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177-072
, STATE OF ALASKA ') ALAE )OIL AND GAS CONSERVATION COMM. . ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission ^nshorsgc RECEIVED OCT 1 9 2005 Stimulate U Other U Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 177-072 Service0 6. API Number: 50-733-10075-01 9. Well Name and Number: MGS ST 17595: Baker-08RD 10. Field/Pool(s): MGS/B, C, D, E, F, G Oil 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull TubingD Cha:1ge Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: Plug Perforatiohs LJ Perforate New Pool D Perforate D 4. Current Well Class: Development D Stratigraphic D 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 79' 8. Property Designation: Baker Platform/Cook Inlet 11. Present Well Condition Summary: Total Depth measured 9,250' true vertical 9,082' Effective Depth measured 7,715' true vertical 7,551' Casing Length Size Structural Conductor 818' 20" Surface 1,986' 13-3/8" Intermediate Production 7801' 9-5/8" Liner Perforation depth: Measured depth: none True Vertical depth: none Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): feet feet Plugs (measured) TOC 400' estimated Junk (measured) 7,685' feet feet MD TVD Burst Collapse 817' n/a n/a 1916' 2730 psi 1130 psi. 7637' 3950 psi 2570 psi 818' 1,986' 7801' ~ANNE') IMO\f 0 3 2005 3-1/2",9.2# DSS @ 6,041' none Treatment descriptions including volumes used and final pressure: n/a Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 90 000 15. Well Class after proposed work: ExploratoryD Development D 16. Well Status after proposed work: oilD Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact J. Gary Eller 263-7848 Oil-Bbl o o Tubing Pressure 300 o Service 0 GINJ D WINJ 0 WDSPL D Sundry Number or N/A if C.O. Exempt: 305-243 Printed Name Timothy C. Brandenburg Title Drilling Manager S¡9narure?ýCÁ 2' ,,' 'Phone 907-276-7600 Forrn10-4~~ed04f20~ftßJìI(;¡fq/o~64486 0 RIG I NAL Date 10 -¡.1- _¿;.-s-- Submit Original Only ) ) Wellbore Schematic: Ba-08RD as of 9/14/05 I ' I Toe. at 400' -est. ' Well Name: Operator: Field: API: Permit: Well Type: Well Status: RKB: TDITVD: PBTD/PBTVD: Ba-08RD Unocal Alaska Middle Ground Shoal 50-733-10075-01 177-072 Water injection, single completion Plugged 79' 9,250'/9,083' 400'/399' Casina Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 20" 89# Conductor 0.00 616.00 616.00 '" 13.375" 54.5# J-55 Surface Casing 0.00 1,986.00 1,986.00 40, 43.5, 9.625 47# S-95 Production Casing 0.00 7,801.00 7,801.00 Tubina Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 3.5" I 9.2# I I DSS Tubing I 0.001 6,040.001 6,040.00 Tubing punches at 6,011 - 6,017' (8/28/05); 4,889' - 4,895' (8/30/05); Jewelry Detail Type Seal Locator and 2.875" and 3.5" XO Baker Model D Packer Seal Assembly Muleshoe ,- .,",':'" ." .",';, ~~ "1, I~ "'.... 'X.(it~.. '.'.'·':'¡i¡, ." 1::;:'i~<;..:)~:,,~.: /,:,",",:,;::':,.:';,:'" ::: '.,,-'::,~,~!«, . ':,;:::' I:'>,:::',!:: r~:::;:: ::,;,: ';:':::<:, '~;.:".:, '~:::;, ": ",:, :;<i II;"': ; :" ':",:~I' '::~:I:~~: '~~', 1~,: ..Ii, ::~i"::;.;:':,:8· : Peñoration Detail Date SPF Zone Sep-05 Sep-05 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Mar-85 Status Squeezed Squeezed Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned ."' ";'~ .; ~~ijlll ~:",'~~ ""f~., ,,~;,',/I:: ':::<':,:' ,::'~¡:"""I" ...~; <, :,~~(, :~:':';; '~Lt;i:.-..- ;~II";; ';,f"':<"": ",~. ,; '~I "Ù':;;;~' ,.~,,~,;':-r-- B B B B B B C C C C D D E . ~ ':.: ;,~'.:'.~ '. ~"'JI:~ ;¡~-:,;:,:~II , ", :, , 'i1 1 . , ".~l"'_ I Last Revised: 110/10/2005 Top (FT) Btm (FT) 1,000.00 1,006.00 1,990.00 1,996.00 6,138.00 6,150.00 6,210.00 6,260.00 6,300.00 6,330.00 6,352.00 6,370.00 6,416.00 6,440.00 6,462.00 6,476.00 6,580.00 6,610.00 6.650.00 6,710.00 6,740.00 6,800.00 6.830.00 6,882.00 7,030.00 7,084.00 7,120.00 7,200.00 7,608.00 7,622.00 1 Revised By: I Depth 6,047' 6,050' 6,066' 6,067' Length (FT) 6.00 6.00 12.00 50.00 30.00 18.00 24.00 14.00 30.00 60.00 60.00 52.00 54.00 80.00 14.00 IDED ) ) 'Well Ba-08rd Operations Summary October 7, 2005 8/19/05 Pressure 9%" casing to 1500 psi, let sit for 45 minutes pressure fell to 1050 psi and straight lined for 20 minutes. Tubing pressure remained constant during entire operation at 300 psi. No significant increase in pressure on the 13%" casing during MIT on 9%". Perform injectivity test, pump rate of 2 bpm, initial pressures of 300 psi tubing, 60 psi 9%" casing, 175 psi 13%" casing, 80 psi 20" casing. Max pressure seen on tubing was 1650 psi at 70 bbl away. SD after injecting 82 bbl. Never saw any pressure increase on 9%" casing during injectivity test. 8/28/05 RU APRS, load tubing punches. RIH locate jewelry, pressure up tubing to 650 psi, fire 61 of 1-9/16" tubing punches at 6,0111-6,01 l' MD. POOH, RD wireline. Pump down 9%" taking returns up tubing to fluid pack with water - total 13 bbl pumped and clean water returns. Pump down tubing taking returns up 9%" casing to fluid pack, got clean water returns after 37 bbl. Pump 157 bbl of 14.5 ppg (630 sx) class "G" cement. Bullhead 157 bbl cement starting at 3.2 bpm down tubing. SD and launch foam ball at 157 bbl cement pumped. Pump displacement fluid at 1.0 bpm rate and casing pressure averaged 1,875 psig until at 20 bbl displacement casing was 2,000 psig. Opened choke and started taking returns on 9%". SD pump at 48.5 bbl total displacement. During the job, the 13%" casing pressured up to 360 psig from 55 psig starting pressure. wac. 8/29/05 Pressure up on 9%" x tbg, starting pressure 9%" 80 psi, 13%" 75 psi. Pressure up 9%" to 1,500 psi, 13%" rose from 75 psi to 190 psi. 9%" fell to 900 psi in 90 seconds. 8/30/05 Pressure up BA-08rd tubing to 1500 psig. After 1/2 hour pressure was still at 1500 psig with no losses. AOGCC witness MIT tubing on BA-8. RU APRS on BA-8. RIH with 61 of 1-9/16" tubing punches and tag cement at 53831 RKB. AOGCC witnessed tag. Pull up hole and shot tubing punches 48891 - 48951 MD. POOH, RD APRS. 9/1/05 Displaced BA-08RD with 9.8 ppg NaCI brine down tubing taking returns up 9%" casing. 9/4/05 Lined up Schlumberger to 13%" annulus and started bullheading 8.4 ppg seawater. At 190 bbl away had 620 psig on 13%",,25 psig on 20" and 95 psig on 9%". On shut down 13%" went to 426 psig and in 10 minutes 13%" dropped to 354 psig. RU APRS. RIH with 2", 60º phase, 6 spf perf guns. Perf 1,9901 - 1,996'. POOH, RD APRS. Pump down tubing taking returns up 13%" casing to confirm circulation through holes. Line up and pump 160 bbl 8.4 ppg seawater down 9%" annulus taking returns up tubing (full displacement). Line up to pump down tubing and take returns from 13%" casing annulus. Pump 11.5 bbl diesel for freeze protection ahead of cement. Pump 2 bbl spacer of 8.4 ppg seawater ahead of cement. Pump 14.5 ppg cement down tubing taking returns up 13%" until 35.7 bbl cement out tubing tail. Pump down tubing taking returns up 9%" annulus with 34.5 bbl cement. Displaced with 12.5 bbl of seawater. Total cement out tail while taking returns up 9%" casing = 34.5 bbl. Left 3.8 bbl cement (431') in tubing. Total cement pumped = 74 bbl. 9/5/05 Wait on cement. Ba-08RD morning report summary (164486), CONFIDENTIAL: last revised 10/7/2005, Page 1 ) ) Well Ba-08rd Operations Summary October 7, 2005 9/6/05 MIT BA-08RD tubing to 1600 psig for 30 minutes and lost 45 psig throughout the test. Line up test pump to 9%" casing to test. At 250 psig on 9%" noticed pressure on the 13%" had increased to 60 psig and was tracking the 9%". Continued pumping with test pump at 0.14 bpm until achieving 450 psig on both casings. SD, pressure dropped gradually to 225 psig over 1 hour on both annuli. Pump down 9%" taking returns up 13%" casing in an attempt to establish circulation, pressure increased to 900 psi and fell back to 500 psi when formation broke down. Circulated 50 bbl of seawater. Returns tank strap was very close to suction tank strap. Performed injectivity test. Pumping in at a 1.8 bpm rate with 750 psi injection pressure. Monitored 2011 casing and saw no pressure increase. Pressure test tubing to 1,500 psi, held for 30 minutes. Monitored 13%" and 9%" casing for pressure increase - none seen. 9/8/05 Pump 10 bbl seawater down 13%" casing taking returns up 9%" casing, establish good circulation. Pump 58 bbl of 14. 5 ppg cement down the 13%". After first 20 bbl of cement noticed that returns on the 9%" had fallen off to 50% or less. Pumped an additional 58 bbl of same 14.5 ppg cement except added CemNet at 1 ppg. Displaced with 11 bbl of seawater followed by 50 bbl of Barazan mixed at 80 second viscosity, followed by 9 bbl diesel for freeze protection. Total cement pumped = 475 sx= 116 bbl. 9/9/05 woe. Pressured up 13%" casing to 1500 psi. Pressure fell back to 1,350 psi over 30 minutes. No pressure increase on 20". Pressured 13%" casing up to 1,500 psi and opened 9%" annulus valve to monitor pressure at choke manifold and as soon as the valve was opened we lost all pressure on the 13%" casing. Pressure tested wellhead 9%" primary and secondary seals to 3,000 psi, held good. RU test pump and pumped for 1 hour, had 13%" pressure up to 650 psi. Monitored 9%" casing and 2011 casing, had no pressure increase. RU test pump on 9%" casing, pressured up to 1,400 psi. 9/10/05 Monitor pressure on 9%", fell from 1400 psi to 1275 psi in 1 hour. Attempt to pressure up 13%" casing, established an injection rate and pressure of 725 psi at 3 bpm. Attempt establish circulation down 9%" casing and up 13%" casing. Pressured up 9%" casing to 1500 psi, could not establish circulation. Monitored 9%", and in 30 minutes pressure was at 1,450 psi. Repeated this 4 times with same results, and each time 13%" casing rose slightly. 9/12/05 Inject 10 bbl of seawater down the 13%" to ensure an injection, followed by 75 bbl of Barazan with Baraseal at 17 ppb. Pump 58 bbl of 14.5 ppg class G cement with CemNet mixed in at 2 ppb. Displace with 11 bbl seawater, 50 bbl of Barazan at 80+ viscosity, followed by 9 bbl diesel (freeze protect). 9/13/05 woe. Pressure test 13%" casing using test pump up to 880 psi. 81 and monitored for 45 minutes pressure fell to 640 psi and continued to fall, leveling out at approximately 440 psi. Attempted to pressure up again with same results. Appears to be injecting at 880 psi. The 9%" casing was 20 psi before testing and with the 13%" casing at 880 psi pressure the 9%" pressure was 160 psi. Pressured up 9%" to 1550 psi and monitored in 20 minutes, pressure fell to 1475 psi. Ba-08RD morning report summary (164486), CONFIDENTIAL: last revised 10/7/2005, Page 2 ) ) '"Well Ba-08rd Operations Summary October 7, 2005 9/14/05 Monitor 9%" casing pressure, pressure fell from 1050 psi to 950 psi over 11 hours. 13%" casing pressure fell from 300 psi to 200 psi in same period. RU APRS, RIH WITH 61 of 211, 60º phase, 6 spf guns. Tagged cement at 14251 RKB. PU to 10001 RKB, perfed 1000'·1006'. POOH, RD APRS. Pump down tubing taking returns up 9%" casing. Had immediate returns and was able to circulate at 4 bpm at 300 psi. Pump down tubing taking returns up 13%" casing, was able to establish circulation. Pumped a total of 15 bbl at 3.5 bpm rate. 9/15/05 Pump 47.5 bbl of 14.5 ppg cement down tubing taking returns up 13%" casing. When cement hit perforations pressure jumped up to 1,380+ psi, reduced rate to 2 bpm pressure fell to 900 psi. With 47.5 bbl away SD and lined up to take returns up the 9%" casing. Pump another 34.5 bbl cement up the 9%". Displace tubing with 3.4 bbl seawater. Total cement pumped = 82 bbl. 9/16/05 Pressure test tubing to 1,500 psi, slow bleed to 1000 psi in 2 hrs. No indication of communication to other annuli at this time. Shut tubing in with 1000 psi. Pressure up 9%" to 1000 psi. Worked to bleed of any trapped air. While bleeding 9%" to remove air we lost the 1,000 psi that we had shut in on the tubing. Pressure 9%" to 1500 psi. Tubing pressure increased to 475 psi. 13%" = slight vacuum. 9%" showing a very slow bleed off. 9/17/05 Continue pressure testing. Similar results. Ba-08RD morning report summary (164486), CONFIDENTIAL: last revised 10/7/2005, Page 3 ) ) Chevron III Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com October 10, 2005 $CANNE~J NOV 0 ~ 20D5 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary ¡1'1-D7~ 0«, ~1ì Dear Commissioner Norman, Tills letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of U nocal' s pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BHP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BHP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BHP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work On the Dillon platform has been initiated. ~..~. Jn~ 1·r ~JE > "i-"~ ~~ u ~... ~~ t..... à ~'..,,~, Union Oil Company of California / A Chevron Company http://www.chevron.com ) ) Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker 501 and in the gas well Baker 32. In light of the Chevron Corporation acquisition of Unocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. Sincerely, ~ ~-Jé', .2 ~ c.-~ /~ =- ¿ Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California / A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27 -Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 --7 Ba-8rd Injector 7 -Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned Ba -11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Injector 6-Jul'"05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey Ba-17 Injector No survey Ba-18 Gas No survey Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 - Ba -30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Ba-32 Producer No survey ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ";/ _ t:( . P.I. supervisor'~¿:l r I z¡{)~ FROM: John Crisp Petroleum Inspector DATE: August 30, 2005 SUBJECT: Plug & Abandonment MGS ST 17595 Baker 08RD Unocal / Baker PL T PTO: 1770720 Middle Ground Shoal Field NON-CONFIDENTIAL Section: 31 Lease No.: ADL 0017597 Operator Rep.: Ken Lucas Township: 9N Drilling Rig: Pollard Wireline Casinq/Tubinq Data: Conductor: 20" 0.0. Shoe@ 818' MD Surface: 133/8" 0.0. Shoe@ 1986' MD Intermediate: 0.0. Shoe@ Production: 95/8" 0.0. Shoe@ 7801' MD Liner: O.D. Shoe@ Tubing: 3.5" 0.0. Tail@ 6041' MD Tubing: 0.0. Tail@ Range: 12W Rig Elevation: 79' Meridian: SMAK Total Depth: 9250' MD Casinq Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Tvpe Pluq (bottom up) Perforation Bottom of Cement 7715' Pluqqinq Data: Top of Cement Depth Verified? 5383' Wireline tag Pressure Test Applied 1500 psi. Founded on PBTD Tvpe Pluq Founded on: Verified? Open Hole Perforation Cmt Retainer WL Tag Annulus Casing Stub Surface Mud Weight above plug 8.5 ppg ~CANNED \~o,ý 0 31 2005 August 30, 2005: I traveled to Unocal's Baker Platform in Cook Inlet to witness verification of an abandonment cement plug placed in well MGS ST 17595,Baker 08RD in the Middle Ground Shoal Field. I witnessed a 1 .69" OD perforation gun RIH thru tubing to a measured depth of 5383'. Cement had been squeezed thru tubing into perfs from 7622' to 6138'. The Production Packer is set @ 6049'. The WL tag in tubing @ 5383' & the pressure test of tubing to 1500 psi for 30 minutes verifies cement above top most perforation that meets AOGCC requirements. The cement squeeze under production packer into perfs meets 20 AAC 25.112 (C) (1) (D) for well plugging requirements. The production casing has no integrity & plans for repair should be submitted to Commission to obtain approval for continued abandonment. Summary: I witnessed the successful wireline tag of a cement abandonment plug and pressure test of tubing to 1500 psi for 30 minutes. ££,;, Distribution: orig - Well File c - Operator c - DNRlDOG c - Database c - Rpt File c - Inspector Attachments: Wellbore Scmematic Form 10-403 Rev.:5/28/00 by L.R.G. Baker PIt. 08 Plug Tag 08-30-05 jc.xls 9/12/2005 -ype of Request: )roperty Designation: cer Platform, Cook Inlet al Depth MD (ft): 9,250' Casing Structural Conductor Surface Intermediate Production Un er 10ratlon Depth MD (ft): 6,138 to 7,622' :::kers and SSSV Type: c7~ ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION.FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New PooJ 0 4. Current Well Class: ) RECEIVED AUG 2 3 Z005 Suspend U Repair Well· D . Pull Tubing D . Ala!ka r.m & Gas C008. Corumission Perforate U WaiverU Am::hQra~8er U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Development Stratigraphic o o Exploratory D Service 0 1770720 6. API Number: 50-733-10075-01-00 Abandon U Alter casing D Change approved program 0 )perator Name: on Oil Company of Califomia ~ress: Box 196247, Anchorage. AK 99519 œ Elevation (ft): Total Depth TVD (ft): 9,082' Length 9. Well Name and Number: MGS ST 17595; Baker-08RD 10, FieldlPools(s): MGSlB C AND DOlL: E F AND G OIL PRESENT WELL CONDmON SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measure~): 7,715' 7,551' 818' Size MD TVD Burst 20· 818' 817' nla 13-318" 1,986' 1916' 2730 psi 9-5/8" 7801' 7637' 3950 psi 1,986' 7801' Perforation Depth TVD (ft): 5,981 to 7,458' Baker Model D Packer Tubing Size: Tubing Grade: 3-1/2" 9.2# DSS Packers and SSSV MD (ft): 6049' MD Attachments: Description Summary of Proposal U tailed Operations Program 0 BOP Sketch 0 Estimated Date for mmencing Operations: , Verbal Approval: 8126/2005 Date: 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: au 0 Gas 0 Plugged WAG 0 GINJ 0 WINJ ~ ~ Junk (measured): 7,685' Collapse nla 1130 psi 2570 psi Tubing MD (ft): 6,041' Service 0 0 Abandoned D 0 WDSPL D mmission Representative: , I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Steven Lambe 907-263-7637 nted Name _ n~Othy C. Brand.,burg~ nt/e Drilling Manager nature r¿~ /') _'i ~Ione 907-276-7600 Date 11- Z 2--0.5 --V ð COMMISSION USE ONLY nditions of approval: Notify Commission so that a representative may witness Sundry Number: .30 r.. ;1'13 Ig Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance D ...r. c..o~\<"c:_\- r~~ ~().JJ\I'--~ ~ét·NC:.se;;.,,~ ~~S-.}~~-\- ~~. ~m(~ COMMISSIONER ::~:I:ION Daæ: ric//oS" Foon 1O-4œ R~04 OUPU CA' I:. Sumnn in Zca~ ~ P£,¿ , I - -3- - y ~; UIDDlE CROUND SHOAL ADl 17595 WElL N04 SRD KENAI CONGlOMERATE ~TFORM BAKER S-38~ 1+F ( ~bO ù / / J IJ" \) o,('-\.oV . h "70 S ~ 1/'-0 4- 20'" 81' CS\ " ¡. ~ :)-e.. Lf{ t\Þ I L. 1\ 5' I.""\~ - 'JI I '.}b~"'" ~ .... Model D Pkr ,....ç:r- . ! 1 I "31' ~ 1P703O' ~ nøcr L~... ~ 13 318" 54.5f CSA. 1 tla' 4 Depth ~ f~ 48' ~ J. lOoW eo41' t~ tcM7' 1041' lOll' 1067' p,_rtInent ~ ~ Reootd ...... ~ . ..... 5~d 00W 111'11/17 Surfa~ t..ocotIoftz t..I" Slot ~ t. Comtl'Oft 10- Nom ..... Doftut h....,. ,It," FNL. 4" PVft., 1M 31. tINJUIW. s.u. ~ : ~ ~ ~/ ~ :: (:.\:red) SubeurfCRil LKaIonI to - zoocr fSl. IOCr PWL. See ~1. tIN. ..,ft, s.u. 4. 3 1/'2" 1.2' ass tuIIInI (aooted) ~_............... .... .,. s. ~ 112" ass end 3 tn- IIuttrua xo (cooted) ~ #.. !NIl .. 3 1/r Iutttue tubIn, ,. (GHtiI4) 'It): t25O' 7. Seal t~hi"'" 2 7/W' ... 3 1/2" XO L SMI ...tmbt1 P8D: ", S' It UutuhH Ca.-'nt: W. ... CuII!t eat tit "1' .... :,...,.. to ~u.r.e~ 13 :vr. M.5I-J-,SS ~ Nt at ..... with Gmt to ~ 1 ..... 40. 4U OIMI 471 s-n c.Int "' at 7101' wfth 2000 .. :1"A~t PetfQl'oaUonat II "31-1tSO' DI 7030-7014' 1210-1210' 7120-noQ- I3OO-I3W Þ 7101-7hr ÐS2-U7O' ..'....440' 14It-1otH' c: 15.....810' 1150-.710' 1740-1800' 1130-...2' (Aa rut ~) ~ t.......... Ceo ,..,., fUll, W IartI _. - · top at 7.13' rut , 2171 . . I:- 1101-1122' Geo T'raÞcer tool 38' I ~.,^ -.~ 1-11/1a a: 1-7118:l1\ ) \ '" :- .nooa .205'" ,,~.... .\,....~ ~ ""., '-, i.f ~ \h ,. ~ ~., · ~. '" "w PBD 7715' ~\~~.\;~.- I ~ 40. 43.5 10 12SO' . -, þa...." .,..~. 47' CSA 7801 . "¿// ,,"//r ~ ~ ..$I ..Q ~ ..... ~f '"': ~-. ~'L-7 ~ ... ,- l' /1 ICD tMted ,OOS .... HeM NOM HaM ~ Md CIt. InItIat r A" J.ued: ktttIGI StImukItIom !AM..lb Þato:_ Cored tnteNatat DST ~~f. .... ftøutb: :'01 Inwntof IS ¡ ~,(5J 117,. i,' ~i ~"./, \ ~, ;.~:' "'\1 j i JJ '\ ;:: 'I ¡ : ¡:! :U: ,~\ : 'I :1: ; , "W Uw ~ ( '~I~ :1Hn'i':lr .,' U' J' ',; ,,=.1 I i¡' .II ; , ~ i ~ '~L .tJ\\"\ '~ :~¡ 'i i---;\~," (-r:;-") (:1' rl /-1 \ '" " : ì\W", ",' , I I' " I /.., !" "". , ,,11 ! 'I ,," 'I , ' \ ,.1 I t 'I '; '" j.f r "I" I U ') i:\ ¡ L\ \ '"",'\ Ii '~\ !:ù \ Ul~ \1 ,i j,;-) \ r\; .i 'I' \ j Ï'c 1\ I U L::::J:-J L\ '...::!.J wW ,::-.;, L\ / I J ,{ ./ / ,I ¡ .I / FRANK H. MURKOWSKI, GOVERNOR ATtA~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 \ --- í-Q ï if- Re: Middle Ground Shoal ST 17595 Sundry Number: 305-243 SCANNED F\UG 3 Ü 2005 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an , application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day follow·ng the date of this letter, or the next working day if the 23rd day falls, n holiday or weekend. A person may not appeal a Commission deci Ion perior Court unless rehearing has been requested. ' DATED thiS~ay of Augu&t, 2005 Enc!. ¡ ~ UNOCAL~ '.,- Alaska Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 August 23,2005 H;~ £- ,(""\\ En ,1-\ ,_ ~, " , .;,,~. \~>~ ~ vElD ÞUG 2 3 2005 Alaska Oil and Gas Conservation Commission Commission Chair John Norman 333 West th Avenue Anchorage, Alaska 99501 fq:;", ;,,, /')"1 8 ~-. C i'.,'-',-\llC; '.J!, '~G2S (HiS. Commission 0'; r't'-!~ /11 Þ·ioll.h"f3ge Re: Application for Well Plugging (Form 10-403) Baker Platform Well #08rd Dear Commissioner Norman, Attached for your approval is an application for plugging the perforations of Baker Well #08rd in the Middle Ground Shoal Unit. Unocal proposes to abandon the active water injection interval with cement and leave a 9.8 ppg kill fluid in the wellbore in accordance with AOGCC Regulation 20 MC 25.112(c). The production of oil and gas from the Middle Ground Shoal Tyonek A-G sands on the Baker Platform had previously been deemed uneconomic, and the Baker Platform was shut down in 2003. Since that time, the wells have remained shut-in. Evaluation for gas potential is ongoing in intervals above the Tyonek A-G sands, and the well bore may have future utility for gas production. Unocal proposes a phased abandonment program starting with plugging the perforated completion intervals. A pilot program has been initiated during the summer of 2005 to begin abandonment of up to 5 injectors and 3 producers. The intent of the trial zonal abandonment is to prove up a cost effective, tree-on abandonment program to be used on the remaining Baker Platform wells and Dillon Platform wells. Unocal intends to continue with the permitting of the eight (8) wells, and will continue execution of operations until freezing temperatures halt forward progress. The overall success of the abandonments and their effectiveness will be evaluated for the 2006 work program. Unocal commenced well diagnostic work on the Baker Platform in early July 2005. The reservoir pressures in the water leg of the reservoir exceed a water gradient with the highest recorded gradient being 9.6 ppg EMW. In addition to the injection interval being charged, we found two producers with pressures exceeding a water gradient. In light of this information, UNOCAL is communicating with ADEC regarding our Spill Contingency Plan and will also better secure the wells for the 2005 / 2006 winter. The Baker well #08rd attachments include: · 10-403 requesting plugging of the Tyonek Reservoir Sands A-G, · Procedure for plugging the perforations and pumping of kill fluids, · Summary of the Slickline Wells Diagnostics, Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com Commissioner John Norman, AOGCC August 23, 2005 Page 2 . Recent pressure and temperature profile showing confinement of fluids to the reservoir, . Current Well Schematic If you have any questions, please contact myself at 263-7657. For any technical questions on the 10-403, please or Mr. Steven Lambe @ 263-7637 or Mr. Gary Eller @ 263-7848. Sincerely, ~~ran1rg ~ Drilling Manager SSL/s Enclosure Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: 1. Type of Request: az¡. f~24';Ç)5' ( STATE OF ALASKA 0,05 ~f 1-.-( ~ AlAb~A Oil AND GAS CONSERVATION COMMì~SIÓN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1~\JaS¡(2 OJ;! & Gas Cor¡",', f'f!í':""";""';"'~'1 "'Ii' \...:T..)i! ~ 11'lll~I~,"'li~"~:' Operational shutdown U Perforate U Wai~f¡8:JG¡,sg(; Other U Plug Perforations 0 Stimulate D Time Extension D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Dri~umber: Development D Exploratory D 1770720 V Stratigraphic D Service 0 6. API Number: 50-733-1 0075-01-00 /" R" ¡r;:,,':'t "' LCEIVED k AUG 2 3 2005 'rsld-~ Suspend U Repair well D Pull Tubing D PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 79' 8. Property Designation: Baker Platform, Cook Inlet 11. Total Depth MD (ft): 9,250' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 6,138 to 7,622' Packers and SSSV Type: 9, Well Name and Number: MGS ST 17595; Baker-08RD 10. Field/Pools(s): MGS/B C AND DOlL; E F AND G OIL PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 9,082' Effective Depth MD (ft): 7,715' Plugs (measured): Junk (measured): 7,685' Collapse Effective Depth TVD (ft): 7,551' Length Size MD TVD Burst 818' 1,986' 20" 818' 1,986' 817' 1916' n/a 2730 psi n/a 1130 psi 13-3/8" 7801' 9-5/8" 7801' 7637' 2570 psi 3950 psi Perforation Depth TVD (ft): 5,981 to 7,458' Baker Model D Packer Tubing Size: Tubing Grade: 9.2# DSS Tubing MD (ft): 6,041' 3-1/2" Packers and SSSV MD (ft): 6049' MD 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for 8/26/2005 Date: 13. Well Class after proposed work: Exploratory D Development D Service 0 15. Well Status after proposed work: Oil D Gas D Plugged 0 Abandoned D WAG D GINJ D WINJ D WDSPL D Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steven Lambe 907-263-7637 Printed Name ,_"'_ _ T~othy C. Brandenbur~ Title Drilling Manager Signature ." (/ . ~,-,Á ~ hone 907-276-7600 Date <7 - 2: ., -05 f!:5.... /. ~ð - COMMISSION USE ONLY t) '-' Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 305'--.;l If.5 Plug Integrity ~ BOP Test D Mechanical Integrity Test D Location Clearance D Other: COf\.\(.,C\- T",,>?~ ,0t~~\t--..~ -.J\\:~C!:'SS\~ ~~S~W ~\-~~c::s (PPROVED BY ~ I5è\rJM)S~I@~~~, VHE COMMISS,ION , " ",Date: ~ /2; U r\ \ O-~ - '- f\A0 (' _,¡;:;"(], , . '2Jl,-L) ~ it in Duplicate Well Ba-8rd, Middle Ground Shoals Unit Plugging Procedure AFE 164486 Recent Well History: In July 2005, a gauge ring tagged fill at 7110' in well Ba-8rd, possibly on the cable of an e-line fish. A static BHP survey showed a 9.2 ppg formation gradient (3288 psi at 7100' MD, 6858' SSTVD), and the temperature survey showed no abnormalities. The highest perforation in well Ba-8rd is at 6138' MD (5575' TVD). The 3Y2" tubing has pressure integrity but the 9%" -::;!:"ì \>Q~\..<t\~ì~~ casing has a slow leak. There was no pressure increase on the 130/8" casing while \"'-\<è~'\~ pressure testing the 90/8" casing, so the leak in the 90/8" casing is assumed to be k~~( below the top of cement. Injection down the 3Y2" tubing was achieved at 2 bpm ~ 1(;( with ±1300 psi. ~ Objectives: 1. Isolate all hydrocarbon-bearing zones as per 20 AAC 25.112(c)(I)(C) 2. Test the cement plug to verify zonal isolation and 9%" casing integrity as per 20 AAC 25.112(g) 3. Fill the wellbore with kill-weight fluid as per 20 AAC 25.112(f) Procedure: 1. MIRV electric line on 3Y2" tubing. Pressure test lubricator and conduct pre-job safety meeting. RIH with tubing punches for 3Y2, 9.2 ppf tubing. Fire tubing punches at ±6000' MD while holding 500 psi on the tubing. POOH, RDMO e- line. '~ ~ 50 l O-~<.;:)"k. n\X:.. ~ '" ¡/i<IVV\. '6'1 '" ~ \-,\ 2. Rig up to circulate filtered Inlet water (FIW) down the tubing and pressure test to 3000 psi. Rig up to take returns off of the 90/8" casing. Pressure test returns line to 2500 psi. Calculated tubular volumes are as follows: a. 3Y2" tubing = 53 bbl b. 9%" casing below packer = 125 bbl c. 9%" x tubing annulus volume = 388 bbl 3. Circulate FIW down the tubing while taking returns up the 9%" casing following the Driller's Method. Formation pressure = 9.2 ppg EMW, so major losses are not expected while circulating FIW. When clean returns are established, shut in the 90/8" casing and establish an injection rate down the 3Y2" tubing. Do not allow the 90/8" casing pressure to exceed 2000 psi. ~ vo\0~\c. sv~",c..\Qf'..~ k-'t4f'l~(ò,-\ 4. Prepare to pump 157 bbl of 14.5 ppg cement to abandon all open perfs. This is sufficient volume to place cement from the PBTD (7715') to 500' above the highest perf (planned TOC = 5638'). Will blend cement on the fly. Will pump B-08rd Plugging Procedure August 22, 2005 Well Ba-8rd Well Plugging Procedure AFE 164486 Page 2 cement down the tubing while taking returns off the 9%" casing. Notify AOGCC with 24-hour notice of planned plugging operations. 5. Shut-in the 90/8" casing, begin bullheading cement down the tubing. Continue bull heading into the perfs until a total of 125 bbl of cement has exited the tubing (sufficient to fill the sump). The objective is to encourage cement across the entire perforated interval down to 7715'. Maximum allowable squeeze pressure on 90/8" casing = 2000 psi. If 90/8" casing pressure reaches 2000 psi during the squeeze, begin taking returns off the 90/8" casing but adjust the choke to maintain ±2000 psi back pressure. After squeezing 125 bbl of cement out the tubing tail, reopen the returns line and finish circulating the planned cement volume. Maintain a minimum of 300 psi on the 90/8" casing the entire job in order to maintain an overbalance on the perfs. Drop a wiper dart for 3Y2" tubing down the tubing and displace with 49 bbl FIW to 5638' MD. Strap the displacement tank to ensure an accurate displacement volume if the well is on vacuum during displacement. ßQsQ:~ D"-. ~\û.~\0(Y>\=" ~ I \.),,""-~\~ \0 ~\)\"'-\> ,~ ~ Ç/~ t\ Lú \. \ "--~ \ ceo.. k, ~ ~/;},-\ 6. Wait on cement a minimum of 12 hours. Wfiile waiting, do not equalize the tubing and 9%" casing. Instead, maintain a minimum of 300 psi on the 90/8" casing the entire time in order to prevent crossflow into the 90/8" casing leak. Monitor the tubing pressure but do not try to adjust. RD cementing equipment. ~ ~ \'......' LO~ ~~ xc> .Jé? C-¡ "~S~ ~>!- -: ~CL ?~~<tb'-\ Pressure test tubing and 90/8" casing to 1500 psi. Contact Project Manager if either of these fail to pressure test. Allow opportunity for AOGCC rep to witness the pressure test. MIRU electric line. Pressure test lubricator and conduct pre-job safety meeting. Rlli with tubing punches for 3Y2, 9.2 ppf tubing. Tag cement at ±5638'. PU 500' above previous tag and tie-in. Fire tubing punches while holding 500 psi on the tubing. POOH, RDMO e-line. 9. Blend 550 bbl of 9.8 ppg kill-weight NaCl brine. (Note: Requires 95 lbs of NaCl per barrel of fresh water. The freeze point of 9.8 ppg NaCl brine is 5° F.) 10. Circulate kill-weight brine down the tubing while taking returns up the 9%" casing. When kill-weight brine is returned, secure well, RDMO pumping equipment. 11. Pressure up the tubing and 90/8" casing to 1500 psi. While holding 1500 psi on the 90/8" casing, pump down the 13%" casing to verify communication with the 130/8" shoe. Monitor pressure on 20" conductor while pumping down 13%" casing. Maximum allowable pump pressure on the 130/8" casing = 1000 psi. Maximum allowable pressure on the 20" conductor = 300 psi. Freeze protect the 13%" casing by pumping 7 bbl of base oil into the 13%" casing. B-08rd Plugging Procedure August 22, 2005 Well Diaanostic Data Well #1 Ba-08RD IAPI# 150-73310075-01 IWell Class: ISpud Date: 8/21/1966 ICondition: Iwater Inj. Casing Top MD Top TVD Btm TD Btm TVD Wt Grade 70% Burst* 70% Collapse* TOC Structural 20" surface 616' 616' Surface Conductor Surface 13-3/8" surface 1986' 1916' Intermediate 9-5/8" surface 7801' 7637' 2000 sx Production Liner .. Based on weakest string Tubing Size Wt Grade 70% Burst* 70% Collapse* Btm TD Btm TVD MinlD Min Depth Long String (DDS HTC) 3-1/2" 9.2 N-80 (coated) 6067' 5506' Short String None Angle 26.5 Degs @ tail ~-.600_ . IKOBE MD TVD Size LS I Size SS I Below Cavity Test Bundle: Above Cavity ISlickline Tag MD TVD I Size I Test LS Only: 11450 psi for 15 min w/"W" circ pll Single string XO / Fish 6048' /7110' 2.70" /2.20" Test SS/Cavity: BHP PSI MD TVD PSI!FT BHT Deg. F I MD TVD 3288 7100 139.6 7100 Injection Rate PSI Testing Test Pressure start 250 Casing Age LS Test U 1/4 bpm 350 psi 1966 SS Test U 1/2 bpm 450 psi Tubing Age Casing Test ~ 1600 1600 V 625 in 30 min 3/4 bpm 600 psi 3/24/1985 1 bpm 750 psi 1.5 bpm 950 psi after bleed off 2.0 bpm 1200 psi 10 sec = 950 psi, 1 min 700 psi, 2 min 625 psi, 3 min 575 psi, 4 min 500 psi, Pressure SPPSI SITP (0) SITP (1 hr) SITP (3 hr) SITP (6 hr) SITP (12 hr) SITP (24 hr) SITP (48 hr) SITP (96 hr) Structural x Conductor Conductor x Surface 20" 70 gas zero zero 5 10 20 psi gas 60 PSI Gas 20 psi gas 60 psi gas Surface x Intermediate 13-3/8" 76 gas zero zero 5 10 10 psi gas 20 PSI Gas 80 PSI Gas 40 PSI Gas Production x Tubing 9-5/8" 100 gas zero no flow slite blow no reading 20 psi gas 40 psi gas 50 psi gas 50 psi 50 psi gas 50 psi gas after bleed off 7-17-05 Long String 300 water flowing @ zero psi 375/ water 375 / water 375 water 400 psi water 375 PSI Water 375 PSI Water 375 PSI Water AFE: xxxxxx last revised: 8/2312005 Thursday, August 23,2005 07 -06-05 07-07-05 07 -OS-05 07-17-05 07-1S-05 07-19-05 OS-19-05 Baker #Srd Summary Ba-Srd - Rig up Pollard with 2.70" gauge ring - Rill with same and tag 2Yg" cross over at 6,04S' rkb slm - Trip for 2.20" gauge ring - RIH with same noted weight loss at 7,110' rkb slm (DSM comment that could be wire on top of fish) - Trip for Pressure/Temperature tools Ba-Srd - Make up Pressure/Temperature tools - Survey in and out of hole at 60'/min - Max tool depth = 7,100' rkb slm (±6937' tvd) BlIP = 3,2SS psi at 1400 F, 9.1 ppg EMW - DSM comment a temperature abnormality at 6,274 & 5,769 rkb slm - Pressures during survey: 3Y2" DDS coated tubing = 300psi, 90/g" by 3Y2" = 90psi, 130/g" by 90/g" = 0 psi, & 20" by 130/g" = 10 psi - DSM comment that survey tools set down at 6,060' on way in hole & also hung the reentry guide on way out - Secure well move to Ba-7L BASrd - Rigged up lines to pressure test 90/g" by tubing annulus (Packer completion) - Starting pressures: tubing = 200psi, 90/g" by tubing = 100psi, 130/g" by 9%" = 50psi, & 20" by 13%" = 70psi - Pump 4bbl drill water down 90/g" annulus, pressure built to 1,600psi (tubing pressure built to 250psi, indicating compression of tubing string) - With pumps off casing pressure would bleed off to 750psi - Pressured up three times with same results - Final test to 1,500psi which bleed off to 635psi in 30min - Tubing pressure maintained at 200 to 250psi Ba-Srd - Rig to bleed down 90/g" by tubing annulus - Starting pressure = 75psi - Bleed pressure off - Pressure fell quickly to Opsi - Shut well in at lS:00hrs to monitor pressure - 9%" by tubing pressure = 40psi at 21 :OOhrs Ba-Srd - Pressure on 90/g" by tubing = 40psi at 05:00hrs - Injection test - Starting tubing pressure = 250psi - Injection pressures = 1I4bbl/min = 350psi, 1I2bbl/min = 350psi, 1I2bbl/min = 450psi, 3/4bbl/min = 600psi, 1bbl/min = 750psi, 1.5bbl/min = 950psi, 2bbl/min = 950psi. Pumps off pressures = 10sec= 950psi, 1min = 700psi, 2min = 625psi, 3min = 575psi, 4min = 500psi - Bled 20 by 13%" from 30psi to Opsi slight gas blow. Bled 13%" by 90/g" from 40psi to Opsi gas then water slight stream, 90/g" pressure was bleed off yesterday. Pressure today = 50psi, Shut in tubing pressure = 300psi - Strong flow to returns tank when we attempted bleed off holding 90psi on bleed off choke -Shut well in to monitor pressures Ba-Srd - Change out Swab Valve Ba-Srd: Pressure up on 90/g" casing to 1500 psi, took 2 bbl. Monitored for 5 minutes, pressure fell to 900 psi. Re-pressured to 1500 psi, fell to 10S0 psi in 10 minutes. Re-pressured, fell to 1250 psi in 15 minutes. Re- pressured, same result with pressure falling to 1250 psi in 5 minutes. Re- pressured one final time, pressure fell to 1050 psi after 45 minutes. Last { Baker Ba-8rd Summary Page 2 of2 20 minutes pressure was flat-lined at 1050 psi. Tubing pressure and 130/8" casing pressure remained constant while testing the 90/"8". Rig up to petform injectivity test down tubing. Pump down tubing at 2 bpm. Initial tubing pressure was 300 psi, 90/"8" = 60 psi, 130/8" = 175 psi, 20" = 80 psi. Max pressure seen on tubing = 1650 psi at 70 bbl away. Formation broke back and pressure fell to 1250 psi. Slowly increased to 1325 psi. Shur down after injecting 82 bbl. Never had any pressure increase on 90/"8" casing during injection test. Unocal II: B .8 Field: I B 07/07/2005 Pressure (psia) 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 0 Pressure -Temperature Profile 500 1. Going in hole TVD 2. Well Static 1000 1500 2000 2500 a.+ 3000 4) w = 3500 a+ Q d 0 4000 4500 5000 5500 600 650 700 50 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) Pressure — Perfs Temperature Report date: 8/23/2005 I ! - -3- - UIDDLE GROUND SHOAL ADL 17595 WElL NO. 8RD kENAI CONGlOMERATE PLttTFORU SAKER . 20" 81' CSA I,., ~ 1) ~.. 54.51 CSA. 118e' ~..:;-.,. ¡ "38" ~ :1 :!tIS 47.' fe.seo' ( ~ 888r fô 7030' ~ 72Ø«Y .. 5 . . ¿ PIer o.pth 32' 3r .ee' 1040' 8041' 1047' 104" lOti' 1061' Bakw NcHMI D _~t.Uoft ~"~. Comeron 10"' Nom ~ Donut hCIfttV 3 1/2" 8RD and ;J 112" ass :~d) ! .0 3 lIr 1.21 DSS ~ ( ) 3 tiT- ...21 DSS tubing (coated) 3 1/2" ass oM ) 112" 8uttnn xo (cootId) 3 112" IhatttM8 tubing pup (coated) s.oI loootor and 2 7/r and 3 112" XO SKI aHmbl1 Uu!uhoe Q. fUn ~) 1 1111/11 let 4. Slot 3 t. ,tI" FNl. 4'13' FWI.. Sea 31. TlN.ft'2W, SJL ~ to - 2000- FSl. 200' PWl. he 31. tIN, "'2W, SoU, ~ ~'~ & t250' 7. .. m~ ~ 20", Øf C~ Nt at It" -"".....nt to N'foce 13 ),11", S4.5f J-SS fJa.tn. Mt ot 'U6' wtth ant to lUfoce . 511". 40, 4J.S and 47' S-.S CaeInt Nt at 7101' with 2000 .. cefNnt 8: 1131-1150' D: 703O-7OM' 12'0-1210' 712Ð-noo- ~ !'; 7I0I-7iW 1352-1370' 14tt-C4W 1482-147r c: es8O-d10' 1150-1710- 1740-110O' II3O-IU2' r.-rttMnt ~ Spud Dote: SutfGoe locotIon: Suhurloce LKaUMI EWtoGtlon: Tt): PBD: Cutntt p~oratIont: ~ oJ;> -0 ~ BCD tated ,OOS ntar None ......... Ceo Perf tun. W long _. .. top at 1685' lo.t 12/17 . I:' 1808-1122' Gø Trocer toot 38' 101\9 _.> -, - ~ ,- 11/1 e ~ 1-7118 o.d. ~-. , '\ '\ , wI5OO' .205.rr. ~''/.,:.,\.\'''.I .... ~ " ~, ..t~~'~~ ,.,. ~.~ I¥ PBD 77'S' a..\~~.,::\:- I Nr 40, 43.5 10 1250' .,;.~ ~.: "..-';0.. a. 47' CSA 7801 , >C..~ " ,. , /r .-.... v:. ..-. '.-I /ì ô f.,;"'- '-t, /1 NOM None C)'ro and CSt. In!tIot Potenttar: Inltlaf stImuJaton: ~ Doto:.. Cored tnteNaft: DST InUn. and RuuIb: Lo, 1nwntory: ) -'~7!Æ~! c'} fÆ~fÆ~~~fÆ ) AT,ASIiA ORAND GAS CONSERVATION COMMISSION FRANKH. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker 1 "D11/ \1' Dear Mr. Cole: This letter confirms your conversation with C0111mission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place. for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be llbmitted forthwith. !:' smcer~~ . . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 SCANNEC NO\! 2 4 ¿DOL} Enel. STATE OF ALASKA ALASJOIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Lj Suspend Li Alter casing ❑ Repair well ❑ Change approved program ❑ Pull Tubing ❑ 2. Operator Name: Union Oil of California aka Unocal 3. Address: 909 West 9th Ave. Anchorage AK 99501 Operational shutdown H Perforate Lj Waiver U Annular Dispos. 17 Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Other 0 Perforate New Pool ❑ Re-enter Suspended Well ❑ Monitor Frequency 4. Current Well Class: 5. Permit to Drill Number: Development 2 Exploratory ❑ 1770720 Stratigraphic ❑ Service ❑ 6. API Number: 50-733-1007.5=01 7. KB Elevation (ft): 9. Well Name and Number: 79' Ba-08RD 8. Property Designation: 10. Field/Pools(s): BAKER MIDDLE GROUND SHOAL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): :' Plugs (measured): 9,250' 9,085' 7,715' 7,552'' Casing Length Size Structural Conductor Surface 616' 20" Intermediate 1986' 13-3/8" Production 7801' 9 5/8" Liner Perforation Depth MD (ft): 6138 to 7622' Perforation Depth TVD (ft): 5981 to 7459' Tu Packers and SSSV Type: Baker "D" pkr @ 6049' 12. Attachments: Description Summary of Proposal Detailed Operations Program ❑ BOP Sketch ❑ MD I ,," TVD I Burst 616' 616' 1,986' 1,916' 2,724 psi 7,801' 7,637' 6,822 psi bing Size: Tubing Grade: 1/2", 1 9.2# DDS Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory ❑ Development P] 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil Q Gas ❑ Plugged ❑ 16. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ Commission Representative: (measured): Collapse 1,128 psi 3,331 psi Tubing MD (ft): 6047' 17. 1 hereby certify that the foregoing is true and correct to the est of my knowledge. Contact Printed Namg� D Cole Title Oil Team Supervisor Signature i Phon 907-263-7805 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a Plug Integrity ❑ BOP Test ❑ (Other: Subsequent Form Required: tative may witness Sundry Number: ical Integrity Test ❑ Location Clearance ❑ ®MS Ivi'L, NOV 2 2 20��PLICATION RETURNED 11/17/0 NOT APPROVED BY COMMISSIO AL BY ORDER OF Approved by: 04,GINTHE COMMISSION Service ❑ Abandoned ❑ WDSPL ❑ 27 -Sep -2004 N R"ECEIVED OCT 12 2004 n. � Pka Oil & Gas Cans. Commission Anchorage Date: Form 10-4t#19evised 12/2003 Submit in Duplicate • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Suspend Lj Operation Shutdown Lj Perforate Lj WaiverLi Other Performed: Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Time Extension Change Approved Program ❑ Pull Tubing[—] Perforate New Pool ❑ Re-enter Suspended Well F-1 Shut in & secure 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development Q Exploratory❑ Stratigraphic❑ Service❑ 1770720 3. Address: 909 West 9th Ave. 6. API Number: Anchorage AK 99501 50-733-10075-01 7. KB Elevation (ft): 9. Well Name and Number: 79' Ba-08RD t 8. Property Designation: 10. Field/Pool(s): _ BAKER IAJ)L— 30 1 531-51 MIDDLE GROUND SHOAL C i 11. Present Well Condition Summary: Total Depth measured 9,250' feet Plugs (measured) true vertical 9,085' feet Junk (measured) Effective Depth measured 7,715' feeSCANNED i � a AFi ���� true vertical 7,552' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 616' 20 616' 616' Intermediate 1986' 13-3/8" 1,986' 1,916' 2,724 psi 1,128 psi Production 7801' 9 5/8" 7,801' 7,637' 6,822 psi 3,331 psi Liner Perforation depth: Measured depth: B: 6138-6150' 6210-6260' 6300-6330' 6352-6370' 6416-6440' 6462-6476'C: 6560-6610' 6650-6710'6740-6800' 6830-6882'D:7030-7084' 7120-7200'E:7608-7622, True Vertical depth: B: 5981-5993' 6053-6102' 6142-6171' 6193-6211' 6257-6280' 6302-6316' C: 6400-6449' 6489-6548' 6578-6638' 6668-6770' D: 6867-6921' 6957-7037' E: 7445-7459' Tubing: (size, grade, and measured depth) 3-1/2", 9.2#,DDS, @604T-- � F _ Packers and SSSV (type and measured depth) Baker "D" pkr @6049' 12. Stimulation or cement squeeze summary: Intervals treated (measured):on 8 "Oon 41 . ampo Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 230 325 Subsequent to operation: 0 0 160 on 10/05/03 250 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ 16. Well Status after proposed work: Daily Report of Well Operations Oi Gas ❑ WAG GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer Title Petroleum Engineer Signature Phone 263-7620 Date 07 Jun 2004 ntIC�MS MAY 2 9 2012 At1r) ( Form 10-404 Revised 12/2003 MIDDLE GROUND SHOAL ADL 17595 WELL NO. $RD KENAI CONGLOMERATE PLATFORM BAKER ferttnent Date: Completion Record Spud Datt: 11/11/7% Surface Looctlon: L 4. Slot 3 1. Cameron 10" Norm Single Donut hanger 1691• F 473' MSea 31, T9*I.R12W. S.M. 2. 3 1/2 SAD and 3 1/2 033 XO (coated) 3. 2 so 3 tri" 9.21 OSS pups (coated) Subsurface t ecatlons TD -- 2000' FSI, 200' 1<Wt„ Sec 31, T9N, R12W, S.M. 4. 3 1i2" 9.21 DSS tubing (coated) 3. 3 1/2" OSS and 3 1/2" Buttress XO (coated) Elevation: 73' KB 7. 33e1oI�Locator Bttd 2 7q"�arsa n) xo TD: 9230' S. Seal assembly PBDs 7713' 9. mWeshoe Casings 20". 89f Costng set at 616' with oement to surface 13 316". 54.51 .I-35 Casing set at 1936' with amt to surface 9 W. 40. 43.5 and 411 3-95 Coming set at 7501' with 2000 ox cement Perforallomr. B: 6136-6130' th 7030-7054' 6210-6260' 7120-7200' $300-6330' E. 7606-7422' 6352-637W 6416-4440' 6462-4476' C: 6560-6610• 6450-6710' 6740-6500' 6830-96821 Insttal Potenttol: BCD tested 10ox water Inwal Stlmulotlon: None Reservolr Data:. Coed intervals: None DST Intervals and Results: Nene Log Inventory. Cyr* and CBC. (As run 3/23/65) 1 Depth 4 32' 32' 4a' L 6040' 6041' 6047" 6049' 6066' 6061' Baker Model 0 Pkr 3 9 20" S9# CSA 616' L • 13 3/3" 34.5# CSA 1966• 3$'. e<76' • asso' 6882' 703W 7200' Coo Perf gun. 40' ton 4 • .. . top at 7685 lost 12/77 7606-7622' Coo Tracer tool 38' Iong 1-11/16 to •sf----- 1-7/1a o.d.' W/300' .203 wiry PBD 7715' 7D 9230' 3/8" 40. 43.5 470 CSA 7801' BAKER PLATFORM API # 50-733-10075-00 M G S ST. 17595 # 8 WELL HISTORY LAST WORK: ?/?/67 Date Work Performed 1966 8-21-66 Spud from slot 3, Leg 4, Pan Am MGS Platform B: 2041' FNL,522' FWL Sec. 31, T9N, R12W, SM 10-20 Cored 8458-8479 (Sandstone). 10-21 Dst #1 8285-8619 I H P 4121 ISI 432 FSI 288 IF 240 FF 288 FHP 4028 TO 5 Min, TC 3 0 mi n, TO 18 hr. 30 min, TC 60 min. Recovered 120' water cushion and 12 bbl mud, no show of oil or gas 10/28 Cored 9450-9479 1/2 (sands tone) 11/6 Cored 10183-10213 (Sandstone) TD 10314 11-8 Set retainer 8280 w/75 sk cmt below and 25 sk; above 11-9 Drilled out cement to 8250. Bot. 9-5/8" - 8350 11-11 Drilling rig released 12-15 Perf. 7485-7490 and 7415-7420 w/2 SPF Tested Zone C (See summary completion) Recovered 3000' oily, gas -cut emulsified -mud and 4000' oily, gas -cut emulsified water. 12-19 Frac w/30,000 gal sand -water 12-20 / 12-22See "Summary of Completion: C Zone 12-23 Squeezed perfs. 7485-7490 and 7415-7420 w/200 sks. Perforated 7408-7213 w/4 SPF. No flow Re -perforated 7208-7213 w/4 SPF. Could not pump in at 5000 psi. 12/25 Opened for flow after reperforating. No recovery. Pumped 8 bbl diesel @4-3/4 BPM @4800 psi. Shut in 15 min. Estimated recovered 32 BLO after 45 hrs. Did not recover 28 BLO. No crude or water shows. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 8 (continued) 12/26 Flow tested perfs from 7208-7213. Recovered 35 BLO in 50 hrs. Cemented perfs 7208- 7213 w/100 sks cmt. Displaced cmt. to 7110. Perforated 6950-6955 w/4 SPF. 12-27 No flow 12/28 Perforated 6943-6948 w/4 SPF Flowed small stream diesel for 12 hrs. Reperforated 6945- 6955 w/4 SPF. Flowed small stream diesel 12/29 Reperforated 6945-6955 w/4 SPF Pumped in diesel at 50 BPM @3500 psi . Opened for flow. Flowed small stream of diesel. 12-30 Fraced perforations 6945-6955"w/6214 gal acid and water @9 BPM and 4800 psi, followed w/4000', 10-20 sand and 4800# 10-20 nut hulls. AIR 8.5 BPM @4500 psi. Flowing well after frac 1967 1-2-67 Flowed 240 bbl water in 35 hrs. Dead for 2 hrs. Reversed 51 bbl water no show of oil or gas. Squeezed perfs w/200 sk cmt. Drilled out cm. and plug to 7316' . Set bridge plug 7275 capped w/5 sks cmt. 1-3 Perforated 7200-7240 w/4 SPF. Gas to surface in 45 min. 1-5 Tested perfs for 60 hrs. Reversed out 540' of oil 4100' of water. Oil 37.941+ API. Well dead. 1-6 Stimulated perfs w/1000 gal acid 500 bbl diesel and W-26. AIR 9 BPM @5700 psi. Flowed 16 hrs. recovered 129 bbl of fluid. Recovered 9 bbl oil last 6 hrs. 1-8 Tested perfs 50 1/2 hrs. Recovered 66 bbl water, 50 bbl load oil. Dead last 12 hrs. of test. Reversed out 25 bbl oil and 33 bbl of water. Fraced w/18500 gal diesel, W-26 and acid, w/2000# 10-20 sand and 1950# 12-50 nut hulls. AIR 9 BPM @6000 psi. 1-9 Shut in 5 hrs. On test 15 hrs. Produced 46 bbl fluid. 1-10 Tested 15 1/2 hrs. Produced 17.7 bbl fluid. 1-11 Flow test 4 hrs. 3 BO. Set bridge plug 6700'. 1-23 Perforated 6610-6624' w/4SPF - strong to faint blow in 49 hrs. 1-24 No fluid to surface in 26 hrs. Reversed out 3 bbl mud and 46 bbl fresh water w/no oil or gas. • • 1-25 Set bridge plug @6505'. Perforated 6380-6410' w/4SPF. Gas to surface in 5 min. No fluid to surface. 1-26 Open 24 hrs. Gas blow. No fluid to surface. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 8 (continued) 1-27 Diesel oil and acid frac w/19,106 gal AIR 9 BPM @ 4,500 psi. Tested 39 hrs. Reversed out 220 bbl fluid - last 8 hrs. 5% BSW, 90% water. 1-29 Set retrievable bridge plug @ 6,300'. Perforated 6,160-6,175'W/4 SPF - 1 -31 Tested 23 hrs. w/weak blow gas to surface. No fluid to surface. 2-2 Recovered retrievable bridge plug. 2-3 Set bridge plug at 6,098' w/15 sk cmt above. Laid down drill pipe. 06/30/03 Pump circulated out of well. All casing and tubing valves closed; pipe connections removed and blind flanges installed. Gauges installed to monitor pressures. Ll Pertinent Data: Spud Date: Surface Location: Subsurface Location: Elevation: Total Depth: Plug Back Depth: Casing: Initial Potential: Initial Stimulation: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 8 U • Perforation Record: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 8 Date Zone Interval 0 Reservoir Data: Zone Depths: Cored Intervals: DST Intervals and Results: Selective Tests: Log Inventory: MIDDLE GROUND SHOAL ADL 17595 WELL NO.8 (Continued) Unocal Corporation Alaska Business Unit 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) October 15,2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Baker Shut-in Injector, B-8RD Dear Tom: This letter is to document your approval to continue the variance on Baker-8RD. B-8RD is a shut-in injector and there is currently no plan to inject into this well. In the future, should the decision be made to return this well to service, Unocal will rerun the tests at normal operating pressures and submit the test for AOGCC approval at that time. A pressure monitor procedure was completed on 10/14/01 in order to demonstrate tubing / packer integrity. · The casing, outer casing and tubing pressures were monitored for three (3) consecutive days. · The 9-5/8" casing pressure was increased by 200 psi. · The casing, outer casing and tubing pressures were monitored for an additional four (4) more consecutive days. The result of the pressure monitoring indicates there is tubing / packer integrity isolating the tubing from the annulus. The results do substantiate minor casing failures which were first documented in May 1992 but no safety risk or risk to hydrocarbon reservoirs or fresh water aquifers. See attachments. Attached is a sundry form 10-403 for your approval. RECEIVED V~ff:is(opheffA. Ruff /:~laska 0il & Gas Con~ Com~'*s~,', ~ ~qnchorao~ Senior Reservoir Engineer Cook Inlet Waterflood Management O:XAOGCC\CorrespondencesL4,ogcc B-8RD 10-15-01 MIT.doc Jeff Dolan STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: __ Time extension: ~ Stimulate: __ Change approved program: Pull tubing: Variance: x Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 79' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: MGS STATE 17595 P.O. Box 196247 Anchorage, AK 99519 - 6247 Service: x 4. Location of well at surface 8. Well number 1991' FNL & 473' FWL, SEC. 31, TDN, R12W, SM 8RD At top of productive interval 9. Permit number Top of "B" sand @ 6205' MD, 2168' FSL & 200' FWL, SEC 31, TDN, R12W, SM 1770720 At effective depth 10. APl number PBD @7715' MD, 2057' FSL & 193' FWL, SEC. 31, TDN, R12W, SM 50-73310075-01 At total depth 11. Field/Pool TD @ 9250' MD,1965' FSL & 240' F--WL, SEC 31, TDN, R12W, SM MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured 9252' feet Plugs (measured) true vertical 9085' feet Effective depth: measured 7715' feet Plugs (measured) true vertical 7552' feet Casing Length Size Cemented Measured depth True vertical depth Structural 616' 20" yes 616' 616' Conductor Surface 1986' 13-3/8" yes 1986' 1916' Intermediate 7801' 9-5/8" 2000 sxs 7801' 7637' Production Liner Perforation depth: measured B: 6138-6150' 6210-6260' 6300-6330' 6352-6370' 6416-6440' 6462-6476' C: 6560-6610' 6650-6710' 6740-6800' 6830-6882' D: 7030-7084' 7120-7200' E: 7608-7622' true vertical B: 5981-5993' 6053-6102' 6142-6171' 6193-6211' 6257-6280' 6302-6316' ECEIVED C: 6400-6449' 6489-6548' 6578-6638' 6668-6770' D: 6867-6921' 6957-7037' E:7445-7459' ~E~' .~ ~ 2001 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, bBS, @ 6047 Alaska 0il & Gas Cons. C0maJssi0p Packers and SSSV (type and measured depth) Anchorage Baker "D" pkr @ 6049' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: __ Supporting Documentation: X 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service:X Waterflood Injection 17. I hereby certify~~,d correct to the best of my knowledge.__. /O/ 5/07, Signed: Title: Reservoir Engineer Date: '"" -~-----~' FOR COMMISSION USE ONLY ~ · Conditions of approval: Notify Commission so representative may witnessIIAppr°val No. ~F,~ Plug integrity.__ BOP T~-st__ Location clearance -,~,- ~ ~ Mechanical Integrity Test'~ ;;~i-I Subsequent form required 10- OriginalSigned By Approved by order of the Commissioner"uammy 0echsli Commissioner Date ,~/c~ -7 / ("~ OCT 15 ~1 04:~0~M · ProcedUre.for Baker_Plafform MIT _on_B_a~8_Shut,!n Iniector , ', C Record daily tubing, casing, and outer aslng pressures for a consecutive three day period. Increase casing pressure by 200 psi. Continue recording daily tubing, casing, and outer casing pressures for an additional, consecutive, four. day period. ~:"' .- '~ ....... ', Ba,8RD ~illtJj. --";:' -, ,'-' MG$ ST 17595 08RD ~i'~' :" , ," '-.. 507331007501 ~'~.-'~.' ' ...:~ ' !1770720, II I III_ ] I Pressures Rc~orded By: /,///C ~.~./.__.._~, procedure for MIT_on Baker Injector B-8 1. Record daily casing, outer casing and tubing pressures for a consecutive three day period. 2. decrease 9-5/8" casing pressure by 200 psi. Continue recording daily casing, outer casing and tubing pressures for a consecutive four day period or until casing pressure stabilizes. .. 3. Fax completed form to Steve Tyler, fax # 263-7874, phone # 263-7649 _Date Tb9 Pressure9,518".,C. sg Pressure .. 13-3/8" Cs9 Pressure _(/-/~-~7 .,5/ 0.~ ~. op , ., .- I ~z..~ .... /1-17-q7Z./O0 3.~0 1~5" -- ~ ,q . ..,. ,,, ,,, _- m ,~ , , ~,_, . ,., /I-'~,o'-'~7!~i o o ~__ __/i q a ,, , ,, i , /~ ' ~'~! ..5/~ o ........ It. ~,~1 ~ 0 O Q,, , ~ ' .... _ ...... i ,, , "~*-~. , , , .,.-~--. i - _~ · ,, i. . . I Dale · I~LL :? · jr& _,. ~)IJBING ilLIECIlON FLUID= iqiODUCE I~ATER IN~ SALT I~IER IIISCIBLE INJEC. IiO~i INJECI'IitG IIOT JIIJECIIIIG · C.?Q6 {rev g5/I0/~0]1 7o~____L S 1ZE/II[I~IlJII~ I~E~EST IOG PIIF. SS '2; ' _~oqo FLUID: DIESEL CLYCOL SALT WATEI: DRILLJNG ItUO OlHER OIHER GRADIEeiT: WELL 1EST-. Initial /~"~ _l soo ~-year / Al]GCC Ii'lilt,ES5 $1(JiATI~E Ci~PAHY REP S I [;NATURE Vorkovcr Eapl a'la -. ( ts8 .o~ ~p*o 0L/£-t I Ot/t t-t o4JOl .OC ~ Jmoo4A e4~oJ ,0t *ur,6 J.~d os0 · qd Q laPOl~ ~ ,Z, O0O .et, OS ,0t0$ .OOF, Z,-*O~ t/. ,0 tS0-'00;0 ::3 .om~m-otzm eoo~,ns o~ lam~JOO q~a .It0 lo 1N D"pD3 l~6g '..0~ /././t tit t · .Am~uk~ 6o~ mloAJo~ut =lOl~J~Qd iOi~ui ~ Uqq:lGJOJ,,,Imd :6uteo:) :4Md :GL :u91~o~13 tuoRo3o'I iQoj, Jneqn$ :UOl~k~O~ MN,ms :~IoO pnds b'3NVE rlaO~LYld ~LVU.qriO'lONO:) IVN3)i 'ON '1'1~ ;6;~. t qaV qYOHS ONtlO~lO 3'lC~Olrl Unocal AlasKa Resourc. · Jnocal Comorauon 309 West 9th Avenue. F.O. Box ~ 96247 :.ncnoraae. AlasKa 995 ! 9-6247 -eie[:)none ~907~ LINGC L January 23, 1998 Blair Wondzell State of AlasKa Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status and Plans for MIT testing of Cook Inlet Injection Wells Dear Blair: Thank you for your assistance in helping us complete our mechanical integrity testing of water injectors in the Cook Inlet Area. The following is a status of our efforts to date. We also request a time extension for a group of wells listed below to allow us to complete testing work. We request a time extension for completing MIT testing on the following wells until the end of March 1998: Currently shut-in wells Granite Point Field Anna 19-42 Anna 27-42 Anna 46-42 _r~.~nlt~ n.,~,., D~.,,~.-.-... Well 33-14RD Middle Ground Shoal Field Baker #4 Baker #9 Currently injecting wells Tradinq Bay Field Monopod Platform A-8RD2 Wells Needing Repair The shut-in MIT on Bruce Platform Well. # 31-42 indicated a problem with the temporary abandonment which was completed on 10/7/88. We will develop and send to you a procedure for repairing or permanently abandoning this well. An MIT on shut-in Granite Point Platform Well. # 33-14 indicated a mechanical problem with this well. We will develop and send to you a procedure for repairing or permanently abandoning this well. We also want to confirm your receipt and approval of the following shut-in MIT tests. For our records, please sign and return a copy of the following shut-in MIT tests: Baker #8 ¢ Baker #12 6 ~ Monopod A-5R czar' Monopod A-12R2 1'¢--~8-° Monopod A-26 ~e,~ Monopod A-29 ,~ ~t.~ Please indicate your approval of the shut-in tests and the time extension requested by signing and returning a copy of this letter. Thanks again for your help in this matter. Sincerely, etanka Reservoir Engineer Agreed to by: Blair Wondzell ~/' Petroleum Engineer AOGCC W. (3. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 March 28, 1985 File: TJZ-IO1-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Noti ce Middle Ground Shoal 17595 Well No. 8RD Platform Baker, Cook Inlet, Alaska Attached in duplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of work recently completed on MGS 17595 Well No. 8RD. This workover successfully eliminated communication from the zone of injection to the annulus. Any questions concerning this project may be directed to Jeff Blagg at 272-8471. Very truly yours, District Manager Attachments JCB/dds STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Amoco Production Company 77-72 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 50- 733-10075 OTHER [] 4. Location of Well Leg 4, Slot 3, MGS Platform Baker 1,991' FNL, 473' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 74.4' KB-MSL 6. Lease Designation and Serial No. ADL 17595 9. Unit or Lease Name MGS 10. Well Number 8RD 11. Field and Pool Middle Ground Shoal 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stim u lat ion Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form'10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Commencing on March 19, 1985 and ending on March 25, 1985, Amoco Production Company' 1. Nippled down tree, nippled up BOP's and tested. 2. Pulled tubing string. 3. Landed new tubing string into packer at 6,030 feet and found annulus communication. 4. Pulled tubing string, milled and retrieved packer at 6,030 feet. 5. Ran retrievable packer to 6,050 feet and pressure tested annulus. Tested OK. 6. Set permanent packer at 6,047 feet. 7. Landed new tubing string into packer at 6,047 feet. 8. Inhibited annulus. 9. Nippled down BOP's, nippled up tree and tested. 10. Returned well to injection. 14. I hereby certify that the fore~oing is~rue and correct to the best of my knowledge. Signed ..... Title District Manager The space below for Commission use Date03/28/85 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date ............ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager March 8, 1985 Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 File: TJZ-O83-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir- Notice of Intent Middle Ground Shoal 17595 Well No. 8RD Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to pull tubing, run new tubing, and return the well to injection. There currently exists communication between the zones of injection and the annulus which we hope to repair by replacing the tubular goods in the well. This work should begin by mid-March 1985. Any questions concerning this project may be directed to Jeff Blagg at 272-8471. Very truly yours, .. ,-',,? ~. ~. Smith Di strict Manager Attachments JCB/jmm RECEIVED Alaska 011 & d~ uo~is, Oommissio~ Anchorage STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL J~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 77-72 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 5o- 733-10075 9. Unit or Lease Name Middle Ground Shoal 4. Location of Well Leg 4, Slot 3, MGS Platform Baker 1,991' FNL, 473' FWL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' KB-MSL 12. 31, T9N, R12W, S.M. I 6 . Lease Designation and Serial No. ADL 17595 10. Well Number 8RD 11. Field and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well J~ Change Plans [] Repairs Made [] Other [] Pull Tubing ,~' Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to: 1. Set back-pressure valves, nipple down tree, nipple up BOP's and test, pull back-pressure valves. 2. Pull single string water injection tubing. 3. Run new single string water injection tubing. 4. Set back-pressure valves, nipple down BOP's, nipple up tree and test, pull back-pressure valves. 5. Return well to injection. Well No. 8RD has recently developed communication to the annulus which is believed to be caused by a tubing leak. Form No~ ~ D&t~ R CEIVED 14. ~ hereby~f reg~lo ~s~true~c rtifythatt foreg ' is true an orrect to the best of my knowledge. S i g n ed ~~/~~~~_,,-7-~ ~ Title District Manager The space below for Commission use eat~03/08/85 Conditions of Approval, if any: Approved by COMMISSIONER Approved Coq3y Returned .5'; / 9-/5. By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow Area Superintendent September 7, 1978. File: LAD-856-WF Mr. Hoyle H. Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Hr. Hamilton: Subsequent Report MGS 17595 Well No. 8 Redrill Platform Baker~ Cook Inlet~ Alaska Attached in duplicate for your approval is State of Alaska Form No. 10-403. This is a subsequent report of the procedure which was used to convert the subject well to a water injector in the "BCD" zone. Yours very truly, L. A. Darsow Area Superintendent Attachments DRR:sls ,'o,,~7;/~ 6o0,%,, ..,e;&/; Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL Water injection well ~ NAME OF OPERATOR Amoco Production Compan7 3. ADDRESSOFOPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 4, Slot 3, MGS Platform Baker 1991' FNL, 473' ~/L, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 79.4' KB-MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re :5. APl NUMERICAL CODE 50-133-10075-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME MGS 17595 9. WELL NO. 8 (Redrill) 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31~ T9N, R12W, S.M. 12. PERMIT NO. }ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF fRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (other) Convert to water injection (NOTE,' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all i~ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. Operations commenced on 7-18-78 to convert the subject well to a "BCD" zone water injector. ConverSion procedure was as follows: l. 2. 3. 4. 5. Killedwell with treated Inlet water. Cleaned out to 7669'. Set Baker Model "D" packer at 6033'. Ran 3-1/2" tubing to 6033', Hydrotested to'6000 psi. Shut well in from 7-25-78 to'8-7-78 to hook up injection lines. Currently injecting 2000 BWPD at 1600 psi. 16. I hereby certify that the foregoing is true and correct TITLE Area Superintendent DATE _September 7, 1978 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form N0~ 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL Leg 4, Slot 3, MGS Baker 1991 FNL, 473'FWL, Sec. 31, T 9 N, R12W, S.M. 5. APl NUMERICAL CODE ~ 50-28~3-20908-°~y- 6. LEASE DESIGNATION AND SERIA ADL-17595 7. IF INDIAN'ALOTTEE OR TRIBE N~ 8. UNIT FARM OR LEASE NAME 9. WELL NO. 8 Redrill Middle Ground S~al 11. SEC. T. R. M. (BOTTOM HOLE 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED tlOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Workover to Convert ~,o, ...Wa.t. er..Injection Service Status as of: 7-18-78 PBTD 7715 Rig move on 0601 hrs. 7-20 PBTD 7715 Cut short string tubing at 6017. 7-21 PBTD 7715 Tag fill at 6613 clean out TO 6835. 7-24 PBTD 7715 Mill tight spot @ 6835 clean out TO 7669 tag perf. gun lost in hole 12-30-77. Set Baker Model "D" Packer at 6033' Rig Released at 1200 hrs. 7-25 Thru 7-31 PBTD 7715 Waiting on injector control valve. 14. I hereby certify that the foregoing is true an $IGNEDL. A. Darsow, by: ntendent DATE.AUgust 14, 1978 NOTE-Report on this' form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. L. A. Darsow Area Superintendent June 29, 1978 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 File: LAD-651-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Notice of Intent MGS 17595 Well No. 8 Redrill Platform Baker Cook Inlet~ Alaska' Attached for your approval is State of Alaska Form No. 10-403 in triplicate. We plan to convert the subject well for water injection in the B, C, and D zones. Very truly yours, L. A. Darsow Area Superintendent Attachment DRR: sls Form 1(~403 REV. 1-1(%73 Submit *'Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to de. Den Use "APPLICATION FOR PERMIT---" for such proposals.) 1. OWIELL L ~] GAS F--] OTHER WELL 2. NAME OF OPERATOR Amoco Production Company 5. APl NUMERICAL CODE 50-133-10075-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME MOS 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 779, Anchorage, Alaska 99510 8 (Redrill) 4. LOCATION OF WELL At surface Leg 4, Slot 3, MGS Platform Baker 1991' F~L, 473' ~gL, Sec. 31, TgN, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 79.4' KB-MSL Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO.- FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS _ (Other) Convert to water injection SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The subject well was completed on the West flank of the ~ddle Ground Shoal Structure in January 1978, and failed to establish commercial oil production. We, therefore, plan to convert the well for water injection in the B, C, and D zones. The conversion procedure is as follows: 2. 3. 4. . Administrative Approval No. 44.32 granted June 19, 1978. Skid rig and kill well. Set back pressure valves, nipple down tree and nipple up BOP. Pull dual tubing strings and Kobe BRA. Clean-out to 7715' (PBTD), circulate hole with inhibited fluid and set packer at 6020'. Run 3-1/2" tubing with Atlas-Bradford couplings. Nipple down BOP, nipple up tree and hook up surface injection 16. I hereby certify that the foregoing is true and correct TITLE L. A. Darsow Area Superintendent DATE (This space for State office use) CONDITIONS OF APPROVAL, IF ANY.- ~z/ Petroleum Engineer See Instructions On Reverse Side DATE July 3, 1978 .lAY S. t~fAI'LMON£, GOVERttO,? 3ooi PO£CliPINE ORIV£--ANCHORAGE 99501 ALASKA OIL AND C~AS CONSERVATION CC~9,~ITTEE June 19, 1978 ADMINISTRATIVE APPROVAL NO. 44.32 Conversion of~ MGS 17595 Well No. 8,.'Redrill in the Middle Ground Shoal Field t'~"'~j~'dtion servia, Mr. L. A. Darsow Area Superintendent Amoco Production Company P. O. Box 779 Anchorage, A]aska 995!0 Dear Sir: On June 15, 1978, Amoco Production Company applied for administrative approval to perform the referenced operation pursuant .to Rule 6 (d) of Conservation Order No. 44. ~nis operation is designed to utilize a well on the west flsnk of the Middle Ground Shoal Structure that failed to establish commercial production in MGS Pools B, C and D. The Oil and Gas Conservation Committee hereby authorizes the referenced operation. Very truly yours ..-~.....-'~' ,p' ....<,.:-,-- June 15, 1978 O. K. Gilbreth, Jr., Director (4) Division_of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Companyr__~ .... Security Life Building Denver, Colorado 80202 ~ (. File: RAS-535-986. 511 Application for Conversion ~11 No~. 8 RD~to Inject±on, Rule 6 (a) of Conservat±on 0rde~ o. - - ' Middle Ground Shoal Yield .Amoco Production Company requests that administrative approval be granted for the conversion of MGS Well No. 8 RD to injection service in MGS Pools B, C and D. The well, located as shown on the attached plat, was a redrill on the west flank of the structure that failed to establish commercial oil production in MGS Pools B, C and D. Pertinent information on the casing strings in MGS Well No. 8 RD are: Surface string: 13 3/8" set at 1986' and cemented with 1200 sacks. Production string: 9 5/8" set at 7801' and cemented with 2000 sacks. It is contemplated that up to 3000 BWPD will be injected at MGS Well No. 8 RD at a maximum wellhead pressure of 4000 psia. MGS Well No. 8 RD is operated by Amoco on behalf of itself, Phillips, Getty, Arco, and Chevron. The only affected other operator is Shell for itself and as a representative for its working interest partners. By this mailing, we ask that Shell sign in the space provided below 3 copies of this letter application indicating it has no objection to this requested application, sending one signed copy to you, returning one to me, and retaining the third copy for its own needs. Enclosures O. K. Gilbreth, Jr. Page two cc: p. j. Carroll (3) Shell Oil Company P. O. Box 831 Houston, ~TX 77001 j. p. Denny Phillips Petroleum Company 1300 Security Life Building Denver, CO 80202 J. W. Hart Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Walter J. Newman Getty Oil Company Three Park Central, Suite 700 1515 Arapahoe Street Denver, CO 80202 C. F. Kirkwold Chevron USA, Inc. P. O. Box 7839 Anchorage, Alaska 99510 The undersigned has no objection to the conversion by Amoco of its MGS Well No. 8 RD to injection service in MGS Pools B, C and D. Shell Oil Company By: Date: VERIFICATION AND AFFIDAVIT STATE OF COLORADO COUNTY OF DENVER ) : SS ) R. B. Giles, of lawful age, being first duly sworn on his oath, deposes and says: That he is employed in an engineering capacity by Amoco Production Company in its Denver, Colorado office; that he has been qualified as an expert engineering witness by the Alaska Conservation Committee and his qualifications have been made of record; that he has testified numerous times before the Alaska Conservation Committee on pressure maintenance or secondary recovery operations; that Amoco's application for approval to convert its MGS Well No. 8 RD to injection service in the MGS Pools B, C and D in Middle Ground Shoal Field in accordance with Rule 6 (a) of Conservation Order No. 44, was prepared under his direction and super- vision; that the matters and things therein set forth are true and correct to the best of his knowledge and beliefs; and that a copy thereof was sent by certified mail from Applicant's Denver, Colorado office on June 15, 1978 to the following operator, at the address shown herein, to wit: P. J. Carroll Shell Oil Company P. O. Box 831 Houston, Texas 77001 and to the best of his information, knowledge and belief, the operator above named is the only operator to whom notice of such application is required to be given in accordance with Rule 6 of Middle Ground Shoal Conservation Order No. 44. ~¢ ~bs~r'~ed and sworn to before me this 15th day of June, 1978. My ~~sion expires: - . NOTARY PUBLIC R 13W k14 R12W 30 LEGEND · BCD PRODUCER A BCD INJECTOR A PROPOSED BCD INJECTOR --====- LEASE LINE DRY HOLE T 05 PLATFORM BAKER 31 7 A 11-1 CHAK ADL 17595 . _ ,~ 12 $.A.S. PORTION MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA T. L. A. Darsow Area Super ntendent February 20, 1978 File: LAD-i98-WF Amoco Production Company P.O. Box 779 ' Anchorage, Alaska 99510 Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Street Anchorage, Alaska 99501 Dear Sir: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 8 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 8 for the month of January 1978. Very truly yours, ~.~:~..~..,. .... / L. A. Darsow Area Superintendent Attachment DMS:mls SUBMIT IN DUPLICATE For.~q No. P-4 ~ REV. 3-*1 -~70 ~ ' STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-10075 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEAS['] NAME Amoco Production. Company MGS 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, AK. 99510 8 (redrill) 4. LOCATION OF WELL Leg 4, Slot 3, ~GS Platform Baker, 1991' FNL, 473' FWL, Section 31, T9N, R12W, S. M. 10. FIELD AND POOL, OR WIL~AT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 77-72 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN ttOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of January 1, 1978 TD: January 2 TD: January 3-5 TD: January 6 TD: January 7-10 TD: January 11-12 TD: January 13-31 TD: Status as of February 1, 1978 TD: 7715' 7715' 7715' 7715' 7715' 7715' 7715' 7715' Testing Testing Pump NG Pull Pump Circ. Well Pump NG Well SI Well completed 2/1/78 as an unsuccessful recomplete due to high WOR. 14. I hereby ce.rtifg that :th~q~s~true and correct ~ /~,- ~-"'~ Area Superintendent DATE 2/20/78 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. L. A. Darsow Area Superintendent February 14, 1978 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 File: LAD-174-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Dear Sir: Completion Report MGS 17595 Well No. 8 Redrill Platform Baker Attached is your Form P-7 in duplicate for the completion of drilling MGS 17595 Well No. 8RD. Also attached is a copy of the chronological history and the directional survey on this well. The open hole logs have previously been forwarded to your office. This well was originally intended to be a "G" zone producer. However, when the "G" zone was not encountered during drilling, it was desired to attempt completion of the well in the upper "BCDE" Sands. This change in the completion procedure was reviewed by our Messrs. G. R. McGregor and J. D. McElhaney in your office on December 21, 1977. State approval to proceed with the "BCDE" completion was given at that meeting. Very truly yours, L. A. Darsow Area Superintendent Attachments JDM :mls ?'ora P--7 SUBMIT IN DUI~A~ATE* STATE OF ALASKA (se,, other M ructions on reverse shit, OIL AND GAS CONSERVATION COMMITTEE II i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW [] WORK OVER ~1 %VELL WELL WELL EN BACK P. ESVR. 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, AK 99510 Other __ Recompletion by Other Sidetracking 4, LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurface Leg 4, Slot 3, MGS Platform Baker, 1991' FNL, 473' n. SEC..T..a.,M..¢BOTVOMaO~ FWL, Section 31, T9N, R12W, S.M. om~,crivz~ At top prod. interval reported below 2189' FSL, 186' FWL, Section 31, T9N, R12W, S.M. At total depth2060, FSL, 173' FWL, Section 31, T9N, R12W, S.M. 12. PEI:I~I'F I~O. at PBTD 77-72 18. TOfFAL D~I:~i'I-I, ~ & TVD~19. PLUG, BA~CK MD & "l'q/~. I.~ 1VfULTIPLE CO1VLPL., 21. INTERVAI,S DRH~LED BY / / I-~OWiVI../~Y* ROT~ARY T00LR [ CABI,E TOOLS 9250' MD 9082'TVD1 7715'MD 7551'TVD1 -- O-TD 22. PRODUCING !NTE2RVAL(S), OF THIS-COMPI_AgTIO~NI--q~OP, BOTTOM, lgAME (MD AND TVD)* ! 23. SVAS DIRECTIONAL ~ SUHVE¥ MADE 6138 - 7622' MD ! Yes Middle Kenai "BcDE" Sand 5981 - 7459' TVD 5. API NUiq~A~ICAL CODE 50-133-10075-01 6. LEASE DESIGNATION A2XlD SERIAL NO. ADL 17595 7.IF INDIA.N, A.LLOTTEE OR TI~iBE NA.M.E '8. UNIT,F/LILM OR LEASE NAME MGS 17595 9. WELL NO. 8 (Redrill) 10. FIELD A/~D POOL, OR wILDCAT Middle Ground Shoal Sec. 31, T9N, R12W, S. M. 24. TYPE ELECTRIC AND OTHEi% LOGS RUN DIL-SP, BHCS-GR, Dipmeter Il Il ! Il I Il [I ~5. CASING RECORD (Report all strings set in well) 20" 89 / B I 616' 26" I To surface (previously s4t) 13-3/8" 54.5 J-55 1~98,6' 17-1/2" To surface (previously s t) 9-5/8" From old well 9-5/8" 40'43'5'47l S-9S i 7,89z' 12-i/4",[2000 sx. Class "O" , 26. LINE~ lv~ECO!P~D 27, 'rUB~G RECOrd) ~8. PERORATIONS OP~ TO PRODUCES ' (interval, size and number) 29. 'ACID, Si]OT, Y;~AC'iURE, C~;IENT SQUEEZE, ETC. 6138-6150 ' 6416-6440 ' 6830-6882 ' D~i iNT~V~ (MD) [ AMOUNF ;~D I'iiND OF MA'I'E:'aAL US~ 6210-6260 ' 6462-6476 ' 7030-7084 ' 6300-6330' 6560-6610 ' 7120-7200' I - 6352-6370' 6740-6800' 7608-7622' with 4 JSPF 35" holes ......... ' , ' , ~:' ~':'~' '-; U ~; ,q'~ ,, , ~. PRODU~ION DATE FIRST Pi%ODUC~ON [ ~ODUCT1ON ME'II{OD (Flowfi*g, gas lifL pump~g--size and type of pump) I%5ELL STATUS (Producing or t 1-1-78 Pumping 3" type "B" Kobe Pump tT.',,i~itm 0i ~].'/.[[',. "': anun-xn _.1-12-781 ! -- I. 0 I 0 I I - FLOW, ~EING- ]CAS~G P~SSURE [CAL~~ OI~BBL.' GA~2vI~. WA~BBL. ]OIL GRAVITY-~I (CO~.) ~ss. 70 100 ~ 0 I 0 I 970 - 1 &l] msPosITlOS oe ass (,gold, used Jot luei, vented, etc.) " ' I TEflT WITNESSED BY Hone 32. LIST 0F ATTACHMENTS Chronological History and Directional Survey 33.'I hereby certify that the foregoing and attached information Is complete and correct as determined from alI-kvallable records SIGNED ~~' ~--~¢--t'~r'' '~ TITLE Area Super int endent D,vrr 2-14- 78 *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,~,ell complet,on report and log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (whe, e not otherwise shown) for'depth measure- ments given ,n other spaces on this forr-~ and ira ar~y att,ach:~.aer'~ls Items :20, and 22:: If ibis well is completed for separ<~tc prcc~'~ction from more th~3n one interval zone (multiple completion), so state ,n item 20. and ir'~ ,te'~ ?? show thc. ~)~cJtJC;:~.!l interv,'~l, or ,,~terv~'~ls, top(s), bottom(s) and name (s) (if any) for only the inter~.~l ret.)orted i,~ ~te~, 30 Subr'n,! a separate report (page) on this form, adequately identificd, for each addlliortclJ i~te~val to be separately produce:i, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAIiY OF PO{tMATI(_)N TTg~'I'.S INt'L.Lll)IN(; IN'I'EItVAL TF..~TED t'IIE.'~SIJFIE DATA A.N"D'~LI~COVEIIIIF~ ()F (_)IL GAS. 35. G IDOI-,OG I C M A RK1EP~ WATT_~II AND MUD ~ , NAMlg ,,, None Kenai Sands: State "A" 5552 ' 5322 State "B" · 6066 ' 5831 State '~C" 6520 ' 6290 State "D" 6946 ' 6704 State "E" 7490 ' 7247 COHE DATA. A~'PACH ~]R~EF D~CB[~ONS O~~ LtTHOLOGY. PoR°S~TY. FHACTURFM~, APpA~'II~N~' ~D~P8 ~N~. D~L'~'ED S~.OWS OM O~L. GAS O~ WAT~L None State "G", Not enco~ ntered Chronological Well History MGS 17595 Well No. 8RD Leg 4, Slot 3, Platform Baker November 10, 1977 November 11 - 12 November 13 November 14 - 16 November 17 November 18 - 19 November 20 - 23 November 24 - 25 November 26 - 30 December 1 December 2 December 3 December 4 December 5 - 7 December 8 December 9 - 15 December 16 - 17 December 18 December 19 - 22 December 23 December 24 - 25 December 26 December 27 - 28 December 29 - 30 January 1 - 12, 1978 January 13 - 31 February 1 Rig operations commenced. TD: 5535' Skid rig and prepare to pull tubing. TD: 5535' TD: 2330' TD: 2155' TD: 2092' TD: 4745' TD: 5143' TD: 6547' TD: 6727' TD: 6783' TD: 6783' TD: 6874' TD: 7215' TD: 7220' TD: 8562' TD: 8895' TD: 9088' TD: 9250' TD: 9250' PBTD: 7893' PBTD: 7893' PBTD: 7715' PBTD: 7715' Nipple up BOP and pull 168 jts. of 2-3/8" tubing. Cut 9-5/8" casing at 2290' and pull casing. Set hard plug using 500 sx class "G" cement. Drill out cement. Drilling 12-1/4" hole. Dyna drill 4745'-4919'. Drilling 12-1/4" hole. Drilling 12-1/4 hole. Using rig to perforate MGS 17595 Well No. 7, drilling 12-1/4" hole, fishing-lost (107 ') BHA. Fishing BHA. Fishing and drilling 12-1/4" hole. Drilling 12-1/4" hole. Drilling 12-1/4" hole, shut down 12 hrs. to work on MGS 17595 Well No. 7. Drilling 12-1/4" hole. Drilling 12-1/4" hole, RU and run log. Drilling 12-1/4" hole. Drilling 12-1/4" hole, RU and run log. Cement plug from 8009-7890 with 100 sx class "G" cement. Run 182' jts. 9-5/8", casing (40#, 43.5#, 47#), set at 7801', cement with 2000 sx of class "G" cement and run Gyro Survey. Finish running SDC Gyro, run CBL 7698-4000 feet. Test casing at 1500 psi, ok and RU to run tubing. Run 339 jts. of 3-1/2" tubing, landed at 6122'. PBTD: 7715' PBTD: 7715 ' Perforate the "BCDE" as follows: 6138-6150 6560-6610 6210-6260 6650-6710 6300-6330 6740-6800 6352-6370 6830-6882 4 JSPF 6416-6440 7030-7084 6462-6476 7120-7200 7608-7622 Ran Kobe SV and pump tested to 2000 psi, ok. Rig released 2400 hours 12-31-77. Testing. Well Tests: January 2, 1978 0 BOPD x 1404 BWPD x 6 MCFD January 12, 1978 0 BOPD x 970 BWPD x 8 MCFD Well SI due to high WOR. Well completed as an unsuccessful recompletion. . WELL NUMBER MGS 'WELL, 8 SURVEY TY P E GYROSCOPIC ',IPLETION REmORT DEC 28, 1977 DCO PRODUCTION CO~fiPANY i'qGS STATE 17595 NC). fi RD D I U 5 0 F C U q V A Z lJ i7 E b.! E T H C? D 0 F C 0 ?4 P LJ T ,A. T I 0 N K B E L E V, '79 F T R()SCOPIC StJRVEY DECLINATION 24 DEGREES EAST :.~,Pt.!TED FOR SDC BY F,i'l. LINDSEY AND ASSOCIATES RE, C()RD OF SURVI!!:Y ALL CALCtJLATIONS PERFORi.,IED BY ! E-~ Iq ELECTRONIC CO?-'lPUTER TRUE AS, DRIFT VERTICAL PTH A~N!GL E DEPTH 0 0 0 ('), 0 () ~.) 0 0 30, O0 50 O ]5 49.99 75 0 25 74,99 100 0 5 125 m 0 :!2~,99 150 0 0 1~.9,99 17~ 0 2.5 174.99 200 0 50 199.~9 225 1 0 224.99 , 250 1 0 249,98 275 0 30(] 0 1~ 2q9,98 325 0 5 324,98 ~75 O 5 ~74,9~ aO0 0 5 399 · 98 425 0 10 424,98 450 O 5 449,~8 475 ~,n10 aYa.98 50~ O 15 525 0 5 524.9~ 550 0 0 57~ 0 20 SUB DR I FI SEA DImEC DEG, -79,00 N35,00W -48,99 N35*OOW -29,00 N35,00W -a,O0 20,99 N 7,00W 4.5,99 N 7,00W 70,99 N 7,00W 95,99 !20,99 145,99 S72,00E 170,98 195,98 54.7,00E 220,9~ 245,9~ S65,005 270,98 295,98 563.00E B20,98 S55,00E 345,98 NBO,OOE ~To,gg 395,98 N46,00W a20,98 NSI,OOE 4a5,98 495,99 N15,00E 52C,9S N26,OOE q NA TOTAL C~.ORDI TE$ 0,3~ N 0,49 E O,17 iq 0,89 E 0,02 S 1,18 E O,10 S 1,~2 E 0,12 $ 1,~7 E 0,1~ S 1,39 E 0.14 S 1,41 E 0,16 s 1,44 E o,17 s 1.49 E 0.15 S 1,55 E 0,10 S 1,55 E 0,02 S 1,55 E 0.02 ~' 1,61 E 0.04 N 1,62 E 0.10 ~.! 1,65 E 0,29 ~'c 1.72 E C L 0 S U R E S DISTANCE ANGLE D M 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.10 N 34 59 59 W 0.32 N 33 17 27 W 0.43 iN 29 30 4 W 0.45 N 28 33 3 W 0,45 N 28 3:3 3 W 0,49 N 19 30 4'3 W 0,46 N 13 4/+ 52 E 0,60 N 54 59 :39 E 0,91 N 78 45:34 E 1.18 S 88 55 41 E 1,32 S 85 26 11 E 1,38 S 84 ~+5 4 E 1,39 S 84 28 46 E 1,41 S 84. 12 6 E 1,z+5 S 8:3 32 35 E 1,50 S 83 19 20 E 1,55 S 84 17 5 E 1,56 S 86 5 38 E 1.56 S 99 z+ 18 E 1,61 N 89 2 15 E 1,62 N B8 30 2.i E 1.66 N 86 16 26 E 1.75 N 80 13 47 E DOG LEG SEVERITY DEG/IOOFT 0,000 0 · 0 00 2,950 0,640 1,360 0,360 0,000 1,720 1,640 0,640 0.697 1,640 1.680 0,320 0,360 0,360 0,050 0,320 0,320 0.320 0,320 0,640 0,360 1,360 1,CO0 SECTION DISTANCE 0,O0 0,00 -0,O6 -0,22 -0.31 -0,33 -0,3~ -0,41 -0,~6 -().45 -0,38 -0,25 -0.21 -0,20 -0.19 -0,19 -(~, 18 -(~, 1~ -0,21 -0.26 -0.34 -C.40 -0.42 -C,69 ..OCO WELL h!O. 8 RD GYROSCOPIC .SiJf~VE'Y DEC, 27, 197'} ' RECOI~.D OF SURVEY ALL CALCULATIONS PERFOF~r'.!ED 5Y ] [..~ t'.~ ELk;CT[...)~...IC COMPUTE [AS. [)RIFT !PTH .ANGLE TRUE VERT I CAL SUB DEPT!.t .SEA 619 1 0 618,98 650 2 0 649,97 700 3 45 699,90 7~0 5 4.5 749,73 800 7 0 799,42 850 ~ 30 8~8,96 900 9 45 898.33 950 10 45 947,53 .000 12 30 996 · 50 .050 13 45 1045,19 109 14 30 1093.68 150 15 30 1ta1.98 2{hO 16 30 1190.0~ 250 17 0 1237,92 350 18 30 1333.09 ~O~ 10, 30 1~80.36 ~50 20 0 1~27,~2 .500 20 g*5 1474.29 .550 21 30 1520.93 '600 22 0 ].567,37 ~700 2~ 45 1659.63 L750 24 30 1705.26 L~O9 25 30 175U,58 L~50 2~ 15 1795.57 LgO0 27 15 ]8~0,21 539,98 570,97 620,90 670,73 720,42 769,96 819,33 868.53 917.50 g66,19 1014,68 1062.98 lll]..Oq 1158,92 1206,60 1254.09 1701.36 1348,z,.2 1395,2g 14.41 1488.37 1534,65 1580.63 1626.26 1671.58 1716,57 1761.21 1 ~z~9,51 193A.40 DRIFT DEG, N48.00E S1 O, S 10,00 W sig.0oW 52 1, S20.OOW $2 1 · OOW S21,0 OW S22. OOW S24,00W S24. OOW S25. OOW S24. OOW S2Z+, 525 · 0 OW S24, OOW S23.0 OW S22 · OOW S2 3 · F..) OW S25 · 0 OW 525 · OOW S26 , 0 OW S26,OUW 52 7 · S28 S28 · 0 OW 52 2 · o o~,.t TOTAL CC, ORDINATES C t 0 S U R E S DISTANCE AN~LE D M 0,50 ?~' 1.88.. E 0.20 F',,! 2.42 E 2.25 S 1.99 E 6.26 S 0.95 E 11,50 S 0,89 W 17.81 S 3.25 W 25,2/+ S 6,C3 t'.! 33.~7 S 9,14 W 34,80 42,~8 S 12,76 W 44,83 53,~4 $ 16.92 W 56.15 6746,, ,: 221'6z'~?W:~-8~::'~W: ~ 6881,,3120 lo9.3o 115,98 S a4,75 W 124,32 130.23 S 51.25 W 139.95 1~5,0~ S 59.00 W 156,21' S 160.54 S 64.73 W 173.10 176.62 S 71.40 W 19C,51 193.27 S 7S,29 W 208.52 210.32 S 85.53 W 227.05 227.62 S 93,23 W 245.97 245,~1 S 101,53 W 265.59 263,86 S 110.33 W 286,00 282,85 S 119.59 W 307.10 302,38 S 129,33 W 328.88 322,3~ S 139,72 W 351.32 363,79 S 161,76 W 398.13 aOS.2A ~ 181. .. o 10 t,',~ 443.89 1,95 N 74 57 34 E 2.43 N 85 7 56 E 3.01 $ 41 22 7 E 6,33 S 8 41 3 E 11.53 S 4 27 16 W 18.11 S 10 21 38 W 25,95 S 13 26 37 W 15 14 36 W 16 32 5 W 17 32 15 W 18 3O ~2 W 19 23 6 W 520 7 35 W 20 /+2 9 W 21 6 4 W 21 28 52 W 21 47 44 W 21 57 43 W 22 0 40 W 22 3 12 W 22 7 50 W 22 16 28 W 22 28 33 W 22 41 3O W 22 55 9 W 23 9 24 W 23 26 5 W 23 58 20 ~.~ 24 4 42 W DOG LEG SEVER I TY DEG/iOOFI' 2.158 3,274 3,500 4,004 2 3.000 2,501 2,001 3,500 2,503 1,521 2,000 2.006 1,015 2.000 1,020 2,012 1.027 1.521 1.524 1.000 1.159 2,500 1,539 2.000 1,550 2.043 1.500 3.207 SEC T I ON D I $ T A N C E -0.93 -0,77 1,72 5,86 11,38 18.08 25,95 34.78 4~,78 56.02 68,06 80.80 94,33 10~,49 123,28 13~,66 154.65 171,30 188.50 206,31 22a,59 243.22 262,47 282,~7 303,12 324,40 346,25 39!.7a 436.61 OCO WELL ~!~. 8 RD GYROSCOPIC SLJRVEY DEC, 2'7, 1977 REC()RD OF SURVt!::Y ALL CALCULATICIN5 PERFOF~,~"!FD DY I [,.~ !'.I ELECTROi",ilC CO!','iPUTER AS. DRIFT PTF,! ANGLE 2gO 23 0 300 22 30 4 ~,,,0 18 500 16 ¢,00 13 15 ?r)O 11 0 800 10 15 900 lO ~5 000 10 30 100 10 15 ~On ~ 30 300 8 15 ~00 7 50 500 7 30 6O0 7 50 8O0 ~ ~5 9no ~ lo 000 9 30 I00 = i5 20n 9 45 30o lo 0 aoo 9 45 500 9 3O 709 P 45 ~00 o 30 900 ¢ t5 0(~0 7 ~0 TRUE VERTICAL 5U?, DRIFT TOTAL COORDINATES, C L 0 DEPTH SEA D I REC D I STANCE DEO, 2108.47 2029.47 519.50W 2200.69 2121,69 S18,50W 2294.34 2215,34. SlO, OOi'.: 2389,71 2310,71 S17,SOW 2486,35 2407,35 $17,50W 2584.11 2505,11 S16,50W 2682.39 2603,~9 Si~,50W 27~0,72 2701,72 S12.50W 2879,00 2800.00 S 9,50W 2977,37 2898,37 S 6,50W 3076.03 2997,03 S 2,90W 3174.96 3095,q6 S 6.00W 3273.98 3194,98 S 7,50W 3373,08 329~,0g S 4,50W 3472.19 3393,19 S 2,00W 3571,20 3a92.20 S 1,50W 3670,11 3591.]1 S O,50E 3768.89 3689.89 S 3~.7.56 3788.56 S 3~66.23 -3~87.23 S O,50E aO6a,89 3985,85 S ~,50E a],63.37 4084,37 S 6.50E 4261.~9 41R2.P. 9 a38(.).a8 42B1.48 S12.ooE a~59.15 a380.15 216,50E a~97,91 4a78,~1 S14,SO~ a556. (,5 a577.65 S 3.0Oh' a755.45 4676,A5 522,307.~' z, 8~a.47 ~775,~7 52 1.50'¢/ 443,85 S 195,72 W 4B0,42 S 208.31 W 513,57 S 219,56 W 542,13 $ 228.9.8 W 566,61 S 236,70 W 586,69 S 242,84 W 604,~0.~ S 247,61 W 622,~5 S 251.71 W 640,~5 S 255.23 W 658,~8 $ ,, 257 702.85 5. :261 7 i s. i 2 s z 729,4/+ S 263,75 W 743,43 S 264,18 W 758,21 S 264,31 W 773,79 S 264,31 W 790,01 S 264.a5 W 806,30 S 264.45 W 822,78 S 263,73 ~.'. 839.b:5 S 2&2.08 855.92 S 260.44 P, T3.45 S 2~° 04 889.Z4 S 25~.0~ W 904.31 S 24g,~5 W 920,03 S 248,27 935.03 S 251,60 W 948.02 S 256,78 ~',: U R E S ANGLE D M S 485,09 S 23 47 43 W 523,63 S 23 26 30 W 558,54 S 23 8 52 W 588,50 S 22 53 52 W 614,06 S 22 40 21 W 634,96 S 22 29 7 W 653,25 S 22 16 28 W 671,24 S 22 1 26 W 689,34 S 21 43 51 W 706,85 S 21 23 4 W 722.43 $ 21 O 1~+ W 736,36 S 20 40 21 W 749,95 S 20 24 55 W 762,89 $ 20 9 57 W 775.66 S 19 52 44 W 788,9~-S 19 33 46 W 802.96 S 19 13 6 W 817.6B S 18 51 32 W 833,09 S 18 30 27 W 86~.02 S 17 46 21 W 8?9.80 S 17 19 52 W ~95.~3 S 16 54 20 W 910.78 S 16 27 31 W 924.82 S 15 56 36 W 938.20 S 15 26 42 W 952,94 S 15 6 6 W 968.28 S 15 3 38 W 982.19 S 15 9 20 W DOG LEG SEVER I TY DEG/iOOFT 2.776 0.521 4.000 2.004 3.250 2,250 0.756 0,501 0,269 0.267 1.7.53 0.263 0,411 0,344 0,.343 0.~+10 0.502 0.~+21 0,.330 0.251 0.513 ~.257 0.256 0.323 C · 276 0.502 () · 889 1,310 0,410 SECTION DISTANCE 477.56 516.07 550.94 580,92 606.53 627,50 6a5.93 664,15 682.56 700.48 716,55 730.90 74~.79 758.02 771.14 784,84 799,23 814,36 83 (;. 1 !'5 845.98 861.82 ~94.22 909.7i 92a.10 937.7~ 9D2.65 968.01 981.~6 .MOCO W~LL N'O, 8 RD GYROSCOPIC SUPVt'.<Y DEC, 27, 19~7 ~ RECORD OF SURVEY ALL CALCLILATION5 PEI{FOR~:'~ED FY I B M ELECTPO?,tlC COF':PUTER TRUE !FAS, DqlFT V,F, RTICAL SUB DRIFT TOTAL COORDIF!ATEG C L 0 ~EPTH ANGLF DEPTH SEA DIREC DI$TANCE D ~."1 D EG, 51r)o 7 15 L~95:J. 60 487~+, 50 521,50W 5200 7 0 5':)52,83 4.973,83 S21,OOW 5300 5 30 F152.13 5073,13 Sl?,50W 5400 7 3() 5251.39 5172,39 S18.50W 5500 8 3o ~350,41 F271,al Sll,oow 5600 8 30 5449,31 5370,31 S 7,50W 5700 9 0 554R,15 5469,15 S 4,50W 5800 7 45 5647,08 5568,08 5 5,50E 5900 8 45 5746,04 5667,04 5 2,50W 6000 8 30 5~44.9! 5765,91 6100 8 30 5943.82 5864,82 512,50W 6200 8 30 ~04'2 · 72 5963,72 6300 7 30 6141,74 6062,74 SiO,50W 6400 8 0 6240.83 6151,23 S12,00W ~500 7 15 5339.94 6260,9a S 6600 6 50 6439,19 6360,19 S12,50W 6700 6 3o 6538.51 5459.51 S16.OOW 6800 5 10 6637.99 6558.99 S 9.00w 6900 4 15 6737.65 6658,55 S 4,50W 7100 3 10 6937,2a' 6a58,28 S 7200 2 50 7037,14 6958,14 S O,SOW 7200 2 a5 7137.02 7058.02 S 4.50E 7400 2 30 7236.92 7157.92 524.00E 7500 2 0 7336.8a 7257.84 523.50E 7600 2 15 7a35.77 7357.77 532.00E 7700 3 ~5 7536.63 7~57,63 529.00E 5 U R E $ ANGLE D M 960,24. 971,80 982,90 994,49 1007,93 1022 , 52 1037,65 1052 .!~9 1066 1081 ,!~/+ 1095 · ?~.. 1110, $ 15 515 S i5 S 15 S 15 S 261.59 W 995.24, 266,09 W 100'7,57 269.96 W 1019.30 273,73 W 1031.47 277.27 W 1045,38 279.65 W 1060.07 281.24 W 1075,09 281.11 W 1089,10 280.73 W 1102.86 S 282,88 W 1117,73 S 2 W~: 1132,51 S ,28 S i 1 ~ 1.16 s 1150,13 S 296,99 W 1187,86 S 1162.19 S 299,22 W 1200,.09 S 1173,4.4' S 302,08 W 1211,70 S 1183,36 S 304,28 ~'i.¢ 1221,86 S 1191.51 S 305.25 W 1229.99 S 119B,03 S 305.82 W 1236,45 S 14' 21 w 18 47 W 21 BOW 23 22 W 22 52 W 17 44 W 9 53 W 14 57 29 W 14 44 49 W 14 39 37 W 14 36 28 W 14 33 53 W la 31 30 W 14 28 ~+ W 14 26 18 W 1~ 26 11 W 14 25 13 W 14 22 9 W 14 19 12 W 1203,58 S 1208,B0 S 1219.67 S 121S,09 S 1221,69 S 1224,96 S 1229.47 S 305,52 306,96 306,79 305,67 30~,08 302,36 299.70 1242.00 S 14 17 17 W 1247,17 S lg lg 54 W 1251,85 S 14 11 9 W 1255.86 S 14 5 13 W 125b,96 S 13 58 38 W 1261,73 S 13 51 55 W 1265,48 S 13 41 59 W DOG LEG SEVERITY DEG/iOOFT 0,590 0.250 0.502 1,000 1.013 0.517 0.505 1,263 1,017 0,354' 0,222 0,148 1.O00 0,501 0.752 0.414 0,343 1,331 0.920 1.000 0.081 0,331 0.091 0.253 0,500 0,250 1,~00 SECTION DISTAN(E 994.87 1007.17 1018.8' 1031,02 1044,92 1059,66 1074.73 1088.83 1102.67 1117.57 1132.35 1147.t~ 1161.03 1174.50 1187,74 1199,09 ].211.60 1221,76 1229.9] 1236.3V 1241.94 12~7,11 12bl.80 1255.83 125~.95 1261.72 1265.45 :OTTOf' HOLE CLOS(~RE 1285,48 FEET Al' S 13 41 59 W .,'.,,..LL NC), 8 R~-) ,0 rE ?,~F A SURE [) 4 E: D E P T F! VEr?T ICAL TF~ LJE VE~T I CAL DEPTH GYF~OSCOPIC SLJ[-7,,VEY DEPTHS, COORDINATFS AND CLOSURES FOR '[OTAL C()ORD I I,.!ATES C L DiSTANCE G I VEN O S U DEPTHS R E ANGLE t,1 S DEC, S U E~ S E A 19'77 5052 6056 6946 7490 5910.19 6359,79 6783 7326,85 95a,51 S 259,27 W 989,10 !090,84 S 285,13 W 112'7o~9 1152,61 S 297,36 ~ 1190,35 1194,73 $ 305,49 W 1233,17 1221,97 S B04,24 W 1258,69 15 14 14 14 13 11 38 27 2O 59 48 W 56 W 58 W 34 W 15 W 4827,00 5831,19 6280,79 6704,54 7247,85 ,'.',,i©CO WELL NO, P RD EASt, IRED [D.[::'PTH ,AND OTHER DATA GYROSCOPIC SURVEY FOR EVEF'.Y EVEN 100 FEET OF SUB SEA DEP TH, DEC. 197'7 TRU~ :',~..,ou,~ED VERTICAL DEPTH DEPTH SEA HD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 179 179, 100 0 270 279, 200 0 979 379, 300 0 479 479, 400 0 570 579, 500 0 679 679 , 600 0 77~ 779, 700 0 ~RO 879, 8,00 1 g82 979, 900 3 1085 1079, 1000 5 ].188 1179, 1100 9 1293 127g, 1200 14 1~99 1379, 1300 19 1505 1479, 1400 26 1613 1579, 1500 33 1721 1679, 1600 42 1831 1779, 1700 52 !944 1879. 1800 64 2057 1979. 1900 78 216n 2079, 2000 89 2276 21.79, 2100 97 2384 · 2279, 2200 105 2a~o 2.379. 2300 110 250 2 247'9, 2400 113 26q~ 2579, 2500 116 2797 2679, 2600 118 2~o~ 2779, 2'700 119 3000 2879. 2~00 121 3!.02 2979, 2900 123 3203 3079, 3000 124 3304 3179, 3100 125 3405 3279, 3200 126 3506 337q, 3300 126 3507 3479, 3400 127 3708 3579, 3500 128 0 0.46 0 0,04 0 0,14 0 0,09 0 0.13 0 1.04 0 9,18 1 22,14. 2 39,a3 2 61,32 4 86,07 5 114,01 5 144,60 ...~ ~.~ 178,26 ~: ~:! :214,65 .... ~: 0 .:! ..i ?.::i' ::294'92 :, , 12 340.23 1~ 387,75 11 431.86 8 471,77 8 508.67 5 539.11 3 564.89 3 585,7g 2 603.94 1 621.93 2 640,38 2 658.48 1 674.87 1 689,52 1 703,52 0 716.90 1 730.38 1 74~.56 0,13 W 1,21 E 1,41 E 1,SZ+ E 1.66 E 2,20 E 0,06 W 4.89 W 11,39 W 20,17 W 31,24 W 43,88 W 57,80 W 72,06 W 87,39 W 105,16 W 125,56 W !49e23 W 173,60 W 191,30 W 205.12 W 217,72 W 227,91 W 235.94 W 242,39 W 247,31 W 251.47 W 255.07 ~ 257,76 W 258,95 W 260,01 W 261.68 W 263.05 W 263,78 W 264,20 W WELL I',.!0. 8 RD :ASURED DEPTH Ar,ID OTHER DATA FOR GYROSCOPIC SURVEY EVERY EVEN 100 FEET OF SUg. ,SEA DEPTH. DEC, 27, 1977 TRUE HFASURED VERTICAL DEPTH DEPTH SUB SEA MD-TVD DIFFERENCE VERT I CAL CORRECT ION TOTAL COORDINATES 3809 3679, 3600 3910 3779, 3700 4012 3879, 3~00 4115 3979, 3900 4214 . 4079, 4000 4316 4179, 4100 4417 4279, 4200 451.9 4379, 4300 4620 4479, 4400 472% 4579. 4500 4823 4679. 4600 4924 4779, 4700 5025 4879. 4800 5126 4979, 4900 5226 5079, 5000 5327 5179. 5100 5~28 5279, 5200 5529 5379. 5300 5630 5479, 5400 5731 5579, 5500 5832 5679, 5600 5933 5779, 5700 6034 5979, 5800 6136 5979. 5900 6237 6079. 6000 6338 6179, 6100 6a39 6279, 6200 6539 6379. 6300 6640 6479. 6400 6741 6579. 6500 6841 6679, 6600 694! 6779, 6700 7042 6879. 6800 7142 6979. 6900 7242 7079. 7000 129 1 131 2 133 2 133 0 135 2 137 2 138 1 140 2 141 1 144 ~ 2 145 ~ 1 146 1 147 ' ~ 147 148 1 148 0 150 2 151 1 152 1 153 1 154 1 155 1 157 2 158 1 158 0 160 2 160 0 161 1 162 1 162 0 !62 0 163 1 163 O 163 0 759,58 S 775.38 S 791.92 S 808.38 S 825,15 S 842.59 S 859,78 S 876.48 $ 892,32 S 907.47 S 923,70 938.17 S 951.15 S 963,24 S 974.74 S 985,88 S 998.03 S 1012.14 S 1026,97 S 1042.39 S 1056,59 S 1071,51 S 1086.23 S 1100.88 S 1115.40 S 1128.73 1142.24 S 1154.94 S 1166.78 1177.72 S 1186.89 S 1194.40 S 1200.36 S 1205.82 $ 1210.86 S 264.31 W 264,31 W 264,45 W 264,44 W 263,56 W 261.81 W 260,21 W 257,38 W 253,16 W 249,17 W 248,60 W 252.86 W 257,98 W 262.75 W 267,19 W 270,88 W 274.81W 278.04 W 280.16 W 281,45 W 280.81 W 281.08 W 284,07 W 287.35 W 290,34 W 292,89 W 295,65 W 297,73 W 300.27 W 303.20 W 304,78 W 305.a6 W 306.06 W 306,80 W 306,93 W ,i()CO WELL NO, 9 RD GYROSCOPIC SURVEY :ASUP, ED DEPTH A?..ID OTHF. R DATA FOR EVERY EVEN 100 FEET OF SUB .SEA DEPTH, DEC, 27, 197~~' TRUE NtEAS[JRED VERTICAL SUB Y,D-TVD VERT!CAb DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7342 71,79, 7100 163 0 7~42 7279, 7200 163 0 7542 7B'79, 7~00 153 0 76~2 7479, 7~,00 16~ 0 1215,63 $ 1219,70 S 1223,0b S 1225,57 S ~06,51 W ~04,96 W 303,45 W 301,38 W lOCO WELL NO, 8 RD 'ERPOLATED VALUES FOR TR i',,IE ASUR ED VERT ! DEPTH DEP ~,, TEN LIE CAL TH GYROSCOPIC SURVEY 1000 FEET OF I',.~EASI, rJF(ED DFPTH. SUB SEA TOTAL COORDINATES 1000 996. 917, 42.98 S 12.75 W 2000 1928, 1.8~9. 363,79 5 161,76 W 3000 2879. 2800. 640.38 S 255.07 W 4000 3867. 3788. 790.00 S 264.31 W 5000 4854. /+775, 948.0Z+ S 256.72 W 6000 58Z~4. 5765. 1081.35 S 282.82 W 7000 6837. 6758. 1198.03 S 305.76 W DEC, 27, 1977 .................................................................................. VERTICAL SECTION _ .. SCALE I"= I000 ' .... AMOCO PRODUCTION COMPANY MGS NO. 8 REDRILL ....................... RADIUS OF CURVATURE GYROSCOPIC SURVEY W_k 8 TVD = 75:57" TMD = 7'700~ ALL DEPTHS SHOWN_ HORIZONTAL VIEW SCALE 1"=500' AMOCO PRODUCTION COMPANY MGS NO. 8 REDRILL RADIUS OF CURVATURE GYROSCOPIC SURVEY ' - ' TVD = 75.'57' .......... ' TMD= 7700' . ................ ................ ............ .._~ .............. /;_.~ ..................... i~__.' ......... '__: ...... ~o~ ~LI~'/t~ ........... '. i.' .... ........ - . .--- - . .--.--.. -,..~/o~ .. I i ~,~ ........................................................ ~o-f l ~ .' ' ' " ' i ~ ....... . ,.~i . ............................................................. . ........................................................ ~oo~, ~ ............................................................................................................ .......... 5600-t,/-0 ' · _. _- -. _....,~~-- ........................................................ i ........ i.~_ .......... ~e~ ............ .. ARE TVD. _ . . . . . . _ SCHLUMBERGER OFFSRORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEASE REPLY TO JANUARY 17, 1978 SCHLUI~IBERGER OFFSHORE: SERVICE' 500 W INTERNATIONAL AIRPORT ROA. ANCHORAGE, ALASKA 99502 AMOCO PRODUCTION COMPANY P.O. BOX 779 ANCHORAGE, ALASKA I 99510 Attention: MR. LEONARD DARSOW Gentlemen: Enclosed are 3 BJ~rintsofthe DIL, BHC/GR HDT CompanvAMOCO PRODUCTION cOMPANY, Well. MIDDI'E GROUND fielcJ ~IIDDLE GROUND SHOAL ,County KENAI ' SHOAL _State__ _on: 17 595 #8 RE. DRILL ALASKA 2 R~k~lj)i6~al~Bf~tJ~re being sent to: 1 B~rints AMO'CO PRODUCT ION COMPANY 1010 SECURITY LIFE BUILDING DENVER, COLORADO 80202 ATTENTION- MR. A.M. RONEY 1 RROLLED SEPIA 1 B~rints CHEVRON U.S.A. INC; P.O. BOX 7-839 ANCHORAGE, /~LASKA 99510 ATTENTION- C.F. KIRKVOLD 2 BL .prints PHILLIPS PETROLEUM COMPANY 1010 SECURITY LIFE BUILDING DENVER, COLORADO 80202 ATTENTION- MR. J.P. DENNY 1 BL prints SHELL OIL COMPANY P.O. BOX 831 HOUSTON, TEXAS 77001 1 RFOLDED SEPIA 1 B.~ints ATLANTICRICHFIELD COMPANY P.O. BOX 360 ANCHORAGE, ALASKA 99510 ATTENT ION- HR. DARRYL BOSE 1 BL ~lr~_ntsN DEPT ATURAL RESOURCES DIVISION OF OIL AND GAS CONSERVATION 3OO1 PORCUP I NE DR I VE ANCHORAGE, ALASKA 99510 ATTENTION- O.K. GILBRETH 2 B~rints. GETTY 0IL COMPANY 1860 LINCOLN STREET DENVER, COLORADO 80202 ATTENTION- J.E. HOFMANN 1 B SHE 601 ~ LPrj)nJsL COMPANY W 5TH AVENUE ANCHORAGE, ALASKA 99510 ETURNEDTO AMOCO The film is D ENV ER ) RECEIVED BY- / "' -~,-'~ ~/ .-/ COMPANY- ~BERG'ER OF~,.ORE SERVIC~ L. A. Darsow Area Superintendent January 17, 1978 File: LAD-063-WF Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 " Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 8 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 8 for the month of December 1977. Very truly yours, L. A. Darsow Area Superintendent Attachment DMS:mls Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-10075 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 8 (redrill) 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 4. LOCATION OF WELL Leg 4, Slot 3, MGS Platform Baker, 1991' FNL, 473' FWL, Section 31, T9N, R12W, S. M. 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S. M. 12. PERMIT NO. 77-72 13. REPORT TOTAL DE~H AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DE~H SET AND VOLUMES USE~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of December 1, 1977 TD: 6727' Drilling 12-1/4" hole. December 2 TD: 6783' Using rig to perforate MGS 17595 Well No. 7, drilling 12-1/4" hole, fishing lost (107') BHA. December 3 TD: 6783' Fishing our BHA. December 4 TD: 6874' Fishing and drilling 12-1/4" hole. December 5 to 7 TD: 7215' Drilling 12-1/4" hole. December 8 TD: 7220' Drilling 12-1/4" hole, shut down 12 hrs. to work on MGS 17595 Well No. 7. December 9 to 15 TD: 8562' Drilling 12-1/4" hole. December 16 to 17 TD: 8895' Drilling 12-1/4" hole, RU and run log. December 18 TD: 9088' Drilling 12-1/4" hole. December 19 to 22 TD: 9250' Drilling 12-1/4" hole, RU and run log. December 23 TD: 9250' Cement plug from 8009-7890 with 100 sx class G cement. December 24 to 25 PBTD: 7893' Run 182 its. 9-5/8", casing (40#, 43.5#, 47#), set at 7801', cement with 2000 sx of class G cement and run Gyro Survey. December 26 PBTD: 7893' Finish running SDC Gyro, run CBL 7698-4000 feet. Decembec 27 to 28 PBTD: 7715' Test casing at 1500 PSI, ok and RU to run tubing. December 29 to 31 PBTD: 7715' Run 339 its. of 3-1/2" tubing, landed at 6122'. Perforate (2-1/4") 6138-6150 6560-6610 6210-6260 6650-6710 6300-6330 6740-6800 6352-6370 6830-6882 6416-6440 7030-7084 6462-6476 7120-7200 7608-7622 Status as of January. l, 1978 4 JSPF Ran Kobe SV and pump tested to 2000 PSI, ok. Rig released 2400 hrs. 12-31-77. PBTD: 7715' Testing. 14. I hereby certify~at ~0~e, ,f~,~g'fS true and correct SIGNED ~~ d '~'i,,-'~,';)~/J~'~-~ TITLEArea Superintendent January 17, 1978 DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 7700! PLEASE REPLY TO JANUARY 3, 1978 SCHLUMBITRGEROFF'HORITIJgFIVICI~I 500 W INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 AMOCO PRODUCTION COMPANY P.O. BOX 779 ANCHORAGE, ALASKA 99510 Attention: HR. LEONARD DARSOW Gentlemen: Enclosed are3 B [prints of the COHPUTED DIPMETER, (4) TAPES & LISTINGS: Company AMOCO PRODUCTION CO ,Well MIDDLE GROUND SHOAL 17595 REDR!LL #8 Field MI DDLE GROUND SHOAL ,County KENAI ~tate ALASKA 2 R F(~cl~i~i~n~l ~R~I~ are being sent to: 1 BLnrints AHOCO PRODUCTION COMPANY 1010 SECURITY LIFE BUILDING DENVER. COLORADO 80202 ATTENTION- MR. A.H. RONEY 2 BL .prints PHILLIPS PETROLEUH COHPANY 1010 SECURITY LIFE BUILDING DENVER, COLORADO 80202 ATTENTION- MR. J.P. DENNY 1 RROLLED SEPIA 1 B Lnrints CHEVRON U.S.A. INC. P.O. BOX 7-839 ANCHORAGE, ALASKA 99510 ATTENTION- C.F. KIRKVOLD 1 BL nrints SHELL' OIL COMPANY P.O. BOX 8~1 HOUSTON, TEXAS 77OO1 1 RFOLDED SEPIA 1 B Lprints ATLANTIC RICHFIELD COHPANY P.O. BOX 360 ANCH ORAGE, ALASKA 99510 ATTENTION- HR. DARRYL BOSE 1 BL .prints DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99510 ATTENTION- O.K. G ILBRETH 2 B Lr~rints GETTY OI!~ COMPANY 1860 LINCOLN STRrFET DENVER, COLORADO- 80202 ATTENTION- J.E. HOFMANN 1 BL "rints SHELI~'OIL COMPANY 601 W. 5TH AVENUE ANCHORAGE, ALASKA 99-510 The film is RETURNED TO AHOCO ( DENVER ) We appreciate the privilege of serving you. RECEIVED BY- COMPANY-' ~ DATE-~ ~, /'e/~c~ Very truly SCHLUMBERGER OFFSHORE SERVICES L. A. Darsow Area Superintendent December 20, 1977 Amoco Production Compariy P.O. Box 779 '" Anchora9e, Alaska 99510 File: LAD-lO49-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 8 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 8 for the month of November, 1977. Very truly yours, L. A. Darsow Area Superintendent Attachment DMS:mls Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. API NUMERICAL CODE 50-133-10075 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS 17595 9. WELL NO. 8 (Redrill) 4. LOCATION OF WELL Leg 4, Slot 3, MGS Platform Baker, 1991' FNL, 473' FWL, Section 31, T9N, R12W, S. M. 10. FIELD AND POOL, OR WIL~AT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM ItOLE OBJECTIVE) Sec. 31, T9N, R12W, S. M. 12. PERMIT NO. 77-72 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED ltOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. November 10, 1977 Rig operations November 11 to 12 TD: 5535' November 13 TD: 5535" November 14 to 16 TD: 2330' November 17 TD: 2155' November 18 to 19 TD: 2092' November 20 to 23 TD: 4745' November 24 to 25 TD: 5143' November 26 to 30 TD: 6547' commenced. Skid rig and prepare to pull tubing. Nipple up BOP and pull 168 jts. of 2-3/8" tubing. Cut 9-5/8" casing at 2290' and pull casing. Set hard plug using 500 sx class "G" cement. Drill out cement. Drilling 12-1/4" hole. Dyna drill 4745~4919.' Drilling 12-1/4" hole. Status as of December 1, 1977 TD: 6727' Drilling 12-1/4" hole. 14. I hereby certify~that .tl~e fpr~n~.gj_s true and correct SIGNED ~~ ~7~i) ~'/~ ,~,~ ?~/'~'"'"~~ TITLE Area Superintendent DATE December 20, 1977 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. DEP~ OF NATURAL RESOUrCeS Divisic~ of Oil and Gas Cc~~ation Chiof Dec~Woer 19, 1977 John C. Miller / · Witness BOPE Test, Amoco - MSS 17595 No. 8RD Tuesday, Dec~zDer 13, 1977 - I left Anchorage by commercial aircraft at 10:00 ~6r ~ and' ~~"by rented car and ccm%0any helicopter, arriving at the. Amoco Baker platform at 12:25 PM to witness BOPE tests c~ the captioned well. Harrell ~Raney, Arax~ drilling f~, said they w~re coming out of the hole with the drill string and would be ready to start the BOPE test shortly. Testing started at 2:40 PM. The BOPE stack frc~. top to bottcm was hydril, pipe rams, blind rams, drilling spool, and pipe rams. Wad_.~ Pace, the toolpusher for Parker rig No. 150, was ~ the test. Pressure tests were done by fill/rig up th~ sys%em %~h mud using the mud ~ and then building, up to test floor valve was s~ in the bottcm of the test plug and the test plug was seated below the bottom pipe ~. The bottc~ pipe rams were closed and the kelly cock was closed. This system was tested without leaking, at 3100 psig test pressure. Pressure ~_sts progressed through the _sys. t~ of the top pipe rams, blLnd rams, choke and kill line vale=s, the bottnm kelly valve, and the choke m~nifold at 3100 psig. The hydril was 'tested without leaking at 1700 psig. The dart type flo~r valve was in place. The accumulator had 2380 psig pressure and each of the 4 nitrogen backup bottles had 1975 psig pressure. The r~ BOP closing controls ware checked for proper operatio~ and all functioned properly except the closing ccntrol for the bottc~ pipe rams. These did not close the rams ~ it was suspected that t~_re was saue ice in th~ oontrol line. All of the other systems c~ the rig and the general housekeep~ c~ the platfon~ were satisfactory. The BOPE test was ccmpleted at 4:45 PM. I completed a Field Inspecticn Ret~t for the BOPE test and advised Harrell that the r~note closing control for the bottom pipe rams would have to be repaired, tested and satisfactory test reported to the state within three days. I left a copy of the Field Inspection Report with ~z~-rell ~Ran~, on the platfozm, mailed a copy to Bill Halverscn, Amoco chief drilling, eng~ineer in Anchorage, and a copy is attached to this report. Due to high ~hnds I was unable to catch a chopper to .~hore to return to Anchorage as planned, so I took txhis oppo~ty to perfoIm routine in ~spection duties on this platform. Well No. 7~D was in the test separator ~f~_re they w~re performing stage production tests ~ ascertain problems cn the well. Since th~e tests are not representative, I requested recent te~ts on several other ~lls and obtained the follow/ng test data cn ~q 17595 w~lls, all on hydraulic lift: 5~S 17595No. 8RD -2- December 19, 1977 6 428 106 34.1 260 607 12/8/77 16 1466 13 35.9 784 535 12/1/77 15 1358 60 36.1 613 450 12/5/77 ~ platfc~m has n~ subsurface safety shut-in valves since no wells are capable of ~, so I proceeded to check the surface casing pressures with the production foreman. ~ pressures w~re below 100 psig except the pressure inside the 13 3/8" casing c~ ~1 No. 9 which was 300 psig. The f~ bleed this pressure dc~n to about 50 psig after w~ ccmplet~d our survey. Wells No. 7 and No. 15 need sc~e additi~al pipe fittings to be inst~m]]ed so w~ can read the pressure inside the 13 3/8" casing. ~ fittings ~ ordered before I left the platform. }~{~~!~ ~__!4, 1977 - I depar~ the Baker platform by ocmpany helicopter at 8:20 AM. I returned frcm the heli~ to Kenai by rented car and by ccmm~_rcial aircraft to ~rage, arriving at 9:55 AM. In s~~: I witnessed a satisfacto~i BOPE test c~ Amoco M~ 17595 No. 8 ~D. ~ ~ closing ~ntrol for the ~ pipe ra~s were not operatic~al during. ~ ~ but these were subsequently repaired, tested and satisfactmry test reported to the state c~ 12/15/77 by Bill Fmlverson of Am~oo. Recent ~11 tests w~re reccx~ed and surface casing pressures w~re checked with c~e high pr~sure ~ bled ~ before I left the platform. :' ~ ~'~: Alas and Gas Conservation Committ6e · .~ ~ ~ ., Field Inspection Report . .~'rDrl:g.~ permit No. '/7-7Z -W~t-1/Platfm Sec T__R__, Opera to~ _ ..... ~..'or ~.~ Represented by~o~/t~C .Name & Number ,,V,,-:- ~ Satisfactory Type Inspection Yes No Item (~ BOPE Tests (~ ( ) 15 'q:~..."Casinfl set ~/'~ (~) ( ) 16. Test fluid-(v)wt~~mud ( ) oil (~ ( ) 17 Master (~) [ } 18 N2 ( ) ~ 19. Remote Controls (~) ( ) 20. Dr~ll~no spool- ~ "outlets (~ ( ) 21. K~!I k~.ne-(~ Check Valve (~ ( ) 22. Choke [lowl~ne (') HtR valve (~ ( ) 23. Choke Man~fold No. valvs~ fl~s (~) ( ) 24. Chokes-(MRemote(~'OPos.(t.~d3: ( ) 25. Test Plu~:(?rWell. hd( )csg( )none . , , , (~ ( ) 26. Annular Preventer,~sio Fina~a~m'ent -- (~' ( ) 27. Blind Rams,g(oopsi~ ~r (~') ( ) 28. Pipe Rams~too.psiq well-( )capped( )plugged' (~ ( ) 29. Kelly & Kelly-cock .aFocpsig (~ ( ) 30. Lower Kelly valve ~?~sio led (~) ( ) 31 Safety Floor valves-(~BV (~Dart 'vation time Total number l'eaks and/or eouip, failures / :"... '~'~ c~ z~' t~, "~i'~:, ~,~, /O, ,F) ~ /'i~-~:"~,l -F~O nspection YeS No Item ,General 'i'(~'. [. ) _ .1-. We],'l Sign, (.t~)'. (..)i : 2i. Gen~eral Housekeeping ,"3':"~'~>'Res~rve Pit-( )open( )filled ..'. ., {,l~').Safet7,valve Tests ~: , 5. Sueface-No. Wells :::,~. ~6. SubSurface-No. Wells '' (':-)' Well Test Data Nos. , , , : .: .8,'.':' obser.__,__,__,__ ,~' :9-, ~. , , , ~n~t ~. 77-"/2 ~ Producticm ~y P. O. ~ 779 Anchor'~age, Alaska 99510 Enclosed ~ ~ approved application for permit to drill the above ref~ ~ at a locatic~ ~ Section 31, Town~p 9N, Range 12W, S.M. %~e~ sa~ptes, ~ hips and a ~ log ave n~: r~. A directional ~ is required. Many rivers in Ala~ ~ ~h~/r drainage systems have ~ classified as important for ~ s~ or migration of ~nad_~ fish. Operaticr~ in th~.~ ~ ~ sub~ to AS 16.50.870 a~] the relations ~gated ~~ (Title 5, Alas~ ~~s~a~ Code). Prior to ~cing. opera~ ~ may be cc~tacted By the ~{abitat Coord~~'s office, Departmm~t of Fish ar~ ~. Pollut/c~ of ~ waters of ~ State is proh~/])ited by ~S 46, Chapter 03, Ar~icle 7 ~ ~ regulations ~gated the~ (Title 18, Alaska Admi~io~trative Code, Chapter 70) and by the Federal Water Pollution con~ by a representative of ~ ~part~nt of En~tal ~rvation. Pursuant to AS 38.40, ~ ~_~/r~ ~ State L~ases, the Alaska Department of ~ is ~ notified of the is~ of tb.~is permit to ¢~i1!. ~ ~ ~ in sche~al~ field work, we would appreciate your r~tifying ~ds ~fice within 48 hours after the ~tl is ,~m]ded. ~e would also like t~ be notified ~ t~hat a z~_~x%~entati~e of the Division may be present to witness tes~' of blowout pr~enter .~~~nt before surface casing shoe is drilled. 17595 10, 1977 Ln ~ e~m%t of suspensic~ or. abandom~snt please gi~ this office adequate ad~~ Px~tficatic~ so ~hat ~ ~ ~ a witness present. Very t~aly ~, O. K. Gilbreth, Jr. ~losure ~t Of FiSh ~ ~, Habitat ~ w/o e~cl. ueparu~nt of Entel oau~a~ w/o ~1. De~ar~nt of ~, Supezvisor, Imbor Law Cx~pliance Di 'vlsi~ w/o encl. L. A. Darsow Area Superintendent October 28, 1977 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 File: LAD-868-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Department of Natural Resources Stateof Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 A,II Dear Sir: Application for Permit toDrill MGS 17595 Well No. 8 Redrill Attached is a Form 10-401, Application for Permit to Drill MGS 17595 Well No. 8 Redrill. This well was originally completed as a dry hole in February 1967 and operations temporarily suspended. Attached for your reference is a copy of the original Form P-3 outlining the abandonment procedure. In August 1967 this well was converted to a gas compressor pulsation chamber with initiation of gas lift operations on MGS Platform Baker. In August 1975 following the conversion of all producing wells to hydraulic lift, the well was blown down, a bridge plug set at 5535' and the well shut-in. We propose to sidetrack the wellbore by cutting and pulling approximately 2500' of existing 9-5/8" casing and drilling new 12-1/4" hole to a subsurface location on top of the Hemlock Conglo- merate'at 2000' FSL, 200' FWL, Section 31, T9N, R12W, S.M. Total depth will be achieved following full penetration of the conglomerate (G-1 - G-5) section, estimated at 9500' TMD. This well is required to recover trapped reserves from the west flank of'-the Middle GrOund Shoal structure, Also attached for your review are the BOP sketches, a plat of the pro- posed location relative to Platform Baker, and a draft in the amount of $100 to cover the filing fee. - 2- Since this well will be the fifth (fourth in the Lower Kenai Conglo- merate) completed in the SW 1/4 of Section 31, we hereby request admini- strative approval for the above location. In addition, according to State Oil and Gas Conservation Regulations No. 2060 and No. 2061, please be advised that Shell Oil Company is an affected operator. A copy of the attached Form 10-401 has been sent this date to Mr. P. J. Carroll withShell Oil Company in Houston, Texas. Yours very truly, L. A. Darsow Area Superintendent Attachments JBK: klt Form 10-40i ' REV. 1-1-71 STATE.OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN TRIP1.; (Other instr.ctions, reverse side) PERMIT TO DRILL OR DEEPEN la.' TYPE GE WORK DRILL [] b. TYPE OF WELL OIL GAS W LL I-il W LL F-1 OTttER DEEPEN l---] (Recomplete by s~.~etrack) iON~ ' [___] hltZONE )1' I'IPI,F 2. NAME OF OPERATOR Amoco Production COmpany : 3. ADDRESS OF OPERATOR P. O. Box 779~ Anchorage, Alaska 99510 4. LOCATION OF WELL Atsurface Leg 4, Slot 3, MGS Platform' Baker, 1991' FNL, 473' FW~L, Section 31, TgN, R12W, S.M. At proposed prod ..... 2000' FSL, 200' FWL, Section 31, TgN, R12W, S.M. at -8000' 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 20 miles northwest of Kenai, Alaska API No. 50-133-10075-01 6. LEASI4 I)ESI(;NA'II()N AND SI'RIAL NO. ADL 17595 7. II: INDIAN, ALI,O'I'FF, I'; OR 'I'RIIIE NAME R. IINI'I' I'AI*,M OR I I:ASI. NAME MGS 17595 9. WI:.LL NO. 8 (Redrill). 10. I.'IliLD AND P()OI., ()R WII.I)('AT Hlddle Ground Shoal I 1. SI';(;., T.. R.. M., (BOTTOM IIOI,E OBJI:;('I'IVE) Sec. 31, T9N, R12W, S.M. 12. 14. BOND INFORMATION: TYPE Blanket Surety and/or No. A ....... , $100,000 15. DISTANCE FROM PROPOSED * ~ 16. No. OF ACRES IN LEASE 17. NO, ACRliS ASSI(;NF, D LOCATION TO NEAREST 2000' FSL, Sec 31 I TOTmSWELI~ PROPERTY OR LEASE LINE, FT. ' (Also to nearest drig, unit. if any) L~LDL 17595 Lease Line 5106 32-40 18. I)ISTANCE FROM PROPOSED LOCATION 19. PROPOSEI) I)EffFII 20.ROTARY OR ('ALII I'i 'IOOLS TO NEAREST WELL DRILLING, COMPLETEI), 700' West of OR APPLIED FOR, FT. MGS 17595 Well No. 11 10,000' Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. I)ATE WORK WILl WIART 79.4' KB-MSL 23. PROPOSED CASING AND CEMI£NTING PRO(;RAM SIZE OF IIOLE SIZE OF CASING ~IGItT PER I:OOT GRADE SETTING DEffFII ()uantit> of cc,ncnr 26" 20" 89# B 6i6' _ To surface (previously set) 17-1/2" 13-3/$" 54.5# J-55 1,986' To surface (previously set) ]2-l/A" 9-5/8" 40-47# S-95 10.000' As recurred to cover_pay NOTE: Zasing design safety factors of 1.125, 1.0 and 1.8 will be used for collapse, ~urst~ and tensile strengths, r]~spectively. Estimated maximum mud weight is 10.5 PPG. Operator plans to cut and pull 2500' of existing 9-5/8" casing in subject well. A sand-cement plug will be spotted to 2100' from which the wellbore will be kicked off and new 12-1/4" hole directionally drilled to a bottom hole location on top of the Lower Kenai Conglomerate at 8080' TVD. Zones of interest, will be perforated, stimulated if necessary, and produced. A plat and BOP draWing are. attached. · , IN ABOVE SPACE DESCRIBE PROPOSED PRO(;RAM: If proposal is to deepen give data on prcscnt prod.ctivc nme and i~,mpo~cd new productive zone. If proposal is to drill or deepen direclionally, give pertinent data Oll sub~'urlace hwalio.s ami mcasurcdimd hue. - vertical depths. Give blowoul preventer program. 24. I hereby c~ thatfl, he F~o~r~,~g is T ..... d Co~._ DATEOCtober 28, 1977 Area Superintendent 'Fl'Il,Il (This space for State office use) SAMPLm AND CORE c. IPS REQUIRED [] YES ~NOI [] YES DIRECTIONAL SURVEY REQUIRED [~[YES [] NO CONDITIONS OF AI)I)ROVAL, IF ANY: MUD LOG OTIIER RI';QUIREMENTS: [] NO A.P.I. NUMERICAL CODE 50-133-10075-01 77-72 PERMIT NO. APPROVAL DATE ~~~~/~ ~' ~' ) ~"t_~ Chairman APPOVED BY ',... . , - ~ />,., TITLE *see Instruction On Reverse Side November 10, 1977 1)ATE November 10, 1977 RECEIVED NOV 1 019'77 ' /.'-" ;'1 ~ ;i ,~; ::' ill 0 0 0 ~ 0~'tr) 0 I ¢ o" I I -9886~0, 31' -7336 RIDDLE 6KDUND R EMLOCY.. Amoco Production Compa, ENGINEERING CHART ,oP I i :~000 · I .... I SHEET NO. OF FiLE APPN ,~T&~ Amoco Production Comp~ I AIVIOCO, ENGINEERING CHART SHEET NO. OF' FILE APPN 2, FILLUP v..ILL b~ NE Forn;' P--- 3 STAT ~'~%LASKA SVBMIT l~~ (Other lnstructions~ OIL AND GAS CON--~'IATION COMMIS': DN verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals ~o drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OI~wELL [--]~E~LOAS [[] 0THOR Dry HOle NAME OF OPERATOR Pan American Petroleum Corporation ADDRESS OF OPERATOR P, O..Box 779, Anchorage, Alaska 99501 LOCATION OF WMLL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface Leg No. 4, Slot No. 3, :MGS Platform I:5; Z041' tVNL,, 522' FWL, Sec. 31, TgN, RIZW, $.M. 14. PERMIT NO. 15. E~.~,VATIONS (Show whether DF, R,T, (IR, eto.) 66-24 RD/~ 78.75 above ESL bh£(,!ivc: July 1, 19G,I LEASE DEBIONATION AND SERIAL NO, ADL ].75'::5 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME MGS State 17595 9. WELL NO, 10. FIELD AND POOL, 0R WII,DCAT ?¢iddle Ground Shoal 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA Surface:Sec. 31, 'rgN, ~IZW, $. M. -¥~', BOROUGII 'j 18. s~e icone i J A 1 a s 1~ 16. Check Appropriate Box To Indicate Natu:e of Notice, Re.po.t, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other)temporary su.~zpension SUBSEQUENT REPORT OF: WATER StlUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Otiler) RI~I'AIRINO WELL AI,TER1NG CASING ABANDONMENT* NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated (late of starting an)' proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertl- Bent to this work.) * This notice sets forth our intent to plug and temporarily suopcnd operations on this well. TD 10314 PBTD 8250. BP set at 8280 with 75 ax belo~v and 25 sx above, drilled out to 8250. Perf. 7415-7420, 7485, 7490; squeezed wP, h 200 ~x. Perf. 7208-7213, ;~queezed with 100 sx. Perf. 6950-6955, 6943-6948, reperf. 6~45-6955 tv¢ice, squeezed with Z00 si. Set BP 7275 with 5 sx above. Perf. 7200-7240. Set I-~P 6700. Perf. 6610-6624. Set ~P 6505 with 5 sxabove. Perf. 6380-641u. Set .EI:' 6300. Perf. 6160-6175. Set BP 6100 with 15 sx above. Well is suspended for possible future testing for ~hallow gas oz' conversion to water injection service. · . · 18. I hereby certffy,I~aat the fo~e~log,~J~lu~'d correct SION~D ~'W.., ~Ii*~_ _ T~T~,~ Area Superintendent DATE February 2, _1967 (This space for Federal~or S~te o)~ee use) CONDITIONS OF APPROVAL~ IF ~N~: DATE *See Instructions on Reverse Side Cr,~ZCK LiSi' fox, ~',., ,',F_LL FF_r,i'i~,b 1. Is the permit fee attached . . Yes No Re?arks 2. Is well to be located in a defined pool ,. Is a registered survey plat a~ached ~ Is v,~ll locau_d Drou~r distance from prep~,-uy line 5 is ,,.,'ell located pr-ope distance from o~Xer ',..'ells 6 Is ~uffi~ient unded~at~d ~an~ a,,aiiable in this pool · ~ ~ , ~ ~. ,,.~,,..,, ~ .--j~ ~ 7. Is well to be deviated ...... , Is operator the only affected party ..... 9. Can permit be approved before ten-day wait . lO. Does operator have a bond in force . Il. Is a conservation order needed -l. 'is ai.:'ir;istrative approval needed ........... 13. Is conductor string provided ............ la. Is enoumh cement used to circulate on conductor and surface 15. Will cement tie in surface and intermediate or production strings Will cemenl~ cover all knov:n productive horizons i7. Will surface casing protect fresh water zones . 18. !-!ill all casing give adequate safety in collapse, tension & burst !9. Does BOPE have sufficient pressure rating - Test to ~oo0 psig 20. Has DHEiI approved Plan of Operation iddi tional ReqUirements· Revised 11/17/76
