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187-044
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:Brooks, Phoebe L (OGC); AOGCC Records (CED sponsored) Subject:FW: AN-13RD (PTD# 187-044) Temperature Survey and CMIT Date:Wednesday, June 26, 2024 4:42:10 PM Attachments:AN 13RD-2 static 06-16-24.pdf From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, June 26, 2024 3:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Aaron Douget <adouget@hilcorp.com>; Jake Strecker <jstrecker@hilcorp.com>; Daniel Wik <dwik@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: AN-13RD (PTD# 187-044) Temperature Survey and CMIT Mr. Wallace, Per AIO 6.013, the Granite Pt St 18742 13RD (PTD 187-044) requires a biennial temperature survey. The 2024 survey was completed on 6/16/24. The survey data is consistent with the previous temperature survey and confirms the injected fluids are being contained in the approved strata. According to the amendment from 2/26/24 to AIO 6.013, this well also requires a combination MIT. Over the past week, we made several passes with a holefinder tool on slickline while conducting pressure tests with the tool set at varying depths. After troubleshooting several items and testing different tools, we determined on 6/22 that the well was not capable of holding pressure sufficient to pass a combination MIT. The well was shut in on 6/22 and will remain shut in while we evaluate options for future utility of this well. Please reach out to me with any questions. Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: Field:06/16/2024HilcorpAN #13RD-2 Anna Plt. 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Temperature (Deg. F)Depth (feet) RKBPressure (psia) Pressure Perfs PKR 20"13 3/8"9 5/8" 7"3 1/2"POOH Press Temperature POOH Temp Pressure-Temperature Profile 1. RIH vs POOH Overlay 2. Well Shut-In Report date: 6/26/2024 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:Brooks, Phoebe L (OGC); AOGCC Records (CED sponsored) Subject:FW: Granite Pt St 18742 13RD, also known as Anna-13RD (PTD 1870440) - AIO 6.013 Compliance Temperature Survey - October 2022 Date:Wednesday, November 2, 2022 3:40:42 PM Attachments:ANNA 13RD - Temperature Survey - 2022-10-07.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Wednesday, November 2, 2022 12:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Granite Pt St 18742 13RD, also known as Anna-13RD (PTD 1870440) - AIO 6.013 Compliance Temperature Survey - October 2022 Mr Wallace, Per AIO 6.013 (Administrative Approval), Granite Pt St 18742 13RD, also known as Anna-13RD (PTD 1870440), requires a biennial temperature survey. The 2022 survey was completed on 10/7/2022. The survey data (see attached plot) is consistent with previous temperature surveys and confirms that all the injected fluids are being contained in the approved strata. Let me know if you have any questions or require additional information/data. Thanks Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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. Well: Field:10/07/2022HilcorpANNA 13RD Anna Platform. 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Temperature (Deg. F)Depth (feet) RKBPressure (psia) Pressure 10-07-22 Perfs PKR 20" 13 3/8"9 5/8"7"3 1/2" Pressure 10-15-20 Press 10-15-18 Temperature 10-07-22 Temperature 10-15-20 Temp 10-15-18 Pressure-Temperature Profile 1. RIH Overlay 10/15/18 - 10/15/2020 - 10/07/2022 Wallace, Chris D (CED) From: Julie Wellman - (C) <Julie.Wellman@hilcorp.com> Sent: Friday, October 30, 2020 11:44 AM To: Wallace, Chris D (CED) Subject: Granite Point State 18742 #13RD (PTD # 1870440) Temp Survey October 2020 Attachments: AN 13RD Temp Survey 10-15-2020 10-15-18.xis Hello Chris, We completed a compliance temp survey on An -1 3RD (PTD # 1870440) in October of this year. The overlay of the 2020 and 2018 survey plots clearly show that the fluids are being contained in the authorized injection zone. We are requesting that that this temp survey satisfies Condition #6 of AIO 6.013, which is the requirement for an every other year compliance temp survey for An -1 3RD. Please let me know if this meets with your approval. Thank you, Julie Wellman Regulatory Tech — Hilcorp Alaska, LLC o: 777-8505 1 c: 360-265-4397 Julie.Wellman(i hilcorp.com 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 it 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. P -1-D t%704- lHilcorp I Well: SAN #13RD-2 I Field:jAnna Pit. 110/15/2018 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Report date: 1013012020 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 aogcc.alaska.gov SECOND AMENDED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 6.013 Ms. Holly Tipton Regulatory Technician Hilcorp Alaska, LLC. 3800 Centerpoint Drive Anchorage, AK 99503 Re: Docket Number: AIO-18-016 Request for administrative approval to eliminate the expiration date to allow Granite Point State 18742 13RD (PTD 1870440) to continue to be online in water only injection service with a known tubing by inner annulus communication Granite PT ST 18742 13RD (aka An-13RD) (PTD 1870440) Granite Point Field Middle Kenai Oil Pool Dear Ms. Tipton: By letter received April 16, 2018 and an email request dated October 17, 2018, Hilcorp Alaska, LLC (Hilcorp) requested administrative approval to eliminate the expiration date and continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 06.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to eliminate the expiration date and continue water only injection in the subject well. This well has communication between the tubing and 9 5/8” casing that was not resolved by a tubing patch intervention performed in August 2014. Hilcorp has committed to repair this well should a workover rig get deployed to the Anna platform. Hilcorp has performed a temperature survey on October 15, 2018 which shows good correlation with the other temperature surveys completed October 18, 2014 and October 30, 2016 and continues to indicate fluid entry is below the packer and to the existing perforations. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 6.013 Second Amended October 22, 2018 Page 2 of 2 AOGCC’s approval to continue water injection only in Granite Point State 18742 13RD is conditioned upon the following: 1.Hilcorp shall record wellhead pressures and injection rate daily; 2.Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli with any bleeds flagged on the report; 3.Hilcorp shall install, maintain and operate automatic well shut-in equipment linked to the well’s inner annulus (IA) and outer annulus (OA) pressure. The actuation pressure shall not exceed 2,150 psi for the inner annulus. The actuation pressure shall not exceed 750 psi for the outer annulus. Testing of the shut in equipment shut-down valve and mechanical or electrical pressure devices shall be performed upon install, and every 6 months thereafter, ideally in conjunction with production well pilots and safety valves. Hilcorp shall provide to the commission the testing procedure that will be used to verify integrity of the well shut-in equipment linked to the inner and outer annulus pressures; 4.Hilcorp shall limit the well’s IA operating pressure to 2,150 psi; 5.Hilcorp shall limit the well’s OA operating pressure to 750 psi; 6.Hilcorp shall perform a temperature survey every two years; 7. Hilcorp 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 DONE at Anchorage, Alaska and dated October 22, 2018. //signature on file// //signature on file// //signature on file// Hollis S. French Cathy P. Foerster Daniel T. Seamount, Jr. 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. 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.m. on the next day that does not fall on a weekend or state holiday. • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Tuesday, November 08, 2016 3:10 PM To: Wallace, Chris D (DOA) Subject: Granite Point State 18742 #13RD (aka An-13RD) AIO 6.013 Compliance Temp Survey 10-30-16 Attachments: AN 13RD Temp Survey 10-30-16 vs 10-18-14.xls; RE:An-13RD AA (PTD: 187-044) 10-23-14 Hi Chris, On 10/30/16, a compliance temp survey was completed on Granite Point State 18742#13RD (aka Anna Well No. 13RD — PTD 1870440), per condition#6 of AIO 6.013. The attached temperature survey plot, overlaying An-13RD temp surveys on 10/30/16 and 10/18/14, indicates downhole containment of the injection fluids with no significant temperature anomalies. No visible anomalies demonstrate that downhole fluid containment is being maintained. Also notable is that the two temp surveys run two years apart nearly overlay one another—another good indicator that nothing has changed regarding casing integrity and all injected fluids are still exiting the casing at the perfs. Per condition#9 of AIO 6.013, the expiration date of this AA is 12/31/16. The attached e-mail resulted in this deadline by referencing (in 2014) the certainty of repairs being completed on this well before the end of this year(2016)...such is not the case. Due to re-verifying the injected fluid containment, as proven by the overlaid temp surveys, and the challenging price environment to justify a standalone costly well repair, Hilcorp is requesting an extension of this AA for two more years (ie 12/31/18). Should an occasion arise to get a WO rig on the platform prior to this new deadline, the opportunity to repair the integrity in this well will be taken. Thank you Please call me if you have any questions. 77�Larry322 SCANNED MAY 2 6 2017 1 . • • 0 I Hilcorp Alaska LLC Well: AN #13RD Field: Anna Plt. 10/30/2016 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1000Imillillilli�_ 2000 - iiiw. — — i T Pressure-Temperature Profile �� 1. RIH Overlay 10/18/14 - 10/30/16 3000 = 11=11411,IINIMME '4 MINIIi MEI 4000 1NIIMIIIN 1111=1•110111=1 .111111111 `-MM IMMIIMMEMM MIN IiiiiiiMMIIMMME CO IMINN=miMilliim IIIIIIIMIIM MI Mil= 111111 W 5000 I — t 6000 4.. d c CI r w16.N.` _mil. EMIL N. 7000 8000 , OIL NM T P011X 900 ot =-iIN 10000 ki Ni 11000 1 1 I I I I I I I I 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) —10-30-16 Pressure - Perfs PKR 20" 13 3/8" —9 5/8" 7" 3 1/2" 10-30-16 Temp —10-18-14 Temp Report date: 11/17/2016 rage ~ of L Regg, James B (DOA) (~?~ ~ ~7-- ~~ ~~ ~ _~.v From: Regg, James B (DOA) ~~ ~~ ~~~ Sent: Tuesday, November 24, 2009 9:59 AM To: 'Martin, J. Hal' Cc: Maunder, Thomas E (DOA); Aubert, Winton G (DOA) Subject: RE: Anna Well An-13RD MIT I concur, and, like the Dolly Varden Pltfm wells, you should add Anna Well 13RD to the monthly injector waiver report. Jim Regg AOGCC t~ 333 W.7th Avenue, Suite 100 ~ ~ L ~= 2~0~ Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, November 12, 2009 4:56 PM To: Regg, James B (DOA) Cc: Greenstein, Larry P Subject: Anna Well An-13RD MIT Tim, I see from your reply to my a-mail to you for the Dolly MITs that you are on aut of the office. I have a similar question about Granite Point State 18742 Well No. An-13RD (Permit # 1870440), Anna Platform, Granite Point Field. A standard MIT is due on An-13RD by 12/3/09. The well has been shut-in almost 2 years (since early January, 2008) because, as you know, waterflood on the Anna has been down since that time due to surface waterflood injection equipment issues. Based on our Dolly a-mails and knowing that you prefer waiting until waterflood injection is restored before conducting standard MITs, I am planning to apply this to An- 13RD and defer the MIT until waterflood injection is restored an the platform. The well will remain shut-in and we will notify you when injection is resumed and an MIT can be conducted. Do you concur? Thanx, Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 11 /24/2009 Yage z of L 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal. martin@chevron.com 11 /24/2009 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg 1<7 IÞ/ t 4 lib P.I. Supervisor t(cr DATE: Wednesday, December 14,2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 13RD GRANITE PT ST 18742 13RD \ ~1- 0 L{ L-f FROM: Jeff Jones Petroleum Inspector Src: Inspector Rcviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: GRANITE PT ST 18742 13RD Insp Num: mitTJ051208121601 ReI Insp Num API Well Number 50-733-20055-01-00 Permit Number: 187-044-0 Inspector Name: Jeff Jones Inspection Date: 12/3/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -W~IITliRD---1Typ~-inTlw ITVD----r- 7785~A -T--~l-----;¡5012ï;5-·1 - 2175 - ; .- - . - T .- -- . ~1!2~~Y~'~'i~: l T~-'=si ·1-'94625_t~~b::, -1 . 2~:ol.. ,:id_··~~I~_t· _ . -. : _ Notes Pre-test pressureswere monitored & found to be stable. The well passed the standard annulus pressure test. SCAtJNIEL· Wednesday, December 14,2005 Page I of I • Maunder, Thomas E (DOA) From: Greenstein, Larry P [greensteinlp@unocal.com] Sent: Thursday, December 08, 2005 7:48 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); 'Martin, J. Hal' Subject: RE: MIT_Anna_12-03-05 Hi Tom, Yes, these wells brought up some interesting thoughts when I saw these pressures too. It appears that they are holding a back pressure on both these annuli. Talking to the operators, they have been doing this from day 1 based on something the Amoco engineers designed from the start. We missed these annulus back pressure wells when we were digging around after the G-16 issue arose. The last MIT tests for both wells used the bleed off and annulus monitoring technique as both annuli were above the minimum required test pressure. Looking at the TIO plots for both these wells, these pressures seem to be in the 'normal' range for the annuli. The MUCI-3 well is their swing well. It is on injection continuously, but it handles the excess from the pumps that the other wells won't take. One of the two water injection pumps quit in mid-November, so when the inspector was on the platform only one pump was in use. This means that almost no water was going into MUCI-3 and, per the operators - it almost goes on vacuumm at low rates, the tubing pressure would drop off to almost nothing. Their sewage system is designed to go only to the MUCI-3 well and was sized for a max of 15-20 bpd, usually 1-2 bpd. This well normally takes around 1750 bpd of water, but with only one pump running it is down to around 10-20 bpd, which is very hard to meter at that level. Our files are very skinny on these wells too. I do have MITs on both wells from 2/8/97 and I sure can dig downstairs to see what else is down there. Hope this helps. Larry J~ i r L u'~ 3. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] `~~~ ~,~ Sent: Wednesday, December 07, 2005 8:19 AM To: Greenstein, Larry P ~~ S~G~ ~~~yc~ ~v~Z_? Cc: Jim Regg Subject: Re: MIT_Anna_12-03-05 Larry, '~~~ ~ SS`1-~Jyy ~7~ S~c,.~ ~$`1~~ \ 3~~ "~-~ I was looking at these MITs and have a couple of questions regarding An-13RD and MUCI-3. 1. On both wells, the initial pressure on the annulus is shown to be 1500 and 2500 psi respectively. Referencing the last MIT from 12/27/2001 in the well files, the "pretest" pressure on the annulus of both wells is shown to be 2500 psi. Is it normal to have the pressures at these levels?? Is it possible for you to provide TIO plots for each well for the last 6 months?? 2. I am interested in the comment "Salt water & sewage. Reduced press 675# & monitor" on MUCI-3. From the tubing pressure, it appears the well was not operating. Is the well "continuously operated"? What is the normal injection volume and how much is seawater and how much sewage?? 3. I looked at both well files and there really isn't a lot of information in either. Each file has a copy of the last MIT from 12/27/2001, but then the next information in the MUCI-3 file is a 404 dated 6/15/87 regarding a workover and the next information in 1 • An-13RD is a log transmittal dated August 30, 1987. Can you check your files on these wells to see what information might be there between 1987 and now?? Let me know what you find and we can determine what information should be provided to make the file more complete. Thanks in advance for looking into this request. Call or message with any questions. Tom Maunder, PE AOGCC Greenstein, Larry P wrote, On 12/6/2005 4:11 PM: > Gentlemen, > Here is the record of the MITs performed on An-13RD and MUCI-3 on the > Anna platform. > Larry > «MIT Anna 12-03-05.x1s» > - - 2 An-13RD & MUCI-3 TIO plots a~997 MITs • Page 2 of 2 An-13RD Pressure Observations aooo -- HRS ON -TBGPRESS -CSGPRES52 9 518 35D0 CSGPRE553 13 318 CSGPRESS520 -DAILY VOLUME 3000 ~ l 2500 ~ J Y 2 ~ 2000 d ~ 1500 1000 \ t l l , N +r ~ .+ 1 500 ` ~ __ _ _ r._ ____ __ D 02!17105 04!08105 05/28/05 07!17105 09/05/05 10!25!05 12!14105 02!02106 Data 10/13/2009 MIT Anna 12-03-OS • • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [greensteinlp@unocal.com] Sent: Tuesday, December 06, 2005 4:11 PM To: 'Winton Aubert @ AOGCC'; Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Regg, James B (DOA) Cc: 'Rodriguez, Tim E.'; 'Moultrie, Dan R'; 'Moore, Dave M'; 'Martin, J. Hal' Subject: MIT Anna_12-03-05 Attachments: MIT Anna 12-03-05.x1s Gentlemen, Here is the record of the MITs performed on An-13RD and MUCI-3 on the Anna platform. Larry «MIT Anna 12-03-05.x1s» 10/13/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@ admin.state.ak.us;Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.u: greensteinlp@chevron.com; trodriguez@chevron.com OPERATOR: Unocal Alaska FIELD /UNIT /PAD: Granite Point Field /Anna Platform DATE: 12/03/05 OPERATOR REP: Dan Moultrie AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well An-13RD Type Inj. W TVD 7,785' Tubing 2,911 2,890 2,905 2,890 Interval 4 P.T.D. 187-044 Type test P Test psi 1946 Casing 1,500 2,150 2,150 2,150 P/F P Notes: OA 52 100 98 100 Well MUCI-3 Type Inj. I TVD 8,021' Tubing 40 38 38 38 Interval 4 P.T.D. 178-019 Type test M Test psi 2005 Casing 2,875 2,200 2,200 2,200 P/F P Notes: Salt water & sewage. Reduced press 675# & monitor. OA 130 100 100 110 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Test Details: TYPE INJ Codes D =Drilling Waist G =Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT_Anna_ 12-03-05.x1s ti ti~ - ALASKA OIL AND GAS CO,.-,NERVATION COMMISSIC3N - " ~ MECHANICAL INTEGRCIY TEST Dane 'Z.'~'~~ Company U,~ocw1 Field C~~AN~t~ Qo~~.,Jt' INELE_ NAME "P *S 'M *t - *N TYPE OF ANNULUS FLUID PKR TVD M© CASING SIZElWt7GRADE TBG SIZE REQ TEST PRESS PRETEST TBG CSG PRESS START TIME TBG CSG PRESS 15 MIN TIME TBG CSG PRESS 30 M[N TIME TBG CSG PRESS P 1= 5-ti+ ~,~85 4~ 00 yo~- N-BAD +~gop yos~ S-9S' ~ s.. ~ qy6 Zo 7.c~ ZO Le 13 RD-2 S z ~,,,,~iR • 8j3oy v~ s~ s-qs ~ ~"ca ,~sd ~-Bo . ~sl 1 9Sb ~ X571 r9.Sa J 9,, 'o Comments: Comments: Comments: i~,i • TUBING INJECTION FLUID: P =PRODUCE WATER INJ m S =SALT WATER INJ ~ M -MISCIBLE INJECTION ~ I =INJECTING N = NOT INJECTING C.0~6 (rev 5f10t9D) ANNULAR FLUID: GRADIENT: WELL'f1=ST: Initial 4 year DIESEL Workover GLYCOL Explain SALT WATER DRILLING MUD OTHER AOGCC WITNESS SIGNATURE OTHER ,~ ~ ~~ COMPANY REP SIGNATURE ~i4••, __ _ . ~.~ ~., '`C ....:a gym! ~ ~ ~ ~ ~.r ~ ~:! Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb~unocal.com UNOCAL Beverly Harrison Business Ventures Assistant 6/17/2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - I'!.::;E:WE~2~ '.'¢'t~'~'~,~';:?',:? I"OG?I;YPE~'~/~:i;~ff;.:;";':5!:''.~':''' :!SCALE: I, "(- DATE:~.~" I~INTERVAI~,'. ii'B-LINE;"I FILM"[ CD" COMPLETION RECORD- 2,5" HSD A-15RD POWER JET 2506 HMX 5 INCH 5/1/2003 11750-12550 2 1 1 AN-13RD2 RST SIGMA MODE 5 INCH 5/22/2003 3400-4650 2 1 1 .... AN-19 RST SIGMA MODE 5 INCH 5/22/2003 3400-4650 2 1 1 AN-37 RST SIGMA MODE 5 INCH 5/22/2003 3100-4250 2 1 1 COMPLETION RECORD- 2.5" HSD G-12RD3 POWERJET6SPF 5 INCH 5/10/2003 12400-13610 2 1 1 2 1/2" HSD PWER JET 2506, HMX 3 1/2" ~'GRINER-1 HALLIBURTON PLUG 5INCH 4/19/2003 250-1780 1 1 1 GRINER-1 CEMENT MAP 4/8/2002 0 0 1 TEMPERATURE SURVEY - CEMENT TOP KGSF-3 IDENTIFICATION PBMS 2 INCH 6/4/2003 3500-7020 1 1 1 COMPLETION REPORT- 2.5" HSD M-5 POWERJET, 6SPF 5 INCH 4/16/2003 3600-3900 2 [..\ 1 1.56" 1606 HMX, TUBING PUNCHER /SRU223-28 COMPJETION RECORD 5 INCH 5/25/2003 1580-5606 1 1\ 3.5 HALLIBURTON CAST IRON PLUG / SRU 223-28 CEMENT DUMP BAILER 5INCH 5/24/2003 1662-5665 1 1 1 Please acknowledge receipt by signing and returning o~...copy...of this transmittaI or FAX to~ t!' *ih'(907)'"~' ,.,.~ ~263'7828' : ........ ~"%?' ...... ~,~ ..;~ ,~.,: ., .~..~ Received B ,~ 0 (1~ D..,..t~/v'x Date: ~ IM 0 r, ?t'l.i"?, MEMORANDUM TO: Camille O. Taylor Chair THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 27, 2001 3 -/ SUBJECT: Mechanical Integrity Tests Tom Maunder ~,O~"~~ "~:>'~'~- Unocal P.I. Superv~sorl'5~_' ~.~.~,.~,~- ' Anna Platform ..% o-- 13RD, MUCI-3 Jeff Jones Granite Pt. State Petroleum Inspector GPF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. .' WellI 13RD Type lnj.I S I T.V.D. I 7785 I Tubingl 3365 I 3365 J 3365 I 0367 l Interval] 4 P.,T.D.I 187-044 Type testI M I Test psiI 1946'I Casing I ,2500 I 2000 I 2000. ! 2000 I P/F '1 13 Notes: WellI MUCI-3 I Typelnj. I S I~ I~°~ I'Tubing I1086 I1087 I1087 I1087 I lntervall z~' P.T.D.I 178-019 TypetestI' M JTestpsiI 2005 I CasingI 2500I 2005} ~)005 J '2005 I P/F I 13 Notes: Notes: P.T.D.I Notes: . P.T-D.I Notes: Type testI ,, I Test psiI 1946 I (~asing,I I I" i I P/,F I IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details December 27, 2001: I traveled to Unocal's Anna Platform to witness Mechanical Integrity Tests on water injection wells 13RD and MUCI-3. Paul Delago was the Unocal representative in charge of the tests, which he performed in a safe and proficient manner. The pre-test pressures were monitored and found to be stable. The annulus pressure on each well was then reduced 500 psi and monitored for 30 minutes with no changes noted. Both wells passed the 30 minute MIT. Summary.; I witnessed successful MITs on Unocal's injection wells 13RD and MUCI-3 on the Anna Platform. M.I.T.'s performed: 2_ Number of Failures: _0 Total Time during tests: 2 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT GP ST Anna 13RD, MUCI-3 12-27-01 JJ.xIs 1/14/02 STATE OF ~ALASKA ALASKA OIL k%'D GAS COXSERVATION C~,~!ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 579-1433 TO: Receipt of the following material which was transmitted via QUANT I TY DESCRIPTION . J Copy sent to sender YES . NO ~k~ STATE OF ALASKA ~ ALAS~ DIL AND GAS CONSERVATION ~ 'MMISSION WFLL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well ~i ( 1. Status of Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICEJ~] .Water Injection .... i' 2. Name of Operator 7. Permit Number 87-44 Amoco Production Company 8. APl Number 3. Address P.0. Box 100779, Anchorage; Alaska 89510 5o- 733-20055-0~ 4. Location of well at surface Legc4, S1 ot 5 P1 atform Anna 9. unit or Lease Name 780' FNL, 708' FEL, Se . 12, T10¢1, R12W, S.M. 6ranite Point 18742 At Top Producing Interval 65 (8,551IMD, 8,027' TVD) lO. Well Number 1.qRD 1,768' FNL, 2,246' FWL, Sec 12, T10N, R12W, S.M. ll. Field and Pool At Total Depth 894'FNL; 2..321' FWI, _q~n. 17. T10.N~ R!2W. S~M. Granite Point Field 5. Elevation in feet (indicate KB, DF, etc.) .... 16. Lease Designation and Serial No. Middle Kenai Sands 105' KBI ADL 18742 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/12/87 06/21/87 08/10/87 7'71, feet MaE one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost 10,302RD 9~757¥VDr" I0:214MD' 9'~873TVI,~YEs~ NO [] ~]/~ feet MD 22. Type Electric or Other Logs Run Phasor Induction, Array Sonic, LDT-CNL, FMS-Dipmeter 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 35¢~ NRC) 7,719 10=?q.R 8½ 700 sx N/A ..~ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See Attached 3½" 8.3~.~' ~,_~nn, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None : 27. PRODUCTION TEST Date First F~:J~XtXc]~ injecti on Method of Operation (Flowing, gas lift, etc.) 07/10/87 Wa tP_r Tni~r. tir n Date of Test Hours Tested PRODUCTION FOR OIL-~I~t~ .... GAS-MCF WATER-EEL CHOKE SIZE IGAS'OILRATIO 08/10/87 24 TESTPERIOD ~ N/A N/A N/A N/aI N/A. ~=Xc)(~(]-L~bing Casing Pressure CALCULATED O~X-~,'li}~XX) ~ WAT'~'-I~BL ~XLx~I~('~(I)~-~'~(c~) Press. 175~ 2000 24-HOUR RATE I~ InjeC~_infi 466 B~PE 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .~ :,., ~ 0 ~3 1.9, ~ 7 Alaska 0il & ~as Cons. Commissior~ Anchorao. Submit in duplicate Form 10-407 ;~, ~'C' S,-//~ ; ~NTINUEDON REVERSE SIDE Rev. 7-1-80 , 29. "-"' 30. GEOLOGIC MARKERS :' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, · MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. C2 8,205 7,689 C3 '8,332 7,813 C4 8,372 7,852 C5 8,458 7,935 C6 8,650 8,124 C7 8,956 8,427 C8 .9,570 9,039 31. LIST OF ATTACHMENTS Directional Survey, Daily Reports, Logs to be forwarded by Service Co._ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~//~Y~~~'~'~'~/~ TitleDistrict Manager. Date 10/06/.87. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 GP 18742 Well No. 13 Perforation DePth (Abandoned) Measured Depth 8,390 - 8,435 8,540 - 8,625 8,650 - 8,690 9,000 - 9,020 9,410 - 9,430 9,480 - 9,560 9,583 - 9,650 9,677 - 9,707 9,935 - 9,960 10,010 - 10,035 True Vertical Depth 7,854 - 7,896 7,994 - 8,074 8,097 - 8,135 8,433 - 8,453 8,837 - 8,857 8,907 - 8,987 9,010 - 9,077 9,104 - 9,134 9,362 - 9,386 9,437 - 9,462 SUBJECT Amoco Production ENGINEgRING CHART Sheet No. Of File A p I)n Date 371 1-8¢o GP 18742 Well No. 13RD Performations Open to Injection C5 Measured Depth 8,551 - 8,581 8,606 - 8,648 True Vertical Depth 8,027 - 8,056 8,081 - 8,122 C7 9,012 - 9,042 9,064 - 9,088 9,102 - 9,112 9,133 - 9,182 9,188 - 9,192 9,217 - 9,223 9,228 - 9,258 9,284 - 9,360 C8 9,582 - 9,645 8,483 - 8,513 8,535 - 8,559 8,573 - 8,583 8,604 - 8,653 8,659 - 8,663 8,688 - 8,694 8,699 - 8,729 8,755 - 8,830 9,052 - 9,115 RECEIVED Oil & ~as ~ons. ~omm~ss~o~ Anchorage D~NVER REglO~ .... ~ ANGHORAQE DISTRIC~'"~*~ 08/11/87 ~ PAGE 05/31/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAG 986349-0~-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 10143, MOVE IN X INSTALL SHAKERS COSTS: DAILY WELL $29693, CUM WELL $29693 REMARKS: SHUT TBG IN ~ 1000 HRS 5-29-87; 20 PSI IN 2 HRS~ 25 PSI IN 6 HRS; 30 PSI IN 10 HRS~ 30 PSI IN 20 HRS; PRESS TEST 9-5/8" ANN 3000 PSI- LOST 25 PSI IN 30 MIN CHRON TIME DISTRIBUTION 18.00 - MI, INSTALL NEW SHAKERS; CHANGE MUD PIT VALVES; RE-ROUTE DE-GASSER MUD LINE; INSTALL MUD DITCHES; FAB FIRE WALL BETWEEN SHAKERS X CELLAR; SKID RIG LEG 4 SLOT 5; N/U SVC LINES; N/D TOP XMAS TREE; INSTALL BPV; MI BOP SO WELDER CAN FAB SHAKER FLOW LINE. JOB INITIATION REPORT: DIRECTIONAL HOLE CURRENT WELL ACTIVITY-AUTHORIZED, DATE 03/27/84 ~.~ 06/01/87 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAG 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 10143, TRIP OUT X L/D 3-1/2" TBG COSTS: DAILY WELL $9050, CUM WELL $38743 CHRON TIME DISTRIBUTION (HRS): 14.00 - MI, INSTALL CHOKE X KILL LINES; INSTALL FLOWLINE TO POSSUM BELLY; WELD IN SHAKER DITCHES 3.00 - TSTBOP, ANNULAR 2200 PSI-RAMS CHOKE; KILL LINES X VALVES~ 3500 PSI-OK. t.50 - PTQ, PULL TBG HANGER LOOSE {~0000 LBS} 2.50 - CIRC, 600 BBLS FIW-OBTAINED INiTiAL FLUID SAMPLE 3.00 - PTG, TRIP OUT X L/D 3-1/2" TBQ- WELL STABLE 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAG 986349-01-7, AP1 50733~005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 10143, PICK UP 5" DRILLPIPE COSTS: DALLY WELL $15371, CUM WELL $5411~ CHRON TIME DISTRIBUTION (HRS>: 5.00 - PTG, TRIP OUT X L/D 3-1/2" TBQ 0.50 - RRIG, REPAIR MOUSE HOLE Alaska 0il & Gas Cons. Anchorage ~ENVER REgIC'-~*~ ANCHORAGE DISTRI~'-- ~ 08/11/87 ~ PAgE 3 5.50 - PTG, TRIP OUT X L/D TBg X SEAL ASSY 1 50 - OTHER, L/D 3-1/2 TOOLS; CHG TO 5" RAMS 4 O0 - TSTBOP, 2500# ANNULAR-3500# RAMS CHOKE~ ETC. 0 50 - OTHER, INSTALL WEAR BUSHING 3 O0 - OTHER, P/U TSA TOOLS X BHA TO PLUCK PKR 0 50 - OTHER, SORT TOP DECK D.P. 3 50 - PU, P/U 5" O.P. X INSTALL RUBBERS EVERY OTHER JT. 06/03/87 gP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, *********************************************************************************** FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 10143, TOH W/CLEANOUT BIT COSTS: DAILY WELL $15442, CUM WELL $69556 CHRON TIME DISTRIBUTION (HRS): 9.50 - PU, P/U X RUBBER 5" DP 2.50 - OTHER, MILL OVER 9-5/8" PKR 4.50 - TRIP, OUT X L/D MILL X PKR 1.50 - TRIP, IN W/8-1/2" BIT ASSY 0.50 - RSER, gREASE X SVC Rig 1. 50 - TRIP, IN - TAg ~ 8400 FT. 1.00 - OTHER, CLEAN OUT TO 8495 FT. CSQ START TO gET TIGHT 1.00 - CIRC, REV ~ 84~5 FT. 2.00 - TRIP, OUT X STRAP PIPE 06/04/87 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS. TD 10693 FT, PBTD I0~43, TRIP iN W/8-1/2" BIT ASSY COSTS- DAILY WELL $24305, CUM WELL $93861 CHRON TIME DISTRIBUTION (HRS): 2.00 - TRIP, OUT W/8-1/2" BIT 7.00 - RBXS, TO 8402-TIgHT-REV CIRC-TOH X L/D BIT X SCRAPER 1.00 - OTHER, TEST 9-5/8" CSg 3000 PSI. LOST 400 PSI IN 5 MIN CBL {8900 FT TO 7900 FT.} IN W/CMT DIVERTER 5. 50 - LOg, 3. O0 - TRIP, O. 50 - CIRC 1. 50 - CMT, BALANCE PLUG ~ 8490 FT. HELD SAFETY MEETINg; PRESS TEST ~000 PSI; OK. PMP 20 BBL FW-BATCH MIX CMT; 20 BBL SLURRY ~ 15.6 PP~ W/.2% CFR-2; 5% HALAD 344; 1% LWL {W/FRESH WATER} PMP CMT- PMP 7 BBLS FW- DISPL W/136 BBLS FIW TO BALANCE-PULL 4 STDS SLOW 1.00 - CIRC, REV- NO CMT BACK 2.00 - TRIP, OUT X L/D CMT DIVERTER 0.50 - OTHER, M/U 8-1/2" BIT ASSY ~ENVER REQIO~ ,4. ANCHORAQE DISTRIC '~ 08/11/87 ~ PAGE 4 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 9B634~-01-7, API ~07332005~00, AUTH TD ~0300, AUTH COST AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 10143, CASED HOLE RFT-CHANQE TOOL COSTS: DAILY WELL $30271, CUM WELL $124132 CHRON TIME DISTRIBUTION (HRS): IN W/8-1/2" BIT ASSY CUT X SLIP DRLG LINE INTO 8005 FT. 1. O0 - TRIP, 1. O0 - RSER, 2. O0 - TRIP, 4. 50 - WOC O. 50 - TRIP, 1. O0 - CIRC, 3. 50 - TRIP, lO. 50 - LOG, IN-TAG CMT ~ 8226 FT. REV-TEST CSQ 3000 PSI-OK OUT/ L/D BlT X 18 EXTRA JTS rI~ DN PITCHER NIPPLE- R/U SCHLUMBERQER FLANQE ON ANNULAR PREVENTER SOS-EGUIP MALFUNC FOUND BAD HEAD-PRESS TEST 3000 PSI-OK-RUN CASED HOLE "REPEAT FORMATION TESTER" TO 8090 FT. <COLLAR> FIRST SHOT 8088 FT. HYDRO PRESS 3385 PSI <TEMP CORR PRESS 3360 PSI} TEMP 137 ~ 8100 FT. APPEARED PACK OFF WAS LEAKING SET TOOL ~ 8072 FT~ HYDRO PRESS 3375 PSI {TEMP CORR 3350 PSI} PACKOFF IS LEAKING- SET TOOL ~ 8063 FT HYDRO PRESS 3391 PSI {TEMP CORR 3346 PSI} PACKOFF- LEAKING - POOH TO CHANQE TOOL 06/06/87 **4 ~P 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 98&J4~-01-7, AP1 507S32005500, AUTH TD !0300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS' TD 10693 FT, PBTD 8226, CUTTINQ SECTION ~-5/8" CSG COSTS: DAILY WELL $13377~ CUM WELL $137509 CHRON TIME DISTRIBUTION (HRS): 4.00 - LOQ, ATTEMPT TO RUN ANOTHER CH-RFT W/SOS-TOOL FAILURE-R/D SOS 1.00 - OTHER, INSTALL BELL NIPPLE X FLOW LINE 3.00 - TRIP, IN W/8-1/2" BIT ASSY-TAG CMT 8226 FT 2.50 - CIRC, DISPL W/SECTION CUT MUD 4.00 - TRIP, OUT <WET} 2.00 - OTHER, M/U SECTION CUTTING ASSY 1.50 - TRIP, IN W/CUTTINQ ASSY 0.50 - RSER 1.50 - TRIP, INTO 8020 FT. 2.00 - OTHER, START CUTTINg SECTION NEVER SAW COLLAR ~ 8006 FT. 0.50 - OTHER, OBSERVE WELL-OK. 1.50 - OTHER, CUTTINQ SECTION 8020-22 DENVER REQI[ ~ ANCHORAGE D I STP I ~ 08/11/87 ~ PAgE .5 06/07/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 8226, TOH FOR SECTION MILL #2 COSTS: DAILY MUD $4123, CUM MUD $4t23, DAILY WELL $22736, CUM WELL $160245 CHRON TIME DISTRIBUTION <HRS): 9.00 - OTHER, CUTTING SECTION {8021-48} O. 50 - C IRC, 1. 50 - CIRC, 3. DO - TriP, 2. O0 - TRIP, I. O0 - RRIG, O. 50 - TRIP, O. 50 - RSER 1.00 - TRIP, O. 50 - RMG, 3. O0 - CIRC, 1. O0 - TRiP~ X WORK PIPE TIGHT MILL TORSUING UP-CIRC BOTTOMS UP OUT X L/D MILL ASSY IN W/8-1/2" BIT ASSY REPAIR FLOWLINE IN IN TO 8010 FT. 8010 FT - 8075 FT. COND MUD-WT UP 8.7 PPG OUT FOR SECTION MILL 06/08/87 GP 18742_ i3RD~ gRANITE POINT, PAREER 150, AMOCO PRODUCTION, FLhtC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. O. 62_50 OPERATIONS: TD 10693 FT, PBTD 8226, CUTTINg 9-5/8" SECTION COSTS: CUM MUD $4123, DAILY WELL $18881, CUM WELL $179126 CHRON TIME DISTRIBUTION (HRS): 1. 50 - TRIP, OUT FOR SECTION MILL 1. O0 - OTHER, M/U C ITTING ASSY-WELD STRAPS 3. O0 - TRIP, INTO 8048 FT. 8. O0 - OTHER, CUTTINg SECTION; CUT F/8048 TO ? TOOL SLIDE TO 8074 - THINW~ PARTIAL CUT 1. 50 - C IRC, CLEAN-WATCH FOR FLOW- OK. 3. O0 - TRIP, OUT FOR NEW MILL O. 50 - RSER 1. O0 - OTHER, M/U NEW CUTTING ASSY 1. O0 - TRIP, IN O. 50 - RSER, SLIP DRLG LINE RESET CROWN-O-MATIC 1. O0 - TRIP, IN 2. O0 - OTHER, RECUT F/8053-8065; CUTTINGS BALLED UP UNDER MILL 06/09/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, "~ENVER REgIO;~--"~ ANCHORAQE DISTRIC ~ 08/11/87 ~ PAQE 6 FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 8226, CIRC ~ 8220 FT. COSTS: DAILY MUD $3086, CUM MUD $7209, DAILY WELL $25350, CUM WELL $204476 CHRON TIME DISTRIBUTION (HRS): 3.00 - OTHER, CUT SECTION 8065 FT - 8081 FT. 1. 50 - ClRC 3. 50 - TRIP, ~ 50 - tr IP, 1. 50 - RMg, I. 50 - C IRC, O. 50 - TRIP, O. 50 - RMQ, I. O0 - CIRC, 2. 50 - TR O. 50 - RSER O. 50 - TRIP. ~. 50 - TRIP~ O. 50 - CIRC, O. 50 - CIRC, 1. 50 - TRIP, OUT X L/D MILL ASSY IN W/BIT ASSY WASH X REAM 8020 FT. - 8224 FT. CLEAN OUT TO 8020 FT. WASH X REAM 8020 FT. - 8089 FT. BTMS UP- WELL STABLE OUT OUT X L/D BHA IN W/CMT DIVERTER X WASH 8021 FT. - 8081 FT. BTMS UP ~ 8081 FT. - CLEAN. IN 8224 FT - CIRC ~ 8220 FT. 06/10/87 18742 13RD, QRANtTE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 106~3 FT, PBTD 8091, TOH W/RR 2 COSTS: DAILY MUD $4301, CUM MUD $11510, DAILY WELL $40454, CUM WELL $244930 REMARKS: C IRC SETSIDE TRACE PLUQ ~ 8~08 FT. ; PUMP 28 BBL WTR; 31BBL OF 16.5 PPQ CMT {167 SX> DISPLACE W/lO BBL WTR X 122 BBL MUD; HELD 250 PSI BACKPRESSURE DURINQ DISPLACEMENT {NOTE LAST RETURNS W/750 PSI}; BALANCE PLUQ PULL 8 STDS; REVERSE OUT 2~ BBL CONTAMINATED MUD TOH TEST BOP X HAD TROUBLE QETTINQ THE TEST PLUg TO SEAT. LOST 3 HRS; PURR 2 X TIH W/RR 2 TAQ CMT TOP ~ 8038. DRLQ 8038-48 IN 4 MIN W/15000 WOB X 75 RPM. DRLQ TO 8091 FT. CIRC TOH TAQ CMT DIVERTER. CHRON TIME DISTRIBUTION (HRS): 1. O0 - CIRC, ~ 8220 FT. 1.50 - CMT, SET SIDETRACK PLU~ 167 SX 0.50 - TRIP, PULL 8 STDS 1.00 - CIRC, REVERSE OUT 2.00 - TOH 8.50 - TSTBOP, TO 3000 PSI 2.50 - TIH, W/RR2 TAQ CMT ~ 8091 FT. 1.00 - CIRC, e 8038 FT. 1.00 - DRL~, CMT TO 8091 FT. 2.00 - CIRC RECEIVED OL.i 0 '!bbl Oil & Gas Cons. Commiss[or~ ~chorage ~ENvER REQIOf ~ ANCHORAQE DISTRIC--"~ 08/11/87 ~ PAQE 7 2. 50 - TOH O. 50 - R SERVICE 06/t 1/87 ~ 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 8026, TOH COSTS: DAILY MUD $5233, CUM MUD $16743, DALLY WELL $27179, CUM WELL $272109 REMARKS: TIH W/DIVERTER TOOL CIRC ~ 8086 FT. MIX X PUMP 125 SX Q 1% HR7 16.5 PPD. PUMP 28 BBL WTR; 23 BBL CMT; DISPLACE W/ i0 BBL WTR X BALANCED PLUQ W/122.5 BBL MUD W/QOOD RETURNS. PULL 8 STDS X REVERSE OUT W/FULL RETURNS; DUMP 10 BBL MUD. TOH PU DC X TIH W/BIT 2 CIRC TRIP IN X TAD CMT. DRLQ CMT 7906-8026 FT. ROP FROM 8000 - 8020 FT. WAS 1MPF 8020-26. ROP WAS 1/2 MPF CIRC BOTTOMS UP. DISPLACE MUD TO DUAL POLYMER SYSTEM TOH X L/D EXCESS PIPE. CHRON TIME DISTRIBUTION (HRS): 2. O0 - TIH, 1. 75 - CIRC, 1. 50 - CMT, O. 50 - TOH, 1. 75 - C IRC, 2. O0 - TOH 2. O0 - WOC, 2. 5O - TIH, 3. O0 - C IRC, O. 50 - TIH, 2. O0 - DRLQ, 3. 50 - CIRC 1. O0 - TOH W/DIVERTER TOOL ~ 8086 FT. MIX X PUMP 125 SX PLUQ PULL 8 STDS REVERSE OUT 60 SPM ~ 250 PSI CUT DRL~ X RiQ REPAIR W/BlT ~2 ~ 7447 TAQ CMT ~ 7906 FT. CMT 7906 - 8026 FT. 06/12/87 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 8083, ORLQ SIDETRACK COSTS: DAILY MUD $5215, CUM MUD $21958, DAILY WELL $23154, CUM WELL $295263 REMARKS: TOH X LAY DOWN EXCESS DRILL PIPE PU SIDE TRACK ASSY; TIH W/RR2 ORIENT TO 90 - 105; LEFT X ATTEMPT TO SIDETRACK PRESENTLY DRLQ OLD CMT; HOLE ANQLE 17. 1. CHRON TIME DISTRIBUTION (HRS>~ 4.00 - TOH0 L/D EXCESS DRILL PIPE 4.50 - COBHA, PU MM 2 DEQREE BS X MWD 2.50 - TIH, TO 8026 FT. DENVER ANCHORAGE DISTRI( *** 08/11/87 *.*~ PAgE 8 13.00 - DRLQ 06/13/87 gP 18742 i3RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 8183, DRLQ COSTS: DAILY MUD $1432, CUM MUD $23390, DALLY WELL $22072, CUM WELL $317335 REMARKS: DRLg TO 8100 FT ; SURVEY; PULL ONE STD~ LOT TO 14.8 PPg E~U; NO LEAK-OFF; RUN IN STD~ DRLQ 8100-8113 FT. TOH; PU 1.5 DEGREE BS~ TIH W/BIT 3~ DRLg 8113-83 FT. CHRON TIME DISTRIBUTION (HRS>: 1. 50 - DRLQ, 2. O0 - LOT, 1. 50 - DRLg, 5. O0 - TOH, 4. O0 - TIH, 1. 50 - CIRC, 8. 50 - DRLg, TO 8100 FT. AND SURVEY 14.8 PPg EQU. TO 8113 FT. CO BENT SUB TO 1.5 DEGREE W/BIT 3 INITIATE HIgH SIDE READ OUT 8113-83 FT. 06/14/87 *~ 18742 !3RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS~ TD 10693 FT, PBTD 8339, DRLQ COSTS~ DALLY MUD $2339, CUM MUD $25729, DALLY WELL $1~97~ CUM WELL $337314 REMARKS: DRLQ TO 8201; SURVEY; DRLQ TO 8231FT.;TOH; NO TIGHT SPOTS; COBHA LAY DOWN MM X PU 3 STAB; TIH W/BIT 4; REAM 8026-8231FT; WORK STUCK PIPE ~ 8108 FT. FREE; DRLQ NO TIGHT CONN CHRON TIME DISTRIBUTION (HRS)~ 2. 50 - DRLO, O. 50 - C IRC, 5. O0 - DRLO, 3. 50 - TOH, 1. O0 - COBHA 3. O0 - TIH, O. 50 - SLIP, 2. 50 - REAM, 5. 50 - DRLQ, TO 8201 FT. X SURVEY TO 8231 FT X SURVEY LAY DOWN 11 JTS DP TO 7960 FT. DRLQ LINE 8026-8231 FT. TO 8339 FT. *** 06/15/87 *** QP 18742 13RD, gRANITE POINT, PARKER 150~ AMOCO PRODUCTION, ~ENVER REQ IC~"*** ANCHORAQE D ISTR I~ **~ 08/ll/87 *~ PAGE FLAC 98634g-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10693 FT, PBTD 8625, DRLO COSTS: DAILY MUD $2583, CUM MUD $28312, DAILY WELL $32908, CUM WELL $370222 REMARKS: DRLO TO 8425 FT; SURVEY TOH; PU SHORT MONEL X TIH W/ BIT #5~ DRLQ TO 8505 FT. ~ SURVEY; HAD MAGNETIC INTERFERENCE¢ PULL UP TO 8435 FT. X SURVEY~ DRLg AHEAD; NO TIGHT CONN; CHECK FOR FLOW ON EACH CONN CHRON TIME DISTRIBUTION (HRS>: 6.50 - DRLg, TO 8425 FT. 0.50 - CIRC, X SURVEY 3.00 - TOH, NO TIOHT SPOTS 0.50 - COBHA, L/D 30 FT. MONEL AND PU SHORT MONEL 3.50 - TIH, NO BRIDGES 6 FT FILL 4.50 - DRLQ, TO 8505 FT. 1.50 - SURVEY, e 8465 FT. ~ 8465 12.54 DEGREES N29E BIT DEPTH 8505 FT. 3.00 - DRLG *** 06/16/87 *** gP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, ****************************************************************************** FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0~6250 OPERATIONS: TD 10693 FT, PBTD 8943~ SURVEY MWD HAS FAILED COSTS: DAILY MUD $1815, CUM MUD $30127, DAILY WELL $23525, CUM WELL $393747 REMARKS~ DRLO TO 8723 FT~;BACK REAM TIGHT SPOTS 8660 TO 8560 FT. TRIP TO 8000 FT.~ FREE~ TRIP IN X REAM 8550 TO TD W/ LARGE VOLUME COAL OVER THE SHAKER~ DRLQ TO 8911 FT.; PUMP High VIS SWEEP X TRIP TO 8000 FT; NO T!~HT SPOT; DRLQ TO 8943 FT. CHRON TIME DISTRIBUTION (HRS)~ 4~00 - DRLQ, T08723 FT~ TIGHT ~ 8660 4.50 - TRIP, TO 8000 FT. WORK TIGHT HOLE 1.00 - DRLG, TO 8736 FT. 0.50 - RR, REPLACE STAND PIPE VALVE 9.50 - DRLQ, TO 8911 WORK TIGHT SPOT 8840-50 FT. 1.00 - CIRC, PUMP VIS SWEEP 1.00 - TRIP, TO 8000 FT.; NO TIGHT SPOT 2.00 - DRLG, TO 8943 FT. 0.50 - SURVEY, MWD TOOL HAS FAILED 06/17/87 *** 18742 13RD, ORANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 DENVER RE~IO ~ ANCHORAGE DISTRI( '~ 08/11/87 ~4s PAGE 10 OPERATIONS: TD 9212 FT, TRIP FOR BIT #5 COSTS: DAILY MUD $4315, CUM MUD $34442, DAILY WELL $20423, CUM WELL $414170 REMARKS: SURVEY DRLG TO 9070 FT.; HIGH VIS SWEEP; TRIP TO 8000 FT. W/TIOHT HOLE ~ 9015 FT. TOH REAM 9008-9070 FT; DRLO TO 9102 FT; SURVEY DRLQ TO 9212; PUMP HIGH VIS SWEEP TOH BACK REAM 90t5-9005 FT. TOH; 1ST X 2ND STAB 1/2" U G. MIKE MINDER W/AO~CC GAVE KURT UNGER PERMISSION {9:30AM 06-16-87} TO TEST BOP WHEN BIT #5 IS PULLED CHRON TIME DISTRIBUTION (HRS): 0.50 - SURVEY, MWD HAS FAILED 7.00 - DRLC, TO 9070 FT. 0.50 - CIRC, PUMP HI VIS PILL 1.00 - TRIP, TO 8000 FT. W/TIGHT HOLE e 9015 0.50 - OTHER, PLATFORM ABANDONMENT DRILL 0.50 - TRIP, IN 0.50 - REAM, 9000 - 9070 FT. 4 FT. FILL 1.00 - DRLG, TO 9102 FT. 0.50 - SURVEY, W/MWD 6.50 - DRLQ, TO 9212 FT. 5.50 - TRIP, BACK REAM 9015-9005 FT. 06/18/87 OP-18742 13RD, GRANITE POINT, PAR~ER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 50733~005500, AUTH TD 10300, AUTH COST $153~000, AMOCO W.i. 0.6250 OPERATIONS: TD 9352 FT, DRLG COSTS: DAILY MUD $2304, CUM MUD $36746, DAILY WELL $26659, CUM WELL $440829 REMARKS: TOH; RIG REPAIR~ TEST BOP 3500/500 X ANNULAR TO 2500 PSI; CO MWD L.D MONEL DC X REPLACE 2 - STAB; TIH W/BIT 6; TAG BRIDQE e 8950 FT.; REAM 8935 TO TD; SURVEY MWD ~ 8903 FT.; 9025; 9153 LARGE VOLUME OF COAL OVER SHARER WHILE REAMINQ. CHRON TIME DISTRIBUTION (HRS): 0.50 - TOH, W/BIT 5 2.00 - RR, CO SWIVEL PACKINQ 7.00 - TSTBOP, TO 3500 PSI/500 PSI 1.50 - COBHA, L/D MONEL X C 0 STAB 3.00 - TIH, HIT BRIDGE ~ 8950 FT. 3.00 - REAM, 8935 FT. TO TD 7.00 - DRLg, TO 9352 FT. 06/19/87 QP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. O. 6250 OPERATIONS: TD 9676 FT, DRLQ, 324 gncflorage DENVER REQIQ ~** ANCHORAGE DISTR. I¢ *** 08/11/87 *** PAgE 11 COSTS: DAILY MUD $630, CUM MUD $37376, DAILY WELL $21760, CUM WELL $462589 REMARKS: DRL~ TO 9469 FT. ; PUMP HI VIS - SWEEP; TRIP TO 8520 FT. BACK REAM 9350-35 FT. X 9315-9285 FT. ; DRAG TO 9250 FT. TRIP IN; REAM 9250 TO 9469 FT. 14 FT. FILL; DRLQ TO 9676 FT. CHRON TIME DISTRIBUTION (HRS>: 8. O0 - DRLG, O. 50 - C IRC, 1.00 - REAM, 2.00 - TRIP, 12.50 - DRLQ, TO 9469 PUMP HI VIS SWEEP; LARGE VOLUME OF COAL X SAND UP W/SWEEP 9250 - TD 14 FT. FILL TO 8520 TO 9676 FT. *** 06/20/87 *** GP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, ****************************************************************************** FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 9984 FT, DRLQ COSTS: DAILY MUD $3135~ CUM MUD $40511, DAILY WELL $1~165, CUM WELL $48175~ REMARKS~ DRLg TO 9752 FT.; TRIP TO 8000 FT. ~ TIGHT AT 8450; CDL; TIH; BRID~E ~ 9435 FT~ REAM ~410-~570 FT. X 9660 TO TD; DRLG TO ~984 FT. CHRON TIME DISTRIBUTION <HRS>~ 4.00 - DRLG, TO 9752 FT. 1.00 - TRIP, TO 8000 FT. 1.00 - CUT, DRLG LINE 0.50 - TRIP, IN X TAg BRIDQE 9435 FT. 17.00 - DRLG 06/21/87 *** 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 98634~-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6~50 OPERATIONS: TD 10088 FT, DRLG COSTS: DAILY MUD $2V28, CUM MUD $43439, DALLY WELL $23888, CUM WELL $505642 REMARKS: DRLQ TO 10009 FT; SURVEY; TOH; TIGHT ~ 9~77 X 9233 FT; L/D 33 JTS 5" 19.5Xg5 DP; ALL 3 STABS WERE 1/16" U g; DID NOT CO; TIH W/BIT 7; PU 34 JTS 5" 25.6XV5; REAM 9230-9330; TRIP IN SINGLES; TAG BRIDGE 9650 FT.; REAM 9620 TO TD; LARGE VOLUME OF FINE CUTTINGS OVER SHARER WHILE REAMINg; DRLQ TO 10088 FT.; REAM COAL SECTION · 10048-10059 FT. CHRON TIME DISTRIBUTION (HRS): 2.00 - DRLQ, TO 10009 FT. X SURVEY 6.00 - TOH, DRAg · ~277 X 9233 FT. 3.00 - TIH, W/BIT 7 ~ENvER REgIO/-"~ ANCHORAGE DISTRI¢~-"~ 08/11/87 ~ PAgE 4.00 - REAM, 0.50 - CIRC, 8.50 - DRLG, 9230-9330 FT X 9620 TO TD X CHECK MWD TO 10088 FT. GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, CIRC COSTS: DAILY MUD $3476, CUM MUD $46915, DAILY WELL $19651, CUM WELL $525293 REMARKS: DRLg TO 10126 FT; BACK REAM TO 10055~ REAM TO TD SURVEYi DRLg TO i0i59 FT; SHORT TIRP TO 9090 FT; REAM 9~25 TO TD; DRLQ TO 10302; REAM OUT COAL SECTION ~ 10180-195 X 10244 FT; CIRC; HI VIS SWEEP CHRON TIME DISTRIBUTION (HRS): 3.50 - DRLG, 1.00 - REAM, 4.00 - DRLG, 1.00 - TRIP, 1.00 - REAM, 13.00 - DRLG, 0.50 - CIRC, TO 10126 FT. TIGHT CONN 10055 TO TD X SURVEY TO 10159 FT; WORK TIGHT CONN TO 9090 W/DRAg ~ 9270 FT. 9925 TO TD 10302 FT. HI VIS SWEEP 06/23/87 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAg 986349-01-7, AP! 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, LO~ ~2 SDT SONIC COSTS: DAILY MUD $1610, CUM MUD $48525, DAILY WELL $17385, CUM WELL $542678 REMARKS: CIRC X SURVEY; TRIP TO 10059 FT; REAM TO BOTTOM; CIRC; TRIP TO SHOE~ TIGHT ~ 9230; TIH REAM 9220-60 X IO090-TD CIRC; TOH; NO TIGHT SPOTS; LOOK FOR WASHOUT; L/D BHA; DID NOT FIND WO; STRAP OUT 10306 FT; NO CORRECTION DUE TO HIGH WIND. DAMAGED DRILL PIPE RUBBERS INDICATE CSG DAMAGE BETWEEN 2000 X 2300 FT. CHRON TIME DISTRIBUTION (HRS,: 1. 50 - CIRC, O. 50 - TRIP, 1. O0 - REAM, 2. O0 - CIRC, 1. O0 - TRIP, 1. O0 - TRIP, 1. 50 - REAM, 1. 50 - CIRC, 4. 50 - TOH, O. 50 - L/D, X SURVEY TO 10059 FT TIGHT ~ 10100 FT. 10059 FT TO TD HI VIS SWEEP TO 8000 FT. TIGHT ~ 9230 FT. IN X REAM 9220-9260 FT. 10090 FT TO TD LOST 350 PSI DROP RABBIT STRAPOUT BHA DENVE~ REQI[ ~ ANCHORAGE DISTRI 08/11/87 *~ PAGE 13 8.00 - LOQ, LOG 1 PHASAR I MD TO 10063 FT. LOG 2 SDT 8560 FT 06/24/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TO 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, TOH FOR LOQS COSTS: DAILY MUD $884, CUM MUD $49409, DAILY WELL $22498, CUM WELL $565176 REMARKS: LOQQINQ TOOL STOPPED ~ 10060 FT. <BRIDQE}; REAMED TO BTM HOLE SLOU~HINQ - RAISED MUT WT - SHORT TRIP OK. TRIP OUT FOR LOQS. CHRON TIME DISTRIBUTION (HRS)~ 3. 50 - LOQ, 1. O0 - TRIP, O. 50 - RSER, 3. 50 - TRIP, 5. O0 - RMQ, 6. O0 - CIRC, O. 50 - TRIP, O. 50 - C IRC, 3. 50 - TRIP, SDT-SONIC F/10060 FT. IN W/8-1t2" BIT ASSY SLIP DRLQ LINE IN - PRESS TEST EVERY 20 STDS F/10045 FT. - 10302 FT. WT UP ~.8 PPQ - HI VIS SWEEP SHORT TRIP 5 STANDS PUMP SLUG OUT FOR LOQS 06125/87 QP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC ~8634~-01-7, APl 507332005500, AUTH TD ~0300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, TOH TO RUN 7" LINER COSTS: DAILY MUD $3478, CUM MUD $52887, DAILY WELL $16480, CUM WELL $581656 REMARKS: HOLE WAS IN QOOD SHAPE FOR LOQS - AFTER QEL SWEEP HAD SMOOTH TRIP THROUQH PREVIOUSLY TROUgLESOME SPOTS CHRON TIME DISTRIBUTION (HRS): 13.00 - LOQ, RAN LDTj CNL X QR TOOL FAILED; RAN NEW TOOL 5. O0 - TRIP, 3. O0 - CIRC, 2. 50 - CIRC, O. 50 - TRIP, 10302 FT. - 8000 FT. -OK. RAN FMS- DIPMETER OK. IN W/8-1/2" BIT ASSY-SLM- 8 FT. FILL ON BTM RAISE MUD WT F/9.8 TO 10 PPQ HI VIS SWEEP FOR 7" LINER 06/26/87 GP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC ~8634~-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS~ TD 1030~ FT, REV CIRC 8 63~4 FT. REOIO~' ~ ANCHORAQE DISTRIC~S~ 08/11/87 ~ PAQE 14 COSTS: DAILY MUD $600, CUM MUD $53487, DAILY WELL $149586, CUM WELL $731242 CHRON TIME DISTRIBUTION (HRS): 3.50 - TRIP, OUT FOR 7" CSG 10.00 - RC, RUN 2577 FT. 7" LINER TO 8000 FT. 1. O0 - CIRC, ~ 8000 FT. O. 50 - TRIP, IN TO 10300 FT. 4. 50 - CIRC, X WORKPIPE 20 FT. 3.00 - CMT, LINER WHILE RECIPROCATING W/50 BBL 14 PPG MUD; 30 BBLS FRESH WATERi 20 BBLS MUD FLUSH; 147 BBLS {700 SX} CLASS "G"~ 2% CFR-2~ 5% HALAD 344i 1% LWL}; 70 BBLS FRESH WATER; 149 BBLS DISPL. MUD; SET LINER HANGER @ 77i9 FT. 06/27/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC ~86349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, TIH W/~-5/8" CSQ SCRAPER COSTS: DAILY MUD $4776, CUM MUD $58263, DAILY WELL $56857, CUM WELL $788099 CHRON TIME DISTRIBUTION (HRS>: 2.50 - TRIP, OUT × L/D BAKER TOOLS 3.50 - RRIG, REPLACE KICKBACK PLATES ON DRAWBACK DRUM 4.50 - TRIP, IN X L/D 18 STDS DP {5"} 3.00 - TRIP, IN W/8-1/2" BIT-TAG CMT 7609 FT. 2.50 - DRLCMT, F/7609 TO 7725 - TAG LINER 2. 50 - C IRC, COND CMT~ CUT MUD 3. O0 - TRIP, OUT 2. 50 - TRIP, IN W/9-5/8" CSG SCRAPER CHANQE OUT BAD DP RUBBERS 06128/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, DRL CMT W/5-7/8" BIT COSTS: DAILY MUD $1454, CUM MUD $59717, DAILY WELL $14354, CUM WELL $802453 CHRON TIME DISTRIBUTION (HRS): 5.00 - RBXS, 9-5/8" TO 7725 FT; CIRC; TOH 11.00 - TSTCSG, RAN 9-5/8" RTTS TO 7715 FT; FILL 47 STANDS W/MUD - OPEN AUXILIARY VALVE; SLIQHT BLOW; STOPPED IN 12 MIN; FILL PIPE W/MUD; PRESS AGAINST LAP 3000 PSI FOR 30 MIN; DROPPED 273 PSI; TEST CSQ ABOVE RTTS 3000 PSI FOR 30 MIN - 0½. 0.50 - DRLCMT, 5 FT CMT X 5 FT STRING RS 1.00 - TRIP, IN TAQ CMT @ 10148 FT. 1.00 - DRLCMT, CMT FIRM 8 10214 FT. DENVER RE(~II'~-~ ~ ANCHORA(~E DISTRI ~ 08/11/87 06/29/87 gP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, PBTD 10214, LOg W/DRESSER ATLAS {CBL} COSTS: DAILY MUD $896, CUM MUD $60613, DAILY WELL $21492, CUM WELL $823945 REMARKS: CHARTER CHOPPER EM ANCHORAGE {ERA} TO BRINg DRESSER ATLAS TECHNICIAN OUT CHRON TIME DISTRIBUTION (HRS): 2.00 - CIRC, X COND MUD 4.00 - TRIP, OUT 3.00 - RBXS, TO 10214 FT. 1.50 - CIRC, CLEAN {RECIPROCATE} 0.50 - TSTCSQ, 3000 PSI - OK 3. O0 - CIRC, X DISPL MUD W/FILTERED INLET WATER 3. 50- TRIP, OUT X L/D SCRAPER 6. 50 - LOg, R/D PITCHER NIPPLE N/U LUBRICATOR - FLY TECHNICIAN X PARTS TO PLAT X REPAIR LOggINg UNIT- 2 HRS.- P/U TOOLS; PRESS 1000 PSI CALIB TOOL {CBL} 2-1/2 HRS LOg CBL-DVL-QR 06/30/87 gP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAG 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W. Io 0.6250 OPERATIONS: TD 10302 FT~ PBTD i0214, TIH W/QEO-VANN PERF gUNS COSTS: CUM MUD $60613, DAILY WELL $22903, CUM WELL $846848 CHRON TIME DISTRIBUTION (HRS): 7.00 - LOg, CBL-VDL-QR 10214 FT - 7725 FT. 1.00 - OTHER~ R/D LUBRICATOR; R/U PITCHER NIPPLE 8.00 - DS, gYRO 10182 FT. - SURF 0.50 - OTHER, CHANGE TO 3-1/2" RAMS LOWER gATE 4.50 - PERF, P/U TAg CONV. gUNS X PKR 3.00 - TRIP, IN W/gUNS - FILL 1ST 48 STANDS DP W/WATER 07/01/87 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAG 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6~50 OPERATIONS: TD 10302 FT, PBTD 10214~ PR TST PERFS COSTS~ CUM MUD $60613, DAILY WELL $40577, CUM WELL $887425 CHRON TIME DISTRIBUTION (HRS>: DENVER REQIO~ ~ ANCHORAGE DISTRIC. ~e 08/11/87 ~ PAGE 2.50 - TRIP, RIH W/DP FILL 48 STDS 3.00 - LOG, USE ELECTRIC WIRELINE CORROLATE PERF GUNS 1.00 - OTHER, SET PKR ~ 8478 FT. 1. OO - PERF, FIRE GUNS; MONITOR WELL - NO FLOW 1. OO - CIRC, CIRC BTMS UP - NO OIL 7.00 - TRIP, POH X L/D PERF GUNS 5.00 - TRIP, P/U PKR; RIH 3.50 - TEST, PERFS 9645 FT. - 9575 FT. 16 07/02/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 307332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, PBTD 10214, RIH W/DSS TBG COSTS: CUM MUD $60613, DAILY WELL $32282, CUM WELL $919707 CHRON TIME DISTRIBUTION (HRS)' 0.50 - OTHER, TST PKR NOT HOLDING 3.50 - TRIP, POH W/TST PKR 2.50 - OTHER, L/D X TARE APART - EVERYTHING WORKING 3.50 - TRIP, RIH W/TEST PKR 9.50 - TST, SET PKR 9362 ; SET e 9350; 9340; 9330; 9320; 9364; 9350; 9340; 9330; 9320~ 9310; 9300; 9290; 9280; 9248; 9238~ 9236; 917~; 9162; 9152~ 9142; 9132; 9100; 9098; 9078; 9068; 9058; 9032; 90~; 9010; 8638; 8628; 8618; 8610; 8605; 8571; 8561; 8550; THE TST PKR WAS A HALIBURTON PIN POINT INdECTION PKR TO TEST INdECTIVITY OF EACH ZONE. ENGINEER REPORT TO FOLLOW. 3~50 - TRIP, POH W/TEST PER 1.00 - TRIP, RIH W/PROD PER 2.50 - TRIP, P/U P~R~RIH BAKER MODEL F-1 4" BORE 0.50 - OTHER, SET PKR ~ 8300 FT. 4.00 - TRIP, POH CHANGE TOOLS 1.00 - OTHER, CUT DRLQ LINE 2.00 - TRIP, RIH W/TST TOOL; TST PKR 15 MtN ~ 2500 PSI 8.00 - TRIP, POH LD 5" AND 3" DP 2.00 - OTHER, CHG RAMS TO 3-1/2; PULL WEAR BUSHING - RIG UP SINGLE TONGS - M/U SEAL ASSY 1.00 - OTHER, P/U SEAL ASSY X RIG UP HYDRO-TST; TST TO 5900 3.00 - TRIP, RIH W/3-1/2 DSS~ HTC TUBING 07/03/87 18742 13RD, GRANITE POINt, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, PBTD 10214, NIPPLE UP TREE COSTS: CUM MUD $60613, DAILY WELL $157316, CUM WELL $1077023 DENVER REQI(i ~ ANCHORAGE DISTRI ~ 08/11/B7 ~ PAGE 17 CHRON TIME DISTRIBUTION (HRS>: 14.00 - TRIP, RIH W/3-1/2 DSS-HTC TUBING; HYDRO TST TO 5900; STING IN PKR TST 2500 PSI - OK. 1.00 - OTHER, SPACE OUT HANGER 2.00 - ClRC, CIRC WELL; PUT INHIBITED FW W/WA 840~ CAUSTIC PH-11~ OXYGEN SCAVENGER 1.00 - OTHER, LAND TUBING Q 8282.59 × KB 33 = 831559 5.00 - NDBOPS, NIPP DOWN BOPS 1.00 - NU, NIPPLE UP TREE 07/04/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT, PBTD 10214, OPERATIONS COMPLETE COSTS: CUM MUD $60613, DAILY WELL $12645, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 4.00 - NU, NU TREE~ TEST 5900 PSI 6.00 - OTHER, CLEAN DECK TO MOVE RIG; DISCONECT SERVICE LINES 4.00 - MO, SKID RIG TO STORE 4.00 - OTHER, ,CLEAN PITS; LEAVE DECK READY FOR 32 MOVE- READY E~UIPMENT FOR BOAT~ MOVE TO BAKER; RIG RELEASED · 000 HRS~ JULY 4 GP t8742 ~3RD, GRANITE POINT, PARKER ~50, A~OCO PRODUCTION, FLOC 986349-0~-7, APi 50733200~D00, AUTH TD ~0300, AUTH COST AMOCO W.I. 0.6250 OPERATIONS: TD 10302 ~T COSTS: CU~ MUD $60~13, CUM WELL CHRON T[~E DISTRIBUTION (HRS): 24.00 - OTHER, ~AITiN~ ON STEP RATE TEST 07/06/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC ~8634~-01-7, API 50733~005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: ~4.00 - OTHER, COMPLETE STEP RATE TEST ANCHORAGE DISTRI 08/11/87 *** PAGE 18 07/08/87 *** 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION° FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 24.00 - OTHER, STEP RATE TEST *~* 07/09/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7~ API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 2~.00 - OTHER~ STEP RATE TEST ~-*~ 07/10/87 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 16.00 - OTHER, STEP RATE TEST 8.00 - OTHER, INJECTING 355 BW AT 3478PSI. ANNULUS PRESS 1500PSI *** 07/11/87 *** 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 98634~-01-7, API 507322005500, AUTH TD 10300, AUTH COST $1522000, AMOCO W.I. 0.5250 OPERATIONSi TD 10302 FT COSTS~ CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 24~00 - OTHER, INdECTING 796 BW AT 3510PSIo ANNULUS PRESS 1500PSI DENVER REQIO;~~ ANCHORAQE DISTR IC.~:~ 08/11/87 ~ PAQE 19 07/12/87 QP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INdECTIN~ 849 BW AT 3580PSI. ANNULUS PRESS 1500PSI 07/13/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INdECTIN~ 859 BW AT 3500PSI. ANNULUS PRESS 1500PSI 07/14/87 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 4.00 - OTHER, SHUT -IN FOR LEG INSPECTION 20.00 - OTHER, INdECTINQ 536 BW AT 3530PSI ANNULUS PRESS 1500PSI 07/15/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS)~ D~NVER RE~I[?~ ANCHORAGE D ISTR ! 08/11/87 ~ PAGE 20 24.00 - OTHER, INUECTINg 214 BW AT 3400PSI ANNULUS PRESS 1650PSI 07/16/87 18742 13rD, grANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TO I0300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INUECTINQ~ PRESSURE 3400PSI ANNULUS PRESS. 1620PSI 07/17/87 gP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, ****************************************************************************** FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 10.00 - OTHER, STEP RATE TEST AND INSTALL TURBINE METER 14.00 - OTHER, INJECTIN~ 626 BW AT 3500PSI; ANNULUS PRESS. 1580PSI 07/18/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD I0300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00- OTHER, SHUT IN W/O MATERIAL TO CHANGE METER SIZE 07/19/87 QP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH td 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 D~NVER REQI'/~ ~ ANCHORAQE DISTR] 08/11/87 ~ PA~E 21 CHRON TIME DISTRIBUTION (HRS)' 24.00 - OTHER, SHUT IN FOR METER CHANGE 07/20/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN FOR METER CHANGE 07/21/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN W/O MATERIAL FOR METER CHANGE 07/22/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION 24.00 - OTHER, SHUT IN WAITING ON METER MATERIAL 07/23/87 18742 13RD, GRANITE POINT, PARKER 1DO, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN W/O MATERIALS FOR METER CHANGE ENVER ANCHORAGE DISTRIC.~. *** 08/il/87 *** PAgE *** 07/24/87 *** 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $t532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN W/O MATERIALS FOR METER CHANGE 07/25/87 *** QP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN WAITINg FOR METER MATERIAL *** 07/26/87 *** QP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, ****************************************************************************************** FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN WAITING FOR METER MATERIAL *** 07/27/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC ~8&349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.&250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN W/O MATERIAL FOR METER CHANGE *** 07/28/87 *** GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, ANCHORAGE 08/11/87 ~ PAGE FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT IN W/O MATERIAL FOR METER CHANGE 07/29/87 QP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 18.00 - OTHER, INdECTING 548 BW AT 2400 PSI ANNULUS PRESS. 1400 PSI 07/30/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.t. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL *108~668 CHRON TIME DISTRIBUTION (HRS>: 24.00 - OTHER, INJECTING 281BW AT 4700 PSI ANNULUS PRESS. 1440 PSI 07/31/87 GP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC ~8&34~-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 24.00 - OTHER, INJECTING 419 BH AT 470 PSt ANNULUS PRESS. 1450 PSI 24.00 - OTHER, INdECTING 419 BW AT 470 PSI ANNULUS 1450 PSI 08/01/87 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, DENVER REQI{ ~ ANCHORAGE DISTRI 08/11/87 ~ PAgE 24 FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INJECTIN~ 469 BW AT 2150 PSI ANNULUS 1470 PSI 08/02/87 QP 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INJECTINQ 466 BW AT 2200 PSI 08/03/87 CP 18742 13RD, gRANITE POINT, PAR~ER 150, AMOCO PRODUCTION, FLAg 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS)' 24.00 - OTHER, INJECTINg 464 BW AT 2250 PSI ANNULUS 1500 PSI 08/04/87 18742 13RD, gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAg 98&349-01-7, API 507332005500, AUTH TD ~0300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INJECTINg 239 BW AT 700 PSI ANNULUS 1500 PSI 08/05/87 QP 18742 13RD, gRANITE POINT~ PARKER 150, AMOCO PRODUCTION, D~NVER RE~I~I ~ ANCHORAQE DISTRI 08/11/87 ~ PAQE FLAC 986349-01-7, AP1 50733~005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): ~4.00 - OTHER, INJECTINQ 132 BW AT 1108 PSI ANNULUS 1500 PSI 08/06/87 QP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, SHUT-IN; WATER FLOOD TURBINE REPAIRS 08/07/87 QP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, AP1 507332005500, AUTH TD 10300, AUTH COST $153~000, AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS>: 24.00 - OTHER, INdECTINQ 165 BW AT i448 PSI ANNULUS 2000 PSI 08/08/87 QP 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION~ FLAC 986349-01-7o AP1 507332005500° AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS~ TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS)i ~4~00 - OTHER, INdECTINQ 445 BW AT 1750 PSI ANNULUS 2000 PSI 08/09/87 18742 13RD, QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, API 507332005500, AUTH TD 10300, AUTH COST $1532000, I~NME2 REQ'~i~-~-~--~- ANCHORAQE DISTF T ~ 08/11/87 ~ PAQE AMOCO W.I. 0.6250 OPERATIONS: TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, INJECTINQ 380 BW AT 1750 PSI ANNULUS 2000 PSI 08/10/87 QP 18742 13RD, GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 986349-01-7, APl 507332005500, AUTH TD 10300, AUTH COST $1532000, AMOCO W.I. 0.6250 OPERATIONS~ TD 10302 FT COSTS: CUM MUD $60613, CUM WELL $1089668 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, IN~ECTINQ 466 BW AT 1758 PSI ANNULUS 2000 PSI ~ENVER REGIOh~ ~* ANCHORAGE DISTRIC'~'-~** 08/11/87 *** PAGE *** FINALLED JOB INFORMATION' GRANITE POINT, GP 18742, 13RD, RENAl O/S STATE, ALASKA OPERATOR' AMOCO PRODUCTION OPERATIONS COMPLETED DATE 07/04/87 TOTAL DEPTH 10700 FTt T.D. REACHED DATE 87/06/21f PLUG BACK TOTAL DEPTH 10214 FT CUMULATIVE JOB COST $1089668, CUMULATIVE MUD COST $60613 FOOTAGE DRILLED: RE-ENTRY NEW HOLE DRILLED 2281FT USELESS FOOTAGE 0 FT July 2, 1987 Mr. Kurt Unger AMOCO Production Company P. O. Box 779 Anchorage, Alaska 99510 Re: Our BOSS Gyroscopic Survey Job No.: AK-BO-70040 Well: 913RD Field: Granite Point Alaska Survey Date: June 29, 1987 Operator: T. McGuire Mr. Unger: Please find enclosed the "Original" and three (3) copies of our BOSS Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Western Area Manager NL SPERRY-SUN, INC. Enclosures NL Sl~erry-Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907)522-1737 Cons, Co SPERRY-,T.-;UN 14EL..L SL!RVEYIIxlG COMF'ANY AMOI-:O F'RODUCTION L. UMFANY ~1:3 RD _.HURAbE ALASKA .,i ............ . ........... ANI .... ' -' ;:::.;::ii:;.?:;??~i;::~:.'"": DATE OF,-'I.:,.IRVEY, ,.ILINE 'Z.".-Ty_. , .1 '-:/o7'-' COMPUTATInN DATE BOSS GYROE;COPI.C: SLIRV. EY 0 F' E R A T 'q -' _ ..Luu, LIRE VERTICAL ._EL. TInN F:ALCULATED ALONG P -'-' TR _IE .=,UB-.:,EA ..'..':' CE~I IR:~;E E:FH IRF;E DOG-LEG TOTAL MEA:--;URED VERT I CAL VERT I CAL I NF:L I NAT I ON D I RE~i..].!.-..:....~_.] ............................................................................................................................................................................................................................................................................................................. 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'. :..! .. ::~:::~:?~:::;~4~?~::~:~::~:~::~:~:;~:~:~:~::~(~¥~B~:~js:::~:~;~:~:~;~¥:~:~<:~:~*;~:::~:~:?::?~?~:~:::::~:::::~b~:~:~:~b~:: ~::.:~:~:~:b::~t~::~:::~%~:~:~:~?::~::::~:~:l:~b~b~.~:~:~:::~:::~:~::?~:%:::~::~:~:~:~:h..:~:~' ~: ::...-... .. ~ ..., · ......... .... .> +. ..>.. ,,...,.x,.,,x.+~......., .., :..../:.,x~:,,.,m~.~..,.~.,:. ~.:~:~..:.>..~ ~,~..~.....,, ....,.,>...-~,,.>,,.,.~.~-.-....~..~....-.~./ ...,.,.......,. .... ...-......... ........ .,... ......... x..,,....,....,...,....,...,..........-....,..........-.,....... .......... ..... :..',:: ~::. <.....::...:.':?: :~.:~:::::~}f~g~F~*~J~t;~:f~]~;~:~(~A~::;~~D~:~:~?::~::~::~;:~:~:::~,::~:~::~:~::~::~:~:~::~:~:::~::~:~:~:~:;:~:~:::~:~}~:~:~:~:::~::~::~::;~::~::~:::~::~::~:~::::::~::~::.~:::~:~:::~:~:~::~:::~:.~.~: :'.:.'::::~ ................. TRLIE ~,LIB-.:,EA TOTAL -- _ VERT I CAL VERT I C:AL RECTANGLILAR COClRD I NATES MD-TVD VERT I CAL DEF'TH DEF'TH NORTH/.SOLITH EAST/WEST D I FFERENCE CORRECT I ON ~'~ 10143 9605. O0 ': "o~nn: r.'~ ~?:~:::~ ~:~::A'~:::~:~:.~?~::::~J~,o'-~',-?~; ' .......................................... :,~:. W '' · ...... "-' · ~'" 101 ::: '? 9/-, 42 ~ '2 ':~ ~'-' ~ '"'-"-' ' ~ 'R':~ 48 ................................. :......: ....................................................... .......................... - ....... T H E '"' i~:'~'E'~:'i:i:'~'Y'~"~'~-~:~'~'~::'~'~i'i:i'~:-'i:i:~-~j~ .................................................................................................................................................................................................................................... THE NEAREST 20 FOOl' MD. ( FRC ....... · :::::::::: :::::::::::::::::::::: "~ ::::'::~ :::::~ ~ :::::':: :::-:. ==================================================================================================================== :::.:::.,. :::::'.::::, :: ::::.F'.:' :?.'::::.::::.:':.:: .: .-~: ~:~>:.:.:~:; ::<.::¥~,~ ~>: ~ .<; ? ~ :: ¥'.:.: ............ ., :.:':',::.,:,.~':~:~::~:,~:~ ..::~::,:.:~::'~%:.<,:.~.~::.:~.::,~.:: .: ........ , ~,::.<..:.:..., ;, .::.':'::., ...,.<. :..< .~ ..< >~,...: :...:.,. . ..~ ::: . :: '." ': ':: :'. ~';. ':':' · :'. :.:<,::::::!:~'?.::',~(:~:%?.::~.:': :.' ~:.L ':'~'~:?:::~'~! :':¥~)~ :':'~:::~:.Y".:':": >~:'.::;::::-~: .<-: .., ':. ~ <.:' .'.: :~:.'." :: ": ...... '... :.' :< · : ':::: :: :'.'".": .: '"' : ...... ...,. :,.. ::,' .': ":.'".~:~% :':;.~:~:;~}~:~:.~:::::~:~'.~::::::.;~<~:~:~:.~<~:~:~:::;~:~:~: ..~.:.<~: ..:':::~::.j: ..;:.~.':~...:,:::: . ..... . :.: .: .: :: :....'h.:.:...:::::" .: .: . , ..... . :. <'~::~!,~:~;~v'~:~,.:. ~,'. ~,, . .~:., . · .: :, .><. :,..:::.:~:.?:.:,.~..,.~.:~.:,:~.. :<?.':::.~::~?~:.:::::::::j%'.:.~ :' ", :: '~';:::~:".', "::9: :: ' ' '.' ':"." ' ". :".~'.: ... ..... SPERRY -SUN SCALE :- ! I-NCH TO 500.00 / 500.0 GRANITE POINT #13 RD RK-BO-?O040 RHOCO PRODUCTION COHPRNT JUNE 29. 1987 TRUE NORTH -25~0. oo -2oho. oo-lsbo. oo _lob~-o. oo .~¢.~ J --soo. oo · --! 000. O0 HORIZON. TflL PROJECTION -t500.00 SPERRY -,SUN 0.00 2000.00 $CRLE :- 1 INCH TO 2000.00 / 2000.0 GRRNITE POINT RHOCO RBOOUCTION COHRRNT ~1~ RO JUNE 29, 1987 RK-80-?O040 4000.00 6000.00 8000.00 10000.00~ 9642.52 10182 20~0.00 I 4000. O0 VFRT I CFIL PROJECT I Olxl W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 October 6, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' C. V. Chatterton, Chairman File' FEW-126-WF Gentlemen' Report of Sundry Well Operations Well Completion or Recompletion Report and Log Granite Point 18742 Well No's 13 and 13RD Platform Anna, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-404 Report of Sundry Well Operations and Form 10-407, Well Completion or Recompletion Report and Log informing you of work recently completed to abandon and redrill GP 18742 No. 13. Also attached is an abandonment diagram, directional survey, and daily reports concerning the work performed. Please direct any questions concerning this project to Kurt Unger in our Anchorage office at 562-2147 extension 211. Very truly yours, / . ,.:' /:" .< / / /:~ : - :. District Manager KWU/dds Attachments O08/kwu STATE OF ALASKA ""~ AL A OIL AND GAS CONSERVATION CO,... tlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging IX] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Amoco Production Company 105' KB, MSL Feet 3. Address 6. Unit or Property name Grani t.e~Pe~i nt 18742 // 13 8. !Approval number P.O. Box 100779: Anchorage, Alaska 99510 4. Location of well at surface Leg 4, Slot 5, Platform Anna 780' FNL, 708' FEL, Sec 12, TION, R12W, S.M. At top of productive interval8,3901 MD (7,854'TVD), 1,673' FNL 2,204' FWL, Sec. 12, TION, R12W, S.M. At effectivedepth 10,134' MD (9,560' TVD) - 1,644' FNL I[910'iFWL, Sec. 12~ T10N, R12W, S.M. . t ota depth 10,700 MD (10,125'1'¥D) - 1,631 INL, 1,994'R~ Sec 12, TION, R12W, $.M. 7-288 9. APl number 50-- 733-20055 10. Pool Middle Kenai Sands 11. Present well condition summary Total depth: measured 10,700 feet true vertical 10,125 feet Effective depth: measured 10,134 feet true vertical 9,560 feet Plugs (measured) Casing Collapse - 8,540' MD Casing Length Size Structural Conductor 627' 20" Surface 2,002' 13 3/8" Intermediate 8,964' 9 5/8" Production Liner 1,940' Perforation depth: measured true vertical (See Attached) Cemented Measured depth True Vertical depth 1,285 ;'sX:.: 627' 626' 1,600 sx 2,002' 1,976' 550 sx 8,964' 8,400' 200 sx 10,693' 10,118' Tubing (size, grade and measured depth) N/A Packers and SSSV (type and measured depth) N/A 12. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Abandoned GP 18742 #13 to drill GP 18742 #13RD Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run I;'] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /....¢~i~./.'~"~-...~~ Title District Manager Form 10-g'04 Rev. 12-1-85 Date 10/06;/87 Submit in Duplicate~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY DESCRI PT ION Copy YES sent to sender W. G. Smith District Manager June 1, 1987 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' C. V. Chatterton, Chairman File- FEW-O81-WF Gentlemen' BOPE Test Granite Point 18742 Well No. 13RD Pursuant to your verbal request (Reference Telecon R. L. Grainger - Mike Minder, AOGCC 05-30-87), attached is the BOPE Test Report for the subject well. Very truly yours, (_...~C--'"' ,/ "'/ ~" +' W. G. Smith District Manager Attachment KWU/dds 010/kwu JUN 01 '87 10:28 AHOCO PROD AHC TO: ALASKE OIVI$10N OF OIL 8NO 8~S ,, PRODUCTION CO, flTI'N: MIKE MtNDER B-31-87 ftS PER OUR TELEPHONE CONVERitF~TION 5-30-.87, THI.~i ~EMO I5; TO PROVIDE YOU WiTH THE RESULTS OF THE ~E TE~T CONDUCTED ON ~RANITE POINT 18742 ., LEASE WELL ~ ;~ REDRIL'L. EQUIPMENT SIZE & RRTtNG TE~t' PRESSURE RESULTS RNNUL. RR 13 518" ~(~ 2Z00 PSI OK UPPER RAHS 13 5f8" $000 3580 PSI OK ,AUTO CHOKE CHOKE CHOKE MRNI FOLD CHOKE LINES RNO VRLVES KILL LINE5 RND VRLVES UPPER KELLY COCK LOWER KELLY COCK STANDPIPE & MRNIFOLO (WILL 8E'TEST~O AFTER T80 IS OUT OF HOLE) ~" 5800 PSI 3S¢e OK ~" ~(D0(4 PSI 35~0 OK PSI 35(%~D OK ~" S~ PSI ;~SOe OK (WILL BE TEBTED RI:TEE TB~ I,~ OUT OF HOLE> (WILL 8£ TESi'ED ~iFTER TBG I$ OUT OF HOLE) ~" 5000 P~I ~6~ OK ~G~~RMN ALASKA OIL AND GAS CONSERVATION COMMISSION . / , 3001 PORCUPINE DRIVE · ' /~ANCHORAGE, ALASKA 99501-3192 ' ' /, TELEPHONE (907) 279-1433~ Telecopy No. \ (907)- 276-7542 , .. April 28, 1987 A D M I N I S T R A T I V E A P P R O.'V A L N O. 76.21 Re: Mr. W. G. Smith District Manager Amoco Production Company. P. O. Box 100779 Anchorage, AK 9951.0-0779 The application of Amoco Production Company to drill the ~G_T~~_~pi___n~zl~.~2 No. 13RD well as part of the pressure maintenance project app~6~ by Conservation Order No. 76. , . ., Dear Mr. Smith.. The application was received on April 24, 1987, and stated that the referenced well would be located to improve oil recovery from the west flank of the Granite Point Field. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and injection of water into the referenced well pursuant to Rule 7 of Conservation Order No.~ .76. Sincerely% W. W. Barnwell Commissioner BY ORDER OF THE COMMISSION jo/3.AA76 _ ~$ April 28, 1987 W. G. Smith District Manager Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510-0779 Telecopy: (907) 276-7542 Re: Granite Point State 18742 No. 13 RD Amoco Production Company Permit No. 87-44 Sur. Loc. 780'FNL, 708'FEL, Sec. 12, TION, R12W, SM. Btmhole Loc. 1797'FNL, 2060'FW?~, Sec. 12, T10N, R12W, SM. Dear Mr. Smith: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior 'to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. s, C. V. c ~ ' Chairman o f Alaska Oil and Gas Conservation Commission dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o enci. Department of Environmental Conservation w/o encl. Mr. Bill H Lamoreaux W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 April 23, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention- C. V. Chatterton, Chairman File' FEW-O64-WF Gentlemen' Application for Abandonment and Permit to Redrill Granite Point 18742 Well Nos 13 and 13RD Platform Anna, Cook Inlet Alaska Attached in triplicate is a State of Alaska Form 10-403, Application for Sundry Approvals, for abandoning the lower part of the wellbore in Granite Point 18742 Well No. 13, in preparation to redrill. Also attached in triplicate is our application for Permit to Drill, State of Alaska Form 10-401 for redrilling the subject well, and our Company Draft No. 353485 dated April 23, 1987 for $100.00 to cover the filing fee. The subject well is shut-in due to a casing failure at 8,540 feet MD. We propose to redrill this well to re-establish water injection to this area of the field. The objective of the proposed abandonment is to isolate all perforations above the casing failure. A proposed wellbore diagram is attached. The new target location is south of the current wellbore. A surface plan, vertical section, and survey calculations for the proposed redrill location are attached. Also attached is a proposed mud program, mud system schematic, BOP diagram, maximum formation pressure calculations, and proposed drilling time curve. Since this will be the third well completed in the northwest quarter of Section 12, we also wish to obtain an exception to the provisions of Alaska Oil and Gas Conservation Commission File' FEW-O64-WF April 23, 1987 ./~ ' C. d~. 7~ $~ ~ ~&~'~' 20 AAC 25.055 of the Alaska Oil and Gas Conservation Commission. The · other wells completed in this quarter section are' GP 18742 Well. No. 25 - Producer GP 18742 Well No. 35 - Producer There are no affected operators on the adjacent sections. The estimate date for commencement of operations is May 4, 1987. Please contact Kurt Unger in our Anchorage office at 562-2147, extension 211 if you have any questions concerning this application. Very truly yours, W. G. Smith Di strict Manager Attachments KWU/dds 049/kwu "-" STATE OF ALASKA ALASKA k-~lL AND GAS CONSERVATION CC...MISSION PERMIT TO DRILL la. Type of work Drill [] Redritl lb. Type of w~ell. Exploratory [] Stratigraphic Test E] Development Oil Re-Entry [] Deepen Service ~ Developement Gas [] Single Zone E] Multiple Zone {_] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Amoco Production Company 105' KB MSL feet Middle Kenai Sands 3. Address 6. Property Designation Granite Point Field P.O. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface Leg 4, S1 ol; b P1 al;fort 17. Unit or property Name 11. Type Bond(see 20 AAC 25.025) Anna 780' FNL, 708' FEL, Sec 12, T10N Granite Point St. 18742 Blanket R12~Jt'toSp'~'productive interval C4Top - (7835 TVD) 8. Well nu,mber Number 1704 FNL, 2235 FWL, Sec 12, T10N, R12W, S.M. 13RD Surety - 599481 At total depth 1797 FNL, 2060 FWL, 10,300'MD 9. Approximate spud date Amount (9,749 TVD) Sec 12, T10N, R12W, S.M. May 14, lc~R7 J;500.000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 05 Top GP 18742 #35 10,300 MD 2,060 feet -Ioriz0ntal 1,000 feet 5,060 t'9,74cb TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth R,r)0~et Maximum hole angle25 0 Uaximumsurface 1,;~47 psigAttota~depthrrVD) Zlr,~ZJ9 psig 18. Casing program Settincj Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8~" 7" 35# N80 LT&C 2550 7750 7247 10300 9749 To cover entire lengtt 19. To be completed for Redrill, Re-entry, and Deepen Operations. '-" ~: ~'~i ~iI ~ii~ !~?~ ~,,!,~,: ii!!~ ~'~ Present well condition summary_ Total depth: measured 10,700 ~ feet Plugs (measured) true vertical 10,125' feet .. :. Effective depth: measured 10,134' feet true vertical 9,560 feet Casing Collapse - 8,5407~i'ND:~:i~;,~' .;'~ ~:~' .... Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 627' 20" 1285 sx 627' 626' Surface 2002' 13 3/8" 1600 sx 2002' 1976' Intermediate 8964' 9 5/8" 550 sx 8964' 8400' Production Liner 1940' 7" 200 sx 10693' 10118' Perforation depth: measured true vertical (See Attached) 20. Attachments Filing fee 22 Property plat ~ BOP Sketch [] Diverter SketchN[~]A Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report [] 20AAC 25.050 requirements ~ 21. I hereby certify that the fore...eping i.s-~t?ue and correct, to the best of my knowledge Signed ~,/,~: ...... ~-'~ ~..~..~~ Title District Manaqer Date04/23 Commission Use Only Permit Number I APl number , I App~yaJ,,di~t~,, _. I See cover letter ~/~'-~:(/~ I 50---~ ~ ~.--?,--0C;S'~.~--0! I uq./z:~/~/ .] for other requirements Conditions of approval Samples required [] Yes j~ No Mud log required [] Yes ~i~ No Hydrogen sulfide measures [~,Yes [] No Directional survey required ~ Yes [] No Required workinQ,4m'6"~sure fo('l~OP..~d~¢.~ ~M; [] bM; [] 10M; [] 15M Other: /' ./ ~ / /~ --//'/ '// // _.// ~ by order of Approvedby ~~y ~ ~//~'~,~ Commissioner the commission Date~/~/~7 Form 10-401 Rev. 12-1-85 Submit ir(triplicate Perforation Depth Measured Depth 8,390 - 8,435 8,540 - 8,625 8,650 - 8,690 9,000 - 9,020 9,410 - 9,430 9,480 - 9,560 9,583 - 9,650 9,677 - 9,707 9,935 - 9,960 10,010 - 10,035 True Vertical Depth 7,854 - 7,896 7,994 - 8,074 8,097 - 8,135 8,433 - 8,453 8,837 - 8,857 8,907 - 8,987 9,010 - 9,077 9,104 - 9,134 9,362 - 9,386 9,437 - 9,462 Granite Point 18742 No. 13RD Anticipated Formation Pressures Anticipated Pressures Basis- GP 18742 No. 13 - Shut-in Pressure - 500 psi - tubing - Fluid in Well - Filtered SW 8.5 ppg - Top Perforation - 8,390' MD - 7,854' '[VD 1. Calculated Maximum Formation Pressures' At 8,390 feet MD · 500 psi + (7,854' x .052 x 8.5) = 3,970 psi At 10,300 feet MD · 500 psi + (9,749' x .052 x 8.5) = 4,809 psi 2. Maximum Surface Pressure' If 20% of the wellbore is evacuated with 8.5 ppg sea water in the well. The maximum surface pressure is' P smax P smax = 4,809 psi-(9,749' - (.20 x 9,749')) x .052 x 8.5 ppg = 1,362 psi 3. Maximum anticipated Mud Weight' 3,970 psi 0.52 x 7854 = 9.7 ppg EMW Mud Program I. Interval' Section Cutting 8,000 - 8,060 feet Mud Type' EPA Mud Type No. 5 - Spud Mud. Mud Description' Milling Mud We i ght V i scos i ty F__~L 8.6-9.0 150 - 250 NC II. Interval- 8,000 - 10,300 Feet (TD) - 8½" Hole Section Mud Type- EPA Mud Type No. 2 - Lognosulfanate Mud Mud Description' Dual Polymer - Fresh water HTHP W e i g h t P__~V Y~P F__~L 9.0-9.7* 10 10 15 *Mud weight will be increased as required to control formation pressures. Drilling Program 1. After abandoning GP 18742 No. 13, per Form 10-403, a 60-foot section will be cut in the 9 5/8-inch casing from approximately 8,000 - 8,060 feet. 2. Set cement plug from 8,350 feet (top of bridge plug) to 7,900 feet. Dress plug to 8,010 feet. 3. Kick off and side track will with mud motor. Perform formation leak-off test below section. 4. Directionally, drill 8½-inch hole per attached direction plan to total depth of approximately 10,300 feet. 5. Run open hole logs. 6. Run 7-inch 35 pound N80 LT&C liner from approximately 7,750 - 10,300 feet and cement over entire length. 7. Perforate zones of interest. 8. Set injection packer and run seal assembly and 3½-inch tubing. 9. Set back-pressure valve, nipple down BOP's, nipple up tree. Test tree to 5,600 psi. Pull back-pressure valve. 10. Place well on injection. 'UO DATE~ JR~ACE LOCATION~ JBSURFACE LOCATiONz GRANITE POINT ADL 18742 WELL NO. 13 MIDDLE KENAI SANDS 18/23/67 LEG 4, SLOT 5, G.P. PLATFORH'ANNA 774' FNL, 7~9' FEL, SEC. 12, T1DN, R12W, S.M. TD - 1649' FNL, 2~14' FWL, SEC. 12, T.lgN, R12W, S.M. LEVATION: D~ BDt [(ITIAL POTENTIAL: 1~5' KB-HSL 18,45~' 964 BOPD; TVDz 18,125' TVD~ 9,876' 1 BWPD; 736 MCFD; GOR 764 NITIAL STIMULATION~ A$ING RECORD~ OHPLFTIOtl RECORD: ,. ERFORATiOtIS: , 28'", 85 X 94.:~ CSA 627' X 1285 S× 13--3/B", 54,.~} CSA 2FJ9'2' X 16~.0' SX 9-5/8", ,Ii) X 43.5# N-Sg × S-95 CSA 896~t' X 55~ SX 7", 38.f) S-95 LINER SET AT 8'753-1g,69'3' 693 X 2g~ SX 1) DCD SINGLE TUBIItG HAt;GER, 34' 2) 3-1/2" 8RI) X 2-.1/2" DLI'FRES,S XO ?,4' 3) 3--1/2" RUTTRE~{S PUP. 42' 4) 3-1/2" P, UTI'RESS PUP. · 5~' 5) 3-1/2" 9.2~I ft-FJO P,U'rTRESS TIIG. \,~/A'ILA!; ~,R,t, DFOJ:.D COUPLINGS. 8,227' 6') 3-1/2" BU'I'TRESS PUP., 7) BAI',ER StTAL LOCA'I'OR. 8 ) BAKER Ii1ODf:'L ' D ' PACKER \,//4-3/4" ID (SET Al' 8,215' ON DP HEASURI~I'II.'NT) 9) BAKER SEAt. ASSEI'IBLY 1JBr) 3-1/2" BUTTRESS TI)G. I 1 ) ~.)UL ESIIOE C-4: 839~-8435' C-5: C-7: 941g-9438' 948~-9568' 9583-9658' 8,233' 8,234' 8,233' 8,-246' 8,278' 8,279' 854g-8625' 865~-869~' 9677-97~7' 9935-996~' 18~1~-1~g35' C-6: AS RUN 84/38/84 2 3 XXXXXg)<x):xx [; I=1 1~ I=1 ]1 1 1 IIIItlIIIIII)PROBAI;LF I C~,)LtAt'SE e X~ 'tOp O1' 7" LIftl 9-'5/B" 0 8964' /////// PBD 18,134' 7" LINER 18,693' ' TD SUBJECT Amoco Production Compan ENGINEERING CHART Top 2_o .'dSA & Z7 ~ Z~US"~4 zooz' E t 48o - q ~(0o Sheet No. File ~77 -~ 707 ! qq3ff-qql~o / loolo - ic)oBS' Of Form :],71 2-71 / / / / /. / / / / ,. / / / / R 1W 1 -/ / ! / / /. / /! / /-~ / GRANITE POINT FIELD C-5 UNIT ~ ~- ~ .-~- 1t 12 LEG. NO. I LEG. NO. 2 LEG. NO. 3 LAT. 60°58' 37.56" LONG.15I° 18' 4 6.00" Y = 2,551, X = 266,816 FROM N.I~. 729' SOUTH 636' WEST LAT. 60058. 36.96" LAT. 60058'36.53" LONG 1St° 18'45.28" LONG. 151°IS'46.82'' Y: 2,551, 352 Y : 2,551 , 310 X : 266,850 X : 266,774 FROM N.E. COR. FROM N.E. COR. 790' SOUTH 8, 834' SOUTH ~, 600' WEST 676' WEST t I 1 SCALE: I": I,OOO kEG. NO. 4 j LAT. 60°58'37. 12'' LONG. 151° 18'47.48" Y: 2,551,371 X : 266,742 FROM N.E. COR. 774' SOUTH 8' 709' WEST CERTIFICATE OF SURVEYOR I hereby certify that I om properly registered and licensed to pract ce land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision and that all dimensions Qnd other delails are correct. Date Surveyor NOTE The location of platform legs was accomplished by Using triangulation stations Dud, Trinity, and Tyonek Offsel. TION 12 13 7 FINAL PLAT OF TYONEK PLATFORM "A" LOCATED IN NCI/4, NE I/4 ,PROTRACTEO SEC.I2,TION,RI2W, S.M. SURVEYED FOR PAN AMERICAN PETROLEUM CORP. P.O. BOX 779 ANCHORAGE, ALASKA SURVEYED BY E M. LINDSEY I~ ASSOC. LAND SURVEYORS ~, CIVIL ENGINEERS 3201 ARCTIC BLVD ANCHORAGE, ALASKA 7600 - 7800 - 8000- 8200 - 8400 86O0 88OO 9200 9400 9600 9800 10000 -3000 VERTICAL -SIDE- VIEW Verticol Section 247.87 Degrees UNITS=F'I' . Legend -2800 -2600 -2400 -2200 -2000 -1800 .] :-?-':':'.6 ........... I :' :::.':::'-!:::: -..Z-:.X~:-Z-'. ...... ': :'X+:' ...::'::2-] ...... .. . · .-..-. ....-.-.-, ., :: .'. :( .. .. · ... .. . PLAN -TOP- VIEW UNIT- FT -500 -600 ....................................................................................................................... -700 ....................................................................................................................... -800 - -900 - -1000 - -1100 -2700 -2600 -250 0 -24.00 -2300 WEST -2.: O0 -2100 Legend 0 GP13R F.ILENAME' gP13R TRADITIONAL UNITS 1987-04-22 13:26 RADIUS OF CURVATURE METHOD ~ - ~ VERTICAL SECTION OR CLOSURE DIREC'TION IS 247. ~5 DEOREES MEAS. DEPTH 7656.00 7694.00 782(.00 SURVEY DEPTH NORTH EAST VERT. CLOSURE DOQ INCL. DIR. (TVD) -SOUTH -WEST SECTION DIST. DIR. LEG 20.00 N77.00W 7158.45 -911.81 -2136.35 2322.40 2323 S67W ... THE ABOVE LINE IS MULTISHOT INPUT DATA ... 20.00 N77.00W 7i94.16 -908.89 -2149.01 2333.04 2333 S67W 0.0 17.25 N82.0©W 73i7.34 -90!.32 --2i89.82 2'368.02 2368 S68W 2. 4 7898.00 7962.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 10300.00 16.75 16.25 16.25 16.25 16 25 18 O0 16 50 15 O0 13 50 12 O0 10.50 9.00 7.50 6.00 4.50 3.00 1.50 0.00 0.00 N85.00W N86.00W S82.00W S72.00W S62.00W S62.00W S62.00W S62.00W S62.'00W S62.00W S62.00W S62.00W S62.00W S62.00W S6~.OOW S62.00W S62.00W S62.00W S62.00W 7388.10 7449.46 7581.95 7677.95 7773.96 7869.52 7965.02 8061.26 8158.18 8255.71 8353 78 8452 33 8551 29 8650 59 875O 17 8849 95 8949 87 90~9 86 9749 86 -898.87 -2211.31 -897.45 -2229.43 -898.79 -2267.96 -905.08 -2295.19 --916.00 -2320.91 -929.82 -2346.91 -943.74 -2373.09 -956.49 -2397.06 -968.04 -2418.79 -978.40 -243~.28 -987.56 -2455.50 -995.51 -2470.46 -1002.25 -248~. 12 1007.76 o.~oq 50 -1012.06 -2501.58 -1015.13 -2507.36 -1016.97 -2510.82 -1017.59 -2511.98 -1017.59 -25il.98 2387. 2403. 2439. 2467. 2~95. 252~. 2553. 2580. 2605. 2627. 2646 2663 2677 2689 2698 2705 2708 2710 2710 02 2387 S68W 28 2403 $68W 49 2440 S68W 09 2467 S68W 03 2493 S68W 32 2524 S68W 81 255~ S68W 81 2581 S68W 29 2605 S68W 24 2627 S68W 64 2647 S68W 49 2663 S68W 76 2678 S68W 45 2689 S68W 55 2699 S68W 05 2705 S68W 96 2709 S68W 26 2710 S68W 26 2710 S68W i.4 1 7~'~ i 5 1 5/~ 1 5 I I 5 i 5 i 5 i 5/ 1 5 1 5~ 1 5 1 5/ 0 0 CHAN~E' (W)ELL (M)ETHOD (V)ERTICAL SECTION (C)REATE A FILE (T)RUE VERTICAL DEPTH (P)LOT (A)LTERNATE FORMAT (O)UTPUT UNITS (E)XTRAPOLATE TO TA~QET T R A_B 1 i' I 0 N A !_. 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':";,;'{) -2495., 87 t 94 ,, 88 NS8W i ,2, t % ~"::' -- ''~.a o o "~ t "'~ 0 ''~ ¢ o ..... _, ,,...,,,.,,_.. ...... _.-.., _ , NS8W i 0i 6,06 -.-':2498 ~ ,5::t 20'.::5., 40 N.-:ggW i0i6 O,S _..,~z:oc~ 8i 19¢~¥ '='"~ N40W i0t6 06 '-,zx,,"; oi o-- "~':':' N4t-~l,I . ,, -" :::. 0 7 C:, .-. ,-: ,,-_ ~.) I., .-:.....~ ..... T 0 ( (.'; F:'t X $ i ) i-'i:;: 0 H N 0., i F:"T' I) I I::: ,, 0,00 N Olii; ")':'; 0(:) N4iW SS:', 4'7 NS6W 60,,28 NStW ,:.:) z. ? 2 i"J ~;> ?, M i i 6 ,. ;':.!0 N2'.SW i 4 '5,. '7 dSi"J.,:.. '') S k~.. ...... o":.~N'::) 3 W i f,::.-.: ........... 200,iA H,, ..... W ~-'-)':: 4'? N2.SWI---' ~....;.. ~.~ _. 245.0i N2,SWP 266., S6 N 24 WI'-" 287., 66 i"!25WI'~' i~,O'-',:', 0..5 N27WP 'S3(:) 72 14,:..7HI-- S.'52,86 N3 t WI"' :37'5.,68 NS4WF' .'39°: , 28 NS6WF:'. 4 ''* S ':"-' 14...,,::: W I-' .,'.. ... _2 ( -', 'ZO -, 448 ,. :'";8 N4(-)t,,IF' i 0 i 6 06 "~ ''~ '"'"' =' 8,89 N40W 4'73 ,, 6''~ - ,~ '-,-_--, '.,' o ,. 8i t ";" '-i0i6,06 --2498,8t t96,2:? N~9W 499,29 - ... '" .~,,..5., t 6 i0t6,06 -9498,8t i93.,.io NSTW ,::.'o- -i Ot 6., 06 -'2498,8i i 89,46 N~_5~_51.,,I 55t .,. -t0t6,06 -2498.,8iP t86,t0 NS2W 57';;,,80 (W) "' I:: t.. I... ,.., ( H ) lii:'f' H 0 D (I) ) Iii: P T I--IS 0 R I i'4 C R E bi E N'T' (0) UTPUT Lli'-411"~ ( P )I_OT (£') TOi:' (DIEi:'&ULT) ~ 'T' 0 ( (; F' t S,S' 2 ) F"ROH NO.,i F '¥' D (.).00 N Olii] "'~ 0 S N 4':?1,,I 7 ~0'.5 N46W t :53,,:..,:.. ''~ ''~ N 4 ;'5 t,.I. S :S ,. 2 9 i',! S 8 W '.5 t , 4 8 N ¥ 5 t,,l '7 2 '::' ''~ -'_... , _,, ,::: N.4 % M 9 7.., 8 0 N 7;'.5 W i i ;!:.-: ,. i 6 NS6W i ;.'-.~ 9., '7'.:5 i .4 ','~; ,. 5:J i N 7;:; ? I.,J i 5'5., i 4 N .'3'7 W t 6/-:, ,. 552 i '7 ,'5.'., ,, :'; ''~ '-' t,.l .::., -: i'.4 S .-' . i":'::; ";' .... c:. .... ,:::. 4 N X '7 t,.I t 94,8,.'_-') NSSW ">,3''~ 67 N:.58t,.I .,,.'.. ,~...... . ,,-..'~ ¢_ 8 , '7 i N :3914. [3t 7,.,~,~!6 N40WP ;::/. t '7 ,. 4 ? i'"-~ 41 W F:' ?4 0 I";:li!: ,..., N42WP 2:2t ,, '7.2; N42WF:' N4SWF:' 226,03 N42WI:' N44WF' 290,37 N4SWF:' N46WP 294,74 N44WI'-" N4'TWF' 29:?,, t '_'5 N45WF:' V i"I R IE A I) .4'.'!.. · Z~ 30.25' 123" PLATFORM ANNA DRILLING STACK ___PITCHER NIPPLE--16"ID W/ 10" FLOWLINE ANNULAR BOP "NL SHAF-FER" M13 5/8" 5000 PSI BX--160 ASSY WT. 13,650 LBS. DEL GATE BOP "NL SHAFFER" .... 13 5/8" 5000 PSI BX--160 ASSY WT. 16,500 LBS. _ _MUD CROSS-- 13 5/8" BORE W/ 4" 5000 PSI VALVES & CK __SGL GATE BOP "NL SHAFFER" 1,:5 5/8" 5000 PSI EX--160 ASSY WT 9100 LBS. RISER 18"OD 13 5/8 5000 FLG w/ GREyi, oK CLAMP RiNG (AX) "CIW" P/N 4-1700--13 LOWER R~SER ~" ID ...... W/ 10" 5000 PSI FLG (RX--54) ; :. S t No. Of ~~ Amoco Production Company [,/~MOCO~ ~-J-- ~ -'~? ENGINEERING CHART Appn : --' 'Z:::)..~ >"~ ........ j ~ CHECK LIST FOR NEW W~z. PERMITS ITEM APPROVE DATE (1) Fee ~ ~-;-? -~ (2) nos '" (2 thru 8) (3) 9. (9 thru 13) 10. (10 and 12. 13. (4) Casg ~..~ ~-~7-$~ (5) '(23 thru 28) YES NO 1. Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ................... , ......... 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected parry ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval-needed ............................. ~ Is the lease number ~ppropriate .. i . .. ~ ..... ~ ....~ . ] Does the well have a unique namm and number .......................... ~ 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in suz-face and intermediate or production strings ... Will c~m~nt cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ ; Is old wellbore abandonnmmt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ For (6) OTHER ~/.~. 29. (2gthru 31) 30. 31. Is a diverter system required .......................... , ............. Is the dzilling fluid progr~n sch~tic and list of equi~t adequate Are necessary diagrams and descriptions of Ci.c:-L_~-~2 BOPE attached. Does BOPE have sufficient pressure rating - Test to 3 oo~ psig .. Does the choke m~n~fold comply w/AP1 RP-53 (May 84) .................. Is the presence of ~S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented ~ ., (6) Add: ~{'~,f', ~-~?-~V 32. Additional requirers ............................................. . Geology: Engineering: ~--/,~_~ rev: 01/28/87 6.011 INITIAL GEO. UNIT 0N/OFF a. xss s-tm'us NO.
