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188-001
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done~'~Two-Sided RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGES: q 0 NOTES' ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: .~"~Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other DATE: /SI [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI PAGES: 9 ~ (at the time of scanning) SCANNED BY~ BEVERLY BREN VINCE~ MARIA LOWELL ReScanned (done) RESCANNED BY~~ BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked (done} UNSCANNED, OVERSIZED MATERIALS AVAILABLE: lW ~FILE# _I Ft'eLd m~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 ~ Anchorage, Alaska 99501 Voice (907) 279-1433 ·Fax (907) 276-7542 • FRANK D~. iNURKOWSKI, GOIIERAlOR ®~e ~®1iT~1~ ~1~°°1'Y~T ~ BSI®I~T ADMINISTRATIVE APPROVAL AIO 12.001 Mr. Steve Lambert Advising Reservoir Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 ~~~,~~,~ JINN ~ ~: ZDO~ 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (307) 279-1433 FAX (907) 276-7542 RE: TBF A-19RD (PTD 188-001) Request for Administrative Approval Dear Mr. Lambert: Per Rule 8 of Area Injection Order 12, the Alaska Oil and Gas Conservation Commission ("AOGCC"} hereby grants Unocal Alaska ("Unocal")'s October 3, 2006 request for administrative approval to inject water in Trading Bay Field ("TBF") A-19RD. Unocal notified the Commission on July 19, 2006 that TBF A-19RD exhibits tubing- casing pressure communication and that the well had been shut-in. Approval to continue injection for the purpose of performing well integrity diagnostics was granted by sundry number 306-262 on August 15, 2006. Unocal has elected to perform no corrective action at this time on TBF A-19RD. Temperature surveys performed as part of the diagnostic testing confirm the injected fluids are exiting the well at the perforations. V~hile there is evidence of fluid movement to sands above the perforations, all injected fluids are contained within the injection interval authorized by AIO 12. Monitoring has shown that pressures are contained within the wellbore. An aquifer exemption is in effect for all aquifers lying directly below Trading Bay Field [40 CFR 147.102(b)(2)(iv)]. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or 'Human safety. The Commission's administrative approval to inject in TBF A-19RD is conditioned upon the following: 1, Injection is Limited to WATER ONLY; ~`[r. Steve Lambert November 2. ?006 Page Z of 2 • 2. Unocal shall monitor and :record tubing, inner annulus, and outer annulus pressures and injection rate daily; 3. Unocal shall submit to the Commission a monthly report of well pressures and injection rates; 4. Unocal shall perform a temperature survey every 2 years in lieu of the mechanical integrity test as outlined in Rule 5 of AIO 12 to demonstrate continued production casing integrity. Fox purposes of this requirement, the next temperature survey is due no later than September 30, 2008: ~. Unocal shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and y 6. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 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 P~1 on the 23rd day following the date of this letter, or the next working day if the 23rd day- falls on a holiday or weekend. A person may not appeal a Commission decisic>n to Superior Court unless rehearing has been requested. DONE at nc orage, Alaska and dated i~~ovember , 2006. f ,,,`~" (~~~ o Norman D niel T. Seamount, Jr. ha ~ Commissioner ~~ ~ Cathy P. oerster Commi sinner · STATE OF ALASKA I ALZA Oil AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well E5 Plug Perforations U Stimulate U Other U Performed: Alter Casing D Pull Tubing Perforate New Pool D Waiver D Time Extension D Change Approved Program 0 Opera!. Shutdown 0 Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development D Exploratory D 188-0010 3. Address: Box 196247 Anchorage, Alasaka 99519 Stratigraphic D Service 0 6. API Number: 50-733-2015101 7. KB Elevation (ft): 9. Well Name and Number: 105' A-19RD 8. Property Designation: 10. Field/Pool(s): Trading Bay State- ADL 18731 Trading Bayl Middle Kenai "C" & "D" oil sands. 11. Present Well Condition Summary: Total Depth measured 7,493' feet Plugs (measured) true vertical 6,012' feet Junk (measured) Effective Depth measured 7,498' feet true vertical 6,012' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,070' 133/8" 1,070' 1,033' 3,090 1,540 Intermediate 4,400' 9 5/8" 4,400' 3,497' 5,750 3,090 Production 3,553' 7" 7,010' 5,563' 8,160 7,020 Liner 691' 5" 7,496' 6,012' 10,140 10,490 Perforation depth: Measured depth: 5755-5890,6032-6140,6476- 6505, 6670-6730, 6934-6950, 6983-7015,7045-7095,7125- 7147,7154-7240,7281-7367. , G &t\~Nß;:¡f) C), Ü \~ . IRE '" ,-'. f:: True Vertical depth: 4514-4622,4735-4822,5097- 5121, 5265-5369, 5496-5512, 5539-5567, 5593-5638, 5664- 5683, 5690-5766, 5802-5881 Tubing: (size, grade, and measured depth) 31/2" N-80 9.3# 5,306' Packers and SSSV (type and measured depth) 7" 29# FB-1 packer Packer 5,296' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 961 BWPD 1100 1200 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Temperature Survey (9-23-06) Exploratory D Development D Service 0 Daily Report of Well Operations 16. Well Status after work: OilD Gas D WAG D GINJ D WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or NIA if C.O. Exempt: 306-262 Contact Steve Lambert Printed Name St:.e-ùe.. l-Q'!Y'. be-(' 1:- Title Advising Reservoir Engineer Signature ~~~c~ Phone 2. (o·ð-ì G:.'5ß Date io I L.\ l 0(0 Form 10-404 Revised 04/2006 Ivy"'_ ~ f>On) <:~~submit Original Only · . III Pressure (psia) 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 0 500 1000 1500 2000 2500 3000 i' ~ 3500 ci ::¡¡ 1::. 4000 .... CI. ( ) C 4500 5000 5500 6000 6500 7000 7500 78 80 82 84 86 88 90 92 94 98 98 100 102 Temperature (Deg. F) Perfs -..~.....". 13-318" 9-518" 5" -iBG - Sept. Pressure -July Temp -Sept. 3 f A-19RD Monopod Platform Trading Bay Field Well History Weil A-19 was drilled and completed as a zone producer in January 1970. initially produced at rates in excess of 3,000 but declined rapidly as water production increased. The well was shut-in in 1974. In 1976, A-19 was a "0" zone injector. The weil historically injected at rates in excess of 6,000 BWPO. Injection was shut-in in 1985 due to collapsed casing in an offset producer. In 1988 A-19 was redrilled north and down dip as a "C" and "0" zone injector. profiles showed ail the water was entering C-7 sand (5,755'-5,890'). The zone and all the "C" zone sands except the C-7 were acidized prior to completing the well. Injection rates were maintained between 2,000-3,000 BWPO thru 2001. The wellwas shut-in for 12 months in 2002 while the waterflood was evaluated. Injection was restarted in early 2003. Since early 2006, injection has been limited to less than 1,000 BWPO to more closely balance withdrawals. . . ~ STATE OF ALASKA . A~ OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS RECEIVED OCT 0 6 2006 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver OAla~TtI~e8I:Cbn$. Commission Change Approved Program [2] Opera!. Shutdown 0 Perforate 0 Re-enter Suspended 1J\1~I.íì 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number.- Name: Development 0 Exploratory 0 188-0010 3. Address: Box 196247 Anchorage, Alasaka 99519 Stratigraphic 0 Service [2] 6. API Number: 50-733-2015101 7. KB Elevation (ft): 9. Well Name and Number: 105' A-19RD , 8. Property Designation: 10. Field/Pool(s): Trading Bay State- ADL 18731 Trading Bayl Middle Kenai "C" & "D" oil sands. 11. Present Well Condition Summary: , f~ t.5.tk Total Depth measured ~' 1rrP t!!.. ~eet Plugs (measured) ~ true vertical '6 2' ,,,of feet ¡þt, Junk (measured) ~ ",-').;. Effective Depth measured ~ 1V/~ feet true vertical 6,012' ~2..¡t- feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,070' 133/8" 1,070' 1,033' 3,090 1,540 Intermediate 4,400' 9 5/8" 4,400' 3,497' 5,750 3,090 Production 3,553' 7" 7,010' 5,563' 8,160 7,020 Liner 691' 5" 7,496' 6,012' 10,140 10,490 Perforation depth: Measured depth: 5755-5890,6032-6140,6476· 6505, 6670-6730, 6934-6950, 6983-7015, 7045-7095, 7125- 7147,7154-7240,7281-7367. '.;,f. .. I"",,,,t-, ; C <.""."" ,- True Vertical depth: 4514-4622,4735-4822, 5097- 5121,5265-5369,5496-5512, 5539-5567, 5593-5638, 5664- 5683, 5690-5766, 5802-5881 Tubing: (size, grade, and measured depth) 31/2" N-80 9.3# 5,306' Packers and SSSV (type and measured depth) 7" 29# FB-1 packer Packer 5,296' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 CT :1 1 2006 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: 961 BWPD 1100 1200 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Temperature Survey (9-23-06) Exploratory 0 Development 0 Service [2] Daily Report of Well Operations 16. Well Status after work: OilO Gas 0 WAG 0 GINJ 0 WINJ [2] WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I ~Undry Number or NIA if C. O. Exempt: 306-262 Contact Steve Lambert P,iot,dN,m, _~~;;_~¡~t Title Advising Reservoir Engineer Phone 2.0'3:/ G~~ ð Date :.1-0/4/ 0 (0 Signature ~ '--' ' . Form 10-404 Revised 04/2006 ~I Submit Original Only O~ - . h\ ,ÃÞ /' Z~ ~ JIIÉ' ~ rnIJerar[l~ {~'..'.".'.'. &01.···. . ~'........ g'"'"'UU lLM YI ((fiù~'lYmúû c.::~ L...,;.:j ~ 01 u © Chevron 2005 DOC ID I - Pressure (psia) 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 500 1000 1500 2000 2500 i 3000 ~ Ô :æ 1:. 4000 Q. Q a 4500 5000 û' ,., ,... II) ~ I' ,.- 7500 - --+-. ~~.. --+ ì 76 80 82 84 86 86 90 92 94 96 98 100 102 Temperature (Deg. F) r ,..... Perfs 13·318" 9-5/8" 0 7" 5" - TEG Pressure -July Temp -Sept Temp --- <µ . . 3 .. . . Ä-19RD Monopod Platform Trading Bay Field Well History Well A-19 was drilled and completed as a "0" zone producer in January 1970. The well initially produced at rates in excess of 3,000 SOPO, but declined rapidly as water production increased. The well was shut-in in 1974. In 1976, A-19 was recompleted as a "0" zone injector, The well historically injected at rates in excess of 6,000 BWPD. Injection was shut-in in 1985 due to collapsed casing in an offset producer, ./ In 1988 A-19 was redrilled north and down dip as a "C" and "0" zone injector. Initial profiles showed all the water was entering the C-7 sand (5,755'-5,890'). The "0" zone and all the "C" zone sands except the C-7 were acidized prior to completing the well. Injection rates were maintained between 2,000-3,000 BWPO thru 2001. The well was shut-in for 12 months in 2002 while the waterflood was evaluated. Injection was restarted in early 2003. Since early 2006, injection has been limited to less than 1,000 SWPO to more closely balance withdrawals, v' Cl.III'MaiiveOifProd; 238f. f5BMbbl ¡¡Veils SeleCted (4) <Amoiguous'> Cum..daliveGiSPtod: 152S.2MMMØ ~I. ~F--" ~W~~=I , m ,~" ,'" .. . . " " " . " . " . . . " . . . . . " . "'= " . . . ~ . ""'" ". 's ,¡ ~ ,!. ~ .0 41 ,;z ioJ '" !.5 "" 1/ ... !II '10 ¡, '17',. .. 1!j .,¡: " ,i., iI!I lIioo ,,' '" ¡ J 'It œ¡ :Iõ Re: A-19RD Pressure Communication . . Steve, Thanks for sending the information following your call. The rate and pressure data shows the 9-5/8" casing and tubing essentially tracking which would be expected with a tubing leak. Since the combined tubing and casing system is showing to be capable of holding pressure, keeping the well in service is acceptable. Tom Maunder, PE AOGCC \~-oa \ Lambert, Steve A wrote, On 9/26/2006 4:57 PM: Tom we did not actually start our injection test unW August 27. We ran the follow-up confirmation temperature survey on September 23. Unfortunately, the well was still receiving injection, so the survey has no value. We are planning to rerun the survey tomorrow. We will forward the survey results to you as soon as we receive them. Attached is a plot of the rate and pressure data for the past 60 days. From: Lambert, Steve A Sent: Thursday, August 10, 2006 9:55 AM To: 'Thomas Maunder' Cc: Greenstein, Larry P Subject: RE: A-19RD Pressure Communication ~.", ~'ia.".. en NO\! 2; Û ht)Á~~~1\~ Your observation is correct. This well had a poor initial cement job and was squeezed 4 times to provide cement isolation. The squeeze perfs are all adjacent to or within existing perforations. There may be some water moving behind pipe to the interval at 5,432'. This zone is the C-5 sand and is not being actively waterflooded in other wells. There does not appear to be any water moving above this point. The zone is below the packer at 5,295'. From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 09, 2006 10:10 AM To: Lambert, Steve A Cc: Greenstein, Larry P Subject: Re: A-19RD Pressure Communication Steve, There are some coolings indicated above the listed perforations. The whole profile changes there from steadily increasing to isothermal or cooler as one goes deeper. What is your interpretation? There were a lot of squeeze holes shot in the 7" liner. Might they have an effect? Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 8/9/2006 7:25 AM: Tom here is the baseline survey. I don't see any issues with this initial survey. 10f2 10/24/2006 8:53 AM Re: A-19RD Pressure Communication . . From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Tuesday, August 08, 2006 4:05 PM To: Lambert, Steve A Subject: Re: A-19RD Pressure Communication Steve, I am reviewing the sundry you submitted. You indicate that you have obtained the baseline temperature survey. Would you please send that in. Email is fine. Also, please include your interpretation ofthe survey. Thanks in advance, Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 7/25/2006 6:51 AM: We had the Cameron man out to the platform on Saturday and he serviced the wellhead. We returned the well to injection yesterday afternoon. Tubing and casing pressures remained good for about 6 hours and then the casing pressure went to 1100 psi. Same as the tubing pressure. The well was shut-in and we will apply for a variance. From: Lambert, Steve A Sent: Wednesday, July 19, 20066:44 PM To: 'Thomas Maunder' Subject: RE: A-19RD Pressure Communication I checked with the guys on the platform and they said they have not been bleeding the well off, so the drops in pressure are most likely due to gauge or recording errors. From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Wednesday, July 19, 20063:32 PM To: Lambert, Steve A Cc: Santiago, Johnny T; Cowan, Tim S; Braun, Eric D; Geller, Greg M; Dolan, Jeff J; Cole, David A Subject: Re: A-19RD Pressure Communication Steve, et al: Thanks for the notice. Looks like a lot of chatter in the casing pressure reading beginning in early May. Any assessment of that? Prior to the pressure climbing in early July, there are no reading for the lA. Why is this so? It appears the pressure was bled down late in the first week of July. Was pressure bled off at other times. Thanks in advance for you reply. Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 7/19/2006 2:42 PM: «A-19RD Pressure Data 2006 07 18.xls» We just became aware that the casing and tubing pressures in injection well A-19RD are tracking (see attached plot). We have shut the well in today and we plan to do some follow-up diagnostics. We will pass on the results of our diagnostics 20f2 10/24/20068:53 AM 200 1400 1200 1000 800 600 400 o Rate 08/01/06 on 1 at AM 08/11/06 Time 09/10/06 600 200 Prism 1400 !! !'II Q: - 00 - "' I I Pressure (pSÎII) 200 400 600 800 1000 1200 1400 1800 1800 2000 2200 2400 2600 1500 2000 2500 7500 78 80 82 84 86 88 90 92 94 96 98 100 102 Perfs 13-3/8" 9-5/8" - Temperature ... Pressure (psia) 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 7500 78 Temperature Î 3500 ci ~ 1::. 4000 is.. ~ 4500 Perfs 13··318"" 9-5/8'" TBG Pressure Temp Temp .. . . FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA. OIL A1Q) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Lambert Reservoir Engineer UNOCAL PO Box 196247 Anchorage, AK 99519 OÐ\ \ f6Cb - Re: Trading Bay Field, Middle Kenai Oil Pool, A-19RD Sundry Number: 306-262 Dear Mr. Lambert: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this £:ay of August, 2006 Encl. ~75 e//¡;:; Ib ('A! -f I! A' . STAT~~lLASKK''1 6,/5 t¥ê.,s.{ ALASKA OIL AND GAS CONSERVATION COMMI ION ({Q APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Commissior RECEIVED AUG 0 3 2006 Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: P.O. Box 196247 Anchorage, Alaska 99519 Suspend 0 Repair well 0 Pull Tubing 0 20 MC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 . 1 . Type of Request: Perforate 0 Waiver 0 Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 188-0010' Service 0' 6. API Number: 50-733-2015101 ' Õ1her 0 7. If perforating, closest approach in pool(s) opened by this operation to~eares property line where ownership or landownership changes: lP .oJ. Spacing Exception Required? Yes 0 No /~,S A-19RD . 9. Property Designation: 10. KB Elevation (It): 11. FieldlPool(s): /flIt:> ¡<EAlA;:1:. 4. ~» Q'1::I- LÞ Trading Bav-State ..fÞ'- Iß'73/ ~".ø~ 105' Trading Bay! Tyonek "C" and "0" zones /""$·ß·cIø 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (It): rTotal Depth TVD (It): Effective Depth MD (It): Effective Depth TVD (It): 7,498' 6,012' 7,498' 6,012' Casing Length Size MD Structural 8. Well Name and Number: ~PIU9S (measured): Burst JUnk (measured): TVD Collapse Conductor Surface Intermediate Production Liner 1,070' 133/8" 1070' 4400' 9 5/8" 4400' 3,553' 7" 7,010' 691' 5" 7,498' 1,033' 3,497' 5,563' 6,012' Tubing Grade: N-80 9.3# 3,090 1,540 5,750 3,090 8,160 7,020 10,140 10,490 Tubing MD (It): 5,306' Perforation Depth MD (It): Perforation Depth TVD (It): Tubing Size: 5755-5890,6032-6140,6,476 4514-4622,4735-4822,5097- 31/2" 6,505,6670-6730,6934- 5121,5265-5369,5496- 5512, 6950,6983-7015,7045-7095, 5539-5567,5593-5638,5664- 7125-7147,7154-7240,7281- 5683,5690-5766,5802-5881 7367 Packers and SSSV Type: 7" 29# FB-1 Packer 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Packers and SSSV MD (It): Packer @ 5,295' 14. Well Class alter proposed work: Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact C-¡t; ~. 'C> '--'o,,,,,^ .\r-. €.,..¡-t_ Printed Name 0- C" '''u = . \ \ ~ Title '\:) r=> .; t::= _ ""',...., , 0 ~ ~ture,.,\...- í\.J ."J ^ s=_ ~ h Q '<'C"\ ''-J~_ "" "'.= f'... ;a\~ t:=- -0 \r\ r \ ,""'u.u.... \~ r::. V~ qn·,. --;J f... ~ ,"7 rroo ,=... P-.. r.i. ,,.... .c........ -\ ç. ( If)('''''' "' COMMISSION USE ONLY --..> Date: Exploratory 0 Development 0 Service 0 16. Well Status alter proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Conditions of approval: Notify Commission so that a representative may witness SUndry Number: :?:oW· fJ..k ().; Approved by: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 RBDMS 8Ft AUG 1 6 200 Other: \-\C\"\\\o\-\~~ f(è.~"-\..-~ o...~ ~\c:,...~~, . . ~~~~~~~<è: ~~~CL'.Â\-c0ÇJ ~ê~~~ r{)\-\o..~,.\k\'... ~\ß,;)OOc.., Subsequent Form Required: 4t>L\ "'-s-I ('L\dli \<.~~ C;~~1 (/jll~ 7ì~ ¡:¡;-riil/~ J ~~ qOMMISSIONER Form 10-403 Revised 06/2006 w.-f\~...." ~ ,.. N...- APPROVED BY THE COMMISSION Da".iS'¡1': ....~ I Submit in DUPliC~ ,¡f¡-/t:i5 . . ~~) ..J~L~ Þj kf¿ ~ II ~ bil) Irk..- 1ft{ ~J, ~~ \..)~\ ~ ~~~-\.d .~ ~<è~-\"'~ ~«:\\..,\",~~~~((: ~I ~' ~ð... (.Q""-M,,"':)f'O.."\.cc:á-'-<o\"'--.. ~~~~~~~~ " \~~~~ ~c\\~~ c..~c~«:: \4~~~~~\",~\'-.)Q\+ :CO\-"~ \\b:\" \-~:\- \- \....(( ~ "\s .ç\c~ où\-"-:,\<t}(ê -\ ~ ""\ \\ \\~\ +e ~~c;,. ~~ ú.~ù~ +k \>~c~,..~~\-". !:~tJ~<è,> N:>\-ú.~~\ -\-~\- ..\.\o~ ey.~~ '-.)~~~. À- \ !-\...o~\... .Ç \Ð ~ ~ a. b~ --\-~ ~~~, G..\ \ '\ ~~'- \-~(,'\ ~ ~\-~ \)...)'~~\o-- -\-k: \,,~~ \ S~~\ \¢:~ '\~~tc ~\O. T",~<ë)~~~~.~~~ G-~ c.cy~~\-rol"--~r'\ ~\",\ ~\ h~\;J ~({) ~\-~k-~ ~~-\-C(.-t t'~~ t.()Œ\è'''-\~,\O~~\('J-)\\0 1..' ~""""....e~ ().,~UO-\ ~ ~N:>CcL~C ~'.)~s.<l 4£~~ <t:J (t- 0 ~ 500 1000 1500 1750 Pressure Report date: 8/1012006 RE: A-19RD Pressure Communication . . Your observation is correct. This well had a poor initial cement job and was squeezed 4 times to provide cement isolation. The squeeze perfs are all adjacent to or within existing perforations. There may be some water moving behind pipe to the interval at 5,432'. This zone is the C-5 sand and is not being actively waterflooded in other wells. There does not appear to be any water moving above this point. The zone is below the packer at 5,295'. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, August 09,2006 10:10 AM To: Lambert, Steve A Cc: Greenstein, Larry P Subject: Re: A-19RD Pressure Communication Steve, There are some coolings indicated above the listed perforations. The whole profile changes there from steadily increasing to isothermal or cooler as one goes deeper. What is your interpretation? There were a lot of squeeze holes shot in the 7" liner. Might they have an effect? Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 8/9/20067:25 AM: Tom here is the baseline survey. I don't see any issues with this initial survey. From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, August 08, 2006 4:05 PM To: Lambert, Steve A Subject: Re: A-19RD Pressure Communication Steve, I am reviewing the sundry you submitted. You indicate that you have obtained the baseline temperature survey. Would you please send that in. Email is fine. Also, please include your interpretation of the survey. Thanks in advance, Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 7/25/2006 6:51 AM: We had the Cameron man out to the platform on Saturday and he serviced the wellhead. We returned the well to injection yesterday afternoon. Tubing and casing pressures remained good for about 6 hours and then the casing pressure went to 1100 psi. Same as the tubing pressure. The well was shut-in and we will apply for a variance. 10f2 8/10/2006 3:57 PM RE: A-19RD Pressure Communication . . From: Lambert, Steve A Sent: Wednesday, July 19, 2006 6:44 PM To: 'Thomas Maunder' Subject: RE: A-19RD Pressure Communication I checked with the guys on the platform and they said they have not been bleeding the well off, so the drops in pressure are most likely due to gauge or recording errors. From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Wednesday, July 19, 20063:32 PM To: Lambert, Steve A Cc: Santiago, Johnny T; Cowan, Tim S; Braun, Eric D; Geller, Greg M; Dolan, Jeff J; Cole, David A Subject: Re: A-19RD Pressure Communication Steve, et al: Thanks for the notice. Looks like a lot of chatter in the casing pressure reading beginning in early May. Any assessment of that? Prior to the pressure climbing in early July, there are no reading for the IA. Why is this so? It appears the pressure was bled down late in the first week of July. Was pressure bled off at other times. Thanks in advance for you reply. Tom Maunder, PE AOGCC Lambert, Steve A wrote, On 7/19/2006 2:42 PM: «A-19RD Pressure Data 2006 07 18.xls» We just became aware that the casing and tubing pressures in injection well A-19RD are tracking (see attached plot). We have shut the well in today and we plan to do some follow-up diagnostics. We will pass on the results of our diagnostics 20f2 8/1 0/2006 3 :57 PM Area Injection o~r~. 12 Page 3 November 20, 1986 , NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affected area: SEWARD MERIDIAN T9N R13W TI0N R13W Section 3 : All. Section 4 : All. Section 5 : E.\. Section 8: NE%, N% SE%. Section 9 : N.\, N.\ SE-\, N~ SW~. Section 10: N~, N~ SE~, N~ SW~. Section 33 : S\ SE-\. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Union Oil Company of California Trading Bay State well A-17 between the measured depths of 3220 feet and 8270 feet for the Trading Bay Middle Kenai liB", "C", liD", "E" and Hemlock Oil Pools. Rule 2 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 3 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. . . Chevron === Steve Lambert Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519-6247 Tel 907 263 7658 Fax 907 263 7847 salambert@chevron.com August 1,2006 RECEIVED AUG 0 3 2006 Alaska Oii & Gas "ons C '. '-' , . ommlsSlon Anchorage Tom Maunder Alaska Oil and Gas Conservation Commission 333 W ih Ave #100 Anchorage, AK 99501-3539 Dear Tom: Unocal is proposing to return well A-19RD to injection. Enclosed is form 10-403. Well A-19RD experienced pressure on the tubing casing annulus and was shut-in on July 24. The well is a critical component of the efforts to maintain productivity and improve recovery from the Tyonek "C" and "D" reservoirs. Following is the proposed procedure for bringing this well back on injection. 1) Baseline temperature survey. (Static survey obtained following confirmation of tubing to casing communication.) 2) Obtain permission to inject. 3) Inject until the well has stabilized (approximately 1 month). 4) Follow-up temperature survey. 5) Obtain variance to inject. 6) Monitor well daily and repeat temperature surveys every two years. Please let me know if you require additional information. Sincerely, h~rx~ Steve Lambert Enclosure 2000 800 1800 1600 Hours 1600 1400 - Rate 1400 1200 1200 000 ~ ::¡ s m 1000 ~ ~ Œ: Q. 800 800 600 600 400 400 200 200 o 03/04/06 03/24/06 3106 07/02/06 07122/06 08/11/06 . . S~\JJd ~~ ~ 0 If\ ( I eo. 'r Q..ð, : -/ -, ....~MECHANICAL INTEGRITY REPORT (¿,U , ,,:;;'~1j:>1 ../ -',,;; ~'o "';~ ._, :"':) OPER & FIELD 'WELL NUMBER ~"". ,-, ! b tA.. ~." ";.7 i'.·.. - .', ;'.-f Y"'! ,'F" ,-,¡ Y!! n _;:: " 1 JI ~_~<-< ~~-/..v .¡ : ·".70··j :...:;; " ,'-·-'1. v j';") <·'1<- i D -- TD: ""5"0:.:; MD b:,:;;·:,'3TVD j PBTD: -r4' t Y MD .$'9 '2,.¢TVD -tv? Sho e : ~tð' ¡" Ç..l MD TVD j'~DV: ".;/4 ;;'7 MD TVD t.7ELI. DATA , / -: "'/"!. i,~\ r. v __~_ ....ca..s..~- -¡ . .;¡"~¡¡;J Liner :L\! (8 ~"J Shoe: '1''f'1b MD TVD j TOP: o¡f;8,Ji MD TVD j Set at 5TS)' f) TVD Tub ing : ?jj /-.- Packer .s '2. 9 ~ Hole Size ï" ¡'''- [//2- and 3rt -,';1, .,1'''' ~,f- ~-; Perfs ..57 S'!:T to -t3f:. 7 MECHANICAL INTEGRITY - PART # 1 j' 15 min 30 min Annulus Press Test: IP Comments: . MECHANICAL INTEGRITY - .PART #.2 ~_'--t.. /#1 ,J'lle~ ,Ðß5tXCement Volumes: Amt. Liner"(: {~ö5'/I; ~ j lfS S¥; DV ~í c,"h<Á<t ~.f(.ï0:;,fr~ . Î. t ~ 35),,3\ ,'" ,,_ S" ::- . ~('2.. 5~mt vol to cover perfsl7'<.9G-'t'l(Is-Lo8-5?-t- (~ ¥..167S) -+(-:'£16 -bf:¡e:J1J..OS{Z::. 4-3 '$.'f ~9-fr~~ 2<::>ð /b -e..~c~~> OY' ç!,'~ MOl ()-.s-7~» ../òe;?......l36 S1ö- U~~~~ ~~ ~~'f et!~.. Theoretical TOC 57.s-S-ilioð -f'3'J.::"',(O e~J ,::...s lfð · 11' ~'ð!¿d ::.. fOS) . 'I A ? . J -. V ~S Cement Bånd Log (Yes or No) c~/~": ''':, j In AOGCC File t!Z:!.Z I, CEL Evaluation; zone above perfs GÒbd }Y\y\c~in;J}.r"J.\j t p12.rf$. Production Log: Type Evaluation CONCLUSIONS: ~~ .~ ~~ ,,~~ '\./ \'~ P ar1: 11: P ar1: # 2: ìV1} ;C;. /~ l'1¡Y" (fd'~;nº rev. OS/20/87 "". ~ ,j" '" r I::>¡S!S''''"' ., C.028 A-19 7-26-06 temp survey.xIs . . Subject: A-19 7-26-06 temp survey.xIs From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 10 Aug 200615:58:16 -0800 To: steve Davies <steve _ davies@admin.state.ak.us> T~ ~~~+~ ~-\~~'Y ~~O~~Od ') The temperature survey. \~-OO \ Content-Type: applicationlvnd.ms-excel A-19 7-26-06 temp survey.xls C E d" b 64 ontent- nco mg: ase ð~~ \~ \.\..\ \rc-- 0" v..)ft\ \~ 'dr\~e- SCANNED JUN 2 5 2007 lofl 6/25/2007 11 :54 AM o o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 70 \ \ 250 750 1000 1500 2000 2250 2500 1250 1750 500 75 80 85 90 95 100 105 Perfs Report date: 6'25/2001 , I:'l'" ( MEMORANDUM State of Alaska ^ l\..~ S1~/kB Oil and Gas Conservation Commission TO: Randy Ruedrich II \¡t> OJ'DATE: April 4. 2003 Commissioner 0 r' \2;lt't SUBJECT: Mechanical Integrity Tests THRU: Maunder/Regg UNOCAL Petroleum Engineer's Monopod platform A-19RD, A-8RD2 FROM: Lou Grimaldi Trading Bay Field Petroleum Inspector Trading Bay Unit NON- CONFIDENTIAL 4 P Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) T est's Details I witnessed mechanical Integrity tests on A-08 RD2 and A-19 RD aboard the Monopod platfonn, both wells passed their tests A-08 RD2 already had annulus pressure above required test pressure, I observed this for thirty minutes with no change. The armulus pressure was dropped 650 psi and observed for an additional thirty minutes with no change. M.I.T.'s performed: ~ Attachments: None Number of Failures: None Total Time during tests: 3 hours cc: Gary Smith (MonoDod) .. .r""'" MIT report form 5/12/00 L. G. SCANNED JUN 1 9 2003 2003-0404_MIT _ TBF _Monopod_A-08RD2Jg.xls 5/8/2003 MR~. 1.¿~~¿ (:¿SRM I'1V . :>£::q r . c./ ,", .. J; ....' ,.-......\ ~ UNOCAL PLATFORM ANNA WELL #19 PRESSURES Month; February..Q2 f4..-\~ Q \) \<6<6-00\ Date Tubina 951811 13 318" BBl"s Injected Comments 1 2605 2600 30 228 #2 Hammelmann down 24 hrs 2 2532 2600 , 0 222 Both pumDS down 2 hrs for DumD #2 repair 3 2588 2800 0 215 4 2600 2800 0 220 5 2600 2600 0 212 6 2600 2600 0 213 - 7 2600 2600 0 211 8 2600 2600 0 208 ,~ ,....9.. ,2600 2600 0 226 .. 10 2610 2600 0 226 11 2615 2600 10 225 , 12 2686 2550 10 217 13 2604 2600 10 210 14 2610 2600 10 220 15 2586 2550 10 197 16 2596 2550 0 216 17 2611 2600 0 214 18 2600 2600 0 215 19 2600 2600 0 205 20 2600 2600 0 184 _.--- 21 2600 2800 0 206 22 2600 2600 0 201 -~ 23 2600 2600 0 19Q 24 2600 2600 0 191 -- 25 2601 2600 10 196 26 2548 2600 10 204 27 2611 2600 10 210 m_ .. 28 2582 2550 10 205 .... . 29 ~- 30 31 Copies To: JUlie K~be"'t'ln, Kenai Office Fax: Blair Wonzell·9.1"'07~276..784~ Alaska Oil & Gas Assoc. F :'msotflcø\exçef\m o-8ndOO\ 1 ~"I't!S~ .xls Well #19 File I mil UNOCAl. PLATFORM ANNA WELl_ #19 PRESSURES Month: Jmnumry-02 Date Tu blng ,9.,6./.8" 13 3f8' BBL'sJpJ_m:ted Comments I 2615 2608 0 210 2 . , 2390 24,00 ..... 0 186 ,. #! Hammelmann prop dn_~ can_run E 3 2299 2300 0 ..... 123 #1 Ham .m.,.elmann prnp dn so can mn BJ 4 2596 .260.0 0 160 #1 Hamm,e!~..,ann prnp dn so oan ~.n BJ 5 2608 2600 0 237 6 2032 2600 0 218 7 . 2610 2600 0 216 8 2600 2600 0 208 9 2630 2630 0 209 10 2600 2600 0 210 11 ..... 2600 2600 0 202 .D. own 1 hr. AC fallur,e , . 12 __2600 26013 0 219 13 2600 2600 0 220 t4 2600 2600 0 222 15 2588 2600 0 217 16 2626 2600 0 214 i., 17 2596 2500 10 214 18 .... 2605 2600 1,0_ .68 W.F. Pumps down 16 hrs_^C down 19 2590 2600 10 229 i ,, J l,,~,,, , ~--,,_ ~ .... ~- ............ 20 2592 2600 10 209 21 2615 2600 0 204 22 2600 2600 0 203 23 2600 2600 0 212 24 2600 2600 0 210 26 2600 2600 0 210 26 2600 2600 0 195 27 2600 2600 0 218 28 25g0 2600 0 222 , m. i .... · - .' 29 2610 2600 0 217 30 2617 2_6.,00 ,,,0 , 230 #2 Hammelman. n down 24 hrs_ 3t 2614 2600 o 231 #2 Hammelmann down 24 hm Copies To: Julle Kobersteln, Kenal office Well m0 File Fax: Blair Wonzell.9.1-907-278-TS42 Alaska Oil & Gas Aesoc. F Ameoffine~et~el~mo-endOa\lt~pres~.xls UNOCAL PLATFORM-A~N-X .... WELL #t9 PRESSURES Month: December-D1 ,,~, ........ Date Tubing 9 $18" 13 318" _B..BL's InJec_ted_ _ Comments I 2350 23§0 0 226 2 2350 2350 O 226 3 2350 2300 0 204 4 _.~5_1j.1_ ......... 2_5~0, 40 202 Down 2 hrs to work on pump 5 ,2286 230,0 ....... 50 205 6 254,9 2300 50 195 7 2419 2300 60 , ,190, ...... , 8 2~67 2450 60 176 ! i :_~ ....... - .... .... 9_~. .............. 2567_ ......... _2_4_8~. .................... 6,0 ............ : ........ 97 Dpwn..11 h~.f. pr. V-;!8 reFair lo 2413 2400 60 104i,Down 14 hrs for V-18 repair 11 2600, 2800' 50 260 I in ,.. 12 2600 2600 60 258 13 2600 2600 60 246 14 28!5 2615 50 250 15 2800 2600 50 238 16 2625 2625 0 . 243 1;' 2600 2600 30 237 18 2600 2600 50 238 19 2600 2600 60 237 20 2650 2680 10 247 21 2600. 26001 10 246 22 2600 2600 10 240 __ ,-~u. · . . 23 2600 2600 20 151 -. ~ , ,.. .. ,~-- _ ............. 24 2600 2600 40 232 25 2600 2600 0 230 26 2600 2600, ..... 0 222 27 2600 2600 0 222 28 2600 2600 0 218 ......... ,,~ I . , 29 2600 2600 0 223 · . ~, r .T~,,~.-- 30 2600 2600 0 221 31 2612 2600 0 213 J[ I II alii uae IMamet form MID Copies To: Julia Kobemtein, Kenal Office Tom Maunder, AOGCC fax: 907.276-7542 Well ~ g File F:~ms~iee~e~el~mo-en~gB~lgpress,xts " UNOC~.L PLATFORM ANNA ' WELL #19 PRESSURES Month: November-01 i.~. imm __ II, .. · D te Tubing_ 9 Sm" am- mBL' In e t ., Commenm 1 2450 2450 0 187 __. 2 2200 2200 0 182 3 2200 2200 0 186 4 2260 2250 0 183 __ · $ 2227 2250 0 182 6 22~2 2250 0 181 ,, m ,~ ,,, .._ - 7 2341 2300 0 188 ~ ,~ .... , .. i , 8 2334 2350 0 166 9 2316 2309 0 189 ...... 10-;" ~-i'.i.' 2'300 2300 .... ~ii ...... "-'0 ............. t55 ' .i..' ...... . ,-, 11 2674 2200 0 71 Down 15 hrs for pump rep~!f .... [ 12 .2445 2200 . 0 ........ J_ 181 ,,, 13 2463 2200 0 179 IllJll.ll __ Il . 14 2173 2150 0 171 .... .-,..-~,:*__. · . , , 16 2297 2350 0 181 .... 16 ..... 2400 2400 0 179 . . 17 2350 2350 0 175 . J · -, . i..i. mfl ' L t8 2750 27.5.0..' . 0 118 Down 1 hour for level control problem. 19 2357 2300 10 0 _ ? q tt_ -- ..a.,_ 20 2357 2300 10 0 ,~,,., ._ ~_tm · ,, .................... 21 1056 - 1060 10 0 ,.. Down 24 hr bad high pressure pump hoses _22 995 1000 .......... 10 13 Down 24 hr bad..h_igh, pressure pum.p..h?Ses 23 952 950 10 0 _ Dow~n. 24 hr bad high pressure pu_mp .hoses _ 24 922 950 0 . 0. ........ Down 24, hr bad hil~h pressure pump hose_s_. 25 904 900 0...... 0 iDown 24 hr bad high pressure pump hoses 26 880 8.,5,0 ........0 0 iDown 2-4 hr bad high_pressure p_u._rn.p hoses 27 880 850 0 0 Down 24 hr bad I~igh pressure pump hoses 28 880 .,850 0 0 Down 24 hr b,a.d.,,high pressu,re ..... pump_ hoses ,, 29 235O 2350 0 79 Down 16,5 hr bad high pressure p.,ump hoses 30 2300 2300 0 199 31 II II ........................ uH Intemet form also Copies To; Julio Kobemteln, Kennl Office Tom Maunder, AOGCC fax: 907.276,7542 Well #19 File F:~me~leme~el~ma-andge~lgpra...~1. rogc 01 200 ~aska 0~1 & ~, ~ , · · . ...... UNOCAL WELL #19 PRESSURES Month: October-01 Date TubinD 9 5/8" 1:3:318" BBL'w Injected Comments 1 2655 2650 0 268 2 2650 2650 0 26'I 3 2615 2600 0 259 p 4 2650 2650 0 259 5 2650 2100 0 246 6 2200 2200 0 160 7 2100 2100 0 159 8 0 0 ~ 0 95. ............ DOw? .,14. h,,ou, m,tp repair injection pumps 9~ 1096 1700 1088 0 Down 24, ,hou~ to mRalr iniection pumps 10 _l _2_500 ........ . :..1.._.._.l-__2450 ~ 2473 83 Down 14 hours to repair in~?ction, ..... ,pumps,, .. 11 2188 2760 2173 164 12 2190 2700 2180 73 Down 15 hours to rep~!r injec, tion pumps__. 13 1010 2500 I000 , 0 ' Down 24 hours to repair injection pumps 14 ... 963 ,.. 26.,.0,p 954 0 Down 23 hours to repair injection.pumps_.. _.!$ ...... _2j70 .... .21Tq ........... 0 208 . ...... 16 2250 2250 0 200 11 2480 2250 0 194 18 2490 2200 O 189 19 2450 2450 0 186 20 2250 2250 0 qB0 21 2200 2200 0 181 22 2250 2~-50 0 182 25 2250 2250 0 178 24 2250 2250 0 179 25 2400 2400 0 26 2400 2400 0 180 27 2400 2400 0 100 28 2400 2200 0 189 29 2200 2350 0 182 30 2200 2200 0 181 31 2200 2200 0 18~ ............................. il il ii i Copies To: Julia Kobemtein, Kenai Office Well #19 File u6e Interest fof~ Tom Maunder, AOGCC fax:907-276-?$42 ' UNOCAL PLATFORM ANNA WELL #19 PRESSURES ,., Month: Sep~ber-0~ Date Tubing 9 $18" 1 $ 318" EIlBL's lnJ ,e~.,. ted co··eMs , 1 583 900 0 0 Down 24 houm for Plant modification 2 580 g00 ,,0 0 Down 24 hou ,·.for Plant mo,!fi ,r..e.. tion 3 576 900 0 0 Down 24 hours for Plant modifioatlon ., 4 576 900 0 0 .... ,Down :~4 houmJor Plarl! mo, ifica, fion 5 576 .9.90 O. . 0 .., Down 24 hours for Plant moClif_icatiop 6, $76 ._9_00 ~ _0 ,. 0 ..... .."Down 24 hours for Plant maCliflcati,.on 7 576 900 0 0 Down ~4 hour~ for Plant modification 8 57'8 900 0 0 Down 24 hours for Plant moMificatlon 9 5.76 900 0 0 Down 24 houm for Plant mo~llfication 10 576 900 0 0 Down 24 hours fOr Plant m_c)~lflcation 11 7,65 · 900 .... 0 0 Down 24 hours for Plan[,modification 12 765 900 .... 0 .0 Down 24 hO. Nm for Plant mo~l. tfi.cation .. 13 755 . 850 . 0 .._ 0 ...... Down 24 hours for Plant mc~ificat)on 14 7r4? .... 850 D 0.,, Down 24 hours for Plant mO~iflcat, i_on !5. 740 ,8,50 0 .. 0 Down 24 hours for plant modification 16 _, ..5.81 850 ,, 0 0 Down 24 hours for Plant m.~difioation 17 500 726 0 0 Down 24, hours for Plant acidification 18 1.810 2550 ~.- 0 ._1..51 :Down 18 .h,.ours for Plant mq, dif. ication _ 15 2615 2600 0 165 20 2610 2500 0 t 17 , 21 2515 2515 0 170 Down 1 hr AC Loadshed 22 2550 2500, 0 ., 302 Down 2 hrs AC LO, adshed,, 23 26r75 2650 0 260... Down 4 hrs Bad.,,fiow meter,', ,, , 24 2550 255.0 : 0 ..... 282 D?.wn 2, hrs to flush pipeline;, 2s 1834 1900 0 283 ' 26 589 600 0 119 WF dn 15,,h,m while working on,~2 e~rator 27 1.,839 2650 .., 0 306. ...... 28 1821t 2650 0 282 29 1830 2660 0 274 30 183;~ 2650 0 265 Copies To: Julia Kobemtein, Kenai Office Well ~t19 FIFe UNOCAL PLATFORM ANNA WELL #t9 PRESSURES _ Month: August-01 ...... Date Tubing,, 9 5/8" 13 31.8,'.T BBL'a Injected.. Co,,m. ment~ I 2705 2700 0 279 2 2689 __2700 0 272 ...... _ -_ I 3 2.6..9..3 2700 10 266 4 2695 2700 0 264 _ $ 2712 2750 10 265 6 2714 ......... ~750 10 263 .... ,, __ .._ 8 2671 2700 10 221 9 .. ~;82 2600 ..... .10 ..... 2.83 ......... ' ..... 10 2830 2800 10 277 t t 2523 2500 10 260 12 2907 2700 10 270 ._1.3 2765 130q..: 10 _268 ..... 14 2841 1400 10 263 .__ 16 2585 , _ 750 10 , 262 16 2520 700 10 258 17' 2618 700 10 256 , 18 _ 2554 700 __t0 255 .... ~;,,. 19 2846 2600 10 239 20 ,1220 1300 0 .... 0 Down 24 h,,o,u,.ra for Plant mddificati0n , 21 1135 1250 0 0 Down 24 hours for Plant m0difioation 22 1135 1250 .... 0 0 Down 24 hours for Plant mcklification 23 1035 1100 0 0 :)own 24 hours for Plant mCldiflcatlon 24 1035 1100 0 0 Down 24 houm for Plant modifl~tlon 25 970 1050 0 0 Down 24 hours for Plant modification 26 970 .... 1050 0 0 Down 24, houm for P,l,a, nt modification 27 918 1000 0 0 Down 24 hours for Plant modification 28 630 1000 .... 0 0 ......... Down 24 hours for Plant mOcli, fication 29 611 1000 0 0 Down 24 hours for Plant mOtlification _ 30 610 __1..000 0 , . 0 Down 24 hours for. Plant modification , 31 592 g00 0 0 Down 24 hours for Plant m~dification Copies To; JUlle Koberateln, Kenai Office Well/t19 File Fax: Tom Maunder, 1.907,276.7542 AOGCC F:~m soffice~exceltme-endge~ll~pres...l~ -" I~N0CAL PL~:TFORM ANNA ..... WELL #t9 PRESSURES ........ Month: June-01 , Date Tubln~l 9 518" 13 3/B" BElL's Inlected Comments I 1 2635 2700 :, 0 ,372, 2 2660 2700 0 276 · .~. ,; ~ · .. ....... _.__: ..................... --.,-,~ .... 3 2660 2700 0 296 .. 4 2053 2700 0 279 $ 2~::~ 2700 0 278 6 2647 2700 0 282 ' 7 ..2650 ..... _2_650 ~ .... _0, ..7 141 W.F, Shutin Generator Problems 8 1000 2650 0 0 W.F. S~utin Generator Prob!~ms 9 2662' 2650 , 0 257 : _ 10 984 ,2650~ ' 0 0 W.F. Shutin To Repair Leaka ii i iiii ] 11 2650 2650 0 164 Dowry...1.5 houm to repair leak[ 12 2675 2675 0 317 Down 2.5 hours to rep, air 13 , 2660 2600 0 373 ........... p . ,,..,, 14 2650 2650 0 339 15 ..2650 :- ........ ,=_2650 0 235 Down 5 hours due to lack if AC Power 16 2650 2650 0 346 Down 2 hours due to lack if AC Power _ 17 2650 2650 0 :344 18 2651 2700 0 335 Down 1 hours ' 19 ..... :27_3! .... --.::_._~7_~_ ...~.=_ .:::.:::_0.=_:~ ,. , 260 Down 3 hours , 20 2641 2650 0' 185 Down 5 houm ii i i ii1.. ,, 21 2632 2..650 0 288 . . 22 2557: 2600 0 250 23 2528 2600 0 231 , 24 2560 2550 0 229 25 2555 2575; 0 227 , i ~-~, . 26 2565 2565 0 230' _.u, mi ,,-...i. , 27 2560 2560 0 224 28 2646 2545 0 236 29 2550 2550 0 240 ' , 30 2550 2550 0 215 Illl I~l I I I I I Copies To: Jufie Kobemtein, Kenai Office ' Well #!9 File RECEIVED JUL 0 2 2001 i i III I UNOCAl. PLATFORM ANNA WELL #19 PRESSURES Month: May-ol ii; ........................... , --, ;: -r Date Tubinll 9 $18" 13 3/8' EIBL'$ Injected , ,C0mment~ I ............. _0............ 600 ....... 0 0 Dn 24hrs, Bleed down to, rep~.~i,r master valve. __~ .................... _0 .............. .6.0, q. . _ _ ....~ ..... 0 Dn 24hrs. Bleed down to repair master valve. ...... 3_ ......... 0 ............ 60,.0...... ~, ....... 0 Dn 24hrs. Bleed dow~ to ,repplr master valve. 4 0 600 0 0 Dn 24hrs. Bleed down to repair master valve. 5 0 600 0 0 Dn 24hrs. Bleed.down to repair master valve. $ 0 600 0 0 Dn 24hm. ,B!.e.e,.d.d.own to rep,air master valve,__ 7 0 600 0 ...... 0 Dn 24hrs. Bleed down to repair mas.~r valve. 8 0 0 0 0 Drt 24hrs. Bleed,al.own to repatr master valve. 9 10 , , 0 O ....... ~ , .0D,p 2,,4hrs. Bleed d ,e~...._~ repair master valve. 10 0 0 0 0 Dn 24hrs. Bleed down to,,rep,a.,Ir master valve. 11 0 0 0 0 Dn 24hrs. Bleed down to repair master valve, 12 o o t o ........ : ..... 0 D,.n...2~h__r_rt.B_le~ down to repair master vai_v~e~, 13 .... 0 ...... 0 0 0 Dn 24hfs. Bleed down to repair master valve. 14 0 0 0 o'Dn 24hrs. Bleed down to rep;air master valve, t$ ....... ~ .... 0 0 ..... 0,, Drr 24hrs, Bleed.down to repair master valve. 16 ......0 0 0 0 Dn 24hrs. Bleed ~ to repair master valve, 17 . 0 0 0 0 Dn 24hrs. Bleed down to reEa.i? master valve. 18 . 0 0 , 0 0 Dn 24hrs. Bleed down, to, ,r,ep, alr master valve. '19 0 0 0 0 Dn 24hfs, Bleed down to repair master valv, e. 20 ___ 0_ ._ , 0 0 , 0 Dn 24hrs. Bleed ,d .o~, to r~,a!_r..master valve. 211 0 0 _ ._0, .......... 0 ~fl 24hrs' Bleed down to repair master valve. ...... 22 0 0 0 0 Drt 24hr& Bleed down to repair master va(va,, I 23 0 0, , ......O ........... 0. ,.Da 24hrs. Bleed down to repair master valve. 24 0 0 .............O ,,, 0 Dn 24h~ B]~,e~,.d.own to repair master valve, 25 .... ~.5_8 ..... 250' .......0 ............ 8.1. DN_14_h...m AC_ ~/~2_!n_~pectlen. '~cl( of power. 26 ...... 2650 250 0 5741 ............ II I I I 27 2664 250 0 242 28 2650 2400 0 307' ...... i i iiii i i 29 2640 2700 0 449 30 2640 2700 I 0 425 I 31 2640 2700 0 4,11 Copies To: Julia Kobemtein, Kenal Office JUN 0 1 2001 Alaska 0il & Gas ~ns. ~m,m~s,~ ANN~ ' " : ..... '" UNOCAL PLATFORM "' WELL #19 PRESSURES ' Menttl: March.01 ,, ' ,, Date Tubing 9 6/$" 13 a(8',', ,,, .BBL's_lnJeeted .- . . Commerlt~ : t 2659 2700 0 178 Down 7 1/2 hrs for malntenan~ , 2 2636 2600 o 249 3 2694 , 2600 ___0. .... 240 .~,. . 4 2652 2650 0 239 , if, [i , ii 6 2650 2500 0 226 7' 2650 2500 ~ 0 ........ 226 , , AD~ 6 2650 2500 0 224 ...... !0 2645 .2500, . 0 . .. 255 ,,,,AA~ 11 2620 2400 0 238 12 _ 2_6.2..8 2.6..5.0,. O 236 .... 13 2630 2640 0 98 Down 13,5 hrs for maintenance iii i~ :7.'~ ~-. ;- . 14 1065 1100 0 ...... _0.. ?_o..,w.n 24 hfs for maintenance , t5 988 1000i 0 0 Down 24 h,m. for maintennnoe t6 2700 2700 , . 0 115 I:)~wm 17 hrs for maintenance , 17 2660 2650 0 288 ,,.., 18 2658 2675 0 ....... .273.. ,~_ 19 2638 2675 0 253 ,,. 20 2833 2875 0 252 ....... ---. 21 2645 2675 0 248 22 2640 2675i 0 50 Down 20 hrs,for..e_l...e~t_~,?mblems' from fire i. panel 23 2880 .... 2700 ........ 0 56 Down 18 hrs for elect. Pmblems. Tr_q~_fim in panel 24 2654 2700 0 ...... 2..9.1, __ ...25 2835 ..,27_00 0 264 ,, 26 2633 2700 0 .... 255, ..... , ....... ;~7 2850 2800 ~ 0 240' , ,,, 28 1172 2800 0 54 Do~, ,n_1,.,9 hrs to install piping, 29 1038 2800 0 0 !Down 24 hrs ,to,lnstnll_p_lp_ln_ g, 30 976 2800 ....... 0 0 Down 24 hfs to install piping, .. 31 987 2800 0 84 Down 20 hfs to install piping. , Copies To: Julia Kobemtein, Kenai Office Well #19 File Ii ii i i il ii .......... UNOCAL PLATFORM ANNA WELL #19 PRESSURES ' Month: Fobmary-O~ Dat~ Tubing 9 SIS" 13 318" BBL's Injected .......... Comment~ I 2659 2650 0 188 Down 6 bra for maintenance, i 2 2660 2660 0 254 ,, $ 2649 2650 0 244 4 2579 2650 0 _._ ,_236 ,~ ...... ...... $ ....267_1 ...... _:~26_.5,0 ....... 0 24,5 ~ . 6 2670 2650 0 225 .... I ., 7 2659 2650 0 ......... 188 Flood down 6 hrs., sourc ,e.p.u?n_p change. 8 2660 2650 0 224 9 2615 2650 0 243 t0 2625 2650 0 24_2_......... 11 2650 2650 0 230 i 12 2660 2650 0 ,,1!8 Down 12 hrs for pipeline tea,t_. ..... 13 2652 2650 0_ . 257 Down 1 hr for dirt wat.er l 14 2660 2650 0 195 Down 6.5 hfs for maintenance 15 2655 2650 0 24:3 .... _16,. 2645 2650 0 250 , 17 2658 2650 0 246 18 2656 2650 0 242 19 2655 2650 0 ,2.~,._~ ....... , 20 2645 2650 0 238 -T 21 2680 2650 0 241 , 22 2665 2650 0 224 ' 23 2650 2650 0 213 2L4_. 2680 2675 0 232 ..... i ........ .... 25_ .... 2650 2625 0 24~2 ..... 26 2650 2300 0 239 27 2651 2300 0 237 -- , 28 2630 2600 0 233 29 , Copies To: Julie Koberateirl, Kenai Office Fax: Blair Wonzelt-9-1-90?-276-TlM2 Alaska Oil & Gsa Assoc. I Well ~t'19 File r:Vmomce~xeed~m(~-ef~dgeVlepres,,xl. PLAYFOI~i~I" UNOCAL ANNA WELL #19 PRESSURES Month: Jmnuary.0'1 D~e_ ..... Tubing 9 518" t3 318" BBL's Injected Comments 1 2835 2800 0 242 2 __28_1~5 , .,2.?.0..0 __.0 .......... 244 ,,,-- 3 2815 2700 0 2,44 i i m 4 2662 2700 .. 0 165 5 2605 2700 0 258 , 6 2655 2700 0 247 .~. i 7 2631 2700 0 242 8 2612 2700 0 247 9 2607 2700 0 243 __ ii dl il ___. 10 2661 2700 0 243 11 2665 2700 0 238 12 2660 2700 0 247 13 2700 2700 0 246 F ___1~ .... . ..... '14 2630 2700 0 240 15 .... 2600 2700 0 241 t6 2674 2750 0 246 ~7 2647 2700 0 242 18 2646 2750 0 244 19 2607 2700 0 242 .20 2643 2700 0 223 , ,,m mm= 21 2659 2650 0 196 Down 5 hm for main,,tenance, 22 2700 2750 0 247 , 23 2660 2600 0 215 - - 7: t:._...~ ......... .. 24 2620 2700 0 247 25 2685 2700 O 242 26 2715 2700 0 244 I Il mm 27 2700 2800 0 238 , . ~ ,, ~ ~,~,-,, .,.,_.. 28 2635 2T® ........ 0 ...... 239 ,, .... 29 2604 2700 0 233 30 2641 2700 0 239 31 2667 2700 0 239 ' Copies To; Julie Kobemtein, Kenai Office Well #19 File Fax: Blair Wonzell-9.1.907.,276.7~42 Alaska OII & Gas A~soc. 2.001 AJmmlcm OiJ& Com. ... II UNOCAL PLATFORM ANNA WELL #19 PRESSURES Month; Oocember. O0 Date Tubing 9 $/8" 13 3/8" BBL'e Injected ........ Comment~ I 2635 2700 0 249 -- ................. *- ,, , , , ,, · - Ii 2 2686 2700 0 244 3 2610 2700 0 263 ,, ,--,, ..... an · 4 3058 2700 0 248 $ 2731 2700 0 252 ~-:'~:'~.~---'~:~: .......... .7.. ' ..... ,tm · ~ .... ,~..-:.~!~, i 6 ~_ 2626 2700 0 246 ' 7 2644 2700 0 247 8 2594 2700 0 24,6 9 2639 2700 ,. Oi ................... 243 , 10 2746 2700 O[ 251 11 2603 2700 0 253 i I 1 :-; ~c -:.:~ ,~- 12 2628 2700 O, 247 13 2651 2700 0 244 14 2620 2700 0 245 .................. ls_ .................. 2650 __. 27oo ............... 0 ................... 16 26601 2700 0 244 17 2650 2700 0 242 18 2655 2700 0 242 I 19 2654 2700 0 242 ...... 2~-.- 2655 1350 0 138 S1..I.,.1.,. h,rs. for,main, ,t.enance -:~,1____ 2365 2350 0 66 SI -17 hm for malnten~.ance 22 2652 2650 0 259 23 2426 2650 0 266 24 264,2 2700 0 257 ,_ 25 2630 . ....2650 0~ 252 ................. 26 2635, 2700 0 249 27 2655 2700 0 254 26 2655i 2700 0 252 2~ .... 26.4..0_ ..... 2700 0 249 30 2795 2650 0 247 ........ 31 2715 28000 0 256 Ii I I iii fl nil Copies To: Julle Kobemteln, Kenai Office Well #t9 File use Interest form afeo Tom Maunder, AOGCC fax: 907-276-7642 F:~m~ol/ice\ex=el~mo.end§8~l I~pr~;;.~; ~' - ......... -UNOCAL PLATFO~M'~NNA ', ,,:~! 'l 2-000 WELL #t9 PRESSURES ~-'~ ............ ~ ........... ~,~,~ Month: November-O0 ~" ;,~.~'i~' ~ ........................ Date Tubin~l 9 ~/8- la 3/~- IBlaL'~ Injected , Comm_en_~___ . _ 1 2655 2700 0 2~8 , . . _ 2 2696 2750 0 240 · , ~ _, ,.,,,,.,, ,,, 3 2620 2700 0 23~ 4, 2690 2660 0 239 5 2570 2700 0 247 , ....., _ ~..~; ........ ~-- $ 2615 2700 0 245 ,. .... ? 2618 2700 0 229 u .............. , 8 2560 2700 0 170 e 2580 2700 0 163 ~0 2284 2700 0 158 ..~ ,.. 11 2618 2700 0 1~4 ~own 10 hfs for maintenan~ · t2 2665 2700 0 230 ~ ,..m . .- ' 13 2644 2700 0 273 14 2635 2700 0 257 ~5 2651 2700 0 25:3 illin 16 2635 2700 O 245 ,,~. 17 2646 2700 0 246 18 2650 2700 0 246 t9 2650 270D O 242 20 2660 2700 0 243 21 2650 2700 0 240 ,,. 22 2640 2750 0 239 :..._: _~..:~ _.. ~:....._.: , . 23 2644 2700 0 236 24 2650 2700 0 216 .,,, 25 983 1100 0 0 Source pump change, out clown 24 hrs 26 2642 2700 0 158 8oume pump chan~e ou_t.d~,0,wn 13.5 hfs 27 2660 2700 0 285 28 2650 2.7,,.00. 0 268 Turbidity problems, A Filter,'. Down 3 hrs.._ 29 2645 2700 0 265 : 30 2655 2700 0 256 I II ...... Copies To: Julie Koberstein, Kenai Office Well ~! 9 File use Int~rnet form also Tom Maunder, AOGCC fax: 907-276-7S42 F.~ItolRm Mx~ol~mo.endO$\ 10press,xb UNOCAL PLATFORM INELL #19 PRESSURES Month: October.00 ! Date Tubing 9 618" 13 3/8" BBL's Injected Comments 1 2644 2700 0 292 . 2 1311 ,,, ..__2_.7_~0 0 77 Sand filters $.1.11 hfs, for sand change out, 3 1059 2700 0 0 Sartd filters $.1.24 hrs. for sand ~han. ge out, 4 960 2700 0 0 ~Sand filters S.I. 24 hfs, for sand change out. _5 .. 900 2700 0 0 Sand filters S.I. 24 hrs. for Sand change out. ............. ----7 ......... ' -~,: .:--- i .....' ............. ~., .. _..... 6 850 800 0 0 !Sand filters S.I. 2,4.h...rs. for. Sand (~hange out. 7' 800 800 0 0 8and filters $,l, 24 hrs. for sand cha ,age 8 780 ~.0_0. 0 .. 0 Sand filtem G.I. 24 hrs. for Sand change out. , 9 750 800 0 0 Sand filters S.l, 24 hrs. for Sand chan~le out. 10 750 800 ._.,0...... 0iSand filtem S.I. 24 hrs. for sand change out. _ .11 2655 2700 0 259"Sand filters S,I. 13 hrs. for sand change o,u,,t_, . 12 2660 2700 0 435 13 2645 2700 0 387 , ,, 14 2635 270_0 ......... p. ...... _3..6_7 15 2660 2700 0 347 .... [[[ , iii ..... . .. 16 2665 2700 0 306 17 2650 2700 0' 370 18 2637 2700 0 347 19 2690 _2..7P0....... 0 ,,, 303 !_pump for 4 hrs. , 20 ........ _2.5__94 2700 0 291 1 pump nlnning ., ........ 21 _26.7.4 2700 0 331 I pump running 22 2636 2700 0 340 1 pump running 23 2658 27001 ..... 0 328 _1_pump_re.. nnlng ........ 24 .... 2653~ 2700 0 332 1 pump running 25 2603 ...... 2700 0 331 I1 pump running , __2_6__ 2630 2700 0 322 1 pump running 27.,, 1256 2700 0 8B !W.F. down for maint; & tamp survey this well 28 2603 _.2_70.? O ...... i'0-1',!1 PumP run~li-ng-''' . 29 2635 2700 _ .,.0 ...... ,. --,, 23,3'_1._p_u_m_P.~nqln~l i 30 2670 2700 0 244 2 pump runnin~ , 31 2655 2700 0 235 2 pump running I I l, n i ...................... use Intemet for~ also Copies To: Julia Koberstein, Kenai Office Tom Maunder, AOGCC ~ fax:907-276.7642 Well #19 File F:~msolfl~exoel~mo. endge\Igpmss.~$ ! I UNOCAL PL/~FORM ANNA , WELL #19 PRESSURES Month; July-oo .... Date Tubin~ 9 s/Ir' 13 318- , .... ,BBL's I~ected ,comments I 39,4 .550 0 0 Down 24 hrs, with in~ectlo.,n.,pump problems. . ..,2_ 394 550 0 ... 0 Down 24 hrs. with,in, jection pump problems._ 3 357 450 . _0 ,0 Down..2_,4 hrs. with injection pump problems. 4 354~. 450 10 ,, 0 Down 24 hfs, with I,nJ.ection pump problems. _. $ 2700 275~0 0 250 __ Down16 hrs. with inject, ion pump problems. 6 .... 2700 2750 0 285 Down 11 bm. with injectiop_pump problems. 7 2699 .. 2750 0 _ 410 Down 8 h,,m..,: with injection pumppr.oblems. 8 2697 2750 0 473 · ~ ,ri , , m _ .. i i ' 9 2695 2750 0 440 10 2685 2750 0 421 · --,. i i ! J~' 11 27~-0 2750 0 · ~ 2 2700 2700 ..... 0 2.00 Down 14hrs. ,T,o modify OB valve Rjptflg 13 2685 2750 0 4,54 , , .~ -':'m.. ~* IIIL I 14 2695 2750 0 413 J_~,, · · ~.. 1~ 2700 2750 0 395 i i,[m __ m I I _ i 16 2675 2750 0 388 · i In 17 2693 2750 0 364 .. _ __ la 2685 2750 0 370 , 19 2663 2750 0 369 20 2692 2750 0 365 21 2650 2750 0 360 u,, - i ,i fa . - - ' ___2_2 2692 . .2,7.50 0 375 ..... .. 23 2679 2750 0 368 --,, ,,,- i i .... , . i 24 2690 2750 0 368 26 2695 2750 0 276 .... i ..~ q ' " 2700 27s0 .._0 3po AUG 01 · t_ t. 26 2695 2750 0 348 ............ '" 3`'=' C.'.,,',~,. 0,¢~ ·"~" ....... f J"dO,~O VII ~ 29 2690 2750 0 3,,48 ,~,,,,.~,,.,.,~., 30 2690 2750 0 343 i i i · ii 31 2690 2750 0 344 _ Copies To; Julia Koberstein, Kenai office Well #19 File JUl--. J. , C..v. fJv__J~J - O , ~.. ( !'-!1'1 .... UN0bALpLATFORM'"" ANNA ............ WELL #19 PRESSURES Month: June.OO . .llll ~1 i ii i1 i iiiii Date Tubing_._ 9 518" 13 3/8" BBL's..lnjected .. Comments , I .... 720 ....950 .,.0 ..... 0 Down,,,2,4 hrs. with inJe~tlon pump_problems, 2 720 950 O. 0 Down 24 hfs. with inje_ction pump problems. 3 680 950 0 . O Down 2,,4 bm. with Injection pump problems. 4 .660 950 ....... 0 .... O Down 24 hrs. with,..injectJon pump problems. .S. 650 950 0, , 0 Do.wp,,, 2~ I~rs, with injection pump_problems, 6 6~1,,8 700 0 0 Down 24 hrs, with Injection pump problems. ? , 609 . ~_6.__50 oi ..... 0 Down 24 hrs. wlt~:J_.nJ..eC_.tlon pump problems. :, ,8 593 ., 650 ,0,: ... 0 Down 24 _h_m. with IlrlJectlon pump..problems. 9 579 600 ..... 0 0 Down 24 hrs, with injection_pump problems, 10 scs _.~ 600 O.. , 0 Down 24..hrs,.. with Injection pumpproblems, tl . .5S6 800 ....... 0 ....... 0 Down 24 hrs. with injection pump problems. 1Z 550 -,, 600 O;... 0 Down 24 hrs. with In, tection pump problems, 13 ,550 600 , 0 .,. 0 Down 24 hts. with injection pump problems. 14 550 .. §00 O .. 0 Down 24 hrs,,with Injection pump problems. 115 0 600 0 0 Down 24 hfs, with injection PU_~P problems, I ..... ~l. ~! i · I - ~ 16 0i 600 O 0 Down 24 hrs. with.inj_e_ct..!on pump problems. 17 0.j,. 600 ~ 0 0 Down 2.4~ hrs. with lr~ectlon pump problems. 1 8 ' 'r 0 6.0,,0,. 0 0 Down 24 hrs. with injection pu_mR, problems. 19 4.,68 550 0 0 Down,.24, hrs, With injection pump problems, .._ 30 460 ,,550 0 .. 0 Down 24 hrs. with injecfl,0~pump problems, 21 ~ 550 0 0 Down 24 hrs. with injection pump problems. 22 . . 442 55,0 0 ......0 Down 24 hrs. with injection, ,pump. problems. ..23 443 .... 550 ~ 0 ~)own 24 h ,m.~,.~th Injection pump problems, 24 42~ 550 ...... 0 0 Down 2.4. hrs, with Injection pump problems, 25 , 418 _,5S. 0 0 ....... 0 Down 24 hrs, with injection pump~p_~_b~ms, 26 418 550 0 0 Down 24 hrs. with InJection pump problems. 2..7. 4,05 550 0 ........... 0 Down 24 hfs, with inJection p_u_mp_problems, 2~ . 3,~4 .550 .......... 0 0 Down 2.4. hrs. with Injection pump problems. 29 394 .550 0 _, 0 Down 24 hrs. with inJection p.?.mp, problems. 30 394 550 0 0 Down 24 h .rs._.With InJection pump problems, 31 I I la I I Ill I I Ju!le Koberstein, Kenai Office Well #19 File Copies To; IIII ..... II · I ' UNOCAL PLATFORM ANNA WELL #19 PRESSURES Mo,nth: May-00 ........ Date Tubin~ 9 ll8"_ .... 13 318" BBI.'s Inject.ed .., Comments , 1 2698 .,2700 0 ... 131 W.F. down 17 houm cha~e pump repair ___ 2 2700 2730 0 382 I I _1 I Ill ;3 2700 2750 0 351 4 2670 2750 0 :337 5 2780 2750 0 332 I I i iiiii 6 2700 2750 0 238 · p_tl t ........ __..IL II 7 2680 2750 0 .,qll , I. I II J 2690 2750 0 338 ---q- I _.-[ L II II I 9 .,Z_6.8_7'' 2750 0 ,,, 177 W.F. clown 11 hours oha~e pump repair 10 ,~ 0 1200 0 0 W.F, down 24 hours oharge pump re.p. ajr... 11 2698 , 2750 0 _~.58W.F. down 17 hours chal~le pump repair '12 2700 2750 , 0 375 W.F. down.,.1, hours charl;le pump repair '13 2697 2750 0 346 _ BJ.L ,,1,,, :~iWj: ....... 14 2687 2750 0 330 15 2690 ,. 2750 0 . _.3,, 2.1 16 2680 2750 0 319 17 2695 2650 0 314 ,jam, i I '-- - JJJ~ '18 ,,, 2675 275o, i ,,, 0 302 .-.. _ .......... 19 2650 2700 0 305 · __.---- lIs i, , 20 0 , 1400 0 ........ 177 Down 10 hrs, with Injection pump problems, 2t 111S 1200 0 0 Down _2.4.hrs. with injection pump problems. 22 1115 1200 0 ,.,0Down 24 hrs. with injection pump problems. 23 0 , 950 0 .....,0Down 24 hrs. with inie ,cUon pump problems. 24 0,, ., 950 0 ...... o Down 24 hrs. with injection pump problems. 25 ,2700 950 ....... o 215 Dowrl 12 hrs. with inJection pump_problems. 26 2700 , 950 0 ............. 360 Down 3 bm. with Injection pump problems. ~_27 tooo ........ 950 0 0 !Down 24 hrs. with Injection pump problems. 28 900 950 ........ 0 0'Down 24 hrs.. with_ipje~ti0n pu_mp.p.~blems. 29 845 ....... g~5_0 0 0 Down 24.hrs. with Injection pump problems. 30 791 9,50 0 0 Down 2,.4,.hrs. with Injection pump problems. 31 768 950 0 0;Down 24 hrs. with Injection pump problems. _111 I iI _ I copies TO: Julia Koberstein, Kenai Office Well #19 File F:~m~cdll~Xexsel~mo-endga~'lepress,,.xl~ UNOCAL 'PLATFORM ANNA WELL #t9 PRESSURES Month:. ......... ...... Ap,.rll-0O Date Tubin9 9 518" 16 3/8" B BI.'s InJected Comments ....... , I 2677 2700 0 316 2 2680 2700 O: 303 3 2085 2700 0 322 4 2700 ._2700 0 319 5 2700 2700 0 323 i 6 2700 2700 0 318 r Ill ? 2700 2700 0 317 8 2700 2700 0 319 9 2700 2700 0 315 t0 2700 2700' 0 290 t I 2697 2750' 0 336 12 2701 i 2750 O' 333 13 2681 2750 0 326 14 2690 2750 0 324 16 2678 2750 0 319 16 ........2_.~~ 2750 0 165 W,F. down 12 hfs for pipe replacement 17 2695 2750 O 145 ,W,F, down 17 hfs for. p.!p,,e replaoement 18 2665 2750 0 367 ._. 19 2690 2750' 0 322 W.F. down 4 hfs due to platform S/I . ;- 20 2685 .... 27.50 0 ,, 347 21 2690 2750 0 340 22 2700 2760 0 321 ........................... .mil-- 23 2700 2750 0 336 24 2700 2750 0 331' ...... :.; =~:,,., *~,,..~. .... ..... ~ .... 25 2700 2750 O 331 26 2678 2750 0 320 , 27 2685 2760 0 316 28 2694 2750 0 330 29 3199 3000 O 325 30 2676 2750 0 71 Do .wo_20_ hmc_h_aq;le pump seal change 3~ ............. ii I I I I I I I II II II I II Copies To: Julle Kobersteln, Kenai Office Well #19 File F:tmselfice~cel~mu-endge~Igpmss~s . UNOCAL PLATFORM ANNA WELL #19 PRESSURES Month: March-00 · Date Tubing 9,618", 13 318" BBL's Injected Comments I 2,,7.,0.,0 2700' 0 360 2 2674 2700 0 366 3 2700 2700 0 357 4 2700 . ,2.700 0 350 G 2700 2700 0 345 ,. 6 2728 2700 0 347 ,.... j _ ,_ _,_. ? 2650 2700 0 329 8 2670 2700 0 334 9 2690 2700 O 335 10 2700! 2700 0 279 11 2690 2700 0 342 12 2685 2700 0 350 13 2700 2750 0 344 14 2681 2700 0 336 15 2666 2700 O 330 16_. 2692 2710 0 327 17 2689 2750 0 327 . . 18 2695i 2750i 0 322 ,, , 19 2665 2750 0 320 20 2700 2750 0 319 21 2685 2700 0 336 22 2670 2700 0 330 ~.,.L 23 2665 2700 0 323: 24 2685 2700 0 32.5 25 2685 2750 0 32:2 26 2700 2700 0' 321 27' 2700 2700 0 312 ,~ j · ,. 28 2687 2700 0 317 29 ......26.80 2700 0 318 30 2679 2700 0 317 31 2675 2700 0 319 Copies To: Julie Koberstein, Kenai Office Well 1/19 File F:~m$ofllc, e~e~'el~rn~nde~ I epmeo~ls RECEIVED APR 0 5 .~000 Alaska Oil & GA Cons. Commi~ioq ~orage UNOCAL PLATFORM ANN/Ii ' ........... WELL #t9 PRESSURES Month: February-00 Date Tubin9 9 518" 13 318" , B B.L'S_ ln~ected comments I ,0,. 850 0 0 W.F..___U..o. wn 24 hrs. wash pump out. . 2 0 850 0 ...... 0 W,F, down 24 hrs, wash~,~mp out. 3 0 850 .,, 0 0 W.F. dow.n 2~4_h _rs. wash pump out, 4 0 850 0 ...... 0 W.F. down 24 hfs. wash pu .m.p out. 5 0 850 0 0 W.F. down 24 hrs. wash pump out. 6 2700 2600 o 563 7 2695 2600 o 463 8 2693 2600 0 435 9 2698 2600 0 417 10 2695 2600 0 400 11 2695 2600 0 ......... $96 12 2880 2600 0 386 , 15 2695 2600 0 377 14 2693 2750 0 $80 16 2691 2750 0 378 16 2691 2750 0 .__!91 Flood down 12 bm.. Mechanical pmb./pumRs. 17 0 1150 0 ~. o Pumps.b?.in~ repaired 18 0 ..... 1,1,,5p ....... 0 0...... pumps bein~ repairedimm. 19 0 900 o 0 Pumpq.bping repaired . 20 0 800 0 .0 Pumps beln~l rep_a?ed 21 2715 2750 0 199 22 245.5 2350 0 342 ..... 23 2690 2650 0 469 I II 24 2700 2700 0 425 25 2695 2700 0 405 26 2685 2700 0 390 27 2695 2700 0 375 28 2696 2700 0 360 2S 2700 2700 0 370 ....... Illlllll · I · mm Copies To: Julia Koberstein, Kenai Office Well #! 9 File Fax: Blair Wonzell-9-1-907-276-7542 Alaska Oil & Gas Assoc, F:~meeffice~xeeBmo-endgi~ 19pms,~d~ RECEIVED MAR 0 1 2000 Alaska Oil & (Jas Cons. C;ommission Ghorage i ii ii ii ilnilnll IIIIll II I UNOCAL PLATFORM ANNA WELL #19 PRESSURES Month: January-00 . Date Tubing .......p.~S ~'. ...... 13 318" BIlL's Injected Comment~, I 2700 27.5,.0 50 385 __. m,~ , ' 2 2700 2750 50 362 _ [ ~ _..,.., $ 2698 2750 50 375 .~__ I ii t J_.. 4 2700 27.5_0. 50 3.7..6. .... 5 2680 2750 50 370 6 2693 2750 50 363 ..... iff , ,, ii 7 2694 2750 50 360 fl ill] 8 26,,90 2750 50 ....... 150 W.F. dn for C sourcff,,pump line replacement 9 2700 27.5_01 5{~ 270 .W.F. dn for C source pump_!ine_r.,e, plaeement 1. !. 0 ~ 2698 2750 ...... 50_ 399 ........... ..... !_1 2656 2750 50 369 ...... : .ira. i., i i . t 2 2680 2750 $0 367 13 2700 2750 50 383 . 14 2790 2750 50 362 15 2694 2750 50 359 ....... Illl i,~.. 16 2675 2750 $0 357 ............... , -- f,. ., , .,,, 17 2678 2750 50 351 . . ,t_lt ..... 18 2686 2750 50 354 . ........ i [,~ 19 2698 2750 0 351 20 2694 2750 0 365 21 .... 268__4_ 2726 0 360 22 2700: 2750 ....... .0 191 W,F. dn for drain down line replacements 2;3 2698 2750 0 389 .... _ . i, ~,. 24 2690~ 2700 0 370 --. 25 1330 .... .!~0_0. 0 218 W. ,F:~own 14 hrs. Wash pump out. 26 1060 1150~ ..... .0 0 W,F. down 24 hfs: Wash pump out. 27 ............ !060 1150 0 ......... 0 W.F. down 24 hfs, Wash pump out. 28 1060 1150 . o. _. O,W,F, down 24 h.m,. Wash pump out. 2,9 1060 1150 0 .... 0 W.F. down 24 hrs. Wash p,u,,m_p out. 30 1060 1150 0 0 W.F, down 24 hrs. Wash pump out. al 1060 1150 0 0 W.F. down 24 hrs. Wash pump out. Copies To: Julie Kobemtein, Kenai Office Well ~/'19 File · Fax: Blair Wonzell-9-1.907.276*?$42 Alaska Oil & Gas Assoc. F:~msefllce~cel~me. end~B~l gprm~s xls RECEIVED 2000 UNOCAL PLATFORM ANNA WELL #19 PRESSURES Month: December-99 · l~ , P~te Tubine o 818" 13 818".. . BBL'. Injected commentB I . ~710' .2750i ........... _0.. 468 ,2 .2700 2750 ._ 0 433 $ 2705 2750 0 436 4 2715 2750 0 41,9 $ 2680 2750 0 401 / i ............ i i iii ..... e r;J.-O°- ......27 0 o 7 267.0 2750 ,.. 0 384 8 266.1 ...... 2750 .... 0 395 i ,~u_! .... 9 2690 2750 0 392 . __~,.~,. ,_.~... ,..-~-: .. _.. 10 2713 2750 0 401 11 2700 2750 0 423 ., 12 2700 2750 0 413 .13 2700 2750 0 296 ,,, , ,,;._. ,.., ...,, 14 2695 2760 0 428 16 2696~ 27_50 0 404 ____.1_6 .~ 2685 2750 0 391 !.7_ 2095 2750 0 396 , .. 18 2700 2750 0 387 19 2700 2750 0 387 i ~LI j~ll 20 2670 2750 0 376~ 21 2,075 2750 0 300 ii * i. , 22 2671 , 2700 0 377 23 ........ 2ee!.' _ ..... 270.0 .............. g :.:.,, 369 _ 24 2625 .,2700 0 370 26 2676 27501 0 371 26 2679 2750 0 368 -- Ill Il l 27 2065 2750 0 369 28 2685 2700 0 366 29 2685 , 2750 0 362 , il ,,, 1~,, ........... 30 . 2095 2760' 0 309 31 2700, 2750 0 318 Illl Copies 1'o: Julle Kobemtein, Kenai Office Well #19 File t, Re: l~nopod A-19 Injector Csg Pressure Subject: Re: Monopod A-19 Injector Csg Pressure Date: Thu, 15 Jul 1999 11:24:23-0800 From: B lair Wondzell <B lair_Wondzell@admin, state.ak.us> To: "Ruff, Christopher A" <ruffc~unocal.com> CC: "Cole, David A" <dcole~Orion. Unocal.com>, "Tyler, Steve L.-Contract" <tylersl~Orion. Unocal.com>, "Johnson, Dwight E" <johnsond~Orion. Unocal.com>, "Geisert, C. Dean" <geisecd~Orion. Unocal.com>, "Dolan, Jeff J" <dolanjj~Orion. Unocal.com> Chris, In regard to your 7/12/99 request to contiue injection into MonopodA_~. we agreee that continued injection is appropriate providin9 the well is monitored daily. Blair, 715/99. "Ruff, Christopher A" wrote: Blair, I am requesting permission to continue injection into the Monopod A-19. The details are listed below, please let me know if a new MIT is required. The well's casing pressure increased from 695 psi to 1000 psi on 7/3/99. It was bled back off on 7/8/99 and has continued to hold pressure. The platform felt it didn't need to be reported since the pressure increase was a one-time thing and was holding far below the injection pressure. << . . . >> << . . · >> I originally thought it was an error in our reporting system or a gauge. We bled the well off on 7/8/99 and monitored the pressure while we were checking our system to make sure it wasn' t a reporting error or gauge problem. The pressure turned out to be real and we can't explain why it increased, but it has. been verified that the increase in pressure was a short term leak and is not a problem. In order to make sure the new disposal well on Bruce and all other wells are reported to you promptly I sent out the attached email to all of our facilities on July 8th. I will follow this email with a phone call this afternoon. Thanks Chris Ruff Unocal 907-263 - 7830 From: Ruff, Christopher A Sent: Thursday, July 08, 1999 5:03 PM To: GRP AK Foreman Cc: Cole, David A; Cronk, Jon A; Dolan, Jeff J; Smetanka, Jeff W; Greenstein, Larry P; Tyler, Steve L. -Contract; Johnson, Dwight E; Myers, Chris S Subject: Well Integrity Failure Reporting Procedures for all Injection Wells The disposal injection order for Class 2 waste disposal was approved on 7/6/99. Rule 4 of that order very clearly lays out the requirements of our company in the case of a possible/actual failure. Below is the exact rule which actually applies to all waterflood injectors and disposal wells. 1 of 3 7/15/99 11:25 AM ~ R.e: Monopod A-19 Injector Csg Pressure "Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain. Commission approval of a plan for corrective action and obtain Commission approval to continue injection." Basically 5 steps need to be done, the first 3 should be done by the Platform and the last two by the engineering staff in anchorage: 1) Shut-in the well if there is any perceived safety or loss of property risk. If the failure is minor and the Foreman/Superintendent is confident the failure is not significant, continue injection operations until the state can be contacted or the Anchorage engineering staff can be contacted to make the decision. 2) Notify the Commission immediately or at least by the end of the next working day if there is any indication of a failure. This should be done by the platform and should be directed to Blair Wondzell. It should probably be done by phone and followed up by fax or email, saving the receipt to document the fax or cc me to document the email (direct contact is not required if receipts are retained). AOGCC Main Phone Number 279-1433 (Voice Mail Menu) AOGCC Fax Number 276-7542 > > > > > > > > > > Blair E. Wondzell Senior PetroleumEngineer Blair Wondzel l @admin. state, ak. us -- 3) The platform should contact the Anchorage office ASAP so we can begin to prepare and make a decision to continue injection or shut-in the well. a) Send me an email (ruffc@orion.unocal.com and ruffca@hotmail, corn) or fax 263-2884. b) Follow that up with a phone call. Continue down the phone list until you have contacted someone, voice mail is not good enough. If no one can be contacted and there is any perceived safety or loss of property risk, shut-in the well until we can obtain permission to continue injection operations from the AOGCC. Chris Ruff Jeff Dolan Dave Cole Hal Martin the office, till???) Chet Starkel 263-7830 work, 337-3682 home 263-7807 work, 277-0449 home 263-7805 work, 348-2576 home 263-7875 (currently out of 263-7636 4) Obtain approval of a plan for corrective action (This will be done by the Anchorage Engineering staff) 5) Obtain approval to continue injection (This will be done by the Anchorage Engineering staff). Without at least verbal approval to continue injection, the well must be shut-in. Written approval should be received following verbal approval, for the Anchorage records. If there are any questions about this plan or recommendations for modifications please let me know. Thank you Chris topher Ruff Senior Petroleum Engineer 907-263-7830 ruffc@orion, unocal, com > > > > 2 of 3 7/15/99 11:25 AM - Mon~od A-19 Injector Csg Pressure Subject: Monopod A-19 Injector Csg Pressure Date: Mon, 12 Jul 1999 12:42:56-0700 From: "Ruff, Christopher A" <ruffc~unocal.com> To: "Wondzell, Blair E" <Blair_Wondzell~admin.state.ak.us> CC: "Cole, David A" <dcole~Orion. Unocal.com>, "Tyler, Steve L.-Contract" <tylersl~Orion. Unocal.com>, "Johnson, Dwight E" <johnsond~Orion. Unocal.com>, "Geisert, C. Dean" <geisecd~Orion. Unocal.com>, "Dolan, Jeff J" <dolanjj~Orion. Unocal.corn> Blair, I am requesting permission to continue injection into the Monopod A-19. The details are listed below, please let me know if a new MIT is required. The well's casing pressure increased from 695 psi to 1000 psi on 7/3/99. It was bled back off on 7/8/99 and has continued to hold pressure. The platform felt it didn't need to be reported since the pressure increase was a one-time thing and was holding far below the injection pressure. << . . . >> << . . . >> I originally thought it was an error in our reporting system or a gauge. We bled the well off on 7/8/99 and monitored the pressure while we were checking our system to make sure it wasn't a reporting error or gauge problem. The pressure turned out to be real and we can't explain why it increased, but it has been verified that the increase in pressure was a short term leak and is not a problem. In order to make sure the new disposal well on Bruce and all other wells are reported to you promptly I sent out the attached email to all of our facilities on July 8th. I will follow this email with a phone call this afternoon. Thanks Chris Ruff Unocal 907-263-7830 From: Ruff, Christopher A Sent: Thursday, July 08, 1999 5:03 PM To: GRP AK Foreman Cc: Cole, David A; Cronk, Jon A; Dolan, Jeff J; Smetanka, Jeff W; Greenstein, Larry P; Tyler, Steve L. -Contract; Johnson, Dwight E; Myers, Chris S Subject: Well Integrity Failure Reporting Procedures for all Injection Wells The disposal in~ection order for Class 2 waste disposal was approved on 7/6/99. Rule 4 of that order very clearly lays out the requirements of our company in the case of a possible/actual failure. Below is the exact rule which actually applies to all waterflood injectors and disposal wells. "Rule 4 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission'approval to continue injection." 1 of 2 7/12/99 2:23 PM · Mono~od A- 19 Injector Csg Pressure Basically 5 steps need to be done, the first 3 should be done by the Platform and the last two by the engineering staff in anchorage: 1) Shut-in the well if there is any perceived safety or loss of property risk. If the failure is minor and the Foreman/Superintendent is confident the failure is not significant, continue injection operations until the state can be contacted or the Anchorage engineering staff can be contacted to make the decision. 2) Notify the Commission immediately or at least by the end of the next working day if there is any indication of a failure. This should be done by the platform and should be directed to Blair Wondzell. It should probably be done by phone and followed up by fax or email, saving the receipt to document the fax or cc me to document the email (direct contact is not required if receipts are retained). AOGCC Main Phone Number 279-1433 (Voice Mail Menu) AOGCC Fax Number 276-7542 Blair E. Wondzell Senior PetroleumEngineer Blair Wondzell@admin. state, ak. us 3) The platform should contact the Anchorage office ASAP so we can begin to prepare and make a decision to continue injection or shut-in the well. a) Send me an email (ruffc@orion. unocal, corn and ruffca@hotmail.com) or fax 263-2884. b) Follow that up with a phone call. Continue down the phone list until you have contacted someone, voice mail is not good enough. If no one can be contacted and there is any perceived safety or loss of property risk, shut-in the well until we can obtain permission to continue injection op.erations from the AOGCC. Chris Ruff 263-7830 work, 337-3682 home Jeff Dolan 263-7807 work, 277-0449 home Dave Cole 263-7805 work, 348-2576 home the office, till7??) Hal Martin 263- 7875 Chet Starkel 263- 7636 (currently out of 4) Obta'in approval of a plan for corrective action (This will be done by the Anchorage Engineering staff) 5) Obtain approval to continue injection (This will be done by the Anchorage Engineering staff). Without at least verbal approval to continue injection, the well must be shut-in. Written approval should be received following verbal approval, for the Anchorage records. If there are any questions about this plan or recommendations for modifications please let me know. Thank you Chris topher Ruff Senior Petroleum Engineer 907-263-7830 ruffc@orion, unocal, com 2 of 2 7/12/99 2:23 PM SEP-2~-98 FRI 09:26 UNOCAL aSSET GaS GRP FaX NO. 9072637874 Unocal Corporation Agricultural Products 909 West 9~' Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL P, 01/02 June 29, 1998 Blair Wondzel State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Request permission to inject into Anna Platform Well #AN-19-2 Dear Blair: This letter is to document your approval to put Anna 19-2 on injection with a variance. AN-19-2 has communication between the tubing and the 9 5/8" casing. A jug test was completed to prove 9 5/8" casing integrity on 9/24/98. The well can be operated safely with no risk to shallow fresh water aquifers or gas zones due to casing integrity. Please grant us permission to continue injection into this well under the assumption that we will monitor the various annuli daily and report this data monthly, and we will run a temp survey every two years for comparison with the base survey which was submitted on 9/8/98. Please sign and send a copy of this letter to my fax at 263-7874. If you have any questions regarding this, please contact Steve Tyler at 263-7649. Sinc rely, David A. Cole Oil Optimization & Exploitation Supervisor Cook Inlet Waterflood Management Please return a signed and dated copy of this letter to document your approval for our recorg~ ~,~,-,t ~ ~ ?'~ ~ ~ ~ Aogcc AN-I 9-2 Variance.doc 09125198 ALASKA OIL AND GAS CONSERVATION COMMISSION MECHANICAL INTEGRITY TEST Date ~- Z~'/- ~i~ Company, Unocal Alaska, Reid Granite Point ..................... PI~EST START 15 MIN 30 MIN WELL *P *1 TYPE OF PKR CASING TBG REQ TBG TIME TIME TIME NAME *S - ANNULUS TVD SIZE/WTIGRADE SIZE TEST C:SG 'rBO 'i'BG TBG P F · M *N FLUID MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS 19-2 S I s~ Water a, 173' sate'.4~.s~ 2,350 ~ X r, ~. s~ N.SO Z C.~m~i ......................... ..................... . .,, , , .... ,,, ....... ~, .., ,, ~ , . , ,, , Comments: ...... , , , ,, , ...... J, ...... ,.. ................. , , .... · ,, , Z 0 t'r'l TUBING IN___ _~atClN FLUID = PRODUCE WATER INJ = SALT WATER INJ =MISCIBLE IN,IECTIOI~ = I~UECqqNG = NOT INJECTING ANNULAR FLUID: GIqADIENT WFJ..LTF:ST InitLal 4-year X DIESEL Wodcover. GLYCOL SALT WATER Explain , DRLLING MUD OTHER OTHER AOGCC WITNESS SlGNA~ COMPANY REP SIGNAT~ Unocal North Americ;/'~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL R.C. Warthen Regional Development Geological Manager Mr. Larry ~~ Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska February 22, 1991 MUD LOGS, TRADING BAY FIELD A-19RD In the course of our operation of redrilling a field development well, Unocal normally does not require the sevices of a mudlogging contractor unless unusual geological conditons are predicted to exist. Mudlogging operations were not conducted on subject well; hence the absence of mudl,~.gf~.~RE~.., ~ l~lOg data package transmitted to the Commission. FEB 2 5 1991 Sincerely, h /o, Regional Development Geological Manager , . ? ~¢, STATE OF A[.ASKA ALASKA ,,~L AND GAS CONSERVATION C~....!MISSION~~"~ ~WELL COMPLETION OR RECOMPLETION REPORT AND LOG '1. Status of Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE3[;~ Classification of Service Well ~ter Injection 2. Name of Operator Onion Oil Company of Califoraia dba Unocal 3. Address P. O. Box 190247, Anchorage, ~ 99,519-0247 4. Location of well at surface 1625'.N, .562' 14. f/SE Corn. Sec. 4, T9N, R13N~, S At Top r'roaucmg Interval · · ' 5890' ~fl), 4622' TV]), 260' N and 3331' W f/surf. Location At Total Depth 7415' ~D, 5929' TVD, 616' N & 4042' W f/surf. Location 7. Permit Number 88-1 8. APl Number 50- 733-201,51-01 9. Unit or Lease Name Trading Bay State 10. Well Number · BS A-19 RD 11. Field and Pool Trading Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 101' RT Above ~L [ ADL 18731 Tyonek 'C" & "D' Zones 12. DateSpudded [13. DateT.D. Reached ] 14. DateComp.,S.u~p. orAband. [,5. WaterDepth, ifoffshore 116. No. of Completions 6123188 + [ 8/17/88 I 9/3/88', I 61' feet MSL I be 17. Total'Depth(MD TVD) [18. Plug Back Depth (MD+TVD)i 19. DirectionalSurvey [ 20. Depth where SSSV set [ 21. Thickness of'Permafrost 7500't, fl)/6003' ~ 741,5't, fl)/,5929' ~f-J~YES~ NO [] [ None feet MD J None , 22. Type Electric or Other Logs Run Dual Ind., LS $onic~_~omp Neut. ,, Co~p. Den.. GR, Diplog_. Cement Bond Log 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP !BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29# N-80 34'57' 7010' 8-1/2" 700sx class "g" None 5" 18# N'80 6807' 7496' 6" 145sx class 'g' None ;)4. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) See Attached 25. TUBING RECORD SIZE ] DEPTH SET (MD) ]PACKER SET (MD) 3-1/2", 9.3#, N-80 5850' 5298' DSS-HTC ~ 26. ACID, FRACTURE, CEMENT SQUEEZE,' ETC. DEPT. H~NTERV ,AL (M.D) ] AMOUNT & KIND OF MATERIAL USED See Attached 27. Date First Production Date of Test Flow Tubing Press.. Hours Tested Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) tPRODUCTION FOR TEST PERIOD ll~ CALCULATED 24.HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF WATER-BBL WATER-BBL CHOKE SIZE I GAS'OIL RATIO OIL GRAvITy-~'P'I (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE6EI,VED ,¢~laska.Oil.& 8as Con~. Cornr~issiOR' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS Perforation Detail, Cement Squeeze and Acid Detail, Well History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Environmental INSTRUCTIONS General' This form is designed for'submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt ,.rater disposal, water supply for injection~_observation, injection for in-situ combustion. ITem 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Trading Bay State TBS A-19 Redrill Perforating Detail Measured Depth 5755-5890 6032-6140 6476-6505 6670-6730 6934-6950 6983-7015 7045-7095 7i25-7147 7154-7240 728i-7367 True Vertical Depth 4515-4623 4739-4825 5098-5125 5265-5319 5495-5511 5545-5562 5592-5645 5659-568i 5687-5765 580i-5881 Interval (ft,) 135 108 29 6O 16 5O 22 86 86 Zone C-7 47-5 50-3 51-6 53-8 54-5 54-9 55-7 56-1 57-2 O019n RECEIVED .?~hska.Oil & Gas Gonso Commission '., Anchorage Trading Bay State TBS A-19 Redrill Acid Procedure 1st Stage Acid Oob Packer Setting Depth: Pumped: 2350 gal. 4725 gal. 10500 gal. 2015 gal. 2350 gal. 4725 gal. 10500 gal. 6822' 7'5 %HCL 6.0% HCL & 1.5% HF FIW W/ '50% Surfactant FIW w/ lppg Benzoic Flakes and ,5% Surfactant 7.5% HCL 6.0% HCL & 1.5% HF FIW w/5% Surfactant 2nd Stage Acid Job Packer Setting Depth: Bridge Plug Setting Depth: Pumped: 2350 gal. 4745 gal. 10000 gal. 2050 gal. 2395 gal, 5670 gal. 9790 gal. 5950' 6760' 7.5% HCL 6.0% HCL & 1.5% HF FIW w/.5% Surfactant FIW w/ 1 ppg Benzoic Flakes and .5% Surfactant 7~5% HCL 6,0% HCL and 1.5% HF FIW w/ .5% Surfactant O019n Squeeze Procedure Perforations 6962-6964 6128-6130 5885-5887 5724-5726 Squeeze 175 sxs class "g" w/.2% CFR-3, .4% Halad 344 & .1% LWL Initial Press: 2300 PSI ~ 1-3/4 BPM; Final Press: 1625 PSI ~ 1/4 8PM. 250 sxs class "g" w/ .2% CFR-3; .4% Halad 344 & .1% LWL; Initial Press: 2100 PSI ~ 1-3/4 BPM; Final Press: 2100 PSI ~ 1/4 BPM 300 sxs class "g" w/.2% CFR-3, .4% Halad 344 & .1% LWL. Initial Press: 2700 PSI ~ 1-1/4 BPM Final Press: 2500 PSI ~ 1-1/3 BPM 300 sxs class "g" w/.2% CFR-3, .4% Halad 344 & .1% LWL; Initial Press: 2050 PSI ~ 2-1/2 BPM; Final Press: 2500 PSI ~ !-1/3 BPM UNION OIL CO. OF CALIFORNIA ,,_ DRILLING RECORD PAGE NO.. LEASE TRADING BAY STATE WELL NO, A-19 FIELD TRADING BAY STATE DATE _ , 1988 6/23/88 6/24/88 6/25/88 6/26/88 6/27/88 6/28/88 6/29/88 6/30/88 2~8O E.T.D, Feet 9259'TD 7759'ETD 9259'TD 7759'5TD 9259'TD 7750'ETD 9259'TD 7750'ETD 9259'TD 7750'ETD 9259'TD 7750'ETD 9259'TD 7750'ETD 9259'TD 7750'ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skid rig over conductor 917, Well A-19RD. Laid down S-135 drill pipe due to potential H2S in well. Cut and slipped drill line. Cleaned mud pits and off loaded boat. Mixed kill mud. Continued to mix mud and weight up. Bled the annulus and tubings to production. Pressure dropped from 670 PSI to zero. Pressure built back to 670 PSI after being shut in for 40 minutes. Bullheaded 87 PCF mud down the long string. Continued pumping on longstring a total of 500 bbls. Shut in well with 1200 psi on the 9-5/8" annulus & 1075 psi on the tubings (LS & SS), bled pressure off tubings. Circulated mud down long string taking returns on annulus. Mud returns on annulus after 53 bbls pumped. Shut in the well and pressure built to 590 PSI. Bleed short string to 0 PSI and pressure on the long string bled to 0 PSI, annulus bled to 80 PSI. Pressure built to 60 PSI after being shut in. Flowed the short string at a rate of 5 to 10 BPM then decreased to 1 to 2 gpm. Pumped 50 bbls mud down the annulus. Checked well & no flow. Nippled down tree, installed riser & single gate. Hooked up single gate. Began to nipple up the remaining BOPE. Finished nippling up BOPE. Stabbed into tubing hanger and picked up 26000~ over buoyed string weight. Rigged up wireline & made a 1-3/4" sinker bar run to 4180' on the short string & 3198' run on the long string. Rigged up slickline & cleaned out to 3202' on both strings. Rigging up slickline to work on the short string. Ran in the hole with slickline on short string with a 2.16" gauge cutter. Cutter stopped @ 3405' Pull out of hole & rigged up coil tubing. Ran in the long string'with a 1.25" joint tool to 5900'. Pulled out of the hole to 3906'. Ran in the hole and worked from 5900' to 5907'. Could not make additional hole. Pull out of hole and coil tubing stuck @ 5797'. Unable to work tubing up or down the hole. Continue to circulate with full returns. Mixed and spotted 18 bbls of 87 pcf mud with 3~/bbl CFR-3 (friction reducer). Unable to work coil tubing. Circulated down the short string taking returns up the 9-5/8" annulus. Circulated & conditioned mud. Worked stuck tubing @ 5797'. Rigged up Dowell, tested surface equipment & pumped 2 BBL FIW, 12 BBL 15% HCL, 2 BBL FIW & displaced with 4 BBL mud. Worked stuck tubing & moved acid. Allowed acid to soak 10 hours. Displaced acid with 87 pcf mud. Finished circulating acid from the hole. Circulated & conditioned mud. Made a surface cut on the 1-1/4" coil tubing & rigged .up a p~]~ in head. Rigged up a 15/16" chemical cutter & run in hole to 5720'. Cut the coil tubing @ 5700' & pull out of hole. Recovered 5700' of coil tubing. Ran back in the hole with coil tubing & 2.125" jet tool. Washed from 3211' to 3220' & pull out of hole. Made up 2.25" mill & 1-3/4" Dyna-Drill & cleaned out from 3220' to 5132'. Pull out of hole & found mill worn on outer edges. Made up new 2.25" mill. Ran in hole with new 2.25" mill and cleaned out to 5665'. Circulated and conditioned mud. Pull out of hole and rigged down coil tubing unit. Rigged up wireline unit and ran in hole on the long string with a 2.23" jet cutter. Cutter stopped @ 3470'. Pull out of hole and ran a 2.125" jet cutter. Cutter stopped at 3470' Pull out of hole and ran 18' of 1-11/16" sinker bar. Sinker bar slopped at 3470'. Rigged up on the short string and p~nped down the short string taking returns from the long string. Circulated out silt and scale. RECEIVED MAE? 2 ,.) ,7'~,Iaska .Oil & Gas Cons. Commission ~", ~chorage UNION OIL CO. OF CALIFORNIA" DRILLING RECORD PAGE NO.. LEASE DATE 1988 7/02/88 7/03/88 7/04/88 7/05/88 7/6/88 7/7/88 TR~DTNG BAY STATE WELL NO A-19 FIELD TRADING BAY STATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Feet 9259'TD 7750' 9259'TD 9259'TD 7750' 9259'TD 9259'TD Rigged up wireline on long string and ran 1-11/16" sinker bar to 3900'. Pressure tested 9-5/8" casing annulus to 750 psi (OK). Pressure tested short string to 1000 psi and had c~munications on long string but 0 psi on casing. Shut well in to observe casing pressure. Pressure built from 40 psi to 580 psi. Circulated down short string taking returns up annulus. Circulated out 39 bbls of 76 PCF salt water mud. Ran 2-1/4" jet cutter and stopped at 3680'. Ran 2-1/8" jet cutter to 5344' and stopped. Worked cutter down to 5350'. POOH with cutter and circulated down the short string taking returns up the long string.. Reran 2-1/4" cutter and stopped again at 4223'. Rigged up coil tubing and ran in the hole. Cleaned out long string with a 2-1/4" mill and Dyna-Drill to 5665'. POOH and rigged up wireline and RiH with 2-1/8" cutter. Cut the tubing at 5632'. Rigged up coil tubing on the short string and cleaned out to 5800'. Ran 2-1/4" jet cutter and cut the tubing at 5570'. Ran 2-1/4" jet cutter and cut the tubing at 5570'. Ran 2-1/4" jet cutter and made another cut in the short string at 5480'. Circulated and conditioned the mud down the short string taking returns up the annulus. Ran 2-1/4" jet cutter on the long string and cut the tubing at 5445'. Rigged down coil tubing and wireline. Engaged both strings and worked tubing. The long string parted at 74,000~ overpull. POOH with 1094' of 2-7/8" tubing (TOF @ 1135') Rigged up wireline on the short string and ran 2-1/4" cutter to 367'. Cut tubing and pulled 367' of 2-7/8" tubing. Ran in hole with overshot and engaged short string. Attempted to run jet cutter but would not pass fish top. Ran string shot and backed off tubing at 2390'. Recovered 2026' of 2-7/8" tubing (TOF @ 2393'). Changed out pipe rams and tested the BOPE, OK. Ran in with fishing assembly 92 and engaged the long string at 1135'. Pumped and worked fish free at 5445'. Recovered 4310' of 2-7/8" tubing. Reran fishing assembly #2 to recover short string. Worked over short string fish at 2393'. Pumped and work free. Pull out of hole with fish. Recovered 3087' of 2-7/8" tubing. (TOF at 5480') Picked up 8-1/2" swedge and ran in hole. Stopped at 4559'. Pull out of hole and ran in hole with open ended drill pipe. Worked drill pipe down to 4589'. Circulated and conditioned hole from 4589'. Pull out of hole to run casing inspection log. 9259'TD 7750'ET] Ran casing inspection log from 4500' to surface. Made up a 8-1/2" bit & scraper & ran in hole to 4558'. Unable to work down the hole. Pulled out of hole. Made up 6-1/2" tapered mill & ran in hole. Milled from 4558' to 4560' & continued in the hole to 5445'. Circulated & pulled out of hole. Made up an 8-1/2" x 6-1/2" watermelon mill & ran in hole. Milled from 4521' to 4558'. 9259'TD 7750' Continued milling to 4565' and pull out of hole. Picked up an 8-1/2" bit and ran in hole. Cleaned out to the top of fish @ 5445'. Pulled out of the hole and stopped @ 4570'. Pulled 30 to 60 K over string weight to work bit through bad spot. Picked up 2-7/8" stinger and ran in hole. Cleaned out to the top of the packer @ 5509'. Pull out of hole and picked up an 8-1/2" mill and worked on bad spot @ 4565'. r UNION OIL CO. OF CALIFORNIA. DRILLING RECORD PAGE NO ........ LEASE TRADIN~ BAY STATE WELL NO, A-19 FIELD TRADING BAY STATE DATE 1988 7/8/88 7/09/88 7/10/88 7/11/88' 7/12/88 7/13/88 7/14/88 7/15/88 7/16/88 E.T.D. Feet 9259' 4498'ETI 9259'TD 4440'ET[ 9259'TD 4440'ET] 9259'TD 4440'ET[ 9259'TD 4080'ETI 9259'TD 4293'ET[ 9259'TD 4250'ET! 9259'TD 4308'ET[ 9259'TD 4349'ET! DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ,,, Continued milling from 4565' to 4567' & from 4664' to 4666'. Ran in hole to 5444' & circulated conditioned mud. Pulled out of hole and piCked up 2-7/8" overshot and ran in hole. Set down at 4565'. Pulled out of hole. 'Made up 3-1/2" open ended drill pipe stinger and ran in hole to 5443'. Plug and abandon lower section of well below 5509'. Laid 150 sacks of class "G" with .2% CFR3, .3% Halad 344 and .1% LWL. Pulled out of hole to 4507' and squeezed at 1/2 BPM and 1500 PSI.. Estimated cement top at 5160'. Cement in place at 1915 hrs. 07/07/88. Pulled out of hole and picked up a 9-5/8" cement retainer. Ran in hole and set the retainer at 4498'. Tested the 9-5/8" annulus to 1500 psi. Prep for cement squeeze to isolate the bad casing at 4565' Mixed and pUmped 865 sacks of class "G" with .2% CFR3, 13% Halad 344 and .1% LWL. Initial rate of 2 BPM and 1200 PSI. Final rate 1/8 BPM and 1450 PSI. Cement in place at 0520 hrs. 07/9/88. Left 25 cu.ft, of cement on top of retainer. Pulled out of hole and rigged up%wireline. Ran CBL-VDL-GR from 4369' to 1000' with 750 PSI on the annulus. Tested BOPE. Tested casing to 1500 PSI and held for 30 minutes. Ran in hole with 8-1/2" bit and cleaned out to 4440'. Pulled out of hole to make up a section mill. Ran in hole with section mill and milled from 4308' to 4358'. Pulled out of hole to change blades on mill. Ran in hole & continued milling to 4358'. Pull out of hole & changed blades on the mill., Regauges section from 4308' to 4358'. Milled on stub @ 4358' & tool failed. Pull out of hole & picked up a new mill. Ran in hole & milled from 4358' to 4374' & mill fell down hole. Circulated & pull out of hole. Found blades on mill cut off. Picked up new mill & found casing stub @ 4358' & recut the section to 4374'. Continued to mill from 4374' to 4388'. Circulated & conditioned hole. Pulled out of hole. Made up under reamer & ran in hole. Opened the hole to 15" from 4308' to 4379'. Unable to open deeper. Pulled out of hole & picked up 3-1/2" drill pipe stinger & ran in hole.' Worked stinger to 4381' & laid 190 sxs of class "G" with 5% CFR. Mixed cement @ 16.5 ppg. Plug laid from 4381' to 4050'. Cement in place @ 2245 hrs on 7/12/88. Pulled to 3860' & circulated & conditioned mud. Pulled out of hole & laid down 3-1/2" drill pipe. Inspected drill collars & ran in hole. Cleaned out cement from 4080' to 4250' & waited on cement. Drilled firm cement from 4250' to 4293'. Drilled hard cement to 4308' then fell to 4319'. Found hard cement again @ 4335'. Pulled out of hole & made up a 3-1/2" drill pipe stinger. Ran in hole & equalized 100 sacks of class "G" with 3% KCL & .5% CFR-3 from 4335' to 4100'. Pulled above cement and pressured up on cement to 550 psi. Reversed out drill pipe & pulled out of hole. Laid down 3-1/2" drill pipe & picked up clean out assembly. Ran in hole & cleaned out cement to 4250'. Continued drilling cement to 4280'. Pulled out of hole & made up kick off assembly. Ran in hole and drilled cement to 4308'. MWD tool was not working. Pulled out of hole and picked a new MWD & ran in hole. Continued to attempt to kick off plug. Attempting to kick off plug @ 4340'. Pulled out of hole & changed bent sub from 2° to 2-1/2°. Ran in hole and drilled cement plug at 4349'. 2/80 UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. LEASE DATE 1988 7/17/88 7/18/88 7/19/88 7/20/88 7/21/88 7/22/88 7/23/88 7/24/88 7/25/88 7/26/88 7/27/88 TRADING BAY STATE WELL NO. A-19 F I E L D TRADING BAY STATE E.T.D. Feet 4404' 29' 4767 ' 363' 5063' 544 ' 5114' 93' 5200' 86' 5504' 304' 5880' 376' 5880' 376' 6194' 314' 6366' 172' 6586' 220' DETAIL~ OF OPERATIONS, DESCRIPTIONS & RESULTS Kicked off plug and drilled 8-1/2" hole to 4404'. Pulled to the casing shoe and ran a formation integrity test to 100 pcf equivalent mud weight. Dumped and cleaned the pits. Built new mud system and changed over. Directionally drilled 8-1/2" hole 4404'-4767'. Pulled out of hole to change bit and bottom hole assembly. Need to change bottom hole assembly to obtain a greater turn rate to the north. Tested BOP and installed wear bushing. -._ Made up bOttom hole assembly with 8-1/2" holeopener and reamed 4415'-4767'. Pulled out of hole and made up 8-1/2" bit with 2-1/2° bent sub. Ran in hole and drilled 4767'-5021'. Attempting to kick the well to the north. Drilled 8-1/2" hole from 5021'-5063'. Ran gyro survey and pulled out of hole. Picked up 8-1/2" hole opener and reamed 4923'-5063'. Pulled out of hole, picked up 8-1/2" bit and build bottom hole assembly. Ran in hole and drilled 5063'-5114'. Discharge line on the inlet water pumps failed leaving no cooling water for engines. Pulled to the 9-5/8" casing shoe and circulating. Repaired the discharge line and ran in hole. Drilled 5114' - 5200'. Bit began to torque up. Pulled out of hole. Made up new 8-1/2" bit, ran in the hole to 360' and tested the MWD tool. Gontinued in the hole to 4900' and tested the MWD. Tool would not work. Pulled out of hole to change out MWD tool. Run in hole with new MWD. Reamed and washed 8-1/2" hole 5140'-5200'. Directionally drilled 8-1/2" hole 5200'-5369'. Tripped for bit and BHA change. Washed 8-1/2" hole 5212'-5369'. Directionally drilled 8-1/2" hole 5369'-5504'. Well flowed. 5 BBL gain, SIDPP = 240, SICP 250 TVD - 4324'. Used driller's method to kill well on choke. Continued killing well. Raised mud weight 74-86 PCF. Hole conditions ok. Directionally drilled 8-1/2" hole 5504'-5880'. Pulled out of hole. Hole tight at 5401'. Swabbed well. Circulated at 5284'. Weighted up mud from 87 to 90 PCF. Shut in pressure increased from 0 psi to 100 psi while weighting up mud. Displaced well with 90 PCF mud thru choke. Ran in hole to 5880'. Changed over remaining mud to 90 PCF. Pulled out of hole. Hole tight from 5375'-5023'. Ran BOPE test - ok. Ran in hole with new bit and BHA. Ran in hole. Drilled 8-1/2" hole 5880'-5976'. (6000 units pf trip gas). Circulated. Pulled out of hole. Ran in hole to shoe~with new bit. Repaired rotary table motor cooling blower (4 hours)..Continued to run in hole. Minor washing and reaming. Drilled 8-1/2" hole 5976'-6194' (had 1600 units trip gas. Background is 45-60 units). Directionally drilled 8-1/2" hole 6194'-6349'. Attempted to trip for BHA - hole was swabbing 5842'-6309'. RIH to 6349' and drilled 8-1/2" 6349'-6366' while conditioning mud to lower YP and gels. Pulled out of hole - trip smooth. Ran in hole. Continue run in hole. Directionally drilled 8-1/2" hole 6366'-6574'. Tripped for BHA #13 - no problems. Driectionally drilled 8-1/2" hole 6574'-6586'. 2/80 UNION OIL CO. OF CALIFORNI'~ DRILLING RECORD PAGE NO.. LEASF TRADING BAY STATE WELL NO, A-19 F I E L D TRADING BAY STATE DATE E.T.D. 1988' 7/28/88 7/29/88 7/30/88 7/31/88 8/01/88 8/02/88 8/03/88 8/04/88 8/o5/88 8/06/88 8/o7/88 Feet 6966' 380' 7303' 337' 7489' 186' 7 489 ' 0' 7489' 7489' 7489' 7489' 7489' 7489' 7489' DETAIL~ OF OPERATIONS, DESCRIPTIONS & RESULTS Directionally drilled 8-1/2" hole 6586'-6806'. Made short trip to 9-5/8" shoe. Hole tight 6520'-6400'. Directionally drilled 8-1/2" hole 6806'-6930'. Made 10 stand trip - no problems. Directionally drilled 8-1/2" hole 6930'-6966'. Drilled 6966'-7155'. Pulled out of hole and changed bit and bottom hole assembly. Ran in hole and drilled to 7303'. Made short trip to 5815'. Finished making short trip. Drilled 8-1/2" hole to 7489'. Circulated and conditioned the mud. Pulled out of hole. Finished pulling out of hole. Laid down the monel collars and M~. Ran in hole and circulated and conditioned the well for logging. Pulled out of hole and made up wireline tools. Ran a DIFL-GR-Sonic to 7474'. Began logging and tool stuck 7452'. Worked tool but~could not free. Stretch indicated tool is stuck at +1600'. Made up side door finishing tool and ran in hole to 1830'. ~nable to free tool. Stretch indicated tool is still stuck at +2000'. Pulled out of hole with side door wireline guide shoe. Made up overshot assembly and stripped over wireline to 7289'. Circulated and conditioned the hole. Worked down over top of the fish at 7422'. Pulled out of hole with fish. Recovered all of fish. Rigged down Dresser. Tested BOPE. Ran in hole to the casing shoe and circulated and conditioned the mud. Ran in the hole to 7489' and circulated and conditioned. Short trip to the 9-5/8" casing shoe. Ran back to 7489' and conditioned. Pulled out of hole to run 7" liner. Rigged up to run a 7" liner. Made up float shoe, float collar and landing collar, 94 joints (+ 3552') of 7", N-80, 29/ft buttress casing and liner hanger. Ran in ho--le strapping and rabbiting the drill pipe. Liner stopped @ 7010' Unable to work the liner down the hole. Picked up and liner stopped ~ 6965'. Working and circulating liner. Continued to work liner 7010'-6965'. Spotted 50 bbls of mineral oil around shoe and worked liner. Unable to free liner. Continued to circulate while preparing for cement job. Stuck liner at 7010'. Mixed and pumped 700 sxs of class "G" with .2% CFR-3, 4% Halad 344 .1% LWL at 15.6 ppg. Bumped the plug and set the liner hanger with 2000 psi. Checked floats and pulled out of hole. Made up new bottom hole assembly and ran in hole to 2850'. Waited on cement. Waited on cement. Drilled out cement to 3377'. Tested 9-5/~" to 1500 PSI. Pressure bled to 1400 PSI in 30 minutes. Drilled to the 7" liner top at 3457'. Pressure tested the 7" x 9-5/8" liner lap to 1500 PSI. Pressure bled to 1440 PSI in 30 minutes. Pulled out of hole and laid down excess 5" drill pipe. Picked up 3-1/2" drill pipe and ran in hole. Began drilling out the 7" liner and rotary table failed. Sent crew to Grayling Platform to remove fast couple for rotary table. Machining new parts for the table. Repaired rotary table. Drilled out 7" liner to 6980'. Pressure tested 7" liner to 1500 PSI. Pressure bled to 1000 PSI in 30 minutes. Pulled out of hole. Nippled up spool and ran CBL-GR-CCL 6964'-3350' under 1000 PSI applied pressure. uNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE LEASE TRADING BAY STATE WELL NO.._~],,9_.~FIELD Tp~ING BAY STATE DATE 1988 8/08/88 8/09/88 8/10/88 8/11/88 8/12/88 8/13/88 E.T.D. Feet 7489' 7000'ET] 7489' 7000'ET] 7489' 7000'ETi 7489' 7000'ETi 7489' 7000 ' ET[ 7489' 7000'ET[ DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Finish running CBL-GR log from 6965'-3350' and CNL-CR from 6960'-3350'. Make up 6" bit along with 7" casing scraper and ran in hole. Drilled cement from 6980'-7000'. Circulated bottoms up and pulled out of hole. Ran in hole with 4" O.D. water shut off gun. Shot 4 holes per foot from 6964' to 6962', (54-S zone). Picked up cement retainer and ran in hole to 6870'. Set retainer and obtained a breakdown of 2100 PSI at 1-1/4" BPM. Pumped 175 sacks of class "G" with .2% CFR-3, .4% Halad 344 and .1% LWL. Initial squeeze pressure was 2300 PSI at 1-3/4" BPM. Final squeeze pressure was 1625 PSI at 1/4 BPM. Cement in place at 1850 hours 8-9-88. Pulled out of hole and rigged up wireline. Ran in hole and shot 4 holes per foot from 6130' to 6128'. (47-5 zone). Picked up squeeze packer and ran in hole to 5880'. Set packer and obtained a breakdown of 2500 PSI at 1-1/2 BPM. Pumped 250 sacks of class "G" with .2% CFR-3, .4% Halad 344 and .1% LWL. Limited squeeze pressure 2100 PSI at 1-3/4" BPM. Finai squeeze pressure was 2100 PSI at 1-3/4 BPM. Final squeeze pressure was 2100 PSI at 1/4 BPM. Cement in place at 2040 hours 8-9-88. Released packer, circulated and pulled out of hole. Finished pulling out of hole and laid down squeeze packer. Ran in hole and perforated (4 HPF) from 5885'-5887' (CBL) (C-7 zone). Pulled out of hole and made up 7" cement retainer. Ran in hole and set retainer at 5800'. Mixed and pumped 300 sacks of class "G" with .2% CFR-3 .4% Halad 344 and .1% LWL. Initial injection at 2700 PSI and 1-1/4 BPM. Final injection at 2100 PSI at and 1-1/3 BPM. Cement in place at 1345 hours 8/10/88/ Pulled out of hole. Ran in hole and perforated (4 HBF) from 5724'-5726' (CBL) (top C-7 zone). Pulled out of hole and made up 7" cement retainer. Ran in hole and set retainer at 5695'. Mixed and pumped 300 sacks of class "G" with .2% CFR-3, .4% Halad 344 and .1% LWL. Initial injection at 2050 PSI and 2-1/2 BPM. Final injection at 2500 PSI and 1-1/3 BPM cement in place at 2300 hours 8/10/88. Pulled out of hole. Pulled out of hole and made up 6" bit. Ran in hole to 5500'. Pressure tested the casing to 1500 PSI. Pressure bled to 1450 PSI in 1 hour. Cleaned out cement retainer at 5695' and cement to 5792'. Pressure tested perforations at 5724' to 5726' to 1500 PSI. (OK). Pulled out of hole for a new bit and ran in hole. Cleaned out cement to 5845'. Pulled out of hole and made up a 6" mill. Ran in hole and cleaned out to 6000'. Tested perforations from 5885'-5887' to 1500 psi. (Held pressure). Drilled to 6870' and tested the perforations from 6128'-6130~ to 1500 psi. (Held pressure). Drilled to 6995' and pulled out of h01e. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. LEASE DATE 1988 8/14/88 8/15/88 8/16/88 8/17/88 8/18/88 8/19/88 8/20/88 8/21/88 8/22/88 TRADING BAY STATE WELL NO. A-19 FIELD TRADING BAY STATE E.T.D. Feet 7489' 7020'ET! 7489' 7141'ET! 7250' 109' 7500' 250' 7500' 0' 7500' 0' 7500'TD 7415'ET! 7500'TD 7415'ET[ 7500'TD 7415'ET[ DETAILS OF oPERATIONS, DESCRIPTIONS & RESULTS Made up a new bit and drilled to 7020'. Pulled to the casing shoe and ran a formation integrity test to 107 pcf equivalent mud weight. Changed over mud systems and drilled to 7083'. Pulled out of hole and changed bits. Ran in hole and drilled from 7,083'-7,125'. Pulled out of hole to pick up a 6" junk mill. Ran in hole and drilled from 7,125'-7,141'. Pulled out of hole to pick up new bit. Ran in hole. (Returns indicate possibility of sidetracking old hole). Ran in hole with bit %20 on BHA~17 and drilled 6" hole 7141'-7215' Pulled out of hole - bit ran 3.25 hours and graded T-8, B-6, 1" out~ Tested BOPE. Ran in hole with 6" bit ~21 on BHA %17 and reamed 7141'-7215' Drilled 6" hole 7215'-7234'. Pulled out of hole. Ran in hole with bit %22 on BHA #17 and reamed 7215'-7234'. Drilled 6" hole 7234'-7250'. 1 Drilled 6" hole from 7250'-7381'. Pulled out of hole and picked up a new bit. Ran in hole and reamed front 7346'-7381'. Drilled 6" hole from 7381'-7500'. Pulled out of hole and picked up an 8-1/2" underreamer. Ran in hole with 6" x 8-1/2" underreamer and underreamed from 7010' to 7085'. Pulled out of hole and picked up bit and ran in hole. Circulated and conditioned mud at 7500'. Pulled out of hole and rigged up to run 5" liner. Made up 17 joints of 5", N-80, 18#/foot, FL4S liner and TIW hanger. Ran in hole to 7500' with liner, circulated and prepared to cement. Completed circulating mud and pumped 40 bbls of sepealite spacer mixed at 78 PCF. Pumped 145 sacks of class "G" with .1% LWL, .2% CFR-3 and .4%-Halad 344 mixed at 15.8 PPG. Cement in place at 0122 hours on 8/19/88. Reciprocated (30' to 40' stroke) throughout the cement job. Bumped the plug and set the liner hanger with 4000 PSI. Pulled 10 stands, pumped a dry job and pulled out of hole. Sifted BOP stack and inspected DCB spool. Nippled up and tested BOP stack. Made up 6" bit and scraper and ran in hole. Drilled out cement from 6419'-6807' (TOL). Pulled out of hole and picked up a 4" mill and 5" scraper. Ran in hole and drilled out 5" liner to 7415' (L.C.). Circulated and conditioned the mud. Pulled out of hole and made up a 7" R~TS and ran in hole. Set the RTTS at 6722'. Tested the 5" x 7" liner lap to 2000 PSI (good). Pulled out of hole and rigged up wireline unit. Ran neutron log f/5700'-7415' Attempted to run CBL but stopped to 7314'. Pulled out of hole and ma~e a mud conditioning trip. Pulled out of hole with drill pipe. Rigged up lubricator and reran CBL from 7415'-6807' (good bond). Ran gyro survey from 7350' to surface. Ran 9-5/8" casing inspection log and stopped at 3020'. Logged from 3020' to surface. Ran in hole with open ended drill pipe and pumped a 50 bbl high viscosity sweep followed by 25 bbl of floculant. Continued circulating with filtered inlet water until returns were clean. Began to displace the wellbore with 72 PCF completion fluid and filters plugged. 2/8O UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. LEASE DATE 1988 8/23/88 8/24/88 8/25/88 8/26/88 8/27/88 8/28/88 8/29/88 TRADING BAY STATE WELL NO. A-19 ,FIELD TRADING BAY STATE E.T.D. Feet 7500'TD 7415'ET! 7500'TD 7415'ET[ 7500'TD 7415'ET! 7500'TD 7415'ETI 7500'TD 7415'ET~ 7500'TD 7415'ET[ 7500'TD 7415'ET£ DETAIL~ OF OPERATIONS, DESCRIPTIONS & RESULTS ContinUed to build volume and change over to 74 PCF Brine (FIW with 3% KCL and NaC1). Circulate and filter to 46-58 NTU using Baker DE filters. Rig up Dowell and pumped 500 gal Xylene followed by 500 gal 15% HCL. Began to displace and found acid in annulus. Reversed acid & Xylene to surface tanks, neutralized acid, and shipped to production. Found problem in surface lines which allowed some acid to flow into annulus. Circulate well to check for acid - none found. Circulate and built fluid volume. Continued to circulate and build fluid volume at 7415'. Pulled out of · · , 8# hole. Rig up Atlas wirellne. Ran in hole with 3-1/ perf guns, 4 HPF at 90° phasing, perfed "D" zone as follows: 57-2 Sand 56-1 Sand 55-7 Sand 54-9 Sand 54-5 Sand 53-8 Sand 7281'-7367' DIL 7154'-7240' DIL 7125'-7147' DIL 7045'-7095' DIL 6983'-7015' DIL 6934'-6950' DIL 7259'-7345' CBL 7131'-7217' CBL 7101'-7123' CBL 7022'-7072' CBL 6961'-6993' CBL 6912'-6928' CBL Rig down Atlas wireline. Ran in hole with Geo-Vann tubing conveyed perf guns. Finished running in hole with tubing conveyed perf guns. Tied in guns on depth with CNL-GR. Perf the following zones with 4 HPF at 90° phasing: 51-6 6670'-6730' DIL 50-3 6476'-6505' DIL 47-5 6032'-6140' DIL C-7 5755'-5890' DIL 6647'-6707' CNL 6453'-6482' CNL 6009'-6117' CNL 5732'-5867' CNL Circulated after firing guns. Well took 45 bbls of fluid. Pulled out of hole and laid down guns. Ran in hole open ended and reverse circulated out fill from 7365' to 7415'. Cut the mud weight back from 74 CF to 70 PCF. Pulled out of hole to 7230' then ran in hole to 7415' (no fill). Pulled out of hole and made up a 5" and 7" scraper. Ran in hole to 7415','began circulating, drill pipe plugged. Pulled out of hole and found cement drill pipe dart and plastic coating from the drill pipe had plugged the 5" scraper. Began to unload and pick up 2-7/8" and 3-1/2" tubing work string. Finished picking up work string. Circulated and filtered completion fluid. Cut mud weight back to 68 PCF and well flowed. Increased mud weight to 70 PCF and pulled out of hole. Made up 7" packer and ran in hole. Set packer at 5622' and tested equipment to 1500 PSI. Displaced tubing with FIW and performed step rate test. Injected water at 2-1/2 BPM with 1800 PSI. Ran spinner survey and found all water being injected into the C-7 sand. Killed well and prepared to acidize lower sands (53-8 to 57-2). RIH with 7" packer and set at 6754'. Attempted to establish injection. Pumped at 1/8 BPM and 1725 PSI. Released the packer and POOH. Picked up a 5" packer and RIH to 6832'. Set packer and established injection at 1-1/2 BPM and 2250 PSI. Pumped 1st stage of 2350 gals 7.5% HCL, 4725 gals 6.0% HCL and 1.5% HF 10,500 gals FIW with .5% surfactant and 2015 gals of FIW with 1 ppg Benzoic Flakes and .5% surfactant. Pressure increased from 1900 PSI to 2150 PSI after diverter contacted perforations. Began pumping 2nd stage. 2/80 UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. LEASE DATE 1988 8/30/88 8/31/88 9/01/88 9/02/88 9/03/88 TRADING BAY STATE WELL NO. A-19 ,FIELD TRADING BAY STATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Feet 7500'TD 7415' 7500'TD Pumped second stage of "D" zone acid job consisting of 2,350 gallons 7.5% HCL, 4,745 gallons 6.0% HF and 10,500 gallons FIW with .5% surfactant. Final rate 3-1/2 BPM and 1,900 PSI. Well on a vaccum after job. Pulled out of hole with 5" packer. Picked up 7" bridge plug and packer and ran in hole. Attempted to set bridge plug at 6,770' without success. Pulled out of hole with bridge plug and packer. Left bridge plug in the hole. Ran in hole with an overshot and tagged bridge plug at 3,467'. Worked down to 3,480' and pulled out of hole. No recovery. Ran in hole with overshot to recover bridge plug. Tagged 7" bridge plug @ 3460'. Worked the plug down to 6775'. Pulled out of hole and recovered the bridge plug. Made up a new bridge plug & packer & ran in hole. Set the bridge plug @ 6760' & the packer @ 5950'. Obtained an initial injection rate of 2 BPM @ 2500 PSI. Pumped a 2 stage acid job on the lower "C' zone (47-5, 50-3 & 51-6)tas follows: 1st Stage 2350 gals. 7.5% HCL 4745 gals. 6.0% HCL 1.5% HF 10,000 gals. FIWw/.5% surfactant 2050 gals. FIWw/.5% surfactant & 1 PPG Benzoic Flake 7500 7415' 2nd Stage 2395 gals. 7.5 HCL 5670 gals. 6.0% HCL & 1.5% HF 9790 gals. FIWw/.5% Surfactant Final injection rate of 3-1/2 BPM & 2050 PSI. Released pkr & ran in hole to recover the bridge plug. Pkr stopped @ 6107'. Well was flowing. Circulated out 65 PCF filtered inlet water. Built the mud weight from 69 PCF to 70 PCF. Circulated well & observed for flow. Slight flow. Began to build weight to 72 PCF. Built mud weight to 72 PCF. Well stable & pulled out of hole. Picked up a 6" bit and ran in hole. Cleaned out hard benzoic acid flakes @ 6130'-37', 6483'-97' and 6619'-6714'. Circulated @ 6740' & pulled out of hole. Ran in h°le with an overshot & recovered 7" bridge plug @ 6760'. Pulled out of hole. 7500'TD 7415' Made up 3-7/8" saw tooth collar and cleaned out to 7415'. Circulated and Conditioned then pulled out of hole laying down 3-1/2" and 2-7/8" drill pipe. Made up 7" Baker permanent packer and ran in hole. Set the packer with the equipment as follows: 7" FB-1 permanent packer - 5295' ~ Otis X Nipple - 5313' Wireline re-entry guide - 5351' Ran in hole and tested the packer. 7500'TD 7415 Pulled out of hole and laid down the 3-1/2" PH-6 work string. Ran in hole picking up the 3-1/2" DSS-HTC completion tubing. Stabbed into the packer and spaced out. Pulled out of the packer and displaced the annulus with corrosion inhibitor. Landed the tubing and nippled up the wellhead. Pressure tested the tubing and sheared out the pump out plug. Tested injection rate at 5 BPM and 1500 psi. Released the rig at 2400 hours on 9-3-88. ~-.~ ANCHORAGE ALASKA UNOCAL A19-RD ' ~ ~_ C; ~ COMPUTATION ~A~E TRADING BA ALASKA . ...... VERTICAL'SECTION CA~ILATED ~LONG'CLOSLIRE .............................. MEASURED 0 100 200 300 400 450 ...... 500 .~lI~,~ 600 650 700 ................... 750 GU(.) 850 PO0 "( ' ~750 1050 1100 1'-'c ' 1~00 1400 - 1500 1600 1700 1750 1800 2000 2100 ......... 2200 ............. SF:ERR_Y=$UN WELL_SURVEYI N6_C_OMP__AN_Y_ DATE OF SURVEY AUGUST 22, ............... BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO-80070 KELLY BUSHING ELEV. = OPER~T_OR:HARGER. TRUE SUB-SEA COURSE COURSE DOG-LEG .... VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY DEPTH DEPTH DEG MIN DEGREES DEG/100 -105· O0 0 0 5 1 17 44 .... 16 .... 28 46 47 38 48 N O. OE S 42.30 E N 52.10 E N 40.1.9 W S 78.10 W S ..85..39... W N 87.69 W N 84.50 W N81. OW N 78.60 W N 77.60 W -5.00 0 95.00 0 195.00 0 294.92 3 344.73 .................. 6 394.31 8 443.5~ 10 4?2.53 12 541.10 14 589.22 16 ......... 19 ...... 5 ........N 77.1.9_.W ................ 21 37 N 77.19 W 24 15 N 77.1~ W 26 2 N 79.10 W 25 55 N 85.60 W O. O. O. O. 3. 4. 4. 4. 3. 4. 4. 5. 5. 3. 5. 636.78 683.64 729.6~ 774.74 819.90 24 37 S 83.80 W 4. 25 ...... 15 ......... S 81.69.W ...............2. '-' 80. A'-] ;:, .... W 4. '.-]10.38 955.71 1044.51 1129.9;~ 1212.58 12'.-72.60 136'?. 7,5 1444.28 1481.14 1518.41 15'P:3.70 1668.88 1742.82 · . 0.00 100.00 200.00 300.00 399.~2 44~.73 499.31 548.5~ 597.53 646.10 6~4.22 741.78 788.64 834.6? 87W.74 ~24.~0 1015.38 1060.71 114~.51 1234.~ 1317.58 13~7.60 1474.75 1547.28 1586.14 1623.41 1678.70 1773.88 1847.82 1721.01 1816 O1 42 48 S.. '=":' /-,9 W O. TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST O0 ............O. O0 .......... 09 O. 06 S 09 ............. O. 11. S 29 0.10 N 61 0 '::'-' 23 ....................... O. 94 5Z 1.14 S S S N N N N N N N N N N N S S S PAGE 1 02 .................... 33.31.. 35 36.96 66 38.33 50 40.06 .. 58 41.~0 58 43.48 29 ................. 45.03 1988 o._,. 0 0 F T. VERT I C:AL SECT I ON O. O0 0.05 E 0.12 E 0.03 W 3.39 W 7.71 W · 14.12 W 22.46 W 32.58 W 44.24 W 57.49 W 72.52 W 8':?. 48 W 108.48 W 129.27 W 150. ':?4 W 152. °:?0 193.47 W 174.82 214.37 W ....... 215.06 259.78 W 258.84 311.03 W :_--:08.25 366.74 W 361. 425.97 W 419.06 488.66 W 479.3:3 0.00 -0.06 -0.13 O. 04 3.2'P 7.47 13.78 22. O'P 32.2'.-?' 44.14 57.66 73.03 :?0.3:3 10'P. 6:2 131.03 S .... ,~.40 W 542 ~':' .............................. . .. :3 ._,._,7.9A W S 621.26 W 607. ,'_=:6 c. ~.o o . . :,_,7.05 W 672.59 ,-' -Z 5 o -.. ~. ':77 W 737.43 ,-' 0'-.: (5 '-~ ~. '-' ' '-' ;-"" '...,-' .- -'- "',W · ,:, L).:,. 6 7 ............ c,,:,,:,..:,,:, W :-':70.74 UNOCAL A19-RD ................ COMPUTATION DATE TRADING BAY AUGUST 23, 1°°'~.=.o ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE ~ERRY~SUN WELL SURVEYING COMPANY__ ANCHORAGE ALASKA PAGE ? DATE OF SURVEY AUGUST 22. 1988 ............ BOSS GYROSCOPIC SURVEY dOB NUMBER AK-BO-80070 KELLY BUSHING ELEV. = 105.00 FT. OPERATOR-HARGER. TRUE 2300 199:3. 2400 2067. 2500 2140· 2600 ..-...z .- 2700 o.-,,",= ZO(.)(.) '-"'{" ~'~' 2900 2433. · z. '.)0o 2511 :3100 .-,='c,,c, .,~ o_, .': .,, · ..... 3";'C)0 '-'/ 33C)0 '-' '"'-' =' ~ !.', ,_1 · :'::40C) · _-,o00 2,_--:74. 360C) 2944. _/ .... 3700 .... o013. · _','-' o '-' (' ~) (.) ' -~, () o .-., yI . I.I,__I · 3900 '" 4000 .:,o.':,.:, 41 O0 '~":,o 1 4200 '""'='-' .~,."~..~ ~ · 4300 3427. ........... 4400 3497. 4500 '"=' '-' 46c)c) '-'/- . . ...,-,41 ........ 4650 :3677. 47(:)(:) 3714. 47._, .) 3751 ............ 4:3C)0 ,:,7,=,,=,, 4900 3864, 5000 '-,o . .............................. · z,... 41 SUB-SEA COURSE COURSE VERTICAL INCLINATION DIRECTION DEPTH BEG MIN DEGREES DOG-LEG SEVERITY DEG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SEC:TION 94 1888.94 10 1962.10 07 2035.07 78 2107.78 74 2180.74 54 2253.54 33 2328.33 80 2406.80 55 2485.55 23 2560.23 ~7' 2630.77 38 2700· 77 276~. 0~ 2839. 65 2908. 77 2978. 85 3048. 19 ........ 3118. 84 3186. 64 3254. 62 3322. 63 3392. 15 3464. 17 3536. 60 3572· 26 360~. 29 3646. 77 3683. 47 375~. 18 .... 3836. 43 31 42 25 43 49 · 42 52 43 25 43 7 40. 3 36 32 39 32 43 47 46 8 S 88.80 W 0.72 46.52 S S 89. 0 W 1.11 47.83 S ::; q'--' 89 W 1 40 49 c),-. ........... ~. 0 S ~--~i ......... S 89.50 W 1.04 5(3.(')4 S · =,'-' 89.50 W O. 54 50.64 S .............. S...89.89 W 0,.40 .................... ._1,?,. 00.... S 88 50 W 3 22 51 '-' .:/(-) ,-. o'-' :=:~:.-- :='9_. W 3-. 52 53.o~'-'"' $' S 88 30 W ..... ~,02 o4. · ............... 0-_, S 87.89 W 4.2~_ 57. (:)5. o ~.o. 19 W 2 36 ='- · o .'.~. 45._."" ~56.78 W 1024.94 W 1073.27 W 1161.93 W 1230·32 W 1298.86 W 1365.23 W 1427.17 W 1488.77 W 1555.19 W 1625.80 W · =,o 45 ._.=;A o oR. 10 W 0,20 ............... 61 77..S 16';'7 75 W ..................... -- -- . ';-' .... ~..'~.,. ......................... I .......... · 7 7 4 6 10 :--; '-~':' '-' ' - ':' .o0 W 0.55 6 .... 72 S 17/_-,9 7:3 W I~ Iii · C) 9 46 4 ':' R':' '-'9 · . .... ,.,_,..:,. W 0.31 6,5 4:3 .S 1841 79 W 65 45 46 '-' ':'- .... o ...LC. '~':/ W O. '--'r 3 · :,.) 67 48 .'5 191 .60 W 77 45 10 S '"'=' . ; ¢,=. 86 W o,:,. 10 W 0.63 69 66 S '--'= :-]6 '-' 2c)5/-, 16 W ,:,._, 4 5 5 0 .S '- '-' :do. 19 W 0.66 71. .:, ..... 938.08 1005·22 1072.55 1140.22 1207.6~ .,. 1275.36 1340.78 1401·77 1462.38 1527.67 15~7.06 ........... 1667.7~ 1738·60 1809.52 1880.15 1750.22 2020.30 19 46 zl ,:. ,:,o 19 W 0.52 74 ~Z:~ S ~1'-"-' 18 W 20'P1 11 · --' . '-"-' · a ......... /-':' i ....... . 84 46 56 S ,-,o_ - o .... 5(3.. W O. 62 76. :~:Z ._,':' 22C)0... P,A_ _ W c,R 60 W 0.74 78 18 S 2274 34 W 64 47 40 S ,_,,_ .... · _,'.-/ S '-"- 60 W 1 26 79 33 q _ ,:,~ ..... 2:347 6A W 63 44 '-"--' '-' ' ')'-' · .',--, N E:6.8'P W ': 32 77.69 .:, J. 241'~/. (. z W '-' = .... 72 ~ '-' ,-4 ...... 71 W 15 44 13 N o4 60 W 1 / '-~ - '-~' ':":' i · . ."m I 17 43 '-"-'~ o- ='C o oC) = ":'.=;'= 4'.-.? · _',.. N ._, .) W 63 ..,4. '-' .......................... ,_,O. 7 W .....................~1 ,' ~ ........ I ."! .... . ......~..~.. ~,~l · - =' ._ .:, -'~...1 08 W 60 4Z 46 N 77, 30 W 4, 72 o6.9& '-' '-'.=,'-? . 26 42 54 N 76.10 W 1.65 49.13 S .'>z=.'"/"-'a 16 W .:'.~z 41 30 N 74 A.-7/ W 3.37 40 67 '-' 2ASA 67 W .... i --.- .......................... · .~l ..... · 7'7, 41 19 N 7:3.69' W 1.37 31 .6,7 S ~'-'/':"-'::,,..,o.._'-it)_. W 47 40 17 N 70. :::9.. W 2.10 11 .82 ._-.'-' ~.'s'7.=,0... 74 W 18 2162.6(3 2234.90 2307· 16 2377.92 2447.57 ...... 2516.91 2551. 11 2585.01 .~.c 1':' 4._-3 2651.27 2715.83 39 31 N.67.,19..W 2.4'~ .................... 11 "- OY.N, '-""'~(" 62 W '-'":"~':: 54 ........................................ I .......... ~_~ii ............................................... _SF.'ERR.Y-__S.UN..WELL SURV. EY. I NG _COM_PANY_ .......................................... ANCHORAGE ALASKA UNOCAL .... A19-RD TRADING BAY ALASKA --'VERTICAl-SECTION CALCULATED--ALONG 'CLOSURE ........... ........... RAGE. 3 DATE OF SURVEY AUGUST 22, 1988 ....................... COMPUTATION DATE ..................... BOSS GYROSCOPIC SURVEY AUGUST 23, 1988 dOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. .................... ~!PERAYOR~_HARGER ............................. TRUE ....... MEASLIRED- VERTICAL (' r'EPTH DEPTH 5100 4017.o._,'-'= 5200 4092.97 5300 4166.34 5400 4239.57 5500 4314.71 - _ '~"~ 5~,00 4~, 71. 'P I 5700 4470.54 5,'_--:00 4550.25 5900 4630.21 6000 4710. 25 23 17 74 76 15 62 24 87 82 84 91 17 36 6100 4790, ................ ,5,200 ............. 4870. r-,ol.) 0 '" ''''/=''"1 /..,~ ' . ,.,o0 5117. · 660o ='-'""-' . ~.l .-' ,...m..-, m 6700 .=, .r,,'o c, 6000 .~.-,-z,-, ....................... · -- ..2,/~ · 6900 5465. 7000 5553. 7100 5641. 7200 7300 ._,=,19. .......... .7...=,. ~,C~_ ........ 5:$:64. SUB-SEA VERTICAL DEPTH COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION .... SEVERITY--RECTANGULAR COORDINATES ·VERTICAL DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION :_:_:912 · 39Lq7.97 4061, :_--:4 41:'-:4.57 4209, 71 4286.91 4365.54 4445.25 4525.21 4605.25 4685.23 4765.17 4845.74 4927.76 5012.15 5098.62 5185.88 5273.24 · .. 536_-,0.87 5448.82 5536.84 5/_-,24.91 5714.17 .... 5759. ..... 40 ..... 21 ......... N'--Z-5~O;'5-W 1.1:_°. 36.64 N '-"=: '- 42 1~ N 65 39 W 1 90 /_-,._-,. ':'=.. '"'--,'-'¢, · . .~...~.': . · i~I ..,... 4:2: ~:Z N -,'=' .... .5._,.0 W 1 17 92....=. ....... · z,.-, N 2991 · .............. 42~.:"7'3 N 6,4.30 W 1 .02 121 .50 N :3052.. 40 6 N E._, 8.-.~ W 2 ='- .... , .-.~ 149. '" ' · :,0 N 31 12, o,:, .... 49 .............. N 64..50_W .............1. · ~.'..-' N 61.80 W 2. · -',=, 48 N 6,1 60 W 0 37 0 N 61.80 W O. z5:6 39 N 6,1. 0 W O. 37 7 N 6, 0..:,'-"(.) W 0 . ......... 3642 ....... N 6,0.39 W ............O. :-":5 ..,,., N 60.19 W O. ,:,o 49 N 6,0.69 W 31 3 N 61 '-"' .o~Y W .............. 2. 29 13 N 61.3'P W 1. 29 13 N 61 ,-,o . · .o. W 0 z..'~ .... 1 ........N._6.1.60...W .................. O. 28 34 N 61.30 W O. ;Z~:, 16 N 60.69 W O. .- ,-, .-.,.7., '/,:, N 61 0 W 0 · .,-, . N 6,2 69 W O. 25 ':'=- · -'-._, N 61.6'.-.?W 2. 3/:, ........ .~.,,">5 .......................................... 1.7:; N 51 W -..:~4.. 67 6,3 W 2904.27 30 W 2969.61 :S'4 W '-'"-' . · :, 0.:. 4 'Fy 1 67 W .-,,-,o,-, ._ ov .. ,:, · 13'D 56 1 7o. 94 N 70. Bt'_-, W .. .s: 1 ='- 1:3 '-' ' ':' - - '3":"--' =- 47 W .,:. 0..:~ · :-: ~Z N .-~.:', l :-R, 1 '-? · , ~ ,1~ ,_i · ,-- ~ .2. _ · . .5,9 :Z3'>'. 45 N :3278.6,4 W .:,..7.., 1 22 ...... 260.92 N 3331.51 W 'q'-~'- ..... L'~I. 7'P .~,:,:.-. 6,1 N '"'"'-' - - .... .:,.:,,:, 4 14 W '" '~''-'':' 4,':-,' 31L-:-. ,_, :~ 1 N ._,4._,6'~' '--' .60 W 3444 . ..F--';/-:.-, 48 '-'~' '-"'- q'~'"'-' 9:::W .............. .:,-,,:, ..~ P N 3500.82 ............ o. '~L.-,O.. _ . ......... 79 377· 6.4 N ._-,._,40 ..... ._q'='o W -q =' =' r., .., ~_, . 19 1 '=' 405·,:,4'" N · .:~._, .-.- .~ 11 W ._-, :, 0 ?,'. 81 .... 4:31,81 N ':'-'-q ..... · .,6._7,04 W :--.:Ah, A 07 :", .- m' ~__ .-., ,.7., ~ 4 .-~ ,.J · ''° I=' , o.., N :3/-,,q 1.1 W :_"1707 ':"-> · ,'i ---,~ 20 479.07 N .:,7~.4.07 g :s:7~:~. '--'/- _ _ '"':' 5o2..! 5 .N 376,6.9::: g .... 37'P9.27 · l~, ,--I ......... - . .......... . 47 ~-'--'S · _,~... 17N '-"='"- '-"-' =,._, · :,,--,L~Y. 24 g o044. 41 ?,~:'~ 24 N '-":'.~,¢' --,o,-,,- --,.-, ,: ........ .87 g ._',,.,o X, · -- --r*_ · 17 571 ?,/--, N .~,-,o.-, ........... o .'. ~' "' "'"? ':' ~ 07 g ._', .'. 7 ,= .... 6 o._', 5'rye::. 70 N '-,o ,-, ,,i ,, ,_i i~ · 77 614.71 N 3973.95 g 4021.~.1'-' 41 '--' '-' ............. 6-"4.06 .N ............ o,-,: ._-. · .,~../-.-. 78 g ........... 4041.38 HORIZONTAL DISPLACEMENT = 4041 '~'~ - .oo FEET AT NORTH ~1 DEG. 6 MIN. WEST AT MD = 7:35(:) THE CALCULATION PROCEDURES ARE BASED ON THE LISE OF THREE DIMENSIONAL RADIUS OF L, LRVATURE-'; ' ' METHOD. .......................................................... i .......... ~E~RY~SUN WELL.$.URVEYING_COMPAN¥_ ANCHORAGE ALASKA UNOCAL _.A19-RD TRADING-BAY ALASKA ........................................ PAGE ..4. DATE OF SURVEY AUGUST 22, 1988 ........................... COMPUTaTION. DATE .................. AUGUST 23, 1988 dOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. .............................. ~PERATOR.HARGER ............ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE ~_ASLIRED VERTICAL ~.. 2PTH DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL NORTH/SOUTH .......... E..A$__T_/._WE_~.T_ .. £!I_.FFERENCE ...... CORRECT I L'IN .. 0 O. O0 -105. O0 O. O0 O. O0 O. O0 1000 9.*70 02 '-'/- = 02 '-'= 05 N 172 48 W 29 98 29. .,-' ,,I · ............. · ........... · :,(')('x') 1773. ::::~ 16c,,:,.,:,,:,'~'~' 41 'pO S 752 97 W o--.A 12 196. 14 3000 ~'=" '-' "~ ~'" z._, l 1 z 4 o 6. '-'" ,:,t S' 1427 17 W c, 0 ~--, .-~ o ,-,,~, 4c, c~. '-'~' '"~ ''~ ~000 '~'-"?'- - · _,~ ~ ;_~, 19 311 ~, 19. 7 ~, 23 S 21 ~o '~''-' , 1 :~ W 776, 81 ~,=,,_,. 61'-'"'° 5000 3941 18 '-,,~'-,~ - - ...... ,c,.-, 0 c,,:,c,:,.l': 11 09 N ~:10 62 W 105:~: ~Z ~._, ~,_, ~.. ~ ~ ~ ~::~ ~ G ~ ~ '~,~,~, _ .... . ~o :~. 75 2:::('). '~"" 7000 =SM'-' -'- =~':' '~"-' - · -,~.:,.~:Z 548 24 N 3850 87 W 144~ 18 156.44 ._l~i~i.i:,~ ... . ....... . 7350 58&4.3& 57._,y. 3& &24.8& N 3'P'~2.. .78 W i~'R=~..,. &4 .:'"'~ .... 4d, ........ .T..HE......C.A..LCULATION PROCEDURES ARE_BASED ON_.THE_L!SE_C!.F__THREE.. DI.MENSIONAL_... RADIUS. OF.....F:URVATLIRE METHOD UNOCAL A19-RD TRADING BAY ALASKA ................................ _S..P_ERRY_..SUN WELL.· SU..RV_EY ING_C.C!M. P_ANY_ .................... ......... PAGE 5 ANCHORAGE ALASKA DATE OF SURVEY AUGUST 22, 1988 ........... COMPUTATION.DATE ............. AUGUST 23, 1'~'~'~oo JOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. ...................................................................... OPERATOR~HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH (:A. URED ~3PTH TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH TOTAL ....................................................... RECTANGULAR COORDINATES MD-TVD VERTICAL ·. NORTH/SOUTH .............EA...S.'.T/_._WE~_T_ ..... D !FFERENCE ........ CORRECT I ON 0 105 205 305 405 505 607 711 817 927 1038 1149 1264 ..1384 1509 16,40 1775 1908 2041 O. O0 105. O0 205. O0 305.00 405. O0 505.00 605.00 705.00 805.00 905. O0 1005.00 1105.00 1205.00 1305. O0 1405. O0 1505. O0 1605. O0 1705.00 1805.00 ............ .~i. ~ i, -105.00 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 ~00.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 O. O0 O. O0 O. O0 0.O6, S ....... 0.06, E ....... O.00 O.00 0.10 S 0.12 E 0.00 0.00 0.11 N O.'A . O~ W O. O0 0 00 0 44 '" . ................ . ~ 3.76 N 0 0:-.? . O.O'P . 1.13 S 14.97 W .. 0.76 0.67 0.91 N 1.90 34.26 W 2.66 6.;°/-_, N 60.67 W 6.2A. c,~'. 60 14 '~ '~ '- .~._, N ....,.97 W 1Z.66 6.40 23 ~'-~ '-' R7 ~ N 141 33 W ~:2. 10 21 i I i___ ~4 ~4 N 1 ....... W 10 71 I 17 87 N 236.05 W 44.42 10.,=,4 9 05 N '-,9'~ - . . ~; ~. 24 W 5'~. 49 15. 0o"~' 0 87 S' .-,~ c,~ ~ 79 .... . ...... . , ~,._ ..._ ...... ~ 20.04 1~. '-~ 50 S 431 . 75 W 104.44 24.91 ~6 91 S 514.44 W 1'~'= ...... ,. 01 30.57 ............................. ~-c.)~,. 01 W 170.44 .................... 43 40 '-~ '~' '~'o '~' . ~ .S A'~2._. .,~='~' W :, .:,. 34 :>:~.' 91. 42 57 '-' 780.54 W 23&..,='-Y '-"~ '~= UNOCAL A19-RD TRADING BAY ALASKA ................ S~ERRY~SLIN WELL. SURVEY!NG_._COMPAN~__ ......................................... ..... PAGE 6 ANCHORAGE ALASKA DATE OF SURVEY AUGUST 22, 1988 COMPUTATION DATE ................................ AUGUST 23, 1988 JOB NUMBER AK-BO-800?O KELLY BUSHING ELEV. = 105.00 FT. ................................................................ OPERATOR,HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH I'RUE SUB-SEA >~EASURED VERT I CAL VERT I CAL ~., .:F'TH DEPTH DEPTH 2178 1905.00 2315 2005.00 2451 2105.00 2589 2205.00 2726 2305.00 2862 2405.00 2991 2505.00 3118 2605.00 · -~,5 2705.00 3399 2805.00 3543 2905.00 3687 3005.00 3830 3105.00 3973 3205.00 ' 411'~ '~'-"~ . . 4267 3405.00 4410 3505.00 4549 9605.00 4687 3705.00 TOTAL RECTANGULAR COORD I NATES MD-TVD VERT I C'AL NOR TH / SOUTH ......... EA:ST_..~ WES T. ..... D.I FFERENCE ........ CORRECT I ON. 1800. 1900. 2000· 2100· 2200. 2300. 2400, 2500· 2600. 2700. 2800· 2900. 3000. 3100. 3200. 3300. 3400. 3500. 3600. 00 O0 O0 O0 50.80 S O0 .51.39 S 00 53.21S 00 55.20 S 00' 58.43 S 00 61.76 S 44.69 S 873.55 W 273.18 36.59 46.74 S ~67.28_.W 310.26 .37.08 48.44 o'-' 1059.77 W 346.48 36.23 49.98 S 1154.70 W 384.38 37.90 .1248.55_..W ............... 421.52 .............. 37.14 1340.92 W .457.67 36.15 1422.07 W 486.50 28.83 1500.87 W 513.86 27.36 1593.72 W 550·40 36.54 1697.36 W 594.45 44.05 O0 6,4 '-"- -' ....................... ,..=, :"x S ................... lo01 00 67 24 '-' ~J4 · .--, 1 '- (' 00 70. :37 S 2006 00 7:2:. 63 S ~.10:?':' 00 76.69:3 '--'"~' ~-'-14 O0 79 17 S "'"'-"-' · z:. -~, ~ ..', 00 77 30 '-' '-' '-' .......................... :.-, ......... ~4-'6 00 Z-:,c~ ~' . 62 S '-' ='-''--' · -' ._m.,:~.._~ O0 51 '-" ::, 2615 '-"' /-'-'":' 65 · ~ 1 W 44.19 · 71 W /-',,:~. 60 43.95 · -'~ . ?, '-.° .21 W 7~._,.11 42 .-.. 11 W -'/' ~' 6,4 43. ~'~' 'P4 W 814 '-"~' · · ~,_-, 4.5.64 .70 W 86,2.05 47.77 24. · W ~05.:~2 43 o.~ W 944 c, 9 '-"-. 5 · ~,~ o~ ~7 W ~oo.~. 35 37 .46, UNOCAL A19-RD TRADING BAY ALASKA 4821 4953 5083 5216 5353 5487 5616 5743 5868 5993 6118 6243 6366 6485 .. 6601 6716 6830 6944 7058 TRUE VERTICAL DEPTH 3805.00 3905.00 4005.00 4105.00 4205.00 4305.00 4405.00 4505.00 4605.00 4705.00 4805.00 4905.00 5005.00 510'5.00 5205.00 5305.00 5405.00 5505.00 5605.00 _SE'_EBRY_-_E:UN WELL._SURVEYI NG._ _C.OM.F.'ANY ANCHORAGE ALASKA COMPUTATION DATE AUGUST 23, 1988 ................ PAGE 7 DATE OF SURVEY AUGUST 22, 1988 · dOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. ORERATOR~H~RGER ........ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEF~TH ........... NORTHZSO.LITH ......... E~T~_WEST ..... DIFFERENCE ....... CORRECTION 3700.00 27.67 S 2702.18 W 1016.57 34.24 · =,,.,oo O0 0.36 S 2783. O0 W 1048.05 '--'1.46 ~ ~00 O0 :~'.-'. 18 N -r,,-,=,- .-, - ~c~._,~. 54 W 1078.1'-' 0,-, 4000. O0 68.40 N ~.°9':'°~.. 55 W 1111 .24 :::3. .11 4100 00 107.77 N 3024.24 W 1148 08 ,S:4 '~'' ] 34 4zoC 00 145. ~71 N 3105.15 W 11 '~"-' '~' ,=~z. ~6 1 '~' 4'::rx]~... 00 180.48 N 3179. o=,'-'~ W 1211. ,~,0'-" 4400 00 '~16 30 N '~'<' '" oz4~. 74 W 1 '-'~"~' . ~oo. 41 61 4500 O0 '"~ z._,l 94 N 3314.77 W 1'r' '-' ~6.~.. 43 '"~ . . z._,. 02 4600.00 287.71 N 3380. Y2 W 1~,o'-'~'-'. 45 ~._'-'~. 02 4700 O0 ................... ~,~4..~6 N 3446.3& W 131'~ ~'-' 4o00. O0 ~,=,1 11 N '~'= - . ~,11 48 W 1'-~° 43 ~4 90 .-,.- . ~,~ .~, c. 15 4~rx]. O0 o ~6.74 N 3573. '-"- . .. ~ W 1361 .,o ~ .... ~0o0.00 428.27 N 3630 55 W 1380 78 1 5100.00 456.22 N '~A'-' ·_col W 1 15. ..... 91 ._ ~ 00.00 c..-, - 4~,~.~:1 N 3731 03 W 1411.18 14.5'~ 5:~:00.00 ~ ' '- Y ~ W ............ 1 '~'~ · .,0:~. 21. N 377'P '-'- ................................ -- . . .................................... 4~._, 61 14.43 5400.00 ~'~ ~'~:'~ ~1 W 14::::~ ._,~,.40 N 13 94 55or~. O0 .., =, 1 71 N 3874 ~ 1 W 1453 1.:S: 13. ~'~' SPERR~cSLIN WELL SUR~EY I NG_.COM~'~ANY_ ANCHORAGE ALASKA UNOCAL A19-RD TRADING BAY ALASKA PAGE .... 8 DATE OF SURVEY AUGUST 22, 1988 COMPUTATIONDATE .................. AUGUST 23, 1988 JOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. OPERATOR~HARGER. .. INTERPOLATED VALUES FOR EVEN 100 FEET OF oUB-~EA DEPTH ,EF TH ]'RUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH. .. NORTH/SOUTH ............ E..A_.~_T_/_WEST ......... DIFFERENCE .......... CORRECTION . 7171 5705. O0 56A0 ...... O0 c,,_,7._,_-,.=,'~-' N .~v.-~,.-,..-~_. ~i., .... W 1466.74 7284 5805.00 5700.00 611.4~ N 3~67.94 W 147'2.27 .... 14o~,. 64 ?o~,~'~=('., .Jo~-4='~ 36 .J7.Jy= ='- 36 624 86 N 3992 78 W 13.61 1'-" 5:3 6.37 THE CALCULATION F°ROCEDURES USE A LINEAR INTERPOLATION BETWEEN ...................................................... THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS ........................................................................... SF.'ERF,.'.Y_-_SUN .WELL. SLI_~_'~.E¥ I NQ_COMFZ~NY ....................... PAGE.__8. ANCHORAGE ALASKA DATE OF SURVEY AUGLIST 22, 1988 ....... COMPUTATION.DATE ....................... AUGUST 23, 1988 JOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. __O~ER~TOR~HARGER .... UNOCAL Ai~-RD TRADING BAY ALASKA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ( ~"SASLIRED _.£PTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL · DEPTH .... NORTH/$OUT. H ............_EA_S_T_/__WE...~.T._.D I FFERENCE .......... CORRECT I ON 7171 5705.00 5600.00 587.58 N 3922.~_ W 1466.74 13.61 7284 =~"~ ~,c,~,._,.00 5700.00 611.49 N 3967.94 W 1479.27 12.5:3 7350 5:~A4.36___ 5759.36 6~4.86 N 3~92.'78 W 1 4oo.64'-'= 6.37 THE CALCULATION F'ROCEDLIRES USE A LINEAR INTERPOLATION BETWEEN ................................................ THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS September 1, 1988 Mr. Robert C. Warthen UNOCAL Alaska District P.O. Box 6247 Anchorage, AK 99502 Re: Boss Gyroscopic Survey Job No. AK-BO-80090 Well: A19-RD Field: Trading Bay Unit Survey Date: August 22, 1988 Operator: D. Harger Dear Mr. Warthen: Please find enclosed four (4) copies of our Boss Gyroscopic Survey on the above well. Please note the original copy was sent to Mr. Underhill in Santa Maria, California. Thank you for giving us this opportunity to be of service. EnclosUres Sincerely, NL SPERRY-SUN, INC. Ken Broussard Western Area Manager NL Sperry.$un/NL Industries, Inc. P.O. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 C C C UNOCAL A19-RD TRADING BAY ALASKA __SPERRY-SUN_WELL_SURVEYING_COMPANY PAGE__] ANCHORAGE ALASKA DATE OF SURVEY AUGUST ~'. lOOO. ~,~, COMPUTATION_DATE ........................ BOSS OYROSCOPIC_..SURVE~ ALIGUST 23, 1.9988 dOB NUMBER AK-BO-800.90 KELLY BUSHING ELEV. = 105.00 FT, OPERATOR-HARGER VERTICAL 'sECTION CALCUL'~'T~-D -~LONG CLOSURE MEASURED DEPTH 0 100 200 300 400 450 500 550 600 700 7._=,0 800 ,_-,._,[.~ '.-.-, 00 S.,50 ! 050 1100 1200 1300 1400 1500 1600 1700 1750 1800 2000 -'--' 1 A_ A_ '22AA TRUE SUB-S~A VERTICAL VERTICAL DEPTH DEPTH COURSE .... COURSE__ .... DOG-LEG ....................... TOTAL .............. INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAl DEG MIN DEGREES DEG/IO0 NORTH/SOLITH EAST/WEST SECTIO~ O. 100. 200. 300. 3Sx9. 44.9. 4~9. 548. 597. 646. 6'F, 4. 741. 788. 834. 877. :-.-'24. 1015. 1060. 1149. 1234. 1317. 13S.,7. 1474. 1549. 1586. 1623. 1698. 1773. I847. 1 ~21. GO ......... ',i GO O0 -5.00 O0 95.00 00 1.95.00 ~2 294.?2 73 344.73 31 394.31 O O N O. O E O.OO O.00 '-6':'-ij~i-' 0.0( · 0 5 S 42.30 E 0. O'P 0.06 S 0.05 E -0. 0 I N 52.10 E 0.0'~ 0.11 S 0.12 E -0. 0 17 N 40. 1 3 44 S 78.10 W 3.61 0.38 S 3.3'.~ W 3.~c":., 6 16 S 85.3.9 ..W 5.23 .......... O..'P4._S ..................... 7.71._W 7....4] 8 28 N 89.69 W 4.57 1.14 :s: 14.12 W 1:--:.7,':: 59 10 541.10 22 589.22 78 636.78 64 683.64 6.9 72.9.6.9 94 774.94 .90 81.9..90 38 ~10.38 443.5.9 10 46 N 84.50 W 4..91 4.92.53 ............ 12 ...... 47 .......N_81.- 0 W ................ 4.26 14 ""'" ,:,o N 78.60 W :~. 87 16 48 N 77.60 W 4.35 .... 19 ......5 ..... N_77._1.? W 4.5.9 21 37 N 77.19 W 5.06 24 15 N 77.1.9 W 5.26 26 '.-' N 79.10 W 3. '~ '~ 25 55 N 85.60 W 5.70 24 37 S 83. o0 W 4.70 W ...... 2..17, W 4 '~-~ . o. 5'~ W ............. 2,51 W z.65 25 15 __ ,~ .:. 81.,.6..'~_ 1044.51 29 27 S 80. ~'~_-9. 112.9..9.9 33 2 S 81.3.9 1212.58 12.92.60 38 8 S 80.60 1369.75 40 52 S 7~.89 .......... 1444.28 42___ 43 S 81_._10 1481.14 42 18 S 86.50 1518.41 41 1~' ' o S 88.80 1~'~'-~ 70 41 0 S :~'~ · _... ~,. ......................... ,_ ,~, ._ 1~_ 1668. ,~,,_oA 41 31 S 88.60 71 .955.71 51 -9.9 .=,8 60 75 2:] 14 41 70 P,2 1742 '-"--' . ,=,.~ 43 6 01 . 1816.01 ............ 42 ..... 48 0.67 S .--.'--"~'. 46 W 22. r c.).. O. 64 N '-"-' S"" ~D." . .- ,-, W -.3'.:" ,'-"' .,:...: "2,. ," 2.76 N 44.24 W 44.14 =' .=,~ N 57.4? W 57.6x_- - o,-, N 72..=;'-' ........ .' W 73. 1::'. 78 N ,_,'--"-?... 48 W 'PO . ~,_ 17. ~'~. 9. N 1 O,z,. 48 W 10'F'. '8..", ................ 21.44 N 12?. 27_ W __ 1:31 .. 0:'- 24.o6 N 150.'74 W 152.?¢ '..'._-:,'- '- 78 N 193.4'? W 1 '.-.?4. ,=:c' ~ _.~.1.12. N ............ 214._:_-':7.... W ...... 215..06 14.15 N .r,=,-, .-,=c, 84 ~..J.-- 7:~W . _ .' ._l ~..~ . 6.18 N 311 03 W 308.'-'s ............... '2.19 S ......... 366.74 W _.361_._~9 11.54 S 425..97 W 4 ! t-,'. 06 W 2. W 2. W 7. W 3. W ................ O. W 0. o'-' 88. AC/_. W 1 . ...... S ._ 88.6'?_ W ............... O. 78 22.32 S 488.66 W 47~.33 02 .............33.31 S ............. 554.40_W ................ 542.,_58 35 36.96 S 58~.96 W 575.18 66 38.33 S 621.26 W 607.86 50 ................. 40.06_S .......... 687.05_W ............. 672.59 58 41..90 S 752..97 W 737.43 58 43.48 S 820.26 W 803.67 2~ ....... 45.03 S ............ 888.38_W .870._74 ( C C UNOCAL A19-RD TRADING BAY ALASKA ............. SPERRY,SUN.WELL..SURVEYING__COMPANY -- VERTICAL SECTION CALCULATED. ~Lo-~5-CLOSLIRE PAGE___2_ ANCHORAGE ALASKA DATE OF SURVEY ALIGLIST COMPUTAT I ON DATE ....................... BOSS._ GYROSCOP I C._ SURVEY .... AUGUST 23, 1988 ,_lOB NLiMBER AK-BO-80090 KELLY BLISHING ELEV. = 105.00 FT. ...................................... OPERATOR-HARGER ........ MEASURED ("~'EPTH 2:300 2400 2500 2600 2700 26:00 2'PO0 3000 3100 3200 3300 3400 3500 3600 · ';, 3700 ,. .-,o(.)0 3900 4000 4100 4200 4300 4400 4500 4600 ._ 4650 4700 4750 4800 4?00 5000 TRUE '--'1 IR--c'FA VERTICAL VERTICAL DEPTH DEF'TH 1793.94 2067. 10 2140.07 2212.76: o .-,._] =. 74 54 2433.33 2511.80 · >~gA 55 .... 2735. ?7 2c, A~ op 2874.77 2944.09 ~'] 3./-~ ~I * I~I ~I · z,O,z,o. 77 31=.-. ,-,~ :~oc,:~ 19 :3291,84 .... ~o 64 3~27, 62 3497, 63 '35~9, 15 ~64~. ~7 3~77, 60 37~4.26 3751.29 oT.=:R 79 ._i __ i_ _ I :3864.47 :3941. 18 COURSE ..... COURSE I~CLINATION DIRECTION DEG M I N DEGREES DOG-LEG TOTAL ............. SEVERITY RECTANGULAR c:OORDINATES VERTICAL DEG/IO0 NORTH/SOLITH EAST/WEST SECTION 188:3.94 43... 31 S 1962.10 42 25 S 2035.07 43 49 S 2107.78 42 52 S 2180.74 43 25 S 2253.54 43 7 S 2328.33 40 3 S mo w o. 89. OW 1. 88.89 W 1. 89.50 W 1. 89.50 W O. 89.89 W O. 88.50 W 3. 2406.80 36 32 S 6:8.89 W 3. 24:35.55 ...... 39 32 .......... S_ .88 ..30_._ W ............ 3. o~.~ C) 5 -~. ~ ......... ~..., 43 47 S 6:7.,_,.°¢.~ W 4. 26:~o. 97 46 8 S ,-,o . .- _. o,_,. 1 "T~ W '-". 2700.._' :: ....... 45 ....56 S 88._10_ W O. ~.7/_-..-y, 77 46 10 S ~:d, 80 W 0, 2839, 09 46 4 S 88, 39 W 0. 2908. z. = · '-' =,.:, .......... 45 46 .......... S_88..=,9_ W 0. 2978.77 45 10 S 88.10 N O. :3:04:_--:. ,-,= . . o._, 45 5(3 S 88.1'~ N 0 :3:118.19 46. .... 21__ S ,S:8._19_..N .............. 0. 3186. :34 46 56 S :38.50 W O. ~:c,.~4 64 47 40 o 88.60 W 0 :~ 60 W 1 o.-~_ ~.-, 62 46 39 S ..... :--:392.63 44 28 N 86.89 W 3. 3464.15 44 13 N 84.60 W 1. 3536.17 43__39 ........... N _ o0.50 _. W ............. 2. 3572.60 42 46 N 77.30 W 4. · -,/. t"),--.' · m · ,:,,_',,..'-.26 42 54 N 76 10 W 1 3646. '2'P ............ 41 ....... 3£) ........ N _74.69.. W ............... 3. ""~'~'"' 79 41 19 N 7:":. 69 W 1 ...', t', i-,._',. · --'~.=;'-~ 47 4(3 17 N 70.89 W 2. .-, ,_-, .-.,,/. , - o,_ ...... 18 39 31 N 67.19.. W ...... 2. .................. 72 46..=;'-' '-' '-?=' 7:3 'u""'-' '"'--' · - .4. .-, 2: .J 0 · W ; . -, c",. v'--, 11 47.8.3 S 102'4.94 W 1005.2'2 40 ............ 49. '" .... __ . _ o,;, S ......... 1093. z'.-.~ N 1072.55 04 50.04 S 1161. :;':3 W 1140,.,_~'.'::"; 54 .=,o_.. 64 ._, '=' 1230 . ._,.- W 12¢)7.69 40 51 O0 S 129F;. c,/. N 1 .~7._,. 3/_-, '-."-'. 51 '70 S "" 5 '- '-' 1 ._-,6...~...- N 1340.78 52 ._,'='-'._-,...,':'":'~ S 1427.17 W 1401 . 77 02 54 '=:'-' o 1488.77__W ......... 1 ................' '... ~ . '--' ........... 2/-, 57 o.=; '--' 1555.19 W 1 ._ .--. ..... :, . .=;.z, 7 67 5:/., 5'.:.7.45 :E; 1/-,'.-,5. '-, ' =,- _ ...... =. o W 1 ._, .-./7.0/-, 20 ............. 61..77'._ S .......... 1697.75 ... W ...... 1667..79_ . ' :'~ ,--, 55 6:3 72 S 1769.73 W 17~o.60 84 79 31 /:.,5.48 ._,':' 1 1 . W 1 '-' ' '-o o ;~.._.=;,'-'-.. :30 67 48 'q lO1':: 60 W l:q:qO. 15 .............. I _'~ ........... .' '.- · .......... -- .... . y,_,4.86 W 1950..s .7. 6Lq ,/_-,9 66 :_-'; 1 c o 66 71,96 :=; '-'C'=' -. _ .-'- .,._,,_-,, 16 W 52 74 '.'- 3 '-' -- - 2:: 212:::.. 1 ':' W .......~U': 1 ..... 11_ ................... I .. ~,i . -- i_l .... · 62 76 '::'--' '=' '-' '~-' ''~ C) ,=, 6 W 2162 60 .-:,.-,2.<I . 74 78.18 S 2274.34 W ~.-'~4 90 ............... - ................. "" '" (3 w _. 26 7? :~.'3 S 2:347,66 W .......... ..-o./._16 32 77.69 S 2419.02 W 2377.92 63 72.52 S 2488.71 W 2447.57 90 ............ 63.54..S ..............2557.49W ........ 2516._91_ 72 56.?6 S 2591.08 W 2551.11 65 49.13 S 2624.16 W 2585.01 37 .................... 4(3 .67 . _..~ _ ............. z6._,6 ,67_W .... 261° ~, ... 4 .~':' _ 37 31.67 S 2688.50 W 2651.27 10 11.82 S 2750.74 W 2715.83 49 11 09 N oo . ~-s, W .... 2778.54_ .......... ~,~ 1 c) ............... C UNOCAL A19-RD TRADING BAY ALASKA SPERRY-SUN_WELL__SURVEYING_COMPANY ANCHORAGE ALASKA COMPUTATION_DATE AUGUST 23, 1988 VERTICAL SECTION 'CAE~.-Lli~T-EK,-'~LONG CLOSURE __E'AGE.~:: DATE OF SURVEY AUGUST 22, 1988 BOSS.GYROSCOPIC_SURVEY JOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. OPERATOR-HARGER TRUE MEASURED VERTICAL OEF'TH DEPTH 5100 4017, 5200 4092, 5300 4166, 5400 4239. 5500 4314. 56,00 4391, 5700 4470. 5800 4550, 5900 46.30. 6000 4710. 6100 4790. 6200 4870. 6300 4950, 6400 5032· SUB-SEA COURSE VERTICAL INCLINATION DEPTH BEG MIN. 85 3912.~5 97 3987.97 34 4061.34 . . . 57 4134.57 71 4209.71 91 4286.91 54 4365.54 25 4445.25 21 4525.21 25 46C._,.~5 23 4685.23 17 4765.17 74 4845.74 76 4927.76 ' 6500. . 5117·15 = ~ · _,OIL. 15 6600 ~^~' 62 ~r'9° 62 6700 5290.88 5185.88 6800 5378.24 5273.24 6900 5465.87 5360.87 7000 5553.82 5448.82 7100 5641.84 5536.84 7200 5729.91 5624.91 7300 5819.17 5714.17 7350 5864.36 5759.36 COURSE DIRECTION DEGREES DOG-LEG SEVERITY BEG/lO0 TOTAL REC]:~NGLILAR c.'O0-~D i N-ATES NORTH/:=-:OUTH EAST/WEST VERTICAL SECTION -~0 21 N 65 · ~o~ W 42 13 N 65.39 W 43 22 N 65. 0 W 42 28 N 64.30 W 40 6 N 65.89 W 38 49 N 64.50 W 37 29 N 61.80 W 36 48 N 61.60 W 37 0 N 61 AP · ~ W 36 39 N 61. 0 W 37 7 N 60.80 W 36 42 N 6O.39 W _ .. -- 35 ~,5 N 60.19 W 33 49 N 60.69 W 31 3 N 61.39 W .... 29 13 N 61.39 W 2~ 13 N 61.80 W __2~ I N_61..60 z,D 34 N 61.30 28 16 N 60.69 28 ..... 22 N_61._0~. 28 9 N 62.69 2~.~ 25 N 61.69 2~ 13 N 61.60 ....... ' ._ ...... I 18 36 64 N '~'--'~-'~ ~'~ · . .- ,"i,..~ ~ . .,_, i W 1 90 '-" '-'~' E. .... . N 2929.63 W . C' 1 17 92 '-'= ........... . ................ .:,._, .N .......... 1.30_W ....... 1.02 121.50 N 3052.84 W 2.5:-.? 14'.-?. 30 N .3112.67 W __1.56 ...... 1.75.94._N ........ 3170.36 W 13 ~_.._. ,_.~-.-,0'~, A'~, N ._'~'-"'-'=... ~._,. 47 W 69 ~.,,~'-'c"~-. 45 N 3278.64 W 22 260.9'2 N 3:3:31 ~ 1 W .................... _ -- · ~.l 5-9 289.61 N '-'""'~-' · c,~,,:,4.14 W 4.'----,' 318.81 N 3436.60 W 48 348. '-"'~ . _ ~..~ N 3488.9~: W 79 377.64 N '-'= .... · -',.,40. ~:-~ W 1 >Z 4 .*._,. N E,'4 3590.11 W 2.81 ........... 431.,81..N_. ...... 3637 .... 04 W. I 82 ~ '"~ _ . . ~._,._.c,._ N 36:~1 12 W 0.20 479.07 N 3724.07 W 2840.67 2904.27 2969.6! 3034.91 3098.32 3159..44 3218.19 3275.15 3331.79 3388.22 3444.56 __3500.?2 3556.1~ 3609.69 3660..0Z 3707.33 3753.36 W 0 '~':-' 502 15 N _ 3766 ..93_ W~_3799,_27._ __ · a%. '...~ .............. -- . · ..... W 0.47 ._ .-' ._,5'-'=. 17N.:,~.,,.,'-'°'"¢~.-. · 24 W ,:,'-"-"* '-~-,:, ~ -, ,/- '-~'=,..:, W 0 41 548.24 N '-"-'='] 6:7 . ,:..:.,-.¢ W 3889 '--'":' · i . ,s,..i ,.,..i · -~ ~ .,,-, ,. W ............. 0 17 571,,:,E . N ........... ' '-"-'-' .... 3o ;/4 '--: 1 .. W ............ 3'-733.. 85_ W O. ,q3' 593, 70 N 3934.07 ~ 3978.56 W 2 7Y 614 71 N 397:-': · · ,~.., W 4021.21 ~' ~:"-~"72 · 78 .. W 4041 .... 38 W 0.41 624 ~--,6 N HORIZONTAL DISPLACEMENT = 4041 .~o - ~'~MC' .o._. FEET AT NORTH :_~1 DEG. 6 MIN. WEST AT MD = xo._., THE CALCULAT I ON PROCEDuREs 'ARE 'B~'~'I:i'-6N'-'TH-IS-"iJS~--"°-~-'¥~REE"-D'i'MENS I ON~qi, Fi'A:, ~'5~-::~-P---ELiR'V~'~O~E--"i~-~:~-6'~' ......... UNOCAL A19-RD TRADING BAy ALASKA SPERRY-SUN WELL_SURVEYING. COMPANY ......................... ANCHORAGE ALASKA COMPUTATION_DATE AUGUST 23. 1'~'~'~oo .... PAGE__Z DATE OF ._,URVEY AUGUST 22, 1:~88 dOB NUMBER AK-BO-80c)90 KELLY BUSHING ELEV. = ............................. OF'ERATOR-HARGER 105.00 FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH MEASURED DEF'TH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH ...... NORTH/SOUTH ....... EAST/WEST___DIFFERENCE VERTICAL CORRECTION 0 O. O0 -105.00 O. 00 O. O0 O. 00 1000 .':T~7A A2 ~"":' 02 25.05 N~__ 172 48 W 29 ¢~'=-'. .............. 29. . · . i_-iO,~. ..................... · ................ · ; ~, .......... . ... _ .__ 2000 177:3.8:3 166:3.8:3 41. :aC) S 752. '~7 W 226.12 196. 14 3000 251 I80 24A/-,. _ ,:,~"(.) 53.3~ S 1427 17 W 488 20 ~'~-'" 08 4000 ..... 3223 .19 ......... ._P, 118 .19 74.23 S__2128.18 W __ 776.81 ...................... '/o,_-, .'-'-"-' 61 5A00 3.941.18 .'-:A3A___~. 18 I 1 .09 N 2810.62 W 1A~'''..~,o 82 282.01 6000 4710 25 4605 25 289.61 N ,-- o,:,-, 14 W 1 '-":' o '-."--' C, '~) · · ~,_~ 75 7000 .~,~.'9,~ ,c,'2 '='""'?' 82 .'9,,',0 24 N 3850 87 W 144/_', 1':' --'""~'--' ... -,~,._ · . 156.44 7:350 ~,~/_-,4 o6 575'2 36 624.'RA~ N Ao,~-~ 7:3 W 1 64 3'? 46 · I ....~ .. ~ · THE CALCLILATION F'ROCEDURES ARE BASED ON THE USE OF THREE D I MENS I ONAL RADI L.:,... OF CURVATURE METHOD UNOCAL A19-RD TRADING ALA._KA __SPERRY-SUN_WELL_SURVEYING_COMPANY ANCHORAGE ALASKA COMPUTATION DATE AUGUST 23, 1~'~'~.. o,~ PAGE = DATE OF SURVEY AUGUST 22. 198:3 dOB NUMBER AK-BU-,=,O0;O KELLY BUSHING ELEV. = 105.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN I00 FEET OF SUB-SEA DEPTH MEASURED -DEPTH ...... TRuE .... VERT I CAL DEPTH z, LIB-:=,EA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEPTH NORTH/SOLITH EAST/WEST D I FFERENCE VERT I CAL CORRECT I ON 0 105 205 305 405 505 607 711 817 927 1038 1149 1264 1384 1509 1640 1775 1908 2041 OI 105. 205. 305. 405. 505. 605. 705. 805. 905. 1005. 1105. 1205. 1305. 1405. 1505. 1605. 1705. 1805. O0 O0 O0 00 O0 O0 O0 O0 O0 O0 -105. O0 O. 00 O. 00' O. O0 0.00 0.06 S 0.06 E 0.00 100.00 0.10 S 0.12 E 0.00 ~. ~.~ 0.00 0 .11 N 0 .0,_,° W 0.00 300.00 0.44 S 3.76 W 0.09 400.00 1.13 S 14..97 W 0.76 500.00 0.'P1 N 34.26 W 2.66 600.00 6,26 N 60.67 W 700.00 14.25 N 95.97 W 800.00 23.32 N 141.~'A W 00 ............. '~00.00 24, 24_N .,. 188, 72 W__ O0 1000,00 17, 87 N ,-~o,'"~-' 05 W 00 1100.00 9. ]= . ~:c, N 292 24 W AO ........... 1200. O0 O. 87 S__ 357.85._W 00 1300.C) 0 12.50 S 431.75 W O0 1400.00 26..91 S 514.44 W 00 ............. 1500.00 37...90_S~_ 605 ,.01_ W O0 1600.00 40.23 S 692.52 W O0 1700.00 42.57 S '~' 7c~o. 54 W O. O0 O. O0 O. O0 O. 09 ....... O. 67 1.90 6.26 ............................ 3./_-,0 ................ . ~. 66 6 40 2~ 87 10.21 33. M'". .......... ~,_~ ......... ~ .... 10 71. 44.42 10.84 59.49 15.08 79.53 ..... 20.04 104.44 24.91 135.01 30.57 170.44 35.43 203.34 32.~1 236.59 33.25 C C UNOCAL A19-RD TRADING BAY ALASKA SPERRY..--SUN. WELL_SURVEY I NO._.. COMPANY ...... ANCHORAGE ALASKA COMPUTATION._DATE AUGUST 23, lcAA~ _~ PAGE__6. DATE OF SURVEY AL;GUST 22, 1'-'~'~' dOB NUMBER AK-BO-800S~O KELLY BUSHING ELEV. = 105.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ( MEAo_IRED sdEPTH TRUE VERTICAL DEPTH - --Si_iBSsEA VERTICAL DEPTH TOTAL ....................................................... RECTANGULAR COORDINATES MD-TVD VERTICAL ___NORTH/SOUTH__EAST/NEST__DIFFERENCE ......... CORRECTION (- 2178 2315 2451 2589 2726 2862 2991 3118 3255 3399 3543 3687 3830 3973 4119 4267 1905.00 2005.00 2105.00 2205.00 2305.00 2405.00 2505.00 2605.00 2705.00 2805.00 2905.00 3005.00 3105.00 3205.00 3305.00 3405.00 4410 3505.00 4549 3605.00 4687 3705.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 44.69 S 873.55 W 46.74 S 967.28 W ._ 48.44 S 1059.77 W 49.98 S 1154.70 W 50 '~P ~' .~ o 1248.55 W 51.3~ S 1340.~2 W 53.21 A 1422.07 W ._,..,.20 ~. 1500.87 W 58.43 S 1593.72 W 61.76 S 1697.36 W 64.39_S 1801.21W 67.24 S 1~04.71W 70.37 S 2006.21W 73.63 S ~210~. 76,69 S oo ~14. 79.17 S 77.3o_s 68.62 S 51.20 S 273 18 36 ='- . . ,_l 310.26 37. 346.48 :36. 384.38 37. 421 ? 52 .................:'::7, 1 457.67 36.15 4 ~:.' A. 50 --:., c, ,-,.-, 51"': ~::, 27 36 · z. -'/' .................. 550.40 36. .-4 ._, >'4.4.., 44.05 ,~ ._ o. 65 , 44. 1 682.60. 43.95 725.11 '-' - 4..-. 11 W 768.64 4:~: 94 W ,_Al4 . 2~c:'-'- 45. 64 2323. 70 W oo..'"---'~' '~-. 05 47. 77 2426.24 W '"~P=' : .... __. . .-..,._,. :; 2 ........................ 4:::. 25>Z.~ 1 ~ W 944.89 s:~?. 57 2615 80 W 982.'~= . ~._, :37.46 C C UNOCAL A19-RD TRADING BAY ALASKA SPERRY-SUN_WELL_SURVEYING_COMPANY ANCHORAGE ALASKA COMPUTATION DATE --. AUGUST 23, 1988 PAGE 7 DATE OF ~.URVEY AUGUST 2;~, lO8::: ,_lOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = OF'ERATOR-HARGER 105.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~MEASLIRED (..~EF'TH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH NORTH/SOLITH EAST/WEST DIFFERENCE CORRECTION 4821 4953 5083 5216 5353 5487 5616 5743 5868 5993 6118 6243 6366 6485 6601 6716 6830 6944 7058 3805.00 3905.00 4005.00 4105.00 4205.00 4305.00 4405.00 4505.00 4605.00 4705.00 4805.00 4905.00 5005.00 5105.00 5205.00 5305.00 5405.00 5505.00 5605.00 3700. 3800. 3900. 4000. 4100. 4200. 4300. 4400. 4500. 4600. 4700. 4800. 4900. 5000· 5100. 5200· 5300. 5400. 5500. 00 27.67 S 2702.18 W 1016.59 34.24 O0 O. 36 S 2783. O0 W 1048.05 .'--:1.46 00 32.18 N 285'P 54 W 1078 13 30 o,-, 00 6:=:. 40 N 2939.55 W 1111. 24 J':,:_--:. 11 O0 107.77 N 3024.24 W 1148.08 36.84 O0 145.91 N 3105.15 W 1182.26 34.18 O0 180· 48 N 317:~. 86 W 1'-'~.I1.8(:) ~'~":'... 54 O0 216.30 N 3248 74 W 12:38.41 '~'/- 61 .......................... · ............................... .m:- -m · ............ O0 251.94 N 3314.77 W 1263.4:3 ..'-'5... ¢--,.~ O0 287.71 N 3380 72 W 1 '-'~"-' · -'¢,,=,. 45 '-'~- .~_ · .~.,..~. ¢')'.~' OO 324.26 N 3446 36 W 131'~ ._-., ~:-q , --.,=' ¢-~,-, .. O0 361 11 N 3511 46: W 1~"-"'~ · . ~,~,. 43 24.90 O0 396.74 N 3573.8~ W 1361.5:=] 2:3. 15 O0 __428.27 N 3A30. ~= ,.. _ ...-, W ....... 1380.7::: ......................... 1 q' 20 ...... OO 456. """" ,'-~ N 3681.80 W 13'~6.59 15.81 O0 482.81 N 3731.03 W 1411.1 '] 14.5,.-.? O0 ._.=,r.)'-~-.,', 2' 1 N 3779..,._99 W ........ 1 zi.'~,~._ ..................................... 61 14 43 00 535.40 N 3827 ',71 W 1439 · , · ,_ ....I I · :,. '.'.".'4 O0 561 71 N 3874.9. 1 W 1453. 13 1 C ./ L'. SP~ERR¥_-SUN_WP'LL_$URVEYING_COMPANY UNOCAL A19-RD TRADING BAY ALASKA ... PAGF~8_ ANCHORAGE ALASKA COMPUTATION_DATE AUGUST 23, 1988 DATE OF SURVEY AUGUST'.~22'~:~y1~ ?8,=, ~' JOB NUMBER AK-BO-80090 KELLY BUSHING ELEV. = 105.00 FT. OPERATOR-HARGER__ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ........................... TRue ........ s-LiB-~SEA '" 'EASURED VERT I CAL VERT I CAL .,EPTH DEPTH DEPTH 7171 5705.00 5600.00. 7~84 5805.00 5700.00 ~.-,u 5864.36 5759.36 TOTAL RECTANGULAR COORDINATES MD-TVD .... NORTH/SOLITH____EAST/WEST___DIFFERENCE ....... 587.58 N 3922.22 W ~ 1466.74 611.49 N 3967.94 W 1479.27 624.86 N 3992.78 W 1485.64 VERTICAL CORRECTION 13.61 __12.53 6.37 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRT -SUN 5CATE :- i INCH TQ 500.00 / 500.0 TRADING BAT UNSCAL Atg-RO AUGUST 22. AK.-80-80090 t988 TRUE ?350 40[0 DO ~5 no 15~o. co -io[o:oo HOR I ZONTRL PROJECT T O'N 4ORTH ~00.00 O. O0 l_50O. OO SPERRY -SUN 0.00 5CRL6 :- 1 TRROING R19-RO RK-80-80090 INCH TO 1500.00 / 1500.0 UNOCRL RUGUST 22, 1988 1500. O0 3000.00 4500.00 8000.00 ~ VERTI~CRL ~7350 I 1500. OO 3O~O. OO 1 4500. O0 PROJECT~ON Unocal Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District TO: 3ohn Boyle LOCATION: Anchorage ALASKA OIL & GAS CONSERVATION CONNISSION Transmitting as Follows: Regarding: Trading Bay Field DOCUMENT TRANSMITTAL October 12, 1988 HAND DELIVERED FROM: R.C. Warthen LOCATION: Alaska District One (1) seoia and one (1) blueline of Compensated Neutron Gamma Ray log - A-l~RD well One (1) copy of Gyrodata survey report - A-16 well .... ACKNOWLEDGE RECEIPT~ PLEASE 8~Y~:S~i~C-~I~ND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL ~IVED BY: · DATED: ~ . . . . ,~,,~-~:~.~ Unocal Oil & Gas DivisiO Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL September 16, 1988 HAND DELIVERED TO: Oohn Boyle FROM: R.C. Warthen · LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL ~ GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Field - A-19RD One (1) blueline and one (1) sepia of Dual Induction Focused Log/Gamma Ray O~oOrne (1) copy of Directional Survey~ e ('l) magnetlc tape wlth lls~lng RECEIVED By:PLEASETRANSMITTAL. THANK You.ACKNOWLEDGE RECEIPT. ~~.BY ~-~'~~ ~~iSiGNiNG ~' 'IV~D~~ AND.~. :~RETURNING~i,~,% ONE~.~..~.COPY~/~.i~~. - DOCUMENT,.. DATED: ~~'ka Oil & G~.s C6ns. uo~r~missiort Telecopy .No. (907) 276 7542 Suly 15, 1988 Candi Lockwood 'Unocal P"O Box 190.2/+7 Anchorage, AK 99519-0247 Res Trading' Bay State well A-19 Dear PIs LockWo°d, The.or£ginal_ AFl number assigned co the subject well was 133 20151 00. In 1981, the American Petroleum Institute directed that 600 be added' ~o the quadrangle code for al1 offshore wells. In 1988, well A-19 was redrilled and erroneously assigned APl number 133-20!$I-01. -'In accordance with the APl directive, the number of the redrill should be 733-20151-01. Please contact me if you ha~ any questions. Sincerely, W W Barnwell ConraC'ss ioner Jo/E.BRS.1 February 19, 1988 ~. Roy D, Roberts Environmental Engineer Union Oti COmPany of California P. O. Box 190247 Anchorage, Alaska 99502 'Telecopy: (907) 276-7542 Re: Trading Bay State A-19 RD Union Oil Company of California Permit No. 88'01 Sur. Loc. 1625'FSL, 562'FEL, Sec. 4, TgN, R13W, SM Btmhole Loc. 2295'FSL, 4683'FEL, Sec. 4, TgN, R13W, SM Dear Mr. Roberts: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in-scheduling field work, please notify this office 24 hours prior to co_m~_encing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Unocal Oil & Gas Divr~ ? Unocal Corporation 1835 Knoll Drive, P.O. Box 6176 Ventura, California 93006 Telephone (805) 656-7600 UNOCAL Western Region February 01, 1988 Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Minder, Attached is a revised Redrill Procedure for A-19 that includes the changes you requested. Also attached is an Application for Sundry Approvals to abandon the existing perforations in A-19 before the well is redrilled. If there are any additional questions, please contact me at (805) 658-7600. Respect/lly, . A J '~ Z.~erhil 1~~~/ Alaska District Drilling Superintendent Union Oil of California 0481N RECEIVED le ® ® ® Se ® 8~ e 10. TBS A-19 RD Permit to Drill Redrill Procedure RIH with 8-1/2" bit to 3900'. Pressure test casing to 1500 psi. Polish off kick off plug to 4000'. POOH and pick up bent sub and mud motor. Orient wellbore and begin redrilling. After drilling 10' of new formation perform LOT. Redrill 8-1/2" hole from 4000' to 7600' MD. Run open hole logs. Run and cement 7" liner. Run CBL-VDL-GR in both the 7" and 9-5/8" casing. Test the 9-5/8" casing, 7" liner and lap to 1500 psi. Perforate and profile "C" and "D" zones. Acidize if necessary. Run single injection string. (3-1/2", N-80. 9.2#/ft, Seal Lock thread, plastic coated tubing.) Place well on injection. Note: Due to the presence of H2S on the platform, H2S monitoring equipment will be utilized in accordance with AOGCC 20AAC25. 0481N(2) MONOPOD MUD PIT SCHEMATIC RESERVE PIT (300 BBLS) SHAKERI EQUIPMENT TRIP TANK (28 BBLS) MIXING PIT (SO BBLS) Mixing pit io one level below the aotive 8yetem ¢100 BBLS) SHAKER DEMANDER 100 BBI_8 E)ESILTER 8UC'FION PIT (100 BBL$) 1) Reserve Pit 2). Degaeeer 3) 2-Shakers 4) Pit Level Indioator (Visual & Audio) 5) Fluid Flow Sensor 6) THp .Tank 7) Pit Agitators E~) Deoander 9) De$11ter 10) Mixing Pit Unocal Oil & Gas Dix~ ~rt Unocal Corporation 1835 Knoll Drive, P.O. Box 6176 Ventura, California 93006 Telephone (805) 656-7600 UNOCAL( Western Region February 01, 1988 Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Minder, Attached is a revised Redrill Procedure for A-19 that includes the changes you requested. Also attached is an Application for Sundry Approvals to abandon the existing perforations in A-19 before the well is redrilled. If there are any additional questions, please contact me at (805) 658-7600. Respect~lly, ~ h~nR,~erhill~ ' Alaska District Drilling Superintendent Union Oil of California 0481N ® ® ® ® Se e 0 9, 10. TBS A-19 RD Permit to Drill Redrill Procedure RIH with 8-1/2" bit to 3900'. Pressure test casing to 1500 psi. Polish off kick off plug to 4000'. POOH and pick up bent sub and mud motor. Orient wellbore and begin redrilling. After drilling 10' of new formation perform LOT. Redrill 8-1/2" hole from 4000' to 7600' MD. Run open hole logs. Run and cement 7" liner. Run CBL-VDL-GR in both the 7" and 9-5/8" casing. Test the 9-5/8" casing, 7" liner and lap to 1500 psi. Perforate and profile "C" and "D" zones. Acidize if necessary. Run single injection string. (3-1/2", N-80. 9.2#/ft, Seal Lock thread, plastic coated tubing.) Place well on injection. Note: Due to the presence of H2S on the platform, H2S monitoring equipment will be utilized in accordance with AOGCC 20AAC25. 0481N(2) MONOPOD MUD PIT SCHEMATIC RESERVE PIT (300 BBLS) ISHAKER I EQUIPMENT TRIP TANK (28 BBL8) TO MUD PITS MIXII4Gi PIT (50 Mixing pit ia one level below the active eyetom (1OO BBLS) SHAKER DESANDER '100 BBL$ E)ESlL.TER SUCTION PIT (100 BBL$) 1) Reaerve Pit 2) Degaaaer 3) 2-~hakers 4) Pit Level Indioetor (Viaual & Audio) 5) Fluid Flow Seneor 6) THp Tank ?) Pit Agitatore 1~) Deeander O) Deallter 10) Mixing Pit TBS A-19 PERFORATION RECORD MEASURED DEPTH VERTICAL DEPTH 5560' - 5654' 4322' - 4391' 5858' - 6020' 4541' - 4660' 6166' - 6176' 4764' - 4771' 6204' - 6247' 4792' - 4822' 6390' - 6404' 4925' - 4935' 7347' - 7365' 5585' - 5598' 7408' - 7450' 5629' - 5658' 7454' - 7468' 5661' - 5671' 7576' - 7614' 5743' - 5768' 7618' - 7624' 5771' - 5774' 7628' - 7670' 5777' - 5805' 0441N ~ STATE OF ALASKA ./'""~ ALASKA .~IL AND GAS CONSERVATION f,,.,,'ClMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill ,~l.lb. Type of well. Exploratory ~ Stratigraphic Test [] Development Oil Lq] Re-Entry [] Deepen_,. Service ~- Developement Gas ~ Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California- 101' RT above MSL feet Trading Bay Field 3. Address . 6. Property Designation P. O. Box 190247 Anchorage, AK 9'9519-0247 ADL-18731 Trading Bay C & D "4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1625'N, 562~W f/SE Cor., Sec 4 TgN, R1-3W, S~ Trading Bay State Statewide-Nat'l Fir At top of productive interval 8. Well number Nur~C~r. Co of Hartford 4130'TVD 195'N, 3015'W F/Surface Location TBS A-~9~Z) B5534278 .. At total depth 9. Approximate spud date Amount 6080'TVD 670'N, 4121'W F/Surface Location February 1 19~ ~ $200,000 · , 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD a,d TVD) property line 3575' feet 460' F/A-30 feet 3840 7600'/6080' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 4000' feet Maximum hole angle47 0 Maxirnumsurface 1590 psig At total depth (TVD) 1800 psig 18. Casing program Settin~l Depth _ size Specifications Top Bottom . Quantity of cement Hole Casing Weight. Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2 7" 29# N-80 Buttres~ 4100' 3500' 2883' 7600' 6080' 528 cuft 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ E", ~ Present well condition summary Total depth: measured 9259' feet Plugs (measured) Cmt Ret @ 7750' true vertical 6894' feetDEC Effective depth: measured 7750' feet Junk (measured) ....... . ._:.~;: .~L U~ & OaS CoilS. C0111! true vertical 5857' feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 1070' 13-3/8" 1300 sx 1070' 1035 ' Intermediate Production 6154' 9-5/8" 1800 sx 6154' 4756' Liner 3178' 7" 500 sx 6034'-9212' 4670'-6859' Perforation depth: measured See Attached true vertical 20. Attachments Filing fee ~ Property plat FI, BOP Sketch ~2 Diverter Sketch [] Drilling program E~ Drilling fluid program [~ Time vs depth plot .Fq, Refraction analysis m Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and corre~the best of my knowledge Signed D.' Title Environmental Engineer Date 12/31/~,7 Roberts Commission Use Only Permit Number I APInumber IApprovaldate iSeecoverletter <~- I 50--"]'~ ~ - '2 Ol.~' I - OI 02/19/88 for other requirements Conditions of approval Samples required ~ Yes [] No Mud log required ~'Yes ,'-q, No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes ~ No Required working/,~sure for BOPE Fq2 ; ,~'3M; ~ 5M; ~ 10M; ~ 151',4 Other://~'( i.---~ ~.~.~ by order of Approved by Commissioner the commission Date 10-401 Rev. 1-85 · * " "'-,~-:::-:-~ !ANGLED FILL UP LINE - "' "?~'HYDRIL ' ~' . ":20 ~ ''~ '"~" ",t..??{:..~ ~}"BLiN~SHEAR RAMS ", :' ' ~ .v ~ ~. :.~.~~ ,~ ......................................... ~' '- -.'- ':'~ :"~"~::5 '~:"/ ' '~''PIPE RAMS ' ' . '%::~':~ ' ~:?[;.- ' -r' ................. MANIFOLD' -.- > ,, ' ~,~;~'~'~. ~ ~. ~ ":' ~ ' ' ' ......... : .' ~ ,~ .' . ~ : '. ':": SEE DRAWING ..,.~ .... ~.~_.:;~':"- ' ~ '.?'-~ .-'- ~.~- . --.-- ~ ..... '~ . ~ .,~ ..... :-,,~ OM"MUD'PUMPS : ..~OTES: ~. ~.YDRAUL[C VALVES OPEN WE~. NA~E;:' ~- / ~ ~U, TO~~CA~LY WHEN' '" · RIG CONTRACTOR:. DIVEETER IS CLOSED. RIG:- ~ ~ - ~o~D ....... 'STACK PREE~URE RATING: ~00~ 2.. FLEX; NOSE ~) I~ TO BE USED ,~, · C~OKE MNE SlZ~ ~ BSP; ,, ~"-~~' IF NECESSARY WITH DDS.~ .... . . . ............ , NOTE: ALE. CHANGES MUST HAVE WRITTEN APPROVAL .APPR_O~'~_~:' . . BY THE DISTRICT DRILLING SUPERINTENDENT~ ,/ . ,, 'DEPT. APPROVAL R[v. j DATE ~ · DRAWN BHE CKD. CGN ~.W,I 6/17186 .. - SCALg: N 0 N E 5M OR 1OM ALL DRILLING OPERATIONS " UNION OIL coMPANY OF CALIFORNIA ANCHORAGE, ALASKA SHEETS j SHEET TBS A-19 RD PROCEDURE: l® 0 0 0 Se ® ® Be 0 Kill well. Install and test BOPE. Recover production equipment. Test 9-5/8" casing to 2500 psi. Abandon existing "C" & "D" completion with cement. Plug back and cut window from 4000' to 4060' MD. Perform LOT. Redrill 8-1/2" hole from 4000' to 7600' MD. Run logs. · Run and cement 7" liner. Perforate and profile "C" & "D" zones. Acidize if necessary. Run single injection string. Place well on injection. Time: 40 DAYS 0441N (7) WELL $,CHEHATIC PRESENT PROPOSED - REDRILL "C" & "D" DUAL INJECTOR "C' & "D' SINGLE INJECTOR 13 3~8" C. 1 O70' DUAL 2 7/8" TO :1::5844' DUAL 2 3/8' BELOW :1:5844' SINGLE ~5 1/2' PLASTIC COATED "DSS-HTC' CONNECTIONS DUAL PACKER 5504' "C' ZONE PERFORATION~ 5560' - 5654 5858' - 6020 6166'- 6176 6204' - 6247 63g0' - 6404 TOP 7" 6034' 9 5/8" C. 6154' ~D~_ZONE PERFORATIONS 7347'- 7365' 7408'- 7450' _ - 7454'- 7468' 75'/0'- 7614' 7618'- 7624' 7628'- 7670' 7" LINER FROM. 6034'~ g217' ETD 7750' CEMENT RET. TOP 7' ,3500' TOP 9 5/8'J WINDOW @ ±4000' DUAL PACKER 7302' 2 3/8" PERM. PKR 7481' 2 3/8" PERM. PKR 7560' PERM. PKR. ±5500' "C" & "D" ZONE SELECTIVELY PERFORATED FROM ±5550' to ±7400' 7' LINER FROM ±3500' to ±7600' JRU/JCL A-19 REDRILL A.P.D. MUD PROGRAM DEPTH WEIGHT Ft PCF FUNNEL VIS PV YP SEC/QT dn/cm2 #/100 ft GELS #/100 ft VOLUME BBLS 4,000 - 7,600' 75-80* 35-45 8-10 60-30 12-20 1000 * Or as required by well cOnditions. 0 441N (6) 12/17/87 Robert T. Anderson District Land Manager Alaska District Unocal Oil & Gas k :;ion Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) October 30, 1987 Mr. Lonnie Smith AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Smith, Unocal intends to complete two water injectors at Trading Bay Field (Honopod Platform) for itself and its working interest partner, Marathon, featuring comingled Tyonek "C" and "D" zone injection. The subject wells are TBS A-25 and proposed A-19 RD. Comingled "C-D" injection has not been previously pursued 'but is now a preferred mode of operation. Comingled injection is consistent with Rules 8 and 9 of Conservation Order 93. Unocal intends to monitor the comingled injectors by running injection~'~ profiles on at least an annual basis. Data will be no less accurate for~' estimating individual sand injectivity than if two separate injection strings were used. Advantages of comingled injection are outlined in the attached two pages. A modified application for sundry approval for A-25 and an initial application for A-19RD will be sent to your office in the near future. If you have any questions, please contact Steve Lambert. jed/O459r Respectfully, · ~//' rson / RECEIVED NOV- ]987 Naska 011 & I~as Cons. Commission Anchorage It is proposed to comingle Tyonek "C" and "D" zone water injection on the Honopod at Trading Bay Field. Given that: A. Trading Bay Field is in a late stage of development. B. Tl~e formerly waterflooded "C" and "D" zones still hold a large share of reserves. C. Flexibility of well completions must be afforded to maximize long-term well utility. D.. All "C" and "D" sand recoveries would benefit from a reinitiation of waterflooding which was sharply curtailed during 1984 and shut-in during mid-1986. E. Investment must be minimized to continue development of the Trading Bay Field Honopod platform. It appears that comingled "C-D" water injection would increase ultimate field recovery. 1. 'Comingled "C-D" injection extends expected life and usefulness of injectors by: a. eliminating chance of losing one injection string for mechanical reasons. b. eliminating loss of zonal injection caused by tubing leaks. c. allowing through-tubing profile modifications and stimulation of "C" zone injectivity. d. allowing for coiled tubing cleanouts of "C" intervals. e. gaining these benefits without being forced to drill two single string injectors. 2. Comingled "C-D" injection will allow injected water to preferentially enter sands with the highest degree of need for voidage fill up. 3. A single string completion allows for wireline injection profiles to be run across both "C" and "D" zones. a. estimates of injection volume breakdowns for individual sands in the "C" and "D" zones is no less accurate in a comingled "C-D" injector than would be similar estimates for a "C" or "D" single string injector. RECEIVED NOV - 1987 Naska Oil & Gas Cons. Commission Anchorage SUMMARY OF BENEFITS With a single string comingled "C" and "D" zone injector: - no compromise would be made as to data on individual sand injection. - well life and thus ultimate field recovery would be increased by eliminating potential for future mechanical problems. - remedial well work is afforded to all subject intervals, thus increasing well life and ultimate recovery. - lowered investment allows marginal projects to be implemented and the recovery of otherwise excluded reserves. - increased well life and recovery extends viable life of Monopod, increasing chance of new development to take place. RECEIVED NOV- 3 1987 Alaska Oil & Gas Cons. Commission Anchorage ITEM APPROVE DATE (2 thru 8) (3) Admin CHECK LIST FOR NEW WELL PERMITS Company U~, o~ O.~ Cc. cA C ~i: Co~:~a Lease & Well No. "~A.:~ ~¥ '[~~RX '~ ~ YES NO S 1. Is the permit fee attached .......................................... ~ · (8) (9 thru (10 and 13) ' (4) Casg (14 thru 22) (23 thru 28) ~) -Ici 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day.wait ...................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19.. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate .or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached./f~ Does BOPE have sufficient pressure rating - Test to ~O~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31) (6) Add: Geology: WVA Eng~ne~g~ing: LcS ?~'~_~ BEW For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of Seabed conditions presented 32. Additional requirements ............................................. ~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE rev: 01/28/87 6.011 o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX~ No special 'effort has been made to chronologically organize this category of information. PR OGR Start LIS exec ution: Tue RE:VISION: 4.0 5 SEP 88 9:40p PART NUMBER: W5550-PE32 HELL DATA FILE : WO3472.WDF ECC: 3~72.00 COMPANY NAME: UNION OIL CALIFORNIA WELL NAME: A-19 R.D FIELD: TRADING BAY UNIT LOCATION: Top of Well: 3323.000 Bottom o'f' We.l'!: 7492.000 Le-ve.1 Spacing: 0.500 NUMBER OF CURVES: 25 DEPTH AC CA'L CCL CCL1 CN CNC CSSN GR GR02 RIiLM SP SPD SPD02 SSN TTEN02 CHT CILD CLSN LSN RFOC RILD TEMP TEN TTEN COMPANY:U!NI'ON OIL CALIFORNIA WELL:A-19 RD FIELD: TRADI'NG BAY COUNTY: KENAI STATE: ALASKA TAPE INFORMATION DEPT 7492.000 7292.000 7092.000 6892.000 FILE:MAIN .001 FILE INTERVAL: START= CHT CILD SPO TTEN TEMP 722.168 117.149 -999.250 -999.250 0.000 875.754 325.582 -977.230 0.000 869.856 120.841 -999.250 -999.250 0.000 896.704 138.247 7492.000 GR02 CN ENO= 3323.000 AC RFOC RILM RILD CNC GR SSN LSN 49.675 93.288 3.075 5.515 8.536 -999.250 -999.250 -999.250 -999.250 -999.250 43.935 86.17t 5.227 3.280 3.071 -?99.250 -999.250 -999.250 -999.250 -999.250 79.027 86.700 8.445 7.702 8.275 -999.250 -999.250 -999.250 -999.250 -999.250 71.706 7.102 6.275 7.233 669~.~00C[ 872. 769 30,220 0,000 6492.000 847,998 30,185 O, 000 6292.000 816,911 30,827 0,000 6092.000 891 -701 30,997 0,000 5892.000 844,027 31,809 0,000 5692.000 839.880 32,100 0.000 5492,000 798,932 29,021 0,000 5292.000 818,572 28,847 O. 000 5092.000 844,005 29.330 0,000 4892,000 81 2,565 29,858 O. 000 4692.000 819.806 30. 2411 0,000 4492,000 809. 785 30,130 0.000 4292.000 822,760 29,814 0,000 4092.000 -999.250 29,997 -999,250 3892.000 -999.250 30.385 -999,250 3692. 000 -999. 250 30.076 -999,250 3492.000 -999,250 30.477 -999.250 3323,000 -999,250 29,997 -999,250 W!ELL OATA FILE: ECC: COMPANY NAME: WELL NAME: FIELO: LOCATION: ToP of We'll: Bottom of 'WelI: LeVel sp. ac'~ng: 284-413 44'864 93.036 3,751 3.499 3,516 2816,265 25,180 29.180 32,109 309,042 161.778 55,361 23,472 123,975 106,677 20,591 18,115 2877.512 93,426 97,426 22.276 127,355 25,081 17..887 36,711 127.570 74,408 39,995 55,908 2901.254 98,034 102,034 29.359 108.019 16.710 156'695 38,356 96.567 7.223 6,507 6.382 2748.237 3t ,752 35,752 33.638 178,409 55.554 193.555 84.243 87,177 5.295 5,482 5,166 2672,215 34.322 38,322 57,083 139,885 31 ,728 219,486 85.767 134.611 3,547 4,073 4.556 2603,955 66,350 70,350 54.965 118.132 23.479 91,700 41'142 104,406 9,296 9.997 10,905 2528.876 32,280 36.280 31.514 179.795 52,362 60.715 29,637 133.335 17.245 11 .371 16,470 2402,485 104.482 108.482 23.228 104.607 I 5,513 116,577 40.854 62,477 18.771 11 .467 8,578 2352,6,65 1 8,864 22,864 34. 309 188. 228 48. 995 131.397 4'9,370 125,614 6.273 9.358 7,611 2259.651 87,991 91 .991 36,349 116,182 20,859 283,642 83.047 103,936 3,453 3,499 3,526 2195.715 37.698 41,698 52.673 168,575 43.193 235,251 80.747 109,639 4,110 3.913 4,251 2125.852 54,271 58.271 52,117 128,387 27,180 299,245 54.262 130.635 0,903 2.717 3,342 2032,982 62.801 66,801 38,861 111 .566 18,535 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 1914.749 60.893 64,893 30.419 122,153 24,196 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 1853.501 55.124 59.124 32,348 130,765 25,355 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 1804,756 110.590 114.590 10.868 104.998 18.963 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 1836,797 47,064 51.064 22,096 14'6,128 30.404 -999,250 -999.250 -999'250 -999.250 -999,250 -999,250 1781.022 102,744 106.744 37,547 114.989 17.998 WO3473,WDF 3472.00 UNION OIL CALIFORNIA 4-19 RD TRADING BAY UNIT 6721.000 6969.000 0.500 EPTH ~ ~CL CCL1 CLSN CN .SN '- SPD SSN TEN TTEN CNC CSSN GR F1LE:REPT .002 FILE INTERVAL: START= 6969.000 END= DEPT CN CNC GR SSN 6969.000 151.000 19.000 64.365 172.983 6721.000 LSN 41.996 676'9.000 44.870 48.870 57.372 146.075 37.370 6721.000 ~27.427 31.427 61.684 159.984 End: of e~ecUtion: Tue .:lapsed execution time = SYSTEM RETURN CODE = 0 5 SEP 88 9:44p 4'mJ. nutes, 28.0 seconds. 47.995 SPD 26.997 29.456 28.997 TTEN 2207.979 2822.575 2842.316
