 0 30 ACT [NJ INJ ANNU 65,805 3,400 2,194 3,400 30 C34-23 ACT [NJ INJ ANNU C23-26 ACT INJ [NJ ANNU C41-26 ACT [NJ [NJ ANNU C44-14RD ACT [NJ [NJ ANNU 1567 ',~S$O 310 1185 2850 31012 1582 2850 310 1553 2250 310~ 1566 2800 310~ 1560 2850 310~ 1567 2800 1563 2850 310~ 1562 2850 310~ 1556 2850 310C 1549 2850 310~ 1545 2850 310(3 1537 2850 31012 1561 2850 310~ 1553 2850 31013 1551 2850 31~ 1552 2850 31~ 1534 2850 31~ 1552 2850 31~ 1531 2850 31~ 1528 2850 31~ 1528 2850 3i~ 1530 31~ 31~ 1520 31~ 31~ 1528 31~ 31~ 1518 3150 31~ 1537 3150 315~ 1530 3150 315f 1543 3150 315{ !523 3150 315f 46,011 3,150 3,150 i,534 2,922 3,107 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 710 510 0 710 510 0 710 550 0 710 550 0 710 550 0 710 550 0 710 550 0 735 550 0 710 550 0 710 550 0 710 550 0 710 550 0 715 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 770 550 0 735 550 0 735 550 0 735 550 0 735 550 0 770 550 0 740 547 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550' 0 0 550 0 0 550 0 0 55£ 0 0 55£ 0 0 55£ 0 0 550 0 0 55ff 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 575 0 0 553 0 C24A-23 ACT INJ [NJ ANN~ 0 75 585 0 75 585 0 0 585 0 0 585 0 0 585 0 0 570 0 0 585 0 0 585 0 0 585 0 0 585 0 0 585 0 0 585 0 0 590 0 0 590 0 0 580 0 0 585 0 0 585 0 0 580 0 0 580 0 0 590 0 0 590 0 0 590 0 0 595 0 0 595 0 0 595 0 0 598 0 0 598 0 0 598 0 0 598 0 0 598 0 75 598 0 5 588 0 C41,23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. C24A- 14 ACT 1NJ [NJ ANNI. 370 4500 339 4500 335 4500 337 4500 344 4450 346 4450 341 4450 337 4400 339 4400 341 4400 347 4400 343 4400 326 4400 335 4400 345 4400 360 4400 361 44O0 337 4450 352 4450 339 4450 340 4450 348 4450 350 4450 342 4450 342 4450 338 4450 331 4450 335 4450 339 4450 342 4450 10,281 4,500 343 4,440 30 WATER INJECTION REPORT PLATFORM C August-2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ INJ ANNU INJ [NJ ANNU: INJ INJ ANNUINJ [NJ ANNU [NJ INJ ANNU [NJ [NJ ANNUINJ INJ ANNU INJ INJ ANNU INJ [NJ' ANNE 01-Aug-2001 2275 3400 1~ 0 490 490 387 3450 345{ 1569 2800 310( 0 0 0 0 495 30~ 0 0 550 0 505 540 368 4500 02-Aug-2001 2276 3400 1~ 0 500 510 388 3450 3450 1566 3500 310( 0 0 0 0 650 49C 0 0 550 0 505 5400 246 4500 15 03-Aug-2001 2283 3425 1~ 0 500 510 389 3450 3450 1564 3500 310( 0 0 0 0 650 5000 0 0 550~ 0 490 545 395 4550 15 04-Aug-2001 2277 3400 1~ 0 500 500 388 3450 3450 1559 3500 310( 0 0 0 0 660 50~ 0 0 550 0 450 550 375 4550 £ 05-Aug-2001 2268 3400 1~ 0 500 510 386 3450 345{3 1554 3500 310( 0 0 0 0 660 50~ 0 0 550 0 425 5500 372 4500 06-Aug-2001 2274 3400 C 0 500 510 389 3450 3450 1556 3500 310( 0 0 0 0 660 50C 0 0 575 0 400 5500 370 4500 07-Aug-200 ! 2269 3400 1~ 0 500 510 391 3450 3450 1554 3500 310( 0 0 0 0 660 5000 0 0 550 0 375 550 370 4500 08-Aug-2001 2258 3400 1~ 0 500 510 391 3450 3450 1555 2900 311) 0 0 0 0 670 50( 0 0 550 0 350 555 359 4500 09-Aug-2001 2299 3400 C 0 500 510 390 3450 3450 1556 2900 310( 0 0 0 0 670 50( 0 0 550 0 350 555 357 4500 10-Aug-2001 2324 3400 £ 0 500 510 389 3450 34500 1549 2900 3100' 0 0 00 0 670 50( 0 0 550 0 350 555 334 4500 1 l-Aug-2001 2334 3400 C 0 500 510 391 3450 34500 1553 2900 310( 0 0 13 0 670 50C 0 0 550 0 325 56~ 362 4500 £ 12-Aug-2001 2334 3400 C 0 500 510 390 3450 34500 1552 2900 310( 0 0 00 0 670 50( 0 0 550 0 325 5600 363 4500 13-Aug-2001 2352 3400 £ 0 500 510 390 3450 34500 1549 2900 3100 0 0 00 0 670 50C 0 0 550 0 325 5600 362 4500 14-Aug-2001 2341 3400 ( 0 500 510 390 3450 34500 1545 2900 3100 0 0 1~ 0 670 50( 0 0 550 0 325 56~ 365 4500 15-Aug-200 ! 2332 3400 ( 0 500 510 389 3450 345(~ 1540 2900 3100 0 0 (~ 0 670 50( 0 0 550 0 325 56C 361 4500 {: 16-Aug-2001 1640 3400 0 0 500 510 286 3450 3451~ 1132 2900 3100 0 0 1~ 0 670 50( 0 0 550 0 325 56~ 367 4500 17-Aug-2001 2300 3425.0 0 500 470 385 3475 3475 1602 2900 3100 0 0 C 0 690 50( 0 0 550 0 250 53¢ 359 4550 18-Aug-2001 2267 3425 1) 0 500 470 381 3475 3475 1582 2900 3100 0 0 C 0 690 50( 0 0 550 0 250 53(~ 361 4550 19-Aug-2001 2269 3425 0 0 500 470 381 3450 345£ 1576 2850 3100 0 0 ( 0 690 50( 0 0 550 0 200 57£ 357 4525 20-Aug-2001 2240 3425 0i 0 500 470 377 3450 345C 1557 2850 3100 0 0 ( 0 690 50( 0 0 550 0 200 57£ 367 4525 21-Aug-2001 2244 3400 0 0 500 470 380 3450 345C 1556 2850 3100 0 0 ~ 0 690 50( 0 0 550 0 175 57£ 351 4525 ( 22-Aug-2001 1939 3400 0 0 500 47(] 309 3450 345( 1389 2850 3100 0 0 £ 0 690 50( 0 0 550 0 175 57( 273 4525 23-Aug-200 ! 2195 3400 0 0 500 4700 322 3450 345( 1560 2850 3100 0 0 f 0 690 500 0 0 550 0 175 57( 0 4525 0 24-Aug-2001 2192 3400 0 0 500 471~ 322 3450 345£ 1558 2850 3100 0 0 0! 0 690 500 0 0 550 0 175 57{: 356 4525 0 25-Aug-2001 2205 3400 0 0 500 4700 324 3450 345( 1562 2850 3100 0 0 0 0 690 500 0 0 550 0 125 58( 383 4525 13 26-Aug-200 ! 2181 3400 0 0 500 4700 329 3450 345( 1546 2850 3100 0 00 0 690 500 0 0 575 0 125 58{: 362 4525 0 27-Aug-2001 2210 3400 0 0 500 4700 351 3450 345{: 1556 2850 31130 0 0 0 0 690 500 0 0 550 0 125 58( 362 4525 0 28-Aug-2001 2176 3400 0 0 500 471~ 348 3450 3450 1538 2850 3100 0 0 0 0 690 500 0 0 550 0 125 5813 363 4525 0 29-Aug-200 ! 2 ! 89 3400. 0 0 500 4700 35 ! 3450 34501 ! 533 2850 3100 0 0 0: 0 690 500 0 0 560 0 75 582 364 4450 0 30-Aug-2001 2195 3400 0 0 500 53C 351 3450 3450 1533 2850 3100 0 0 0 0 710 550 0 0 570 0 75 582 349 4450 0 3 I-Au~-2001 2133 3400 0 0 550 53£ 356 3400 3450 1509 2850 310(1 0 0 0 0 710 550 0 0 55(1 0 75 585 356 4450 0 TOTAL 69,071 0 11,391 47,610 0 0 0 0 10,689 MAXIMUM 3,425 0 550 5300 3,475 3,475 3,500 3,100 0 0 710 550 0 575 505 585 4,550 15 AVERAGE 2,228 3,404 0 0 501 494 367 3,450 3,452 1,536 2,992 3,100 0 0 0 0 673 496 0 0 553 0 273 561 345 4,510 1 #DAYS 31 0 31 31 0 0 0 0 30 09/12/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. Z24A-23 shut in for field study and evaluation per Doug Marshall. July-2001 01-Jul-2001 02-Jul-2001 03-Jul-2001 04-Jul-2001 05-Jul-2001 06-Jul-2001 07-Jul-2001 08-Jui.-200 1 09-Jul-2001 10-Jul-2001 1 l-Jul-2001 12-Jul-2001 13-Jul-2001 14-Jul-2001 15-Jul-2o01 16-Jul-2001 17-Jul-200 1 18-Jul-2001 19-Jul-2001 20-Jul-2001 21-Jul-200 1 22-Jul-2001 23-Jul-2001 24-Jul-2001 25-Jul-2001 26-Jul-2001 27-Jul-2001 28-Jul-2001 29-Jul-2001 30-Jui-2001 31 -Jul-200 1 TOTAL MAXIMUM AVERAGE # DAYS 08/14/2001 WATER INJECTION REPORT PLATFORM C C23-23 ACT INJ INJ ANNU 2383 3400 2383 3400 2391 3400 2382 3400 2371 3400 2365 3400 2364 3400 2264 3400 2373 3400 2362 3400 2291 3400 2319 3400 2347 3400 2339 3400 2341 3400 2352 3400 2369 3400 2352 3400 2355 3400 1987 3400 2305 3400 2291 3400 2292 3400 2297 3400 2343 3400 2332 3400 2322 3400 2313 3400 2318 3400 2124 3400 2294 3400 71,921 3,400 2,320 3,400 31 C41-23 ACT INJ INJ ANNU 0 450 440 0 450 440 450 44O 450 440 470 470 480 470 480 470 480 470 490 475 490 475 490 480 490 480 490 480 490 480 490 480 490 480 490 480 490 480 490 490 490 490 490 490 490 49(] 490 49(] 490 490 490 49(1 490 490 490 490 490 49(] 490 49~ 490 49~ 490 49(] 0 490 490 0 483 477 0 C24-23 ACT INJ INJ ANNU 370 3450 3450 368 3450 3450 367 34O0 34O0 368 3400 3400 370 3400 340~ 365 3450 3450 365 3450 345(] 361 3450 3450 376 3450 3450 373 3450 3450 319 3450 3450 343 3450 3450 345 3450 3450 346 3450 3450 348 3450 3450 354 3450 345£ 362 3450 345~ 363 3450 345{ 367 3475 3475 338 3475 3475 390 3450 345( 385 3450 345( 385 3450 345( 386 3450 345( 392 3450 345{ 392 3450 345( 390 3475 3475 390 3475 3475 391 3475 3475 372 3500 35001 390 3500 3500 11,431 3,500 3,500 369 3,452 3,452 31 C34-23 ACT INJ INJ ANNU 1551 2900 310( 1570 290O 310( 1572 2800 310( 1566 2800 310( 1561 2800 310( 1558 2800 31001 1563 2800 3100 1512 2750 3100 1610 2800 3100 1602 2850 3100 1556 2800 3100 1568 2800 3100 1576 2800 3100 1568 2800 3100 1570 2800 3100 1573 2800 3100 1581 2800 3100 1567 2800 3100 1575 2800 3100 1349 2800 3100 1588 2800 3100 1573 2850 31O0 1569 2850 3100 1566 2800 3100 1587 28OO 310~ 1576 2850 310~ 1569 285O 3100 1559 2850 31O0 1567 2850 3101] 1466 2800 3100 1587 2800 31O0 48,355 2,9O0 3,100 1,560 2,816 3,100 31 C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 130 5C 0 130 5C 0 130 5C 0 130 5C 0 430 25C 0 450 25C 0 450 25C 0 470 25C 0 480 30( 0 490 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 0 495 300 495 300 441 261 C44-14RD ACT INJ INJ ANNU 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 56~ 0 0 570 0 0 575 0 0 553 0 C24A-23 ACT I~l INJ ANNU 2150 395 2000 4ltl 1850 425 1750 430 1750 48~ 1600 450 1600 455 1500 46~ 1350 465 1300 475 1300 475 1150 485 1125 49(3 1075 495 1025 495 975 50( 950 50~ 950 50~ 900 50( 900 50( 810 52~ 76O 52( 740 52( 740 52~ 740 52~ 675 525 650 53~ 625 53~ 575 535 575 535 575 535 0 2,150 535 0 !,118 490 0 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Woedzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. C24A- 14 ACT ~ ~NIJ I~J ' ANNU 360 4500 352 4500 348 4500 355 4525 347 4600 339 4500 343 4500 341 4550 337 4550 376 4550 364 4500 365 4500 340 4500 335 4500 353 4500 338 4500 389 4500 369 4500 361 4550 367 4550 360 4550 362 4550 360 4550 363 4550 377 4550 365 45O0 367 4475 372 450O 369 4500 354 4500 375 4500 11,103 4,600 358 4,519 31 June-2001 01-Sun-2001 02-Jun-2001 03-Jun-2001 04-Jun-2001 05-$un-2001 06-Jun-2001 07Oun-2001 08-Jun-2001 09-Jun-2001 10-Jun-2001 1 l-Jun-2001 12-Jun-2001 13-Jun-2001 14-Jun-2001 15-Jun-2001 16-Jun-2001 17-Jun-2001 18-Jun-2001 19-Jun-2001 20-Jun-2001 21-$un-2001 22-~un-2001 23-Jun-2001 24-Jun-2001 25-$un-2001 26-Jun-2001 27-Jun-2001 28-Jun-2001 29-~un-2001 30-Jun-2001 TOTAL MAXIMUM AVERAGE # DAYS WATER INSECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 ACT ACT ACT ACT ]NJ INJ A~NU ]NJ ]NJ ANNU ]NJ INJ ANNU ]NJ ]~J A~NU 345 3475 352 3475 343 3475 340 3500 333 3500 886 3500 1596 3400 1574 3400 1912 3400 2029 3400 2363 3400 2570 3400 2872 3400 2746 3400 2708 3400 2727 3400 0 425 430 0 425 430 0 425 430 0 425 430 0 425 430 0 425 430 0 450 420 0 420 42(3 0 460 42(3 0 460 425 0 425 425 0 425 43C 0 430 43C 0 430 43C 0 430 43£ 0 430 43£ 394 3500 3500 395 3500 3500 395 3500 3500 393 3500 3500 391 3500 3500 368 3500 3500 390 3500 3500 388 3500 3500 386 3500 3500 389 3500 3500 384 3500 3500 385 3500 3500 380 3500 3500 376 3500 3500 369 3500 3500 367 3500 3500 1923 3400 340(3 1943' 3400 340~ 1941 3400 340(3 1932 3400 340~ 1922 3400 340~ 1466 3400 340~ 1814 3200 320C 1703 3100 310C 1623 3100 310C 1601 3150 315(3 1588 3100 310( 1590 3125 3125 1568 3125 3125 1572 3125 3125 1575 3125 3125 1586 3125 312~ C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT i ACT ACT ]NI ]NJ ANNU ]NJ ]NJ ANNU ]NJ ]NJ ANNUl INJ ]NJ ANNU ]NJ ]NJ ANNL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 70 60 0 70 6O 0 70 60 0 70 6O 0 70 60 0 70 6O 0 125 50 0 I10 50 0 80 50 0 70 50 0 70 50 0 70 50 0 70 5(3 0 70 5(3 0 70 5(3 0 70 5(3 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 251 4550 25 253 4550 25 249 4550 25 246 4600 3£ 256 4600 3C 196 4600 3£ 246 4500 3~ 258 4600 3C 262 4600 3£ 262 4550 3~ 246 4550 3~ 253 4550 3~ 219 455O 3~ 236 4550 3~ 228 4550 3~ 211 4550 35 2749 3400 323 1850 718 3375 2633 3375 2569 3375 2502 3375 2451 3375 2476 3400 2399 34O0 1972 2900 1789 3250 2099 3250 2439 3400 2407 3375 55,222 3,500 1,841 3,334 30 0 430 43( 0 430 43( 0 430 430 0 430 430 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 372 3500 3500 44 1400 140(1 220 3475 3475 0 3475 3475 380 3450 3450 372 3450 345(3 407 3400 340~ 393 3400 340(3 386 3400 340C 385 2800 280C 277 3300 330( 325 3300 330C 372 3450 345£ 371 3400 340( 0 0 460 440 0 0 438 432 0 10,454 ; 3,500 3,500 348 3,373 3,373 29 1595 3125 3125 189 1400 1400 755 3100 3100 1586 3100 3100 1585 3100 3100 1562 3100 3100 1551 3100 3100 1573 3100 3100 1566 3100 3100 1302 2800 2750 1142 3000 3000 1361 2900 2900 1604 2900 3100 1593 2900 310(] 46,311 3,400 3,400 1,544 3,080 3,092 3O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 70 5C 0 70 5C 0 70 5C 0 70 5£ 0 130 5( 0 130 O, 130 5( 0 130 5( 0 130 50 0 130 50 ~ 0 130 50 0 0 130 50 0 0 130 50 0 0 130 50 0 0 130 60 0 0 94 52 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 55(3 0 0 55C 0 0 56C 0 0 57£ 0 0 575 0 0 553 0 205 4550 35 132 4200 90 62 3300 90 61 3300 90 72 3450 230 100 3400 235 117 3400 270 114 3450 260 138 3450 26(] 238 4200 9~ 189 4200 80 0 3050 250 0 2600 338 0 2300 375 5,300 4,600 375 177 4,062 107 27 357 4575 358 4575 358 4575 366 4600 371 4600 280 4600 378 4500 368 4600 352 4600 354 4600 350 4600 353 4600 318 4600 350 4600 338 4600 317 4600 346 4600 304 4275 122 3300 122 3300 151 3500 160 3500 155 3500 178 3500 181 3500 381 4250 330 4300 419 4500 405 4550 364 44OO 9,186 4,600 306 4,280 30 07/10/2001 ~41-23 shut in due to annular communication problem. 34-23 has developed an annular communication problem. AOGCC notified on 12/12~)9. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM May-2001 01-May-2001 02-May-2001 03-May-2001 04-May-2001 05-May-2001 06-May-200 ! 07-May-2001 08-May-2001 09-May-200 1 lO-May-2001 1 l-May-2001 12-May-2001 ! 3-May-200 1 14-May-2001 15-May-2001 16-May-2001 17-May-2001 18-May-200 1 19-May-2001 20-May-2001 21 -May-200 1 22-May-2001 23-May-2001 24-May-2001 25-May-2001 26-May-2001 27-May-2001 28-May-2001 29-May-2001 30-May-2001 31 -Ma¥-200 1 TOTAL MAXIMUM AVERAGE # DAYS C23-23 C41~23 C24-.23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT ACT INJ INI ANNU INJ 1NI ANNU INI ][NJ ANNU INI INJ ANNU INJ INJ ANNU INJ INI ANNU INJ INS ANNU I~N$ INI ANNU IN./ INJ' ANN~ 1380 3400 930 3400 738 3450 650 3400 596 3400 557 3400 534 3400 197 3400 0 2800 130 2600 704 3400 529 3450 480 3450 448 3450 436 3450 298 3400 416 3400 381 3400 365 3400 356 3400 363 3450 367 3400 556 34OO 449 3450 401 3450 383 3450 373 3450 363 3450 364 3450 366 3450 359 3475 14,469 3,475 467 3,378 30 0 450 45{3 0 450 45{3 0 450 45{3 0 450 45{3 0 450 45C 0 450 45C 0 450 45£ 0 450 45£ 0 450 45£ 513 0 480 44( 0 485 44( 0 450 43~ 0 475 43~ 0 475 43~ 0 450 435 0 435 435 0 435 435 0 435 435 ~ 0 435 435 0 435 435 0 425 430 0 435 435 0 435 435 0 400 425 0 400 425 0 425 43{3 0 425 43{3 0 425 43C 0 425 43C 0 425 43¢ 0 425 43C 377 3450 3450 384 3450 3450 377 3450 3450 378 3450 3450 378 3450 3450 375 3450 3450 380 3450 3450 146 3450 3450 0 1450 1450 51 1375 1375 410 3400 3400 401 3450 3450 399 3450 345{3 392 3450 345{3 402 3450 345{3 266 3450 345C 395 3450 345C 388 3450 345£ 383 3450 34513 380 3450 34513 389 3450 345( 382 3450 345( 383 3450 3450 395 3450 3450 391 3450 3450 391 3450 3450 389 3450 3450 389 3450 3450 393 3450 3450 399 3450 3450 396 3500 3500 1836 3350 335{3 1874 3350 335{3 1849 3350 335~ 1853 3350 335~ 1852 3350 335C 1843 3350 33513 1857 3350 335~ 713 3350 335£ 0 1500 150( 197 1475 1475 1977 3475 330( 1953 3500 3325 1937 3500 335( 1903 3500 335( 1966 3500 3350 1247 3300 3300 1940 3300 3300 1880 3300 3300 1835 3300 3300 1819 3300 3300 1842 3350 3350 1799 3300 3300 1814 3300 3300 1873 3350 3350 1854 3350 3350 1857 3350 3350 1843 3350 335{3 1842 3350 335{3 1857 3350 335{3 1932 3350 335C 1945 3400 340~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 5{3 0 50 5{3 0 50 5{3 0 50 5{3 0 50 5{3 0 50 5C 0 50 513 0 50 5C 0 50 5C 0 50 513 0 50 5C 0 50 5C 0 50 5( 0 50 5( 0 60 5( 0 60 5( 0 60 5( o ~o 50 0 60 50 0 60 50 0 70 50 0 60 50 0 60 50 0 70 60 0! 0 70 60 0 0 70 60 0 0 70 6O 0 0 70 6(3 0 0 70 6(] 0 0 70 6~ 0 70 6~ 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 · 0 550 0 0 550 0 0 550 0 0 55{3 0 0 55{3 0 0 55{3 0 0 55C 0 0 55C 0 0 55C 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 560 0 485 45{3 0 441 438 0 10,959 3,500 3,500 354 3,319 3,319 30 52,789 3,500 3,400 1,703 3,244 3,2 ! 8 30 0 0 0 0 0 0 0 70 6O 0 0 58 53 0 0 0 575 0 0 553 0 167 4500 15 142 4500 15 193 4500 15 221 4550 15 161 4550. 15 180 4550 15 173 4550 15 190 4550 15 115 4300 3( 178 4500 2£ 160 4500 2C 171 4525 15 170 4500 15 162 4500 1~ 170 4500 22 92 3900 20 128 4500 20 136 4550 18 134 4600 18 105 4400 18 218 4525 25 127 4400 18 162 4400 18 174 4425 25 180 4425 25 176 4450 25 194 4500 25 218 4525 25 238 4550 25 219 4550 25 221 4550 25 5,275 4,600 3{3 170 4,478 2{3 31 06/13/2001 C41-23 shut in due to annular communication problem. ~34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. WondzeH on 12/14/99. 370 4575 249 4575 399 4550 399 4575 332 4575 368 4575 371 4575 401 4575 209 4350 379 4600 398 4600 402 4600 395 4575 362 4575 218 4000 424 4500 400 4450 377 4600 337 4450 363 4575 368 445O 354 4450 352 4500 353 4500 369 4500 385 4550 363 4575 361 4600 359 4600 365 4575 11,186 4,600 361 4.527 31 WATER INJECTION REPORT PLATFORM C April-2001 DATE & N0~ 01-Apr-2001 02-Apr-200 1 03-Apr-2001 04-Apr-2001 05-Apr-2OOl 06-Apr-2001 07-Apr-2001 08-Apr-2001 09-Apr-2001 10*Apr-200[ 11 -Apr-2001 12-Apr-2001 ! 3-Apr-200 1 14-Apr-2001 15-Apr-2001 16-Apr-2001 17-Apr-2001 18-Apr-2001 19-Apr-2001 20-Apr-2001 2 l-Apr-2001 22-Apr-2001 23-Apr-2001 24-Apr-2001 25-Apr-2001 26-Apr-2001 2?-Apr-2001 28-Apr-2001 29-Apr-2001 30-Apr-2001 TOTAL MAXIMUM AVERAGE # DAYS 05115/2001 C23-23 ACT INJ INJ ANNU C41-23 C24-23 ACT INJ INJ ANNU C34-23 ACT INJ INJ ANNU C23-26 ACT INJ INJ ANNU C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ 11'41ANNU 0 760 60O 0 760 600 0 770 600 0 770 600 0 770 600 0 770 600 0 770 600 0 770 600 · 0 770 600 0 770 600 0 770 600 0 790 625 0 790 625 0 790 625 0 775 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 · 770 625 0 770 625 0 770 625 0 775 625 0 775 625 0 775 625 0 775 625 0 775 625 0 0 55(3 0 0 55C 0 0 55C 0 0 55C 0 0 55( 1,011 1,300 575 0 0 55£ 0 0 55£ 0 0 550 0 0 550 0 0 550 0 0 550 0 0 5501 0 0 550 0 0 550 0 0 5501 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 400 1,300 575 0 0 550 548 1,375 550 790 1,4OO 560 954 1,375 570 3,703 1,400 575 123 225 553 5 256 4500 269 4500 259 4550 210 4550 216 4550 224 4550 242 4550 211 4550 203 4550 121 4550 264 4450 245 4500 237 4550 213 4550 179 4500 185 4500 186 4500 165 4525 157 4525 149 4525 139 4525 133 4525 129 4525 122 4450 126 4450 163 4450 174 4525 162 4500 156 4500 169 4500 5,664 4,550 189 4,516 30 338 4550 346 4550 370 4600 368 4600 370 4600 373 4600 367 4600 365 4600 380 4600 · !63 4600 384 4500 379 4550 386 4600 377 4600 367 4600 374 4600 374 4600 368 4625 370 4625 366 4625 381 4625 392 4625 372 4625 238 3150 408 3150 381 4500 383 4600 381 4575 383 4575 368 4575 10,872 4,625 362 4,494 30 ACT INJ INJ ANNI 0 880 1600 0 500 490 0 880 160~ 0 500 490 0 940 160~ 0 500 490 0 940 160~ 0 500 490 0 480 160~ 0 500 49~ 0 350 160{3 0 500 490 0 290 185 0 500 490 0 290 185 0 500 49~ 0 290 185 0 500 490 0 290 185 0 500 49{] 0 290 185 0 500 49~ 0 0 0 490 475 0 0 0 490 475 0 0 0 490 47(3 0 0 0 490 47(3 0 0 0 490 47(3 0 0 0 490 47(3 0 0 0 490 47(3 0 0 0 490 47(3 0 0 0 490 47C 0 0 0 490 47C 0 0 0 490 47C 0 0 0 490 47( 0 0 0 490 47( 0 0 ff 0 490 47( 0 0 fi' 0 450 45( 0 0 t~ 0 450 45( 0 0 00 0 450 45( 0 0 i 0 450 45( ! 72 2800 0 450 450 172 2,800 1,600 6 291 351 1 0 500 490 0 487 474 0 374 3450 345C 392 3450 345C 396 3450 345( 390 3450 345( 388 3450 345( 387 3450 345( 384 3450 345( 385 3450 345( 386 3450 345( 384 3450 345( 382 3450 345( 388 3500 345( 387 3500 345( 391 3500 345( 394 3500 3450 396 3500 34501 393 3500 3450 395 3500 3475 394 3500 3475 392 3500 3475 390 3500 3475 389 3500 3475 385 3500 3475 383 3500 3475 379 3500 3475 382 3450 345O 378 3450 3450 379 3450 3450 390 3450 3450 385 3450 3450 11,618 3,500 3,475 387 3,473 3,457 30 1765 3350 3350 1895 3350 3350 1891 3350 3350 1881 3350 3350 1856 3350 3350 1836 3350 3350 1825 3350 3350 1819 3350 3350 1806 3350 3350 1801 3350 3350 1786 3300 3300 1808 3500 3350 1808 3500 3350 1833 3500 3375 1842 3500 3375 1847 3500 3350 1844 3500 3375 t855 3500 340~ 1855 3500 340~ 1842 3500 340~ 1832 3500 340~ 1828 3500 340~ 1810 3500 340~ 1800 35OO 340~ 1774 3500 340( 1792 3350 335( 1770 3350 335¢ 1768 3350 335( 1855 3350 335( 1839 3350 335( 54,763 3,500 3,40(3 1,825 3,418 3,364 · 30 '! 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 790 625 0 772 616 0 ',41-23 shut in due to annular communication problem. :34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. :23-23 shut in for repairs from 4/1/01 thru 4/29/01. Returned to injection on 4/30/01 @ 1:30 p.m. March-2001 C23-23 .... '"'"'~'"'"' ' ' '"""""":' ACT I 01-Mar-2001 02-Mar-2001 03 -Mar-2001 04-Mar-2001 05-Maro2001 06-M ar-2001 07-Mar-2001 08oMar-200 I 09~Mar-2001 I 0-Mar-2001 I l-Mar-2001 12-M ar-2001 13 -M ar*200 I 14~Mar-2001 15-Mar-2001 16-Mar-200 I 17-Mar-2001 18-Mar*2001 19-Mar-2001 20-Mar-2001 21-Mar-2001 22-Mar-2001' 23-Mar-2001 24-Mar-2001 25-Mar-2001 26-Mar-2001 27-Mar-2001 28-Mar-200 I 29-M aro200 I 30-Mar-2001 3 l-Mar-2001 TOTAL MAXIMUM AVERAGE # DAYS C41-23 0 1700 1600 0 1700 1600 0 1500 1500 0 1500 1500 0 1500 1500 0 1450 1450 0 1450 1450 0 1700 1600 0 1500 1400 0 1500 1400 0 1450 1350 0 1400 1350 0 1400 1350 0 1400 1350 0 1400 100C 0 580 80C 0 360 90~ 0 295 925 0 · 295 102~ 0 350 1175 0 480 1325 0 480 132! 0 620 150( 0 700 155( 0 615 155( 0 615 155( 0 615 155~ 0 615 1550 0 615 15s° 0 880 1600 0 880 1600 0 1,700 1,600 0 1,018 1,383 0 ACT INJ INJ ANNU WATER INJECTION REPORT PLATFORM C C24-23 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 52~ 0 500 520 0 500 52~ 0 500 520 0 500 52~ 0 500 52~ 0 500 52C 0 500 52C 0 500 52C 0 500 50~ 0 500 50C 0 500 50~ 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 500 0 500 500 0 500 5OO 0 500 500 0 500 500 0 500 500 0 500 490 0 500 490 ACT INJ INJ ANNU 424 3500 3500 412 3500 3500 405 3500 3500 402 3500 3500 403 3500 3500 409 3500 3500 402 3500 350~ 424 3500 350C 402 3450 345C 402 3450 345C 403 3450 345C C34-23 ACT INS INJ ANNU 2010 3400 3400 1940 3400 3400 1902 3400 3400 1885 3400 3400 1870. 3400 3400 1891 3400 3400 1856 3400 3400 2010 3400 3408 1852 3100 3350 1843 3100 335C 1847 3100 335C 1855 3100 335C 1865 3100 335C 1863 3100 335£ 1825 3100 334~ 1845 3500 335£ 1861 3500 337~ 1836 3500 335( 1824 3500 3325 1846 3500 335( 1858 3500 335( 1830 3500 335( 1830 3500 335( 1853 3500 335( 1856 3500 3350 1869 3500 3350 1881 3500 3350 1872 3500 3350 1884 3500 3350 1843 3350 3350 1837 3350 3350 C23-26 ACT INJ INJ ANNI 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 650 50~ 0 650 50C 0 650 50C 0 650 50C 0 700 55C 0 700 55C 0 700 55£ 0 650 50( 0 700 55( 0 700 55( 0 700 55( 0 700 55( 0 700 55( 0 700 550I 0 740 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 760 600 0 760 600 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 O. 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 ' 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A~23 ACT INJ INJ AIXt'l~ 262 4500 258 4500 258 4500 256 4500 242 4500 230 4500 209 4500 262 450O 201 4500 265 4500 248 4500 207 4500 236 4550 286 4550 224 4500 203 4550 198 4450 203 4425 256 4425 274 4400 242 4400 240 4400 272 4400 269 4400 220 4550 273 4550 271 4550 265 4550 270 4550 272 4500 265 4500 C24A- 14 ACT [NJ [NJ AN3~ 390 4550 387 4550 380 4550 378 4550 382 4550 381 4550 377 4550 390 4550 347 4550 384 4550 389 4550 388 4600 398 4600 386 4600 376 455O 368 4500 361 4525 364 4500 368 4500 368 4500 387 4500 386 4500 380 4500 390 4500 344 4575 412 4575 392 4575 332 4575 389 4575 385 455O 375 4550 405 3450 345f 408 3400 335( 405 3400 335£ 397 3400 345( 401 3500 345( 404 3500 347~ 399 3500 345( 394 3500 342~ 398 3500 345( 399 3500 345( 393 3500 345{ 391 3500 3450 391 3500 3450 391 3500 3450 391 3500 3450 394, 3500 3450 394 3500 3450 392 3500 3450 392 3450 3450 393 3450 3450 0 500 520 0 500 509 0 12,420 3,500 ~500 401 3,481 3,456 31 57,939 3,500 3,400 1,869 3,374 3,363 31 0 0 0 0 0 0' 0 760 600 0 0 720 569 0 0 0 550 0 0 550 0 7,637 4,550 246 4,490 31 11,734 4,600 379 4,545 31 04/12/2001 :41-23 shut in due to annular communication problem. :34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received bom Mr. Wondzell on 12/14/99. :23-23 shut in for upcoming drilling operation in April. WATER INJECTION REPORT PLATFORM February-2001 01 -Feb-200 I 02-Feb-2001 03-Feb-200 I 04-Feb-2001 05-Feb-200 I 06-Feb-2001 07-Feb-2001 08-Feb-200 l 09-Feb-200 I I 0-Feb-200 I 1 l-Feb-200 I 12-Feb-200 1 13-Feb-2001 14-Feb-200 I 15-Feb-200 I 16-Feb-2001 17-Feb-200 l 18-Feb-2001 19-Feb-2001 20-Feb-2001 21 -Feb-2001 22-Feb-200 1 23-Feb-2001 24-Feb-2001 25-Feb-2001 26-Feb-200 I 27-Feb-2001 28-Feb-2001 TOTAL MAXIMUM AVERAGE # DAYS , , C44-14RD C23-23 C41,23 C24-23 C3&23 C23-26 C41-26 C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT ACT ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNE ~J ~J ANNL 1762 3250 3250 1632 3250 3250 1702 3250 3250 1696 3250 3250 1693 3250 3250 1710 3200 3200 1694 3200 3200 1708 3200 3200 1667 3200 3200 1653 3200 3200 1680 3200 3200 1674 3200 3200 1667 3200 3200 1674 3200 3200 1647 3250 3200 1652 3250 3200 1649 3250 3200 1648 3250 320~ 1654 3250 3200 1644 3250 320¢ 1445 3250 3200 0 2200 220{ 0 2200 220{ 0 1900 1825 0 1850 1775 0 1750 175( 0 1750 165( 0 1750 165( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 520 0 500 525 0 500 525: 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 523 0 386 3500 3500 379 3500 3500 393 3500 3500 389 3500 3500 386 3500 3500 386 3450 3450 384 3450 3450 385 3450 3450 382 3450 3450 375 3450 3450 379 3450 3450 382 3450 3450 380 3450 3450 381 3450 3450 372 3450 3425 373 3450 3425 368 3500 3450 368 3500 345~ 367 3500 345C 366 3500 345C 333 3500 345C 237 1500 165C 77 1500 165( 425 3450 345( 406 3450 345( 406 3450 345( 425 3500 350( 423 3500 350( 10,313 3,500 3,50~ 368 3,332 3,332 28 1742 3200 3200 1665 3200 3200 1741 3200 3200 1730 3200 3200 1727 3200 3200 1733 3200 3200 1727 3200 3200 1745 3200 3200 1728 3200 3200 1711 3200 3200 1729 3200 3200 1739 3200 3200 1728 3200 3200 1737 3200 3200 1707 3200 3175 1714 3200 3175 1706 3500 320~ 1704 3500 3200 1708 3500 ~20C 1696 3500 3175 1533 3500 3175 887 1800 1625 291 1800 1625 1949 3050 330{ 1863 3300 330( 1873 3300 330{ 2003 3400 340( 2000 3400 340( 46,816 3,500 3300 1,672 3,170 3,109 28 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 800 650 0 800 65C 0 800 650 0 800 650 0 800 650 0 800 65C 0 800 65C 0 800 650 0 800 65C 0 800 65C 0 800 65C 0 800 65C 0 800 65C 0 800 65( 0 800 65( 0 800 65C 0 800 65( 0 .800 65( 0 800 65( 0 180 10( 0 300 10~ 0 300 10~ 0 300 10~ 0 300 105 0 300 1051 0 300 105 0 300 105 0 300 105 0 0 800 650 0 0 635 475 0 34~51 3,250 3,250 1,248 2,900 2,875 21 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 o o 55oi 0 0 550! 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 248 4400 253 4475 277 4500 272 4500 259 4500 266 4525 262 4525 252 4525 250 4500 246 4500 243 4500 258 4500 256 4500 247 4500 246 4450 253 4450 251 4450 248 4450 247 4500 257 4500 260 4500 162 4500 19 4500 263 4350 283 4400 286 4550 286 4500 268 4500 6,918 4,550 247 4,484 28 356 4475 357 4525 399 4575 392 4575 387 4575 382 4575 370 4575 369 4575 366 4550 369 4550 364 4550 359 4550 355 4550 362 4550 359 4500 359 4500 356 4500 360 4500 362 4500 365 4500 368 4500 225 3000 32 '3000 423 4350 426 4350 421 4550 401 4550 396 4550 10,040 4,575 359 4,414 28 03/12/2001 :41-23 shut in due to annular communication problem. :34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. :23-23 shut in for upcoming drilling operation at the end of March. UI injectors have reduced inected barrels on 2/22 & 2/23 to change accumulator relief valve. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage WATER INJECTION REPORT PLATFORM C January-2001 0 i-Jan-200 ! 02-Jan-2001 03-$an-2001 04-Jan-2001 05-Jan-2001 06-Jan-2001 07-Jan-2001 08-Jan-2001 09-Jan-2001 10-Jan-2001 1 l-San-2001 12-Jan-2001 13-Jan-2001 14-Jan-2001 15-Jan-2001 16-Jan-2001 17-Jan-2001 18-Jan-2001 19-Jan-200 ! 20-Jan-2001 2 l-Jan-2001 22-Jan-2001 23-Jan-2001 24-Jan-2001 25-Jan-2001 26-Jan-2001 27-Jan-2001 28-.Fan-2001 29-Jan-2001 30-Jan-2001 31 -Jan-2001 TOTAL MAXIMUM AVERAGE # DAYS C23-23 ACT INJ INJ ANNU 1732 3250 3250 1749 3250 32501 1775 3250 3250 1822 3300 3250 1748 3300 3250 1726 3250 3250 1758 3300 3250 1792 3250 3250 1783 3250 3250 1773 3300 3250 1750 3300 3250 1748 3300 3250 1760 3250 3250 1752 3250 3250 1760 3250 3250 1773 3250 325C 1730 3250 3225 1737 3225 3225 1653 3250 3225 1781 3250 325£ 1562 3250 325( 1709 325O 325( 1730 3250 325( 1732 3250 325( 1738 3250 325( 1748 3250 3250 1707 3250 3250 1758 3250 3250 1741 3250 3250 1752 3250 3250 1752 3250 3250 54,031 3,300 3,250 1,743 3,259 3,248 31 C41-23 ACT INJ INJ ANNU 0 500 520 0 500 520 0 500 520 0 500 520 0 500 52C 0 500 52C 0 500 52C 0 500 525 0 500 525 0 500 525 0 500 572 0 500 572 0 500 525 0 500 525 0 500 525 0 500 525 0 500 520 0 500 520 0 500 525 0 500 525 0 500 525 0 500 525 0 5O0 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 524 0 C24-23 ACT INJ INJ ANNU 371 3400 340( 370 3400 340( 373 3400 340( 389 3500 3500 377 3500 3500 371 3~00 3400 380 3450 3450 386 3450 3450 384 3450 3450 387 3450 3450 379 3450 3450 376 3450 3450 378 3450 3450 380 3450 3450 382 3450 3450 382 3450 345C 371 3425 3425 371 3400 345C 371 3450 345( 393 3450 345( 355 3450 345( 375 3450 345( 378 3450 345( 377 3450 345( 376 3450 3450 377 3450 3450 376 3450 3450 390 3450 3450 382 3450 3450 387 3450 3450 381 3450 3450 11,725 3,500 3,500 378 3,444 3,446 31 C34-23 ACT INJ INJ ANNU 1618 2950 3150 1616 2950 3150 1630 2950 3150 1678 3200 .3200 1609 3000 320~ 1623 2950 3150 1634 2950 320~ 1654 3200 320~ 1642 3200 3200 1640 2950 320~ 1621 2950 320C 1610 2950 320( 1621 3200 320( 1616 3200 320( 1627 3200 320( 1631 3200 320( 1589 3200 3200 1593 3200 3200 1529 3200 3200 1657 3200 3200 1454 3200 3200 1610 3200 3200 1625 32OO 32O0 1626 3200 3200 1628 3200 3200 1632 3200 3200 1600 3200 3200 1706 3200 320~ 1729 3200 3200 1735 3200 320(3 1725 3200 320~ 50,508 3,200 3,200 1,629 3,129 3,194 31 02/12/2001 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 C44-14RD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ACT INJ INJ ANNU ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 780 625 0 780 625 0 780 625 0 780 650 0 0 780 625 0 0 780 625 0 0 ' 780 625 0 0 785 65O 0 0 785 650 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55C 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 ACT INJ INJ ANNE C24A- 14 0 785' 650 0 785 650 0 785 650 0 785 65C 0 785 65C 0 785 65C 0 785 65C 0 790 65( 0 650 79( 0 790 65( 0 790 65( 0 790 650 0 790 650 0 790 650 0 790 650 0 790 650 0 790 650 0 790 650 0 0 790 650 0 0 790 650 0 0 790 650 0 0 790 650 0 0 790790 0 0 782 650 0 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 ACT INJ INJ ANNL 141 3400 0 212 3500 132 3400 0 243 3500 135 3400 0 257 3500 .129 3500 110 264 3500 120 3500 105 260 3500 144 3350 0 287 3500 252 4100 100 374 4100 294 4250 405 4300 271 4350 400 4400 272 4350 409 4350 269 4350 411 4350 260 4350 414 4350 264 4450 412 4400 283 4450 402 4400 271 4450 398 4400 233 4450 403 4400 234 4525 403 4575 238 4550 400 4600 248 4400 346 4450 288 4500 0i 397 4550 228 4500 0 317 4550 279 4500 0 380 4550 285 4500 0 385 4550 230 4450 0 369 4500 233 4450 0 371 4500 273 4450 0 374 4500 217 4450 348 4500 269 4450 398 4500 253 4450 379 4500 257 4450 379 4500 262 4450 378 4500 7,264 4,550 110 234 4,231 10 31 11,175 4,600 360 4,267 31 WATER INJECTION REPORT PLATFORM C December-2000 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ACT ACT ACT ACT ACT ACT ACT ACT ACT iiii~::~.~i ii::ili::::!::i:: INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU; INJ INJ i:i:!: :~:~:~:::::::: :!::: :!:::: :1 :::::::::::::::::::::::::::::::::::::::::::::::::: 01-Dec-2000 1872 2550 3200 0 500 54(3 389 3400 3425 1862 3050 3275 0 0 01 0 770 650 0 0 550 147 3400 0! 291 3450 02-Dec-2000 1716 2550 3200 0 500 54(3 352 3400 3425 1681 3050 3275 0 0 0i 0 770 650 0 0 550 123 3400 0: 259 3450 03-Dec-2000 0 2550 3200 0 500 54~ 0 3400 3425 0 3050 3275 0 0 0 0 770 650 0 0 550 0 3400 0 0 3450 04-Dec-2000 184 2550 3200 0 500 54(3 76 3400 3425 202 3050 3275 0 0 0 0 770 650 0 0 550 56 3400 0 79 3450 05-Dec-2000 1853 2550 3200 0 500 54(3 412 3400 3425 .1848 3050 3275 0 0 01 0 770 650 0 0 550 182 3400 0 366 3450 · 06-Dec-2000 1961 2550 3200 0 500 54(3 410 3400 3425 1947 3050 3275 0 0 0 0 770 650 0 0 550 180 3400 0 313 3450 07-Dec-2000 1739 3250 3250 0 500 52(3 406 3500 3500 1825 3300 330~ 0 0 . 0 0 775 625 0 0 550 171 3500 0 299 .3500 08-Dec-2000 468 2500 2500 0 500 52(3 409 3500 3500 1762 3300 330(] 0 0 0 0 775 550 0 0 550 141 3500 0 287 3500 09-Dec-2000 166 2500 2500 0 500 52(3 404 3500 3500 1728 3500 325{3 0 0 0 0 770 55{3 0 0 550 131 3500 0 276 3500 10-Dec-2000 2048 3250 3200 0 500 52C 402 3500 3500 1729 3500 325(3 0 0 0 0 770 625 0 0 550 120 3500 0 279 3500 11-Dec-2000 1899 3250 3250 0 500 52( 404 3500 3500 1740 3500 325{3 0 0 0 0 770 625 0 0 550 154 3500 0 273 3500 12-Dec-2000 1867 3250 3250 0 500 52£ 404 3500 3500 1751 3500 . 325(3 0 0 0 0 770 625 0 0 550 162 3500 0 271 3500 13-Dec-2000 1839 3250 325{3 0 500 52( 403 3500 3500 1738 3500 325(3 0 0 0 0 770 625 0 0 550 152 3500 0 268 3500 14-Dec-2000 1817 3250 325{3 0 500 52( 398 3500 3500 1726 3500 325(3 0 0 0 0 770 625 0 0 550 145 3500 0 257 3500 15-Dec-2000 1809 3250 325(3 0 500 52( 401 3500 3500 1726 3500 325C 0 0 0 0 770 625 0 0 550 138 3500 0 270 3500 16-Dec-2000 1815 3250 325(3 0 500 52( 402 3500 3500 1730 3500 325( 0 0 0 0 770 - 625 0 0 550 132 3500 0 275 3500 17-Dec-2000 1820 3250 325(3 0 500 52( 404 3500 350~ 1734 3500 325( 0 0 0 0 770 625 0 0 550 110 3500 0 275 3500 18-Dec-2000 1838 3250 325~ 0 500 52(~ 406 3500 350~ 1746 3500 325( 0 0 0 0 770 625 0 0 550 123 3500 0 289 3500 19-Dec-2000 1834 3250 325~ 0 500 520 407 3500 350(] 1740 3500 325( 0 - 0 0 0 770 625 0 0 550 237 4100 0 389 4100 20-Dec-2000 1723 3250 325( 0 500 520 375 3400 340~ 1611 2950 315( 0 0 0 0 780 625 0 0 550 227 4250 0 395 4350 21-Dec-2000 1793 3250 325( 0 500 520 398 3500 350{3 1724 3500 320( 0 0 0 0 780 625 0 0 550 287 4250 {3 443 4250 22-Dec-2000 1787 3250 325( 0 500 520 398 3500 350~1711 3200 320( 0 0 0 0 780 625 0 0 550 263 4250 {3 434 4300 23-Dec-2000 1778 3000 325( 0 500 520 393 3450 345{3 1698 3300 320( 0 0 0 0 780 625 0 0 550 259 4325 {3 450 4350 24-Dec-2000 1775 3300 325( 0 500 520 392 3450 345(3 1689 3450 320( 0 0 0 0 780 625 0 0 550 268 4350 {3 432 4400 25-Dec-2000 1774 3300 325( 0 500 520 395 3450 345(3 1681 3000 320( 0 0 0 0 780 625 0 0 550 247 4400 {3 433 4450 26-Dec-2000 1444 3300 325C 0 500 520 321 3450 345{3 1363 2950 320( 0 0 0 0 780 625 0 0 550 267 4400 {3423 4450 27-Dec-2000 1723 3250 325( 0 500 520 375 3400 340~1611 2950 315( 0 0 0 0 780 625 0 0 550 227 4250 {3 395 4350 28-Dec-2000 1733 3250 325~ 0 500 520 371 3400 340~ 1635 2950 315( 0 0 0 0 780 625 0 0 550 201 3350 {3 317 2700 29-Dec-2000 1680 3250 325( 0 500 520 365 3400 340~ 1587 2950 315( 0 0 0 0 780 625~ 0 0 550 223 4250 {3 363 4350 30-Dec-2000 1726 3250 325( 0 500 520 371 3400 340~ 1623 2950 315( 0 0 0 0 780 625 0 0 550 144 3350 (3 287 3500 31-Dec-2000 1720 3250 325( 0 500 520 369 3400 340~ 1614 2950 315( 0 0 0 0 780 62.s 0 0 550 198 3400 (3 310 3500 TOTAL 49,201 0 11,412 49,762 3 300 0 0 0 5,415 9,698 MAXIMUM 3,300 3,25(3 500 540 3,500 3,500 3,500 , 0 0 780 650! 0 550 4,400 0 4,450 AVERAGE 1,587 3,063 3,190 0 500 524 368 3,455 3,460 1,605 3,242 3,22§ 0 0 0 0 774 625 0 0 550 175 3,720 0 313 3,734 # DAYS 30 0 30 30 0 0 0 30 30 01/12/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Vefoal approval to continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM C TOTAL MAXIMUM AVERAGE # DAYS C23-23 [NJ [NJ ANNU 1807 3300 3300 1788 3300 3300 1815 3300 330~ 1799 3300 3300 1795 3300 3300 1804 3300 3300 1806 3300 330~ 1780 3300 330~ 1808 3300 330¢ 1800 3300 330( 1726 3300 330~ 1698 3250 325C 1695 3250 325( 1718 3250 325( 1705 3250 325( 1687 3250 325( 1702 3250 325( 1710 3250 325( 1694 3250 325( 1707 325O 325( 1690 3250 3250 1693 3250 3250 1688 3250 3250 1693 3250 3250 1694 3250 3250 1711 3250 3250 1695 3250 3250 1301 3250 3250 1704 3250 3250 1767 3300 33OO 51,680 3,300 3,300 1,723 3,270 3,270 30 C41-23 C24-23 ACT · INJ [NJ ANNU 0 500 520 o 500 52C O 500 52C 0 500 52C 0 500 52C 0 5O0 .52C 0 500 52C 0 500 52C 0 500 52C 0 5OO 525 0 500 52~. 0 500 52t. 0 500 52~. 0 500 52~. 0 50O 520 0 500 520 0 500 520 0 5OO 520 0 5OO 520 0 500 520 0 500 520 0 500 530 0 500 530 0 500 530 0 500 520 0 500 520 0 500 520 0 500 520 0 500 535 0 500 520 0 500 535 0 500 522 0 ACT [NJ [NJ ANNU 435 3500 3500 430 3500 3500 436 35OO 35OO 431 350O 3500 428 3500 3500 430 3500 35OO 432 3500 350O 422 3500 350~ 433 3500 350~ 431 3500 3500 426 3500 350~ 424 3500 350~ 423 3500 350~ 431 3500 350( 427 3500 350( 420 3500 350C 425 3500 350( 426 3500 350( 422 3500 350( 426 3500 350( 420 3500 350( 420 3500 35O( 418 3500 35O( 421 3500 35O( 419 3500 350( 424 3500 35® 420 3500 3500 321 3500 3500 404 3450 3462.5 422 3500 3500 12,647 3,5OO 3,500 422 3,498 3,499 30 C34-23 ACT [NJ [NJ ANNU 1730 3300 330( 1710 3300 330C 1736 3300 330( 1714 3300 330C 1710 3300 330( 1720 3300 330C 1727 3300 330( 1690 3300 330( 1733 3300 330( 1723 3300 330( 1673 3300 33O( 1648 3250 325( 1643 3250 325( 1668 3250 3256 1657 3250 3250 1639 3250 3250 1663 3250 3250 1674 3250 3250 1662 3250 3250 1684 3250 3250 1667 3250 3250 1669 3250 '3250 1667 3500 3250 1676 3550 3250 1684 3500 3250 1708 3500 3250 1693 3500 3250 1297 3500 325C 1769 3275 325¢ 1683 3300 33OC 50,317 3,550 3,300 1,677 3,323 3,270 30 C23-26 ACT [NJ INJ ANNU 0 0 o o 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT [NJ [NJ ANNU 0 760 600 0 760 60¢ 0 760 60G 0 760 .60C 0 760 60C 0 760 60C 0 760 60( 0 760 60C 0 760 60£ 0 76O 60( 0 760 60( 0 770 60( 0 770 60( 0 770 60( 0 770 62~ 0 770 62~ 0 770 625: 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 760 60~ 0 770 625 0 766 613 0 C44-14RD ACT [NJ [NJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55o 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 ' 550 0 0 550 0 C24A-23 ACT · [NJ [NJ ANNU 108 3500 165 104 3500 165 112 3500 165 116 3500 165 120 3500 165 117 3500 165 118 3500 165 121 3500 165 129 3500 165 126 3500 145 120 3500 145 120 3500 160 127 3500 150 116 3500 150 121 3500 155 126 3500 155 135 3500 155 123 3500 155 129 3500 145 137 3500 145 135 3500 145 136 3500 142 132 3450 142 137 3450 140 130 3500 135 135 35O0 135 131 3500 135 104 3500 135 151 3500 150 103 3500 175 3,719 3,500 175 124 3397 153 30 12/11/20oo C41-23 shut in duc tO annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 1 2/12/99. Verbal approval to continue to inject received fi.om Mr. Wondzell un 12/14/99. RECEIVED DEC 2 1 00o Alaska 0{i & Gas Cons. Commission Anchorage WATER INJECTION REPORT PLATFORM C · TOTAL MAXIMUM AVERAGE # DAYS C23 -23 ACT INJ INJ ANNU 1879 3350 3300 1861 3350 3300 1886 3450 3300 1852 3450 3300 1864 3450 3300 1658 3350 3200 1830 3450 3300 1837 3450 3300 1854 3450 3300 1839 3450 3300 1844 3450 3300 1871 3350 3300 1896 3350 3300 1870 3350 3300 1881 3350 3300 1791 3350 3300 1783 3300 3200 1772 3300 3200 1783 3300 3200 1794 3300 3200 1766 3300 32OO 1747 3300 3200 1788 3300 3200 1782 3300 3200 1802 3300 3300 1780 3300 3300 1785 3300 3275 1796 3300 3300 1864 33OO 3300 1767 3300 3300 1782 3300 3200 56,304 3,450 3,300 1,816 3,352 3,267 31 C41-23 ACT INJ rNJ AN'NU C24-23 ACT. [NJ [NJ A]~NU C34-23 ACT INJ INJ ANNU C23-26 ACT INJ INJ ANNU C41-26 ACT INJ I'NJ ANNU C44-14RD ACT INJ INJ ANNU C24A-23 ACT. INJ INJ ANNU C24A- 14 ACT , INJ INJ ANNU, 0 500 5H 0 500 515 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 515 0 500 515 o 500 515 0 500 510 0 500 510 0 500 515 0 500 515 0 500 515 0 500'515 0 500 515 0 500 515 0 500 515 0 500 515 o 5OO 520 0 500 520 0 500 520 o 500 520 0 500 520 0 500 520 0 500 515 0 5oo 520 0 500 514 0 422 3450 345( 420 3450 345( 426 3450 345( 416 3450 345( 419 3450 345( 411 3450 345( 409 3450 345( 410 3450 345( 414 3450 345( 411 3450 345( 413 3450 345~ 418 3450 3450 427 3450 3450 423 3450 3450 424 3450 3450 423 3450 3450 427 3450 3450 424 3450 3450 426 3450 345O 429 3450 3450 422 3450 3450 416 3450 3450 426 3450 3450 428 3450 3450 432 3500 3500 426 3500 3500 426 3450 3450 430 3500 3500 446 3500 3500 422 3500 3500 428 3450 3450 13,094 3,500 3,500 422 3,458 3,458 31 1824 3350 330C 1813 3500 330C 1839 3500 330C 1798 3500 330C 1812 3500 330C 1812 3350 330C 1771 3500 330( 1773 3500 330( 1785 3500 330C 1767 3500 330( 1775 3500 330( 1803 3500 330( 1835 3500 330( 1817 3500 330( 1824 3500 330( 1730 3500 330( 1717 3500 325( 1705 3500 325( 1713 3500 325( 1717 3500 325( 1694 3500 325( 1669 3500 325( 1708 3500 325( 1704 3500 325( 1723 3300 330( 1703 35OO 330( 1704 3300 330( 1712 3300 3300 1777 3300 3300 1683 3300 3300 1704 3500 3250 54,411 3,500 3,30(3 1,755 3,458 3,285 31 o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o 0 o o 0 o o o 0 o o o o o 0 o o o o o o o o o o o 0 o o o o o o o 0 750 60( 0 750 60( 0 750 60C 0 750 60( 0 750 60( 0 745 60( 0 750 60( 0 750 60( 0 750 60( 0 750 60~ 0 750 600 0 750 600 o 750 600 0 75o 6oo o 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 600 0 750 6oo 0 75o 6o0 0 750 600 0 750 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 60O 0 760 600 0 750 60(} o o 760 600 o o 752 600 o o o 550 o o 550 o o 550 o · o 550 o o 550 o o 550 o o 550 o o 550 o o 550 0 0 550 o o 550 o o 550 o o 550 o o 550 o o 550 o o 550 0 0 550 0 0 550 0 0 550 o o 550 o o 550 0 0 550 0 0 55C 0 0 55C 0 0 550i 0 0 5501 0 0 550 0 0 550 0 0 550 0 0 550 o 0 550 o o 550 o 80 3450 225~ 74 3450 225~ 71 3450 210; 61 3450 210 77 3450 210 86 3450 230 68 3450 210 67 3450 210 80 3450 210 99 3450 210 I00 3450 210 83 3450 185 73 3450 185 78 3450 185 74 3450 180 72 345O 180 70 3450 188 70 3450 188 70 3450 188 68 3450 188 74 3450 188 103 3450 188 86 3450 188 94 3450 188 117 35O0 185 100 3500 19C 104 3450 19C 107 3500 185 105 3500 185 103 3500 175 94 3450 188 2,608 3,500 230 84 3,458 196 31 344 3450 341 3500 341 3500 337 3500 343 3500 329 3500 308 3500 306 3500 312 350O 316 3500 318 3500 312 3500 311 3500 307 3500 306 3500 306 3500 308 3500 309 3500 271 3500 345 3500 302 3500 298 3500 259 3500 197 3500 256 3400 284 3500 281 3500 278 3500 294 3500 280 3500 197, 3500 9,296 3,500 300 3,495 31 I 1/14/2000 11-23 shut in due to annular conmunication problem. 14-23 has devcloped an annular communication problem AOGCC notified on 12/12/99. Veflaal approval to continne to inject received fromMr. Wondzellon 12/14/99. WATER INJECTION REPORT PLATFORM C · C23-23 C41,23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT ACT. l~J [~J A.~fNU ]NJ ~J .,~s~U l~j ~J A~U ]~J l~J A~U INJ ]NJ AJ~U l~J INJ .~U ]~J INJ AJN~NU l~qJ ]]'~J AJqNU I~J l~J 1916 3350 3350 0 500 502 449 3500' 350C 2149 3400 ' 340( '' 0 15 ~ 0 702 560 0 0 550 126 3500 255 358 3500 1905 3350 3350 0 500 502 446 3500 350C 2131 3400 340C 0 15 o 0 702 56~ 0 0 550 130 3500 25~ 347 3500 1931 3350 3350 0 500 502 442 3500 350C 2146 3400 340( 0 15 0 0 702 56~ 0 0 550 123 3500 19c 350 3500 2026 3350 3350 0 500 502 445 3500 350( 2151 3400 340( 0 15 0 0 702 56c 0 0 550 128 3500 20( 329 3500 2018 3350 3400 0 500 51~ 446 3500 350c 2151 3400 345( 0 15 0 0 702 558 0 0 550 124 3500 20( 335 3500 2000 3350 3400 0 500 518 443 3500 350c 2135 3400 345c 0 15 0 0 702 55~ 0 0 550 123 3500 25( 329 3500 1975 3350 34000 500 51c 437 3500 350(2104 3400 345( 0 15 00 702 55c 0 0 550135 3500 260322 3500 1982 3350 3400 0 500 51~ 438 3500 350( 2106 3400 345(0 15 0 0 702 55¢ 0 0 550 135 3500 265 322 3500 1957 3350 3400 0 500 51~ 432 3500 350(2078 3400 345( 0 15 00 702 55c 0 0 550128 3500 260321 3500 1969 3350 340~0 500 51c 435 3500 350(2085 3400 345( 0 15 00 702 55c 0 0 550130 3500 260325 3500 1956 3350 340~0 500 51c 433 3500 350(2073 3400 345c 0 15 00 702 55( 0 0 550129 3500 260323 3500 1987 3350 34000 500 51¢ 438 3500 350c2108 3400 345( 0 15 00 702 55C 0 0 550139 3500 260323 3500 38 3350 340(] 0 500 51c 11 3500 350( 37 3400 345(0 15 00 702 55c 0 0 55023 3500 260 20 3500 1173 3250 325~0 500 5K 301 3500 350(1048 3300 3300 0 15 00 702 55( 0 0 550125 3500 260343 3400 1965 3300 330C0 500 51( 488 3500 350(1944 3300 3300 0 15 00 702 55( 0 0 550145 3500 260405 3500 1909 3300 330~0 500 51( 475 3500 350(1938 3300 3300 0 15 00 702 55( 0 0 550159 3500 260363 3500 1900 3350 330~0 500 51~ 475 3500 350(1941 3300 3325 0 15 00 720 57~ 0 0 550145 3500 265356 3500 · 243 3350 330C 0 500 51( 62 3500' 350( 248 3300 3325 0 15 0 0 720 57~ 0 0 550 20 3500 265 47 3500 2079 3350 330C 0 500 51( 481 3500 3500 2008 3300 3300 0 15 ~ 0 720 57~ 0 0 550 164 3500 25~ 441 3500 1949 3350 330C 0 500 51( 460 3500 350(1982 3300 3300 0 15 00 720 57~ 0 0 550140 3500 250370 3500 1930 3375 3325 0 500 51( 458 3500 350( 1973 3325 3325 0 0 ~ 0 720 57~ 0 0 550 143 3500 255 356 3500 1919 3375 3325 0 500 51( 458 3500 3500 1972 3325 3325 0 0 ~ 0 720 575 0 0 550 141 3500 255 352 3500 1920 3375 3325 0 500 51( 458 3500 3500 1970 3325 3325 0 0 ~ 0 720 575! 0 0 550 144 3500 255 345 3500 1895 3375 3325 0 500 51( 453 3500 3500 1947 3325 3325 0 0 ~ 0 720 575 0 0 550 135 3500 255 347 3500 1895 3375 3325 0 500 51( 452 3500 3500 1943 3325 3325 0 0 C 0 720 575 0 0 550 127 3500 255 345 3500 1900 3375 3325 0 500 510 455 3500 3500 1948 3325 3325 0 0 ¢ 0 720 575 0 0 550 128 3500 255 346 3500 1897 3375 332~ 0 500 51~ 454 3500 3500 1942 3325 3325 0 0 C 0 720 575 0 0 550 125 3500 255 350 3500 1898 3350 335f 0 500 51( 454 3500 3500 1940 3350 3350 0 0 ~ 0 720 575 0 0 550 133 3500 25~ 342 3500 1886 3350 335( 0 500 510 450 3500 3500 1925 3350 3350 0 0 ¢ 0 720 575 0 0 550 135 3500 25~ 330 3500 1891 3350 335( 0 500 510 451 3500 3500 1935 3350 3350 0 0 C 0 720 575 0 0 550 141 3500 25~ 328 3500 1872 3350 335( 0 500 51~ 445 3500 3500 1916 3350 3350 0 0 C 0 720 575 0 0 550 143 3500 27~ 324 3500 55,781 0 13,025 57,974 0 0 0 3,966 10,094 3,375 3,400 500 510 3,500 3,500 3,400 3,450 15 0 720 575 0 550 3,500 270 3,500 1,799 3,349 3,346 0 500 509 420 3,500 3,500 1,870 3,354 3,370 0 10 0 0 711 563 0 0 550 128 3,500 252 326 3,497 31 ..... 0 31 31 0 0 0 31 31, TOTAL MAXIMUM AVERAGE # DAYS 09/I 8/2000 ~ust 13th - Wells temporarily offiinc duc to repairs to watcrflood turbine. -23 shut in duc to annular conmaunication problem. ;-23 has dcvclopcd an annular conmaunication problem. AOGCC notified on 12/12/99. Verbal approval to contlnuc to inject n~:eived fi'om Mr. Wondzcll on 12/14/99. WATER INJECTION REPORT PLATFORM C J uly-2 TOTAL MAXIMUM AVERAGE # DAYS C23-23 C41-23 C24-23 C34-23 C23-26 ACT ACT ACT ACT · ACT [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ AN~U [NJ [NJ ANNU 192 3400 340( 1665 3400 340( 2063 3400 340( 2124 3400 340( 2066 3400 340( 0 550 49( 0 550 49( 0 550 49( 0 550 49( 0 55O 490 88 3500 3500 465 3500 3500 454 3500 3500 452 3500 3500 · 446 3500 3500 259 3400 3401~ 2288 3400 340(~ 2366 3400 34012 2368 3400 3408 2337 3400 3408 2073 3400 330( 2047 3400 330( 2029 3400 330( 2006 3400 330( 1996 3400 330( 1987 3400 330( 1977 3400 3325 1977 3400 3325 1974 3400 332~ 1955 3350 3350 1954 3350 3350 1937 3350 3350 1945 3350 3350 1927 3350 3350 1911 3360 3325 1872 3360 3300 I895 3360 3300 1908 3360 3300 1905 3360 3315 1910 3360 3325 1905 3375 3335 1906 3350 3350 1886 3350 3350 1931 3350 3350 1917 3350 3350 1922 3350 3350 58,762 3,400 3,400 1,896 3,375 3,338 31 0 550 4851 0 550 485! 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 49O 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 495 495 o 5OO 5OO 0 500 500 0 500 500 0 500 500 0 500 505 0 500 502 0 500 502 0 500 502 0 500 502 0 500 502 0 500 502 o 550 505 o 530 494 o 456 3500 350~ 456 3500 350~ 455 3500 350{] 451 3500 350~ 451 3500 350C 448 3500 350~ 447 3500 350~ 448 3500 350( 449 3500 350( 444 3500 350( 445 3500 350C 442 3500 350( 445 3500 350( 440 3500 350( 437 3495 350( 428 3450 3475 436 3450 3495 441 3450 3495 441 3495 350( 443 3450 350( 442 3495 350( 445 3500 350( 441 3500 350( 452 3500 350( 448 3500 350( 451 3500 350( 13,487 3,500 3,500 435 3,493 3,499 31 2369 3400 340~ 2357 3400 340( 2345 3400 340( 2323 3400 340( 2312 34OO 340( 2300 3400 340( 2283 3400 340( 2283 3500 340( 2279 3500 340( 2258 3500 340( 2255 3500 340( 2238 3500 340C 2241 3500 340C 2222 3500 ~40( 2200 3500 340( 2148 3500 340( 2167 3150 340( 2180 3150 340( 2172 3150 340~ 2170 3175 3415 2157 320O 3425 2153 3400 340( 2124 3400 340( 2179 3400 340( 2155 3400 340( 2158 3400 340( 67,646 3,500 3,425 2,182 3,391 3,401 31 o 0 o o o o o o o o 0 o o 0 0 0 o 0 0 o 0 o o 0 0 0 o o 0 0 o o o 0 0 o 0 o 0 o 0 0 0 o 0 0 o o o 0 0 o o 0 o o o o o o o o 0 o 0 0 o 08/08/2000 [1-23 shut in duc to annula~ communication problem. i4-23 has dcvcloped an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondz¢ll on 12/14/99. C41-26 C44-14RD C24A-23 ACT ACT ACT ACT · [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ AN~U [NJ JNJ AN~U 0 0 550 o o 55(3 0 700 55( 0 700 55( 0 700 55( o 7O0 55f 0 700 55( 0 700 55( 0 700 55( 0 700 55( 0 700 55( 0 700 5501 o 7OO 550 0 700 550 0 700 555 0 700 555 0 700 555 0 700 555 0 700 555 0 700 555 o 7OO 555 0 70O 560 0 700 560 0 705 560 0 705 560 0 700 560 0 705 560 0 702 560 0 702 56~ o 702 560 0 702 56~ o 702 56~ 0 702 56~ 0 0 705 560 0 0 701 555 0 55(3 55a 550 550 550 550 550 550 55O 55O 550 550 550 550 550 55O 550 550 55O 550 550 550 550 550 55O 55O 55O 55O 550 60 3500 148 183 3500 14(3 126 3500 14~ 112 3500 175 108 3500 175 107 3500 18C 113 3500 185 107 3500 19C 106 3500 19C 112 3500 20( 126 3500 205 129 3500 22( 130 3500 225 125 35O0 225 124 3500 235 118 3500 235 119 3500 235 117 3500 23~ 118 3500 23( 119 3495 235 115 3450 240! 127 345O 243! 128 3450 243 118 3475 245 117 3475 245 121 3475 245 139 3500 255 140 3500 255 126 3500 255 121 3500 255 129 3500 255 0 0 550 0 0 550 0 3,740 3,500 255 121 3,493 217 31 C24A- 14 -, 166 3500 664 3500 558 3500 531 3500 508 3500 509 3500 482 3500 482 3500 470 3500 466 3500 443 3500 428 3500 421 3500 415 3500 414 3500 413 3500 411 3500 411 3500 407 .3500 401 3500 390 3500 387 3525 383 3525 357 3540 364 3550 355 3550 353 3500 358 3500 360 3500 360 3500 354 3500 13,021 3,550 420 3,506 31 WATER INJECTION REPORT PLATFORM C C23 -23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD . C24A-23 C24A- 14 TOTAL MAXIMUM AVERAGE # DAYS 07/10/2000 Acer ]NJ I~J AN~U 0 1300 1300 0 1300 1300 0 1300 1300 0 1300 1300 0 1300 1300 0 1300 1300 o 1300 1300 0 1250 1200 0 1250 1200 0 1200 1200 0 1200 1195 0 1175 1175 0 1175 1160 0 1160 1150 0 i 160 1150 0 1160 1150 96 1160 I 150 ACT. l~J ~J AI~ ACT INJ INJ ANNU ACT_ INJ INJ ANNU ACT INJ INJ ANNU ACT INJ INJ ANNU ACT INJ ~'~J ~ 0 550 500 0 550 500 0 550 5® 0 550 500 o 55O 5O0 0 550 500 0 550 500 0 550 495! 0 550 495 0 555 495 o 555 495 0 550 488 0 550 480 0 550 490 0 550 490 o 550 490 0 550 490 0 1200 1250 0 1200 1250 0 1200 1250 0 1200 1250 0 1200 1250 0 1200 1250 0 1200 1250 0 1150 1200 0 1150 1200 0 1150 1200 0 1150 120~ 0 1150 1195 0 1150 1190 0 1140 1190 0 1140 1190 0 1140 1190 46 1140 1190 0 800 100{ 0 800 100~ 0 800 100C 0 800 100~ 0 800 100~ 0 800 100~ 0 800 10(K 0 750 975 0 750 975 0 74O 96C 0 700 95C 0 700 95C 0 700 95C 0 700 94C 0 700 94C 0 700 94C 155 700 94( o o o o o 0 o o o o o o o o 0 0 o o o o 0 o o o 0 0 o o 0 0 0 0 0 o 0 700 550 0 700 550 0 700 550 0 70o 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 695 55O 0 700 55o 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 ACT INJ INJ ANNU 0 500 410 0 500 410 0 500 410 0 500 410 0 500 410 0 500 410 0 500 410 0 255 425 0 255 425 0 255 430 0 205 432 0 200 435 0 175 438 0 150 440 0 150 440 0 150 440 35 150 440 1533 1160 1150 2401 1160 1150 2339 3300 3300 2270 3300 3300 2219 3300 3300 2210 3350 3300 2182 3350 3350 2162 3350 3350 2141 3350 3350 1867 3400 3400 0 3400 3400 0 3400 3400 0 3400 3400 21,420 3,400 3~00 714 2,007 1,999 11 0 550 490 0 550 490 0 550 490 0 550 490 0 .550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 55O 490 0 555 500 0 550 493 0 332 i140 119~ 464 !140 1190 488 3450 3450 467 3450 345fl 464 3450 345fl 469 3500 350~ 465 3500 350~ 462 3500 350~ 458 3500 350~ 404 3500 350(] 0 3500 350~ 0 3500 350~ o 3500 350~ 4,519 3,500 3,500 151 2,016 2,048 11 34 700 94C 2528 700 2486 3350 300~ 2463 3350 2445 3350 300( 2457 34O0 340( 2437 3400 340( 2412 3400 3¢0~ 2397 3400 340( 2095 3400 340( 0 3400 340( 0 3400 340( 0 3400 34(K 21,909 3,400 3,400 730 1,713 i,820 11 0 o o o 0 o o 0 0 o o o 0 0 o o o 0 o 0 o o o 0 o o 0 o o o o o o 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 o 700 550 0 700 550 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 o 550 0 0 550 0 2O6 150 440 171 150 440 148 3450 3450 132 3450 3450 119 3450 3450 122 3450 113 3500 105 115 3500 120 123 3500 135 92 3500 140 0 3500 140 0 3500 140 0 3500 140 1,376 3,50O 3,450 46 1,468 649 11 !-23 shut in due to annular communication problem 4-23 has developed an annular conltm~cation problem. AOGCC notified on 12/12/99. Verbal approval m con6nue to inject rcccived from Mr. Wondzcll on 12/14/99. Platform '*C~ injectors shut-in fix~m May 11 th~ June 16 due to pump failure. ACT INJ INJ ANNU 0 0 75 0 0 88 0 0 98 0 0 98 0 0 98 0 0 98 686 0 98 850 0 98 578 3500 350~ 576 3500 350~ 549 3500 350C 537 3500 516 3500 495 350O 476 3500 417 3500 0 3500 0 3500 0 3500 5,680 3,500 3,500 210 i,283 375 , I0 · ~xia~ka 0ii & Gas cOns. C0mmis~0n Anch0r~e WATER INJECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 ! ACT ACT ACT ACT ACT ACT ACT ACT ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU May-2000 i:i:i:i:i:!:!:i~!:!:!:i:!:!:i:!:i':':':':':' :::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: :~:~:~:~:~:~:i:i:~:i:~:~:~:~:~:~:~:i:i:i:i:~ 0 l -May-2000 02-May-2000 03--May--2000 04-May-2000 05-May-2000 06-Ma?2000 0'7-May-2000 08~May-2000 09-May-2000 I O.May.2000 I 1 ..May..2000 12-May-2000 13-May-2000 14..Ma?2000 15 .May- 2000 16-M ay-2000 17-May-2000 18.May.2000 19..M'ay-2000 20-May-2000 21 -May-20(g) 22~May.-2000 23-M. ay.2000 24-M~,-2000 25-May-2000 26.May-2000 27-M'ay*20(R) 2g-May-2000 29-M~,-2000 30..May--2000 31 .May. TOTAL MAXIMUM AVERAGE # DAYS 1743 3340 3300 1814 3340 3300 1873 3340 3300 1827 3340 3300 1810 3340 3300 1703 3340 3300 1831 3340 3300 1846 3340 330~ 1836 3340 3300 366 3340 330C 0 2100 205~ 0 500 52( 0 500 52¢ 0 500 525! 0 500 5251 0 500 525! 0 500 525 0 500 525 0 500 525 0 500 525 0 5OO 525 0 550 525 374 3500 3500 393 3500 3500 404 3500 3500 393 3500 35O0 388 3500 3500 385 3500 3500 394 3500 3500 401 3500 3500 397 3500 3500 ~9 3500 3500 ~0 1500 1500 1949 3450 340( 2010 3450 340£ 2102 3450 340£ 2060 3450 340( 2035 3450 340( 2028 3450 340f 2074 3450 340£ 2104 3450 340£ 2090 3450 340~ 417 3450 3400 0 1500 1650 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 670 550 0 0 670 550 0 0 670 550 0 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 680 500 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 1900 1895 0 1840 184¢ 0 1750 176C 0 1710 171E 0 1700 169¢ 0 1650 164£ 0 1650 164~ 0 1650 164£ 0 1650 164£ 0 1650 164£ 0 1650 164( 0 1650 164f 0 550 520 0 550 525 0 550 525 0 55O 525 0 56O 525 0 55O 52O 0 550 520 0 550 520 0 55O 52O 0 550 520 0 550 520 0 550 52O 0 1400 1450 0 1410 1410 0 1400 1400 0 1360 1390 0 1350 1360 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1650 164( 0 1400 140f 0 1400 140( 0 1400 140£ 0 1350 1350! 0 1350 1350 0 1350 1350 0 1300 1300 16,649 3,340 3,300 537 2,166 2,149 !0 0 550 520 0 550 510 0 550 510 0 550 510 0 550 500 0 550 500 0 550 500 0 550 500 1350 1350 1300 1300 1300 1300 1250 1250 1250 1250 1250 1250 1250 1250 1200 1250 0 560 525 0 534 519 0 0 1350 1525 0 1450 1450 0 1200 1400 0 1300 1350 0 1300 1310 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 900 I100 0 900 i100 0 900 1100 0 900 1100 0 900 1100 0 850 1050 0 800 1000 0 0 0 O. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3,608 3,500 3,500 ! 16 2,033 2,037 10 18,869 3,450 3,400 609 1,882 1,950 !0 0 0 0 0 0 0 675 55O 0 675, 540 0 675 550 0 675 550 0 675 550 : 0 675 550 0 675 550 0 675 550 0 675 550 0 675 550 0 675 550 0 675 550 0 675 550 0 1150 55~ 0 i000 550 0 1250 55~ 0 1400 55~ 0 1500 55~ 0 1200 55~ 0 700 55¢ 0 1,500 550 0 786 548 0 0 0 55O 0 0 550 840 1,500 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 340 1300 550 1,020 1,400 550 o 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 o 55O o 0 550 0 0 550 0 0 550 2,200 1,500 550 73 143 550 3 06/14/2000 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOG-CC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. All Platform "C" injectors shut-in fi'om Mayl 1 thru today due to pump failure. Pump has be~n repaired and is currently being installed. 113 3500 30 112 3500 30 114 3500 30 113 3500 30 113 3500 30 113 3500 30 113 3500 30 113 3500 30 113 3500 30 113 3500 30 0 2200 257 0 1855· 293 0 1700 310 0 1550 325 0 1440 335 0 1325 345 0 1255 350 0 1255 350 0 1255 350 0 1255 350 0 1255 350 0 1255 35~ 0 1255 35~ 0 1255 35~ 0 725 38~ 0 725 38~ 0 500 40C 0 400 40C 0 400 40C 0 250 41c 0 500 410 1,130 3,500 410 36 !,891 250 10 April-2000 01 -Apr-2000 02-Apr-2000 03 -Apr~2000 04-Apr-2000 05-Apr-2000 06-Apr-2000 07-Apr-2000 08-Apr-2000 09-Apr-2000 i 0-Apr-2000 I I-Apr-2000 12-Apr-2000 13 -Apr-2000 14-Apr-2000 15-Apr-2000 i 6-Apr-2000 17-Apr-2000 18-Apr-2000 19-Apr-2000 20-Apr-2000 21 -Apr-2000 22-Apr-2000 23-Apr-2000 24-Apr-2000 25-Apr-2000 26-Apr-2000 27-Apr-2000 28-Apr-2000 29-Apr-2000 30-Apr-2000 TOTAL MAXIMUM AVERAGE #DAYS WATER INJECTION REPORT PLATFORM C C2a-o'~ [ C34-23 ~...1~. ! <.~ <,lq ~ ~ ACT ~' ACT ~J ~J A~U ~J ~J A~U I C23-23 [ C41-23 ACT [NJ [NJ ANNU ACT [NJ [NJ ANNU 1817 3300 3300 1762 3300 3325 1834 3300 3325 1850 3300 3325 1858 3300 3325 1839 3300 3325 1841 3300 3325 1837 3300 3325 1846 3300 3325 1826 3300 3325 1838 3300 3325 1838 3300 3325 1823 3300 3350 1833 3375 3350 1800 3375 3350 1784 3375 3350 1779 3350 3300 1774 3350 3300 1785 3350 3300 1783 335O 33OO 1293 3350 330O 1878 3350 3300 1622 3350 3300 0 2100 3300 0 0 3300 459 0 3300 1953 3325 3275 1918 3325 3300 1860 3340 3300 1848 3340 3300 49,178 3,375 3,350 1,639 3,064 3,315 28 0 550 520 0 550 520 0 550 0 550 515 0 550 0 550 515 0 550 515 0 550 515 0 550 515 0 550 515 0 550 515 0 550 520 0 550 525 0 550 525 0 550 525 0 550 525 0 550 510 0 550 510 0 550 520 0 550 520 0 550 520 0 550 520 0 550 520 0 550 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 550 525 0 540 519 0 394 3500 3500 380 3500 3500 397 3500 3500 399 3500 3500 401 3500 3500 397 3500 3500 395 3500 35OO 396 3500 3500 399 3500 3500 395 3500 3500 395 3500 350O 393 3500 3500 392 3500 3500 395 35OO 35O0 389 3500 3500 383 3500 3500 382 3450 3450 381 3450 3450 389 345O 3450 387 345O 3450 288 345O 3450 402 3450 345O 352 3450 345O 11 39: 40( 39~ 399 10,584 353 28 05/10/2000 241-23 shut in due to annular communication problem. Z34-23 has developed an annular communication problem. AC)GCC notified on 12/12/99. Verbal approval to contil 1982 3450 3400 1932 3450 3400 2019 3450 3400 2038 3450 3400 2050 3450 3400 2025 3450 3400 2024 3450 3400 2025 345O 34O0 2036 3450 3400 2009 3450 3400 2025 3450 3400 2024 3450 3400 2016 3450 3400 2023 3500 3420 1954 3500 3420 1933 3500 3420 1934 3450 3400 1932 3450 3400 1919 3450 3375 1926 3450 337~ 1390 3450 337! 2010 3450 33751 i~¢ C23-26 ACT [NJ [NJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 [NJ [NJ ANNU 0 640 50C 0 640 50C 0 650 50( 0 65O 50C 0! 0 650 50( 0 0 650 500~ 0 0 650 500 0 0 650 500 0i 0 650 500 0 0 650 500 0 0 650 50O 0 0 65O 5OO 0 650 500 0 650 500 0 650 500 0 650 500i 0 65O $0( 0 650 50( 0 650 50( 0 650 5001 0 ~ -- C44-14RDs ACT [NJ [NJ ANNU 0 0 550 0 0 550 0 ' 0. 550 0 0 55O 0 0 550 0 0 550 0 0 55O 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 55O 0 0 550 0 0 55O o o 55O 0 0 550 0 0 550 o o 550 0 550 0 550 0 55o o 55O 0 55O 0 550 0 550 0 550 0 550 0 550 550 550 C24A-23 ACT [NJ [NJ ANNU' 150 3500 55 150 3500 55 150 3500 55 150 350O 60 150 35OO 150 3500 150 3500 107 3500 60 108 3500 108 3500 108 3500 107 3500 65 107 3500 62 107 3500 108 3500 57 108 3500 57 107 3450 50 110 3450 5¢ 108 3450 il3 3500 40 80 3500 40 147 3500 112 3500 4C 0 2300 40 0 0 40 112 0 113 3500 25 114 3500 2C 113 3500 3C 113 35OO 3C 3,360 3,500 65 I 12 3,222 49 28 March-2000 01-Mar-2000 02-Mar-2000 03-Mar-2000 04-Mar-2000 05-Mar-2000 06-Mar-2000 07-Mar-2000 08-Mar-2000 09-Mar-2000 I 0-Mar-2000 i I-Mar-2000 12-Mar-2000 13 -Mar-2000 14-Mar-2000 ! 5-Mar-2000 16-Mar-2000 i 7-Mar-2000 18-Mnr-2000 ! 9-Mar-2000 20-Mar-2000 2 I-Mar-2000 22-Mar-2000 23-Mar-2000 24-Mar-2000 25-Mar-2000 26-Mar-2000 27-Mar-2000 28-Mar-2000 29-Mar-2000 30-Mar-2000 3 l-Mar-2000 TOTAL MAXIMUM AVERAGE # DAYS 04112/2OOO ACT WATER INJECTION REPORT PLATFORM C C23-23 INJ INJ ANNU 1802 3240 320(] 1820 3250 322~ 1807 3250 322~ 1924 3350 330C 1940 3350 332C 2794 3150 310( 667 3200 315( 1637 3150 314( 1664 3150 3140 1652 3150 3140 1644 3150 3140 1646 3150 3140 1634 3150 3140: 1590 3150 314~ 1617 3150 3140 1621 3150 3150! 1771 3275 323~ 1761 3275 324~ 1787 3300 325~ 1778 3300 325~ 1846 3350 3300 1805 3350 3300 1814 3350 3300 1801 3300 3300 1812 33OO 33OO 1777 330O 3300 1718 3300 3200 1704 3300 3200 1748 3250 3250 1687 3300 3275 54,058 3,350 3,320 !,744 3,250 3,219 31 C41-23 C24-23 ACT INJ INJ ANNU ACT INJ INJ ANNU C34-23 C23-26 C41-26 ACT INJ INJ ANNU 1998 3425 3375 2041 3450 3400 2037 3450 3400 2054 3450 34O0 2056 3450 3400 2021 3425 3400 2022 3450 34O0 2044 3450 3400 2082 3450 3400 2061 3450 34O(] 2049 3450 3400 2024 3450 3400 1966 3450 3400 1896 3450 3400 1917 3450 3400 1943 3420 3400 2002 3440 34OO 2009 3440 3400 2003 3450 3400 2006 3450 3400 2001 3450 3400 2040 3450 3400 1994 3450 3400 2009 3450 3400 1997 3400 340( ACT INJ INJ ANNU o 50 0 0 o 0 o 0 0 0 o 0 o 0 o o 0 o 0 0 0 o 0 0 0 0 0 0 o 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 o 0 ACT INj INJ ANNU 0 550 502 0 550 51C 0 550 51C 0 550 51( 0 550 51( 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 55o 510 0 550 510 0 550 515 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 0 520 0 520 50~ 0 520 50( 0 550 50C 0 550 50( 0 550 515 0 547 509 o 377 3440 3450 384 3500 350~ 382 3500 3500 386 3500 350( 385 3500 350C 380 3500 350C 379 3500 350( 384 3500 350( 388 3500 350C 386 3500 350( 383 3500 350( 384 35O0 350( 388 350O 350( 370 3500 350( 380 3500 350( 382 3500 350( 393 3500 350( 391 3500 350( 388 3500 350( 387 350O 350( 386 3500 350( 393 35OO 3500! 385 3500 3500 387 350O 35OO 384 3500 3500 387 35OO 35O0 386 3500 3500 390 3500 3500 391 3500 3500 386 3500 3500 375 3500 3500 11,927 3,500 3,500 385 3,498 3,498 31 2014 3400 340( 1953 34OO 340( 1975 ' 3400 340( 1962 3400 340( 1958 3450 34oo 1866 3425 3400 62,000 3,450 3,400 2,000 3,438 3,399 31 0 0 o 0 0 0 0 0 0 0 o o o 50 o 2 0 0 645 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 64O 500 0 640 500 0 640 50(] 0 640 50~ 0 640 500 0 640 500 0 640 500 0 640 5O0 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 50C 0 640 500 0 640 50~ 0 640 50( 500 50( 500 50( 500 50( 500 500 640 500 640 500 645 500 622 500 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 5501 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 o 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 o 0 550 o o 55o o ,! C24A-23 ' [' ACT INJ INJ ANNU 160 4500 294 4550 248 4600 72 3500 124 3500 136 3500 143 35OO 119 3500 52 ~ 2650 19 2650 0 2650 0 2650 0 265O 0 2650 138 3500 174 3800 248 4050 240 4100 243 4250 99 3500 138 3500 142 3480 153 4000 310 4300 303 4500 303 4500 161 4500 97 3500 126 3500 147 3500 150 3500 4,539 4,600 0 146 3,646 0 27 ',41-23 shut in due to annular communication problem. 134-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. RECEIVED APR 132000 Alaska Oil & Gas Cons. Commission Anchorage ~ruar~-2000 0 l-Feb-2000 02-Feb-2000 O3 -Feb-2000 , . 04-Feb-2000 05-Feb-2000 06-Feb-2000 07-Feb-2000 08-Feb-2000 09-Feb-2000 I O-Feb-2000 I l-Feb-2000 ! 2-Feb-2000' 13-Feb-2000 ! 4-Feb-2000 15-Feb-2000 16-Feb-2000 17-Feb-2000 18-Feb-2000 19-Feb-2000 20-Feb-2000 2 I-Feb-2000 22-Feb-2000 23-Feb-2000 24-Feb-2000 25-Feb-2000 26-Feb-2000 27-Feb-2000 28-Feb-2000 29-Feb-2000 TOTAL MAXIMUM AVERAGE # DAYS 03/09/'2000 WATER INJECTION REPORT PLATFORM C C23-23 C4 i -23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 : ACT ACT ACT ACT ACT 'ACT ACT ACT [NJ [NJ ANNU [NJ [NJ ANNU [NJ INJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU INJ [NJ ANNU [NJ [NJ O 3175 3175 0 575 532 ' 373 3475 3490 1926. 3450 340( 0 50 C 0 640 50( 0 0 550 160 4500 0 0 1770 0 570 528 375 3480 3495 1930 3460 340C 0 50 C O 640 50( 0 0 550 294 4550 0 0 1750 0 575 530 380 3500 3500 1952 3450 3422 0 0 C 0 640 50C 0 0 550 248 4600 0 0 1700 0 570 530 381 3500 3500 · 1948 3450 3422 0 0 C 0 640 50( 0 0 550 72 3500 0 0 1700 0 560 525 378 3500 3500 1934 3450 342C 0 0 C 0 640 50( 0 0 550 124 3500 0 1600 1675 0 560 520 377 3500 3500 1933 3450 342~ 0 0 C 0 640 50C 0 0 550 136 3500 0 1600 1650 0 560 520 378 3500 3500 1926 3450 342~ 0 0 ¢ 0 640 50C 0 0 550 143 3500 0 1600 1625 0 560 520 305 3500 3500 . 1557 3450 342~ 0 0 C 0 640 50C 0 0 550 119 3500 0 1600 1600 0 520 520 341 3500 3500 33 2900 342~ 0 0 C 0 640 50( 0 0 550 52 2650 0 1600 1600 O 520 520 401 3500 3500 2047 3450 342~ 0 0 ~ O 640 50( 0 0 550 19 2650 0 1600 1600 0 520 520 379 3500 3500 2036 3470 342~ 0 0 ~ 0 640 50C 0 0 550 0 2650 0 1600 160( 0 520 520 391 3500 3500 2072 3470 342~ 0 0 ~ 0 640 50C 0 O 550 0 2650 0 1600 160( 0 520 520 391 3500 3500 2074 3450 342C 0 0 ~ 0 640 50C 0 0 550 0 2650 0 1600 16OC 0 520 520 382 3500 350( 2026 3450 342~ 0 0 0 0 640 50~ 0 0 550 0 2650 0 1600 160C 0 520 52( 381 3500 350( 1991 3500 3420 0 0 G '0 640 50~ 0 0 550 138 3500 0 1450 148~ 0 550 51~ 382 3500 350( 2012 3470 3420 0 O 0 0 640 500 0 0 550 174 3800 0 1500 148C 0 550 51~ 382 3490 350C 2011 3460 ' 3400 0 50 0 0 645 500 0 0 550 248 4050 0 1500 150~ 0 550 51£ 375 3485 349C 1973 3450 3400 0 50 0 0 648 500 0 0 550 240 4100 0 1500 1475 0 550 51¢ 377 3470 3475 1989 3450 3400 0 50 0 0 647 500 0 0 550 243 4250 0 1450 1450 0 550 51~ 380 3485 3485 1982 3450 3400 0 50 0 0 650 500 0 0 550 99 3500 0 1450 1450 0 550 51C 384 3485 3485 1999 3450 3400 0 50 0 .0 650 500 0 0 550 138 3500 0 1450 1420 0 550 510 382 3475 - 3590 1993 3450 . 3400 0 50 0 0 650 500 O 0 550 142 3480 0 1400 1400 0 550 508 328 3475 3490 1653 3450 3400 0 50 Oi O 650 500 0 0 550 153 4000 2066 3200 1400 0 550 508 382 3500 3490 2002 3500 3400 0 50~0[ 0 650 500 0 0 550 310 4300 199g 3200 1400 0 550 5O8 375 35OO 3490 1994 3500 3400 0 50 ~ 0 650 500 0 0 550 303 4500 1919 3200 1400 0 550 508 375 3500 3490 1999 3500 3400 0 50' O 0 650 500 0 0 550 303 4500 1882 3200 1400 0 550 508 377 3500 3490 2008 3500 3400 0 50 ~ 0 650 500 0 0 550 161 4500 1835 3200 1400 0 550 508 373 3500 3490 1992 3500 3400 0 50 ~ 0 650 500 0 0 550 ' 97 3500 181 i 3200 1400 0 550 508 376 3500 3490 2003 3500 . 3400 O 50 0 O 650 500 0 0 550 126 3500 i !,51 i 0 10,861 54,995 0 0 O 4,242 3,200 3,175 575 532 3,500 3,590 3,500 3,425 50 0 650 500 0 550 4,600 397 1,727 1,597 0 547 516 375 3,494 3,498 1,896 3,446 3,41 ! 0 26 0 O 644 500 O 0 550 146 3,656 6 0 29 29 0 0 0 25 shut in due to annular communication problem. has developed an annular communication problem. AC)C-CC notified on 12/12/99. Verbal approval t.o continue to inject rec~ved from Mr. Wondzell on 12/14/99. down for flange repairs. January-2000 OI-Jan-2000 02-Jan-2000 03-Jan-2000 04-Jan-2000 05-Jan-2000 06-Jan-2000 07-Jan-2000 08-Jan-2000 09-Jan-2000 10-Jan-2000 I I-Jan-2000 12-Jan-2000 13-$an-2000 14-Jan-2000 15-Jan-2000 16-Jan-2000 i 7-Jnn-2000 ! 8-Jan-2000 19-Jan-2000 20-Jan-2000 21 -Jan-2000 22-$an-2000 23-Jan-2000 24-Jan-2000 25-Jan-2000 26-Jan-2000 27-Jan-2000 28-Jan-2000 29-Jan-2000 30-Jan-2000 31 -Jan-2000 TOTAL MAXIMUM AVERAGE # DAYS 02/10~000 WATER INJECTION REPORT PLATFORM C C23-23 ACT [NJ INJ ANNU 1428 3190 3075. 1433 3190 3075 1419 3190 3075 1429 3190 3075 1427 3190 3075 1421 3200 3075 1406 3200 3075 1392 3200 '3075! 1389 3200 3100 1384 3200 315C 1386 3200 315C 1398 3200 3150 1396 3200 315C 1411 3200 3150 1407 3200 3150 1410 3200 3150 1408 3200 3150 1405 3200 3150 1410 3200 3150 1406 3200 · 3150 1399 3200 · 3150 1408 3180 3145 1417 3190 3150 1388 3175 3175 1392 3175 3175 585 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 35,754 3,200 3,175 1,153 3,191 3,135 26 C41-23 ACT [NJ [NJ ANNU C24-23 ACT INJ [NJ ANNU C34-23 ACT [NJ [NJ ANNU 0 580 650 0 580 650 · 0 580 65O 0 580 650 0 . 580 650 0 580 650 0 580 650 0 580 650 0 525 650 0 530 530 0 540 530 0 575 535 0 575 535 o 575 535 0 575 535 0 575 5351 0 575 533 0 575 '533 0 575 540 0 575 532 0 575 522 0 575 513 0 575 53! o 575 53! 0 575 534 0 575 532 0 575 532 0 575 532 o 575 532 0 575 532 0 575 532 0 580 650 0 572 567 0 C23-26 C41-26 C44-14RD ACT INJ INJ ANNU ACT [NJ [NJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 , 0 0 '550 395 3500 3500 396 3500 3500 391 3500 3500 393 3500 3500 392 3500 3500 390 3500 3500 387 3500 3500 381 3500 3500 381 3500 3500 381 3500 3500 381 3500 3500 382 3500 3500 379 3500 350O 383 3500 350C 381 3500 350C 382 3500 350C 380 3500 350C 383 3500 350C 382 3500 350¢ 381 3500 3506 379 3500 3500 381 349O 3500 383 3500 3500 375 3490 350~ 376. 3470 3475 374 3475 349~ 368 3475 3490 370 3475 3490 368 3475 3490 370 3475 3490 370 3475 349~ 11,815 3,500 3,500 381 3,494 3,497 1950 3560 3425 1955 3560 3425 1931 3560 3425 1942 3560 3425 1940 3560 3435 1910 3500 3425 78 2300 1950 0 23O0 1950 0 1900 1750 352 1750 1700 2155 3450 3400 2100 3460 3400 2079 3460 3400 2088 3460 3400 2069 3460 3400 2064 3460 340C 2054 3460 3400 2050 3460 340C 2049 3500 3423 2031 3465 341C 2020 3475 3423 2030 3460 341C 2039 3470 3423 1986 3450 341C 1988 3450 340C 1971 3450 340C 1937 3450 340C 1937 3450 340C 1925 3450 340C 1926 3450 340C 1918 3450 340C 54,474 3,560 3,435 1,757 3,296 3,207 ACT [NJ [NJ ANNU 0 50 0 50 0 50 0 50 0 5o 0 0 0 0 0 0 · 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 0 50 0 50 0 5O 0 50 0 50 0 50 0 50 0 50 0 50 0 5o 0 5O 0 50 0 27 0 o 650 450 0 650 450 o 650 450 0 650 450 0 630 450 0 630 45o 0 630 450 o 630 450 0 630 450 0 630 500 0 640 500 0 640 500 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 50O 0 0' 640 500 0 0 64O 50O 0 0 640 500 0 0 640 5OO 0 .640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 0 640 500 0 0 640 500 0 650 500 0 0 639 485 0 o d 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55o 0 0 550 0 0 550 0 0 55o 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 C24A-23 ACT . ~ [NJ INJ ANNU 175 3500 0 175 3500 0 173 3500 0 174 3500 0 174 3500 0i 173 3500 0 173 3500 0 171 3500 0 171 3500 171 3500 172 3500 173 3500 169 3500 172 3500 170 3500 171 3500 169 3500 170 350O 170 3500 167 3500 167 3500 168 35OO 168 3500 163 3500 166 3475 162 3490 238 4500 37O 4500 331 4500 302 4500 419 4500 6,087 4,500 196 3,660 31 ~1-23 shut in due to annular communication problem. 14-23 has developed an annulnt communication problem. AOC, CC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. !3-23 down for five days due to flange repairs and expected to be back online in mid-February. ~4-23 shut in for two days for survey. WATER INJECTION REPORT PLATFORM C December-99 01 -Dec-99 02-De¢-99 03 -De¢-99 04-Dec-99 05 -De¢-99 06-De¢-99 07-De¢-99 08-Dec-99 09-Dec-99 I 0-Dec-99 I I-Dec-99 12-De¢-99 13 -Dec-99 14-Dec-99 15-Dec-99 16-Dec-99 17-De¢-99 I 8-Dec-99 19-De~-99 20-Dec-99 2 ! -Dec-99 22-Dec-99 23-De¢-99 24-De¢-99 25-De¢-99 26-De¢-99 27-De¢-99 28-De¢-99 29-De¢-99 30-Dee-99 3 I-De¢-99 TOTAL MAXIMUM AVERAGE # DAYS 01113/00 C23-23 ACT INJ INJ ANNU 1389 3175 3100 1394 3175 3100 1394 3175 3100 1392 3175 3100 1391 3175 3100 1389 3175 3100 1388 3175 3100 1332 3175 3100 1386 3175 3100 1388 3200 3050 1390 3200 3050 1391 3200 3050 1395 320O 3050 1386 3200 3050 1379 3200 3050 1382 3200 3050 1372 32O0 3050 1364 3200 3050 1371 32OO 3050 1391 3200 3050 1378 3200 3050 1396 3200 3050 1383 3160 3050 1404 3170 3050 1391 3160 3050 1409 3195 3075 1425 3190 3060 1419 3190 3025 1413 3190 3025 1408 3190 3075 1423 3190 3075 43,113 3,2OO 3,100 1,391 3,187 3,069 31 ACT INJ C41-23 INJ ANNU 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 525 650 0 525 650 0 580 650 .0' 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 o 580 650 0 580 650 0 575 650 0 575 650 0 580 650 0 580 650 0 575 650 0 580 650 0 580 650 0 580 65¢ 0 580 650 0 580 650 0 575 650 0 C24-23 ACT INJ fNJ ANNU 383 3460 3475 390 3460 3475 382 3500 3475 382 3500 3475 380 3500 3475 379 3500 3475 378 35OO 3475 373 3500 3475 383 3500 3475 386 3500 3500 386 3500 350(3 386 350O 350~ 388 3500 350~ 385 3500 350~ 382 3500 35O0 379 3500 350~ 374 3500 350~ 371 3500 3500 375 3500 3500 380 3500 350~ 379 3500 350~ 383 3500 3500 379 3450 3450 385 3475 3485 383 3450 3475 394 3500 350~ 395 3500 3500 394 3500 3500 390 35O0 3500 387 3500 350( 392 35OO 350C i !,883 3,500 3,50O 383 3,493 3,490 31 C34-23 ACT INJ INJ ANNU 1941 3525 1945 3525 1941 3500 1931 3500 1928 3500 1931 3500 1928 3500 1844 3500 i921 3500 1933 3500 1937 3500 20 i943 3500 3400 1953 3500 3400 1938 3500 3400 1704 3500 3400 1683 3500 3400 1738 3500 3400 1738 35O0 3400 1757 3500 3400 1814 35O0 3400 1807 3500 3400 1837 3500 3400 1839 3525 3400 1882 3550 340~ 1869 3525 340~ 1907 3550 3425 1923 3555 3425 1911 3560 3425 1905 3560 3425 1898 3560 3422 1930 3560 3422 58,156 3,56O 3,425 !,876 3,516 2,205 31 C23-26 ACT INJ INJ ANNU 0 50 0 50 0 50 0 5O 0 50 0 50 0 50 0 50 ' 0 5O 0 0 0 0 0 0 0 0 0 0 0 0 . 0 0 0 0 0 0 0 0 C41-26 .ACT INJ INJ ANNU 0 645 450 0 645 450 0 645 0 645 450 0 645 .450 0 645 45C 0 645 450 0 645 450 0 645 450 0 645 450 0 645 45C 0 650 45C 0 650 45C 0 650 45C 0 650 45c 0 650 45C 0 650 45C 0 650 45c 0 650 45C C44-14RD ACT. INJ INJ ANNU 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 0 0 0 0 0 50 0 50 0 $0 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 29 0 0 650 45C 0 650 .45C 0 650 450 0 650 450 0 .640 450 0 650 450! 0 650 450 0 650 450 0 650 450 0 0 650 450 0 0 650 450 0 .0 650 450 0 0 650 450 0 0 648 450 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 108 3460 150 3460 325 4500 376 4500 335 4500 317 4500 314 4500 309 4500 276 4500 89 3500 343 3500 297 4400 285 4450 277 4450 103 445O 0 4450 0 4450 140 4450 109 4450 146 4450 151 4450 160 4450 162 3475 168 3490 167 ' 3475 171 3500 173 3500 171 3500 171 3500 170 3500 174 3500 6,137 4,5OO 0 198 4,057 0 29 '41-23 shut in due to annular communication problem. 134-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM C November-99 01 -Nov-99 02-Nov-99: 03-Nov-99 04-Nov-99 05-Nov-99 06-Nov-99 07-Nov-99 08-Nov-99 09-Nov-99 ! 0-Nov-99 I I-Nov-99 12-Nov-99 13 -Nov-99 14-Nov-99 15-Nov-99 16-Nov-99 17-Nov-99 18-Nov-99 19-Nov-99 20-Nov-99 21 -Nov-99 22-Nov-99 23-Nov-99 24-Nov-99 25-Nov-99 26-Nov-99 27-Nov-99 28-Nov-99 29-Nov-99 30-Nov-99 TOTAL MAXIMUM AVERAGE # DAYS C23-23 ACT [NJ [NJ ANNU 1316 3500 3110 1316 3500 3110 1313 3500 311C 1365 3500 311C 1378 3500 311~ 1386 3500 311~ 1385 3500 311~ 1380 3500 311~ 1382 3500 311C 1381 3500 311~ 1379 3500 311~ 1376 3500 311~ 1379 3500 3110 1383 3500 3110 1373 3500 3110 1384 3500 3110 1369 3500 3110 1375 3500 3110 1359 3500 3110 1374 3500 3110 1375 3500 3110 1377 3500 3110 1375 3500 3110 1388 3500 3110 1379 3200 310~ 1385 3200 31~ 1394 3200 310C 1398 3200 310C 1391 3195 310~ 1392 3195 310~ 41,207 3,500 3,110 1,374 3,440 3,108 30 C41-23 ACT [NJ [NJ ANNU 0 750 6501 0 750 6501 0 750 650 0 750 650 0 750 650 0' 750 650 0 750 650 0 750 650 0 750 650 0 750 650 0 750 65O 0 750 650 0 750 0 750 65C 0 750 65C o 750 65C 0 750 65¢ 0 750 65¢ 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 575 65C 0 575 6501 0 575 650 0 575 650 0 575 650 0 575 650 0 750 650 0 715 650 0 C24-23 ACT [NJ [NJ ANNU 394 3500 350C 398 3500 350C 395 3500 350C 396 3500 350C 397 3500 3500I 400 3500 35001 40i 3500 350C 394 3500 350C 396 3500 350C 397 3500 350C 393 3500 350C 391 3500 350C 393 3500 350C 392 3500 350~ 388 3500 350C 392 3500 350~ 387 3500 387 3500 350~ 381 3500 350C 387 3500 350~ 387 3500 350~ 388 3500 350C 387 3500 350~ 389 3500 350~ 387 3490 350~ 385 3~90 350C 388 3500 350C 389 3500 350C 386 3490 350C 384 3490 350~ !1,729 3,500 3,500 391 3,499 3,500 3O C34-23 ACT [NJ [NJ ANNU 1940 3550 1962 3550 1965 3550 1978 3550 1987 3550 1998 3550 1993 3550 1978 3550 1959 3550 1964 3550 1974 355O 1976 3550 1976 3550 1978 3550 1960 3550 1979 3550 1958 3550 1958 3550 1930 3550 1950 3550 1950 3550 1958 3550 1959 3550 1973. 3550 1951 3500 1955 3550 1963 3550 1963 3560 1956 3550 1951 3550 58,942 3,560 i,965 3,549 30 C23-26 ACT [NJ [NJ ANNU 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 ~ 0 0 50 0 0 50 0 0 50 0 0 50 o o 50 0 0 50 0 50 . 0 5O 0 5O 0 5O 0 50 0 5O oi o 5o 0~ 0 50 0i 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 5O 0 0 50 0 12113/99 C41-26 ACT [NJ [NJ ANNU 0 0 635 450 0 0 635 450 0 0 635 '450 0 0 635 450 0 0 635 450 0 0 635 450 0 635 450 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 635 450 0 635 450 0 635 450 0 635 450 0 635 450 0 635 450 0 0 635 450 0 0 635 45O 0 0 635 450 0 0 .635 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645 45O 0 0 645 450 0 0 637 450 0 C44-14RD ACT [NJ [NJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550' 0 0 550 o o 55o! 0 0 550 o 0 550 0 0 550 o o 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 .0 0 550 0 0 550 0 0 550 0 0 550 o o 550 0 0 550 0 ~ 0 550 0 0 550 0 C24A-23 ~ACT' ~ [NJ [NJ ANNU 244 3500 140 247 3500 140 230 3500 125 120 35O0 125 114 3500 125 113 3500 125 114 3500 125 109 350O 125 109 3500 125 109 3500 125 ill 3500 125 112 3500 125 109 3500 125 II0 3500 125 109 3500 125 112 3500 125 I!0 3500 125 il2 3500 125 106 3500 125 112 3500 125 Iil 3500 125 !i5 3500 125 '115 3500 125 il2 3500 125 109 3490 75 I10 3475 75 i!3 3495 70 116 3500 65 il4 3490 60 114 3490 60 3,741 3,500 140 125 3,498 115 30 I!-23 shut in due to annular communication problem. WATER INJECTION REPORT PLATFORM C March-99 0 l-Mar-99 02-Mar-99 03 -Mar-99 04-Mar-99 05-Mar-99 06-Mar-99 07-Mar-99 08-Mar-99 09-Mar-99 10-Mar-99 1 l-Mar-99 "~ar-99 ~lar-99 · ,~Maro99 15-Mar-99 16-Mar-99 17-Mar-99 18-Mar-99 19-Mar-99 20-Mar-99 21-Mar-99 22-Maro99 23-Mar-99 24-Mar-99 25-Mar-99 26-Mar-99 27-Mar-99 28-Mar-99 29-Mar-99 30-Mar-99 3 l-Mar-99 TOTAL MAXIMUM ~ GE __ ~A¥$ ff4-/08/99 C23-23 ACT INJ INJ ANNU C41-23 ACT INJ INJ ANNI C24~23 ACT INJ INJ ANNU C34-23 ACT INJ INJ ANNU 1265' 3250 3175 1306 3250 3175 1307 3250 3175 1320 3250 3150 1314 3250 3150 1316 3250 3150 1311 3250 3150 1298 3250 31501 1315 3250 31501 1296 3200 315C 1320 3250 315C 1310 3200 315~ 1335 3200 315~ 1327 3200 315~ 1330 3200 315~ 1329 3200 3150 1342 3200 3150 1333 3200 3150 1337 3200 3150 1333 3200 3150 1340 3200 3150 1358 3200 3150 1338 3200 3150 1339 3200 3150 1343 3200 3150 1354 3200 3150 1347 3200 3150 1357 3200 3150 1357 3200 3150 1366 3200 3150 1361 3200 3150 41,204 3,250 3,175 1,329 3,216 3,152 31 782 700 635 786 700 635 786 700 635 792 700 640 793 700 640 791 700 640 790 700 640 778 700 640 791 700 640 780 700 640 792 700 640 787 700 640 783 700 640 781 700 640 782 700 640 787 700 640 790 700 640 789 700 640 790 700 640 779 700 640 783 700 640 793 700 640 789 700 640 788 700 640 790 700 640 792 700 640 785 700 640 794 700 640 792 700 640 794 700 640 792 700 640 24,421 700 640 788 700 640 381 350O 3500 391 3500 3500 391 3500 3500 395 3500 3500 393 3500 3500 392 3500 3500 394 3500 3500 392 3500 3500 396 3500 3500 390 3500 3500 395 3500 3500: 395 3500 3500! 404 3500 35001 400 3500 3500 401 3500 3500 399 3500 3500 402 3500 3500 399 3500 3500 399 35O0 3500 396 3500 3500 397 3500 3500 403 3500 3500 396 3500 3500 396 3500 3500 397 3500 3500 400 3500 3500 397 3500 3500 401 3500 3500 399 3500 3500 401 3500 3500 398 3500 3500 12,290 3,500 3,50C 396 3,500 3,500 1932 3500 0 1981 3500 0 1990 3500 0 2014 3400 0 2007 3400 0! 2015 3400 2000 3400 2000 3400 2000 3400 2000 350O 2014 3400 2000 3500 2000 3500 2000 3500 2000 3500 2000 3500 2000 3500 2000 3500 2000 3500 2OO0 35O0 2000 3200 2000 3200 2000 3200 2000 3200 1885 3200 1881 3200 1854 3200 1866 3200 1860 3200 1868 3200 1854 3200 0 61,021 3,500 0 1,968 3,371 0 C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0i 0 0 0i 0 0 0 0 0 0i 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 475 0 550 425 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 475 0 550 441 0 C44-14RD ACT INJ INJ ANNU 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 C24A-23 ACT INJ INJ ANNI 57 3500 0 0 3500 0 0 3500 0 0 1600 0 0 1400 0 371 3500 0 176 3500 0 66 3500 0 74 3500 0 0 2100 0 0 1600 0 0 2100 0 0 2100 0 2100 0 2100 0 2100 0 1925 0 1925 54 3500 0 3500 0 3500 0 2800 0 1800 0 1800 0 350 0 650 0 640 0 600 0 525 0 475 0 475 798 3,500 0 26 2,134 0 6 cbruary-99 [ C23-23 ! C41-23 INJ INJ ANNU INJ INJ ANNU WATER INJECTION REPORT PLATFORM C C24-23 I C34-23 ACT ACT INJ INJ ANNU INJ INJ ANNU 0 l-Feb-99 02-Feb-99 03-Feb-99 04-Feb-99 05-Feb-99 06-Feb-99 07-Feb-99 08-Feb-99 09-Feb-99 I O-Feb-99 1 l-Feb-99 12-Feb-99 16-Feb-99 17-Feb-99 18-Feb-99 ' 19-Feb-99 20-Feb-99 2 l-F~b-99 22-Feb-99 23-Feb-99 24-Feb-99 25-Feb-99 26-Feb-99 27-Feb-99 28-Feb-99 TOTAL MAXIMUM AVF~ ---0 a~9. 1290 3200 3110 1249 3200 3110 1243 3200 3110 1243 3200 3110 1235 3200 3110 1245 3200 3110 1264 3200 3175 1260 3200 3175 1273 3200 3200 1254 3200 3200 1272 3200 3200 1269 3200 3200 1279 3200 3200 1286 3200 3200 1272 3200 3200 1275 3200 '3200 1264 3250 3150 1248 3250 3175 1262 3250 3175 1243 3250 3175 1263 3250 3175 1251 3250 3175 1250 3250 3175 1257 3250 3175 1240 3250 3175 1224 3250 3175 1233 3250 3175 1292 3250 3175 35,236 3,250 3,200 1~58 3,221 3,167 28 795 700 630 751 700 630 751 700 630 750 700 630 751 700 630 751 700 630 754 700 630 753 700 630 821 700 630 747 7O0 630 757 700 630 752 700 630 755 700 630 770 700 630 793 700 630 796 700 630 795 700 680 793 700 640 799 700 640 785 700 635 801 700 635 792 700 635 795 700 635 774 700 635 780 700 635 780 700 635 · 782 700 635 788 700 635i 21,711 700 680 775 700 63~ 28 438 3500 3500 401 3500 3500 399 3500 3500 396 3500 3500 394 3500 3500 397 3500 3500 399 3500 3500 398 3500 3500 433 3500 3500 392 350O 3500 396 3500 3500 396 35OO 3500 399 3500 3500 399 350O 3500 393 35O0 3500 393 3500 3500 395 3500 3500 392 3500 3500 396 3500 3500 395 3500 3500 399 350O 3500 399 350O 3500 400 3500 3500 402 3500 3500 386 3500 3500 367 3500 3500 370 3500 3500 393 3500 3500 11,117 3,500 3,500 397 3,500 3,500 28 2151 · 3500 0 2121 3500 0 2114 3500 2104 3500 2082 3500 2095 3500 2126 3500 2119 3500 2313 3500 2094 3500 2118 3500 2106 350O 2104 3500 2099 3500 2073 35O0 2046 3500 2091 3500 2086 .' 3500 2115 3500 2056 3500 2059 3500 1945 3500 1900 3500 1980 3500 1912 3500 1884 3500 1881 3500 1981 3500 o[ 57,755 3,500 0 2,063 3,500 0 28 C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 I C44-14RD I INJ ANNU 0 0 5501 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 ii C24A-23 ACT INJ INJ ANNI 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ' 0 0 0 0 ACT INJ INJ 0 0 400 0 0 400 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 55O O' 0 550 0 0 3500 0 2200 0 1900 0 1850 0 1600 0 1425 356 3500 147 3500 1,658 3,500 59 '2,971 17 0 .0 0 400 0 0 400 0 '0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 ACT ANNU INJ 4001 0 1400 366 1400 81 1400 21 3500 40 3500 24 3508 13 3500 20 3500 20 3500 14 3500 8 3500 0 3500 0 3500 0 3500 0 3500 373 3500 120 3500 4O 35OO 12 3500 3 3500 0 0 0 0 400 0 0 40C 0 0 40C 0 0 40C 0 0 40C 0 0 40~ 0 0 40¢ 0 0 40C 0 0 40C 0 0 400 0 0 40O 0 0 400 0 0 400 0 0 400= 0 0 400: 0 0 400 0 0 400' 0 0 400, 0 0 400 Shell Western E&P Inc. O 601 West Fifth Avenue * Suite 800 Anchorage, Alaska 99501 September 6, 1991 State of Alaska ~ Alaska Oil & Gas Conservation commigsion 3001 Porcupine Drive Anchorage, Alaska · ggs02 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C44-14RD Enclosed are duplicates of the Subsequent Report.for the recently completed conversion of Middle Ground Shoal we)J~ ~44-14RD into a disposal well. The operations were completed on August 14, 1991. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very truly yours, Division Drilling Engineer Alaska Division VEU/sl m Enclosure SE/: 10 1991 Alaska Oil & Gas Cons. AnChorag~ ComQiiss[e. rl aogcc/subrep.doc STATE OF ALASKA A~ ~ OIL AND GAS CONSERVATION COMMi )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Perforate __ Pull tubing __ Alter casing__ Repair well ~ Other 5. Type ot Well: 2. Name of Operator Shell Western E & P, Inc. Developmen! Exploratory 3. Address 601 West 5th Avenue, Suite 810 Anchorage, Alaska 99501 Stratigraphic Service X 4. Location of well at surface Platform C, Leg 4, Conductor 4779' S and 1542"~ of NE corner of Sec. 23, T8N, R13W, S.M. At top of productive interval 330'N & 853'W of NE corner of Sec. 23, T8N, R13W, S.M. At effective depth At total depth 1006'N & 1196'W of NE Corner of Sec. 23, T8N, R13W, S.M. 6. Datum elevation (DF or KB) 105' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number C44-14RD 9. Permit number/approval number 77-79/91-043 10. APl number 50-133-20252-01 11. Field/Pool Middle Ground Shoal/"G" Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 11,400 feet Plugs (measured) 9399 feet 7,500 feet Junk (measured) feet Size Cemented 2,483' 13-3/8",61#,J-55 2170 sx 6,724' 9-5/8",43.5-47#,N-80 122 sx 11,398' 7",26-29#,N-80 1000 sx Measured depth True vertical depth 2,183' 2013' 6,724' 5769' 11,400' 9399' Perforation depth: measured 10,059'- 11,112' true vertical 8293' - 9161' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 EUE @ 11,001' Packers and SSSV (type and measured depth) Otis RH @ 10,015', Otis WD Permanent @ 10,267' f ' 'EIVED 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A .Oil & Gas Cons. Commissien '~chorage' 14. Prior to well operation Subsequent to operation OiI-Bbl 0 Re.oresentative Daily Averaqe Production or Injection Date, Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 0 0 SI SI 8/1/91 Disposed of 392 BBLS Waste Fluid, 3.2 BBLS/MIN at 2200 PSI. 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X_~ 17. I hereby certity that the foregoing ~s true ar 6. Status of well classification as: Oil Gas Suspended correct to the best of my Knowledge Title Service Disposal Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DAILY REPORT OF ACTIVITIES C44-14RD DATE ACTIVITY 073091 Drilling cement out of 7" Pressure test perforations to 1,000 PSI for 1/2 hr. POH to perforate 073191 Clean out to 6751~ POH lay down BHA. Rig up western atlas and run in hole with 4" casing guns to perforate guns would not go below 6760~ Trip with clean out assembly to 7350~ (below bottom perf.) Rig up Western Atlas, Perforate with Jumbo Jet 11, 120 degr.e.e.. Phasing ~ ~~O~__to 7250~ ...... ~-~ ~u~ 2 7/8"' ~ubi~--~tion as follows- 2 7/8" Otis wireline entry guide, shear out sub 6634.58~ Otis RH-1 Packer 6622.00~ Otis "XN" Nipple 6587.42~ Set packer with 1500 PSI. Pressure up to 4000 PSI and shear out wireline entry guide. Land tubing, run in lock down screws. Pump into disposal perfs with FIW at 2 BPM 2400 PSI 4 BPM 2500 PSI 8 BPM 3000 PSI 080191 Set BPV. Layed down 111 jts excess tbg f/derrick Nipple down BOPE. Nipple up tree. Rig up BPV lubricator. Attempt to remove BPV. Unable to remove BPV Lubricator. Installed TRE cap. (ORDERED NEW TOOLS TO REMOVE BPV) Tear out rig. Move to C24-23. This report 1800 hours. Rig released at midnight, 07/31/91. 081391 Rig accepted at 0600 hrs 08/12/91 Moved rig on location. Rig up. Install BPV. Nipple down tree. Nipple up bope. Test bope 250/2500, will test blinds when out of hole. Rig up t/take all returns t/production system. Unseat packer f/6622~ Disp weil W/238 bbls 8.9 ppg kill fluid. (well had 105 psi on tbg) poh laying down tbg. 081491 Finished laying down 2-7/8" tbg/packer. TIH w/3 stds of DC~s and Howco Storm Pkr, set at 85~. Test t/1500# OK. Changed out DCBS spool. Test t/500 psi f/15 mins OK. Nipple up riser. Annular valves and drill nipple. Change rams t/3.5". Test BOPE 250/2500 psi. POH w/storm packer/DC~s. Rig up tbg running equipment and running 3.5" Duo-line tubing. AOGCC\C4414RD. DOC 081591 Running in hole with Duo-Line tubing completion. Make up tubing hanger and land in DCB spool. Reverse circulate 200 bbls. filtered inlet water treated with 5 gals Visco 3900 corrosion inhibitor into annulus. Drop 2" ball to set packer. Pressure up tubing to 2500 psi then to 3000 psi for 5 min. Bleed off tubing and pressure up annulus to 1600 for 30 min. No flow/bleed off. Shear out ball seat with 3200 psi. Install Back pressure valve and nipple down BOP, pull riser. Part of tubing hanger seal had rolled over and was in riser. Pickup tubing hanger and install new seals. Land hanger and install seal flange and tree. Test flange and hanger to 5000 psi. for 15 min. Pull BPV and shut in well. Released rig from C44-14 at 1930 hrs. 08/14/91. Prepare rig for skid to C 23-23. Completion Detail: Rotary to DCB spool 33.30 Tubing hanger 33.95 19 jts. 3 1/2" Duoline tubing 316.37 Inconel "X" nipple (2.313) 199 jts. Duo-line tubing Inconel "X" nipple (2.313) 1 jt. Duoline tubing Baker "CH" anchor assembly Baker Hydro set packer and mill out extension Crossover 4 1/2 X 3 1/2 1 jt. Duoline tubing Inconel "XN" nipple (2.205) 1 jt. Duoline tubing Baker wireline entry guide 317.62 6545.87 6547.12 6578.51 6579.28 6584.08 6590.15 6621.71 6623.06 6654.36 6655.19 Up weight 90,000 Down weight 68,000 AOGCC\C4414RD.DOC July 2, 1991 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission ATTN: Commission Lonnie Smith 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Commissioner Smith- SUBJECT' TRANSMITTAL OF ADDENDUM TO AN APPROVED SUNDRY NOTICE FOR MIDDLE GROUND SHOAL WELL C44-14RD During a recent conversation between R. Wagner (SWEPI) and yourself, the upcoming workover to convert Middle Ground Shoal well C44-14RD to a disposal well was discussed. Mr. Wagner pointed out that some numbers submitted in the original Application for Sundry Approval (approval number 91-043) needed to be revised or clarified. By way of this letter we are providing this information. Enclosed for your inclusion in the approved sundry notice are the details of the revisions and clarifications, the conversion procedure, and well diagrams. If you have additional questions, please contact R. R. Wagner at (907) 263-9632 or S. B. Brown-Maunder at (907) 263-9613. Very TrUly Yours, W. . SimlYson Manager Regulatory Affairs Alaska Division SBBM Enclosures JUL - 5 l%B1 Alaska Oil & G~S Oons. Gommiss'~o~ 'Anchorage a:O70291b.doc REVISIONS & CLARIFICATIONS TO APPLICATION FOR SUNDRY APPROVALS TO CONVERT WELL C44-14RD TO A DISPOSAL WELL Per a telephone conversation between Mr. Randy Wagner of SWEPI and Commissioner Lonnie Smith on 6/28/91, the following revisions and clarifications are being submitted: · References to the DM marker at 7278' in Well C44-14RD found in Table 1 on p. 9, and in Attachments C, F, G & H should all be changed to 7328'. The DM marker depth was incorrectly correlated back to the depth it is found in Well C44-14. In Well C44-14RD, the DM marker is found at 7328' (reference the Dresser Atlas SP/DIFL log dated 3/11/78). · Although the lowest perforation in the disposal well will be at the DM marker, it should be recognized that there is no cement behind the 7" production casing below the DM marker until an estimated measured depth of 8000'. It is possible that fluids injected into the C44-14RD disposal well will migrate down the uncemented annulus and into the "A" Pool sands (found in Well C44-14~-'--MD)'~ Ther'e is Pr°J~-~{'~6~h~'from the "A" Pool sands from Platforms "A" and Baker but no production from Sections 12, 13, 14, 23 or 26. There are no significant hydrocarbon zones found in the "A" Pool within a mile of C44-14RD. Any possible migration of injected waste fluids into the "A" Pool will not affect any present or future production of hydrocarbons from the Middle Ground Shoal field. . A detailed procedure with well diagrams is included which more clearly describes the scope of plugging and abandoning the production interval of C44-14RD and converting the well to a disposal well. RECEIVED JUL - ,5 t99t Alaska Oil & Gas Cons. Commission Anchorage MIDDLE GROUND SHOAL WELL C44-14RD CONVERS!ON TO DISPOSAL WELL PROCEDURE STATUS: The well has been shut-in since March, 1986. After a workover in 1986 to fracture treat the HR-HZ and isolate the HC-HR with straddle packers (watered out), the well tested 43 BO + 677 BWPD. The GR-GS was perforated and the HR-HN isolated with a PX plug near the EOT. No production was established from the GR-GS. While performing a CTU acid treatment on the GR-GS, a CTU wash nozzle was lost and is assumed to be resting on the PX plug. Numerous unsuccessful attempts were made to retrieve the wash nozzle. Using a CTU, the GR-GS perforations were squeezed and successfully tested to 1000 psi. After squeezing, the well was cleaned out to 10961' with a CTU and a Dyna-Drill mill. Several attempts to cut off the tailpipe to return the HR-HZ to production have been unsuccessful. A 2-1/8" ceramic perforating ball was lost in the hole on 4/4/87. While cleaning out with a CTU wash nozzle on 4/5/87, all attempts to wash past a bridge at 10110' were unsuccessful. A Sperry Sun multi-shot gyroscopic survey was run to a depth of 7532' on 11/21/88 before drilling C43-14. It is possible that a drilling assembly used to drill Cll-23 collided with the 13-3/8" surface casing at 675' MD (2/8/91). The retrievable SSV has been removed. The wellhead was successfully field hydrotested to 5000 psi on 6/8/91. OBJECTIVES: 1. P&A lower section of wellbore. 2. Prepare well for waste disposal into the CK-DM interval. 3. Preserve well for later disposal into the BC-BG interval. PERTINENT DATA: Leg 4, Conductor 31, Platform "C" KB to MSL : 105' TD = 11,400 MD; PBTD: 11,287' MD See Attachment I for Casing Detail REFERENCE LOGS: Below 6724' - Dresser Atlas SP/DIFL dated 3/11/78 and Dresser Atlas GR/BHCAL dated 3/13/78. Above 6724' - ATTACHMENTS: Schlumberger SP/DIL dated 10/10/73. I Present Status II Completion Equipment Detail III Proposed Status JUL *- 5 I99) Alaska Oil & Gas Cons. Commission Anchorage RRW/062691. MGS C44-14RD CONVERSION TO DISPOSAL WELL PROCEDURE · . . · P&A LONER SECTZON OF NELL Move rig over well and nipple up. Test BOP equipment. Test choke manifold, kill valves, HCR, blind rams, pipe rams, floor valves, IBOP, and safety valve to 250 psi and 5000 psi. A 3" type "H" two-way check valve in the tubing hanger and a 1/8" NPT control line plug are required to test the rams. Test annular preventer to 250 psi and 3500 psi. Give AOGCC 24 hours notice prior to testing BOP. Pull tubing and Otis RH packer out of the hole. The Otis WD straddle packer assembly will remain in the hole (reference Attachments I & II for mechanical details). Give AOGCC 24 hours notice prior to commencing plugging operations. GIH with a bridge plug on the work string and set at 10030'± (within 50' of top perforation). Release from bridge plug and spot 55 sx Class "G" cement (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk) on top of bridge plug. Estimated TOC is at 9730'±. Squeezing into the formation should not be attempted since the GR-GS perfs have already been squeezed and the remainder of the perfs are mechanically isolated. This plug satisfies the requirements of 20 AAC 25.105(h)(1)(C). Pressure test 7" casing and plug to 4000 psi for 30 minutes to satisfy the requirements of 20 AAC 25.105(1) and ensure casing integrity. It is not necessary to tag the TOC if a successful pressure test is conducted per 20 AAC 25.105(1). CONVERT TO DISPOSAL WELL . Perforate a 1' interval in the 7" casing with the top shot at 6730'. Observe for any increase in surface pressure. · Attempt to establish circulation conventionally through the 9-5/8" x 7" annulus. Do not exceed 3000 psi. If circulation cannot be established, attempt to reverse circulate without exceeding 3000 psi. If still unsuccessful, consult Engineering and prepare to re-perforate. Hold and isolate all returns from the 9-5/8" x 7" annulus. · After establishing circulation, pump a 40 bbl HEC sweep followed by FIW or a heavier mud to kill the well (if necessary). . Mix and pump 100 sx Class "G" cement (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Displace with Halliburton pumps. Stop displacement with 4 bbl of cement still in the 7" casing (104' in 7" 26# casing). Hesitation squeeze 2 bbls, leaving 2 bbls of cement in the casing and the TOC 78' below the RTTS. TOC in the annulus will be at 6040'±. Shut in work string and hold pressure for 8 hours. Release RTTS and reverse out. POOH. This cement plug provides 684' of annular fill-up and satisfies the requirements of 20 AAC 25.030(d)(3)(C). RE~EIV ED RRW/062691. J U L - 5 199t Alaska Oil & Gas Cons. Commission Anchorage MGS C44-14RD CONVERSI'ON TO DISPOSAL NELL PROCEDURE 9. GIH with a 6" bit and drill out cement. POOH and run a scraper to no deeper than 6700'. Pressure test squeezed perfs to 1000 psi. POOH. 10. RIH with completion equipment. Set packer at 6620'+. 11. Perforate the interval 7248' - 7328' (the DK-DM sand). Rig down. RRW/062691. RECEIVED J U L - 5 199~ Alaska Oil & Gas Cons. Oommissior~ Anchorage ATTACHMENT I MGS C44-14RD PRESENT STATUS 06/17/91 TOP JOB:· ~~ 120 ex 'G' 2% CaCl2 SPOTTED at 120' to SURFACE NOTE: SEE ATTACHMENT II FOR COMPLETION EQUIPMENT DETAIL. NOTES-- AFTER SQUEEZING GR-GS, CLEANED OUT w/CTU to 10961' (12/26/86) LEFT 2-1/8' CERAMIC PERFORATING BALL IN HOLE AFTER FREEING STUCK WlRELINE CHARGE at 9684' (4/4/87) COULD NOT GET PAST BRIDGE at 10110' w/CTU V~SH NOZZLE (4/5/87). 24' CONDUCTOR at 370' 13-3/8' SURFACE CASING at 2483' 61# J-55 BTC CEMENTED w/ 2350 cf 'G' * 10% GEL FOLLOWED BY 200 sx 'G' ESTIMATED TOC at 6670' li~ 9-6/8' PROTECTIVE CASING at 6724' 0-4976' 40# N-80 BTC 4976'-6724' (WINDOW) 43.5# N-80 BTC CEMENTED w/122 ax 'G' at 15.6 ppg ESTIMATED TOC at 8000' OTIS RH PACKER at 10015' SQUEEZED GR-GS PERFS w/6.6 bbl 15.5 ppg CEMENT. TESTED TO 1000 psi w/NO LEAK OFF (10060'-10134'). HC-HR PERFORATIONS BETWEEN PACKERS FISH: CTU WASH NOZZLE on top of PX PLUG PX PLUG In 'X' NIPPLE at 10983' (ISOLATES HR-HZ ZONE) PBTD at 11287' .L.~ii!iiiiiii!i[ii:iii:iiiiiiiii!i!iiiiiiiii!i (~ ~ :::::::::::::::::::::::::::::::::::::::::::::: 7' CEMENTED w/990 eX 'G' '~'~'_~'~; RRW/C4414PRS.CHT WL RE-ENTRY GUIDE at 10045' PERFORATIONS: 10060'-11110' OTIS WD PACKER at 10267' KBMG MANDREL w/DUMMY VALVE at 10622' OTIS WD PACKER at 10970' EOT at 11001' (2-7/8' 6.5# N-80 EUE) POSSIBLE FILL at 11162' 7' PRODUCTION CASING at 11398' ,.,o ,,o RECEIVED 7989'-11398' 29# N-80 BTC J U L - ,5 199~ Alaska OJJ & Gas Cons, Commiss[of~ Anchorage J 7 8 9 10 11 12 13 14 15 16 17 18 19 2O COMPLETION EQUIPMENT [DETAIL SHEET MGS C44-t4RDI I 6/17/87 NO. ITEM 1. OTIS XEL LANDING NIPPLE 2. CAMCO KBMG MANDREL #1 3. CAMCO KBMG MANDREL #2 4. CAMCO KBMG MANDREL #3 5. CAMCO KBMG MANDREL #4 6. CAMCO KBMG MANDREL #5 7. CAMCO KBMG MANDREL #6 8. CAMCO KBMG MANDREL #7 9. CAMCO KBMG MANDREL #8 10. OTIS "XO" SLIDING SLEEVE 11. OTIS RH PACKER 12. OTIS "X" NIPPLE 13. W/L RE-ENTRY GUIDE STRADDLE ASSEMBLY 14. OTIS WD PERMANENT PACKER 15. 3.44' SEAL BORE EXT. 3.25" 16. CAMCO KBMG MANDREL #9 17. OTIS WD PERMANENT PACKER 18. 3~41' SEAL BORE EXT. 3.25" 19. OTIS "×" NIPPLE 20. W/L RE-ENTRY GUIDE APPROXIMATE TVD. MD. PSI OR 290 290 1649 1740 3162 3590 4461 5158 5548 6457 6467 7648 7203 8596 7928 9584 8220 9963 8234 9981 825B 10015 8266 10026 82B1 10045 8461 10267 8463 10271 8753 10622 DUMMY 9043 10970 9045 10973 9054 10983 9069 11001 CASING 13 3/8", 61#, J-55 @ 2483' w/2170 sx 9 5/8", 43.5#, ? @ 6724' w/? sx 7" 26-29#, N-80 @ 11398' w/lO00 sx PBTD = 11162'??? TD = 11400' TUBING 2 7/8", 6.5#, N-80 EUE @ 11001' PERFORATED ZONE GROSS INTERVAL GR-GS 10060-10134 HC-HD 10320-10331 HC-HD 10342-10348 HC-HD 10370-10374 HE-HF 104B0-10484 HK-HN 10720-10766 HN=HR 10793-10817 HN-HR 10849-10943 HR-HZ 10995-11110 RECEIVED JUL - 5 '{99 Alaska OJJ & Gas Cons. Commissio~ Anchoraoe ATTACHMENT III MGS C44-14RD PROPOSED STATUS CONVERSION TO DISPOSAL WELL TOP JOB: 120 ex 'G' * 2% CaCl2 SPOTTED at 120' to SURFACE 24' CONDUCTOR at 370' ~ 13.3/8. SURFACE CASING at 2483' 61# J-56 BTC CEMENTED w/ 2350 cf 'G' * 10% GEL FOLLOWED BY 200 ex 'G' TOC at 6040'*/- PUMP 100 ex 'G' to ISOLATE 9-5/8' x ?' ANNULUS from DISPOSAL PERF$ PERMANENT PACKER at 6620'*/- ESTIMATED TOC at 6570' PERFORATE at 6730'*/- to CEMENT 9-8/8' x 7' ANNULUS DISPOSAL PERFORATIONS: 7248'-7328' (DK-DM SAND) SPOT 55 ex 'G' on top of BRIDGE PLUG SQUEEZED GR-GS PERF8 w/6.6 bbl 15.6 ppg CEMENT. TESTED TO 1000 psi w/NO LEAK OFF (10060'-10134'). FISH: CTU WASH NOZZLE on top of PX PLUG PX PLUG in 'X' NIPPLE at 10983' PBTD at 11287' 7' CEMENTED w/990 ex & ADDITIVES at 15.8 ppg RRW/C4414PPS.CHT ~/~_l~/a~~ T 0 C & t 973 O' * / - ~<~ ~/~'~'~'~]~ BRIDGE PLUG at 10030'*/- PERFORATIONS: 10060°-11110, 9-5/8' PROTECTIVE CASING at 6724' 0-4976' 40# N-80 BTC 4976'-6724' (WINDOW) 43.5# N-80 BTC CEMENTED w/122 sx 'G' at 15.6 ppg OTIS WD PACKER at 10267' _~ KBMG MANDREL w/DUMMY VALVE at 10622' ~ OTIS WD PACKER at 10970' ~.._ ~_~ EOT at 11001' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '.~ P O S S I B L E F I L L a t 11162' ~ ,~,~.~, ~:~(~ ::::::::::::::::::::::::::::::::::::::::::::::: ~ ~~¢&~~ 7' PRODUCTION CASING at 11398' 7989'-11398' 29~ N-80 BTC JUL - 5 199~ Alaska Oil & Gas Cons. 6ommissio[~ Anchoraqe Shell Western E&P Into 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Eebruary 18, 1991 Mr. Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Comm*is~i:6~ 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: UNDERGROUND DISPOSAL WELL APPLICATION, REVISIONS TO APPLICATION SUBMITTED JANUARY 21, 1991 Dear Mr. Smith: I would like to extend my thanks to you for taking;'~t~me last Wednesday to discuss the SWEPI application for a disposal well with Wayne Simpson and Susan Brown-Maunder of my staff, and Luke Franklin, a SWEPI consultant. This meeting was helpful in understanding what fluids are authorized for Class II disposal. As a result of these discussions, SWEPI has modified the proposed waste fluid list. Enclosed, find the revised pages 10 and 11, in triplicate. I believe you will find the revisions satisfactorily reflect the meeting discussions. Please direct any additional questions to either W.F. Simpson at (907) 263- 9645 or S. B. Brown-Maunder at (907) 263-9613. Manager Alaska Operations Alaska Division RGB/LCF/pck RECEIVED FEB 2 o 1991 021591 .LCF been included as Attachment D1 and D2 respectively. From the SWEPI operated portion of the field, there are no service wells completed for disposal of fluids into the Upper Tyonek formation. Any future injection wells to be drilled will be in accordance with 20 AAC 25.071.b. SECTION VII - CASING INFORMATION - 20 AAC 25.252.b - 20 AAC 25.252.c.6 Attachments E, F, G and H represent the casing and cementing detail for the presently suspended C44-14RD and the proposed disposal well, C44-14RD. Casing and cementing details for all wells that penetrate the injection zone within one-quarter mile have been included as Attachments I through M. The disposal well operation has been proposed in two phases; the upper disposal interval (BC-BG) will be utilized only after (if) the lower interval (CK-DM) is no longer serviceable. Attachments E and F show the casing and cementing detail for each phase. Additionally, well C44-14RD is in accordance with 20 AAC 25.030.c,e,g and 20 AAC 25.412.a,b,c,d,e. At no time will the production/liner casing be subjected to an annular pressure which would cause the casing hoop stress to exceed 70 percent of the minimum yield strength of the casing. Shell Western is requesting a variance to 20 AAC 25.030.d.3.c. which states that, for intermediate casing, "... in cases where zonal coverage is not required, a minimum fill-up of 500 feet of cement above the casing shoe is required." As indicated on Attachment G, we have only 150' of cement above the intermediate casing shoe. In consideration of our exempt aquifer status, we request an exception to the 500' requirement. In our completion of the lower disposal interval, we will limit the top of our perforation interval to 6720' to maximize the cement coverage. Also, a minimum of 500' of cement will be circulated into the 9-5/8" by 7" casing annulus above the proposed injection intervals. SECTION VIII - INJECTION FLUID PROPERTIES - 20 AAC 25.252.c.7 - 20 AAC 25.252.c.8 Underqround Disposal of Water and Other Oil Field Waste Fluids This disposal well will handle produced fluids, drilling/workover fluids, and other wastes associated with the operation of the Middle Ground Shoal (MGS) Field. The wastes that may be injected are listed below, or are specifically identified as Class II fluids in the EPA document "Evaluation of the Alaska Oil & Gas Conservation Commission Underground Injection Control Program." - Drilling/Workover Fluids o water o seawater o drilling muds and fluids (including oil-based muds) o CaCl2 or KC1 brine fluids o solvent-free rig washdown water ~ E C 10 Anchoracja ~ o completion fluids and diatomaceous earth as a filter media o workover fluids o well treatment fluids (eg. acid stimulations) - Other Oil Field Waste Fluids o produced water filter backwash o oily produced water and deck drainage o milled and fluidized oily silts, sands and gravels o tank bottoms and scale The total estimated annual volume of materials to be injected is 50,000 barrels, with a maximum daily rate of 2000 BPD. SECTION IX - FRACTURE INFORMATION - 20 AAC 25.252.c.9 - 20 AAC 25.252.c.ll The injection zone for produced/platform waste disposal may be hydraulically fractured because of the consistency of the fluids and the relatively low formation strengths involved. This would be accounted for in the design of the well and its location in the Upper Tyonek sands. The confining shales are the same as those described in Section V. There would be little or no risk of contamination of water zones adjacent to the injection zone. All water zones lying beneath the Middle Ground Shoal Field (to 1/4 mile area beyond) are exempt fresh water aquifers per 40 CFR 147.102.b.2.C. SECTION X - FORMATION WATER CHEMICAL ANALYSIS - 20 AAC 25.252.c.10 The zone to be used for disposal has had it's salinity calculated from wireline logs on eight wells. The salinity for the "BC" zone varies from 11,000 ppm to 20,000 ppm. This method uses the deep induction resistivity log and the density porosity log to calculate an apparent water resistivity from which a salinity can be determined if the temperature is known. SECTION XI - APPLICABLE FRESH WATER EXEMPTIONS - 20 AAC 25.402.c.ll The USEPA, under 40 CFR 147.102.b.2.C, designated any portion of a freshwater aquifer beneath Cook Inlet described by a quarter mile area beyond and lying directly below the Middle Ground Shoal Field as an exempt aquifer, and the AOGCC accepted this designation in 20 AAC 25.440(c). SECTION XII - MECHANICAL INTEGRITY - AIO #9, Rule 6 (para a, AIO #9.3A) 20 AAC 25.252.d and e All wells drilled by SWEPI at MGS will be in accordance with 20 AAC 25.030.c,g and at no time will the casing/tubing annulus be subjected to a 11 been included as Attachment D1 and D2 respectively. From the SWEPI operated portion of the field, there are no service wells completed for disposal of fluids into the Upper Tyonek formation. Any future injection wells to be drilled will be in accordance with 20 AAC 25.071.b. SECTION VII - CASING INFORMATION - 20 AAC 25.252.b - 20 AAC 25.252.c.6 Attachments E, F, G and H represent the casing and cementing detail for the presently suspended C44-14RD and the proposed disposal well, C44-14RD. Casing and cementing details for all wells that penetrate the injection zone within one-quarter mile have been included as Attachments I through M. The disposal well operation has been proposed in two phases; the upper disposal interval (BC-BG) will be utilized only after (if) the lower interval (CK-DM) is no longer serviceable. Attachments E and F show the casing and cementing detail for each phase. Additionally, well C44-14RD is in accordance with 20 AAC 25.030.c,e,g and 20 AAC 25.412.a,b,c,d,e. At no time will the production/liner casing be subjected to an annular pressure which would cause the casing hoop stress to exceed 70 percent of the minimum yield strength of the casing. Shell Western is requesting a variance to 20 AAC 25.030.d.3.c. which states that, for intermediate 1casing'up ~f" required, a minimum fil 50~" in cases where zonal coverage is not - feet of cement above the casing shoe is required." As indicated on Attachment G, we have only 150' of cement above the intermediate casing shoe. In consideration of our exempt aquifer status, we request an exception to the 500' requirement. In our completion of the lower disposal interval, we will limit the top of our perforation interval to 6720' to maximize the cement coverage. Also, a minimum of 500' of cement will be circulated into the 9-5/8" by 7" casing annulus above the proposed injection intervals. SECTION VIII - INJECTION FLUID PROPERTIES - 20 AAC 25.252.c.7 - 20 AAC 25.252.c.8 Underqround Disposal of Water and Other Oil Field Waste Fluids This disposal well will handle produced fluids, drilling/workover fluids, and other wastes associated with the operation of the Middle Ground Shoal (MGS) Field. The wastes that may be injected are listed below, or are specifically identified as Class II fluids in the EPA document "Evaluation of the Alaska Oil & Gas Conservation Commission Underground Injection Control Program." - Drilling/Workover Fluids o water o seawater o drilling muds and fluids (including oil-based muds) o CaC12 or KC1 brine fluids o solvent-free rig washdown water i~ E C E' JV 10 F.EE~ 2 o Gas Cons. Comm..issiO~ ~,-~chora~e o completion fluids and diatomaceous earth as a filter media o workover fluids o well treatment fluids (eg. acid stimulations) - Other Oil Field Waste Fluids o produced water filter backwash o oily produced water and deck drainage o milled and fluidized oily silts, sands and gravels o tank bottoms and scale The total estimated annual volume of materials to be injected is 50,000 barrels, with a maximum daily rate of 2000 BPD. SECTION IX - FRACTURE INFORMATION - 20 AAC 25.252.c.9 - 20 AAC 25.252.c.ll The injection zone for produced/platform waste disposal may be hydraulically fractured because of the consistency of the fluids and the relatively low formation strengths involved. This would be accounted for in the design of the well and its location in the Upper Tyonek sands. The confining shales are the same as those described in Section V. There would be little or no risk of contamination of water zones adjacent to the injection zone. All water zones lying beneath the Middle Ground Shoal Field (to 1/4 mile area beyond) are exempt fresh water aquifers per 40 CFR 147.102.b.2.C. SECTION X - FORMATION WATER CHEMICAL ANALYSIS - 20 AAC 25.252.c.10 The zone to be used for disposal has had it's salinity calculated from wireline logs on eight wells. The salinity for the "BC" zone varies from 11,000 ppm to 20,000 ppm. This method uses the deep induction resistivity log and the density porosity log to calculate an apparent water resistivity from which a salinity can be determined if the temperature is known. SECTION XI - APPLICABLE FRESH WATER EXEMPTIONS - 20 AAC 25.402.c.ll The USEPA, under 40 CFR 147.102.b.2.C, designated any portion of a freshwater aquifer beneath Cook Inlet described by a quarter mile area beyond and lying directly below the Middle Ground Shoal Field as an exempt aquifer, and the AOGCC accepted this designation in 20 AAC 25.440(c). SECTION XII - MECHANICAL INTEGRITY - AIO #9, Rule 6 (para a, AIO #9.3A) 20 AAC 25.252.d and e All wells drilled by SWEPI at MGS will be in accordance with 20 AAC 25.030.c,g and at no time will the casing/tubing annulus be subjected to a 11 been included as Attachment D1 and D2 respectively. From the SWEPI operated portion of the field, there are no service wells completed for disposal of fluids into the Upper Tyonek formation. Any future injection wells to be drilled will be in accordance with 20 AAC 25.071.b. SECTION VII - CASING INFORMATION - 20 AAC 25.252.b - 20 AAC 25.252.c.6 Attachments E, F, G and H represent the casing and cementing detail for the presently suspended C44-14RD and the proposed disposal well, C44-14RD. Casing and cementing details for all wells that penetrate the injection zone within one-quarter mile have been included as Attachments I through M. The disposal well operation has been proposed in two phases; the upper disposal interval (BC-BG) will be utilized only after (if) the lower interval (CK-DM) is no longer serviceable. Attachments E and F show the casing and cementing detail for each phase. Additionally, well C44-14RD is in accordance with 20 AAC 25.030.c,e,g and 20 AAC 25.412.a,b,c,d,e. At no time will the production/liner casing be subjected to an annular pressure which would cause the casing hoop stress to exceed 70 percent of the minimum yield strength of the casing. Shell Western is requesting a variance to 20 AAC 25.030.d.3.c. which states that, for intermediate casing2" . in cases where zonal coverage is not required, a minimum fill-upu, 50~'feet of cement above the casing shoe is required." As indicated on Attachment G, we have only 150~ of cement above the intermediate casing shoe. In consideration of our exempt aquifer status, we request an exception to the 500~ requirement. In our completion of the lower disposal interval, we will limit the top of our perforation interval to 6720' to maximize the cement coverage. Also, a minimum of 500~ of cement will be circulated into the 9-5/8" by 7" casing annulus above the proposed injection intervals. SECTION VIII - INJECTION FLUID PROPERTIES - 20 AAC 25.252.c.7 - 20 AAC 25.252.c.8 Underqround Disposal of Water and Other Oil Field Waste Fluids This disposal well will handle produced fluids, drilling/workover fluids, and other wastes associated with the operation of the Middle Ground Shoal (MGS) Field. The wastes that may be injected are listed below, or are specifically identified as Class II fluids in the EPA document "Evaluation of the Alaska Oil & Gas Conservation Commission Underground Injection Control Program." - Drilling/Workover Fluids o water o seawater o drilling muds and fluids (including oil-based muds) o CaC12 or KC1 brine fluids o solvent-free rig washdown water 10 completion fluids and diatomaceous earth as a filter media workover fl uids well treatment fluids (eg. acid stimulations) - Other Oil Field Waste Fluids o produced water filter backwash o oily produced water and deck drainage o milled and fluidized oily silts, sands and gravels o tank bottoms and scale The total estimated annual volume of materials to be injected is 50,000 barrels, with a maximum daily rate of 2000 BPD. SECTION IX - FRACTURE INFORMATION - 20 AAC 25.252.c.9 - 20 AAC 25. 252.c. 11 The injection zone for produced/platform waste disposal may be hydraulically fractured because of the consistency of the fluids and the relatively low formation strengths involved. This would be accounted for in the design of the well and its location in the Upper Tyonek sands. The confining shales are the same as those described in Section V. There would be little or no risk of contamination of water zones adjacent to the injection zone. All water zones lying beneath the Middle Ground Shoal Field (to 1/4 mile area beyond) are exempt fresh water aquifers per 40 CFR 147.102.b.2.C. SECTION X - FORMATION WATER CHEMICAL ANALYSIS - 20 AAC 25.252.c.10 The zone to be used for disposal has had it's salinity calculated from wireline logs on eight wells. The salinity for the "BC" zone varies from 11,000 ppm to 20,000 ppm. This method uses the deep induction resistivity log and the density porosity log to calculate an apparent water resistivity from which a salinity can be determined if the temperature is known. SECTION XI - APPLICABLE FRESH WATER EXEMPTIONS - 20 AAC 25.402.c.ll The USEPA, under 40 CFR 147.102.b.2.C, designated any portion of a freshwater aquifer beneath Cook Inlet described by a quarter mile area beyond and lying directly below the Middle Ground Shoal Field as an exempt aquifer, and the AOGCC accepted this designation in 20 AAC 25.440(c). SECTION XII - MECHANICAL INTEGRITY - AIO #9, Rule 6 (para a, AIO #9.3A) 20 AAC 25.252.d and e All wells drilled by SWEPI at MGS will be in accordance with 20 AAC 25.030.c,g and at no time will the casing/tubing annulus be subjected to a 11 I i I I i ~ ! WELL I I 27 Attachment B LOCATIONS OF WELLS / WITHIN 1/4 MILE C44-1~RD C~44-14 / ~ ~34-t4D C3]-23 C21-23 C12-23 C32.-2.: C23-23 Z-23 / / C43-23 -8915 :22A-26 621-26 C22-26 C22-26R / / / / / / / / C43-14 . ( , ( Shell Western E&P Ine. ~ r/ 601 West Fifth Avenue. Suite 800 Anchorage, Alaska 99501 January 21, 1991 1.[,,1 ¡ ~,/$3l~vtA ~ 1- -I '$ -q¡ f" 1'-</;,' '""""¡: I ,\ n . ",,>i!.ì CA.'7c" l...,:5 í h {c j/Þ ' -re- \j'. \ U / D 'Š ì II , j (tIC) /' , ,. c/ ~," -"(,{ R Q,~":""-.Q.. k Vl S h-,." S 2.- 2,0 -'11 Mr. Lonnie Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Underground Disposal Well Application Dear Mr. Smith: She 11 Western E&P Inc. (SWEPI) is request i ng your approval to inject and dispose of fluids underground through well C44-14RD in the Middle Ground Shoal (MGS) Field. The conversion of well C44-14RD as a disposal well is provided for in Rule 2 of Area Injection Order No.9. Section I~, Injection Fluid Properties, details the wastes the disposal well will handle. Shell Western is also requesting a variance to 20 AAC 25.030.d.3.c as provided for in 20 AAC 25.450.a and described in Section VII, Casing Information, of the Disposal Well Application. Enclosed in triplicate is an Application for Sundry Approvals (Form 10-403) and a completed underground Disposal Well Application with necessary attachments. Please direct any questions you may have or requests for additional information to Susan B. Brown-Maunder of my staff at (gO?) ß¡""~~õrj~ 2.. :çh Sincerely, ~~ R. G. B ackburn Manager Alaska Operations Alaska Division ~ \JP-O70290.lCF R'IE8IVID JAN 2 5 1991 ~~=.... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing ~ Repair well Change approved program __ 2. NameofOpermor Shell Western E&P Inc. 3. Addre~ 601W. 5th Ave., Suite 800, 4. Location of well at surface and 1542' W of NE At top of productive interval N/A At effective depth Platform C, corner of Operation shutdown ~ Re-enter suspended well m Pluggingm Time extension __ Stimulate ~ Pull tubing m Variance __ Pedorate ~ Other 5. Type of Well: Development __ Exploratory ~ Stratigraphic ~ Anchorage, AK 99501 Service._~.x Leg 4, Conductor 31, 4779' S Section 23, TSN, R13N, S.M. At total depth 12. Present well condition summary Total depth: measured true vertical 11,398 feet Plugs (measured) feet 6. Datum elevation (DF or KB) KB 105 feet 7. Unit or Property name Middle Ground Shoal 8. Well number C44-14RD 9. Permit number 77-79 10. APl number 50-- 133-20252-01 11. Field/Pool Middle Ground Shoal/"G" Poo Effective depth: measured 7,5 0 0 true vertical feet Junk (measured) feet Casing Length Structural Size Cemented Measured depth True vertical depth Conductor Surface 2,483' Intermediate 6,724 13-3/8", 61#, J-55, 2170 sx 2,183' 9-5/8", 43.5-47#, N-80, 122 sx 6,724' Production Liner 11,3 98' 7 ", Perforation depth: measured 10,059' - 11,112' true vertical 26-29#, N80, 990 sx 11,398' RECEIVED 8,292' - 9,161' Tubing (size, grade, and measured depth) 2-7/8:, 6.5#, N-80, Packers and SSSV (type and measured depth) Unipacker VII 7" JAN 25 1991 EUE @ 10,045' ~las~Oj/&.6asCons..C.~mBlss{I)~ 10,199' Description summary of proposal ~ Detailed operations program __ BOP sketch __ Disposal Nell Application 13. Attachments Underground 14. Estimated date for commencing operation MARCH 15, 1991 16. If proposal was verbally approved N/A Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended X__ ( e x i s t i n g ) Service Underqround Disposal Wel 1 (Proposal) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title Manager, A1 aska '-~ FOR COMMISSION USE ONLY Operations Date January 21, 19' Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BqP~ Test ~ Location clearance ~ Mechanical Integrity Test/¢~ Subsequent form required 10- /-~s' r-~:~,~o~ I~-~--,- /-~2~'> I,~- '~/t .,,.,. -z.~z~.-~r~ 0RIGIN~L SIGNED BY Approved by order of the Commission LONN IE C. SMITH Fnrm lf~.4f~.cl FIc. v ¢)R/1R/RR Commissioner Date SUBMIT IN TRIPLICATE Shell Western E&P Inc.Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 January 21, 1991 Mr. Ray M. Barnds Regional Vice President Unocal Corporation Western Region Oil & Gas Exploration 909 W. 9th Avenue Anchorage, Alaska 99519-0247 SUBJECT: UNDERGROUND DISPOSAL WELL APPLCIATION PLATFORM C, MIDDLE GROUND SHOAL Dear Mr. Barnds: Shell Western E&P Inc. (SWEPI) has requested an approval from the Alaska Oil and Gas Conservation Commission to inject and dispose of fluids underground through well C44-14RD in the Middle Ground Shoal (MGS) field. SWEPI has enclosed a copy of the above referenced application to Unocal Corporation as operator notification required by 20 AAC 25.252.c.3. Please direct any questions you may have to Susan B. Brown-Maunder of my staff at (907) 263-9613. W. F. Simpson WFS/LCF/pck cc: Lonni e Smi th, AOGCC 070290. LCF R:ECEiVED IAN 25 ]99! ~./-~.OJJ & Gas Cons. "' ~chora~ Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 January 21, 1991 Mr. Gary Gustafson, Director Division of Land and Water Management Department of Natural Resources State of Alaska P.O. Box 107005 Anchorage, Alaska 99510-7005 SUBJECT: UNDERGROUND DISPOSAL WELL APPLCIATION PLATFORM C, MIDDLE GROUND SHOAL Dear Mr. Gustafson- Shell Western E&P Inc. (SWEPI) has requested an approval from the Alaska Oil and Gas Conservation Commission to inject and dispose of fluids underground through well C44-14RD in the Middle Ground Shoal (MGS) field. SWEPI has enclosed a copy of the above referenced application to ADNR, surface owner, as the notification required by 20 AAC 25.252.c.3. Please direct any questions you may have to Susan B. Brown-Maunder of my staff at (907) 263-9613. W. F. Simpson WFS/LCF/pck cc' Lonnie Smith, AOGCC 070290. LCF RECEIVED ,JAN 2 5 1991 ~.~il & Gas Cons, ~ ~ ~10h0m~ UNDERGROUND DISPOSAL WELL APPLICATION Submitted By Shell Western E&P Inc. 601 W. Fifth Avenue, Suite 800 Anchorage, Alaska 99501 RECEIVED JAN 2 5 ]991 ~~ Gas Cons. Commissip~ . UNDERGROUND DISPOSAL WELL APPLICATION GENERAL INFORMATION JANUARY 1991 Subject' Underground Disposal Well Application Submitted To' Alaska Oil & Gas Conservation Commission Facility Name and Location- Shell Western E&P Inc. Middle Ground Shoal P1 atform C Cook Inlet, Alaska Operator Name and Mailing Address' Shell Western E&P Inc. 601 W. 5th Avenue, Suite 800 Anchorage, Alaska 99501 Technical Contact' Susan Brown-Maunder (907) 263-9613 070290. LCF RECEIVED DISPOSAL WELL APPROVAL REQUEST MIDDLE GROUND SHOAL UNIT TABLE OF CONTENTS SECTION III VI VII I Injection Order Requirements II Operators/Surface Owners Affidavit IV Description of Operation V Geological Information Well Logs Casing Information VIII IX X XI XlI XIII XIV XV Injection Fluid Properties Fracture Information Formation Water Analysis Fresh Water Exemptions Mechanical Integrity Wells Within Area of Injection Completion Records REGULATORY CITE 20 AAC 25.252.c.1 20 AAC 25.460.a 20 AAC 25. 252.c.2 20 AAC 25.252.c.3 20 AAC 25.402.c.4 20 AAC 25.252.c.4 20 AAC 25.252.c.5 20 AAC 25.252.b 20 AAC 25.252.c.6 20 AAC 25.252.c.7 20 AAC 25.252.c.8 20 AAC 25.252.c.9 20 AAC 25.252.c.10 20 AAC 25.402.c.12 20 AAC 25.252.c.ll 20 AAC 25.252.d 20 AAC 25.252.e 20 AAC 25.252.h 20 AAC 25. 252.c.8 20 AAC 25.412.d 20 AAC 25.43O PAGE 6 8 8 9 10 10 11 11 11 11 12 12 12 ADDENDUMS AND ATTACHMENTS TABLE OF CONTENTS ATTACHMENT A ATTACHMENT B ATTACHMENT C ATTACHMENT D1 ATTACHMENT D2 ATTACHMENT E ATTACHMENT F ATTACHMENT G ATTACHMENT H ATTACHMENT I ATTACHMENT J ATTACHMENT K ATTACHMENT L ATTACHMENT M Development Map Location Plat Waste Disposal Zones Well Log (C44-14) Well Log (C44-14RD) Casing and Cementing Detail (Casing Description) Casing and Cementing Detail (C44-14RD -existing) Casing and Cementing Detail (C44-14RD -Phase one injection) Casing and Cementing Detail (C44-14RD -Phase two injection) Casing and Cementing Detail (C31-23) Casing and Cementing Detail (C41-23) Casing and Cementing Detail (C42-23) Casing and Cementing Detail (C43-14) Casing and Cementing Detail (C43-23) SECTION I - INJECTION ORDER - 20 AAC 25.460.a - 20 AAC 25.252.c.1 As provided for in Area Injection Order No. 9, Rule 2, Shell Western E&P Inc. (SWEPI), requests approval to inject and dispose of fluids underground through well C44-14RD in that portion of the Middle Ground Shoal (MGS) Field for which SWEPI is designated operator. The injection operations meet the following requirements of 20 AAC 25.460.a, Area Injection Order: Table I lists and describes all of the existing wells, grouped together by type of service. ° All of the wells are within the same fi eld. ° This portion of the field is operated by a single operator. Fluid injection into the Upper Tyonek non-productive saline sands would be for the purpose of disposal of approved oil field materials. Attachment A, Development Map, identifies the MGS well locations, including the proposed disposal well. Attachment B, Location Plat, depicts the well locations of wells that penetrate the injection zone within one-quarter mile. Existing orders - State of Alaska Conservation Order #44 was issued July 19, 1967, authorizing enhanced recovery injection system use in the MGS field. Area Injection Order No. 9 was issued September 12, 1986. Existing exemption - Federal regulations (40 CFR 147.102.b.2.C) satisfy the State requirements for freshwater aquifer exemption as specified in 20 AAC 25.440.c. for any portion of aquifers lying beneath the Middle Ground Shoal Field (to 1/4 mile area beyond). RECEIVED JAN 25 Alaska Oil & Gas Cons. 1 lill { SECTION II - OPERATORS/SURFACE OWNERS - 20 AAC 25.252.c.2 The surface owner and operators within 1/4 mile radius of any existing or planned injection well are the owners/operators of the MGS Field. There is one operating injection well within 1/4 mile of the SWEPI operated lease lines. This is well 8-12 operated by Unocal. The surface owner is the State of Alaska, Department of Natural Resources. The operator, other than SWEPI, in the Middle Ground Shoal Field, is Unocal Corporation. SECTION III - AFFIDAVIT - 20 AAC 25.252.c.3 See attached affidavit. 6 !( \ AFFIDAVIT STATE OF ALASKA ) ) ) ss. Third Judicial District R. G. Blackburn, being first duly sworn on oath, deposes and says: That I am an employee of Shell Western E&P Inc. That on the 21st day of January, 1991, I caused to be mailed a true and correct copy of this application to the following operators and surface owners listed in Section I I: Unocal Corporation State of Alaska, Department of Natural Resources By placing said copy in the United States mail with postage prepaid and certified at Anchorage, Alaska. /~~~ R. G. ackburn SUBSCRI BED AND SWORN to before me on th is ¿,.l day of OFFICiAL seAL STATE OF ALASKA PEGGY C. KELLY NOTARY PUBLIC My Comm. Expires: July 25, 1993 dl¥l.\<.J Av \- 1991. Q~ c. ~ Notary Public in and for Alaska My Commission Expires: 7--2~-?3 ."""i-"':""'::"""~ ~",:~"~~,,,^, 7 ~ ,l \ SECTION IV - DESCRIPTION OF OPERATION - 20 AAC 25.402.c.4 The Middle Ground Shoal (MGS) field is located in the Cook Inlet Basin approximately 60 miles southwest of Anchorage. The central portion of the fi e 1 d has two drill i ng and producti on platforms (" A" and II C ") located in water about 100' deep. Both of the plat forms are four 1 eg tower type platforms, with the well conductors located inside of the towers to provide protect i on from i ce movement and the extreme water currents seen in the Inlet. An 8" pipeline carries approximately 3000 BOPD from Platform "C" to Pl at form" A II wi th the 1 atter currently produc i ng approxi mate 1 y 3000 BOPD. This production is then shipped to the beach via an 8" underground pipeline to the production facility located near Nikiski. Since the first well was completed in 1965, the SWEPI operated portion of the field has produced 1.lmm bbls of oil (as of June, 1990). Primary development was completed in mid-1969 with the completion of 33 wells. By this time, a rapid decline in reservoir pressure had become evi dent. Because of thi s, pressure mai ntenance by water inject i on was i ni ti ated in 1969 by convert i ng producers to water injectors. Presently, Platforms "A" and "C" have 33 producing wells, 13 injection wells and 2 wells being prepared for completion. Shell Western proposes to convert well C44- 14RD (Production well, presently suspended) to a disposal well for the injection and disposal of approved oil field materials. SECTION V - GEOLOGICAL INFORMATION - 20 AAC 25.252.c.4 OIL POOL DESCRIPTION The MGS field produces from sandstones and conglomerates of the lower Tyonek formation of Miocene - Oligocene age. The gross interval of approximately 2800' is found at depths of 5200' to 9800' subsea. The productive members are interbedded with siltstones, conglomeratic sands, shales, and coal that were deposited in a braided stream environment. WASTE DISPOSAL ZONE DESCRIPTION SWEPI OPERATED PORTION OF MIDDLE GROUND SHOAL FIELD The sand unit identified as "BC" and defined as occurring between 3134' and 3205' (measured depth) in the Shell Western - MGS A42-11 well is the upper- most section of the selected disposal zone. The selected disposal zone extends through the BG sands to a measured depth of 3480 feet. The top of the BC sands unit in well A42-11 is calculated to be at 3012' true vertical subsea. It appears to be a single depositional unit at least sixty-five feet th i ck wh i ch is cont i nuous over a wi de area. Litho log i ca 11 y, i t i s a conglomeratic sandstone described as variable in color, hard to firm, with fine to coarse subangular to subrounded grains. Some calcareous cement is found. The grain sorting is poor to fair. Some mica, clay material, and chert are included in the sediment. 8 i !~, ,t The general anticlinal structure of the productive zones in this accumulation persists at shallower depths and provides the trap for the disposal zone. The top confining zone is provided by a sixty-plus foot interval of interbedded soft claystone, carbonaceous shale, coal, and tight, argillaceous s i 1 tstone wh i ch appears to everywhere overl i e the" BC" sand. The bottom confining zone consists of seventy or more feet of similar material. The seal is further demonstrated by the different log responses in the 118C" compared to the overlying sediments. This is thought to result from a contrast in the salinities of the respective formation waters. Attachment C, Waste Disposal Zones, depicts the correlation between well A42-11 and the requested disposal well C44-14RD. The lower selected i nterva 1 occurs between 4680 and 5283 feet (measured depth) in the Shell, et al-MGS A42-11 well and is correlated locally as the interval between the Tyonek "CK" and "DM" markers. The top of the interval i n A42 -11 is ca 1 cul ated to be at 4509 feet true vert i ca 1 subsea. The i nterva 1 contai ns two sandstone depos it i ona 1 uni ts, each about 100 feet thick, which appear continuous over a wide area. Lithologically, they are very fine to coarse grained, partly conglomeratic sandstones described as variable in color and firm with clay, mica, coal fragments and chert in the matrix and some calcareous cement. The interval also contains several other sand lenses, ten to thirty feet thick of similar description. Table 1, Disposal Zone Correlation, shows the correlation between wells A42-11 and C44-14RD. The general anti c 1 i na 1 nature of the fi e 1 d's producti ve zones persi sts at these shallower depths and provides the trap for the disposal zones. Each of the two main sands is bounded and sealed by at least 120 foot thick intervals of interbedded impermeable argillaceous siltstones and coal beds. Table 1 DISPOSAL ZONE CORRELATION A42-11 (TYPE WELLt 3134 (BC) 3480 (BASE BG SDS) C44-14RD * 4680 (TOP CK SD) 5283 (DM) 4718 5168 6633 7278 * THE Kick Off Point FOR C44-14RD (i.e. SIDETRACK FROM C44-14) WAS 6720 FEET. (All Depths are M.D. Feet) SECTION VI - WELL LOGS - 20 AAC 25.252.c.5 Logs for all 13 enhanced recovery injectors are on file with the AOGCC. The dual induction-laterologs for C44-14 and the subject areas of C44-14RD have 9 ~' " '\ been included as Attachment Dl and D2 respectively. From the SWEPI operated portion of the field, there are no service wells completed for disposal of fluids into the Upper Tyonek formation. Any future injection wells to be drilled will be in accordance with 20 AAC 25.071.b. SECTION VII - CASING INFORMATION - 20 AAC 25.252.b - 20 AAC 25.252.c.6 Attachments E, F, G and H represent the casing and cementing detail for the presently suspended C44-14RD and the proposed disposal well, C44-14RD. Casing and cementing details for all wells that penetrate the injection zone within one-quarter mile have been included as Attachments I through M. The disposal well operation has been proposed in two phases; the upper disposal interval (BC-BG) will be utilized only after (if) the lower interval (CK-DM) is no longer serviceable. Attachments E and F show the casing and cementing detail for each phase. Additionally, well C44-14RD is in accordance with 20 AAC 25.030.c,e,g and 20 AAC 25.412.a,b,c,d,e. At no time will the production/liner casing be subjected to an annular pressure which would cause the casing hoop stress to exceed 70 percent of the minimum yield strength of the casing. Shell Western is requesting a variance to 20 AAC 25.030.d.3.c. which states that, fori ntermed i ate cas i ng, "... i n cases where zonal coverage i s not required, a minimum fill-up of 500 feet of cement above the casing shoe is required." As indicated on Attachment G, we have only 150' of cement above the intermediate casing shoe. In consideration of our exempt aquifer status, we request an exception to the 500' requirement. In our completion of the lower disposal interval, we will limit the top of our perforation interval to 6720' to maximize the cement coverage. Also, a minimum of 500' of cement will be circulated into the 9-5/8" by 7" casing annulus above the proposed injection intervals. SECTION VIII - INJECTION FLUID PROPERTIES - 20 AAC 25.252.c.7 - 20 AAC 25.252.c.8 Underqround Disposal of Water and Other Oil Field Waste Fluids This disposal well will handle produced fluids, drilling/workover fluids, and other wastes associated with the operation of the Middle Ground Shoal (MGS) Field. The wastes that may be injected are, b,~~__~?~----~,._~-~~_!~q.,tQ;_. -- l-1-Ô - Drilling/Workover Fluids v 0 > 0 0 \/ 0 V 0 V 0 water seawater sewage water drilling muds and fluids (including CaC12 or KCl brine fluid~ . \ rig washdown water ("",0 ")""(\'-~"'::\'~,) oil-based muds) 10 I"~ \. ,( ~' '" ) D (' - 'e ¡"-f v ¡ ";; -p. .;êX t c- ),>-/ <rf-.." -) .... " ,I ~ ,~ ~ 'I \ 0 0 0 ,/~" L t completion fluids and filter 'media workover fluids well treatment fluids (eg. acid stimulations) - Other Oil Field Waste Fluids V'o 0 v' 0 V 0 produced water filter backwash oily produced water and other oily waters - milled and fluidized oily silts, sands and tank bottoms and scale ,. waste crankcase and lubrication oils ~ ; '--:; .-:::: ,.,'c ( .-- g r a vel s .;~~ .',' h~: - 0 The total est i mated annual volume of materi a 1 s to be i nj ected is 50,000 barrels, with a maximum daily rate of 2000 BPD. SECTION IX - FRACTURE INFORMATION - 20 AAC 25.252.c.9 - 20 AAC 25.252.c.11 The injection zone for produced/platform waste disposal may be hydraulically fractured because of the consistency of the fluids and the relatively low formation strengths involved. This would be accounted for in the design of the well and its location in the Upper Tyonek sands. The confining shales are the same as those described in Section V. There would be little or no risk of contamination of water zones adjacent to the injection zone. All water zones lying beneath the Middle Ground Shoal Field (to 1/4 mile area beyond) are exempt fresh water aquifers per 40 CFR 147.102.b.2.C. SECTION X - FORMATION WATER CHEMICAL ANALYSIS - 20 AAC 25.252.c.l0 The zone to be used for d i sposa 1 has had it's sa 1 in i ty ca 1 cul ated from wireline logs on eight wells. The salinity for the "BC" zone varies from 11,000 ppm to 20,000 ppm. This method uses the deep induction resistivity log and the density porosity log to calculate an apparent water resistivity from which a salinity can be determined if the temperature is known. SECTION XI - APPLICABLE FRESH WATER EXEMPTIONS - 20 AAC 25.402.c.11 The USEPA, under 40 CFR 147.102.b.2.C, designated any portion of a freshwater aquifer beneath Cook Inlet described by a quarter mile area beyond and lying directly below the Middle Ground Shoal Field as an exempt aquifer, and the AOGCC accepted this designation in 20 AAC 25.440(c). A } D ~ll q' R üJJ i~ (i, ~.- øirt:.l¡ /\) t/~:': '.~ " /\ SECTION XII - MECHANICAL INTEGRITY - 20 AAC 25.252.d and e . All well s dri 11 ed by SWEP I at MGS wi 11 be in accordance wi th 20 AAC 25.030.c,e and at no time will the casing/tubing annulus be subjected to a r') ~. 11 ¡¡ "" II c--' - . '~\¡\'~U:'\ ')t;)<:~'¡.."\,, :>"'" ~ (/~c::..) ;' ò ~' '" pressure that would cause the casing hoop stress to exceed 70 percent of the minimum yield strength of the casing. SECTION XIII - WELLS WITHIN AREA OF INJECTION - 20 AAC 25.252.h Existing producing, injecting and abandoned wells that have penetrated the di sposa 1 inject i on zone wi thi none-quarter mi 1 e of C44-14RD are shown on Attachment B. To the best of SWEPI's knowledge, all of these wells were drilled, cased, cemented, (or abandoned) in accordance with 20 AAC 25.030.c,e. or 20 AAC 25.105.b,e,f,h-k. Because of this, we would expect no communication between zones. Additionally, refer to Section XI for the fresh water exemption. SECTION XIV - METHOD OF COMPLETION - 20 AAC 24.252.c.8 - 20 AAC 25.412.d The standard tubing to be used is 3-1/2" J-55 7.7# EUE tubing with a burst rating of 5940 psi. Our maximum injection pressure would be 4300 psi, or 25 percent less than the rated burst pressure for the 9-5/8" casing in place. The tubing, with a 1.33 safety factor, is rated to 4466 psi. SECTION XV - RECORDS - 20 AAC 25.430 Individual well records on injector wells showing volumes and tubing/casing pressures are cont i nua 11 y mai nta i ned for all well sin MGS. These are reported on a monthly basis (form 10-406) and are available for inspection at any time. 12 I( { Attachment C WASTE DISPOSAL ZONES Correlation Between A42-11 & C44-14RD A42-11 (As approved by Rule 2 of AID No.9) C44-14RD (As requested) -------- -\ Upper 3134t-3480t \ \ Disposal , ------- \ Interval \ \ \ BC-BG \ \ \ \ \ \ , \ \ \ , \ , \ \ \ \ ------- \ , \ , '------- 4680'-5283t \ \ \ \ 4718'-5168' \ \ - ----\ \ \ '---------- \ \ \ \ \ Lower \ \ \ Disposal \ \ \ Interval \ \ \ CK -DM \ \ \ \ \ \ \ , \ , \ \ '------ - \ \ 6633'-7278t \ '--------- RECElvm:o JAN 2 L) ] 991 I41f'~r;" n:l .. , ~~;~~Y) .& Gas Cons. Commission .~"'¡., !änchoraga 12/21/90 It .~, ATTACHMENT E C44-14RD CASING AND CEMENTING DETAIL SURFACE CAS~(13-3/8") reused from C44-14; CASING: CEMENT: SPACER: 2483', 13-3/8", 61#, J-55, BTC 2350 cf Class "G" + 10% gel (12.8 ppg) followed by 200 sx Class "G". Mixed with sea water. Had 50 cf of cement returns but found top of cement in annulus at 120'. 17.8 bbls water TOP JOB: 120 sx Class "G" + 2% CaC12. Pumped at 120'. Mi xed wi th sea water. ~E CASI.JiL{9-5/8") reused from C44-14.; CASING: CEMENT: SPACER: 6724', 9-5/8", 40 & 43.5#, N-80 122 sx Class "G" (15.6 ppg). Estimated cement top at 6570'. 15 bbls water PRODUCTION CASING 7" ; CASING: CEMENT: SPACER: 11398', 7", (11398-7989, 29#; 7989-0, 26#) N-80, BTC 990 sx Class "G" cement +0.75% D-31 + 0.3% D-19 + 0.1% D-6 (15.8 ppg, 1.14 cf/sk). Displaced 8 BPM. 10 bbls water R)'B"':"€"""E"~" :. """i,:","",I"I".,V:,','E, D I. '" '.!' " ' , . ,. I J/\1\1 251991 1!.~l-)sk ','4 a Oil & G\ as Cons.C~$JQb Anchoraga ".~'~' ,',:' , ,i { Attachment F C44-14RD { CASING & CEMENTING DE-~. ..¿.. 13-3/88 SURFACE CSG at 2483' . 9-5/8. PROTECTIVE CSG at 6724' .:.~.,?'tTOP JOB 0-120' . . TOC at 120' Upper Disposal Interval BC-BG 4718-5168' Toe at 6570' Lower Disposal Interval CK-DM 6633-7278' Q;~ Estimated TOC at 8000' '. . 78 PRODUCTION CSG at 11 ,398' ~~. ~~~~¡.~~~~1. : TOC at 11,300' 1/21/91 DF-600-276-90 Attachment G PHASE ONE INJECTION( C44-14RD CASING & CEMENTING DETAIL ~ )J ':0:: TOP JOB 0-120' ::d . TOC at 120' ( 13~3/8. SURFACE CSG at 2483' PLAN 1) P&A well below 7500' 2) Set bridge plug at 7500' 3) Perforate at 6720' 4) Cement from 6720-6220' 5) Test cement in annulus 6) Perforate as reQuired 6720- 7 2 78' 7) Inject as reQuired; monitor 78 by 9-5/88 annulus pressure during aff injection activity 9-5/88 PROTECTIVE CSG at 6724 I 78 PRODUCTION CSG at 11.398' h\i . ie" I I P&A : Upper Disposal Interval BC-BG 4718-5168' TOC at 6220' TOC at 6570' Lower Disposal Interval CK-DM 6633-~7-a,1'7 ~~) ;::tç' .I PERFORATE 6 720-.J-2.7-8-' 7 ~ 'z.f;"' BRIDGE PLUG at 7500' t,,;:\') I ~:--."" !"\ '\ <ê" cO' I "7 ( 1~:)" Estimated TOC at 8000' , \ "i,. ... .' '<' RECEIVE JAN D ~~~~t4.. .~. 25 I991 ...,...¡"""Q¡}.IIt f't.!:Jrt" .:~~" '~~"',uons. Ci . ,lfQc4oraua, ~ml1JI$$lgl1t . . TOC at 11.300' 1/21/91 DF-600-276-90 ( Attachment H PHASE TWO INJECTIO~' C44-14RD CASING & CEMENTING DETAIL <J1~~,"'~TOP JOB 0-120' TOC at 120' 13-3/88 SURFACE CSG at 2483' PLAN 1) Cut & pull 78 to 6200' 2) Cement from 7500-6050' 3) Set bridge plug at 5250' 4) Perforate at 4718' 5) Cement from 4718-4218' 6) Test cement in annulus 7) Perforate as reQuired4718-5168' 8) Inject as required: monitor 9-5/88 by 13-3/88 annulus pressure during all injection ac tivity TOCat4215' Upper Disposal Interval BC-BG 4718-5168' BRIDGE PLUG at 5250' TOC at 6050' 9-5/88 PROTECTIVE CSG at 6724' . TOP of 78 at 6200' TOC at 6570' Lower Disposal Interval CK-DM 6633-7278' PERFORATE 6720-7278' BRIDGE PLUG at 7500' Estimated TOC at 8000' P&A 7" PRODUCTION CSG at 11.398' ~', ~¡;'~~~-:fi .- ;' TOC at. 11,300' 1/21/91 DF-600-2ï6-90 ¡,t { ATTACHMENT I C 31-23 Casing and Cementing Detail SURFACE CASING (10-3/4"): CASING: CEMENT: SPACER: 17291, 10-3/4", 40.5#, J-55, BTC 1100 sx Class "G" + 27 sx gel followed by 200 sx Class "G" (15.8 ppg). Mixed cement with Inlet water. Lost circulation while cementing. 35.7 bbls water. TOP JOB: Cemented through 1" pipe at 1801. Had cement returns to surface. PRODUCTION CASING (7"): CASING: CEMENT: SPACER: 0630a/VEU2 10167',7", (10167-8789',29#; 8789 -01,26#), N-80, BTC 900 sx Class "G" + 1% CFR-2 (15.4 ppg). Mixed with fresh water. 71.3 bbls water. ~':E(EIVED JAN 251991 Alaska Oil & Gas ConS.~QP1lD.isslQn ,Anchorags'" :1","":' SURFACE (10-3/411) CASING: CEMENT: SPACER: PRODUCTION (7") CASING: CEMENT: SPACER: VEU2/0615 i~ f A TT ACH~'1ENT J CASING AND CEMENTING DETAIL C 41-23 1653', 10-3/411, 40.5#, J-55, STC Lead 1150 sx class "G" + 28 sx gel (12.8 ppg). Tail 200 sx Class ¡IG" neat (15.8 ppg). Mixed and displaced cement with Inlet water. 35.7 bbls water 10593', 7", 26# and 29#. 900 sx Class "G" (15.8 ppg). Tagged cement at 10,366'. Drilled out cement to float collar at 10,5041. I( II \ Þ.TTAOH~ENT K CASING AND CEMENTING DETAIL C-42-23 Sidetrack Plug =1: CEMENT: SPACER: Sidetrack Plug ~2 CEMENT: SPACER: Sidetrack Plug ff3 CEMENT: SPACER: Hit adjacent well C 44-14RD 915 sx Class "G" cement (15.4 to 16.0 ppg). Mixed with sea water. Pumped cement at 7421. Tag cement at 315'. Drilled out cement to 378'. Kicked off and hit adjacent well again at 742'. 20 bbls water Class "G" cement + 2~& CaCl. Mixed with sea water. Pumped cement at 742'. Tag cement at 4131. Drilled out cement to 5001. Kicked off and hit adjacent well at 5391. 10 bbls water ... 300 sx Class IIG" + l~~ CaCl. Mixed with sea water. Pumped cement at 5391. Tag cement at 3661. Drilled out cement to 4001. Kick off and hit adjacent well at 4931. Continue on. 20 bbls water Su rface Cas i n<LJ 13 -3/8") CASING: CEMENT: SPACER: TOP JOB: VEU2/0616 25781, 13-3/8", K-55, BTC (0-1759', 54.5#) and (1759-2578', 61#) 1558 sx Class "G" + 2.5% gel + 2% CaCl (12.8 ppg). Tail of 311 sx Class IIG" neat + 2% CaCl (15.8 ppg). Returns lost pumping last 90 bbls. Had some cement returns to surface before losing circulation but it was severely mud cut. 10 bbls water RECEIVED 140 sx at 125'. Class "G" + 2~~ CaC'Z' :JA,N 2'5 l.9j ¡ .,.~ '-. ",,' ",' .Gas Cons. Commissiím &!Choraga , it CASING AND CEMENTING DETAIL C-42-23 (Continued) Production Casing (7-5/811) CASING: CEMENT: SPACER: Liner (5-1/211) CASING: CEMENT: SPACER: SQUEEZE: LINER SEAL: VEU2/0616 88231, 7-5/811, N-80, 29.7# and 33.7# 450 sx Class jlGII + 0.75% 0-31 + 0.3% 0-19 + O.U~ 0-6 (15.8 ppg, 1.14 cf/sx). Lost returns after running 5000' of casing. Cemented without returns. 30 bbls water 9848 - 86241 (12241),5-1/211, N-80, 17#, SFJ. plain groove hanger. Used Burn's 210 sx Class "G" + 0.75% 0-31 + 0.3% 0-19. Insufficient volume to cover liner lap. Displaced 8 BPM. 5 bbls water 150 sx Class IIGII + 0.75~b 0-31 + 0.3% D-19 + 0.U6 D-6 (14.8 - 15.0 ppg). Squeeze tool set at 85341. Tagged cement at 85341, cleaned out to top of 1 i ner. Set Burns liner seal on top of liner. ~ 1\ TTAC!-H.1ENT L lit '\ 29 C43-14 CASING AND CEMENT DETAIL SURFACE CASING (13-3/8"): CASING: CEMENT: SPACER: TOP JOB: 2285 I (57 JTS) 13-318" 54.5# K-55 BTC. Used Baker gui de shoe and float collar. Float collar at 2244', 680 sx Cl ass "G" cement .¡. 10~~ GEL + 2~6 CaC12 + .25% CFR-3 (12.8 ppg, 11.7 gal/sk, 2.08 cflsk, 5:02 TT) followed by 200 sx Class "G" + 2~6 CaClz + .5% CFR-3 (15.8 ppg, 5.04 gal/sk, 1.15 cf/sk, 2:11 TT). Displaced at 8.5 bpm with full returns. Had cement contaminated mud returns at surface. 50 bbls fresh water 75 sx Class "G" cement from surface to 42'. ORIGINAL INTERMEDIATE CASING (9-5/8"): CASING: CEMENT: SPACER: 8620', 9-5/8", (8620-4756', 47#; 4756-0', 43.5#), L-80, LTC. Used Baker float shoe and float collar. Casing stuck on bottom after reciprocating for 45 minutes. 360 sx Class "G" + 1.5% prehydrated gel + 0.3% CFR-3 + 0.1% HR-7 (14.2 ppg, 7.3 gal/sk, 1.46 cf/sk) followed by 200 sx Class "G" + 0.3% CFR-3 + 0.1% HR-7 (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Displaced cement 8.6 bpm with full returns. 100 bbls fresh water SIT PLUG IN 8-1/2" HOLE CEMENT: SPACER: 180 sx Class "G" + .75% CFR-3 mixed at 16.7 ppg (4.0 gal/sk, 1.02 ft3/sk). Displaced at 7 bpm with 12.1 ppg mud with full returns. Spotted plug on top of Baker Open Hole Packer at 8725'. Calculated top of cement 8314'. Actual top of cement 83301, Drilled hard cement and kicked off at 8629'. 40 bbls fresh water preceding cement and 13.5 bbls fresh water following cement. ISOLATION PLUG 8-1/2" SIT #1 HOLE CEMENT: SPACER: RRW/012489 193 sx Class "G" mixed at 15.8 ppg (5.0 gal/sk, 1.15 ft3/sk). Displaced cement with 11.9 ppg mud with full returns. Calculated TOC = 8289'. Tagged cement at 8290'. Washed soft cement from 8290' to 8360'. Polished off firm cement to 8386'. 40 bbls fresh water preceding cement and 5 bbls fresh water following cement. ( (Attachment L Continued) f CEMENT PLUG INSIDE 9-5/8" CASING STUB 30 CEMENT: SPACER: 120 sx Class JIG" mixed at 15.8 ppg (5.0 gal/sk, 1.15 ft3/sk). Displaced cement with 10.1 ppg mud with full returns. Calculated BOC = 2805'. Calculated roc = 2475'. Top of 9-5/8" casing stub is at 24551. 10 bbls fresh water preceding cement. SIT PLUG IN 12-1/4" HOLE CEMENT: SPACER: 242 sx Class JIG" + .75% CFR-3 mixed at 16.7 ppg (4.0 gal/sk, 1.02 ft3/sk). Displaced with 10.1 ppg mud with full returns. Spotted plug on top of Baker/Brown Open Hole Packer at 2434'. Calculated top of cement 2211'. Actual top of cement 2216'. Drilled hard cement and kicked off at 23011. 40 bbls fresh water preceding cement and 2.5 bbls fresh water following cement. INTERMEDIATE CASING (9-5/8"): CASING: CEMENT: SPACER: 9950' of 9-5/8" (9950-9561', 43.5#, N-80, BTC; 9561-5022', 47#, L-80, LTC; 5022-0',43.5#, L-80, LTC). Used Baker float shoe and float collar. 522 sx Class "G" + 1.5% prehydrated gel + 0.2% CFR-3 + 0.1% HR-7 (14.2 ppg, 7.3 gal/sk, 1.46 cf/sk, 136 bbl slurry volume) followed by 200 sx Class "G" + 0.2% CFR-3 + 0.1% HR-7 (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk, 41 bbl slurry volume). Displaced cement with 9.8 ppg mud at 8.5 bpm with full returns. Bumped plug with 1500 psi. 100 bbls fresh water preceding cement and 5 bbls fresh water following cement. PRODUCTION LINER (7") CASING: CEMENT: SPACER: 12527 - 9346' (3226'),7", (12,572 - 11,020,35#, L-80, LTC; 11,020 - 10,980, 26#, N-80, LTC; 10,980 - 10,940, 35#, N-80, LTC x BTC; 10,940 - 10,211,26#, N-80, BTC; 10,211 - 9346,26#, L-80, LTC). Hung from a Baker Hi-Flow 2 liner hanger at 9346'. Used Baker float shoe, float collar and landing collar. 1100 sx Class "G" + 0.2% CFR-3 + 0.5% Halad 344 + 0.05 LWL + 1% NaCl (15.6 ppg, 5.2 gal/sk, 1.18 cf/sk). Displaced with 271 bbls of 11.9 ppg mud. Bumped plug with 2200 psi. Tagged cement 18' above TaL. 50 bbls fresh water preceding cement and 10 bbls fresh water following cement. RRW/071089a ( :f " A TT ACHMENT r.,~ C43-23 CASING AND CEMENTING DETAIL SURFACE CASING (10-3/411): CASING: CEMENT: SPACER: TOP JOB: 1627', 10-3/411,40.5#, J-55, STC 1050 sx Class IIGII + 10% gel (12.8 ppg) followed by 200 sx Class IIGII (15.8 ppg). Lost circulation during last 89 bbls of displacement. Tagged cement 611 below wellhead. 35.7 bbls water 143 sx Class "GII througn 111 pipe at 941. PRODUCTION CASING (711): CASING: CEMENT: SPACER: 0701/VEU2 98101,711, (9810-8039',29#; 8039-0,26#), N-80, STC 900 sx Class IIG" + 1~& CFR-2 (15.5 ppg). Mixed with fresh water. 71.3 bbls water , Shell Western E&P Inc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson' In a recent telephone conversation you discussed with Ms. Susan Brown,Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following' 2 location surveys showing the location of Platform A 1 list of conductor/well locations (in relation to the SE corner of Sec. 11, T8N, R13W) for Platform A wells 1 location survey showing the location of Platform C 1 list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly~Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc' Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC REEEIVED JUN 1 1990 Alaska Oil.& Gas Cons. Anchorag3 PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. CONDUCTOR WELL DISTANCE FROM SE CORNER NORTH WEST LEG 2 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 CONDUCTOR LEG 3 LEG 4 9 10 11 12 13 14 15 16 CONDUCTOR 25 26 27 28 29 3O 31 32 Centered 618.65 ft. North and 1549.76 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C22-23 623.65 1552.66 C24A-14 624.15 1548.36 C43-14 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613 . 85 1546.26 C21-26 612.65 1550.46 C24A-23 614.85 1554.26 C13-23 619.].5 1555.66 Centered 582.42 ft. North and 1489.90 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. WELL C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 DISTANCE FROM SE CORNER NORTH WEST 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 West DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 West DISTANCE FROM CENTER OF LEG N/s E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.50 -6.00 -0.70 -3.80 -4.50 0.50 -5.90 West West DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 , re.l,! :et Se LO~..AT ION ~A.$. INLET ,'"' ALASKA SC. diLl' 1%2000' 'MEMORANDuM TO: 'THRU: State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie Co Smith ~/~~ Commissioner / 0 Michael T. Minder Sr. Petroleum Engineer DATE: August 8, 1988 FILE NO: D. BDF. 008 TELEPHONE NO: SUBJECT.' Safety Valve Tests Shell-MGSU Platfom C MGS Oil Pools FROM: Bobby D. Fost er ~~~, Petroleum Inspector · Thursday, August_4, 1988: The tests began at 7:30 a.m. and were concluded at 10.30 a.m. With 10 Pilots, 10 SSSV's and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. This will be repaired and the AOGCC Office notified. ,Comment by Mike Minder: Richard Vickerson called August 8, 1988, to notify Commission that the SSSV in C42-23 has been replaced and tested OK. Attachment PtlotS Tested 10'· SSSV' s Tested 10 SSV' s Tested 10 Pilots Failed 0 SSSVI§ Failed 1 SSV's Failed 0 AOGCC SAFETY VALVE TEST REPORT PAGE PRESSURES - PSIG · FIELD: MIDDLE GROUND SHOAL SHELL C PLATFORM [OPERATOR: SHELL WESTERN E&P REPRESENTATIVE: WELL C44-14RD PERMIT NUHBER 77-0079-0 C-23-23 68-0030-0 C-31-23 68-0069-0 C-32-23/ 75-0035-0 C-42-23 / 78-0024-0 68-0060-0 C-43-23 ~ C22-26RIf SV TSTIPILOTI FLG DUE I(LOW)I TBG I~1~ I 76-0065-0 C24-26RD 79-0062-0 C-31-26 67-0063-0 C'34-26 / 68-0019-0 SI TBGIIP I [ SSV FP __lSSVl .sssv ITSTI IP FP I I ~1 I I DATE: ~>qD_ d'- ~1 7o REMARKS: __1 INSPECTOR ) ~' ~/ ~? - , July 2, 1987 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT- SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL NO. C 44-14 RD Gentlemen- Enclosed, in duplicate, is the Report of Sundry Well Operations for the cement squeeze that was performed on Middle Ground Shoal well number C 44-14 RD. If you have any questions, please contact Susan Brown at (907) 263-9613. Ve~r~ truly yours, /-] Mana~/~ Regulatory Affairs AlasN Division ' SBB/kka Enclosure · Alaska Oil & Gas Cons, SBBF/aogcc. 04c STATE OF ALASKA ALAf=,,~A OIL AND GAS CONSERVATION COlV,,,,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [3 Plugging [] Perforate [] Pull tubing Alter Casing [] Other~ 2. Name of Operator 5. Datum elevation (DF or KB) She11 Western E&P I nc · 1 05 ' KB Feet 3. Address 6. Unit or Property name 601 West 5th Avenue, Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform C, Leg 4, Conductor 31. 4779'S & 1541'W from NE corner of Sec. 23, T8N, At top of productive interval At effective depth At total depth 7. Well number C 44-14 RD R13W, S.M. 8. Approval number 6-469 9. APl number 50--733- 20252-01 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11 ,400 ' 11 ,162' feet Plugs (measured) feet feet Junk (measured) feet Casing Length Size Structural Conductor Surface 2,483 ' Intermediate 6,724 ' Production 11 ,398 ' Liner Perforation depth: measured 10,059 - 11.112' true vertical 8,292 - 9,161 ' Tubing (size, grade and measured depth) 2-7/8", 6.5#, N-80 EUE ~ 10,045' Packers and SSSV (type and measured depth) Unipacker VII (7") set at 10,015' Cemented 1:~-3/8", 61#, J-55 9-5/8", 43.5#, 7", 26-29#, N-80 Measured depth True Vertical depth 2150 sx 100 sx 2,183' 6,724' 11 ,398 ' RECEIVED JUL- 1987 Alaska Oil & Gas Cons. C0rnr~lissi0ri Anchorage 12. Stimulation or cement squeeze summary Intervals treated (measured) CTU cement squeeze attempt of GR-GS perforations (10,060'-10,134') with 6.5 BBL of cement. Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Well shut in. Well shut in. Tubing Pressure 14. Attachments Daily Report of Well Operations I~ ,t~l!~\l~~. I hereby certify that the foregoing is true and correct to the best of my knowledge igned Title Production Superintendent Form 10-404 Rev.~T2~-l-~85 Copies of Logs and Surveys Run [] Date 7¢'~ Submit in Duplidate DAILY JOB SUMMARY DATE: WELL NO: OPERATION: 10/15/86 C44-14 RD Squeeze Job 0730 1330 1445 1720 1730 2000 2150 2255 0015 SBBF/djs .02 Companies arrive and hold Safety meeting w/T. L. Pritchard. Begin rigging up. CTU rigged up. Attempted to measure volume from cementing unit to end of CT by circulating 3 gallons of red food coloring through system. Food color reacted w/fluid in CT and changed color to green. Volume appeared to be about 15.5 bbl. Confirmed volume of 15.5 bbl by circulating 3 gallons of red hydrau- lic fluid through system. Pressure tested all lines and lubricator to 4,400 psi for 10 minutes using B.J. unit. RIH 100 fpm. At PBTD pulled about 17,000#. Maximum pull is about 20,000#. Began circulating and whi-le easing down hole. Tagged PBTD at 10,514' based on CTU odometer. Slickline PBTD at 10,940'. Because of apparent higher PBTD than earlier measured, decided to spot smaller mud plug to avoid covering perfo- rations. Spotted 8 bbl of mud (16#/gal) which should bring PBTD to 10,088' if CT is at 10,500'. Spray painted CT w/red marker for later correlation w/wireline. POOH to odometer reading of 10,090' and mark line w/blue paint. On POOH, found odometer read 9,494', indicating odometer slipped running in hole. PBTD probably near 10,940'. SD for night. JUL ~-~ Alaska, Oil & Gas Cons. Comm~ssio~ DAILY JOB SUMMARY DATE' WELL NO' OPERATION' 10/16/86 C44-14 RD Squeeze Job 0730 1030 1115 1215 1520 1755 1815 1845 1935 1940 2025 2145 SBBF/djs.02 SOS arrived and RU. SOS unit placed between CTU and B.J. on pipe rack. 45 minutes repairing leaking SOS lubricator BOP. Tested lubricator to 1,000 psi and RIH w/CCL/GR/Gradi ometer. Tied into SOS production log 9/23/86. Logging down 2,000 fpm. Mud top found at 10,204'. Above mud top gradiometer indicated some mud mixing had occurred. RU CTU and B.J. Pressure tested all lines to 4,500 psi for 5 minutes. RIH circulating filtered injection water .25 bpm, returns to test separator. Tagged at 11,027' based on Arctic CT odometer. Between runs Arctic had tightened spring tension on odometer. Assumed this depth correlated to 10,973' and reset Arctic's odometer for rest of job. Pumped additional 2.5 bbl of mud to bring mud plugback to 10,150'. Moved end of CT to 10,150' and circulated w/filtered injection water. Circulated an additional 30 bbl. Pulled up to 10,140' and did an injection test. Perfor- ation taking 0.6 bpm at 1,000 psi on 5 minute test. Meeting to discuss job w/service companies and production operator. B.J. did fluid loss test of cement. Approximately 100 cc/30 minutes at 1,000 psi. Alaska Oil & Gas Cons. 2145 2223 2228 2315 2355 W/end of CT at 10,140', spotted 2 bbl fresh water, 6.5 bbl 15.5#/gal cement, 2 bbl fresh water and displaced w/filtered injection water. After 4.5 bbl were spotted across the perforations and to the end of the 2-7/8" tubing, the CT was moved to 9,900' and the returns line was SI. W/return line SI, an additional 2 bbl of cement were squeezed into the formation. No firm squeeze obtained. Final pump pressure was 750 psi at 1/16 bpm. ISIP was 650 psi. Pressure bled off to 250 psi in 40 minutes. Next 10 bbl of contaminate (lO#/bbl bentonite + 20#/bbl borax) were circulated from 10,200-9,900' in two passes. A constant tubing pressure (250 psi) was maintained by taking returns via the production line and choking the returns back. After contamination, the CT was POOH while maintaining backpressure using B.J. unit. SBBF/djs.02 DATE: WELL NO: OPERATION: 0115 O70O 0915 0934 1010 1420 1516 DAILY JOB SUMMARY 10/17/86 C44-14 RD Squeeze Job POOH CT and SD for night. SI pressure on tubing is 165 psi. SI tubing pressure is 50 psi. Opened tubing to atmosphere w/no flow. Began RIH w/CT circulating at 1/2 bpm w/filtered injection water. Set down at 4,768'. Attempted to wash through plug w/no luck. POOH. RIH w/Otis 2.25" Hydro-Blast wash nozzle. Mixed up 5#/1,000 gal HEC pill. Slick water is supposed to increase wash nozzles efficiency. Made about 6' of hole before bogging down. Circulated up some uncontaminated cement. No progress. Tagged plug 6 times. POOH and ordered Navadrill and 2.25" junk mill from Tri-State. SD for night. SBBF/djs.02 DAILY JOB SUMMARY DATE: WELL NO: OPERATION: 10/18/86 C44-14 RD Squeeze Job 0745 0800 0815 1135 1235 1420 i630 1700 1800 2000 Navadrill and junk mill arrived. Surface tested drill in bucket. Worked well. Pump stalls at 500 psi. RIH w/drill. Tagged plug at 4,786' PU to 4,785' and began pumping i bpm at 3,500 psi. ~lid through 70-80' of loose cement. Circulated up about 3 cups of semi-solid cement. All returns sent through 40 mesh screen secured above J-tube. At 10,169' tagged additional loose cement and drilled 10-20'. Tagged PBTD about 15' higher than original marked spot on CT. Attempted to make additional hole. No luck. Cir- culated hole clean w/lO0 bbl of 20#/1,000 gal HEC. Returns were clean gel. Displaced 20#/1,000 gal gel w/salt water. POOH. Tested squeeze at 1,000 psi for 5 minutes w/no leak off. Prior to job perforations took 0.6 bpm at 1,000 psi. RD B.J. and Arctic CT. RU SOS and RIH w/2.25" jet cutter. Set down at 10,157'. Could not get past bridge. POOH. Master and swab valves leaking injection gas. Call out Cameron to repair. SBBF/djs.02 April 10, 1987 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF SUBSEQUENT REPORTS OF OPERATIONS FOR MIDDLE GROUND SHOAL WELLS C 31-26 AND C 44-14 RD Enclosed are the Subsequent Reports of Operations for the recently completed stimulations on Middle Ground Shoal well numbers C 31-26 and C 44-14 RD. Each report is submitted in duplicate. If you have any questions regarding these reports, please contact Susan Brown at (907) 263-9613. Very truly yours, D. L. Yesland Manager, Regulatory Affairs Alaska Division SBB/kka Enclosures Alaska Oil & Gas Cons. Commission Anchorage SBBE/SR.3126 STATE OF ALASKA _. ALASK/ L AND GAS CONSERVATION COMMi 'ON REPORT' OF SUNDRY WELL OPtRATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Shell Western E&P Inc. 3'~e~est Fifth Ave., Suite 810, Anchorage, AK 99501 4. Location of well at surface Platform "C" Leg 4 Conductor 31 4779'S & 1541'W from NE corner of Sec 23, T8N, R13W, S.M. At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) 116' DF Feet 6. Unit or Property name Middle Ground Shoal 7. Well nucm~e4r- 14RD 8. Approval number 7-150 9. APl number 50- 733-20252-01 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical 11,400' feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) 11,162' feet Casing Length Structural Conductor Surface 2483' 6724' Intermediate 11,398' Production Liner Perforation depth: measured Size Cemented Measured depth 13-3/8", 61#, J-55 2170sx 9-5/8", 43.5# 7" 26-29# N-80 lO00sx 10,059'-11,1123' true vertical 8,292 ' -9,161 ' True Vertical depth Tubing (size, grade and measured depth) 2-7/8", 6.5#, N-80 @ 10,045' Packe.r.,s aod SS,~V.(.t,yp,,e.~.n.d measured depth) yacKer Lo IU,UIb' RECEIVED 12. Stimulation or cement squeeze summary treateC, leanout~ attempt was unsuccessful Intervals (measured) ' ' Treatment description including volumes used and final pressure APR I 6 1987 Alaska Oil & Gas Coas. Commis~ior] Anchora~ 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 .... 0 0 0 14. Attachments Y Daily Report of Well Operations"[] Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge H Title Production Superintendent Date Submit in Duplicate DAILY REPORT OF OPERATIONS Well - Date- Operation' Foreman' 0600-0830 0830-1200 1200-1215 1215-1400 1430-1530 1530-1700 1700-1800 1800-2400 C 44-14RD 04/04/87 Stimulation T. L. Pritchard Move rig over well slot. Rig up Arctic Coiled Tubing and Halliburton. Pressure test to swab gate to 5000 psig. RIH with Otis indexing wash tool. Tagged bridge @ 10215'. Try to wash bridge. No luck. Pull out of hole. Rig up Dialog to RIH with shaped charge. Got stuck @ 9584'. Pulled loose and pull out of hole. Left 2-1/8" ceramic perforating ball in hole. Rigged down Dialog. RE£EIVED APR 1 6 1981 Alaska 011 & Gas Cons. Commis~lor~ Anchorage SBBE/asa.5a Shell Western E&P Inc. ~ 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 March 10, 1987 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: SUBMITTAL OF AN APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NUMBER C 44-14 RD Gentlemen: Enclosed, in triplicate, is the Application for Sundry Approval for an upcoming workover on Middle Ground Shoal well no. C 44-14 RD. The stimulation is scheduled to begin as soon as approval is obtained. If you have any questions, please contact Susan Brown at (907) 263-9613. Ver~c~ truly yours, ~ Manag~/~ R. egu 1 a tq/ry Affairs Alaska Division' SBB/kka Enclosure RECEIVED !V!>,,!-:: 1 ;:.) ~,~laska Oil & Gas ,r?~)ns, [;ommis$io~ Anchor:~ge SBBE/aogcc.02 STATE OF ALASKA ALAS..., OIL AND GAS CONSERVATION COM,...dSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order L1 Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc. 105' KB feet 3. Address 6. Unit or Prop. erty name 601 West Fifth Ave., Suite 810; Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface P1 atform "C", Leg 4, Conductor 31 4779'S & 1541'W of NE corner of Sec 23, T8N, R13W, SM At top of productive interval At effective depth At total depth 7. Well number C 44-14 RD 8. Permit number 77-79 9. APl number 5o-- 733-20252-01 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,400' 11,162' feet Plugs (measured) feet feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size 2483' 13-3/8" 6724' 9-5/8" 11, Cemented , 61#, J-55 2170sx , 43.5# 26-29#, N-80 lOOsx 10,059'-11,112' true vertical 8,292' -9,161 ' Measured depth Tubing (size, grade and measured depth) 2-7/8", 6.5#, N-80, EUE @ 10,045' Packers and SSSV(type and measured depth) Unipacker VII 7" @ 10,199' True Vertical depth 2,183' 6,724' 11,398' 12.Attachments Description summary of proposal ~ Detailed operations program L~ BOP sketch 13. Estimated date for comme.qcJ, ng operation as soon as possID/e 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢/~~ ~,~~ Title Production Superintendent Commission Use Only Date ~ --'/¢- ~'7 Conditions of approval [] Plug integrity [] BOP Test Approved by ~v ~:~4~.:;~' ....... Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Location clearance Commissioner [Approval No. the commission Date ¢_~/'-"//~ 7 / Submit in triplicate CLEAN OUT MGS C44-14RD MARCH 5, 1987 OPERATION: Clean out to fish (CTU wash nozzle) on top of "Px" plug at 10983'. shoot off tubing directly above fish. Return Hemlock to production. TUBING: See attached COMPLETION EQUIPMENT DETAIL SHEET. REFERENCE LOG: SOS Perforating Record 2/10/86 EQUIPMENT: 1-1/4" Coiled Tubing Unit Pump (Single Skid) 5000 psi I BPM Mixing Vessel Otis Hydro-Blast wash nozzles (assorted sizes) Two (2) 1-3/4" Nava-Drills 2.25" E-Line tubing cutter and E-Line unit 2.25" Tubing cutter mounted on Vann Pressure Actuated firing head SUPPLIES: 100# HEC (500 BBL mixed 5# HEC/(IO00 gal) Two (2) 2.25" junk mills PROCEDURE: li RU coiled tubing unit, mixing vessel and pump. Attach Otis Hydro-Blast wash nozzle to end of CT with swedgelock connector.. RU lubricator and pressure test from pump to wellhead to 4200 psi. Mix up viscous fluid (5# HEC/IO00 gallons fresh water) in mixing vessel. Before RIH, make sure pressure actuated indexing head is functioning. 1 Displace diesel in CT to production header. RIH. Begin jetting at 10,100' taking returns to J-tube. Wash down to fish at 10,983'+. If unable to get into "WD" at 10267, POH and clean out with 2.25" mill run on Nava-Drill. Minimum clean out depth is fish at 10,983'_+. Tag CT with paint at maximum depths. 1 If well was successfully cleaned out to fish, standback coiled tubing unit. RU 3/16" braided line unit and make dun~ny tubing cutter run to 10,983: JHF/0305 PAGE 2 4.a. If unable to get to 10,983'-+ with slickline dunmly run, tubing cut will be made using a cutter run on coiled tubing as follows: 1-1/4" CT 1-3/4" Vann Pressure Firing Head X-Over 2.25" Tubing Cutter Use tag mark {Step 2) on CT to ensure cutter is at maximum depth. b. If able to get to 10,983'+ with slickline dummy run, RD coiled tubing unit and pumping equipment. Call out E-line Company. RU E-line with lubricator and pres- sure test lubricator to 3500 psi. RIH with 2.25" cutter and get on depth using REFERENCE LOG. Pressure up tubing to 2000 psi and make cut. POH. RD E-line. Record any pressure changes and/or any indications of cutter firing. . Place well on production. If tubing blows dry, make drift run with braided line to determine if tubing cut was unsuccessful. If cut was unsuccessful, RIH and pull duniny at 10622' and place well on test. If unable to pull dummy, contact Anchorage Production Engineer. RECOMMENDED' DATE' APPROVED- JHF/0305 J J _1 ._J 4 COMPLETION EQUIPMENT DETAIL SHEET MGS C44-14RD TV_V_. MD. 1. OTIS XEL LANDING NIPPLE 2. GAS LIFT MANDREL 3. GAS LIFT MANDREL 4. GAS LIFT MANDREL '.5. GAS LIFT MANDREL ,4 6. GAS LIFT MANDREL ,5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL ,7 9. 6A$ LIFT MANDREL #8 10. OTIS XO SLIDING SLEEVE 11. OTIS RH PACKER 12. OTIS X NIPPLE 13. N/L RE-ENTRY GUIDE STRADDLE ASSEMBLY 14. OTIS ND PERMANENT PACKER 15... 3.44' SEAL BORE EXT. 3.25" 16. GAS LIFT MANDREL (DUMMIED) 17. OTIS ND PERMANENT PACKER 18. 3.41' SEAL BORE EXT. 3.25' 19. OTIS 'X' NIPPLE 20. N/L RE-ENTRY GUIDE 290 1740 3590 5158 6457 7648 8596 9584 9963 9981 10015 10026 10045 10267 10271 10622 10970 10973 10983 11001 CASING 3/8". 61,. J-55 O 2483' N/2170 SX 26-29, N-80 O 11398' N/lO00 sx¥..~,i~.~,. ,:, :~ TD:ll400~ PBTD:l1287' 2 7/8", 6.5~, N-80 EU~ \~"/~ \ PERFORATED ZONE GR-GS HC-HD HE -HF HK-HN HN-HR HR -HZ INTERVAL 10060-10]34 20320-~033i 10342-10348 ~0370-10374 10480-10484 10720-~0766' ~0793-10817' 20849-10943 10995-11110 PAG5 77 SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTO~I. TEXAS 77001 January 2, 19B7 601W. Fifth ~M&._~_Suite 810 Anchoraze, AK 99501 A~ention: Joe Fram ~,J~E R[PLY TO ~~E~ orKsKR[ IERVIC~ P. O. Box 'I. 001 Kenai, AK 99611 Attention: Shelley Ramsey Gentlemen: Enclosed are 2 BL prints of the Company. Shell Western E&P Field .. Middle Ground Shoal Production Log 10/16/86 on' ,Well Middle Ground Shoal "C" #44-14 RD , ,Coun~ Kenai ~tate Alaska Additionalprintsorebeing sentto: 1 BL prints, original film Shell Western E&P~ Inc. P. 0. Box 527 Houston, TX 77001 Attn: Log Files, .WCK 4147 / I___BL prints, 1 Reverse Folded Sepia State of Alaska Oil & Gas Conservation Commission Anchorage,_AK 99501 Attn: H. W. Kugler 1BL prints Shell Western E&P, Inc. P. O. Box 527 Houston, TX 77001 Attn: R. J. Vallejo, WCK 1134 1BL prints, 1 Mylar ARCO Alaska, Inc. P. O. Box 100360 Anchorages .AK 99501 Attn: H. F. Blacker 1BL prints SHell Platform "C" % Shell Kenai Office North Star Route #1 P. O. Box 485, Wik Road Kenai, AK 99611 prints 2 BL prints, 2 Reverse Rolled Sepia Chevron U.S.A., Inc. P. O. Box 107839 Anchora eg~ AK 99510 Attn: J. L. Weaver The film is_returned to Shell, --Houston. We appreciate the privilege of serving you. prints Please sign and re/turn one com¥ of Very truly yours, SCHLUMBERGER OFFSHORE SERVICES DISTRICT MANAGER SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 November 4, 1986 ' .~hell Western E&P, Inc. §01W. Fifth Ave,, Suite 810 Anchorage, AK 99501 A~ention: Joe Fram PL. IrAEE I~EPLY TO ICHLUMIERGER OFFSHORE SERVICES P.O. Box 1OO1 Kenai, Alaska 99611 Attention: Shelley Ramsey Gentlemen: Enclosed ore_2_J3iprints of the Cornpony Shell Western E&P Field. Middle Ground Shoal Product i mn Lng on: ,Well Middle Ground Shoal "C" #44-14 RD , ,Coun~ Kenai State Alaska Additionoiprintsore being sent 1 BL prints , original film Shell Western E&P, Inc. P.O. Box 527 Houston, TX 77001 Attn: Log Files, WCK 4147 1BL printm 1 Reverse Folded Sepia State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: H. W. Kugler 1BL prints Shell Western E&P, Inc. P. O. Box 527 Houston, TX 77001 Attn: R. J. Vallejo, WCK 1134 I BL prints Shell Platform "C" c/o Shell Kenai Offico North Star ROute #1 P. O. Box 485 Wik Road Kenai? AK 99611 I BLprints, 1 Mylar ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99501 Attn: H. F. Blacker ~prints 2 BLprints, 2 Reverse Rolled Sepia Chevron U.S.A., Inc. P. O. Box 107839 Anchorage, AK 99510 Attn: J. L. Weaver ~prints _Plo~so sign &_Roturn nnm copy of _ this tra~smitta! The film is returned to Shell - Houston.__ We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Roger H. Theis DISTRICT MANAGER October 15, 1986 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen- Enclosed are three copies of an Application for Sundry Approval for the Middle Ground Shoal (MGS) well C 44-14 RD. The work is scheduled to commence upon receipt of approval. If there are further questions, please contact Susan Brown at (907) 263-9613. Very truly yours, M. L. Woodson Division Operations Manager MLW/SBB/kka Attachment SBBD/aogcc.2 STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COMM,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Et Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order Lq Perforate [3 Other [] 2. Name of Operator Shell Wc.s-I-.c.r'n F'&P Tnc. 3. Address 601 West. Fifth Avenue, Suite 810, Anchorage, AK 99669 4. Location of well at surface Ptatform "C". Leg 4, Conductor 31 4779'S & 1541'W from NE corner of Sec. 23, T8N, R13W At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) 105 KB 6. Unit or Property name Middle Ground Shoal 7. Well number ¢ 44-!4RD 8. Permit number 77-79 9. APl n~:~e~0252_01 50-- 10. ?CipJG,, feet 11. Present well condition summary Total depth: measured true vertical 11,400' feet Plugs (measured) feet Effective depth: measured 11,162' true vertical feet Junk (measured) feet Casing Structural Conductor Surface 2483' Intermediate 6724' Production Liner Perforation depth: measured Length Size Cemented true vertical 13-3/8", 61#, J-55, 2170 sx 9-5/8" 43.5# - - 7", 26-29#, N-80 1000sx 10,059' - 11,112' 8,292' - 9,161' Tubing (size, grade and measured depth) 3-1/2'' 9.3#, N-80 buttress @ 10,215' Packers and SSSV (type and measured depth) Unipacker VIT 7" @ 10,155' 12.Attachments Description summary of proposal [] Measured depth True Vertical depth 11,398' Detailed operations program E3 BOP sketch [] 13. Estimated date for commencing operation Immed i ate ly 14. If proposal was verbally approved Name of ap~-?er . Date appro, ved 15. I here~ c¢.t~ ti;hat the ,f,~egoing is true and correct to the best of my knowledge Signed Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ......... ~.v~:,~,~, ~ o.~:.--.~ Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate PROGNOSIS MGS C44-14RD 10/14/86 OPERATION: CTU Squeeze Cement GR-GS, Clean out tailpipe, fish wash nozzle and recover "PX" plug. WELL DATA: PBTD: 10983' + wash nozzle Fish and sand in tailpipe TD: 11400' TUBING: See Attached Detail Sheet CAPACITIES: 7" 29# 0.0371 BBL/FT 1¼" CT 0.00112 BBL/FT 2 7/8" 6.5 0.00579 BBL/FT 2 7/8 X 1¼ 0.00427 BBL/FT PERFORATIONS: ZONE GR'-GS HC-HD HE-HF HK-HN HN-HR HR-HZ INTERVAL 10060 - 10134 10320 - 10331 10342 - 10348 10370 - 10374 10480 - 10484 10720 - 10766 10793 - 10817 10849 - 10943 10995 - 11110 REFERENCE LOG: SOS Perforating Record 2/10/86 STATUS: Shut In. Last test of GR-GS 0 + 593 BWPD 3/11/86. CTU wash nozzle and sand cover "PX" plug in "X" nipple at 10983'. PROCEDURE: le PRODUCTION LOG RU slickline and pull ball valve. Make 2.25" drift run. RD. Leave well Shut in. e e RU Dresser Atlas. Pressure test lubricator with 1" line from offsetting injection well to 3500 psi for 10 minutes. RIH with: CCL Basket Flow Meter Temperature Tool This logging will determine if water is channeling from above or below the perforated GR-GS interval and may impact cement quantities used in STEP 6. Get tool on depth using REFERENCE LOG. With tool on depth, make static temperature pass. With tools below EOT, open flowline and begin gas lifting well. After 12 hours when well has stabilized, make one flowing temperature pass. Production Engineer on-site will evaluate whether additional lift time or BFM readings are necessary. POH and RD Loggers. O012/JHF1 Page 2 NOTE: KILL WELL Bleed off casing and tubing pressure. Circulate well down annulus with injection water taking returns to the group separator. Total casing annulus plus tubing volume is 377 BBL. After circulating 800 BBL, shut in and monitor tubing and casing pressure. Continue circulating if gas is present. . TUBING AND INJECTION TEST RU slickline. RIH with "Px" plug and set in "X" nipple at 10026' Pressure up tubing to 3500 psi with 1" line from offsetting injection well. Monitor tubing and annulus pressure for 10 minutes. If leak exists, dummy all GLV and retest tubing to 3500 psi. If there is no communication with casing, remove "PX" plug. RD slickline. Establish injection rate using one inch line from offsetting injection well. Monitor injection rate using water flood panel. Maintain rate for 10 minutes. Report rate on morning report. CEMENT SQUEEZE Prior to job start, sample of cement to be used on job and water sample from Platform "C" will be lab tested under anticipated well conditions. Cement to have the following properties: Thickening Time = 5-7 hours Fluid Loss = 50 +/- 20 CC at 1000 psi Density = 15.5 #/Gal Bottom hole static temperature = 157°F 6. RD coiled tubing unit and cementers. pumping equipment and coiled tubing by circulating a marker (hydraulic) fluid through system on surface. Record volume. Pressure test CTU lubricator to 5000 psi for 10 minutes. Coiled tubing to be run in with cementing nozzle. Wash and circulate down to PBTD ("X" nipple at 10983' with "PX" plug and wash nozzle fish on top) take all returns to shale shaker. If returns contain gas, circulate to group separator. If sand will not circulate out with water, add 20# HEC/IO00 gal. (B.J. G-21) to fluid. At PBTD, to ensure clean tailpipe, circulate an additional 150 BBL. Hole volume is 66BBL. . With coiled tubing at PBTD, spot a 9.0 BBL 16#/gal mud pill from PBTD to 10134'. Spot mud with end of coiled tubing at PBTD. At 10134', circulate 100 BBL of injection water or until returns clean up. Tag line. POH. Move CTU and RU loggers. 0 RIH with CCL and density tool. Determine depth of mud/brine interface. This depth will be used to calibrate actual CTU depth. POH. . RIH with CT. If mud plug based on electric line measurement is above bottom perforation at 10134', circulate out mud to 10150'. Maximum acceptable mud depth is 10155', spot additional mud if necessary. O012/JHF1 Page 3 10. 11. 12. 13. 14. 15. 16. Mix and test 4.3 BBL of cement. Test for density and fluid loss. With the end of the coiled tubing at 10144', pump the following: 2 BBL fresh water 4.3 BBL cement 2 BBL fresh water Displace with tail of cement to 9958' (Balanced Plug). Slowly pull out of cement to 9800' and pressure up to 1000 psi or until zone takes up to 0.5 BBL of fluid. Ae If zone takes fluid, leave cement in place for 40 minutes and then circulate out with filtered injection water to 10' below mud-cement interface. At 10' below interface, circulate an additional 100 BBL once the returns clean up. Reciprocate CT during clean out operation. If difficulty is experienced during cleanout phase, cement will be contaminated after 2 hours. Zone will be resqueezed using same procedure. Be If zone holds 1000 psi without taking fluid, hold pressure for 40 minutes. After 40 minutes, circulate in 9 BBL of contaminant consisting of 20#/BBL Borax + IO#/BBL Bentonite from 10154' to 9900'. Reciprocate pipe during contamination operation. POH to 9600'. Leave 200 psi on tubing. Leave well shut in for 6 hours. Pressure test squeeze to 1000 psi for 10 minutes. If squeeze fails to hold pressure, resqueeze starting at Step 10. If squeeze holds, RIH with coiled tubing and circulate out mud to PBTD at 10983'. POH and RD CTU. Send service company employee's in while gas lifting well down. Gas lift well and place on test. If squeeze break down, well will not be resqueezed. After well stabilizes, fish wash nozzle and plug with slickline. If wash nozzle is not fishable with slickline, the tailpipe will be shot off. Place on production. RECOMMENDED: APPROVED: DATE: DATE' O012/JHF1 NO. , 2. 3. 4. 6. 7. 8. 9. 10. 11. .1.2. 13. 14. 15... 16. i7. 18. 19. 20. COMPLETION EQUIPMENT MGS C44-14RD 6/20/86 ITEM OTIS XEL LANDING NIPPLE GAS LIFT MANDREL ~1 GAS LIFT MANDREL t2 GAS LIFT MANDREL #3 GAS LIFT MANDREL #4 GAS LIFT MANDREL #5 GAS LIFT MANDREL #6 GAS LIFT MANDREL #7 GAS LIFT MANDREL #8 OTIS XO SLIDING SLEEVE OTIS RH PACKER OTIS X NIPPLE W/L RE-ENTRY GUIDE STRADDLE ASSEMBLY OTIS WD PERMANENT PACKER 8.44' SEAL BORE EXT. 3.25" GAS LIFT MANDREL (DUMMIED) OTIS WD PERMANENT PACKER 3.41' SEAL BORE EXT. 8.25" OTIS "X" NIPPLE W/L RE-ENTRY GUIDE DETAIL TVD. SHEET MD. 290 1740 3590 5158 6457 7648 8596 9584 9963 9981 10015 10026 10O45 10267 10271 10422 lOGT0 10973 10983 11001 CASING 13 3/8", 61#, J-55 0 2483' W/2170 SX 7" 26-29# N-80 0 11398' W/1000 sx TD:ll400' PBTD:l1287' TUBING 2 7/8", 6.5#, N-80 EUE PERFORATED ZONE GR-GS HC-HD HE -HF HK-HN HN-HR HR -HZ INTERVAL 100~0-10134' 10320-10331' 10342-10348' 10370-10374' 10480-10484' 10720-10766' 10793-10817' 10849-10943' 10995-11110' PAGE 77 ~-~ STATE OF ALASKA .... ' ~ ALASKA ~_ AND GAS CONSERVATION C 'IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Qrilling well [] Workover operation 2. Name of operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave., Suite 810, Anchorage, Alaska 99501 4. Location of Well at surface Conductor 31 of Leg 4. 4779' S & 1542' W of NE of Sec. 23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 116' KB J ADL 18754 corner 7. Permit No. 77-79 8. APl Number so- 733-20252-01 9. Unit or Lease Name Middle Ground Shoal 10. Well No. C 44-14 RD 11. Field and Pool Middle Ground Shoal "G" Pool For the Month of February ,19 86 12. Depth at end of month, footage drilled, fishing jobs, dir~tional drilling problems, spud date, remarks Depth' 11,287' Completed workover' 02-03-86 13. Casing or liner ru.n and ~uantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIG~~- ~='~<:Z2~ TITLE Production SuDerintendentDATE ~-\'~-~o NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. SCHLUi~IBERGI='R OFFSHORE: SERVICES Division of Schlumberger Limited HOUSTON. 'r£XA$ 77001 MARCH 13, 1986 SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON: TX. 77001 Attention: LOG FILES, WCK 4147. PLEAIE REPLY TO ANCHORAGE, ALASKA 99518 CUZZO Gentlemen: Enclosed ore 1BL prints of the PERFORATING RECORDS (2) Compony SHELL WESTERN E&P INC. , Well MGS G-44-14 RD Field. MIDDLE GROUND SHOAL Additionol prints ore being sent to: tBL prints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 ATTN: R.J.VALLEJO ,WCK 1134 ,'County KENAI state_~_ALASKA .... .- on: ~iBL nrints / STATErOF ALAS~ ( ALAS~ OIL a CAS CONSERVATXON CO~. ~ ~OR~N~~ ~ '~CHORAGE, ALAS~ 99501 ATTN: 'H~W.--KUGLER ............... 2BL SHEL~rinT~STERN E&P INC. 601 W.FIFTH AVE;SUITE 810 ANCHORAGE ~ ALASKA 99501 ATTN- JOE Fp~a_M 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL nrints SHELL' PLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NORTH STAR ROUTE #1 F.O. BOX 485 WIK RD. KENAI, ALASKA 99611 prints --2RROLLED SEPIA P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN' J.L. WEAVER prints SOS.-..1585. A The film is RETURNED TO SHELL (HOUSTON) We appreciate the privilege of serving you. DATE' Ve~ ~ruly yours, SCHLUMBERGER O~SHOR[ 5ERVICE~ DAVID ~ EBOI_. OISTNICT MANAO~N Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 March 10, 1986 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen' SUBJECT' SUNDRY NOTICE OF INTENT TO PERFORM A WORKOVER ON MIDDLE GROUND SHOAL WELL NO. C44-14RD Enclosed is a Sundry Notice of Intent to perform a workover, on Middle Ground Shoal Well No. C44-14RD. Shell Western E&P Inc. (SWEPI) is planning to perform an acid stimulation on the subject well. Please note on the Sundry Form that Harold Hedlund gave verbal approval to Susan Brown on March 6, 1986. If you have any questions concerning this notice, contact Susan Brown at (907) 263-9613. Very truly yours, , D. L. Yes]and Sr. Staff Environmental Engineer Alaska Division SBB/kka Enclosure SBBC/aogcc. 5aa .... STATE OF ALASKA .... ALASK, ilL AND GAS CONSERVATION )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL E3 COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Shell Western E&P Inc. 77-79 3. Address 8. APl Number 601 West Fifth Avenue, Suite 810, Anchoraqe, Alaska 99501 5o-733-20252-01 4. Location of Well Conductor 31 of Leg 4. of Sec 23, T8N, R13W. 5. Elevation in feet (indicate KB, DF, etc.) 105' 12. 4779'S & 1541'W from NE corner I6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 44-14RD 11. Field and Pool Middle Ground Shoal "G" PO01 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ['-] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see the attached prognosis for the details of the acid stimulation. NOTE' Susan Brown received verbal approval for this from Harold Hedlund on March 6, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Su .... ,---~ ~,.....~~ Title Production SUperintendent The space below for Commission use I ' Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Form 10-403 Submit "Intentions" in Triplicate Rev 7.1-Rt3 nnH "~uh~l~.nllpnt Rpnnrt~" in I~llnlir'nt, PLtOOIiC~IS ~I~S C44-14 ltd OPERATIONz A~id stimulate the STATOSt The veil vas recently worked over and fracture treated. The ~racturs propagated into a watered out zone and the well began pr~duoing 3~0 grc~s with an 85Z eater cwt, &vLre l~ne plug vas p~a~ed in the straddle pack assembly; Lgolat~ng the HK/HZ, This reduced production to zero. The Oft/OS vas initially perforated thru tubing after tho re-oospletion with very little underbalanoe. The veil vas recently reperfo~ated with good underbalence which only inoreamed production to 3 BOPD. A cased hole LeFT ran during the re-oospletion shoved very slow pressure build up. Wail'logs indicate that this zone'is veil developed in this veil. The 3uetifioetion ~or the vorkover v~e b~dt~ ~n an in~tia~ production rate o£ 150 BOPD ~rom the Olt/~S. This vas baaed on thy previous performanue o~ this zone Ln other ~elle. It appears %hwt the laser vellbore region is highly damaged, An acid stimulation should reduce the apparent da~ge. .'SCHEXATIC~ ~ee attached PERPORATIONSt GR/~S 1012~-10134 ' 10114'10123 Note fluid levee. PO0~ 2. Dilpllce die,el frol CTU to ~Loat cell with ~.5 volu~el of ~iltered ~n~eot~on water. water. 'IHPORTAHTs Filter all ~Iutds through a eked moanted 3 micron unit, 4. RIH with CTU with a high preeeur~ yeah ~ozzld to I02SO' while circulating filtered tn3ection v~t~r, takin~ r~turns on the tubing-esPied tubing annulus. Slowly re-enter the tubing at 102~7' and ltZH to ~X plug at 10983'. ¥~th CTU at 10963' cLrculat~ bottoms up with ~0 bbls of ~iltered in3e~tion eater. With CTU 3usa above PX plug circulate in 330 g~l of ~OX Ane~nium Chloride (the density of the AamoaLue Chloride'~ust be gre~ter th~n either the ECL/I{F or the HCL acid) while con2inuing to take returns from the production 't-ub~ng e~de. Displace the CTO vi%h oue CTU volume of fflttr~d ~n~ection water. This will place t~e top ~f the Amn~oM Chlor~d~ 5. #ith the CTU at 10170' atraulate tn 200 gal cf lOX HCL v/l~; USS vhtle continuing to take returne from the Dteplaoe the ~ vtth one CTU voZu~ o~ mud acid. Cloee the p~uotton tubing in. ~im vii1 pXaoa the top o~ the mctd mt 6. With the production tubtn9 closed pump the folloving treatment reetproeating the coiled tubing over the given interval. Do not alloy pueping ~&~el to exceed 1/2 bbl/m~n nor pumping pr~eeure to important that the coiled tubing gomm n~ 1ovv~ than 1013{' durtne the HCL/HF treatment. TREATMENT INTERVAL, 1000 'OAL 7, SX/,t, 5~ HCL-HF ','/.tX U66 10060-10134 ~00 OAL lOX ~CL W/I~ U66 10060-10134 v~ter. Yh£1e continuing to reciprocate coiled tubing. Open production tubing ltde. With coiled tubing at 102~' ~he coiled ruble). 9. Immediately place vel1 back on production. 10. POOH vith CTU and RD. 11. Report etab,J~,tze~ prgduc~ton to 5. R. Logan (7.t3-870-4465). Reooaeendeds ' _ Date~ C44-14RD 290' S.S.S.V. 9981' XO Sliding Sleeve 10025' X Nipple 10045 ' EOT Gas Lift K~MG Mandrels 1740' 3590' 5158' 6457' 7648' 9584' 9962' Perforations; lone IntervAl ~tC/HD 10320-331 ~tC/HD 10342-348 ~tC/RD 10370-376 itE/HF 10680-486 lit/liN 10720-766 IN/RR 10793-817 iN/Hit 108/~9-943 10267' WD Scoop Faced Yermauent Yacker 10623' Icl~lta w/d~y Perforations ~one - ZnCmrval iR/HZ 10995-111~ 10970' WD Permanent Packer 10983' X Nipple w/PX Plug 11001' .EOT February 24, 1986 Shell Western ~I~P Inc. 'O 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: JANUARY MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Gentlemen: Please find the enclosed subject reports of Drilling and Workover Oper- ations for the month of January. The.wells that were worked on during the month of January were the Middle Ground Shoal Wells, A 33-11, C 43-23, and C 44-14. ~. Each enclosed monthly report is submitted in duplicate. ~'~//~_~.~Ve'r~( trily yours^ D. U./Y)~S land I Sr. ~t~ff EnvirOnmental Alask~ Division\ Engineer SBB/kka Enclosures RECEIVED ~,qR 0 6 1986 SBBC/aogcc.2d STATE OF ALASKA · ALASKA ~ .- AND GAS CONSERVATION C~ ~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [~ Name of operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave., Suite 810, Anchorage, 4. Location of Well Alaska 99601 atsurface Conductor 31, Leg 4. 4779' S & 1542' W of NE corner of Sec. 23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 116' KB ADL 18754 7. Permit No. 77-79 8. APl Number 50- 733-20252-.01 9. Unit or Lease Name 10. Well No. C 44-14 RD 11. Field and Pool Midd ! e Ground Shoa ! "G" Ponl For the Month of January ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth' 11,162' 13. Casing or liner ru.n and quantities of cement, results of pressure tests Date' 01-29-86 Test all lines to 3000 psi. Test valves to 3000 psi. Test Annular preventer to 1500 psi. 14. Coring resume and brief description None 15. Logs run and depth where run Date' 01-25-86 Logs run' Temp/GR/CCL 6. DST data, perforating data, shows of H2S, miscellaneous data Date Performed' 01-24-86 Interval Perforated' 11,014-11,034' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SlG~EED --------,---- ~._¢:a=.,~TiTLE Production SuperintendentDATE_ 24/~./S..~.. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must b~filed in {duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. q,,l~mi* in d~nlJ~'ntp SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 FEBRUARY 13,1986 SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 500 W.'f~f~'~I~'iS~,~'L"'~PORT RD. ANCHO~GE, ALASKA 99518 ATTN' BETH CUZZORT Gentlemen: TE]V[PERA~IJRE SPINNER L(~, Enclosed are lBL prints of theCASED HOLE RFT & PRODUCTION LOGS (2) Company SHELL WESTERN E&P INC. , Well. MGS C 44-14 RD Field MIDDLE GROUND SHOAL Additional prints are being sent to: 1BL prints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON: TX. 77001 ATTN' R.J.VALLEJO ,WCK 1134 .on~ , County. KENAI State ALASKA "~BL Prints ,j' STATE OF ALASKA '~,, I ALASKA OIL & GAS CONSERVATION COMM. ~ 3001 PORCUPINE DR. ~-ANCHORAGE, ALASKA 99501 A-T~.:._ H.W. KUGLER 2BL mrints SHELl, WESTERN E&P INC. 601W.FIFTH AVE;SUITE 810 ANCHORAGE~ ALASKA 99501 ATTN' T~ ~n~ 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL ~rints SHELL"PLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NORTH STAR ROUTE P.O. BOX 485 W.iK RD. KENAI, ALASKA 99611 ~prints --2RROLLED SEPIA P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN' J.L. WEAVER prints We appreciate the privilege of se~ing you[ ~. ~~IE~G~;'FSHOR E SERVICES DAVID R_EBOL OISTI~ICT MANA~31'R SCHLUMBF'R(~F'R OFFSHORI= SF'RViCF'$ Division of Schlumberger Limited Anchorage Shell Western E&P, Inc. 601W. Fifth Avenue, Suite 810 Anchorage, AK 99501 A~ention: Mr. Joe Fram HOUSTON, TEXAS 77001 December 29, 1985 PLEASE REPLY TO SCHLUMBERGER OFFSHORE SERVICES P. O. Box 1001 Kenai, AK 99611 Attention: Shelley Ramsey Gentlemen: Enclosed are 2 BL printsofthe. Company Shell Western E&P, Inc. Field Middle Ground Shoal Gamma Rav/CCL on' ,Well. Middle Ground Shoal "C" #44-14 R.D. , ,Coun~ Kenai Additionolprintsore being sentto: 1BL printsplus original film Shell Western E&P, Inc. P. O. Box 527 Houston, TX 77001 _AY_tn: Log Files, WCK 4147 1BL prints Shell Western E&P, Inc. P. O, Box 527 Houston, TX 77001 Attn: R. J. Vallejo, WCK 1134 i BL ..pri~fs plus I Reverse F~l'~"d~ Sepia Staf~ of Alaska Oil & Gas Conse~ation .'"'"Commission i__ ~001 Porcupine Drive · iAnchorage, AK 99~1 ~tn: H. ~ Ku~er 1 BL ~rinfs ......... Shell Platform "C" c/o Shell Kenai ~ffice North Star Route #1 P. O. Box 485 Wik Road Kenai~ AK 99611 I BL prints plus 1 Mylar ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99501 Attn: John C. Havard prints 1BL prints plus 1 Reverse Rolled Sepia Chevron U.S.A., Inc. P. O. Box 107839 Anchorage, AK 99510 Attn: J. L. Weaver The film is returned to Shell-Houston We appreciate the privilege of serving you. prints PI,RAgE SIGN AND RRTIIRN ONE COPY_DF_. THIS TRANSMITTAl,. THANK, YOI] DATE ~ ~J.~ka b,, ,.~ . . Very truly yours, SCHLUMBERGER OFFSHORE SERVICES $OS--I 56 §-A David N. Rebol DISTRICT MANAGER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuwlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Shell 0~il Company 77-79 3. Address 8. APl Number John Douglas, P.O. Box 4500, Kenai, AK 99611 5o_733-20252-01 4. Location of Well P1 atform C Leg 4, Conductor 31, 4779' Sec. 23, T8N, R13W. S & 1541' W from NE Corner 5. Elevation in feet (indicate KB, DF, etc.) 105' K.B. 6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name HGS 10. Well Number C 44-14RD 11. Field and Pool Middle Ground Shoal "G" Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pr0posal' Perforate and test the HE/HF and HC/HD(L) zones. 9/14/83 - MIRU Dresser Atlas. Perforated 4 holes in HE/HF (10,480-10,484). 9/15/83 9/22/83 - Tested zone. 9/23/83 -APerforated 4 holes in HC/HD (10,370'-10,374~. Rigged down Dresser Atlas. 14. I hereby certify that the foregoing is true and correct to the best of my knowlbdge. Signed '~~& Title Mgr. Production Adm. The space below for Commission use Date ,~10/27/83 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 W~LL RE¢O~PLET~ON REPORT k~rker Ho~izons · -- . · __ i _ /i ~L? / ! P~oducIion Data ,,~ __ _ -- ii iii Depbh ,m I nltlal Production -- -- J_ / · Sio,d m mi ,i Ado~l. Prcd. D.-~ · il i _ L -- Calculald P~ential _ i m __ iii il __ __ J I I mm j ~ i m · i j~ __ i,,,i · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION O-i-HER '~I DRILLING WELL COMPLETED WELL 2. Name of Operator _ 515[I_1_ 0IL C0~.t~JIY 3. AdOres$ ATTN' PRODUCTION SUPERINTENDENT 4: Location of Well Platform "C" Leg 4, Cond. 31 7. Permit No. 77-79 8. APl Numner 50-733-2fi?.~?-0! 9. Unit or Lea~e Name 10. Well Number 4779' S 1542' l,I from N.E. corner Sec 23, T-8-H, R-13-H C 44-!4 RD 11. Field and Pool 5. Elevation in feet {indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. FIELD - ~ POOL KB=lO5' ] ADL 18756 ' 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data MIDDLE r~ROllND SHF1AL NOTICE OF INTENTION TO: (Submit in Triplicate) Per%rate ~ Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [--i Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Dup;icate) [] Altering Casing [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposod work, for Abandonment see 20 AAC 25.105-170). See attached. 14. I hereD¥ certify tha~ the foregoing ~s true and correct to the best of my knowledge. o"ignc~_/,~ //~ T tleM.Or_ ..... Production Administration The space below for Commission use Date CohO,lions of Approval, if any: Approved by ORIG~'NAI. SttlEI Approved COp), ~.? Returned BY i. ONNIE g. SlliTI ~,~ O,oe, of , , .: COMMISSIONER the Cornm,issiQ~.:~ ,.~'ale AUTHORITY FOR EXPENDITURE oq-'r. J aRANC~ OFFiCe PRODUCTION PACIFIC DIVISION LOCATION OF PROJECT WQRK ORDER NUMBER C44-14RD. Platform "C" Middle Ground Shoal Field Kenai, Alaska LOCATION NUMBER DESCRIPTION 1ORIGINATING OFFICE HOUSTON SHE LL'S 100% COST BUDGET 33 NON-BUDGET NO, DATE P~[PklIED J DAT~ 8/15/83 1 %SHARE E~E~E T~AL BUDGET' POSITION JUSTIFICATION: Perforate HC/HD(L) and HE/HF zones in C44-14RD Non Operators ApproVal Required Not Requested by' T. S. Burns J. H. Douglas $35,000 SU=--?OTAI.S $35,000 AVAILABLE IN BUDGET NEW CAPITAL FUNDS REQUIRED BY BUDGET REVISION $11,600 $11,600 $11,600 RE:TIREI~tENT EXPENSE: I TOTAL COST ,,, ~ $11,600 See Attached Justification CONTINU E~g O V [ ~ ,iL ~ APPROVALS Justification Pressure Buildup Perforate HC/HD(L) and HE/HF C44-14 RD. Middle Ground Shoal Field Funds totalling $35,000 ($11,600 Shell's 1/3 share) are requested to~ perforate the HC/HD(L) and HE/HF in C44-14RD. The economics are as fol 1 ows' Shel 1 Net Total Gross Expenditure $11,600 $ 35,000 Oil Increase 14 42 P. V. P. A.T. $50,000 $150,000 % P.V.P.A.T. 428 4.28 Pay Out (Months) 4 4 C44-14 was drilled and completed in December 1974. Initial production was 1000 BDO (20% cut). Production declined rapidly to 170 BDO (30% cut) by 1977. Well C44-14 was redrilled and completed in March 1978. Initial production was 447 BDO (44% cut). Production again declined rapidly to +200 BDO (8% cut) by 1979 and remained relatively constant until September 1982. Since September 1982, production has decreased to the current rate of 106 BDO (3% cut). C44-14RD was reviewed in detail to determine the reasons for its low productivity and cut. Initially it was believed that the well had high skin damage. The well was reperforated in 1981, acidized in 1982 and again acidized with a solvent prewash in 1983. A significant change in production did not occur with any of the above listed stimulations. It is currently believed that C44-14R suffers from insufficient injection. As can be seen from the attached injection and perforation profiles, poor injection profiles exist in two of the three offsetting injectors. A pressure build-up in C44-14RD would confirm the lack of water injection. If this is found to be the case, several items can be done to the neighboring injection well to increase the waterflood efficiency. A pressure build-up in C44-14RD should not be damaging. With the well producing a 3% cut, damaging crossflow of water into an oil producing zone would be minimal. Also noted in the review of C44-14RD was that several zones which were potentially oil productive were not perforated. The most prominent is the HE/HF. Well C44-14 (original hole) was located some 500' east of C44-14RD. In this well, the HE/HF calculated to be wet and was never perforated. C44-14RD was drilled into better quality rock and the water saturations in the HE/HF were similar to the other pay opened in this well. Perforating the HE/HF was recommended for the completion, but was deferred due to uncertainty about the zone. There is still uncertainty about the HE/HF and limited perforating is recommended. Only four holes will be opened and the well tested before the entire zone is opened. If the HE/HF is watered out and at high pressure, limited perforating will increase the water production but not as significantly as perforating the entire interval. Both the HC/HD(L) and portions of the HI/HK also calculated oil productive, but were not perforated. It is recommended to attempt limited perforating and test the HC/HD(L). If productive, the entire HC/HD(L) should be opened. At this time, 'we do not recommend opening the HI/HK. There is a very small shale break (+4') separating the calculated oil bearing zone from a watered out zone. Isolation across this interval is doubtful and the zone would most likely produce water if perforated. In 1976, a production log run on C44-14 (original hole) indicated that the HC/HD(L) produced 41% of the wells clean production. If similar ratios are assumed, opening the HC/HD(L) in C44-14RD would result in an increase of 70 BDO. Similar results are expected by opening the HE/HF resulting in a maximum expected increase of 140 BDO. A 30% probability of success and a 50% per year decline rate in incremental production is assumed. Your approval is recommended. TSB: mh Pressure Buildup and Perforation Worksheet C44-14RD Conductor 31 W. H. Room #4 Platform "C" Middle Ground Shoal Field Status' Objective- Well gas lifting 106 BDO (3% cut). 1. Obtain pressure build-up to confirm poor pressure maintenance and justify work on neighboring water injectors. 2. Perforate and test the HE/HF and HC/HD(L) zones. Procedure' 1. Rig up wireline and lubricator. Test lubricator to 3000 psi. Make drift run to bottom. Tag and record bottom. P.O.O.H. 2. With well flowing, run in hole with 2-3000 psi pressure bombs with 72 hour clocks. 3. Make following stops on the way in to obtain flowing pressure survey and check gas lift system for proper operation. Stop Location 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Surface 1000 2000 3000 4000 5OOO 6000 7000 8O0O 9000 9500 9900 10200' 10700' 4. Keeping the bombs at 10,700' place well on test separator. Test well for 24 hours recording surface test data hourly. 5. At the end of 24 hours, close production choke on tree. Close wing valve. Shut off injection gas, but do not bleed off annulus. Keep well shut in for 24 hours. 6. At the end of 24 hours, pull bombs and return well to production. Read charts and send data to T. S. Burns-Houston. 7. Produce well several days before proceeding with worksheet. Obtain production tests to determine damage (if any) caused by pressure build-up. 8. M.I.R.U. Dresser Atlas. Test lubricator to 3500 psi. 9. Test perforate HE/HF (10,480'-10484') using a 2-5/8" ho.llow carrier gun, i SPF, 0° phasing and decentralized with magnets. Produce well while perforating. 10. Test well overnight. If no appreciable increase in cut occurs, perforate entire HE/HF interval (10,46.5'-10,515') using a 2-5/8" hollow carrier gun, 4 SPF, 0° phasing and decentralized with magnets. Produce well while perforating. Test well to determine results of perforating. 11. Perforate HC/HD(L) in same manner. Zone Interval HC/HD(L)(test) HC/HD(L) 10370'-10374' 10365'-10395' 12. Send all test rates to T. S. Burns-Houston. Place well on production and test frequently until stable. Approved ~~.------~. Date ~//Z .cb/~ -2 DAllJM 34' "Item # i "Des'ctxiption Otis. Ball Valve Camco KBUG Mandrel Camco KBUG Mandrel Camco .KBUG Mandrel · Camco KBUG Mandrel Camco KBUG Mandrel Camco KBUG Mandrel Camco' KBUG Mandrel I i ' 10. '11. .12.. ~'13.' Camco KBUG Mandrel Guiberson UniPacke · Otis X-Nipple Otis X-Nipple E'O'T .Mule shOe r VII '"TQbin'q .. 3~" .9.3~ N-80.Buttre.ss .. "Casing 7". 29# N'80 .. .. ORIGINAL' PERFORATIONS - MARCH 1978 HC-HD 10,320-10,331 (11') HK-HN'(L) 10,720-10,725 (5') HK-HN (L) 10,725-]0,766 (41') .. MN-HR (L) 10,849z10,943 (94') ,Depth 284 2087 4224 5962 7448 84.74 9254 9733 10,078 7" 10,155 10,19~ '10,232 10,241 10,215 '. 11,290, 10,995-11,110 (115') ' -~_ HR-HZ , ~~ PBTD '· 11,290' Tagged BTM @ 11,217' REPERFORATIONS - JULY.1981 HC-HD HK-HN HN-HR .... HR-HZ .' July 1981 73' Fill 10320-10331 (ll') 10342-10348 (6') '10720-1 0736 (]6I)' 10850-7 0886 (36') 1 0905-10930 ( llOl2-11040 (28') 4 holeS/shot .. i ,4 ~ q3' ,433-/Y i 700 BD ~' ?/qO>-£g ££ I ~oo 8D ~ CLOSED ..... 05 ED /:iL L 52_ CZ /7o CL C L. 00 6o0 WESTERN E&P OPERATIONS J~ I 1 FIELD S H ELL-ATLA NTIC-STANDARD ,.,. TgN . r,r~$ ! .-.... m-~ / · , , ...... , , 71:! ~ .,., .~ i i I I I I l I I I INJECTION WELL PRODUCING WELL P.A. PLUGGED & ABND. {o.__ 4000 ,, [' ScALE-~N F":i'~ : ~00 I0 I00' 10 lO0 ~ ooo r.,q~ ~qE/o ;.'~ ~,. 1000 ' 1000 0t[ B/D .. lO000 10000 Shell Oil Company Q 200 North Dairy Ashford P. O. Box 527 Houston, TX 77001 July 13, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- In response to the July 1 letter from The Commission's Mr. William Van Alen, we enclose a complete history for Shell's West Mikkelsen Unit No. 4 well. The well's mud log was transmitted under separate cover last week. The requested reports of production tests, including time intervals, quantity and description of recovered fluids and pressure data were included on the Well Completion Report (Form No. 10-407) which was sent to the Commission on June 3. A separate page of the Well Completion Report Form was submitted for each of the four production tests. No drill stem tests were performed. Al so enclosed are the following routine reports' Sundry Notices - Subsequent Reports for Middle Ground Shoal Wells A12-01, A42-11, A43-23, C23-23, C44-14, A43-11, A42-14, and A24-01. a Monthly Report of Drilling & Workover Operations for Seal Island Well No. BF-47 //1. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH:mh Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator 7. Permit No. Shell 0il Company 77-79 3. Address 8. APl Number John Douolas, P.O. Box 4500, Kenai, ^K 99611 5o-733-20252-01 4. Location of Well Conductor 31, Leg 4, 40.78'S & 54.15' from Center Leg I @ 541.65'N & 1596.41'W from SE Corner Sec. 23. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 6. Lease Designation and Serial No. APL 18754 9. Unit or Lease Name Middle e, round Shoal 10. Well Number C 44-14 11. Field and Pool Hiddle Ground Shoal "~" Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). June 7, 1983 - Rigged up coiled tbg and tested equipment to 5000 PSI. RIH and tagqed bottom. Pumped 30 BBLS P-20, 30 BBLS 10% HCL, 60 BBLS 7½-1½ HCL-HF, 30 BBLS 10% HCL and displaced with diesel. POOH and RTP._~.~-~ 14. I hereby ce, qtify that t.l:)e foregoing is true and correct to the best of my knowledge. Signed Title Manager Prod, Adm. The space below for Commission use Date 7/12/83 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~X OTHER [] 7. Permit No. 77-79 2. Name of Operator She!l n~q 3. Address ~ ~ "; """ii'r'~''~. John: Douglas~ P 0'"BOx 4500, ~Kenai, AK 9961] 4. Location of Well Conductor 31, Leg 4, 40.78" $' & 54.15' from center Leg 1 @ 541.65' N & 1596.41"W from SE' corner Sec. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. I 6 . Lease Designation and Serial No. ADL 18754 12. 23. 8. APl Number so- 733-20252-01 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 44~14 11. Field and Pool Middle Ground Shoal "G'l Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. RECEIVED Alaska 0ii & Gas Cons. C0mmissl0n 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/X~ )~--~ Title Production Administration The space below for Commission use Date 5/19/83 . Conditions of Approval, if any: Approved by. ORIGINAl.' SIlIIEI i]Y LOItHIE C. SMITJI Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate COILED TUBING ACID S i'IMULATION C 44-14 W.H. ROOM CONDUCTOR MIDDLE GROUND SHi)A~ FIELD KENAI, ALA '.Ki~, Status' Well gas lifting iO! !: HC through HZ Zoo, ~. ~) (8% cut) from the Mechanical Details' See Attache,i '-i' Purpose' Acidize productio~ ,,:~,~,l.,ers with coiled tubing. Procedure' 1. M.I.R.U. wireline and lubricator. Test lubricator to 3000 .. psi. Pull ball valve.. .2 R.I.H. with gauge run. Clean out tubing as necessary to bottom. Tag and record bottom. P.O.O.H. Rig down wireline. Note' Shut well in at surface 12 hours before acid job to allow well to build up. 3. M.I.R.U. coiled tubing and Dowell acidizing equipment. Test lines, tree, and coiled tubing to 5000 psi. Test hydraulic system and B.O.P. Tubing and lines should be filled with diesel. Filter all fluids through a 2 micron filter. Note' If tubulars were found to be scaled, make a dyna drill trip to E.O.T. (10,241). Use diesel as circulation fluid. Produce well and take returns out production flowline. 4. R.I.H. with coiled tubing (no more than 100 FPM). Tag. bottom and record depth. . Pump.following acid treatment: S. ta~e Fluid Quantity 1 P-20 Solvent 1260 gal. (30 bbls) ' 2 10% HCL'~ow/additives 1260 gal. (30 bbls) 3 7½0- 1½% HCL-HF w/additives 2520 gal. (60 bbls) 4 10% HCL w/additives 1260 gal. (30 bbls) pUmp treatment at 1/4 bbl/min, and move coil tubing uphole to treat entire interval (10,320' - 11,110') during each stage of treatment. ~!i!6~ Displace acid to end of tubing with diesel and pump an additional ~,' .~: § bbls of diesel to flush coil. P.O.O.H. with coiled tubing. 7. ~'.Bl'eed off gas column and slowly return well to production. Test ""i~ well daily until stable. Date ~ ~--~,.- 7_4--- fE~Zt .... ~.. FILL . · ... "' Item #'.' De~c~ip~t~i~6_nI 44 l';".''Otis. Ball 2,. '41' :6. :9,. .. Valve ' Camco KBUG-Mandrel Camco' KBUG 'Mandrel Camco'. KBUG Mandre.1 Camco.· KBUG Mandrel Camco KBUG Mandrel Camco' KBUG M~ndrel Camco· KBUG Nandre'~ · Camco KBUG Mandr'u-, . ::'.i.:'.l 1 ..'. ·Otis'.. X-Nipple -. ".",'.,12;.' 'Otis'X-Nipple · .. ' ',..~]3,'. "['O'T Mule shoe , o . , ',' ". '-.'T~bi n'g'- _ '. "' 3~" 9 3~ N.-.80 Buttress .-·,~ :'~" 7": 29#' N...'80.' ! · · . · . , · , · .. · , , , , , '";. ;,. .. · . . ., .., OR IG I NAL 'PERFORATION~ - Gui'berson Uni Packer MARCH 1978 HC-HD': ': · HK,HN (L) · HK-HN (k) · ~ . · · RN-HR (L) HR-HZ. :. , , o , , . _~,,~' .PBTD ' 10,320-10,331' (1.1') · · 10,720-10,725 · (5') 10,725-.10,766 .. 10,849 '10,943 (4.'i ')' (94I)' 10;995-11 ,llO (ql,15 ' la~ka !1.,290' 284. .2O87 4224', 5962 7448 8474. 925,I. L.) .., {J ,' ,' 0,155 O,19d. 0,232 0,241 .' · . 10,215' , 11,290' .. · REPERFORATIONS - JULY.l·981 HC-HD' HK-HN HN-HR 10320-10331 (ll') 10342-10348 (6') 10720-10736 (16')' 10850-10886 (36') 10906-10930 (24'),. 11012-11040 (28,') 4' hole~/shot .. ' STATE OF ALASKA ALASK.''''~ ~iL AND GAS CONSERVATION ~ MMISSION SUI DRY NOTICES REPORTS OH WELLS; 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shel 1 0i 1 Company' 3. Address P.O. Box 92047 Worldway Center, Los Angeles, CA 4. Location of Well 90009 Leg 4, Conductor' 31, 4779' South and 5042' West of Northeast Corner of Section 23, T8N, R13W S.M 5. Elevation in feet (indicate KB, DF, etc.) 105'D.F. 6. Le~i~LDe~n)~n and Serial N o. 7. Permit No. 77-79 8. APl Number so- 133-20 9. Unit or Lease Name HGS 10. Well Number C-44-14RD 11. Field and Pool Middle Ground Shoal 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon r-) Stimulation [~ Abandonment r'~ Repair Well [] Change Plans ' [] Repairs Made [] Other [-J Pull Tubing r'-] 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). · Please see attached. RECEIVED ~bska 0il & Gas Cons. 14.~.._..=~. - ~ A I/']_1 hereby certify that the foregoing is truepnd~orrect tothebest of my knowledge. s'-o~~J/'~J~-~./~j//,/)7~j/~-~/~-~ T,t,e Mgr., Production Administration T~~~'=''¥x~tj'/''~V''-~lv~'es~acebelOwfOrcOmm/si~nuseFor' B Nevil] Da,e 4-22-82 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submi! "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duphcate WELL SHELL OIL COMPANY ..... RECOMPLETiON REPORT C-44-14RD SHELL OIL COMPANY Middle Ground Shoal ti 3/28/82 3/28/82 105' D.F. -- · Warker Horizons 11,290' 7 .._~.~.[ _29# N-80 _- 11,290' _-_ · -- 11 i iiiii i · __ -- 11 i -- , .. , ii ii ii ii -- i i -- i ii ii ~.,! i i · Product{on Data C,=r~"°A. ]". L _ S~.~Jt7, p~m N~C3 (t m ~) _ Depth w.~o.~ - ,lit i - ~,.~~=, HC/'~D 10320/i03~1 ' ~ '10342/f0348 __ I IIll I · 1 " RK'/I-I~ 10Z2o/fo/36 _ UN/HR, 108,5.0/10886., · 1, Q .9.06/fl0930., m, · HR/_HZ, 110'12/,1'1040 i, I nltlal Production -- ii1 il i iii · _ · Adcrtl. Prcd. D:-ta ~=, ~,~, _-,. . , , -- : , · Calculated P~ential i ii ii ' 11 iisi i i ii __ ii ~ ii _ E, i ii Clean up perforations and stimulate well by spotting mud acid across producing formations using Otis coiled tubing unit. ~EEE~VE.D ami ddl e Ground Shoa 1 l~C~, ,'i l= ~I'i'iCNII'~<~ Kenai, Alaska 3/28/82 3/28/82 ii i ii mm m i III mil I I I I _ II II I II m I II I m m' I I Il I C-44-14RD i i _ m i I i II STATUS· Well currently gas lifting 148 BPDG, 145 BPDO from the HC/HD, HK/HN, HN/HR, and HR/HZ. PROPOSAL- Clean up perforations and stimulate well by spotting mud acid across producing formations using Otis coiled tubing unit. 3-28-82 2:00 AM Rig down and move off C-22-26 and move equipment to 9:00 AM over W.H. Rm 4 and rig up on C-44-14. 9:00 AM Rigging up and pressure testeing to 5000 psig. to 11:00 AM Running in well w/coil tubing at 60 ft/min. 2:30 PM Tubing stopped at 10,160' and pulling hard to move it (12,000 psi Otis weight indicator.) Put well on production and opened gas lift injection line. Dowell pumped in 50 bbls diesel while moving tubing from 9,800 to ]1,200. Tubing moving free new and working up and down good (9000 Otis W.I.) 4:25 PM Stopped tubing at 11,110' started pumping acid as per worksheet. 7:00 PM Pumped all the acid and started out of hole with to 11:00 PM coil tubing. Out of hole with coil tubing and rigging down to move. III i iii i i mil m · i --I SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL ~ OTHER 2. Name of Operator Shell Oil £nmpany 2. Address P.O. Box 92047 Worldway Center: Los Angel~ C.A 90009 4. Location of Well Leg 4, Conductor 3], 4779' South & 5042' West of Northeast corner of Section 23, T8N, R13W S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 12. I 6 . Lease Designation and Serial No. ADL 18754 7. Permit No. ~' 77-79 8. APl Number · 50-133-20 9. Unit or Lease Name MGS 10. Well NUmber C44-14RD 11. Field and Pool Middle Ground Shaol Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~[ Abandon [] Stimulation [] Abandonment [-~ Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see attached Subsequent Work Reported 3-23-82 14. I hereby certify~ja'~ the ~f~eregoing is t'rUe and correct to the best of my knowledge. The space below for Comrr~ssion use For.' B. Nevi ] ] Conditions of Approval, if any: 8'¥ H,~t~.~l( W. KUGLEII Approved Copy ~turnr~d COMMISSIONER the Commission Approved by Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 C44-14RD STIMULATION PROGNOSIS STATUS' Well currently gas lifting 148 BPDG, 145 BPDO from the HC/HD, HK/HN, HN/HR, and HR/HZ. OBJECTIVE' Clean up perforations and stimulate well by spotting mud acid across producing formations using Otis coiled tubing unit. MECHANICAL DETAILS' See attached schematic PROCEDURE' 1. M.I.R.U. wireline unit and lubricator. Test lubricator to 3000 psi. Run in with'wireline and retrieve ball valve at 284'. POOH. Make drift'run with 2-!/4" tools to bottom (tagged bottom at 11217' in 7/81). POOH. and rig down wireline equipment. 2. Shut well in at surface - do not bleed casing pressure. 3, M.I.R.U. Otis coiled tubing unit and Dowell acidizing equipment. Test tree and coiled tubing to 5000 psi. Test hydraulic system and BOP. 4~ Run tubing in the hole slowly (no more than 100 FPM). Tag bottom (+11217'). If fill is above bottom perforations at 11,110', notify K. J. Evans (713) 870-2342 or (713) 531-8676 (home). e With coiled tubing at ll,llO', spot 400 gallons of 7% HC1 with 0.3% W-35, 0.2% F-75N and 1.0% A-200. Slowly move coiled tubing uphole while spot- ting acid to cover all perforations (HN/HZ, 10,849'-11,110'). Displace coiled tubing with 10 bbls. of diesel. 1 Stop coiled tubing at 10,800' Wait 30 minutes after clearing coiled tubing of acid and pump 15 bbis. of diesel to displace acid into perfs. 7· Run coiled tubing to ll,llO' Spot 400 gallons of 7-1/2% - 1-1/2% HC1-HF acid with 0.3% A-200. Slowl$ move coiled tubing uphole while spotting acid in order'to cover all of the perforations (HN/HZ, 10,849'-11,110'). Dis- place coiled tubing with 10 bbls. of diesel. , Stop coiled tubing at 10,800' Wait 30 minutes after clearing coiled tubing of ac~d and pump 15 bbis. of diesel to displace acid into perfs. · (Repeat Steps 7 & 8 one time). After repeating Steps 7 & 8 one time, raise coiled tubing to 10,736' · Spot 120 gallons of 7% HC1 with 0.3% W-35, 0.2% F-75N and 1% A-200. Slowly move coiled tubing uphole while spotting acid to cover all perforations (HK/HN, 10,720'-10,736'). Displace coiled tubing with 10 bbls. of diesel. 10. Stop coiled tubing at 10,600'. Wait 30 minutes after clearing tubing and pump 10 bbls. of diesel to displace acid into perfs. ll. Run coiled tubing to 10,736'. Spot 120 gallons of 7-1/2% - 1-1/2% HC1-HF with 0.3% A-200. Slowly move coiled tubing uphole while spotting acid to cover all perforations (HK/HN, 10,720'-10,736'). Displace coiled tubing with 10 bbls. of diesel. 12.. Stop coiled tubing at 10,600'. Wait 30 minutes after clearing tubing of acid and pump 10 bbls of diesel to displace acid into perfs. (Repeat steps 11 & 12 one time). 13. After repeating steps ll & 12 one time, raise coiled tubing to 10,348'. Spot 120 gallons of 7% HC1 with 0.3% W-35, 0.2% F-75N, and 1% A-200. Slowly move coiled tubing uphole while spotting acid to cover all perforations (HC/HD, 10,320'-10,331', 10,342'-10,348'). Displace coiled tubing with !0 bbls. of diesel. 14. Stop coiled tubing at l0 250' Wait 30 minutes after clearing coiled tubing of acid and pump ~0 bbis. of diesel to displace acid into perfs. 15. Run coiled tubing to 10,348'. Spot 120 gallons of 7-1/2% - 1-1/2% HC1-HF with 0.3% A-200. Slowly move coiled tubing uphole while spotting acid to cover all perforations (~HC/HD, 10,320'-10,3311, 10,342'-10,348'). Dis- place coiled tubing with 10 bbls. of diesel. 16. Stop coiled tubing at 10,250'. Wait 30 minutes after clearing tubing of acid 'and pump 10 bbls. of diesel to displace acid into the perfs. (Repeat steps 15 & 16 one time). 17. After repeating steps 15 & 16 one time, POOH and rig down. Leave tubing full of diesel (10 bbls) pending further use of coiled tubing unit. 18. Put'C44-14RD back on gas lift production. Test well for several days until well is producing at stable rates. Report rates to K.. J. Evans in Houston. Return well to regular test rotation. KJE'ckk ~/~0 APPROVED ~.M. ~ ~_~. , DATE DATL 34: 'Item #' "D~s'arip'tiOn 1 '. Otis. Ball· Valve ' 2. Camco 'KBUG Mandrel 3... Camco --4.' Camco 5 .. Camco 6. Camco 7. Camco 8. Camco 9. Camco 10. 11. 12. :13. KBUG Mandrel .KBUG Mandrel KBUG Mandrel KBUG Mandrel KBUG Mandrel KBUG Mandrel KBUG Mandrel Depth 284 2087 4224 5962 7448 8474 9254 9733 10,078 Guiberson UniPacker VII 7" 10,155 Otis X-Nipple .~.'" ' 10,19~ Otis X-Nipple - . '10,232 E.O.T. Mule shoe 10,241 '-'TUbing - . 3½. 9.3~ N-80 Buttre.ss - · .. ' 'casing_ 7". 29# N-80 .. . 10,215 . 1,290' , : : FILL · . ORIGINAL PERFORATIONS -'MARCH 1978" _:_ HC-HD 10,320-10,331] (ll') · HK-HN (L) 10,720-1·0,72~ (5') - HK-HN'(L) 10,725L.10,766 -. ~N-HR (L) 10,849-10,943 . HR-HZ 1 O, 995-11,11.O -i (41 ')' -. (94') · . ~_ _ PBTD 1'1,290, Tagged BTM @ 11,217' July 1981' Page 73' 75 .. REPERFORATIONS · . HC-HD HK-HN ~ ~N-HR ... HR-HZ - JULY. 1981 Fill 10320-10331 (ll') 10342-10348 (6') 10720-10736 (16') 10850-i0886 (36') 10906-i0930 (24') 11012-i1040 (28') 4 holes/shot .. O. -I I I ! .~, .o WESTERN E&P 'OPERA'-'ONS i SHELL'ATLANTIC-STANDARD ' I I ~ . I ' · , ........ ,~'~- A~ ~ ~ ........ . " 1~ ,,, i 7"* '.', . ~ / / 1~441I / ; ~' / ' I -t]x~(. I / ~=~ / J . i I PATTerN .~..n- , ,~ ~ _ . . I ' I~o ~-o, /. I ~.I · / / /'.. .... '1 ' ,~ ~_ .:. . . · ' ' I ./ ~,~ ,~,~, ,' - -:. · ' !~~ / ~ ~ 7- ~'. - . i~~ / t ,../. . · - - ~ .. ...... fDS I ~1 ~ i · . ADL ]~75I ~ ~ 'i ~ ~4~ /~ INJECTION WELL ~z ~ ! ; t ~ I~' ~ ~ · ' i / . ~ ~~--~ --~ PRODUCING WELL' - I / ~ ~-"' i ¢~ · ' ' i /¢~t~' [ / ' ~ P.~ PLUGGED & ABNQ Page 3 Equipment CO'IL TUBING S~ECIFICAT]-ONS Length Width Power Pack 8' 4'l" Blowout Preventer 4' 2' Injector Head 5' 6" 4' Reel lO' 6" 8' Operators Console 9' 8' · o Hei hg~_~ 5~ 10' 10~ 6' ?~eight_ - · ' 68oo l s. 538 lbs. 5500 1 bs. '12,800 lbs. 3800 lbs. Description Working Depth (.1.255F) Working Pressure/Max PSI Tensile Strength/lbs. Tubing O.D./in. Tubing I.D./in. Wall Thickness/in. Capacity of Tube/gals. per 1 O0 ft. Capacity of Tube/bbls. per 1000 ft. Displacement of Tube/gals. per lO0 ft. Displacement of Tube/bbls. per 1000 ft. Tubing weight/lbs, per ft. -Standard Pipe_ 12,500 5,000 lO,O00 1. 000 .874 . O63 3. 120 · .742 ·964 · · 230 .630 .. Heavy-Wall Pipe 12,500 5,000 12,000 1. 000 .'840 .081 2.8 o .650 1. 200 .290 .810 ,o/c/ _ 6,".,',// f ~51 AlE OF ALASKA ALASKA OIL AND GAS CONSERVATION-~.OMMISSION SUIgDR ;OTICES AND REPOR. S ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX) OTHER [] 2. Name of Operator 7. Permit No. 0IL COHPANY 77-79 3. Address 8. APl Number P.O. Box 92047 Worldwa.v Center, Los Angeles, CA 90009 50-133-20252-0l 4. Location of Well Platform C, Leg 4, Conductor 31, 4779' S & 1542' W of NE Corner of Section 23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. i 6 . Lease Designation and Serial No. ADL 18754 12. 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C44-I 4RD 11. Field and Pool Middle Groun~ Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [-} Perforations Stimulate [] Abandon [] Stimulation Repair Well Fl Change Plans [] Repairs Made Pull Tubing [] Other [] Pul-ling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonn~ent [] Other (Reperf.) (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). · Please see attached OCT 0 2 ALaska 0il & Gas Cons. Anch0rags certify t t heforeg ingi he best of my knowledge. Signed TitleMqr., Prod. Administration The space below for Comm~,sion ~fe for B. Nevi 11 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Dale Form 10-403 Rev. 7-1-80 Subm~! "lnlenlions" mn Triplicate and "Subsequen! Reports" in guphcale SHEU. OIL COAdPANY RE¢OMPLETI'ON REPORT C44-]4RD i i SHELL OIL COMPANY ii 11 ii Unchanged , 11 11 i i 1111 , , lrt~Jd MIDDLE GROUND SHOAL .Reco mal_e tian _ rker Horizons 11 · _ _ i , _1 I I ill _1 L I · 6-18-8l 7-2-81 i ill, i i Ill I I , ]05' D...F~ ll ~390' 11,290' Production Data ~ m,,~-m~ ...... ~ C~-B/~ ,,, I Ill C~vtty-°A.. ?. L ILl I _ ii i Dept _ -- _m lztezvtl ?~:luced __ i Initial Production 10,320'/11 ,llO' Illll I I I I i i i i m mm ii i i m mn 29# ii i m i , i I ii i ]1 i i mi i i i I , i i , ,~'lO,2~l ' 10 '3'~0'/10,331"' 10~.342"/1 0~.348' , 10.,7,,20'/.1.0,,;725' , ln.725'/10.766' 10. 8_49 './l 0,.943' 10~'995'/11 ~11O' ' 10,792'/10~800 Ad,ti. Prcd. Data i _ i m m ii i i mi ii i! i i i i ii im i I i_ _ i i i iii _ i m i i i i ii i i i ill ii i i i i .__. __ i illi i ii i i i ill i i _ __ n lmm m I i I mi ii mi m __J -- -- -- Illll II Ill I I II - I ---- I I I -- ] i _ i ] immll II I · i I m I II I I iim III I _ m i _ _ mi Calculated Potential i _ m ii m mi m PerforatedfHC/HD (.LOWER) and reperforated 'HC~HD, HK/HN, HN/HR (lower), HR/HZ: ' HTDDLF GROUND SHOAL' ,, i~-~'NI$ ~riI~NIINt<S C44-14RD. ' ALASKA ,, 6-18-81 7-2-B1 Pla tforrl] ~, , IIBI I I I I I I I I Im I ~1 I III I I I II I IIII ] I I · I I I ] I m I I I .. · HN/HR HR/H . ' 6-18-81 Pull Ball valve. Run 2 1/2" and tools to ll,151'. 6-19-81 Ran Schlumberger packer flow meter survey. ., 6-29-81 Reperf HC/HD 10,342' - 10348' with Hyperdome II, 4 holes per foot. 6-30-81 Reperf HR/HZ 11,012' - 11,040', HN/HR 10,906' - 10,930' with Hyperdome I~, 4 holes per foot. 7-1-81 Reperf HN/HR 10 850' - 10 886' HK/HN 10,~20' - 10 736' with Hyp~rdome II, 4 holes per foot. 7-2-81 Reperf'HC/HD 10,320' _ 10,331' with Hyperdome II, 4 holes . per foot. Rig down Schlumberger and return to production. '. ~ I iii I J I i i I ii i i i ' i , i _ SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEASE REPLY TO July 28, 1981 500 W. International Airport Rd. Anchorage, Alaska 99502 Sh~] 1 n~ 1 r'r,mr~m, Alaska _Operations 601 W. 5th Avunue Suite 810 Anchorage: Alaska 99501 Attention: Gentlemen: Enclosed are 1 ]~ prints of the CCI4~E~' CompanyShell Oil Company , WelJ [4GS C-44-14RD Field Middle Ground Shoal , County. Kenai State. Alaska on: Additional prints are being sent to: 1 BL prints Shell Oil Company/Pacific Division P.O. Box 831 Houston, Texas 77001 Attention: Ed Scott 1 RFolded Sepia 1 BL .prints Atlantic Richfield Company P.O. Box 360 Anchoraqe, Alaska 99510 Attention: J.W. Hart 1 BL prints Shell Oil Company North Star Route 1 Box 485 Kenai, Alaska 99661 1 BL prints Shell Oil Company Western E & P Reqion P.O. Box 576 Houston, Texas 77001 Attention: E & P Files 1 RRolled Sepia 1 BL prints Chevron U.S.A. Inc P.O. Box 7-839 Anchorage, Alaska 99510 Attention: C.F. Kirkvold 1 BL prints Amoco Production Company P.O. Box 779 Anchoraqe, Alaska 99510 Attention: L.A. Darsow f Alaska Di~isio.q-Qf~JDi~l.. & ,_C~s Conservatiom~ 3.001 Porcup~e Drive ~~aska 99510 prints _ [C.~. ~tate of ~ka / , The film is Returned to Shell Western E & P Region We appreciate the privilege of serving you. RECEIVED JUL l .om Alaska 0il & G~.~ ~..,, ,,,,,.,,~,~ .:. Anchorage Very truly yours, SCHLUMBERGER OFFSHORE SERVICES DISTRICT MANAGER SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEX~E REPLY TO July 24, 1981 Shell Oil Company 601 W. 5thAvenue Alaska Operations Suite 810 Anchoraqe, Alaska 99501 Attention: Production Superintendent SCHLUMBERGER OFFSHORE SERVICES · 500 W. International Airport Rd. Anchorage, Alaska 99502 Gentlemen: Enclosed arel BL prints of the Engineered Production Logs Company Shell Oil Company , Well Middle Ground Shoal C-44-14RD Field Middle Ground Shoal , County Kenai State Alaska on: , Additional prints are being sent to: 1 BL prints Shell Oil Company/Pacific Division P.O. Box 831 Houston, Texas 77001 Attention: Ed Scott 1 RFolded Sepia ! BL prints Atlantic Richfield Company P.O. Box 360 Anchorage, Alaska 99510 Attention: J. W. Hart 1 BL prints Shell Oil Company North Star Route 1 BOx 485 Kenai, Alaska 99661 1 BL prints Shell O±1 Company Western E & P Reqion P.O. BOx 576 Houston, Texas 77001 Attention: E & P Files 1 RRolled Sepia 1 BL prints Chevron U.S.A. Inc. P.O. BOx 7-839 Anchoraqe, Alaska 99510 Attention: C. F. Kirkvold 1 BL prints _,~%moco Production Company P.O. Box 779 Anchorage, Alaska 99510 Attention: L, A. Darsow te of Alaska ~ Di~s/z~n__/).f_ Oil & .~_Gas Conservation 1 Porcup~e Drive ~ ~rage, ~aska ~0.~ ~ State o~ ~/ Alaska Oil and Cas Conse~ation Comm~on 30Ol Porcupine Drive Anchorage, Alaska 99601 The film is Returned to Shell Western E & P Region We appreciate the privilege of serving you. $0~--15~5-A RECEIVFD dUL ~ & Alaska O, & Very truly yours, Anchu,~[le SCHLUMBERGER OFFSHORE SERVICES V -DISTRICT MANAGER STATE OF ALASKA ALASKA O~_ AND GAS CONSERVATION COk. MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator Shell Oil Company 3. Address P.O. Bo~ 92047 Worldway Center, Los Angeles, CA 90009 4. L~ationofW~ll (At Surface) - _ Platfor~-~C, Leg 4, Conductor 31, 4779' S & 1542' W of NE Corner Cf Sec. '23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 12. I 6 . Lease Designation and Serial No. ADL 18754 7. Permit No. .-. 77-79 8. APl Number_ 50-133-20_252-01 9. Unit or Lea~e Name Middle Ground Shoal 10. Well Number C44-14RD 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: {Submit in Triplicate) Perforate 1~ Alter Casing D - Perforations Stimulate [] Abandon 1-] Stimulation Repair Well [] Change Plans I"] Repairs Made Pull Tubing [] Other(Reperf.) ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 0 [] 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). · ,. See Attached RECEIVED . , ~.,~,..~?~a ,JILL 1 3 1981 i~orm Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The $~ace below for Commission use For: B. Nev'ill f)a,e 7/9/81 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy Returned By Order of COMMISSIONER the Commission Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate JUSTIFICATION Cqq-14RD Reperforati on/Perforati on Total'gross funds of $48,000 are required to reperforate;and open new perforations in producer, C44-14RD. This well was redrilled 3/-78 because of fonn.~.ion impairment and mechanical deficiencies of the original well. The redr~-l~l rapidly declined from initial rates of 706 BDG~ 390 BDO to-~an average of 550 ~G, 200 BDO in its first year of production. This :vas substantially less than~n anticipated 800-1000;BDO, production response. No stimulations or re- medial activities have been ~tte'mpted since this well was redrilled. Current production averages 180 BDG, 160 BDO. A recent inflow survey of the open intervals revealed the following' HC/HD (11') 31 BDG HK/HN (48') 76 BDG HN/HR (94') 84 BDG HR/HZ (115') 114 BDG Total 305 BDG Although more than average fluid volume was produced that test, it did demon- strate that all perforated intervals contribute some-production. None are con- sidered completely wet. The production potential is considerably higher because of the over- injection in this area (patterH 5) by nearly 2500 BDW. That is the field high. Yet, estimated, water fronts place C44-14RD in an ideal location to produce numerous zones relatively water free. We also recommend, contingent upon production response of the reperfora- tions, to open additional intervals in the HC/HD. These sands calculate to be oil productive via the open-hole log suite. They are estimated to be out- side of'the injection water fronts. ~ - '- A production increase of only 40 BDO would pay out in less than three months (April/May, 1981 net operating profit of $14.06 per BO). Based upon offset well production and reserves potential of this area, a 150 BDO increase due to reperforating and 50 BDO due to the new perforations is expected. JRM/meb - -RECEIVED ,-,,, - JUt_. 1 3 1981 AI2ska Oil & Gas Cons. Commission Anchorage ' ' SAg C~.4-14RD MIDDLE GROUI.iD SHOAL FIELD, ALAS}CA REPERFORATION WORKSHEET STATUS' Gas lifting 174 B/D gross, 149 B/D clean (9.65 cut), 62 iqCFPD, from zones HC/HD, HK/HN (lower), HN/HR_, and HR/HZ ll ,390' PBTD' ll ,290' ,.,FCn~,;,iCAL DETAILS See at.tached drawing. PROPOSAL' To perforate HC/HD (lower). Also to reperforate HC/HD, HK/HN, HN/HR (middle), HN/HR (lower), HR/HZ. PROCEDURE' 1. IqIRU. Schlumberger with lubricator and grease injection head. Pressure test lubricator to 3000 psi. ' . 2. Pull Otis ball valve at 284'MD. Run 2-1/2" tubing gauge on sinker bar to bottom to check for fill and clearance. Record the results of this run. 3. Perforate selected intervals with 4 shots per foot using a Schlumberger 2-1/8" Hyperdome II perforating gun. Depths referenced to Dresser Atlas DIL survey dated 3/11/78. (Report these depths.) NOTE: An engineer will be on the platform to correlate GR/CCL log (dated 6/19/81) with DIL (dated 3/11/78) for perforation depths, and to coordinate communications with Houston engineering. Please consult Houston' engineering before proceeding with 2-6. These steps are contingent on the results from step 1. SEQUENCE ZONE DIL DEPTHS 1 HC/HD 10,342/10,348-(6') i-._~ 6' See Above Note 2 HR/HZ 3 HN/HR 4 HN/HR 5 HK/HN 6 HC/HD PHASING 0o 11,012/11,040 (28') 90o 10,906/10,930 (24') 90o 10,850/10,886 (36') 90o 10,720/10,736 (16') 900 10,320/10,331 (ll') 131' 4. Keep wet.l ',gas lifted down" wh.ile perforating. ~.-:- - 5. Test each zone after perforating for 12 hours_~r~ntil ra~e stabilizes. Send results to Mr. K' J.-Evans, RM 7578 Wood creek, Houston, TX 77001. RECEIVED Oil & Gas Cons. 6. Rig down Schlun;1~erger' and 'replace ball valve. 7. Test well rotation. for 3-days after operation and then resume normal testing APPROVED DATE CKB/meb RECEIVED .JUL 1 5 1581 Alaska Oil 8, Gas Cons. Comm}ssior~ /~inchorage t ','J _ i - ! # --' ' -R [C ~ I:il. lE D . : - '" '.J!-J--k 1 ;~ 138'1 '- . Alaska'Oil '& Gas Con's. Anch~raee ii JUI,,I OEC JUN OEC VAIl JLIlt SCl.' · lq . 15 LOC_ ~TI o r'4 · ' 3 ·_-'u 2-q - .. I I ! I I I I 1 t .- - i I I I I- .I ! 'l ! ! ! ! ° C~roff (J~ ~ ~ ~n~l ~ POS 2055~ ADL 22050 j:- ~ .'-:~ R~-CE ! V ~ ~. - ~--~_~~__~ -~ ...... . ~as~Oii & ?s Cons. Conu. is~:~ ,j'":tt:::::-~ " - Anchorage 'j'"~,~ ~.6~.~ ~0.~ I LAYER MAP HCl~I ~.- ! i I I : ! L I- I ! ! ! · ! ! ! ! I ! ! ! ! I __t. ADt t I 1 I ! I · ., J I 1 I I I I I I I I I I I I I ! ~L .... I I I POS ~DL ]5751~ 5] 20 jill 1.3 19gi PaPSS - ! I I I I -LEGEND- · -~--N.P. NOT P[RFORAIED -~B.P. BRIDGE PLbG --~ C.S. CE'~E NT P.A. PLUGGED POS 24a£ Ac.. 'il -~.~,,m I I ! i I I I I I I 11] 1~ i: MIDDLE GROUND SHOAL FIELD J~'~ELL-&TL~NTIC -El AND&I~J) LAYER MAP NKIH~ (~'~ WELLS LOCATED AT HK MAR'K[~ POS 5]~0 Ac. I ' - 221 I I · I I I '! I I ' ' I I I '1 ! ! I I 23-23 * 523 ..... " 22-2,"d. 0 / . :1~ '!-:"' ' A INJECTION wE'LL- P[ RF ORATED ! I i I : I I I : I I I .e- l RECEIV .-~ N.P. NOT PERFORATED -~ B.P. BRIDGE PLUG · '~-C.$. CEMENT SOUE£ZED P.A. PLUGGED & ABND. [.L.~' G.A CooA r'a ri:pon Ju¥. 196.9) POS 20555 AD[ 22050 244~ Ar.. JUL ! ~ L" SC.ALi ~N FEET Oil & aas Oons, ._ ~ I'aP S,S- o,,~ D MIDDLE GROUND SNO&L FIELD &N l LL --AT.t. ANI*C LAYER MAP MN~R (~ WELLS LOCATED AT H~ MARXER I - I - I - I ! I I I I I ! I I I I I I I ! o I I I I ! ! 1 ! ! ! ! ! ! ! ! ! · 1 I I I I i I I I I I I I I I I I · i i I ! I I I I I 0 0 I 0 0 { RECEIVED JUL 1 NaS~ 0il & Gas Con~ Anchorage SAS '1- PaP$$ I ! I I I BUERLES & 111,'~D -LEGEND- A ~'E LL'- ,~.TE ~ INJE CTIOI~ P[ R F ORA'I' ED - - -,G~N.p.NO1 PERFORATED -~C.S, CE~qENT SOUEEZED ~.S. SLIDING 20556 mill m SCALE tN FEET 3mi _ MIDDLE GROI..I~ID SHOAL FIELD LAYER ~LL$ LOCATED AT HN MARKER I I { I ,' l I I ! I I I I I I I. I !$ j '. I I I I I ,c3 -II Oo / I~, "-'-"'~ /""Mi., ' -r ~--~-~:,~T .... · ~-2~ ~ I / k { /, . ~ 3~-2E I 0~~ ' _ ~-- ~. . ~ ~'-" ""1' ' ~ ~"-~- I '. I -- ' 'l'J - I SIS _ ~.[__.. ,s; .+ i ~/'' -' - RECE! JUL 1 ~ ._ Anchom MIDDLE {;ROUND 5{.IOAL FIELD J IN[ LL--~TL~TIC --{TA~D&RD J LAYER ~AP H~Z/U{ J '-- I I '1 ! ! --2 J ! I I I BUSSL£S ia 111/S0 -LEGEND- A ' PERFORAIED -~----N.P. IvOT PERFORA"JED · '.~--B.R BRIDGE PLUG -.~-C.$. CEI~EN] SOUE£ZED -~- S.$. SLIDING SLEEVE -~P. A. Pt UGGED & ABNO. 20556 _. ]1 DRESSER &'fLAS'DIVIStON, DRESSER INDUSTRIES, INC. P.O. BOX 1407, HOUSTON, TEXAS 77001 713 784-6011 TW× August Z8, 1978 State of Alaska Division of Oil and Gas .Attn: O.K. Gilbreath, jr. 3001 porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Transmittal of Data Shell Oil Company ( Final Prints ) HCC 999 .. Enclosed please find the data as described below' ~%LL NAME AND LOCATION DATA Shell oil Kenai, Alaska Shell Oil Company M.G.S. C-4Z-23 Middle Ground Shoal Kenai, Alaska Z pr ints 1 Sepia Z prints 1 Sepia Please acknowledge receipt of attached copy of this letter. the information by signing and returning Very truly yours, the 01in R. Holt Manager Log Analysis Dresser Center Center For:u SUBMIT IN D ,* STATE OF ALASKA struct,i,n~ o. reverse side; 5. API N~CAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20252-01 WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLETION: WELL OVER EN BACK RESVR. Other 8. UNIT,FAX/2VI OR LEASE NAME 2, ~,,,~,IZ or orZRATO~ MGS Shell Oil Company 9. W~.LNO. 3. A,~R~SS O~ Or~*TO~ C-44-14 RD 1700 Broadway, Denver, Colorado 80290 ~0. Fm~ A~D POO~., O~ Wm~CAT 4. LOCATION O~ WZLL (Report Zocation c~earZy a.d in accordance w~th any State requirements)* MGS "g" Pool At suvaco Platform C, Leg 4, Conductor 31, 4779'S & 1542'W of NE OBJECTIVE) Corner of Section 23-T8N-R13W, S.M. Section 14-T8N-R13W At tod prod. interval reported below 467'N & 916'W of SE Corner of Section 14-T8N-R13W, S.M. S.M. At total depth 1006'N & 1196'W of SE Corner of Section 14-T8N-R13W, S.M. ~..PmUmT~O. 77-79 IF 1VIULT~PLE CO1V~L., i 1. ' D ~ow ~¥* aoTaa~ TOOLS 9399 TVD ] 9290 TVD , Total =.PRODUCING I~TE/qVAL(S>, OF THIS COMPI. JgTIO~--'IX)P, BOTTOM, NAME (IVIDAND'PVD)* Top: 10,316' MD & 8500' TVD Btm: 11~112' MD & 9161' TVD 24.TYPE ELECTRIC AND OTHER LOGS RUIN[ FDC/GR, BHC Sonic~ DIF/GR/Cal ZS. - CASING RECORD (Report all strings set in well) CASI2~G SIZE WEIGHT, LB/FT. DEPTH SET (1VID) ~ '13-3/8" 9-5/8" 40 & 43.5 6720 26. LINER 1R.EC OtR23 28. PERFORATIONS OPEN TO PRODUC~PION (intervaI, size and number) 11,110-10,995 10,943-10,849 10,817-10,793 all perfs - 4 holes/ft 10,766-10,720 10,331-10,320 i i 30. PRODUCTION HOLE SIZE 6. LEASE DI~IGNATION A_ND SERIAL NO. ADL ~ /~?~.~ 7. IF INDIAN. ALLOTTEE OR TRIBE NA1ViE 23. WAS DIRECTIONAL SURVEY MADE Yes DAT~ Or T~ST, I]-~OUlqS TESTED '[CHOXE SIZE [PROD'N FOR 3/31/78 , I 24 1 2s/64 FLOW, ~BING [CAS~G PR~SU~ [CAL~~ OI~BBL. ~SS. [ ' [24-HOUR R~ ,I s0I 7a0 I~ [ 2064 31. DISPOSITIONOF GAS (Sold, used f~r ]ueI, vented, etc.) Gas l~ft, fuel, sold C~A~LNTING RECORD I AMOUNT PULLED 2670 cuft - 1300 s~ - -- 27. TUBING 1RECOFJ) 3-1/2 10~241 "' 10,155' 29. -ACID, SHOT, F2ACI'URE, CEax, IE:NI['~(~, ETC. DATEF~RSTP~D~CT~NIP~OD~cT~NME~H~D(F~wh~g~ga$~ift~pumpmg-sizeandtype~fpump)3/28/78 Gas Lift [WEifI~%wl~iPr°ducing °rt-;a) Prod OII_~--BBL. GAS~-MCF. WATER~--BBL. 1. 2064 [ 1576 1376 764 GAS--~viCP. [ 1576 32. LIST OF ATTACHMENTS ~ell History I GAS-OIL r~,%TIO i WA~BBL. [ OIL GRAVITY-API (COI:I~.) 1376 1 ITEST WITNESSED BY 33.I hereby eertify~_~, t~otng and attached informationiscomplete and correctasdetermined from all-available records APR 2 5 1978 SIGNED * .... , TITLE Div. 0pets. Engr. DATE · (See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any attachments Items 20, and 22:: If this well is completed for separate prcducti©n from more thc~n one interval zone (multiple completion), so state .n iter~ 20, ond in ite'~ 22 show thc. prcJ.c~;'~g interv,~l, or ~tervals, top(s), bottom(s) and name (s) (if any) for only the interv01 ret~orted ir~ item 30. Submit a separate report (page) on this form, adequately identified, for each additional ir~te~val to be seperately produce~t, show- ing the ack.titional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cemer~ting and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each ~r~terva to be separately produced (See instruction for items 20 and 22 above). SUMMAI{.¥ OF' F(,itMATI(.,N TF_..STS IN('I_,~Ii)IN(~ INTEi~VAL T~ST~'r). m~I~$UrtE D^TA AND RECOVERIES (;p OIL7 GAS. 35. GEOLOGIC MARK~ VVAT~II AND MUD NAM~ M~AS. D~mT~t '~aU~ V~T. GN 9650 7976 GO 9690 8007 GR 10,059 829B GS 10,146 8362 HC 10,316 8500 HD 10,395 8565 HE 10,465 8623 HF 10,513 8663 HI 10,556 8699 HI< 10,624 8755 , , , HN 10,767 8874 DATA. A'I'I'A<'I{ "IRIF. F OF__,SCJl~EeP~-TION.~, 'OF LITIIOLOGY. POIR¢).%ITY. F[{AC'TURF~. APPA.R~NT DIPS H~ 10,945 9022 ^N~) .~:'r~C'TE. s,.~wS 0~' tnt., C~S 0~ ~v^Tm~. .... HZ 11,112 9161 TD 11,400 9399 NEW OIL WELL MIDDLg GROUND SHOAL SHELL-CHEVRON USA-AMOCO-ARCO LEASE DIVISION FROM: 1/19/78 - 4/5/78 . COUNTY MGS WESTERN WELL NO. C-44-14 RD ELEV 105' DF STATE ALASKA ALASKAI MIDDLE GROUND SHOAL! C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF "FR" TD 11,350. Bldg mud wt. Located Platform C, Leg 4, Conductor 31; 4779'S & 1542'W of NE Corner, Section 23- T8N-R13W, S.M. (592'E & 5329'N from sfc) AFE provides funds to abandon lower portion of MGS C-44-14 (producer SE/4 Section 14-T8N-R13W) and mill window in 9-5/8" csg @ 6720' (5767 TVD) to kick well off & redrl as C-44-14 RD. Could not pull gas valves & sliding sleeve w/slick line. MI WL & prep to attempt to pull with 5/16 braided line. JAN 1 9 1978 TD 11,350. Circ'g. Blt mud wt to 12 ppg. RU 3/16" WL & fish'd gas valve @ 9394'. Circ'd in mud to kill well. JAN 2 0 1978 TD 11,350. NU & try'g to test. Mud: (.624) 12 x 45 x 5.6 TD 11,350. Test'g BOP. Test chk manifold, lines, valves, rams & pipe to 3000 psi & hyd to 1500 psi. TD 11,350. Pull'g tbg. Fin'd test'g BOP; found hanger leak'g. RU to pull pkr @ 10,233. Worked pipe & circ'd hole clean. Pipe then freed up; pull'g prod equip. Mud: (.624) 12 x 45 x 6.5 (Oil 6%) JAN ~ 3 1978 C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF TD 11,350. Sgl in DP. Fin'd LD prod equip & installed 5" pipe rams. PU DA (3-1/2 x 5") & sgl in. Mud: (.624) 12 x 45 x 6..5 (Oil 6%) JAN 2 ~- 1978 TD 11,350. PU DP. Had to repair line on brk, chng'd swivels & WP packing assy & repaired clutch on draw- works. JAN 2 5 1978 Mud: (.624) 12 x 45 x 6.4 (Oil 6%) C-44-14 RD (D) Platform C 11,500' "G" 2ool 105' DF TD 11,350. RIH. Cont'd sgl in DP & found top liner @ 9360. Found fill @ 10,265 & CO fill & scale to 10,583. Started torquing up & couldn't make any more hole. POOH; shoe worn out & catchers gone. PU new shoe w/junk catcher & RIH. .,iA N ~ ~ Ig78 ~ud: (.629) 12.1 x 41 x 6.4 (Oil 5%) ~C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF C-44-14 RD (D) Platform C I!,500' "G" Pool 105 ' DF TD 11,350. RIH w/wash shoe #2 milled 10,583-10,586. Mill gave up & couldn't make any more hole; POOH. Catcher torn; no fish. RIH & set Bkr cmt ret @ 10,233. Stung out & press tested csg from 10,233-sfc w/2000 psi 30 mins; no drop in press. Stung in & est inj rate. Brk down perfs ~ 1900 psi, then was able to prop in 4 B/M ~ 400 psi. Stung out & pmp'd 110 cu ft 15.8 ppg slurry w/400 psi on backside. Stung in ret 10 bbls before slurry reached ret. Displ'd w/160 bbls. Stung out & rev'd out; had stol amt of cmt to reach sfc. Pmp'd 68 cu ft 15.8 ppg slurry ~ from ret to 9933'. Pulled 5 stds & rev'd out. Slurry contained .1% R5 & .1% D31 on both jobs. Yield was 1.14 cu ft/sx. CIP on 2nd job @ 11:10 p.m. j~N ~ 7 1978 TD 11,350. Set'g ret. RIH w/3 4-3/4 DC's & 11 stds 3-1/2 DP. POOH LD same. RIH to liner top w/Bkr 9-5/8 csg scraper. POOH. RIH w/Bkr 9-5/8 csg cmt ret. TD 11,350. Mill'g. Set ret @ 9322; wouldn't hold. Press tested lap w/2000 psi sfc press & 12.1 ppg mud in hole; no leak off. Pmp'd 125 cuft 15.8 ppg slurry for a 300' lin plug (est top @ 9022) w/.l% D19 & .1% D31. Pulled 6 stds & rev circ'd clean. POOH. PU Servco section mill x-overs & RIH. Tried to find collar to start mill, but couldn't. Set mill & started @ 6720'. Cut thru & cut 1' @ midnight. Mud: (.509) 9.8 x 70 x 7.4 TD 11,350. POOH. Milled to 6765 (45'). Circ'd & worked pipe. POOH w/mill. RIH w/8-1/2 bit. Circ'd & pmp'd 50 bbls sweep w/walnut hulls. Cond mud. ~ud: (.520) lO x 50 JAN 3 0 t978 C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF C-,~-!4 RD ,.D) Platform C ~, ..~ Pool 105 ~ TD 11,350. No report. TD 11,350. 1/30 RIH w/Bkr 9-5/8" retrievamatic & set · . tool @ 6595. Took inj rate @ 3.5 B/M @ 1400 psi for 10 bbls. Bled off to 1000 in 5 mins. Released & bled back 4 bbls. Pmp'd in 10 BW ahead, then 150 sx mixed w/.75% D31 & .2% D19 w/total of 18 BW. Total slurry vol 171 cu ft. Held 600 psi on backside while pmp'g. Closed tool w/10 BW in DP & cont'd pmp'g a total of 118 bbls mud behind cmt. SI 5 mins & pmp'd 1 more bbl in w/500# sfc press. Bled off to 250 psi after 30 mins. Cont'd to sqz 1 bbl each 30 mins for total of 122 bbls. No chng in press. Closed tool for 4 hrs; press drop'd to O. POOH & PU bit. RIH; found soft cmt @ 6689 & good cmt @ 6709. CO to 6775. 1/31 NU BOP's. POOH & PU 15" Servco 15" hole .opener. RIH OE. Circ'd btms up; tail @ 6810. BJ put 15 BW ahead of 122 sx "G" 15.6# slurry. Displ'd w/3 BW & 110 mud; pulled dry. CIP 3:40 p.m. POOH F~st top of cmt 6570. O 7 7978 Tn!I, .... = ~ ' 3~u. zest g BOP s. Tested blind rams, stack & 9-5/~" csg to ~u,.,u psi. Tested chk lines, manifold, kelly ~oc~, inside BOP & std pipe to 3000 psi, ok. Mud: (.509) 9.8 FEB 02 ~97~ C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF fD 11,350. RIH w/dyna drl. Top of cmt @ 6685; drld to 6724. Circ'd & POOH. RIH to 90' Johnston BP. Tested pipe rams, blind rams & kill line to 3000 psi, ok. Mud: (.509) 9.8 x 40 x 14 FEB 0 3 ~97~ Depth 6774; cut 50'. Dyna drlg. Mud: (.509) 9.8 x 38 x 21 Depth 6930; cut 156'. POOH. POOH w/dyna drl & eye tool. Made up BHA & RIH. Washed & reamed dyna drl run 6724-82. POOH w/Bit #3' high torque would not drl. Survey: 6837'/ 36-1/2 deg/N21E. 4 9 7 x42x18 Mud: (.50) ' - .... ~ & left 3 cones off Bit Depth 6994;. cut 64 ,..or~z!~l=~ ~ver ~unk from 6930-32. #3. RIH w/junk bas~e~ ~ ~'~ ....... POOH; rec'd 2-1/4 cones. RIH w/drlg assy. Survey: 6984'/38 deg/N20g. ~B ~6 ~978 Mud: (.509) 9.8 x 42 x 18 C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' D~ 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' '~G" Pool i05' DF 9-5/8" csg i~ 6720' Depth 7~78; cut 184'. POOH w/bit. Survey: 7140'/39 deg 45 '/N18E · Mud: (.509) 9.8 x 41 x 18.4 ~EB 0 7 197~ Depth 7328; cut 150'. Dyna drlg. Survey: 7262'/41 deg 15 '/N18E. ,~' ~ Mud: (.504) 9.7 x 43 x 19.8 ~'~ 0 8 !978 Depth 7420; cut 92'. Drlg. Washed & reamed dyna drl run 7272-7366. Survey: 7402'/42 deg 30'/N12E. Mud: (.514) 9.9 x 38 x 15 ~[B 0 9 1978 Depth 7591; cut 171'. Dyna drlg. Survey: 7517'/43 deg 15'/NILE. FEB 1 0 ~978 Mud: (.514) 9.9 x 41 x 14.8 Depth 7773; cut 182'. POOH w/bit' Survey: 7640'/43 deg O'/NSE & 7763'/44 deg 15'/N4E. Mud: (.514) 9.9 x 51 x 12.2 Depth 7848; cut 75'. POOH w/dyna drl. Dyna drld 7773- 7848. Mud: (.520) 10 x 44 x 12 ' Depth 8035; cut 187', Mak'g up dyna drl. Survey: 7890 / 43 de?_., 30'/N2W & 8010'/Z,.2 deF./.N2W. FEB 1,3 1978 ~.%~d: (.525) 10.1 x 43 x 11 0= Depth 8059; cut 24' POOH w/bit. Dyna dt-ld 8035-8 .~9; bit won't drl. Mud,', (.540) !.0.4+ x 44 x 12.2 ,6~B 1 ~ 1~978 C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF 9-5/8" csg @ 6720' Depth 8157; cut 98'. Reaming-- 8050. Mud: (.535) 10.3 x 43 x 12 F~B 1 ~ ]9?8 Depth 8335; cut 178'. Dyna drlg. Survey: 8189'/40-1/2 deg/NlOW & 8252'/40-1/2 deg/N10W. Mud: (.530) 10.2 x 42 x 12 FE~3 1 6 1978 Depth 8445; cut i10'. Test'g BOPE. Survey: 8378'/39-1/4 deg/N16W. Mud: (.525) 10.1 x 42 x 12 ~EB 1 ? ~978 Depth 8630; cut 185'. RIH. PU Johnson RBP & set in 9-5/8 below csghd. Tested rams, valves, lines & chk manifold to 2500 psi, hyd to 1500 psi & lower Kelly valve & ball valve to 3000 psi. Pulled RBP. Reamed 8415-8445. Survey: 8504'/40-1/4 deg/N17W. Mud: (.525) 10.1 x 44 x 11.5' Depth 8827; cut 197'. Drlg. Survey: 8681'/42 deg/N18W & 8776'/42-1/4 deg/N19W. Mud: (.525) 10.1 x 42 x 11.5 Depth 8939; cut I12~. Ream'g to btm. Lost 200# press on pmp. POOH; found washout on 44th std in slip area. RIH, circ'd (dry job) & POOH. Reamed 8879-8939. Survey: 8898'/44-1/4 deg/N19W. Mud: (.530) 10.2 x 43 x 10 Depth 9132; cut 193'. Circ'g for survey. Survey: 8992'/ 44-3/4 deg/N19W. Mud: (.530) 10.2 x 42 x 9.6 FEB g 1 1978 C-44-14 RD (D) Platform C- 11,500' ~'G" Pool 105' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G'~ Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ~ DF 9-5/8" csg @ 6720' · .. Depth 9313; cut 181'. Drlg. P. eamed 9081-9138'. Survey: 9122'/44-1/4 deg/N21W. Mud: (.530) 10.2 x 48 x 7.8 FEB?. % ~975 Depth 9494; cut 181'. POOH. Survey: 9397'/42-1/2 deg/ N22W. Mud: (.535) 10.3 x 49 x 7.2 FEB g 3 197(t Depth 9574; cut 80'. Drlg. MaE.nafluxed all tool its on DA. RIH & reamed last 38'. Survey: 9484'/4].-3/4 deg/ N22W. Mud: (.535) 10.3 x 45 x 7.2 F~ 2.~ 1978 Depth 9761; cut 187'. Dr_!g. Mud: (.540) 10.4 x 44 x 6.8 Depth 9866; cut 105' Drlg. Survey: 9792'/39-3/4 N22V.. Mud: (.546) 10.5 x 45 x 6.0 Depth I0,024', cut 158'. Chng'g bit. Survev:_ _ ~ 10,014'/ 38-1/4 deg/N23V. M:ud: (.546) 10.5 :;. /,-6 x 6.4 FEB 2'7 1978 · C-44-14 RD (D) Platform C 11,500' '~G': Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF 9-5/8" csg @ 6720' Depth 10,207; cut 183'. Wipe ~ud: (.546) 10.5 x 45 x 6.4 FEB ~ ~ 1978 Depth 10,434; cut 227'. POOH w/bit· Mud: (·572) 11 x 48 x 6.4 EL 2316' G C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' Depth 10,566; cut 132'. Drlg. Survey: 10,424'/33 deg 45'/N27W. Mud: (.582) 11.2 x 47 x 6.4 0 Z 19Z Depth 10,710; cut 144'. Drlg. Survey: 10,559'/33 deg 45 '/N27W. Mud: (.587) 11.3 x 49 x 6.6 ~R 0 3 1978 Depth 10,778; cut 68'. Drlg. Survey: 10,750'/33-1/2 deg/ N27W. Mud: (.592) 11.4 x 52 x 6.6 Depth 10,925; cut 147'. POOH w/bit. Survey: 10,925'/34 deg/N28W. Mud: (.582) 11.2 x 50 x 6.2 Depth 10,925; cut 0'. RIH w/bit. Washed & reamed to btm. Survey: 10,925'/34 deg/N28W. Mud: (.582) 11.2 x 48 x 6.4 C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' Depth 10,982; cut 57'. Drlg. Washed & reamed to btm. Mud: (.582) 1!.2 x 48 x 6.4 ~AR 0 ? '1978 Depth 11,130; cut 148'. RIH w/bit. Survey: 11,130'/34 deg/N28W. Mud: (.582) 11.2 x 45 x 6.6 MAR 0 8 t978 C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" cSg @ 6720' Depth 11,267; cut 137'. Drlg. Mud: (.582) 11.2 x 44 x 6.6 MAR 0 9 t978 Depth 11,300; cut 33'. RIH w/bit. POOH to look for washout due to low pmp press; found 2 lrg jets in bit. · ~,~.'.,t ~t~ 1 0 t978 Chng~d ~ets & 57/2 ~ ~ 45 x 6 & Mud: ( '~' ± x · C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8".csg @ 6720' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' Depth 11,400; cut 100'. POOF~-~or logs. Mud: (.577) 11.1+ x 46 x 6 Depth 11,400; cut 0'. Log'g. Circ & cond hole for logs. Dresser Atlas RU & started run'g logs. Mud: (.577) 11.1+ x 48 x 6.2 Depth 11,400; cut 0'. Log'g. Ran FDC/GR & now run'g BHC. Mud: (.582) 11.2 x 44 x 6 MAP 1 3 1978 Depth 11,400; cut 0'. Run'g 7" csg. I'~AR 1 .~ 1,978 Depth 11,398 (corr'd); cut 0'. NU. Fin'd run'g csg to 11,398'. FC @ 11,310 & all csg is 7" N80 BT&C. KB to 7989 is 26# & 7989-11,398 IS 29#. RU BJ & circ'd. Pmp'd 10 BW ahead, then pmp'd 1140 cuft 15.8 ppg Class "G" slurry w/.75% D31, .3% D19 & .1% D6 per prog. Foll'd slurry w/10 BW & 419 bbls mud. Bumped plug w/2600 psi; float equip held ok. CIP @ 8:30 a.m. Set slips w/300,000# pipe wt. ND BOP. Installed 10" 5000# x 12" 3000# DCB tbg spool. Press tested seal assy & AP1 ring to 3000~ NU. D,~AR 1 5 78 Depth 11,398; cut 0'. PU 3-1/2 tbg. Tested rams, lines & valves to 3000 psi & hyd to 1500. LD 5" DP & PU 3-1/2 tbg. Depth 11,398; cut 0'. POOH. Sgl'd in to 11,290' (tbg meas) & found top of cmt. Rev circ'd out mud w/900 bbis clean inj wtr. Pmp'd 45 bbls KC1 & displ'd w/87 bbls inj wtr. Chk'd 35 mins for flw back, ok. Press tested csg 20 mins w/2400 sfc press, ok. Depth 11,398; cut 0'. Run'g prod equip. RU Dresser & press tested lubri to 2400 psi, ok. Bond log tool shorted out; LD & repaired tools. RIH log'g to TD w/1300 psi. Relog'd w/2300 psi & POOH & LD tools. RU & ran prod equip. Partial bond'g 8300-10,000 & from 10,000' to TD good to excellent. M~ ~ 0 ~'.~. Depth 11,398; cut 0'. Gas lift'g. Fin'd run'g prod equip. Set pkr (10,155/10,163) & ran total of 8 gas lift valves. Set pkr w/1850 psi & then slacked off 2-1/2'. Fished out X-plug @ 10,232. Installed Cameron BPV. Installed tree & tested to 3300#. Hooked up flwlines & gas lines. Depth 11,398; cut 0'. Prod'g well. Fin'd gas lift'g @ 1:10 p.m. total of 321 bbls. RU Dresser Atlas & perf'd w/2.6" slim kone steel hollow-carrier guns w/12.5 grm jumbo-jet chrgs w/magnet @ btm w/4 HPF. Run #1 - 11,110- 11,089 (21' & 80 holes). Depth II,~98; cu: 0'. Perf'g HR-HZ. Run #2 !I,089-1i,068 [21, ~ ~ & 80 holes~, Run #3 · --,068-11,047 (2~' & 80 holes), Run ~' i I ~4~ ~ 026 ~ ~ & 80 holes), Run #5 11,026-11,005 (21' & 80 holes). C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' Depth 11,398; cut 0'. Test'i-- Run #6 - 11,005-10,995 (10' & 40 holes). Fin'd perf g HR-HZ for total of 440 holes. ~ o~ ~97~' Depth 11,398; cut 0'. Flw test'g. Fin'd test'g HR-HZ 11,110-10,995. Last test 135 BDG, 7.2% cut, 125 BO, 242 MCF gas/D. Started perf'g HR-HN 10,943-10,849. Run #1 - 10,943-10,922 (21' & 80 holes), Run #2 - 10,922-10,901 (21' & 80 holes), Run #3 - 10,901-10,880 (21' & 80 holes), Run #4 - 10,880-10,849 (31' & 120 holes). ~AR 23 197~ C-44-14 RD (D) Platform C 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) Platform C 11,500' "G" Pool 105' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) 11,500' "G" Pool 105' DF . 9-5/8" csg @ 6720' 7" csg @ 11,398' Depth 11,~98; cut 0'. Prep to flw test. Last test on HR-HZ 11,110-10,995 - 135 BDG, 7.2% cut, 125 BO, 242 MCF/D gas. After perf'g & test'g HN-HR 10,943-10,849 - 255 BDG, 52% cut, 123 BDO. RU & perf'd 5' of HK-HN 10,725-10,720. Depth 11,~98; cut 0'. POOH w/2nd misrun. Flw tested after perf'g 5' of HK-HN; did not show incr in cut. RIH w/gun to perf HN~HR-(10,7~3-10,817) 24'. Gun hung up @ 6664 & had to pull out of rope socket. RIH & fished gun. PU & ran perf'g gun; had misrun & POOH. Found firing cap open. RIH again; gun still wouldn't fire. POOH. Depth 11,298; cut 0'. Perf'g. Installed new collar locator. RIH & perf'd 24' interval 10,793-10,817. Ran flw'g BHPS; indicated lower gas lift valve work'g. Est'd prod test before perf'g the last 41' - 460 BDG, 43.8 cut, 258 clean. RIH & perf'd the last 41' of HK-HN; no test est. Depth 11,~98; cut 0'. Flw test'g well. POOH w/WL. Flw tested well after perf'g HR-HZ, HN-HR, HK-HN. Latest test - 706 BDG, 44.6 cut, 391 oil & 298 MCF gas. ~ ~i,'.t ~.~i' Depth 11,398; cut 0'. Flw test'g. RU Dresser Atlas & RIH to perf HC-HD interval 10,331-10,326 (5'). POOH & made 2nd run - 10,326-10,320 (6'). Perf'd total of 11' '@ 4 HPF w/2.6" D Kone, hollow-carrier, thru-tbg gun. POOH. Last test before perf'g HC-HD was 798 BDG, 44% cut, 447 clean & 328 MCF/D. TD 11,398. PB 11,290. Flw test'g well. Released rig 10:30 a.m. ~/28/78. ~'~P ~ ?~7~ TD 11,398. PB 11,290. Flw test'g. ~-44-14 RD 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' C-44-14 RD (D) 11,500' "G" Pool 105' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' _ £D 11,398. PB 11,290. Flw tes~ g. On 4-hr test 3/28, prod 798 bbls gross, 44%, 447 clean, 1334 MCF inj, 328 MCF prod GOR 734, 128/64 chk, TP 70 & CP 760. ~ TD 11,398. PB 11,290. Flw test'g. On 6-hr test 3/29, prod 860 bbls gross, 46.7%, 458 clean, 1334 MCF inj, 410 MCF prod, 895 GOR, 128/64 chk, TP 70 & CP 770. ~PP ~,3 TD 11,398. PB 11,290. On 4.5-hr test 3/30, prod 891 bbls gross, 40%, 535 clean, 1290 MCF inj, 406 MCF prod, GOR 759, 128/64 chk, TP 80 & CP 780 ~P~ 0~ ~97~ C-44-14 RD (p) 11,500' "G" Pool 105 ' DF 9-5/8" csg @ 6720' 7" csg @ 11,398' TD 11,398. PB 11,290. OIL WELL COMPLETE. On 24-hr test 3/31/78, prod 3440 bbls gross, 40%, 2064 clean, 5336 MCF inj, 1576 MCF prod, GOR 764, 128/64 chk, TP 80, CP 780 from HR-HZ 11,110-10,995, HN-HR 10,943-10,849, HN-HR 10,817-10,793, HK-HN 10,766-10,720 & HC-HD 10,331-10,320. Log Tops: MD TVD Subsea GN 9,650' 79'76' -7871 GO 9,690' 8007' -7902 GR 10,059' 8293' -8188 GS 10,146' 8362' -8257 HC 10,316' 8500' -8395 HD 10,395' 8565' -8460 HE 10,465' 8623' -8518 HF 10,513' 8663' -8558 HI 10,556' 8699' -8594 HK 10,624' 8755' -8650 HN 10,767' 8874' -8769 HR 10,945' 9022' -8917 HZ 11,112' 9161' -9056 FINAL REPORT 1978 .g U R V E Y ~ R T f:l i'EFIS:Ui;.~EZ~ DE:-," I FIT I DH 'VERT I CFtL LFIT"ZRFIL DEFLt:_L. F I i]i't DDG LEG DEPTi'I TJR I FT 7~R I FT DEPTH FROi'I ..-JJRFF~CE LDCFIT I Di't .:: 2~EG .... 100" .'.' -" ""'" ;":'- )FtH,qLE D I F.:ECT I i]i-i .': 2:';-iF ) i"l BR .E.: -.';-- ':, E i]F.: i,I "-- ) ,. e',,LI I _ · " 0 4,2,:! 50 :) 5.30 C:H FI H G E 5::, 1 62.3 r:, C-: 6 717 749 779 .~ ,:, 1 I ,_', ¢ 994 1:3;_:9 11 P, ':' 1277 1.37' 1 14r:,5 1553 162 ~'l 17,22 134'? 200 ',] 2025 2 ',:1 ;D 212.3 2213 2.--',C<3 ~2. 4 ,", 2 r:, .37 ,297' ;3 · 315: G 3G57 · :: 9 ;31 425L:, 4.359 447,5 472.3 4793 4 .-; .z, b 52.3,3 541.5 554. ;-_-: :] 0 :.]'. 9 :] b.I L] 10 .S '30 i.:! :) 15 H 4.5 b.I :-I 25 J'"l L:,;_--: i.,J I i'.t D F.: I F T D I F.: EC:T I D i't :3 2'3 H 50 E 1 15 H 1(:, L: 2 15 H 2 ,J L:. 3 15 i-t29 E 5 1-3 i'].3.3 ~ L:, 45 i't 43 E · -':] H --:'q E · :':] i'] 2'3 L: 3 45 it 27 E 9 45 H 20 E 12 1.5 i'] 9 E 1..515 i'~ ..-.4 E 19 0 i'{ 3 E 22 45 it 11 E 2,'-', 45 i'"l11 E · 3 n 0 H 12 E 33 1.=; H 13 E .:,._, 3 0 i'~ 1,::E 37 1.=] i'.l11 E .;:::, 45 H 1,-'L: · ::.-'] 45 i'~ 12 E .34 3,] H ~.':, I:. 32 .33 i"! ld E .--:4 45 it 23 E 33 15 ' H 21 E 2:7 15 i'~ 21 E .2:,2,0 H 21 .3c'] 45 i-.I 21 E .35 4.=; it 22 E 34 45 H ,-'d ~- 31 45 H 17 E 30 0 i'l19 E 35 3,) H 19 E 33 ~ it 17 E 3? 3 it 13 E , 36 0 H 17 E .37,0 H 17 E 35 3,) H '17 E · :,._, 0 it 17 E 33 1--; i'~!r:, E 33 ;3 it 1 G E · 32:4.5 i'¢, 16 E 35' 4.5 i'~16 E 35 0 H 17 E O. 0 O. 0 O. :] :]. 0 422.0 0. :] .- :-i. r:, :]. :3 50:3.0 0.1 --0.9 0.2 5 v ,'l O n 2 -- 1 :'l :~1 ? E;~',F:EEZ~ '~0 T~EGF:EE2 · ~<L:V~-R i_I..-.:EF.i.-i'IFli'~i_IFIL, 5:2, 1.0 :]. 4 .- 1. :) ,-'. c, 5'32.0 3.7 .- :]. E: 3.3 r:, 2.3.3 1 . :'_:, .- :]. 5 .:',. 2 L-', 54.9 3 ' :]l I']I . 1 .3.4 7' 113.7 7. :_:, .3.2 5.4 ? 4 C':. 4 I 0. G: .--i. :3 3.9 7 7 3.1 14.2 :--:. 2 4. '-'0'3:3 lC< 3 l:'l 4 d o i"l i · ' · · · -'-' 1 0 ,-'-"',". o- 14 3 . ,._.:' 4 -.-.4:39.7 49. :3 2 :]. 1 2.7' 1 0:32. O 72.1 2.3. L:, .3.2 1173.9 ..-.49.2 27.7 4. 0 125'3.6 132. O .3,:: · .S 4. 1 1.345.3 171 . 2 4 :_'l. :--: 4..:2 1427.7 214.9 4 '3. ," .: ..... 1-3 3 L:,. :3 2"_:, 2 ---, ::, :]. 2 .::. C, 155:3. 3 2'?,. 7 F, 7 .:3 .::. 7' 164 h.. 1 .3-=,_ ::,_. 3 7 '3 . q.. 1 .,_"~ 174 ,]. 3 429.7 94.9 :]. 6 1 E: F, 3.3 51:3.2 11.3.7 ;]. 7' 1 ;3 ;3.3. :3 .532.2 11 I'-~' · 190 :~. ;3 54:3.0 1 c~ 1 . ," ,-, · ," 19 ~:~ =-i. 4 :--i :::.3. ::, ! 34.3 .3. ? 2 04 1 . 2172.2 7.3 ,]. 9 19 l). 3 0.6 2252. ,~.3 ," :" · ._ l_! I il · ' 2 G 54.3 1 :)56.2 .31 ::,. 7 3.2: 278.2:. 1 i 141.2, .2, 4 321 F:. 7 141,2.1 44 0.0 :3.7 .":', 49 I_~,. · 37 2 :E:. 0 171:3.9 5,39. ;3 '2 0 '-":' i 0:5 176'~ 5 .-'].-3 3. ;--: 2 7 ' .__l I_1 lEI i 3 L-.-I,."1 ._, ]' . 3 1 ;3.37 .4 .-'] 3 3...3 1 · 0 ' 4 33,3.0 i 9 :] ?. ? ::. ;:l.--'. 4 0 · 9 41 02.5 1 ..-.476.9 ,_". 23. F, O. :] 41 =,F, ."a ':' ,] 14 v, F,.'::.-3 3 0 7.:.' _ · _- Iim. 4276.1 20'34.9 6.59.? 0.3 44 ,].3. G -2177.7' 634.2 1 . 2 452.3.4 2252. o'-' 705. ? 0 .2 t- ~ · · 4 L:, 76 4736.7 ' ,.24 t ~:. ~".4 - 754. ,3 1.7 ../ 5415 554;3 56;33 5;307 5932 6151 1:',277 6401 645.3 6:337 7140 ,!C ) 74 :]2 7517 7 G 4 0 77G3 8 01 :) E:5,]4 :3 G :31 :377G :3:39:3 :3998 9397 94 ;34 1 0014 1 04&4 1 '9559 1 075 3 1 0925 1113 ,] 44 33 .G 4523.4 4L:,25.8 4,:, 7 g:, .3 47;36.7' 4 ;39 ;3.3 5001 .4 51 3G.~-', 51 ;3,:,. G 529 3.5 0 .:: '~ L",. 2 55 :] 0. ,S · '-5.-544.4 :D L', --_, r-" . 3 5733. ? 5:}62.2 5979.4 G 1 00. :2: G 193. iB G 297. :2: :E:,:: ;:,' c~. 1 6471 .'3 GSa:, .). 9 711 I_-': . l_": 7249.9 p s :,:] .4 74,]9 747,5.3 75G9.0 77,:, :3.9 7:3.3.2:. 4 ;_o, L] ':, L:, . ~, ;32.3'3 ;2:.-'q 7 3. ') ;3 G ;33. I ;3;342. :.' ;::'J ;37.7 '3157. F, 2177.7 22.:72. ;_:: 2-3 1 I_", , 5 2.347.7 241 ::-:. 8 2492.1 2557.7 ._ i:, ,:: c:..d 2':,71 ' lS 2 :'-'.~ l:" .4 '0 q I 4 2 C'::':' 4.8 2:2:9 i · 4 2959 · '3 3 00:3 · 4 .:: LI '_.-I 4 . '~ 3 I F-" ;2:. ~I .2:27 0..--; .--', .34 -B. 9 343 L:,. 1 · 3.-q 12. .z: -D 'J I:, . 51 · 2: L:,:2: J. ~:, · 2:7 ::.:3. :-:, · :: ;35 :]. :ii 39 L:, ,?..2: 4:3 :] 7. L:, 4 ,] :--': :",. 2 41 ":,.-": · 4,274 .s 4~, ,..,, o.:, 4.9 4414.0 44 ,'-" F,..3 45,:, 1 . 9 47.2: 7. i:, 47' 91.7 .-:1 .-'.n .. I ~"l . 1 .51 07.2 5.392..2: 54;3 L-',..o 5572 ':' 5G74.0 6:24.2 7..]5.7 724.0 7 .--: 2.9 754. ,] 7 ? 5 . 7 79=, . 1 :314.3 '--' ':' ']' 4 ,--, I_.. ,_, · :~4'-' ," ,_: · :2:7 ,]. ,] :2:'.91 . F' · ~ :.l d. 1 -- · j ._-:-~. ~ 97 :]. 7 L] :_'l 1 . :_--: :'133.7 :] 5 ;3.1 :] C-: ,2..3 :] 9 ?. 9 1 :] 9. 11 E,.._7 117. lllc,.d 1 ::l 2. :_:. :_1 'J .D , ..-., 1 L'177.4 1054 · :-5 101'~ .z, 9'3'}. 3 '372. ;] 95 O. ,_-". · 31 ._-.4.4 1.2 0.2 ,]. 2 3. ;] ,]. 9 '9.9 3. ? 3. ~3 '9. 0 ..-3 1.1 ',]. 4 1.1 1..2', 1.4 1.,2 3.0 0. '3 3..--', 1.2 .2:..2', 1 3.1 3. '9 .2: · ,:' '9.9 1.1 :) o · I . G L]..--i 1.1 ;'1. ,--" 3. G :'l, ,.~' 1.2 3.1 3.4 :]. :] Ii"tTERPDLFITED i,IEFI._.-.:i_Ii;:ET~ DEPTH FIT i00 FEIDT Ii'tC:F.:Ei'IEi']T._7 DF THE .giJ2,._--.:E(~ DEPTi4 .',. LI z:, ._". I: I t DEF:'Ti'I 1 ::l 1:1 . 2 :] 0. .30 :]. 400. 5 30. G :] :]. 70 '9. ;3 '93. 9 O '9. .-' '9 5. ._ '9..E: :) 0. :] ::l .3 :]5. .- 0.44 0. :] ,. 4 :] 5. -- L'! 5 ') L'I . ;.'i il .:, O 5,. -- 0. :3'2 0.12 6 05. '- ,9. r:, 9 I . 1 '9 7 ,] 5. 2.5,3 ,S. ,':, :] :3 :ih:,. 1 0. 03 17.71 9 :] ~3. 1 =;. 90 33. C-:,:, 1 O10. 20 .Gg' 53.47 900. 10 :] 0. 1100. 1200. 13 :] :). 14 O0. 1500. 1600. 1'7'00. 1;300. 1900. 2000. 21 00. 22 00. 2.300. 2'4 00. 2!5 0 O. 2(3 :] 0. 27 0 ,]. ~ L': U 0. 2'3 :] 0. 3 :] :] 0. .31 O0. 32:3 :]. · :,.:, 00. 34 :)0. .2',!5 ,] 0. 2, C-, :] 0. 37 O q · 2:i_s: 00. · 39 :) 0. 4 000. 41 ',] 0. 42 O :]. 4.300. 44 0 0. 45,9 :]. 4,=', :3 :]. 47 :):]. 48 00. 4'? :] :]. 5 :] :] :]. · _, 1 ',] 0. 52 n :'~ 5.3 00. 5 4 II 0 · ._-5.7--30 '0. 5,_:, 00. 57 0 ,]. .-'];'.] ;.] ;3 · 5'30,3. G :)0 :). ,31 0 0. 62 0 0. G.30 O. (34 0 0. 6 530 0. ~-, (3 :'1 II . ,S 7 0 0. 6;3 O O. G 9 00. 7:300. ;306. 9 0;3. 1 O10. 1113. 1219. 1.327. 14.3 ?. 155G. 1 ,':. 7 L=:. 1 ;2: 0.2:. 1928. 2 05 0. 2172. ,d'~d. 2424. 2.-5--~ ':' · _ "f ~...~ · 27'34. 2913. · _: :] 4 :]. · 31 ~'-', 2. · 3,-';-',,"" · 34 :] 1. · 3.D,"" i ,,, .3:341 · 31374. .=:-y ¥-¢ 1 ,. 411L]. 4229. 42,52. 447;_°, . 4 G :] 2. 4726, · 404'? ,,, 4'371. 5 ,]'32. o,=.11 . 533 0. 545 0. 5570. 5 L:, '? 1 . :'~;:: 11 . 59 ._--: ,]. ,E, 049. 61 ,'=',;3. Ir, {.L ,Z, I' ,34 0,$. ,$52c,. ,'=', r=', .4.4.. 6767. ,S S'31 . 7 ,] 17. 7146. 7277. 7.412. 75,43. 7(-];36 . 7824. 7962 , ;3 ',]'3 G. ~:,2,2 ;:-,'. 3-359. · -- . -"-, 10.03 15.9;3 20.69 24. ,3;3 29 .;33 · 37.26 47.24 5'3.9'3 74.71 8'3.61 1 04.7;3 121 . 02 144.25 171 '~-' 19;3.70 224 . 9'3 251. OI 277.4 ,] · 3 :].3.7 ;3 .329. L:, 2 3 =-3.:',. '3,_:, · 374.7,E, · 3 ...4 r_', . :Z, {:, 4 16./::,'_:, 4._77.1G 455. '3 ,:; 474.4.3 4'33.11 514.05 :-;.:: 4. '3'3 5 ;30.6.2: G 02. ;=: 7 G24.1 0 G.4.4. '37 665.25' 6 ;2:4..45 7 :] 2.43 72 0 . 2;_--,' ,..=,,.:, . 41 757 · 5 ,_:, 777.0._=: 7'35 1:3 l L=: 13. '3'3 '=' =' 1 '~ ','1 i_l ._! i .' . ~351 , 2 0 L7 ,=" 1 . 7 :=:'32.0'? 912.4 0 · _-.43.2:. 14 956 l 7 0 · :.4 :_:: 2. FI 6 0 O :_--:. 51 034.7 L:, 06 0.78 :] :_:: 3. r:, 4 1 00. :39 117 . ,] 0 lllG.11 1 09.06 0'.-.4 :_--:. 2 0 OC-: 0.1 ._--: ,.._, ~ . 2.2, ,%--, 4 --, 17.71 ">:' :3,:, 5,3.47 79.0'3 111.99 15.3.07 2 02.9.3 2,$1 . 42 33a ~:-~ 4 0.3. ;3;3 47G..34 545. ~:,.3 611 . 07 ~'-', 6' 2.2 G 753.6 0 · ='--'-'. 01 · '3;3'3 ='q · 35,:,. 3G 1 02.2:..2', 4 1 0 ;3'.3. ;31 1154. '35 121,.-'. 12 1279..-' 1341.45 14 :] 2,. F:, 2 14,':,1.21 151 ;3. :] 7 157o. dc, 16.3 L:,. 07 16'36.3 '3 17,:,5. 1''~ ='''-' 5;2: i_i .__l i_i · 19 Fig. 13 19 ,"" ;2:. 5'.-.4 2 04,$. -' -' ;=, 2 t 13. ,':,6, 2178. ,'_:. 1 2241 . 33 230.:~. 57 3.3 r_:,,'_:,, l ..-.4 24.3 F~ q TM . · i_ ."1 24'3,'",. 5,_:, 255'). 95 2,'",21 . ._=:2 2F'-'-' 01 =, ,_-, .£~ . 27.45. ~'~ 206,7 ~ 5 t 2'323.21 29'30.1 '3 .3056..3;3 · 3125.24 31'..47.51 ~ -'-' -' '34 ._-, .=, ._, o. 77 3442.6.4 35.34.02 -Z, Iz, ,' I' - ~ -, -, .=~ -_--:;317.12 -'9 ,'h:, ! .3 -3'.-.492 . 37 4 074.2._7 4154.21 L:: 2 2 ~;. , ! 0'~ 3.2 0 .3 3'? 2..3 7 ~3 3 5'~. 1 O ~3 3.1.3 4 0 7 4. ~ 3 ~3 4 3 ~}. 1 0 5 ~. ~,3 415 4. ~ 1 ;3,3 ~ I . IU.:, ~ -' 1 . ~-3 '~ c.~, :' . 9 '] :' ~ '~4:3 '95 45 33.75 · ~ 17 t . ') 06. '} ;3 45'}.3.4 · } 3 0 '} . ,_,'~ 72 . .3546 ;3 t . 4 · ~446. 337. -}-7¢ 4767. ;34 · 3c, 7;~. ;3 :)5 .dE, 4;34;3 '}7 t 0. 773. '}3 4'}3;3.75 · };341 . 741 . 3 ;3 5 O OS. 7 · ~'~ 70. 71 O. 21 5 3;31.52 00')5. 6 7'). 41 515 3.4.3 :]21'). 643.71 5216.26 034.3 . 6,13 . 01 ._,c,z,c= TM'-' -'. 3 0465. 5 ;37.44 5345.7 05;35. 557.13 5435. 0705. 5~6 .')4 5464.51 3 ;3 ~ 6. ' 4 ')E,..3.3 55 ~ 5:. 77 0 ') 4 ,'],. 465.34 ~ ~ ;35',. 1 067. 4.3.3. E, 7 5643.64 l~m'~ No. I~V. ~- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, WKLL, ~LL '2. NAME OF OPEP. ATOR SHELL OIL COMPANY 3. ADDRESS OF OPEI~TOR OTHEI% SUBMIT IN DUPLICATE ~ API NUAIER1CAL CODE 50-133-20252-01 LEASE DESIGNA~qON AND S~RRIAL NO ADL 18754 IF INDIAkT. AI_,OT-I'E.E OR TRIBE NAME 8. L,~IT FArt~ OR LEASE NAME 'Middle Ground Shoal 9 WELL NO C-44-14 RD l0 FIF. LD /~.ND POOL. OR WILDCAT MSS - "G" Pool 11 SEC. T., R,, M. (BOTTOM HOLE Sec 14-T8N-R13W-S .M. 12. PEI:LMIT 1~O 77-79 1700 Broadway, Denver, Colorado 80202 4. LOCATION OF WF-J.J~ Platform C, Leg 4, Conductor 31: 4779'S & 1542'W of NE Corner of Section 23-T8N-R13W-S.M. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHAI'fGF~ IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/VD VOLU'MES USED. PERFORATIONS. TF. STS A_N'D RESULTS FISHING JOB~ JLLNK IN HOLE AND SIDE-'IqR~CKED HOLE A3CD ANY OTHIgR SIGNIFICA.NT CHA~GI~S IN HOLI~ coBrDITIONS OPERATIONS FOR MARCH, 1978 1. Drilled 8-1/2" hole to 11,400' 2. Logged w/DIF/GR/Cal, BHC Sonic, DIF/GR 3. Ran 7" csg (26# & 29# N80) to 11,398' 4. Cemented w/l140 ft3 Class "G" 5. Ran 3-1/2" tubing w/packer @ 10,155' 6. Perforated w/4 holes/ft, as follows: Depth 10,995' - 11,110' 10,849' - 10,943' 10,793' - 10,817' 10,720' - 10,766' 10,320' - 10,331' Zones HR-HZ HN-HR HN-HR HK-HN HC-HD 7. Tested well as follows: Test No. Zones Tested B/D Gross Water Cut MCF/D Gas 1 HR/HZ 135 7.2% 242 2. HR/HZ 255 52% - HN/HR HN/HR 706 44 6Z 298 HK/HN HK/HN 798 44% 328 STATUS: 3/31/78; Flow Testing '14. hereby certify~ th correc% ............. j ~ Div. 0pers..~n~r. D.~, .... APR 1978 IGNI~D ~'_~ TITLR .... ,,:., :. i, ,.,.t ' , . NOTE --Report t s form ired for .each calendar month~ regardless of the status of operations, and must be filed ia duplicate wltlt tl~e oil and gas conservation committee by the IDth of the succeeding month, u, le$1~ Otherwise directed. l~tta ~o, P--4 P~V, STATE OF ALASKA OIL AND GAS CONSERVATION COM~AITi'EE t MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR SHELL OIL COMPANY 3. ADDRESS OF OPEi~ATOR 1700 Broadway, Denver, Colorado LOCATION OF WELL Platform C, Leg 4, Conductor 31: SUBMIT IN DUPLICATE 80290 4779'S & 1542'W of AP! N~EmCAL ~ODE 50-133-20252-01 LEASE DESIGNA~ON AND S~IAL NO. ADL 18754 IF INDIAN, AL,OTT'EE OR T!RIBE NAME 8, U'NIT FAriA{ OR LEASE NAME 9 WE~ NO C-44-14 RD I0 F~ ~%ND P~L, OR %VILDCAT Middle Ground Shoal "G" Pool NE Corner of Section 23-T8N-R13W, S.M. omr~v.~ Sec 14-T8N-R13W, S.M. 12, PER.MIT NO 77-79 13. REPORT TOTAL DKPTH AT END OF NON'I/q, CI-IA2qGES IN HOLE SIZE. CASING AND C~WIENTING JOBS INCLUDING DEPTH SET ANI) VOLLrMES USED. PERFOI:~kTIONS, TESTS AIN-D RESULTS FISHING JOBS JU~qK IN HOiOg AND SIDE-TRACKED HOLE AND A2qY O~H~ER SIGNIFICA2iT CI-IA/~GES IN HOLI~ CONDITIONS OPERATIONS FOR FEBRUARY, 1978 1o Kick off @ 6724' 2. Drill 8-1/2" hole STATUS: 2-28-78: Drilling 8-1/2"_hole @ 10,434' 14, I he. by ~~,..r ' ~PR 25 1978 s~ NOTE ~Report on this form is._.uired for each calendar ~nth~ regardless of the ~tat,s of operations, and must ~ flied in duplicate with the oil and gas conservation commi~ee bythe 15~ of the Suec~ding month, u~it~ oth,rwise ~irscted. No, P---4 5-1-70 STATE OF ALASKA SUBMIT ~N' D~TPLICA'I~E OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL ~ GAS [~ OTHER WELL WELL 80290 2. NAME OF OPERATOR SHELL 0IL COMPANY ADDRESS OF OP~I{ATOR 1700 Braodway, Denver, Colorado 4. LOCA~ON OF WELL Platform C, Leg 4, Conductor 31: 47791'S & 1542'W of NE Corner of Section 23-T8N-R13W, S.M. APl NUA~ERiCAL CODE 50-133-20252-01 LF~kSE DESIGNA%qON AND SERIAL NO, ADL 18754 !7 IF INDIA]~I[ ALO'i'-['EE O1R TRIBE NAME 8. L~,'IT FARA~ OR LEASE NAIVE Middle Ground Shoal 9 WV. LL NO C-44-14 RD 10 FIFJ~D A_ND POOL. OR %VILDCAT Middle Ground Shoal "G" Pool n SEC,T.,~.,~. ~O~'TOMHOL~ Sec 14 - T8N-R13W, S.M. 12. PF~GMIT NO 77-79 13. REPORT TOTAL DKPTH AT F~D OF MONTH. CHA~GES IN HOLE SIZE, CASING AND CEMF~NTING JOBS INCLUDING DEPTH SET A/Xq) VOL~ USED. PERFORATIONSi T~.~STS A/N~D I~ESULTS FISHING JOBS Jb~,JK IN HOLE AND SIDE-T~ACKED HOLE AN'D ANY OTI-IER SIGNIFICANT CI-La_NGES IN HOL~ CONDITIONS OPERATIONS FOR JANUARY, 1978 1. Removed production equipment - found fish @ 10,586' (Refer to "Sundry Notice and Report on Wells" dated January 27, 1978) 2. Set cement retainer @ 10,233' and pumped 110 ft3 cement below retainer and placed 68 ft3 on top of retainer (top cmt @ 9933') 3. Set retainer @ 9322' and placed 125 ft3 of cement on top (top cmt @ 9022') 4. Milled section in 9-5/8" csg (6720' - 6765') 5. Pumped 150 sx cement thru cement retainer @ 6595' 6. CO cement to 6775' and placed 122 sx cement to 6685' (Kick-off plug) STATUS: 1/31/78: Preparing to kick off @ 6724' 14. I hereby certi th correct 1978 NOTE:--Report on this form is re ired for each calendar ~nth~ regardless of the status of operations, and must ~ filed iff duplicate with the oil and gas conservation commiffee by the 15~ of the succNding mon~, u~l~ otherwise dirscted. Conservation ApriI 5, 1978 ~ Re: Shell Oil Ccmapany Middle Ground Shoal ~C-44-14-RD ~r. R. Planty Shell Oil Co~%pany 1700 Broadway Denver, Colorado 80202 Dear .~r. Planty: A permit for the subject well was approved on December 20, 1977 and plans for the abandonment of Well .~ C-44-I4 were approved on ~he same date. The following operational info~ation 'has been received on the s~ject well: (I) A Sundry Notice and Report on Wells dated January 27, 1978 and received Janua,~f 30, 1978 concerning abandon- ment of the ~C-44-14 well and noting that verbal approval of the changes in abandonment progra~ had been re~iveO on Januaz~z 26, 1978. Our records in ~cate that operations were underway on this well in Janua~, 1978 and cons~uently Shell oil Company has not com- ptied~ with the Oil and Gas Regulations of the State of Alaska as follows: (1) (2) A Monthly Report of Drilling and Workover Operations for the ~on~h of January, 1978 was required by Februa~ 15, 1978 -- 1 month and 16 ,_~33s late. A }~{onthly Report of Drilling and Workover Operations for the month of February, 1978 was require~.~ on :~r. R~ ~lanty Shell Oil Company April 5, 1978 ~:~arch 15, 1978 -- 16 d~s late. request that the info~a%ion on this well be i~.~ediate!y. Very truly yours, O. I~. ~ilbre~h~ ,~r. Director cc: ~ o ~ans ~athieson sH ELL OIL COMPANY _ . ~1~00 .BROADWAY DENVER, COLORADO 80202 January 27, 1978 Subject: Middle Ground Shoal Cook Inlet, Alaska Platform C, Well C-44-14Fz~ SE/4, Sec 14-8N-13W, S.M~ State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' O.K. Gilbreth, Jr. Gentlemen' Attached in triplicate is a "Sundry Notices and Reports on Wells" form to obtain written approval of a change in plans of abandon- ing the lower portion of well C-44-14. Verbal approval for the change was obtained from your John C. Miller on 1/26/78. M.L. Woodson Division Drilling Superintendent Western Division LLN/aaw cc- Atlantic Richfield Company PO Box 360 Anchorage, Alaska 99510 Amoco Production Company PO Box 779 Anchorage, Alaska 99510 Chevron USA, Inc. PO Box 7-839 Anchorage, Alaska 99510 United States Geological Survey Department of Oil and Gas 218 E. Street Anchorage, Alaska 99501 · Form ?.-0-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLII OTHER 2. NAME OF OPERATOR Shell Oil Company 5. APl NUMERICAL CODE 4. LOCATION OF WELL Atsurface Platform C, Leg 4, Conductor 31 4779'5 & 1542'W of NE Corner of Section 23-T8N- R13W, S.M. 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 1700 Broadway, Denver, C010rad0 80290 C-44-14 /~ ~ 10. FIELD AND POOL, OR WILDCAT MGS "G" Pool 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105' DF 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 14-T8N-R13W, S.M. 12. PERMIT NO. 73-13 )orr, or Other Data NOTICE OF INTENTION TO-- TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF-. WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= ReDort 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. Refer to the original Sundry Notice of Intention to Abandon Well C-44-14 (including P&A Prognosis and Sketches) dated 12/6/77 and approved by your John C. Miller on 12/20/77. During abandonment operations it became necessary to alter the approved method of P&Aing the bottom portion of the well. When cleaning out the 7" liner, attempts to get below 10586' were unsuccessful due to a wireline fish left in the hole, scale and fill in the hole and potential collapsed casing. Two attempts to wash over the fish and clean out fill below 10586' were made without progress. Therefore, a 7" cement retainer was set at 10233' and 110 cu.ft.(150% of casing volume from retainer to 10586') of cement squeezed below it. (This was done instead of the original proposal to spot cement from PBTD of 11254' to 10200'_+ and then place a retainer 'at 10000'+). A 300' cement plug (68 cu.ft.) was then placed on top of the retainer to 9933' and abandonment operations continued as per original proposal. Verbal approval on 1/26/78. for this change was obtained by M.L. Woodson from your John C. Miller 16. I hereby certify that~oregoing is true and correct · SIGNED ~~/~,j'~ TITLE Div. Drl~g. Supt. 1/27/78 DATE (This space for State office use) APPROVED BY .. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 20, 1977 Mi4kile Grcund Oil Permit }%D. 77-79 R. Planty Divisic~ Operations Manag~ 'r Shell 1700 ~~~ ~, C~~ 80290 Er~losed is ~ ~ ~plication for permit to drill the above ref~ well at a tocat/on in Secti~ 14, ~p 8N, Range 1~7, S.M. Well samples, ~ chips ~ a ~ ~ ave ~ ~.required. surly is =equired. A directicnal Many ri%~-rs in Alaska ~ ~ dra/nage system~ _h~e been classifi~t as i~t0o-~m~t for ~he spawn/r~ ~ migratic~ of ~ fish. Operations /~n these ~s ~ subject ~ ~ 16.50.870 ~ ~ reguta~ promulgated thereunder (Title 5, ~ska ~strati~ ~). Prior to ~c/ng operations ~ may. ~ cc~ta~ by ~ Habitat Coordinator's office., Department of Fish ~ ~.. Pollution ~ any waters of ~he State. is ~ited by AS 46, Chapter 03, Article 7 ~ ~ regutaticns .~xlgated thereunder (Title 18, Alaska ~]minis~~ CrW~, Chapter 70) ~ by ~ Federal ~mter Pollution c0n~~ ~ a representative of ~ De~t of Envircrm~ntal CcDm~rvatiG%. Pursuant ~ ~ 38.40, ~ ~ t~r State Leases, the Alaska DeparU~nt ~ ~ is being notified of ~ i~ of this ~t to drill. To aid us in ~~ field work, we ~ appreciate ~our noti~- this office wi~hLn 48 ~ a~ ~ ~tl ~ ~. We w~uld also like to be notified so tb~t a rep~=~entati~e ~ tlte Division may be present to witness testir~ of blow~at preventer equipment bef~ .~_~face casing shoe is drilled. R. Planty -2- ~ C-44-14 RD Dec~r~er 20, 1977 In ~he event of suspension or ~t please gi%~ this offioe ~3_.~.equate adv~ ~ficatic~ so that we may ha~ a witness present. O. K. Gilbreth, Jr. ~ Alaska Oil ~ C~s Conservatio~ Cc~mittee Enclosure Department of Fish and Gau~, },~itat Section w/o encl. De~t of En '.virom~ntal Cc~mvation w/o encl. Divisic~ w/o ~ncl. SH ELL OIL COMPANY ].700 BROADWAY DENVER~ COLORADO 80202 December 6~ 1977 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. O.K. Gilbreth, Jr. Gentlemen' Attached in triplicate is a request to drill Middle Ground Shoal C-44-14 Rd. Included are the following' 1. Application for Administrative Approval 2. Application for Abandon - Form 10-403 3. Application to Drill - Form 10-401 4. P&A Prognosis with Abandonment Proposal Sketch 5. Drilling Prognosis with Proposed Directional Plan 6. Proposed Location Sketch 7. BOP Assembly 8. $100 Filing Fee LLN/KWL/aaw Attachments Yours very truly, R. P1 anty Division Operations Engineer Rocky Mountain Operations Office CC: w/Attachments Atlantic Richfield Company Standard Oil Company of California Amoco Production Company USGS - Alaska Form 10~401 REV. 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN SUBMIT IN TRIF, .bATE (Other instructions on la. TYPE OF WORK DRILL ~] DEEPEN []]] b. TYPEOEWELL Redri 11 to OIL GAS ~ONE [---] WELL ~ WELL ['~ OTHER same reservoi SINGLE reverse side) 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver, 4. LOCATION OF WELL Atsu, race Platform C, NE Corner of Section 23-T8N-R13W,S.M. At proposed prod. zone 592'E and 5329'N from Surface** 13, DISTANCE IN blILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 17 miles NW of Kenai, Alaska 14. BOND INFORMATION: MULTIPLE ZONE [--] API No. 50-133-20252-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 7.IF INDIAN, ALLOTTEE OR TRIBE NAME 8.UNIT FAP, M OR LEASE NAME Middle Ground Shoal 9. WELL NO. C-44-14 Rd (*See below) Col orado 80290 lO. FIELD AND mOL, OR WILDCAT Leg 4, Conductor 31; 4779'S & 1542'W of Middle 6round Shoal -"6" 11.SEC., T., R., M., (BOTTOM tlOLE OBJECTIVE) Section 14-THN-RI3W,S.M. 12. Po Tree Oil & GaS Surety and/or No. TIC 136503 15. DISTANCE FRObt PROPOSED * 18. LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit. ffany) 4330' (Lease kine) DISTANCE FROM PROPOSED LOCATION TO NEAREST V,~LL DRILLING, COMPLETED, OR APPLIED FOR, FT. 600'@"G" Pool Mkr(C-44-14 org. hole) i6. No. OF ACRES IN LEASE 5120 19. PROPOSED DEPTH 11,500' MD Amount $1 00,non 17. NO,ACRES ASSIGNED TO THIS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START 105' DF January 10, 1978 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH [ Quantity of cement 17½" 13-3/8" 61 J-55 2483' ~670 cu.ft. (in place) 12~4" 9-5/8" 40 & 43.5 N-80 9569' 1300 sx (*See below) ~z" 7" 29 N-80 11500' 450 sx * Plan to abandon lower portion of MGS C-44-14 (producer - SE/4 Section 14-8N-13W) as indicated by separate Sundry Notice on Well. Plan to mill window in 9-5/8" casing at 6720' MD (5767' TVD) to kick well off and redrill as C-44-14 Rd. ** Top of productive zone ("G" Pool Mkr) 08555' TVD (8450' SS); 550'N and 95q'W ~of,~ SE Corner, Section 14-T8N-R13W, S.M. *** See attached Drilling. Prognosis and Proposed Directional Plan. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. It- proposal is to drill or deepen dixectionally, give pertinent data on subs'uxface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby ccrtj.g~,~hat tho'F6'~oing is Tr,~ and Correct (~is space f~ State oft'i~e use) ~,~ SAMPLES AND CORE CttlPS REQUIRED [ I ~ ~s ~ so DATE 12/6/77 TITLE Div. Opers. Engr. DIRECTIONAL SURVEY REQUIRED [] YES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG OTHER REQUIREMENTS: [] YES gl NO A.P.I. NUMERICAL CODE 50-133-20252-01 PERMIT NO. 77-79 APPROVAL DATE APPOVED BY TITLE Chairman ee lnstruction On Reverse Side December 2 0, 1977 DATE December 20, 1977 Dec~~ 13, 1977 ADMI N I S T RAT IVE AP P ROVAL ~ O. 44.30 Drilling ~. R. Planty Divisio~ Opera~s F~~ Shell Oil ~y / RDcky Mot~tain O~&ti~ns Office 1700 BroadWay Dena~r, Colorado 80202 On De~ 6, 1977, Shell Oil ~y applied for administrative approval to perfonu the reference operation .pursuant to Rule 6 (d) of Cc~~~ Order ~k~. 44. This opera~ is designed to recover more reserves frcm The Oil and Gas C~nservatic~ ~ttee hereby authorizes tt~e reference1 g~ratic~. SH ELL OIL COMPANY 1700 BROADWAY DENVER COLORADO 80202 December 6, 1977 Subject: Middle Ground Shoal Cook Inlet, Alaska Platform C, Well C-44-14 Rd SE/4, Sec 14-8N-13W, S.M. State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: O.K. Gilbreth, Jr. Gentlemen: We would appreciate administrative approval for redrilling and completing the subject well into the same "G" Pool reservoir at a new location. Our plan is to abandon the lower portion of C-44-14. Attached is Form 10-401 and related data for drilling of the proposed well. Also attached is Form 10-403 for abandonment of the bottom of C-44-14 with a prognosis and diagram- matical sketch for squeezing off the productive intervals. The proposed well is located in an area of leaseholds owned in undivided 1/3 interests by Shell, Chevron and ARCo. As shown on the attached plat, the location is approximately 4300' from the nearest lease line to the West. Justification for this redrill is based upon a low probability of success of repairing current mechanical problems and restoring production in the original well. The redrill will also provide a more optimum location for drainage of the area reserves. Your early consideration will be appreciated to enable prompt use of an available rig. LLN/aaw Attachments Yours very truly, 1 R. Planty Division Operations Engineer Rocky Mountain Operations Office cc: Atlantic Richfield Co. PO Box 360 Anchorage, Alaska 99510 Amoco Production Co. PO Box 779 Anchorage, Alaska 99510 State of Alaska cc: (cont.) Chevron USA, Inc. PO Box 7-839 Anchorage, Alaska 99510 United States Geological Survey Department of Oil and Gas 218 E. Street Anchorage, Alaska Form 1(~403 REV. 1o10-73 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.) 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. °W~kL[X[X~ GAS g~ OTHERWELL 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME She]] 0il Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 1700 Broadway, Denver, Colorado 80290 C-44-14 10, FIELD AND POOL, OR WILDCAT MGS "G" Pool 4. LOCATION OF WELL Atsurface Platform C, Leg 4, Conductor 31 4779'S & 1542'W of NE Corner of Section 23- T8N-R1 3W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etco) 105' DF 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 14-T8N-R13W, S.M. 12. PERMIT NO. 73-13 )crt, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF E~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multtple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letalls, and give pertinent dates, including estimated date of starting any proposed work. Abandonment of C-44-14 is required because of mechanical problems. Apparently, a liner lap failure occurred in early 1977. During the first 5 months of 1977 the well averaged 800 B/D water and the oil production rate is declining at +70%. Remedial operations to restore production in the well are given a low probalility of success. Therefore, it is proposed to redrill C-44-14 to a more favorable location for drainage of the area reserves. A separate permit to drill application for C-44-14 Rd has been filed showing proposed detai 1 s. PROPOSED OPERATIONS' Refer to attached P&A Prognosis and sketches giving present status and proposed abandon- ment operations. ESTIMATED STARTING DATE' December 25, 1977 .. 16. I hereby certlfy~,t~t the/foUr going Is~true and correct (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE Div. Opers. Engr. DATE 12/6/77 TITLE DATE: See Instructions On Reverse Side MIDDLE GROUND SHOAL COOK INLET, ALASKA P&A PROGNOSIS NELL NO' C-44-14 RIG' PLATFORM C PRESENT STATUS' Perforation record (4 shots/ft) 10302~- 10318 10718 - 10796 · 10345 - 10371 108~2 - 10896 10578 - 10598 10938 - 11002 10608 - 10625 11065 - 11105 10660 , 10678 Refer to "Mechanical Detail" and "Abandonment Proposal" sketches attached for additional information. 1. Position rig on well C-44-14 (Leg 4, Conductor 31). 2. Kill well as follows' a. RU wireline unit on ~" tubing 'string. Open sliding sleeve 10221'. If unable to open sliding sleeve due to scale problems, attempt to remove KBM valve or dummy at 1018~'.. If both are unsuccessful, punch hole in tubing as deep as possible (above packer at 10226'). b. Mix and circulate well with 12 ppg mud. Circulate down tubing Until good returns are obtained at the surface from the annulus. 3. Install back pressure valve in tubing hanger. 4. ND tree. NU BOP stack to tubing hanger spool Test BOP's to 3000 psi. 5. Screw into tubing hanger using 2 joints'of 3~" tubing. Unseat tubing hanger and pull 7" uni-packer loose. Circulate 12 ppg mud around. Pull and lay down tubing string. NGTE' a. If tubing is stuck or scaled in, cut and fish out as required. b. Collect samples of-any scale recovered from the interval of the 7" liner top (9342') to the packer (10226'). Forward sam- ples to the Anchorage office for further handling. 6..MU 6,, bit and BHA. RIH with 3½" drill pipe and clean out 7" liner to PBTD of 11254'. NOTE' a. Heavy scale could be encountered at _+10395'. b Collect samples (cuttings) of scale caught while reaming and cleaning out to bottom. Forward samples to Anchorage of'Fice for further handling. c. Possible fill (barite??) will be encountered at ±10850' d. Cleaning out to PBTD of 11254'. is preferred to prevent future crossflow of' water from zones in this well to zones in C-44-1~ Rd. 7. Spot cement Plugs from 11254' to 10200'-+ using 330 cu.ft, class "G" cement (casing volume + 50% exCess). 8. Set 7" cement retainer @lO000'_+. 9. Spot 300' cement plug on top of 7" retainer using Class "G" cement (65 cu. ft.). 10. Set 9-5/8" cement retainer @9300'+. Pressure test 9-5/8" casing above retainer to 2000 psi for 30 minutes. Squeeze cement 7" liner lap below retainer with Class "G" cement if required (volume to be determined by pumping rate 'and pressure). 1.1. Spot 300' cement plug on top of 9-5/8" retainer using Class "G" cement (125 cu. ft.). '12. MU 9-5/8" section mill and RIH~ Mill 40'+ section in 9-5/8" casing starting at 6720' MD. Depending on milling progress, milled interval may be increased. 13. RIH wi th 9-5/8" RTTS tool and set at 6600'_+. Squeeze cement 9-5/8" casing shoe at 6720' to assure that it is properly cemented for future drilling operations. Cement volume will be determined by pumping rate and pressures. 14. WOC as required. Clean out cement with 8~" bit. 15. Underream milled section to 15" (this will expose new formation 'For purposes of obtaining a better kickoff cement plug). 16. SPOT 250'+ kickoff cement plug (100' below milled section to 100' above) using Class "G" cement (150 cu.ft.). 17. After waiting on cement a minimum of 12 hrs., dress off cement plug to 6722' (2'_+ below milled window). WOC additional time if required by -cement conditions when starting to clean out. 18. Kick off and drill C-44-14 Rd as per separate drilling prognosis. ~i. L. Woodson Division Drilling Supt. Western Division LLN/aaw ll~ S4/' psr~b MIDDLE GROUND SHOAL C-44-14 ABANDONMENT PROPOSAL CURRENT PROPOSED 13-3/8" CSG @2483' 3~" 9.3# N-80 Top of .linc @9342' 9-5/8" CSG @9569' Pkr [a10226' ~_~::.,.1 . I.....:,~ 25o', cement kickoff p 1 ug~l~--~-.~ ~n 9-~/8 csg ~=:-~ ..... -. ,~ .... :-.. 300'+ Class "G" cement plug ",, top of retai 300 i± Class "G" cement plug on top of retainer Top "G" Pool 10302' MD Base "G" Pool 11190 'HD NOTE' All depths shown are measured depths 5/8" cmt retai net @9300'+_ SQZ cmt be.low ret. if possible 7" cement retai net COl 0000 Class "G" cement Volume = CSG Capacity +50 Cement Perforated I nterva l from PBTD of 11254' to 10200' ± (1 00' _+_ above top perf) -q M-51 (8-71) WELL. NAME TY, PE WELL FIELD/AREA DRILLING WELL PROGNOSIS C-44-14 Rd Ri ddle Ground-~h--0-~-i Platform C, Leg 4, Conductor 31:4779'S, 1542'W from NE SURFACE LOCATION (SUBJECT TO SURVEY)_ C-orne r o~~23~-~FSN-,--R1-3~F-SM EST. G.L. ELEVATION 105' PROJECTED TD ll500'MDoBJECTiVE "G" Pool Zones OLE CASING PROGRAM 9-5/8" 43.5# N-80 Existing To 9569' i' 11 Full String LOGGING PROGRAMS ORIGINATOR: L.L. NOVACEK [~GIN~FRING APPROVAL: DE PTHS AND FORMATION TOPS KOP _+_6720' MD HC _+10535' MD HD (-8 50) _+10615' MD +-10690' MD HF +_10730'MD HI ±10770 'MD HK (-865o) +10840 'MD HN +ll015'MD HR +-l 1150' MD HZ ±11355'MD TD +_11500' biD DATE 11/21/77 SPECIAL INSTRUCTIONS SA~,~PLES: None (~ Refer to P&A prognosis for C-44-14 i:o Prepare well 'For dril'lin~, below KOP CORES: None DST'S: None DIRECTIONAL CONTROL: Single shot surveys and scientific eye as required. SEE PROPOSED DIRECTIONAL PLAN SKETCH ATTACHE[ CEMENT 7" - su'Fficient cement..to bring top to 9500'-z~qD (Approx 450 sx). SUPPLEMENTAL DETAILED PROG~t0SIS T0 BE ISSUED ON'CASING/CEMENTING OPERtVFtONS .... MUD Freshwater - Liqnosul'Fonate mud C1 < 3100 ppm WL-~ 10 cc's (KOP i:o 10,500') ~ 5 cc's (10,500' to TD) WT - As required to control formation pressure due to water injection. Formation fracture gradient' at K0P estimated to be +ll.5 ppg. OPE F~.~¢ t 0 ~.t.5,-1 L: ~ MIDDLE GROUND SHOAL C-44-14 Rd PROPOSED LOCATION T8N R13W SECTION 14 A-32-14 A-42-14 A-33-14 C-24-14 SECTION 23 C-31-23, A-34-14 Rd 2 A-34-14 ~ C-41-23 -Proposed C-44-14 Rd 550' FSL & 950' FEL at "G" Pool Mkr 8555' TVD (-8450 SS) 4 (Original. Hole) NOTE' Circles represent point of penetration at "G" pool marker 12 -.'3000 TO K,LL L,Nr- ~"~,~ I 'G. K. HYDRIL 12"- 3000 1 II SHiFtER GATE ~ 12'- :3000 ~ TO CHOKE MANIFOLD ~ %"-~ooo --~ CIW RX 57 ~ ' RISER tZ"-- .3000 12"- 3000 DOUBLE STUDDED ADAPTER [-~, ] 12"- 3OOO [. t MIDDLE DECK IO 3/4' CASt DRA'¢~'N i~Y I't.D. Kidd ~'.; SCALE Dk"t'E ?- 6 --7'6 ~ , oOOOr'SI BLOvVOUT Pr-~E,/Ei4TER ST_CK i PLA'FFORM C M.G.S., COOK INLET, STATE OF ALASKA i:' .~M-51 (8-71) DRILLING WELL PROGNOSIS WELL NAME C-44-16 Rd T Y, P E W E L L FIELD/AREA Middle Ground Platform C, Leg 4, Conductor 31:4779'S, 1542'W 'From NE suRFACE LOCATION (SUBJECT TO SURVEY)_ 'CO-F~ e r o~~t-i-6 n---23';-~FSN ,--P, T3~FSM EST. C.L. ELEVATION 105' "G" Pool Zones PROJECTED TD 11 500' MD OBJECT IVE OLE .'IZE CASING PROGRAM 9'5/8" 43.5/? N-80 -Zxisting To 9569' 11 Full String .L , LOGGING PROGRAMS ORIGINATOR: L.L. NOVACEK ENGtNEEFtlNG APPROVAL: P'g T R(11 F-tIM' DE PTHS AND FORMATION TOPS KOP ±6720'MD HC ±10535'MD HD (-845o) ±10615'MD HE¸ HF ti ±10690' MD ±10730' MD ±10770 'MD HK HN HR HZ (-8 5o) ±10860 'MD +ll015'MD. ..... ±l 1150' MD ±l 1 355' MD TD (-9150) ±l 1500' MD SPECIAL INSTRUCTIONS SAMPLES: None C9 Refer to P&A p.rognosis for C-44-16 to prepare well for drillin~ below KOP CORES: None DST'S: None DIRECTIONAL CONTROL: Single shot surveys and scientific eye as required. SEE PROPOSED DIRECTIONAL PLAN SKETCH ATTACHED CEMENT 7" - sufficient cement ~to bring top to 9500'±MD (Approx 450 sx). SUPPLEMENTAL DETAILED PROGNOSIS TO BE ISSUED ON'CASING/CEMENTIFIG OPERATIONS .. . . MUD Freshwater - l_iqnosulfonate mud C1 < 3100 ppnl , WL < 10 cc's (KOP to 10,500') < 5 CC'S (10,500I to TD) WT - As required to control formation pressure, due to water injection. Formation fracture gradient at KOP estimated to be ±11.5 ppg. DATE 11/21/77 OPE RA'£10~~/CN L: ~ ' MIDDLE GROUND SHOAL C-46-14 Rd PROPOSED LOCATION T8N R13W SECTION 14 A-32-14 A-42-14 A-33-14 C-24-14 SECTION 23 C-31-23 NOTE- Circles represent point of penetration at "G" pool marker A-34-14 -_P_Egposgd C-44'14 Rd 550' FSL & 950' FEL at "G" Pool Mkr 8555' TVD (-8450 SS) ~4-16 (Original. Hole) FG.K. HYDRIL 1 L ,~"-:,ooo II SHAFFER GATE ~ ~2'- sooo 12'.'.3000 fI ~ To K~LL UNE ~:~ %"- aGOG CIW RX 57 (° RISER IZ"-- :5000 12"- 3000 DOUBLE STUDDED ADAPTER ,o,,- ooo - '_L' 12"- 3000 ~ TO CHOJtE MANIFOLD DRA~C,N t~'f ti.D. Kidd ,i SCALE c,.,...~.,~:o ~;, i SHELL OiL CO'~ ,,~PANY Dkl E 7 - 6 -76 ~~~ ' . oOOOrSI BL_Ov~OUT Pr,~VE~dTER STACK PLATFORM C M.G.S., COOK INLET, STATE OF ALASKA ..................... ~¡,~:..,."-,_: ~""""'." CHeCK LISi fOt{ t¡th ¡,;eLL rt.KHl ¡ ~ Con¡p,any - ',:, '.:5,1,£// Yes No Remarks -- 1. Is the permit fee attached. . . . . . . . . . . . . . . . . . . . . ~K '3- LcdJt: è1 ..,e II ,\u. c- ¥Lf--/<f k!D 2. Is well to be located in a defined pool . . . . . . . . . . . . . . ~K - '"' j. Is a registered survey plat attached ~ . . . . . . . . . . . . . . . - ~~ /110 f #eCt? S1>c7 ~ 4. Is \-¡ell located proper distance from.property line. . . . .'. . . . '~t:... - ~'-ØP-4.J' /1,/1- "~,,,,"""-,.. """""'-"""'-"'-"'--"':"""""""':-"""--""-- -_. -- -."...- - 5 . 6. Is \':ell located proper distance from other \"Jells . . . . . . . . . . }h-4K..- 7 . Is \'!ell to be deviated. . . . . . . . . . . . . . . . . . . . '.' . f.Jc¡J( - I Is sufficient undedicated acreage available in this pool. . . . . . 8, 9. Is operator the only affected party . . . . . . .' . . . . . . . . . ~ - '. r .~ '" " Can. permi t be arp~~oved before ten-day \'¡a it. '.' .' . . . . . . . . . ÆM./( - -diet" ,q.IJ. Does opera tor ha ve a bond in .force . . . . . . . . . . . . . . . . . ~/::...- , ' <::: °"1, CA: fltHf I ~e/t{~" ~~~' ~"'FDJ' ~.tR~~ (,'""'-"",,,',',;', " ;,; : ~",. 20. Has Qt'1Ef1 approved Plan of Operation. . . . . . . . i\ddîtional Requirements: ~t""'~ L4-<r-.L ~, ',' ' '~ OfldJ My, tvJl"?/77 " ~ ' /~'~J~,I::J~/ ~ ðBPt~ova 1 Recommended: Geology: Engin TRM<1fvt1' dAL HHH H\' K jMK. -LCS Revised 11/17/76 Is conductor string provided. . . . . . . . . . . . . '," . " . . Jf¥1 - . . . . ~", ,-'-- ,~""'~. gh1,,~ ~ - ~~dl~~ . g&fl , '¡m . . . . .. . . . - fM. . kA- .t1tfl 3-<) ~y)~wLJ. 1 . Is a conservation order needed ~ . . . . . . ~ . . . . . . . . . . . ~ #cðK ~ r. u: . I S f: ,~ :;' i n i s t rat i ve a p pro val nee de d . . . . . .'. . . . . . . . . . . .,t.L.ItJK- 13. 14. Is enough ce~ent us~d to circulate on conductor and surface vii 11 cement tieinsurfacean;d intermediate or Pfoç1qction$trinQs 15. 16. \~i"l cer;ent cover al1k<:oo\'Jn productive hqri2:ons . . . . . . . . . . "~f.'r, \.1i 11 surface cas i ng pr~~tect fresh wa ter zones. . . . . . . . . . . 17 . 18. 19. , I , Will all casing give ad~quate safety in çollapse~ tension & burst Does BOPE have sufficient pressure rating -Tes't to 3. ð (] (L P s ig , . Æ!~..i;~ p- s /~a~ c -4' Lf -j '/ ~ . ,. -..' ---",--_.,-~ "', ....,.... ,.,_.. , , ,--,.", ..'
